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| issue date = 04/01/2010
| issue date = 04/01/2010
| title = Response to Request for Additional Information for the Review of the License Renewal Application - Environmental Document Request
| title = Response to Request for Additional Information for the Review of the License Renewal Application - Environmental Document Request
| author name = Franke J A
| author name = Franke J
| author affiliation = Florida Power Corp, Progress Energy Florida, Inc
| author affiliation = Florida Power Corp, Progress Energy Florida, Inc
| addressee name =  
| addressee name =  
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=Text=
=Text=
{{#Wiki_filter:0Progress Energy Crystal River Nuclear Plant Docket No. 50-302 Operating License No. DPR-72 April 1, 2010 3F0410-04 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001 Ref: 10 CFR 54 50 0ý
{{#Wiki_filter:0Progress Energy Crystal River Nuclear Plant Docket No. 50-302 Operating License No. DPR-72 Ref: 10 CFR 54 April 1, 2010 3F0410-04                                                                               50          0ý U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001


==Subject:==
==Subject:==
Crystal River Unit 3 - Response to Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278) - Environmental Document Request


==References:==
==References:==
(1)    CR-3 to NRC letter, dated December 16, 2008, "Crystal River Unit 3 -
Application for Renewal of Operating License" (2)    NRC to CR-3, letter dated March 5, 2010, "Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278)"


Crystal River Unit 3 -Response to Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278) -Environmental Document Request (1) CR-3 to NRC letter, dated December 16, 2008, "Crystal River Unit 3 -Application for Renewal of Operating License" (2) NRC to CR-3, letter dated March 5, 2010, "Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278)"
==Dear Sir:==


==Dear Sir:==
On December 16, 2008, Florida Power Corporation (FPC), doing business as Progress Energy Florida, Inc. (PEF), requested renewal of the operating license for Crystal River Unit 3 (CR-3) to extend the term of its operating license an additional 20 years beyond the current expiration date (Reference 1). Subsequently, the Nuclear Regulatory Commission (NRC), by letter dated March 5, 2010, provided a request for additional information (RAI) concerning the CR-3 License Renewal Application (LRA) and a request for documents (Reference 2). The Enclosure to this letter provides the response to the request for documents. A response to the RAI is being provided in a separate letter (CR-3 letter 3F0410-03 dated April 1, 2010).
On December 16, 2008, Florida Power Corporation (FPC), doing business as Progress Energy Florida, Inc. (PEF), requested renewal of the operating license for Crystal River Unit 3 (CR-3) to extend the term of its operating license an additional 20 years beyond the current expiration date (Reference 1). Subsequently, the Nuclear Regulatory Commission (NRC), by letter dated March 5, 2010, provided a request for additional information (RAI) concerning the CR-3 License Renewal Application (LRA) and a request for documents (Reference 2). The Enclosure to this letter provides the response to the request for documents.
No new regulatory commitments are contained in this submittal.
A response to the RAI is being provided in a separate letter (CR-3 letter 3F0410-03 dated April 1, 2010).No new regulatory commitments are contained in this submittal.
If you have any questions regarding this submittal, please contact Mr. Mike Heath, Supervisor, License Renewal, at (910) 457-3487, e-mail at mike.heath@pgnmail.com.
If you have any questions regarding this submittal, please contact Mr. Mike Heath, Supervisor, License Renewal, at (910) 457-3487, e-mail at mike.heath@pgnmail.com.
ce President Crystal River Unit 3 JAF/dwh  
ce President Crystal River Unit 3 JAF/dwh


==Enclosure:==
==Enclosure:==
Response to Request for Documents xc:      NRC CR-3 Project Manager NRC License Renewal Project Manager NRC Regional Administrator, Region II Senior Resident Inspector Progress Energy Florida, Inc.
Crystal River Nuclear Plant 15760 W. Power Line Street Crystal River, FL 34428
PROGRESS ENERGY FLORIDA, INC.
CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50 - 302 / LICENSE NUMBER DPR - 72 ENCLOSURE RESPONSE TO REQUEST FOR DOCUMENTS
U. S. Nuclear Regulatory Commission                                                      Enclosure 3F0410-04                                                                              Page 1 of 5 RESPONSE TO REQUEST FOR DOCUMENTS The following requests for additional information are needed by the U.S. Nuclear Regulatory Commission (NRC) staff to complete its review of the Crystal River Nuclear Generating Plant, Unit 3 (CR-3) application for license renewal and prepare the draft supplemental environmental impact statement. To support the staff's continued review of the CR-3 environmental report (ER), please provide the information and documents described below. Those items marked with letter and number (i.e., AQ-1, H-2, etc.) refer to corresponding items in the Revised Environmental Site Audit Needs List dated October 6, 2009.
RAI 1 - Cumulative Impacts NRC staff must evaluate the cumulative impacts of extended operation of all reasonably foreseeable activities. The following information is needed to complete the cumulative impact evaluation.
: 1.      Provide information on the status of the refurbishment activities discussed in Section 3.2 of the ER. Also, provide information on when the power uprate amendment is expected to be submitted.
===Response===
The response to this request is being submitted in a separateletter.
: 2.      Provide information on the resources that would be affected by the construction of the proposed Levy County nuclear plants' cooling tower discharge line to the CR-3 discharge canal. Also provide a summary of impacts the potentially chemically-treated cooling water from the Levy County plants may have on the CR-3 discharge canal.
===Response===
The response to this request is being submitted in a separateletter.
RAI 2 - Air Quality and Meteorology
: 1.      Provide documentation demonstrating that Progress Energy submitted an application to renew its Title V permit to the Florida Department of Environmental Protection (FL DEP) on or before the renewal application due date of July 5, 2009, specified in the permit and that the renewal application was accepted by FL DEP, allowing the Title V Permit to remain in effect past its expiration date during FL DEP's processing of the renewal application.
===Response===
Refer to the enclosed document "RAI 2-1 Title V Permit."
U. S. Nuclear Regulatory Commission                                                  Enclosure 3F0410-04                                                                          Page 2 of 5 RAI 3 - Aquatic Ecology
: 1.      Provide a summary of releases from the Progress Energy Mariculture Center 1992-2008.
===Response===
Refer to the enclosed document "RAI 3-1 CrystalRiver MaricultureCenter Juvenile Releases."
: 2.      Progress Energy 2009 - Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida;
===Response===
Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida."
: 3.      Ager et al. 2008 - Crystal River Power Plant Fish Impingement Study Report.      Please provide the entire report, if possible. Otherwise provide the following:
* Executive Summary
* Chapter 2 (including the figures and tables)
* Tables 4 through 11, 13 through 20, and 34 through 40
* Figures 3 through 4, 6 through 19
* Appendices 1 through 32
===Response===
Refer to the enclosed document "RAI 3-3 Crystal River Impingement Report March 3, 2008."
: 4.      Copies of the 1993-1995 Seagrass Monitoring Reports, November 2001 Seagrass Recovery Report, the 2008 Seagrass Quantification Report, and the final report of the Seagrass Technical Advisory Committee.
===Response===
Refer to the enclosed documents:
            *  "RAI 3-4  CR Seagrass TechnicalAdvisory Committee Final Report,"
            *  "RAI 3-4  CrystalRiver 1993 SeagrassStudy,"
            *  "RAI 3-4  CrystalRiver 1994 SeagrassStudy,"
            *  "RAI 3-4  CrystalRiver 1995 SeagrassStudy,"
            *  "RAI 3-4  CrystalRiver November 2001 SeagrassSurvey, " and
            *  "RAI 3-4  Seagrass QuantificationReport_4-24-08."
: 5.      TP-042 Marine Turtle Permit (the current annual permit).
===Response===
Refer to the enclosed document "RAI 3-5 Marine Turtle Permit."
U. S. Nuclear Regulatory Commission                                                    Enclosure 3F0410-04                                                                            Page 3 of 5
: 6. AQ-1 (Also T-20) - The response letters from National Marine Fisheries Service (NMFS) and Florida Wildlife Commission regarding listed species and sensitive habitats were not provided (only the Fish and Wildlife Service (FWS) response letter was provided).
Correspondence from NMFS and Florida or a statement that none exists should be provided.
===Response===
Refer to the enclosed document "RAI 3-6 National Marine Fisheries Service Letter."
In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.
: 7. Provide copies of the reports prepared by Applied Biology, Inc (1983), Florida Power Corporation (FPC) (1978b), FPC (1 982b). Complete citations for these reports are listed on page 4-2 of the 316 Study.


Response to Request for Documents xc: NRC CR-3 Project Manager NRC License Renewal Project Manager NRC Regional Administrator, Region II Senior Resident Inspector Progress Energy Florida, Inc.Crystal River Nuclear Plant 15760 W. Power Line Street Crystal River, FL 34428 PROGRESS ENERGY FLORIDA, INC.CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50 -302 / LICENSE NUMBER DPR -72 ENCLOSURE RESPONSE TO REQUEST FOR DOCUMENTS U. S. Nuclear Regulatory Commission  F0410-04 Page 1 of 5 RESPONSE TO REQUEST FOR DOCUMENTS The following requests for additional information are needed by the U.S. Nuclear Regulatory Commission (NRC) staff to complete its review of the Crystal River Nuclear Generating Plant, Unit 3 (CR-3) application for license renewal and prepare the draft supplemental environmental impact statement.
===Response===
To support the staff's continued review of the CR-3 environmental report (ER), please provide the information and documents described below. Those items marked with letter and number (i.e., AQ-1, H-2, etc.) refer to corresponding items in the Revised Environmental Site Audit Needs List dated October 6, 2009.RAI 1 -Cumulative Impacts NRC staff must evaluate the cumulative impacts of extended operation of all reasonably foreseeable activities.
Refer to the enclosed document "RAI 3-7 Crystal River 3 Impingement Study (1978b)."
The following information is needed to complete the cumulative impact evaluation.
A statement that the other two requested documents could not be located is provided in a separate letter.
: 1. Provide information on the status of the refurbishment activities discussed in Section 3.2 of the ER. Also, provide information on when the power uprate amendment is expected to be submitted.
RAI 4- Hydrology
Response: The response to this request is being submitted in a separate letter.2. Provide information on the resources that would be affected by the construction of the proposed Levy County nuclear plants' cooling tower discharge line to the CR-3 discharge canal. Also provide a summary of impacts the potentially chemically-treated cooling water from the Levy County plants may have on the CR-3 discharge canal.Response: The response to this request is being submitted in a separate letter.RAI 2 -Air Quality and Meteorology
: 1. H-9 (also H-5) - Quarterly National Pollutant Discharge Elimination System, Industrial Waste Water, Domestic Waste Water monitoring reports (for past 5 years) with cover letters to the FL DEP. Provide the full reports and cover letters. Spreadsheets of sampling data were previously submitted, however the reports provide more comprehensive information on what was sampled, standards measured against, exceedances, explanations for exceedances, and corrective actions as well as maps and other useful information.
: 1. Provide documentation demonstrating that Progress Energy submitted an application to renew its Title V permit to the Florida Department of Environmental Protection (FL DEP)on or before the renewal application due date of July 5, 2009, specified in the permit and that the renewal application was accepted by FL DEP, allowing the Title V Permit to remain in effect past its expiration date during FL DEP's processing of the renewal application.
Response: Refer to the enclosed document "RAI 2-1 Title V Permit."
U. S. Nuclear Regulatory Commission  F0410-04 Page 2 of 5 RAI 3 -Aquatic Ecology 1. Provide a summary of releases from the Progress Energy Mariculture Center 1992-2008.
Response: Refer to the enclosed document "RAI 3-1 Crystal River Mariculture Center Juvenile Releases." 2. Progress Energy 2009 -Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida;Response: Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida." 3. Ager et al. 2008 -Crystal River Power Plant Fish Impingement Study Report. Please provide the entire report, if possible.
Otherwise provide the following:
* Executive Summary* Chapter 2 (including the figures and tables)* Tables 4 through 11, 13 through 20, and 34 through 40* Figures 3 through 4, 6 through 19* Appendices 1 through 32 Response: Refer to the enclosed document "RAI 3-3 Crystal River Impingement Report March 3, 2008." 4. Copies of the 1993-1995 Seagrass Monitoring Reports, November 2001 Seagrass Recovery Report, the 2008 Seagrass Quantification Report, and the final report of the Seagrass Technical Advisory Committee.
Response: Refer to the enclosed documents:
* "RAI 3-4 CR Seagrass Technical Advisory Committee Final Report,"* "RAI 3-4 Crystal River 1993 Seagrass Study,"* "RAI 3-4 Crystal River 1994 Seagrass Study,"* "RAI 3-4 Crystal River 1995 Seagrass Study,"* "RAI 3-4 Crystal River November 2001 Seagrass Survey, " and* "RAI 3-4 Seagrass Quantification Report_4-24-08." 5. TP-042 Marine Turtle Permit (the current annual permit).Response: Refer to the enclosed document "RAI 3-5 Marine Turtle Permit."
U. S. Nuclear Regulatory Commission  F0410-04 Page 3 of 5 6. AQ-1 (Also T-20) -The response letters from National Marine Fisheries Service (NMFS)and Florida Wildlife Commission regarding listed species and sensitive habitats were not provided (only the Fish and Wildlife Service (FWS) response letter was provided).
Correspondence from NMFS and Florida or a statement that none exists should be provided.Response: Refer to the enclosed document "RAI 3-6 National Marine Fisheries Service Letter." In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.7. Provide copies of the reports prepared by Applied Biology, Inc (1983), Florida Power Corporation (FPC) (1 978b), FPC (1 982b). Complete citations for these reports are listed on page 4-2 of the 316 Study.Response: Refer to the enclosed document "RAI 3-7 Crystal River 3 Impingement Study (1978b)." A statement that the other two requested documents could not be located is provided in a separate letter.RAI 4- Hydrology 1. H-9 (also H-5) -Quarterly National Pollutant Discharge Elimination System, Industrial Waste Water, Domestic Waste Water monitoring reports (for past 5 years) with cover letters to the FL DEP. Provide the full reports and cover letters. Spreadsheets of sampling data were previously submitted, however the reports provide more comprehensive information on what was sampled, standards measured against, exceedances, explanations for exceedances, and corrective actions as well as maps and other useful information.
If the quarterly data is summarized in annual reports, then therannual reports may be submitted instead of the quarterly reports. Because these documents can be large, electronic files can be submitted in lieu of hardcopies.
If the quarterly data is summarized in annual reports, then therannual reports may be submitted instead of the quarterly reports. Because these documents can be large, electronic files can be submitted in lieu of hardcopies.
Response: Refer to the enclosed National Pollutant Discharge Elimination System (NPDES), Industrial Waste Water (IWW), and Domestic Waste Water (DWW) documents:
 
* "RAI 4 2005 NPDES Reports,"* "RAI 4 2006 NPDES Reports," o "RAI 4 2007 NPDES Reports,"* "RAI 4 2008 NPDES Reports,"* "RAI 4 2009 NPDES Reports,"* "RAI 4 2005 IWW Reports,"
===Response===
U. S. Nuclear Regulatory Commission F0410-04 Page 4 of 5* "RAI 4 2006 IWW Reports,"* "RAI 4 2007 IVWV Reports,"* "RAI 4 2008 IWVV Reports,"* "RAI 4 2009 IWVVW Reports,"* "RAI 4 2005 DWW Reports,"* "RAI 4 2006 DWW Reports,"* "RAI 4 2007 DWW Reports,"* "RAI 4 2008 DWW Reports," and* "RAI 4 2009 DWW Reports." RAI 5 -Terrestrial Ecology 1. T-7 -Provide the tables, figures, and appendices from the report "Environmental Support Document, Crystal River Unit 3, South Cooling Tower Laydown Area, Citrus County Florida." Response: Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida." 2. T-10 -The November 5, 2009, request for additional information response provided a map of the percolation ponds and an FWS wood stork colonies core foraging areas map, but there is no explanatory text provided.Provide a brief description of wood stork use of the site along with an explanation of how the two figures relate to that use.Provide the source for the FWS wood stock map so it can be properly cited.Response: The response to this request is being submitted in a separate letter.3. T-14 -No information was provided on measures to protect threatened or endangered species during transmission line ROW maintenance.
Refer to the enclosed National Pollutant Discharge Elimination System (NPDES), Industrial Waste Water (IWW), and Domestic Waste Water (DWW) documents:
The letter from the FWS to Progress Energy (October 28, 2008) regarding impacts to the listed eastern indigo snake provides recommendations for mitigation for this species when carrying out transmission line maintenance, including the submission of a protection/education plan that, if implemented, would result in a "may affect, not likely to adversely affect" determination.
            *   "RAI 4 2005 NPDES Reports,"
Provide a transmission line ROW maintenance plan per the recommendations of the FWS to protect the eastern indigo snake and its habitat that includes the protection/education plan referenced above.Response: The response to this request is being submitted in a separate letter.
            *   "RAI 4 2006 NPDES Reports,"
U. S. Nuclear Regulatory Commission F0410-04 Page 5 of 5 4. T-17 -Provide information on the potential effects of cooling tower drift on terrestrial vegetation of the CR-3 site. Has deposition of particulates (salt drift) from cooling towers plumes resulted in any damage to vegetation or increased salinity of soils? Provide salt drift study reports for the years when helper towers were added. If no reports exist, then a statement that no such information exists should be provided.Response: Refer to the enclosed documents:
o   "RAI 4 2007 NPDES Reports,"
* "RAI 5-4 Crystal River Salt Drift Correspondence,"* "RAI 5-4 Crystal River Salt Drift FDEP Response, " and* "RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report." In addition, a statement regarding the impact of salt drift from cooling towers is provided in a separate letter.5. T-20 (Also AQ-1) -Provide all responses from correspondence with the State of Florida regarding threatened and endangered species. If no responses were received from the State, provide a statement to that effect.Response: Refer to the enclosed Florida Natural Areas Inventory (FNAI) documents: " "RAI 5-5 FNAI Central Florida Report," and" "RAI 5-5 FNAI Lake Tarpon Report." In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.
            *   "RAI 4 2008 NPDES Reports,"
rwaoo*ýU. S. Nuclear Regulatory 3F0410-04 Documents Enclose Response to Request for Documents 1.N RAI 2-1 Title V Permit 4 2009 NPDES Reports 2. RAI 3-1 Crystal River Mariculture Center Juvenile 19. RAI 4 2005 Industrial Waste Water Reports Releases.3. RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling 20. RAI 4 2006 Industrial Waste Water Reports Tower Laydown Area, Citrus County, Florida.4. RAI 3-3 Crystal River Impingement Report Mar 3 21. RAI 4 2007 Industrial Waste Water Reports 2008 5. RAI 3-4 CR Seagrass Technical Advisory 22. RAI 4 2008 Industrial Waste Water Reports Committee Final Report 6. RAI 3-4 Crystal River 1993 Seagrass Study 23. RAI 4 2009 Industrial Waste Water Reports 7. RAI 3-4 Crystal River 1994 Seagrass Study 24. RAI 4 2005 Domestic Waste Water Reports 8. RAI 3-4 Crystal River 1995 Seagrass Study 25. RAI 4 2006 Domestic Waste Water Reports 9. RAI 3-4 Crystal River November 2001 Seagrass 26. RAI 4 2007 Domestic Waste Water Reports Survey 10. RAI 3-4 Seagrass Quantification Report_4-24-08  
            *   "RAI 4 2009 NPDES Reports,"
: 27. RAI 4 2008 Domestic Waste Water Reports 11. RAI 3-5 Marine Turtle Permit 28. RAI 4 2009 Domestic Waste Water Reports 12. RAI 3-6 National Marine Fisheries Service Letter 29. RAI 5-4 Crystal River Salt Drift Correspondence
            *   "RAI 4 2005 IWW Reports,"
: 13. RAI 3-7 Crystal River 3 Impingement Study 30. RAI 5-4 Crystal River Salt Drift FDEP Response (1978b)14. RAI 42005 NPDES Reports 31. RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report 15. RAI 4 2006 NPDES Reports 32. RAI 5-5 FNAI Central Florida Report 16. RAI 4 2007 NPDES Reports 33. RAI 5-5 FNAI Lake Tarpon Report 17. RAI 4 2008 NPDES Reports Progress Energy PROGRESS ENERGY FLORIDA, INC.CRYSTAL RIVER ENERGY COMPLEX LICENSING  
 
& REGULATORY PROGRAMS (NAIB)15760 W. POWER LINE STREET CRYSTAL RIVER, FL 34428-6708 U.S. Nuclear Regulatory Commission Attention:
U. S. Nuclear Regulatory Commission                                                     Enclosure 3F0410-04                                                                             Page 4 of 5
Document Control Desk 11555 Rockville Pike Rockville, Maryland 20852 RETURN AND FORWARDING POSTAGE.GUARANTEED U. S. Nuclear Regulatory Commission 3F0410-04 Response to Request for Documents RAI 2-1 Title V Permit NOTICE OF FINAL PERMIT In the Matter of an Application for Permit by: Florida Power Corporation Permit No. 01 70004-024-AV dba Progress Energy Florida, Inc. Crystal River Power Plant 299 First Avenue North Title V Air Operation Permit Renewal Mail Code CN77 Citrus County St. Petersburg, Florida 33701 Responsible Official: Mr. Larry Hatcher, Plant Manager Enclosed is the final permit package to renew the Title V air operation permit for Crystal River Power Plant. The existing facility is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. This permit is issued pursuant to Chapter 403, Florida Statutes.Any party to this order has the right to seek judicial review of it under Section 120.68 of the Florida Statutes by filing a notice of appeal under Rule 9.110 of the Florida Rules of Appellate Procedure with the clerk of the Department of Environmental Protection in the Office of General Counsel (Mail Station #35, 3900 Commonwealth Boulevard, Tallahassee, Florida, 32399-3000) and by filing a copy of the notice of appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The notice must be filed within 30 days after this order is filed with the clerk of the Department.
            *   "RAI 4 2006 IWW Reports,"
Executed in Tallahassee, Florida.Trina Vielhauer, Chief Bureau of Air Regulation TLV/jh/sm CERTIFICATE OF SERVICE The undersigned duly designated deputy agency clerk hereby certifies that this Notice of Final Permit (including the Final Permit and Final Determination), or a link to these documents available electronically on a publicly accessible server, was sent by electronic mail with. received receipt requested to the persons listed below: Mr. Larry Hatcher, Progress Energy Florida, Inc.: larry.hatclier@pgnmail.com Mr. Dave Meyer, P.E., Progress Energy Florida, Inc.: dave.mever@pgnmail.com Mr. Scott Osbourn, P.E., Golder Associates, Inc.: sosboum@golder.com Ms. Cyndy Wilkinson, Progress Energy Florida,, Inc.: cyndy.wilkinson@pgnmail.com Ms. Danielle Henry, DEP -SWD: danielle.d.henry dep.state.fl.us Ms. Susan Machinski, DEP -SD: susan.machinski@,dep.state.fl.us Ms. Katy Forney, U.S. EPA Region 4: forney.kathleen@epamail.epa.gov Ms. Ana Oquendo, EPA Region 4: oquendo.ana(aepamail.epa.gov Ms. Barbara Friday, DEP -BAR: barbara.friday~dep.state.fl.us (for posting with U.S. EPA, Region 4)Ms. Victoria Gibson, DEP -BAR: victoria.gibson@dep.state.fl.us (for reading file)Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to Section 120.52(7), Florida Statutes, with the designated agep4\clerk, receipt of which is hereby Florida Department of Environmental Protection I. V( I C~IJA Bob Martinez Center 2600 Blair Stone Road Tallahassee.
            *   "RAI 4 2007 IVWV Reports,"
Florida 32399-2400 PERMITTEE:
            *   "RAI 4 2008 IWVV Reports,"
Florida Power Corporation dba Progress Energy Florida, Inc.299 First Avenue North Mail Code CN77 St. Petersburg, Florida 33701 Permit No. 01 70004-024-AV Crystal River Power Plant Facility ID No. 0170004 Title V Air Operation Permit Renewal The purpose of this permit is to renew the Title V air operation permit for the above referenced facility.The existing Crystal River Power Plant is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. UTM Coordinates are: Zone 17, 334.3 km East and 3204.5 km North. Latitude is: 280 57' 34" North and Longitude is: 820 42' 1" West.The Title V air operation permit is issued under the provisions of Chapter 403, Florida Statutes (F.S.), and Florida Administrative Code (F.A.C.) Chapters 62-4, 62-210, 62-213 and 62-214. The above named permittee is hereby authorized to operate the facility in accordance with the terms and conditions of this permit.Effective Date: January 1, 2010 Renewal Application Due Date: May 20, 2014 Expiration Date: December 31, 2014.\ !;Joseph Kahn< Director Division of Air Resource Management JK/tlv/jkh/sm FINAL DETERMINATION qPERMITTEE Florida Power Corporation dba Progress Energy Florida, Inc. (PEF)299 First Avenue, North Mail Code CN77 St. Petersburg, Florida 33701 PERMITTING AUTHORITY Florida Department of Environmental Protection (Department)
            *   "RAI 4 2009 IWVVW Reports,"
Division of Air Resource Management Bureau of Air Regulation, Title V Section 2600 Blair Stone Road, MS #5505 Tallahassee, Florida 32399-2400 PROJECT Permit No. 0170004-024-AV Crystal River Power Plant The purpose of this project is to renew the Title V air operation permit for Crystal River Power Plant.NOTICE AND PUBLICATION The Department distributed a draft/proposed Intent to Issue a Title V Air Operation Permit Renewal package on October 27, 2009. The applicant published the Public Notice of Intent to Issue a Title V Air Operation Permit Renewal in the Citrus County Chronicle on November 2, 2009. The Department received the proof of publication I.on November 5, 2009. A proposed permit was issued for EPA review on October 27, 2009.COMMENTS No comments were received from either the Public during the 30-day public comment period or from EPA during their 45-day review period; however, comments were received from the Permittee.
            *   "RAI 4 2005 DWW Reports,"
The comments are minor administrative corrections to the permit. The comments were not considered significant enough to reissue the draft Title V air operation permit and require another Public Notice, therefore, the draft/proposed Title V air operation permit was changed. Those comments are addressed below. Additions to the permit are indicated by a double underline.
            *   "RAI 4 2006 DWW Reports,"
Deletions from the permit are indicated by a st~ke thr mtgh.Email from Dave Meyer dated November 19, 2009 COMMENT 1. It is requested to add the following language to the end of Specific Condition A.L.: "Heat input shall be determined by coal analysis and the coal feeder scales, 24 hour average. The CEMs heat input value shall not be used." RESPONSE 1. A review in response to this comment resulted in the discovery that the following permitting note, which was contained in permit No. 0170004-003-AC, was inadvertently omitted in the draft/proposed permit. It has been reinserted following Specific Condition A.1.(Permitting Note: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operation to 110 percent of the test load), to establish appropriate emission limits and to aid in determining future rule applicability.]
            *   "RAI 4 2007 DWW Reports,"
COMMENT 2. Delete specific condition A.2.b. Bartow Unit 1 has been taken out of service.RESPONSE 2. Specific condition A.2. has been changed as follows: A.2. Methods of Operation.
            *   "RAI 4 2008 DWW Reports," and
: a. Fuels. The fuels that are allowed to be burned in these units are: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 1 of 6 FINAL DETERMINATION (1) Bituminous coal, (2) Bituminous coal and bituminous coal briquette mixture, (3) Distillate fuel oil for startup, and (4) Used oil in accordance with the specific conditions in Subsection J.7 (5) Oily flyash in aadridance with Spcifi o n.nditiens A.2.b. and A.26.b. Oily A7yash. These beenssins units may burn ily flyash (reuyahb) fredm Bar-tow Unit 1 int aMENT rdante with the fuellewing h ificc d Flyash. Only flyash freom e Baeigw Unit 1 may be burned in these emssions units.Onie the achufulated batklug ef Bantew Unit 1 flyash (cstimnatb d at approfxiately 13,000 tuns)is burned, 3 nTly the additional flyash grneratcd At Baflec Unit 1 shall be bund in thesercnsttsion urits.(2) Blend Rate Limeit. The aximum flyash blend rate shall not exaeed 2% of the total bcileri feed en a 'weight basis.[Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AG; and, 0170004-006-AC]
            *   "RAI 4 2009 DWW Reports."
In addition specific condition A.26. has been deleted as follows: A.26. Oily beusdash 0- eorfdkeein.
RAI 5 - Terrestrial Ecology
The a lowoerd fr opersatar shall mfuake and maintain the fmllwinb g ruedrds srt eaah day that flyash is burned in the boiler: a. Date and Unit numtiberm, b. Timfe period of flyash burning and start and end timfes-, e. Total quantity of flyash burned in tons per day, and d. Maximiumo flyash blend fate during perliod of fyash burn (percent flyash in total em ssiens unit fuel feed en a weight basis).[Rule 62 213.4110, F.A.C.; and Permfit No. 0170004 005 AO]Specific conditions A.27. and A.28. have been renumbered as A.26. and A.27., respectively.
: 1.     T Provide the tables, figures, and appendices from the report "Environmental Support Document, Crystal River Unit 3, South Cooling Tower Laydown Area, Citrus County Florida."
COMMENT 3. Quantifying the fuel density is appropriate for fuel oil, it is typically not measured for fuels such as coal. Change specific condition A.22.b. to read "Recordkeeping.
 
Record daily the amount of coal fired, the density opacityof each fuel, the Btu value, and the percent sulfur content by weight of each fuel." RESPONSE 3. The language in specific condition A.22.b. reflects the language in the air construction permit.The requested language was not found to be in an air construction permit for these units. Therefore, no change will be made.COMMENT 4. The wording in the current permit is not clear regarding flame stabilization.
===Response===
We want to clarify that fuel oil is used as an ignitor fuel and for low load flame stabilization.
Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document CrystalRiver Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida."
It is requested to change specific condition B.2.a.(2) to read "Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and low load flame stabilization fuel. Natural gas may be used as a startup and low load flame stabilization fuel.RESPONSE 4: Air construction permit 0170004-006-AC authorized No. 2 fuel oil to be used as an ignitor fuel and natural gas as a startup and low load flame stabilization fuel. The air construction permit did not authorize No.2 fuel oil to be used as a low load flame stabilization fuel. Therefore, no change will be made.COMMENT 5: One purpose of the Title V permit is to summarize the operating requirements.
: 2.     T The November 5, 2009, request for additional information response provided a map of the percolation ponds and an FWS wood stork colonies core foraging areas map, but there is no explanatory text provided.
We felt that it was appropriate to outline the opacity allowance in specific condition B.11. in the Title V permit to clarify when the opacity standard used is in effect. It is requested to add the following language at the end of specific condition B.11.: "The opacity standards set forth in 40 CFR 60.11 shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard.  
Provide a brief description of wood stork use of the site along with an explanation of how the two figures relate to that use.
[40 CFR 60. 11 ]" RESPONSE 5: The requested language is in Attachment NSPS A. The requested language from 40 CFR 60.11 is not applicable to excess emissions.
Provide the source for the FWS wood stock map so it can be properly cited.
Condition B.11. is from Rule 62.210.700, F.A.C. Please note that Rule 62-2 10.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
 
This is stated in the permit under the heading Excess Emissions.
===Response===
No change will be made.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 2 of 6 FINAL DETERMINATION COMMENT 6: Quantifying the fuel density is appropriate for fuel oil. It is typically not measured for fuels such as coal. Change specific condition B.25.b. to read "Recordkeeping.
The response to this request is being submitted in a separate letter.
Record daily the amount of coal fired, the density (f of each fuel, the Btu value, and the percent sulfur content by weight of each fuel." RESPONSE 6: The requested language was not found to be in an air construction permit for these units.Therefore, no change will be made.COMMENT 7: We have historically submitted our excess emissions report on a quarterly basis. Our intent is for the Title V permit to accurately reflect when we submit our excess emissions report. Change specific condition B.28 to read: B.28. Reporting Schedule.
: 3.     T No information was provided on measures to protect threatened or endangered species during transmission line ROW maintenance. The letter from the FWS to Progress Energy (October 28, 2008) regarding impacts to the listed eastern indigo snake provides recommendations for mitigation for this species when carrying out transmission line maintenance, including the submission of a protection/education plan that, if implemented, would result in a "may affect, not likely to adversely affect" determination.
The following reports and notifications shall be submitted to the Compliance Authority:
Provide a transmission line ROW maintenance plan per the recommendations of the FWS to protect the eastern indigo snake and its habitat that includes the protection/education plan referenced above.
Report Reporting Deadline Related Condition(s)
 
Notice of Excess Emissions Postmarked by the 3 0 th day following the B.13. and B.29 end of each g RESPONSE 7: Specific conditions B.13., B.28. and B.29. are conditions stating applicable requirements of 40 CFR 60 Subpart D relating to excess emissions and reporting.
===Response===
It is the intention of these conditions to bring to awareness federal requirements for excess emissions which the facility is subject. Subpart D requires excess emissions reporting every six months. The Department is not able to rewrite the federal regulations.
The response to this request is being submitted in a separate letter.
However, the facility may submit these reports more frequently if they choose to do so. No change will be made.COMMENT 8: Delete specific condition C.16. This is not required in our current TV permit. The above record-keeping is required in sections III.A. & B. We feel it is redundani to require this information in this section of the permit.RESPONSE 8: Condition C.16 has been deleted. Condition C.17. has been renumbered to C.16.COMMENT 9: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity Change specific condition D.14 as follows: D.14. The visible emissions test shall be a minimum of thirty minutes in duration.
 
Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statemfent of the approximfate ash transfer rate during the test shall be submfitted with each test report. Failure to submit the process tr-ansfier-rate, -And or operationf unider conditionis that are not representative of normal operations may invalidate the test and fail to provide reas.nable assurance of eemp.la.nee.
U. S. Nuclear Regulatory Commission                                                       Enclosure 3F0410-04                                                                               Page 5 of 5
Unit load will be utilized to assure 90 to 100% capacity during testing. [Permit No. AC09-235915]RESPONSE 9: The language in Condition D.14. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee.
: 4.     T Provide information on the potential effects of cooling tower drift on terrestrial vegetation of the CR-3 site. Has deposition of particulates (salt drift) from cooling towers plumes resulted in any damage to vegetation or increased salinity of soils? Provide salt drift study reports for the years when helper towers were added. If no reports exist, then a statement that no such information exists should be provided.
The language may only be changed through an air construction permit. No change will be made to condition.
 
COMMENT 10: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity.
===Response===
Change specific condition D.15. as follows: D.15. Reporting Ash Transfer Rate. A statem.ent f the appr-oximate ash transfer rate during the test shall be submitte'd wiit~h feaeh. compliance test report. Failure to submit the process tr-ansfer rate and o prto under conditions that afe not representative of normfal operations mfay invalidate the test and fail to provid-e reasonable assurance of comfipliance.
Refer to the enclosed documents:
Unit load will be utilized to assure 90 to 100% capacity during testing. Unit load shall be submitted with each compliance test report. [Permit No. AC09-235915]
            *   "RAI 5-4 Crystal River Salt Drift Correspondence,"
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 3 of 6 FINAL DETERMINATION RESPONSE 10. The language in Condition D.15. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee.
            *   "RAI 5-4 Crystal River Salt Drift FDEPResponse, " and
The condition may only be changed through an air construction permit. No change will be made to condition.
            *   "RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report."
COMMENT 11: The current TV permit utilizes the below wording. We prefer this wording as it allows more flexibility in determining the test operating rate (fuel flow may difficult to measure).
In addition, a statement regarding the impact of salt drift from cooling towers is provided in a separate letter.
Electrical output may be a better indicator.
: 5.     T-20 (Also AQ-1) - Provide all responses from correspondence with the State of Florida regarding threatened and endangered species. If no responses were received from the State, provide a statement to that effect.
E.17. Operating Rate During Testing. Testing of emissions shall be conducted with the generator(s) operating at 90 to 100 percent of the maximum fuel firing rate for each generator.
 
If it is impracticable to test at permitted capacity, an emissions unit may be tested at less than the minimum permitted capacity (i.e., at less than 90 percent of the maximum operation rate allowed by the permit); in this case, subsequent emissions unit operations may be limited to 110 percent of the test load until a new test is conducted, provided however, operations do not exceed 100 percent of the maximum operation rate allowed by the permit. Once the emissions unit is so limited, operation at higher capacities is allowed for no more than 15 consecutive days for the purpose of additional compliance testing to regain the authority to operate at the permitted capacity.
===Response===
Failure to submit the actual operating rate may invalidate the test. [Rule 62-297.310(2), F.A.C.; and, AC 09-202080]
Refer to the enclosed Florida NaturalAreas Inventory (FNAI) documents:
            "   "RAI 5-5 FNAI Central Florida Report," and
            "   "RAI 5-5 FNAI Lake Tarpon Report."
In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.
 
U. S. Nuclear Regulatory 3F0410-04 rwaoo*&#xfd;                                        Response to Request for Documents Documents Enclose N                                      4 2009 NPDES Reports
: 1. RAI 2-1 Title V Permit
: 2. RAI 3-1 Crystal River Mariculture Center Juvenile 19. RAI 4 2005 Industrial Waste Water Reports Releases.
: 3. RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling       20. RAI 4 2006 Industrial Waste Water Reports Tower Laydown Area, Citrus County, Florida.
: 4. RAI 3-3 Crystal River Impingement Report Mar 3   21. RAI 4 2007 Industrial Waste Water Reports 2008
: 5. RAI 3-4 CR Seagrass Technical Advisory           22. RAI 4 2008 Industrial Waste Water Reports Committee Final Report
: 6. RAI 3-4 Crystal River 1993 Seagrass Study         23. RAI 4 2009 Industrial Waste Water Reports
: 7. RAI 3-4 Crystal River 1994 Seagrass Study         24. RAI 4 2005 Domestic Waste Water Reports
: 8. RAI 3-4 Crystal River 1995 Seagrass Study         25. RAI 4 2006 Domestic Waste Water Reports
: 9. RAI 3-4 Crystal River November 2001 Seagrass     26. RAI 4 2007 Domestic Waste Water Reports Survey
: 10. RAI 3-4 Seagrass Quantification Report_4-24-08   27. RAI 4 2008 Domestic Waste Water Reports
: 11. RAI 3-5 Marine Turtle Permit                     28. RAI 4 2009 Domestic Waste Water Reports
: 12. RAI 3-6 National Marine Fisheries Service Letter 29. RAI 5-4 Crystal River Salt Drift Correspondence
: 13. RAI 3-7 Crystal River 3 Impingement Study         30. RAI 5-4 Crystal River Salt Drift FDEP Response (1978b)
: 14. RAI 42005 NPDES Reports                           31. RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report
: 15. RAI 4 2006 NPDES Reports                         32. RAI 5-5 FNAI Central Florida Report
: 16. RAI 4 2007 NPDES Reports                         33. RAI 5-5 FNAI Lake Tarpon Report
: 17. RAI 4 2008 NPDES Reports
 
Progress Energy PROGRESS ENERGY FLORIDA, INC.
CRYSTAL RIVER ENERGY COMPLEX LICENSING & REGULATORY PROGRAMS (NAIB) 15760 W. POWER LINE STREET CRYSTAL RIVER, FL 34428-6708 U.S. Nuclear Regulatory Commission Attention: Document ControlDesk 11555 Rockville Pike Rockville, Maryland 20852 RETURN AND FORWARDING POSTAGE.GUARANTEED
 
U. S. Nuclear Regulatory Commission                         Response to 3F0410-04                                         Request for Documents RAI 2-1 Title V Permit
 
NOTICE OF FINAL PERMIT In the Matter of an Applicationfor Permit by:
Florida Power Corporation                               Permit No. 01 70004-024-AV dba Progress Energy Florida, Inc.                 Crystal River Power Plant 299 First Avenue North                                 Title V Air Operation Permit Renewal Mail Code CN77                                         Citrus County St. Petersburg, Florida 33701 Responsible Official:
Mr. Larry Hatcher, Plant Manager Enclosed is the final permit package to renew the Title V air operation permit for Crystal River Power Plant. The existing facility is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. This permit is issued pursuant to Chapter 403, Florida Statutes.
Any party to this order has the right to seek judicial review of it under Section 120.68 of the Florida Statutes by filing a notice of appeal under Rule 9.110 of the Florida Rules of Appellate Procedure with the clerk of the Department of Environmental Protection in the Office of General Counsel (Mail Station #35, 3900 Commonwealth Boulevard, Tallahassee, Florida, 32399-3000) and by filing a copy of the notice of appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The notice must be filed within 30 days after this order is filed with the clerk of the Department.
Executed in Tallahassee, Florida.
Trina Vielhauer, Chief Bureau of Air Regulation TLV/jh/sm CERTIFICATE OF SERVICE The undersigned duly designated deputy agency clerk hereby certifies that this Notice of Final Permit (including the Final Permit and Final Determination), or a link to these documents available electronically on a publicly accessible server, was sent by electronic mail with. received receipt requested to the persons listed below:
Mr. Larry Hatcher, Progress Energy Florida, Inc.: larry.hatclier@pgnmail.com Mr. Dave Meyer, P.E., Progress Energy Florida, Inc.: dave.mever@pgnmail.com Mr. Scott Osbourn, P.E., Golder Associates, Inc.: sosboum@golder.com Ms. Cyndy Wilkinson, Progress Energy Florida,, Inc.: cyndy.wilkinson@pgnmail.com Ms. Danielle Henry, DEP - SWD: danielle.d.henry dep.state.fl.us Ms. Susan Machinski, DEP - SD: susan.machinski@,dep.state.fl.us Ms. Katy Forney, U.S. EPA Region 4: forney.kathleen@epamail.epa.gov Ms. Ana Oquendo, EPA Region 4: oquendo.ana(aepamail.epa.gov Ms. Barbara Friday, DEP - BAR: barbara.friday~dep.state.fl.us (for posting with U.S. EPA, Region 4)
Ms. Victoria Gibson, DEP - BAR: victoria.gibson@dep.state.fl.us (for reading file)
Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to Section 120.52(7), Florida Statutes, with the designated agep4\clerk, receipt of which is hereby
 
Florida Department of Environmental Protection Bob Martinez Center 2600 Blair Stone Road                                     I. V(IC~IJA Tallahassee. Florida 32399-2400 PERMITTEE:                                                   Permit No. 01 70004-024-AV Florida Power Corporation                                   Crystal River Power Plant dba Progress Energy Florida, Inc.                       Facility ID No. 0170004 299 First Avenue North                                       Title V Air Operation Permit Renewal Mail Code CN77 St. Petersburg, Florida 33701 The purpose of this permit is to renew the Title V air operation permit for the above referenced facility.
The existing Crystal River Power Plant is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. UTM Coordinates are: Zone 17, 334.3 km East and 3204.5 km North. Latitude is: 280 57' 34" North and Longitude is: 820 42' 1" West.
The Title V air operation permit is issued under the provisions of Chapter 403, Florida Statutes (F.S.), and Florida Administrative Code (F.A.C.) Chapters 62-4, 62-210, 62-213 and 62-214. The above named permittee is hereby authorized to operate the facility in accordance with the terms and conditions of this permit.
Effective Date: January 1, 2010 Renewal Application Due Date: May 20, 2014 Expiration Date: December 31, 2014
                                                                            . \     !;
Joseph Kahn< Director Division of Air Resource Management JK/tlv/jkh/sm
 
FINAL DETERMINATION qPERMITTEE Florida Power Corporation dba Progress Energy Florida, Inc. (PEF) 299 First Avenue, North Mail Code CN77 St. Petersburg, Florida 33701 PERMITTING AUTHORITY Florida Department of Environmental Protection (Department)
Division of Air Resource Management Bureau of Air Regulation, Title V Section 2600 Blair Stone Road, MS #5505 Tallahassee, Florida 32399-2400 PROJECT Permit No. 0170004-024-AV Crystal River Power Plant The purpose of this project is to renew the Title V air operation permit for Crystal River Power Plant.
NOTICE AND PUBLICATION The Department distributed a draft/proposed Intent to Issue a Title V Air Operation Permit Renewal package on October 27, 2009. The applicant published the Public Notice of Intent to Issue a Title V Air Operation Permit Renewal in the Citrus County Chronicle on November 2, 2009. The     I. Department received the proof of publication on November 5, 2009. A proposed permit was issued for EPA review on October 27, 2009.
COMMENTS No comments were received from either the Public during the 30-day public comment period or from EPA during their 45-day review period; however, comments were received from the Permittee. The comments are minor administrative corrections to the permit. The comments were not considered significant enough to reissue the draft Title V air operation permit and require another Public Notice, therefore, the draft/proposed Title V air operation permit was changed. Those comments are addressed below. Additions to the permit are indicated by a double underline. Deletions from the permit are indicated by a st~ke thr mtgh.
Email from Dave Meyer dated November 19, 2009 COMMENT 1. It is requested to add the following language to the end of Specific Condition A.L.: "Heat input shall be determined by coal analysis and the coal feeder scales, 24 hour average. The CEMs heat input value shall not be used."
RESPONSE 1. A review in response to this comment resulted in the discovery that the following permitting note, which was contained in permit No. 0170004-003-AC, was inadvertently omitted in the draft/proposed permit. It has been reinserted following Specific Condition A.1.
(PermittingNote: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operation to 110 percent of the test load), to establish appropriateemission limits and to aid in determiningfuture rule applicability.]
COMMENT 2. Delete specific condition A.2.b. Bartow Unit 1 has been taken out of service.
RESPONSE 2. Specific condition A.2. has been changed as follows:
A.2.     Methods of Operation.
: a. Fuels. The fuels that are allowed to be burned in these units are:
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                           Title V Air Operation Permit Renewal Page 1 of 6
 
FINAL DETERMINATION (1)       Bituminous coal, (2)       Bituminous coal and bituminous coal briquette mixture, (3)       Distillate fuel oil for startup, and (4)       Used oil in accordance with the specific conditions in Subsection J.7 (5)             flyash in aadridance with Spcifi Oilyn.nditiens                             o        A.2.b. and A.26.
: b. OilyA7yash. These                 beenssins units may burn ily flyash (reuyahb) fredm Bar-tow Unit 1 int aMENTrdante with the fuellewing h         ificc   d Flyash. Only flyash freom Baeigw e   Unit 1 may be burned in these emssions units.
Onie the achufulated batklugef Bantew Unit 1 flyash (cstimnatb d at approfxiately 13,000 tuns)is burned, 3         nTly the additional flyash grneratcd At Baflec Unit 1 shall be bund in thesercnsttsion       urits.
(2)       Blend Rate Limeit. The aximum flyash blend   rate   shall not exaeed 2%of the total bcileri feed en a 'weight basis.
[Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AG; and, 0170004-006-AC]
In addition specific condition A.26. has been deleted as follows:
A.26. Oilybeusdash 0- eorfdkeein. a Thelowoerd fr opersatar shall mfuake and maintain the fmllwinbg ruedrds srt eaah day that flyash is burned in the boiler:
: a. Date and Unit numtiberm,
: b. Timfe period of flyash burning and start and end timfes-,
: e. Total quantity of flyash burned in tons per day, and
: d. Maximiumoflyash blend fate during perliodof fyash burn (percent flyash in total em ssiens unit fuel feed en a weight basis).
[Rule 62 213.4110, F.A.C.; and Permfit No. 0170004 005 AO]
Specific conditions A.27. and A.28. have been renumbered as A.26. and A.27., respectively.
COMMENT 3. Quantifying the fuel density is appropriate for fuel oil, it is typically not measured for fuels such as coal. Change specific condition A.22.b. to read "Recordkeeping. Record daily the amount of coal fired, the density       opacityof each fuel, the Btu value, and the percent sulfur content by weight of each fuel."
RESPONSE 3. The language in specific condition A.22.b. reflects the language in the air construction permit.
The requested language was not found to be in an air construction permit for these units. Therefore, no change will be made.
COMMENT 4. The wording in the current permit is not clear regarding flame stabilization. We want to clarify that fuel oil is used as an ignitor fuel and for low load flame stabilization. It is requested to change specific condition B.2.a.(2) to read "Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and low load flame stabilization fuel. Natural gas may be used as a startup and low load flame stabilization fuel.
RESPONSE 4: Air construction permit 0170004-006-AC authorized No. 2 fuel oil to be used as an ignitor fuel and natural gas as a startup and low load flame stabilization fuel. The air construction permit did not authorize No.
2 fuel oil to be used as a low load flame stabilization fuel. Therefore, no change will be made.
COMMENT 5: One purpose of the Title V permit is to summarize the operating requirements. We felt that it was appropriate to outline the opacity allowance in specific condition B.11. in the Title V permit to clarify when the opacity standard used is in effect. It is requested to add the following language at the end of specific condition B.11.: "The opacity standards set forth in 40 CFR 60.11 shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard. [40 CFR 60. 11 ]"
RESPONSE 5: The requested language is in Attachment NSPS A. The requested language from 40 CFR 60.11 is not applicable to excess emissions. Condition B.11. is from Rule 62.210.700, F.A.C. Please note that Rule 62-2 10.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. This is stated in the permit under the heading Excess Emissions. No change will be made.
Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                              Title V Air Operation Permit Renewal Page 2 of 6
 
FINAL DETERMINATION COMMENT 6: Quantifying the fuel density is appropriate for fuel oil. It is typically not measured for fuels such as coal. Change specific condition B.25.b. to read "Recordkeeping. Record daily the amount of coal fired, the density (f         of each fuel, the Btu value, and the percent sulfur content by weight of each fuel."
RESPONSE 6: The requested language was not found to be in an air construction permit for these units.
Therefore, no change will be made.
COMMENT 7: We have historically submitted our excess emissions report on a quarterly basis. Our intent is for the Title V permit to accurately reflect when we submit our excess emissions report. Change specific condition B.28 to read:
B.28. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority:
Report                               Reporting Deadline                                   Related Condition(s)
Notice of Excess Emissions           Postmarked by the     3 0 th day following the       B.13. and B.29 end of each g RESPONSE 7: Specific conditions B.13., B.28. and B.29. are conditions stating applicable requirements of 40 CFR 60 Subpart D relating to excess emissions and reporting. It is the intention of these conditions to bring to awareness federal requirements for excess emissions which the facility is subject. Subpart D requires excess emissions reporting every six months. The Department is not able to rewrite the federal regulations. However, the facility may submit these reports more frequently if they choose to do so. No change will be made.
COMMENT 8: Delete specific condition C.16. This is not required in our current TV permit. The above record-keeping is required in sections III.A. & B. We feel it is redundani to require this information in this section of the permit.
RESPONSE 8: Condition C.16 has been deleted. Condition C.17. has been renumbered to C.16.
COMMENT 9: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity Change specific condition D.14 as follows:
D.14. The visible emissions test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statemfent of the approximfate ash transfer rate during the test shall be submfitted with each test report. Failure to submit the process tr-ansfier- rate, -Andor operationf unider conditionis that are not representative of normal operations may invalidate the test and fail to provide reas.nable assurance of eemp.la.nee. Unit load will be utilized to assure 90 to 100% capacity during testing. [Permit No. AC09-235915]
RESPONSE 9: The language in Condition D.14. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee. The language may only be changed through an air construction permit. No change will be made to condition.
COMMENT 10: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity. Change specific condition D.15. as follows:
D.15. Reporting Ash Transfer Rate. A statem.ent f the appr-oximate ash transfer rate during the test shall be submitte'd wiit~h feaeh. compliance test report. Failure to submit the process tr-ansfer rate and o prto under conditions that afe not representative of normfal operations mfay invalidate the test and fail to provid-e reasonable assurance of comfipliance. Unit load will be utilized to assure 90 to 100% capacity during testing. Unit load shall be submitted with each compliance test report. [Permit No. AC09-235915]
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                               Title V Air Operation Permit Renewal Page 3 of 6
 
FINAL DETERMINATION RESPONSE 10. The language in Condition D.15. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee. The condition may only be changed through an air construction permit. No change will be made to condition.
COMMENT 11: The current TV permit utilizes the below wording. We prefer this wording as it allows more flexibility in determining the test operating rate (fuel flow may difficult to measure). Electrical output may be a better indicator.
E.17. Operating Rate During Testing. Testing of emissions shall be conducted with the generator(s) operating at 90 to 100 percent of the maximum fuel firing rate for each generator. If it is impracticable to test at permitted capacity, an emissions unit may be tested at less than the minimum permitted capacity (i.e., at less than 90 percent of the maximum operation rate allowed by the permit); in this case, subsequent emissions unit operations may be limited to 110 percent of the test load until a new test is conducted, provided however, operations do not exceed 100 percent of the maximum operation rate allowed by the permit. Once the emissions unit is so limited, operation at higher capacities is allowed for no more than 15 consecutive days for the purpose of additional compliance testing to regain the authority to operate at the permitted capacity. Failure to submit the actual operating rate may invalidate the test. [Rule 62-297.310(2),
F.A.C.; and, AC 09-202080]
RESPONSE 11: The requested language is in Appendix TR, Condition TR2. The language in Condition E.17. is from the federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee.
RESPONSE 11: The requested language is in Appendix TR, Condition TR2. The language in Condition E.17. is from the federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee.
The condition may only be changed through an air construction permit. No change will be made to condition.
The condition may only be changed through an air construction permit. No change will be made to condition.
COMMENT 12: Replace the word "nine" with the word "all" in the last sentence of the first paragraph of the emission unit description in Subsection F.RESPONSE 12: The Department believes that the description is clear as written. No change will be made.COMMENT 13: In accordance with an alternate procedure dated June 7, 2000, the wording for condition F.4. is not in the current TV permit. The current TV permit requires the following preferred wording: F.4. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators.
COMMENT 12: Replace the word "nine" with the word "all" in the last sentence of the first paragraph of the emission unit description in Subsection F.
During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate): (a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).(b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.(c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
RESPONSE 12: The Department believes that the description is clear as written. No change will be made.
[Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139);
COMMENT 13: In accordance with an alternate procedure dated June 7, 2000, the wording for condition F.4. is not in the current TV permit. The current TV permit requires the following preferred wording:
and, ASP No. 00-E-01 dated June 7, 2000]RESPONSE 13: The provisions of the approved alternate procedure, ASP No. 00-E-01 dated June 7, 2000, which were reflected in Condition F.4. of the previous Title V permit, were inadvertently omitted during this renewal process. Condition F.9. of the renewal permit has been corrected as follows to replace the omitted ASP provisions:
F.4.           Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate):
1P 0 0-- 1-&#xfd;Op T-&#xfd;&#xfd;&#xfd;&#xfd;11 +&#xfd; 1- t, +t-' D O.J T AjuI f1 .. ..; 1.... .1; .... t-, a ,a ..,l l 1i., 'kk .....fl L'" .... L 'J Depar.tm ..ent, shall be c.nducted fer ea.h e..ling tower- while it is gperated at 90 100% capacity.
(a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).
Suche tests shall" be conduceted int accordanceewith 40 CER 60 Appendixi A, using EPA Method 5, oray te equivlent mnethod approeved by the Depar-tment.
(b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.
Specifically, when using EPA Method 5, -A distilled eater r-inse shall be used in place of aeetonle, and the impinge catch shall be eyxcluded from emission calculations, The salt water flew rate dur-ing the compliance tests shall be determinifed using the manufactturer's ceenified Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 4 of 6 FINAL DETERMINATION pump cur-vos, or any other equivalent mnethod approeved by the Depaftmfent.
(c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
If compliatnce test resut indicate that the pafticulate eision arfgeater-than 90% but less than 100% of its allowable limiit et 11.89 lbs~ir- per- eeil! (stack), the failt .ill b. rquir-ed to conduct anoether-stack test withint thirty mnonths.Whereas, a partfieulate stack test will be roquir-ed onee evefy five y'ear~s if the compliance test results show that the partficulate emissions are below 80% of the 11.89 lbs/bf allowed limit.Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators.
[Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7, 2000]
During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate): (a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans (b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up ispections and correction of uroblems when the daily visual inspection of the cells indicates a problem.(c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
RESPONSE 13: The provisions of the approved alternate procedure, ASP No. 00-E-01 dated June 7, 2000, which were reflected in Condition F.4. of the previous Title V permit, were inadvertently omitted during this renewal process. Condition F.9. of the renewal permit has been corrected as follows to replace the omitted ASP provisions:
[Rule 62-213*440, F.A.C.; and, AC 09-162037 (PSD-FL-139);
1P 0
and, ASP No. 00-E-01 dated June 7. 2000]COMMENT 14: The below dates reflect the current testing schedule: G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012).[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]RESPONSE 14: Specific Condition G.10. has been corrected as follows: G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012).[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]COMMENT 15: We believe the reference to Specific Condition 1.6. in Specific Condition 1.8. is a typo RESPONSE 15: Condition 1.8. has been corrected as follows: 1.8. Inspection Log. Any problems detected during the work practice inspections identified in Specific Condition 1.610t. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000]COMMENT 16: My understanding was that a trailer mounted engine is not considered a stationary source, and thus not subject to the new NSPS & HAPS regulations.
    ' D.J O 0--     1-&#xfd;Op T-&#xfd;&#xfd;                                                                   &#xfd;&#xfd;11           +&#xfd; 1-             t,     +t-Depar.tm ent,.. shall be c.nducted fer ea.h e..ling tower-while it is                                  90 100% capacity. Suche at gperated tests shall"be conduceted int accordanceewith 40 CER 60 Appendixi A, using EPA Method 5, oray T  AjuI  f1 ul,~,*- *F .. . .; v*A 1.... t-, . 1; .... a ,a    *tl ..,l l 1i., A**  'kk    fl    L'"    .....  **'.U
I now understand that the DEP considers it a stationary source when in operation, and therefore request that it be added to Appendix ICE -Requirements For Internal Combustion Engines: E.U. No. Brief description of engine 031? Crystal River Unit 3 trailer mounted fire pump Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 5 of 6 FINAL DETERMINATION RESPONSE 16: The table in Appendix ICE has been changed as follows: In- Displacement Rule E.U. No. Brief Description of Engine Service Applicability Date 028 3500 kW diesel generator associated with Unit 3 03/2006 12,443 in 3  ZZZZ 029 Diesel fire pump, south yard 08/2009 14.5 L zzZZ, IIII 030 Emergency generator (meteorological weather station) 09/2009 992 CC ZZZZ, JJJJ 031 Fire Pump, Trailer Mounted, Unit 3 02/2008 8700 CC ZZZZ, IIII As a result of this change the second to last paragraph of the Facility Description in the Statement of Basis has also been changed as follows: The facility has th-ee four new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1111, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 and EU031) were created for these units.CONCLUSION The final action of the Department is to issue the permit with the minor corrections noted above.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 6 of 6 STATEMENT OF BASIS Title V Air Operation Permit Renewal Florida Power Corporation dba Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV APPLICANT The applicant for this project is Florida Power Corporation dba Progress Energy Florida, Inc. The applicant's responsible official and mailing address are: Mr. Larry Hatcher, Plant Manager, Florida Power Corporation dba Progress Energy Florida, Inc., 299 First Avenue, North, Mail Code CN77, St. Petersburg, Florida, 33701.FACILITY DESCRIPTION The applicant operates the existing Crystal River Power Plant, which is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida.This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and Nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generator(s).
                                                                                                                                    . L 'J
                                                                                                                                          ... te equivlent mnethod approeved by the Depar-tment. Specifically, when using EPA Method 5, -A                                   distilled eater r-inse shall be used in place of aeetonle, and the impinge catch shall be eyxcluded from emission calculations, The salt water flew rate dur-ing the compliance tests shall be determinifed using the manufactturer's ceenified Progress Energy Florida, Inc.                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Air Operation Permit Renewal Page 4 of 6
 
FINAL DETERMINATION pump cur-vos, or any other equivalent mnethod approeved by the Depaftmfent. If compliatnce test resut indicate that the pafticulate eision arfgeater-than 90% but less than 100% of its allowable limiit et 11.89 lbs~ir-per- eeil! (stack), the failt   .illb. rquir-ed to conduct anoether- stack test withint thirty mnonths.
Whereas, a partfieulate stack test will be roquir-ed onee evefy five y'ear~s if the compliance test results show that the partficulate emissions are below 80% of the 11.89 lbs/bf allowed limit.
Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate):
(a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans (b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up ispections and correction of uroblems when the daily visual inspection of the cells indicates a problem.
(c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
[Rule 62-213*440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7. 2000]
COMMENT 14: The below dates reflect the current testing schedule:
G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012).
[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
RESPONSE 14: Specific Condition G.10. has been corrected as follows:
G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012).
[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
COMMENT 15: We believe the reference to Specific Condition 1.6. in Specific Condition 1.8. is a typo RESPONSE 15: Condition 1.8. has been corrected as follows:
1.8.     Inspection Log. Any problems detected during the work practice inspections identified in Specific Condition 1.610t. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000]
COMMENT 16: My understanding was that a trailer mounted engine is not considered a stationary source, and thus not subject to the new NSPS & HAPS regulations. I now understand that the DEP considers it a stationary source when in operation, and therefore request that it be added to Appendix ICE - Requirements For Internal Combustion Engines:
E.U. No.               Brief description of engine 031?         Crystal River Unit 3 trailer mounted fire pump Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                             Title V Air Operation Permit Renewal Page 5 of 6
 
FINAL DETERMINATION RESPONSE 16: The table in Appendix ICE has been changed as follows:
In-       Displacement             Rule E.U. No.                   Brief Description of Engine             Service                           Applicability Date 028       3500 kW diesel generator associated with Unit 3       03/2006     12,443 in3            ZZZZ 029       Diesel fire pump, south yard                         08/2009     14.5 L                 zzZZ, IIII 030       Emergency generator (meteorological weather station) 09/2009   992 CC                 ZZZZ, JJJJ 031       Fire Pump, Trailer Mounted, Unit 3                   02/2008   8700 CC                 ZZZZ, IIII As a result of this change the second to last paragraph of the Facility Description in the Statement of Basis has also been changed as follows:
The facility has th-ee four new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1111, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 afid-*EU030 and EU031) were created for these units.
CONCLUSION The final action of the Department is to issue the permit with the minor corrections noted above.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 6 of 6
 
STATEMENT OF BASIS Title V Air Operation Permit Renewal Florida Power Corporation dba Progress Energy Florida, Inc.
Crystal River Power Plant Permit No. 0170004-024-AV APPLICANT The applicant for this project is Florida Power Corporation dba Progress Energy Florida, Inc. The applicant's responsible official and mailing address are: Mr. Larry Hatcher, Plant Manager, Florida Power Corporation dba Progress Energy Florida, Inc., 299 First Avenue, North, Mail Code CN77, St. Petersburg, Florida, 33701.
FACILITY DESCRIPTION The applicant operates the existing Crystal River Power Plant, which is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida.
This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and Nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generator(s).
The nuclear unit (Unit 3) is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit. The facility has the potential to emit particulate matter, sulfur dioxide, nitrogen oxides, and carbon monoxides.
The nuclear unit (Unit 3) is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit. The facility has the potential to emit particulate matter, sulfur dioxide, nitrogen oxides, and carbon monoxides.
This facility is subject to regulation under Acid Rain, Phase II, 40 CFR 75, Clean Air Interstate Rule, Rule 62-296.470, F.A.C., 40 CFR 60 Subparts A, D, Y, 1111 and JJJJ, General Provisions, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction Is Commenced After August 17, 1971, Standards of Performance for Coal Preparation Plants, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines, and Standards of Performance for Stationary Spark Ignition Internal Combustion Engines, respectively.
This facility is subject to regulation under Acid Rain, Phase II, 40 CFR 75, Clean Air Interstate Rule, Rule 62-296.470, F.A.C., 40 CFR 60 Subparts A, D, Y, 1111 and JJJJ, General Provisions, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction Is Commenced After August 17, 1971, Standards of Performance for Coal Preparation Plants, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines, and Standards of Performance for Stationary Spark Ignition Internal Combustion Engines, respectively. The facility is subject to the regulations of 30 CFR 63 Subparts A and ZZZZ, General Provisions and National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines, respectively.
The facility is subject to the regulations of 30 CFR 63 Subparts A and ZZZZ, General Provisions and National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines, respectively.
The facility operates stationary reciprocating internal combustion engines (EU019), therefore, it is subject to regulation under 40 CFR 63, Subpart ZZZZ - National Emissions Standards For Hazardous Air Pollutants For Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.
The facility operates stationary reciprocating internal combustion engines (EU019), therefore, it is subject to regulation under 40 CFR 63, Subpart ZZZZ -National Emissions Standards For Hazardous Air Pollutants For Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.The facility has three new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1III, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 and EU030) were created for these units.Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities.
The facility has three new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1III, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 and EU030) were created for these units.
PROJECT DESCRIPTION The purpose of this permitting project is to renew the existing Title V permit for the above referenced facility.PROCESSING SCHEDULE AND RELATED DOCUMENTS Application for a Title V Air Operation Permit Renewal received May 21, 2009 Additional Information Request dated July 10, 2009 Additional Information Response received October 8, 2009 PRIMARY REGULATORY REQUIREMENTS Title III: The facility is identified as a major source of hazardous air pollutants (HAP).Title IV: The facility operates units subject to the acid rain provisions of the Clean Air Act.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 1 of 2 STATEMENT OF BASIS Title V: The facility is a Title V major source of air pollution in accordance with Chapter 62-213, Florida Administrative Code (F.A.C.).PSD: The facility is a Prevention of Significant Deterioration (PSD)-major source of air pollution in accordance with Rule 62-212.400, F.A.C.NSPS: The facility operates units subject to the New Source Performance Standards (NSPS) of 40 Code of Federal Regulations (CFR) 60.NESHAP: The facility operates units subject to the National Emissions Standards for Hazardous Air Pollutants (NESHAP) of 40 CFR 63.CAIR: The facility is subject to the Clean Air Interstate Rule (CAIR) set forth in Rule 62-296.470, F.A.C.Siting: Emissions units EU001, EU002, EU003 and EU004 were originally certified pursuant to the power plant siting provisions of Chapter 62-17, F.A.C.CAM: Compliance Assurance Monitoring (CAM) applies to emissions units EU001, EU002, EU003 and EU004 at the facility.
Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities.
CAM applies because these units have control equipment used to meet federally enforceable limits or standards.
PROJECT DESCRIPTION The purpose of this permitting project is to renew the existing Title V permit for the above referenced facility.
PROJECT REVIEW Changes made as part of this renewal were reformatting, replacement of TV-6 with new Appendix TV, streamlining of EU sections by moving common conditions to the new appendices.).
PROCESSING SCHEDULE AND RELATED DOCUMENTS Application for a Title V Air Operation Permit Renewal received May 21, 2009 Additional Information Request dated July 10, 2009 Additional Information Response received October 8, 2009 PRIMARY REGULATORY REQUIREMENTS Title III: The facility is identified as a major source of hazardous air pollutants (HAP).
New regulated emission units were created due to applicability to 40 CFR 60 1III, 40 CFR 60 JJJJ and 40 CFR 63 ZZZZ. Minor changes were requested by the applicant.
Title IV: The facility operates units subject to the acid rain provisions of the Clean Air Act.
Changes requested by the applicant include adding concrete batch plants and grout batch plants to Appendix I, and adding a 20,000 gallon underground storage tank for diesel to EU017 in Appendix U. Additionally, a change was made to the ambient air monitoring specific condition for EU003 and EU004 (FFSG units 5 and 4, respectively) to make it consistent with the change made to Conditions of Certification, PA 77-09, in the Post-certification Amendment, dated June 19, 2008. In this amendment, the Department determined that Progress Energy Florida could cease to operate and remove Site No. 4 monitoring station (SO 2 only).CONCLUSION This project renews Title V air operation permit No. 0170004-009-AV, which was issued on January 1, 2005.This Title V air operation permit renewal is issued under the provisions of Chapter 403, Florida Statues (F.S.), and Chapters 62-4, 62-210, 62-213 and 62-214, F.A.C.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 2 of 2 Florida Power Corporation dba Progress Energy Florida, Inc. (PEF)Crystal River Power Plant Facility ID No. 0170004 Citrus County Title V Air Operation Permit Renewal Permit No. 0170004-024-AV (Renewal of Title V Air Operation Permit No. 0170004-009-AV)
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                           Title V Air Operation Permit Renewal Page 1 of 2
 
STATEMENT OF BASIS Title V: The facility is a Title V major source of air pollution in accordance with Chapter 62-213, Florida Administrative Code (F.A.C.).
PSD: The facility is a Prevention of Significant Deterioration (PSD)-major source of air pollution in accordance with Rule 62-212.400, F.A.C.
NSPS: The facility operates units subject to the New Source Performance Standards (NSPS) of 40 Code of Federal Regulations (CFR) 60.
NESHAP: The facility operates units subject to the National Emissions Standards for Hazardous Air Pollutants (NESHAP) of 40 CFR 63.
CAIR: The facility is subject to the Clean Air Interstate Rule (CAIR) set forth in Rule 62-296.470, F.A.C.
Siting: Emissions units EU001, EU002, EU003 and EU004 were originally certified pursuant to the power plant siting provisions of Chapter 62-17, F.A.C.
CAM: Compliance Assurance Monitoring (CAM) applies to emissions units EU001, EU002, EU003 and EU004 at the facility. CAM applies because these units have control equipment used to meet federally enforceable limits or standards.
PROJECT REVIEW Changes made as part of this renewal were reformatting, replacement of TV-6 with new Appendix TV, streamlining of EU sections by moving common conditions to the new appendices.). New regulated emission units were created due to applicability to 40 CFR 60 1III, 40 CFR 60 JJJJ and 40 CFR 63 ZZZZ. Minor changes were requested by the applicant. Changes requested by the applicant include adding concrete batch plants and grout batch plants to Appendix I, and adding a 20,000 gallon underground storage tank for diesel to EU017 in Appendix U. Additionally, a change was made to the ambient air monitoring specific condition for EU003 and EU004 (FFSG units 5 and 4, respectively) to make it consistent with the change made to Conditions of Certification, PA 77-09, in the Post-certification Amendment, dated June 19, 2008. In this amendment, the Department determined that Progress Energy Florida could cease to operate and remove Site No. 4 monitoring station (SO 2 only).
CONCLUSION This project renews Title V air operation permit No. 0170004-009-AV, which was issued on January 1, 2005.
This Title V air operation permit renewal is issued under the provisions of Chapter 403, Florida Statues (F.S.),
and Chapters 62-4, 62-210, 62-213 and 62-214, F.A.C.
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                       Title V Air Operation Permit Renewal Page 2 of 2
 
Florida Power Corporation dba Progress Energy Florida, Inc. (PEF)
Crystal River Power Plant Facility ID No. 0170004 Citrus County Title V Air Operation Permit Renewal Permit No. 0170004-024-AV (Renewal of Title V Air Operation Permit No. 0170004-009-AV)
JETItON F/LORI A Permitting Authority:
JETItON F/LORI A Permitting Authority:
State of Florida Department of Environmental Protection Division of Air Resource Management Bureau of Air Regulation Title V Section 2600 Blair Stone Road Mail Station #5505 Tallahassee, Florida 32399-2400 Telephone:  
State of Florida Department of Environmental Protection Division of Air Resource Management Bureau of Air Regulation Title V Section 2600 Blair Stone Road Mail Station #5505 Tallahassee, Florida 32399-2400 Telephone: (850) 488-0114 Fax: (850) 921-9533 Compliance Authority:
(850) 488-0114 Fax: (850) 921-9533 Compliance Authority:
State of Florida Department of Environmental Protection Southwest District Office 13051 North Telecom Parkway Temple Terrace, FL 33637-0926 Telephone: 813/632-7600 Fax: 813/632-7668
State of Florida Department of Environmental Protection Southwest District Office 13051 North Telecom Parkway Temple Terrace, FL 33637-0926 Telephone:
 
813/632-7600 Fax: 813/632-7668 Florida Power Corporation dba Progress Energy Florida, Inc. Crystal River Power Plant Title V Air Operation Permit Renewal Permit No. 0170004-024-AV Table of Contents Section Pa2e Number I. Facility Information.
Florida Power Corporation dba Progress Energy Florida, Inc.                                                                                         Crystal River Power Plant Title V Air Operation Permit Renewal Permit No. 0170004-024-AV Table of Contents Section                                                                                                                                                                 Pa2e Number I. Facility Information.
A .F acility D escrip tio n .....................................................................................................................................
A . F acility D escrip tio n . ....................................................................................................................................             2 B . Sum m ary of Emissions U nits . .....................................................................................................................                       2 C . Applicable R egulations . ..............................................................................................................................                   2 II. F acility-w ide C ond ition s. ...................................................................................................................................             4 III. Emissions Units and Conditions.
2 B .Sum m ary of E m issions U nits ......................................................................................................................
A. Fossil Fuel Steam Generator (FFSG), Units land 2 ................................................................................                                           6 B. FFSG Units 4 and 5.........................................................                                                                                               11 C. Fly A sh Transfer & Storage, Units 1 and 2 ..........................................................................................                                     17 D . Bottom Ash Storage Silo for U nits 1 and 2 ...........................................................................................                                   20 E . R elocatable D iesel Generators . .................................................................................................................                       23 F . C ooling T owers for U nits 1, 2 and 3 . ........................................................................................................                         26 G. C ooling Tow ers for U nits 4 and 5 ........................................................................................................                               28 H. Material Handling Activities for Coal-Fired Steam Units .....................................................................                                             30 I. Portable Cooling Towers for U nits 1 and 2 ...........................................................................................                                     32 J. U sed O il C omm on C ondition . ...................................................................................................................                       34 IV . A cid R ain P art ...................................................................................................................................................         36 Phase II Acid Rain Application/Compliance Plan.
2 C .A pplicable R egulations  
Phase II Acid Rain NOx Compliance Plan.
...............................................................................................................................
Phase II Acid Rain NOx Averaging Plan.
2 II. F acility-w ide C ond ition s ....................................................................................................................................
V . C lean A ir Interstate R ule P art . .........................................................................................................................                 48 V I. A ppen dice s. ......................................................................................................................................................         54 Appendix A, Glossary.
4 III. Emissions Units and Conditions.
Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997).
A. Fossil Fuel Steam Generator (FFSG), Units land 2 ................................................................................
Appendix CAM, Compliance Assurance Monitoring Plan.
6 B. FFSG Units 4 and 5 .........................................................
Appendix I, List of Insignificant Emissions Units and/or Activities.
11 C. Fly A sh Transfer & Storage, U nits 1 and 2 ..........................................................................................
Appendix NSPS, Subpart A - General Provisions.
17 D .Bottom A sh Storage Silo for U nits 1 and 2 ...........................................................................................
Appendix NSPS, Subpart D - Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971.
20 E .R elocatable D iesel G enerators
Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.
..................................................................................................................
Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.
23 F .C ooling T ow ers for U nits 1, 2 and 3 .........................................................................................................
Appendix NSPS, Subpart Y - Standards of Performance for Coal Preparation Plants.
26 G .C ooling Tow ers for U nits 4 and 5 ........................................................................................................
Appendix NESHAP, Subpart A - General Provisions.
28 H. Material Handling Activities for Coal-Fired Steam Units .....................................................................
Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.
30 I. Portable Cooling Tow ers for U nits 1 and 2 ...........................................................................................
Appendix RR, Facility-wide Reporting Requirements.
32 J. U sed O il C om m on C ondition ....................................................................................................................
34 IV .A cid R ain P art ...................................................................................................................................................
36 Phase II Acid Rain Application/Compliance Plan.Phase II Acid Rain NOx Compliance Plan.Phase II Acid Rain NOx Averaging Plan.V .C lean A ir Interstate R ule P art ..........................................................................................................................
48 V I. A p p en d ice s .......................................................................................................................................................
5 4 Appendix A, Glossary.Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997).Appendix CAM, Compliance Assurance Monitoring Plan.Appendix I, List of Insignificant Emissions Units and/or Activities.
Appendix NSPS, Subpart A -General Provisions.
Appendix NSPS, Subpart D -Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971.Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.Appendix NSPS, Subpart Y -Standards of Performance for Coal Preparation Plants.Appendix NESHAP, Subpart A -General Provisions.
Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.Appendix RR, Facility-wide Reporting Requirements.
Appendix TR, Facility-wide Testing Requirements.
Appendix TR, Facility-wide Testing Requirements.
Appendix TV, Title V General Conditions.
Appendix TV, Title V General Conditions.
Appendix U, List of Unregulated Emissions Units and/or Activities.
Appendix U, List of Unregulated Emissions Units and/or Activities.
R eferenced A ttachm ents .................................................................................................................................
R eferenced Attachm ents .................................................................................................................................                     At End Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996).
A t E nd Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996).Table H, Permit History.Pagei SECTION I. FACILITY INFORMATION.
Table H, Permit History.
Pagei
 
SECTION I. FACILITY INFORMATION.
Subsection A. Facility Description.
Subsection A. Facility Description.
This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generators.
This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generators.
Nuclear Unit 3 is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit.Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities.
Nuclear Unit 3 is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit.
Subsection B. Summary of Emissions Units.E.U. No. I Brief Description Regulated Emission Units 001 FFSG, Unit 1 002 FFSG, Unit 2 004 FFSG, Unit 4 003 FFSG, Unit 5 006 Fly ash transfer (Source 1) from FFSG Unit 1 008 Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009 Fly ash transfer (Source 4) from FFSG Unit 2 010 Fly ash transfer (Source 5) from FFSG Unit 2 014 Bottom ash storage silo for FFSG Units 1 and 2 012 Relocatable diesel generators 013 Cooling towers for FFSG Units 1, 2, and 3 015 Cooling towers for FFSG Units 4 and 5 016 Material handling activities for coal-fired steam units 020 Portable Cooling Towers for FFSG Units 1 and 2 028 3500 kW diesel generator associated with Unit 3 029 Diesel fire pump, south yard 030 Emergency generator (meteorological weather station)Unregulated Emissions Units and/or Activities 017 Fuel and lube oil tanks and vents 018 Sewage treatment, water treatment, lime storage 019 Two 3500 kW diesel generators associated with Unit 3 Subsection C. Applicable Re2ulations.
Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities.
Based on the Title V air operation renewal application received May 21, 2009, this facility is a major source of hazardous air pollutants (HAP). Because this facility operates stationary reciprocating internal combustion engines (EU019), it is subject to regulation under 40 CFR 63, Subpart ZZZZ -National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time. The existing facility is a PSD major source of air pollutants in accordance with Rule 62-212.400, F.A.C. A summary of applicable regulations is shown in the following table.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 2 of 54 SECTION I. FACILITY INFORMATION.
Subsection B. Summary of Emissions Units.
Regulation EU Nos.40 CFR 60, Subpart A, NSPS General Provisions 003, 004, 016 40 CFR 60, Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction 003,004 is Commenced After August 17, 1971 40 CFR 60, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion 029 Engines 40 CFR 60, Subpart JJJJ, Standards of Performance for 030 Stationary Spark Ignition Internal Combustion Engines 40 CFR 63, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating 028,029,030 Internal Combustion Engines 40 CFR 63, Subpart Y, Standards of Performance for Coal 016 Preparation Plants.40 CFR 75 Acid Rain Monitoring Provisions 001,002, 003,004 Rule 62-296.405, F.A.C. 001,002 Rule 62-210.370, F.A.C. 001,002, 003,004, 006, 008,009,010, 013,014, 015,016, 020 Rule 62-210.700, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.410, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.440, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-297.310, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, Rule_62-297.3_10,________
E.U. No. I Brief Description Regulated Emission Units 001         FFSG, Unit 1 002         FFSG, Unit 2 004         FFSG, Unit 4 003         FFSG, Unit 5 006         Fly ash transfer (Source 1) from FFSG Unit 1 008         Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009         Fly ash transfer (Source 4) from FFSG Unit 2 010         Fly ash transfer (Source 5) from FFSG Unit 2 014         Bottom ash storage silo for FFSG Units 1 and 2 012         Relocatable diesel generators 013         Cooling towers for FFSG Units 1, 2, and 3 015         Cooling towers for FFSG Units 4 and 5 016         Material handling activities for coal-fired steam units 020         Portable Cooling Towers for FFSG Units 1 and 2 028         3500 kW diesel generator associated with Unit 3 029         Diesel fire pump, south yard 030         Emergency generator (meteorological weather station)
1015,016, 020 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 3 of 54 SECTION II. FACILITY-WIDE CONDITIONS.
UnregulatedEmissions Units and/orActivities 017       Fuel and lube oil tanks and vents 018       Sewage treatment, water treatment, lime storage 019       Two 3500 kW diesel generators associated with Unit 3 Subsection C. Applicable Re2ulations.
Based on the Title V air operation renewal application received May 21, 2009, this facility is a major source of hazardous air pollutants (HAP). Because this facility operates stationary reciprocating internal combustion engines (EU019), it is subject to regulation under 40 CFR 63, Subpart ZZZZ - National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time. The existing facility is a PSD major source of air pollutants in accordance with Rule 62-212.400, F.A.C. A summary of applicable regulations is shown in the following table.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 2 of 54
 
SECTION I. FACILITY INFORMATION.
Regulation                                                     EU Nos.
40 CFR 60, Subpart A, NSPS General Provisions                 003, 004, 016 40 CFR 60, Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction 003,004 is Commenced After August 17, 1971 40 CFR 60, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion           029 Engines 40 CFR 60, Subpart JJJJ, Standards of Performance for         030 Stationary Spark Ignition Internal Combustion Engines 40 CFR 63, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating     028,029,030 Internal Combustion Engines 40 CFR 63, Subpart Y, Standards of Performance for Coal       016 Preparation Plants.
40 CFR 75 Acid Rain Monitoring Provisions                     001,002, 003,004 Rule 62-296.405, F.A.C.                                       001,002 Rule 62-210.370, F.A.C.                                       001,002, 003,004, 006, 008,009,010, 013,014, 015,016, 020 Rule 62-210.700, F.A.C.                                       001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.410, F.A.C.                                       001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.440, F.A.C.                                       001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-297.310, F.A.C.                                       001, 002, 003, 004, 006, 008, 009, 010, 013, 014, Rule_62-297.3_10,________
1015,016, 020 Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                      Title V Air Operation Permit Renewal Page 3 of 54
 
SECTION II. FACILITY-WIDE CONDITIONS.
The following conditions apply facility-wide to all emission units and activities:
The following conditions apply facility-wide to all emission units and activities:
FW1. Appendices.
FW1. Appendices. The permittee shall comply with all documents identified in Section VI, Appendices, listed in the Table of Contents. Each document is an enforceable part of this permit unless otherwise indicated.
The permittee shall comply with all documents identified in Section VI, Appendices, listed in the Table of Contents.
[Rule 62-213.440, F.A.C.]
Each document is an enforceable part of this permit unless otherwise indicated.
Emissions and Controls FW2. Not federally Enforceable. Objectionable Odor Prohibited. No person shall cause, suffer, allow or permit the discharge of air pollutants, which cause or contribute to an objectionable odor. An "objectionable odor" means any odor present in the outdoor atmosphere which by itself or in combination with other odors, is or may be harmful or injurious to human health or welfare, which unreasonably interferes with the comfortable use and enjoyment of life or property, or which creates a nuisance. [Rule 62-296.320(2) and 62-210.200(Definitions), F.A.C.]
[Rule 62-213.440, F.A.C.]Emissions and Controls FW2. Not federally Enforceable.
FW3. General Volatile Organic Compounds (VOC) Emissions or Organic Solvents (OS) Emissions. The permittee shall allow no person to store, pump, handle, process, load, unload or use in any process or installation, volatile organic compounds or organic solvents without applying known and existing vapor emission control devices or systems deemed-necessary and ordered by the Department. The owner or operator shall:
Objectionable Odor Prohibited.
: a. Tightly cover or close all VOC or OS containers when they are not in use.
No person shall cause, suffer, allow or permit the discharge of air pollutants, which cause or contribute to an objectionable odor. An "objectionable odor" means any odor present in the outdoor atmosphere which by itself or in combination with other odors, is or may be harmful or injurious to human health or welfare, which unreasonably interferes with the comfortable use and enjoyment of life or property, or which creates a nuisance.  
: b. Tightly cover all open tanks which contain VOC or OS when they are not in use.
[Rule 62-296.320(2) and 62-210.200(Definitions), F.A.C.]FW3. General Volatile Organic Compounds (VOC) Emissions or Organic Solvents (OS) Emissions.
: c. Maintain all pipes, valves, fittings, etc., which handle VOC or OS in good operating condition.
The permittee shall allow no person to store, pump, handle, process, load, unload or use in any process or installation, volatile organic compounds or organic solvents without applying known and existing vapor emission control devices or systems deemed-necessary and ordered by the Department.
: d. Immediately confine and clean up VOC or OS spills and make sure wastes are placed in closed containers for reuse, recycling or proper disposal.
The owner or operator shall: a. Tightly cover or close all VOC or OS containers when they are not in use.b. Tightly cover all open tanks which contain VOC or OS when they are not in use.c. Maintain all pipes, valves, fittings, etc., which handle VOC or OS in good operating condition.
[Rule 62-296.320(1), F.A.C.; Permit No. 0170004-024-AC]
: d. Immediately confine and clean up VOC or OS spills and make sure wastes are placed in closed containers for reuse, recycling or proper disposal.[Rule 62-296.320(1), F.A.C.; Permit No. 0170004-024-AC]
FW4. General Visible Emissions. No person shall cause, let, permit, suffer or allow to be discharged into the atmosphere the emissions of air pollutants from any activity equal to or greater than 20% opacity. EPA Method 9 is the method of compliance pursuant to Chapter 62-297, F.A.C. This regulation does not impose a specific testing requirement. [Rule 62-296.320(4)(b), F.A.C.]
FW4. General Visible Emissions.
FW5. Unconfined Particulate Matter. No person shall cause, let, permit, suffer or allow the emissions of unconfined particulate matter from any activity, including vehicular movement; transportation of materials; construction; alteration; demolition or wrecking; or industrially related activities such as loading, unloading, storing or handling; without taking reasonable precautions to prevent such emissions. Reasonable precautions to prevent emissions of unconfined particulate matter at this facility include:
No person shall cause, let, permit, suffer or allow to be discharged into the atmosphere the emissions of air pollutants from any activity equal to or greater than 20% opacity. EPA Method 9 is the method of compliance pursuant to Chapter 62-297, F.A.C. This regulation does not impose a specific testing requirement.  
: a. Maintenance of paved areas as needed.
[Rule 62-296.320(4)(b), F.A.C.]FW5. Unconfined Particulate Matter. No person shall cause, let, permit, suffer or allow the emissions of unconfined particulate matter from any activity, including vehicular movement; transportation of materials; construction; alteration; demolition or wrecking; or industrially related activities such as loading, unloading, storing or handling; without taking reasonable precautions to prevent such emissions.
: b. Regular mowing of grass and care of vegetation.
Reasonable precautions to prevent emissions of unconfined particulate matter at this facility include: a. Maintenance of paved areas as needed.b. Regular mowing of grass and care of vegetation.
: c. Limiting access to plant property by unnecessary vehicles.
: c. Limiting access to plant property by unnecessary vehicles.[Rule 62-296.320(4)(c), F.A.C.; and, proposed by applicant in Title V air operation permit renewal application received May 21, 2009.]Annual Reports and Fees See Appendix RR, Facility-wide Reporting Requirements for additional details.FW6. Annual Operating Report. The permittee shall submit an annual report that summarizes the actual operating rates and emissions from this facility.
[Rule 62-296.320(4)(c), F.A.C.; and, proposed by applicant in Title V air operation permit renewal application received May 21, 2009.]
Annual operating reports shall be submitted to the Compliance Authority by April 1st of each year. [Rule 62-210.370(3), F.A.C.]FW7. Annual Emissions Fee Form and Fee. The annual Title V emissions fees are due (postmarked) by March 0 of each year. The completed form and calculated fee shall be submitted to: Major Air Pollution Source Annual Emissions Fee, P.O. Box 3070, Tallahassee, Florida 32315-3070.
Annual Reports and Fees See Appendix RR, Facility-wide Reporting Requirements for additional details.
The forms are available for download by accessing the Title V Annual Emissions Fee On-line Information Center at the following Internet web site: http://www.dep.state.fl.us/air/emission/tvfee.ht-n.  
FW6. Annual Operating Report. The permittee shall submit an annual report that summarizes the actual operating rates and emissions from this facility. Annual operating reports shall be submitted to the Compliance Authority by April 1st of each year. [Rule 62-210.370(3), F.A.C.]
[Rule 62-213.205, F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 4 of 54 SECTION II. FACILITY-WIDE CONDITIONS.
FW7. Annual Emissions Fee Form and Fee. The annual Title V emissions fees are due (postmarked) by March 0 of each year. The completed form and calculated fee shall be submitted to: Major Air Pollution Source Annual Emissions Fee, P.O. Box 3070, Tallahassee, Florida 32315-3070. The forms are available for download by accessing the Title V Annual Emissions Fee On-line Information Center at the following Internet web site: http://www.dep.state.fl.us/air/emission/tvfee.ht-n. [Rule 62-213.205, F.A.C.]
FW8. Annual Statement of Compliance.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 4 of 54
The permittee shall submit an annual statement of compliance to the compliance authority at the address shown on the cover of this permit within 60 days after the end of each calendar year during which the Title V permit was effective.  
 
[Rules 62-213.440(3)(a)2.  
SECTION II. FACILITY-WIDE CONDITIONS.
& 3. and (b), F.A.C.]FW9. Prevention of Accidental Releases (Section 112(r) of CAA).a. As required by Section 1 12(r)(7)(B)(iii) of the CAA and 40 CFR 68, the owner or operator shall submit an updated Risk Management Plan (RMP) to the Chemical Emergency Preparedness and Prevention Office (CEPPO) RMP Reporting Center.b. As required under Section 252.941(1)(c), F.S., the owner or operator shall report to the appropriate representative of the Department of Community Affairs (DCA), as established by department rule, within one working day of discovery of an accidental release of a regulated substance from the stationary source, if the owner or operator is required to report the release to the United States Environmental Protection Agency under Section 112(r)(6) of the CAA.c. The owner or operator shall submit the required annual registration fee to the DCA on or before April 1, in accordance with Part IV, Chapter 252, F.S., and Rule 9G-21, F.A.C.d. Any required written reports, notifications, certifications, and data required to be sent to the DCA, should be sent to: Department of Community Affairs, Division of Emergency Management, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2100, Telephone:  
FW8. Annual Statement of Compliance. The permittee shall submit an annual statement of compliance to the compliance authority at the address shown on the cover of this permit within 60 days after the end of each calendar year during which the Title V permit was effective. [Rules 62-213.440(3)(a)2. & 3. and (b), F.A.C.]
(850) 413-9921, Fax: (850) 488-1739.e. Any Risk Management Plans, original submittals, revisions, or updates to submittals, should be sent to: RMP Reporting Center, Post Office Box 10162, Fairfax, VA 22038, Telephone:  
FW9. Prevention of Accidental Releases (Section 112(r) of CAA).
(703) 227-7650.Any required reports to be sent to the National Response Center, should be sent to: National Response Center, EPA Office of Solid Waste and Emergency Response, USEPA (5305 W), 401 M Street SW, Washington, D.C. 20460, Telephone:  
: a. As required by Section 112(r)(7)(B)(iii) of the CAA and 40 CFR 68, the owner or operator shall submit an updated Risk Management Plan (RMP) to the Chemical Emergency Preparedness and Prevention Office (CEPPO) RMP Reporting Center.
(800) 424-8802.Send the required annual registration fee using approved forms made payable to: Cashier, Department of Community Affairs, State Emergency Response Commission, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2149
: b. As required under Section 252.941(1)(c), F.S., the owner or operator shall report to the appropriate representative of the Department of Community Affairs (DCA), as established by department rule, within one working day of discovery of an accidental release of a regulated substance from the stationary source, if the owner or operator is required to report the release to the United States Environmental Protection Agency under Section 112(r)(6) of the CAA.
[Part IV, Chapter 252, F.S.; and, Rule 9G-21, F.A.C.]Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 5 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: c. The owner or operator shall submit the required annual registration fee to the DCA on or before April 1, in accordance with Part IV, Chapter 252, F.S., and Rule 9G-21, F.A.C.
Subsection A. Emissions Units 001, 002 The specific conditions in this section apply to the following emissions units: EU No. Brief Description 001 FFSG, Unit 1 002 FFSG, Unit 2 Emissions unit 001 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler, It is rated at 440.5 megawatt (MW). Emissions are exhausted through a 499 feet stack with a 15 feet exit diameter, 2910 F exit temperature and 1,407,923 acfm actual volumetric flow rate.Emissions unit 002 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler. It is rated at 523.8 MW.Emissions are exhausted through a 502 feet stack with a 16 feet exit diameter, 3000 F exit temperature and 1,931,324 acfm actual volumetric flow rate.Emissions from both EUOO1 and EU002 are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Buell Manufacturing Company, Inc.[Permitting Notes: These emissions units are regulated under Acid Rain, Phase I and II and Rule 62-296.405, F.A.C., Fossil Fuel Steam Generators with More than 250 million Btu per Hour Heat Input, and Power Plant Siting Certification PA 77-09 conditions.
: d. Any required written reports, notifications, certifications, and data required to be sent to the DCA, should be sent to: Department of Community Affairs, Division of Emergency Management, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2100, Telephone: (850) 413-9921, Fax: (850) 488-1739.
The pollutants' emissions limits in Rule 62-296.405, F.A. C. have been changed through Permit Nos. 0170004-003-AC, 0170004-006-AC, PSD-FL-007, and PA 77-09. Fossil fuelfired steam generator Unit 1 began commercial operation in 1966. Fossilfuel fired steam generator Unit 2 began commercial operation in 1969.]Essential Potential to Emit (PTE) Parameters A.1. Permitted Capacity.
: e. Any Risk Management Plans, original submittals, revisions, or updates to submittals, should be sent to:
The maximum allowable heat input rate is as follows: EU No. MMBtu/hr Heat Input Fuel Type Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330  
RMP Reporting Center, Post Office Box 10162, Fairfax, VA 22038, Telephone: (703) 227-7650.
& 62-296.405, F.A.C.; and, Permit Nos.0170004-003-AC and 0170004-006-AC]
Any required reports to be sent to the National Response Center, should be sent to: National Response Center, EPA Office of Solid Waste and Emergency Response, USEPA (5305 W), 401 M Street SW, Washington, D.C. 20460, Telephone: (800) 424-8802.
[Permitting Note: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operation to 110 percent of the test load), to establish appropriate emission limits and to aid in determining future rule applicability.]
Send the required annual registration fee using approved forms made payable to: Cashier, Department of Community Affairs, State Emergency Response Commission, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2149
[Part IV, Chapter 252, F.S.; and, Rule 9G-21, F.A.C.]
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 5 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection A. Emissions Units 001, 002 The specific conditions in this section apply to the following emissions units:
EU No. Brief Description 001       FFSG, Unit 1 002       FFSG, Unit 2 Emissions unit 001 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler, It is rated at 440.5 megawatt (MW). Emissions are exhausted through a 499 feet stack with a 15 feet exit diameter, 2910 F exit temperature and 1,407,923 acfm actual volumetric flow rate.
Emissions unit 002 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler. It is rated at 523.8 MW.
Emissions are exhausted through a 502 feet stack with a 16 feet exit diameter, 3000 F exit temperature and 1,931,324 acfm actual volumetric flow rate.
Emissions from both EUOO1 and EU002 are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Buell Manufacturing Company, Inc.
[PermittingNotes: These emissions units are regulated under Acid Rain, Phase I and II and Rule 62-296.405, F.A.C., Fossil Fuel Steam Generatorswith More than 250 million Btu per Hour Heat Input, and Power Plant Siting CertificationPA 77-09 conditions. The pollutants' emissions limits in Rule 62-296.405, F.A. C. have been changed through Permit Nos. 0170004-003-AC, 0170004-006-AC, PSD-FL-007,and PA 77-09. Fossilfuelfired steam generator Unit 1 began commercial operation in 1966. Fossilfuelfired steam generator Unit 2 began commercial operationin 1969.]
Essential Potential to Emit (PTE) Parameters A.1.     Permitted Capacity. The maximum allowable heat input rate is as follows:
EU No.         MMBtu/hr Heat Input         Fuel Type Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture
[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330 & 62-296.405, F.A.C.; and, Permit Nos.
0170004-003-AC and 0170004-006-AC]
[PermittingNote: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operationto 110 percent of the test load), to establish appropriateemission limits and to aid in determiningfuture rule applicability.]
A.2. Methods of Operation.
A.2. Methods of Operation.
: a. Fuels. The fuels that are allowed to be burned in these units are: (1) Bituminous coal, (2) Bituminous coal and bituminous coal briquette mixture, (3) Distillate fuel oil for startup, and (4) Used oil in accordance with the specific conditions in Subsection J.[Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AO; and, 0170004-006-AC]
: a. Fuels. The fuels that are allowed to be burned in these units are:
A.3. Hours of Operation.
(1) Bituminous coal, (2) Bituminous coal and bituminous coal briquette mixture, (3) Distillate fuel oil for startup, and (4) Used oil in accordance with the specific conditions in Subsection J.
The emissions units may operate continuously, i.e., 8,760 hours/year.  
[Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AO; and, 0170004-006-AC]
[Rule 62-210.200(PTE), F.A.C.]A.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
A.3.     Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
[Rule 62-297.310(2), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 6 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
A.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
Subsection A. Emissions Units 001, 002 Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions A.5.-A.9.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 6 of 54
are based on the specified averaging time of the applicable test method.A.5. Visible Emissions (VE).a. EUO01. The VE from FFSG Unit 1 shall not exceed 40 percent opacity, six minute average. [Rule 62-296.405(1)(a), F.A.C.; OGC Case No. 86-1576, Order dated December 11, 1986; Permit No. 0170004-003-AC]b. EUO02. The VE from FFSG Unit 2 shall not exceed 20 percent opacity, six minute average, except for one two-minute period per hour during which opacity shall not exceed 40 percent. [Rule 62-296.405(1)(a), F.A.C.; Permit No. 0170004-003-AC]
 
[Permitting Note: Quarterly PM testing not required per Rule 62-296.405(1)(a), F.A.C. per OGC Case No.86-1576]A.6. VE -Soot Blowing and Load Change. Excess emissions resulting from boiler cleaning (soot blowing)and load change shall be permitted provided the duration of such excess emissions shall not exceed 3-hours in any 24 hour period and visible emissions shall not exceed Number 3 of the Ringelmann Chart (60 percent opacity), six minute average, and providing (1) best operational practices to minimize emissions are adhered to and (2) the duration of the excess emissions shall be minimized.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: a. Load Change. A load change occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more.b. VE > 60%. VE above 60 percent opacity shall be allowed for not more than 4, six (6)-minute periods, during the 3-hour period of excess emissions allowed by this condition, for boiler cleaning and load changes, at units which have installed and are operating continuous opacity monitors.[Rule 62-210.700(3), F.A.C. and Permit No. 0170004-003-AC]
Subsection A. Emissions Units 001, 002 Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions A.5.-A.9. are based on the specified averaging time of the applicable test method.
[Permitting Note: These units have operational continuous opacity monitors.]
A.5.     Visible Emissions (VE).
A.7. Particulate Matter (PM) Emissions.
: a. EUO01. The VE from FFSG Unit 1 shall not exceed 40 percent opacity, six minute average. [Rule 62-296.405(1)(a), F.A.C.; OGC Case No. 86-1576, Order dated December 11, 1986; Permit No. 0170004-003-AC]
PM emissions shall not exceed 0.1 pound per million Btu heat input.[Rule 62-296.405(1)(b), F.A.C.; Permit No. 0170004-003-AC]
: b. EUO02. The VE from FFSG Unit 2 shall not exceed 20 percent opacity, six minute average, except for one two-minute period per hour during which opacity shall not exceed 40 percent. [Rule 62-296.405(1)(a), F.A.C.; Permit No. 0170004-003-AC]
[Permitting note: The averaging time for the particulate matter standard corresponds to the cumulative sampling time of the specified test method.]A.8. PM -Soot Blowing and Load Change. PM emissions shall not exceed an average of 0.3 pounds per million Btu heat input during the 3-hours in any 24-hour period of excess emissions allowed for boiler cleaning (soot blowing) and load change. [Rule 62-210.700(3), F.A.C.; Permit No. 0170004-003-AC]
[PermittingNote: QuarterlyPM testing not requiredper Rule 62-296.405(1)(a), F.A.C. per OGC Case No.
A.9. Sulfur Dioxide (SOZ).a. Coal Burning. When burning coal, SO 2 emissions shall not exceed 2.1 pounds per million Btu heat input, 24-hour average.b. Coal/Briquette Mixture. The maximum percent sulfur content of the coal/briquette mixture shipment shall not exceed 1.05%, by weight, averaged on an annual basis.[Rule 62-213.440, F.A.C.; PPSC PA 77-09; Permit Nos. PSD-FL-007, 0170004-003-AC; and, 0170004-006-AC]Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
86-1576]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 7 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
A.6.     VE - Soot Blowing and Load Change. Excess emissions resulting from boiler cleaning (soot blowing) and load change shall be permitted provided the duration of such excess emissions shall not exceed 3-hours in any 24 hour period and visible emissions shall not exceed Number 3 of the Ringelmann Chart (60 percent opacity), six minute average, and providing (1) best operational practices to minimize emissions are adhered to and (2) the duration of the excess emissions shall be minimized.
Subsection A. Emissions Units 001, 002 A.10. Excess Emissions Allowed.a. Excess emissions resulting from startup, shutdown, or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
: a. Load Change. A load change occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more.
[Rule 62-210.700(1), F.A.C.]b. Excess emissions resulting from startup or shutdown shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized.
: b. VE > 60%. VE above 60 percent opacity shall be allowed for not more than 4, six (6)-minute periods, during the 3-hour period of excess emissions allowed by this condition, for boiler cleaning and load changes, at units which have installed and are operating continuous opacity monitors.
[Rule 62-210.700(2), F.A.C.]A.11. Excess Emissions Prohibited.
[Rule 62-210.700(3), F.A.C. and Permit No. 0170004-003-AC]
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
[PermittingNote: These units have operationalcontinuous opacity monitors.]
[Rule 62-210.700(4), F.A.C.]Monitoring of Operations A.12. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM)requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64;Rules 62-204.800 and 62-213.440(1)(b)1.a., F.A.C.]Continuous Monitoring Requirements A.13. Continuous Monitoring System. Each owner or operator shall install, calibrate, operate and maintain a continuous monitoring system for continuously monitoring opacity. Performance specifications, location of monitor, data requirements, data reduction and reporting requirements shall conform with the requirements of 40 C.F.R. Part 51, Appendix P, adopted and incorporated by reference in subsection 62-204.800(2), F.A.C., and 40 C.F.R. Part 60, Appendix B, adopted by reference in subsection 62-204.800(7), F.A.C. [Rule 62-296.405(f), F.A.C.](Permitting Note: The Acid Rain CEMs, required by 40 CFR 75, satisfies Specific Condition A.13.}Test Methods and Procedures A.14. Test Methods.Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 3 Gas Analysis for Carbon Dioxide, Oxygen, Excess Air, and Dry Molecular Weight Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources 5 Determination of Particulate Emissions from Stationary Sources 5B Determination of Nonsulfuric Acid Particulate Matter from Stationary Sources 5F Determination of Nonsulfate Particulate Matter from Stationary Sources 6 Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6C Determination of Sulfur Dioxide Emissions from Stationary Sources Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 8 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
A.7. Particulate Matter (PM) Emissions. PM emissions shall not exceed 0.1 pound per million Btu heat input.
Subsection A. Emissions Units 001, 002 Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Particulate Emissions from Stationary Sources (In-Stack Filtration Method)Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, 19 Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.)ASTM D2013-72, Standard Methods by the American Society of Testing and Materials for Fuel ASTM D3177-75, Analysis ASTM D4239-85, or latest ASTM edition methods The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.  
[Rule 62-296.405(1)(b), F.A.C.; Permit No. 0170004-003-AC]
[Rules 62-297.401, and 62-204.800, F.A.C., Permit No. 0170004-003-AC]
[Permitting note: The averaging time for the particulatematter standardcorrespondsto the cumulative sampling time of the specified test method.]
A.15. Common Testing Requirements.
A.8. PM - Soot Blowing and Load Change. PM emissions shall not exceed an average of 0.3 pounds per million Btu heat input during the 3-hours in any 24-hour period of excess emissions allowed for boiler cleaning (soot blowing) and load change. [Rule 62-210.700(3), F.A.C.; Permit No. 0170004-003-AC]
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.3 10, F.A.C.]A.16. Annual Compliance Tests Required.
A.9. Sulfur Dioxide (SOZ).
Except as provided in Specific Condition A.23., during each federal fiscal year (October 1st to September 30th), each EUOO1 and EU002 shall be tested to demonstrate compliance with the emissions standards for PM and VE. [Rule 62-297.310(7), F.A.C.; OGC Case No. 86-1576; and Permit No. 0170004-003-AC]
: a. Coal Burning. When burning coal, SO 2 emissions shall not exceed 2.1 pounds per million Btu heat input, 24-hour average.
A.17. Compliance Tests Prior To Renewal. Except as provided in Specific Condition A.23., compliance tests shall be performed for PM and VE once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions A.5. -A.9.[Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]A.18. PM Emissions.
: b. Coal/BriquetteMixture. The maximum percent sulfur content of the coal/briquette mixture shipment shall not exceed 1.05%, by weight, averaged on an annual basis.
The test methods for PM emissions shall be EPA Methods 17, 5, 5B, or 5F, incorporated by reference in Chapter 62-297, F.A.C. The minimum sample volume shall be 30 dry standard cubic feet.EPA Method 5 may be used with filter temperature no more than 320 degrees Fahrenheit.
[Rule 62-213.440, F.A.C.; PPSC PA 77-09; Permit Nos. PSD-FL-007, 0170004-003-AC; and, 0170004-006-AC]
For EPA Method 17, stack temperature shall be less than 375 degrees Fahrenheit.
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
The owner or operator may use EPA Method 5 to demonstrate compliance.
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 7 of 54
EPA Method 3 or 3A with Orsat analysis shall be used when the oxygen based F-factor, computed according to EPA Method 19, is used in lieu of heat input. Acetone wash shall be used with EPA Method 5 or 17. [Rules 62-213.440, 62-296.405(1)(e)2., and 62-297.401, F.A.C.; Permit No.0170004-003-AC]
 
A.19. VE. The test method for VE shall be EPA Method 9, incorporated in Chapter 62-297, F.A.C. In lieu of Method 9 testing, a transmissometer utilizing a 6-minute block average for opacity measurement may be used, provided such transmissometer is installed, certified, calibrated, operated and maintained in accordance with the provisions of 40 CFR 75. [Rules 62-296.405(1)(e)1.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
and 62-297.401, F.A.C.; Permit No. 0170004-003-AC]A.20. SO2. The test methods for SO 2 emissions shall be EPA Methods 6, 6A, 6B, or 6C, incorporated by reference in Chapter 62-297, F.A.C. Fuel sampling and analysis may be used as an alternate sampling procedure.
Subsection A. Emissions Units 001, 002 A.10. Excess Emissions Allowed.
The Department will retain the authority to require EPA Method 6 or 6C if it has reason to believe that exceedences of the sulfur dioxide emissions limiting standard are occurring.
: a. Excess emissions resulting from startup, shutdown, or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
Results of an approved fuel Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 9 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: b. Excess emissions resulting from startup or shutdown shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized.
Subsection A. Emissions Units 001, 002 sampling and analysis program shall have the same effect as EPA Method 6 test results for purposes of demonstrating compliance or noncompliance with sulfur dioxide standards.
[Rule 62-210.700(2), F.A.C.]
The permittee may use the EPA test methods, referenced above, to demonstrate compliance; however, as an alternate sampling procedure authorized by permit, the permittee may demonstrate compliance using fuel sampling and analysis.
A.11. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
If the permittee elects to discontinue fuel sampling and analysis, it shall perform a stack test for sulfur dioxide at the time of the next particulate matter test, and annually thereafter until fuel sampling and analysis is resumed. [Rules 62-213.440, 62-296.405(1)(e)3.
Monitoring of Operations A.12. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM) requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64; Rules 62-204.800 and 62-213.440(1)(b)1.a., F.A.C.]
and 62-297.401, F.A.C.; Permit No. 0170004-003-AC; PA 77-09]A.21. SO? -Fuel Analysis.
Continuous Monitoring Requirements A.13. Continuous Monitoring System. Each owner or operator shall install, calibrate, operate and maintain a continuous monitoring system for continuously monitoring opacity. Performance specifications, location of monitor, data requirements, data reduction and reporting requirements shall conform with the requirements of 40 C.F.R. Part 51, Appendix P, adopted and incorporated by reference in subsection 62-204.800(2), F.A.C.,
The owner or operator may demonstrate compliance with the SO 2 limitation using fuel sampling and analysis.
and 40 C.F.R. Part 60, Appendix B, adopted by reference in subsection 62-204.800(7), F.A.C. [Rule 62-296.405(f), F.A.C.]
This protocol is allowed because the emissions unit does not have an operating flue gas desulfurization device. See specific conditions A.20. and A.22. [Rule 62-296.405(1)(f)1.b., F.A.C.;Permit Nos. 0170004-003-AC and 0170004-006-AC]
(PermittingNote: The Acid Rain CEMs, requiredby 40 CFR 75, satisfies Specific Condition A.13.}
A.22. SO? -Alternate Fuel Sampling.
Test Methods and Procedures A.14. Test Methods. Required tests shall be performed in accordance with the following reference methods:
The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the SO 2 standard: a. Method. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.b. Recordkeeping.
Method           Description of Method and Comments 3             Gas Analysis for Carbon Dioxide, Oxygen, Excess Air, and Dry Molecular Weight Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources 5             Determination of Particulate Emissions from Stationary Sources 5B             Determination of Nonsulfuric Acid Particulate Matter from Stationary Sources 5F             Determination of Nonsulfate Particulate Matter from Stationary Sources 6             Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6C             Determination of Sulfur Dioxide Emissions from Stationary Sources Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                        Title V Air Operation Permit Renewal Page 8 of 54
Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.c. Calculations.
 
Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.[Rules 62-213.440, 62-296.405(1)(e)3., 62-296.405(1)(f) 1.b. and 62-297.440, F.A.C.; Permit Nos. 0170004-003-AC and 0170004-006-AC]
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
A.23. When PM Tests Not Required.
Subsection A. Emissions Units 001, 002 Method           Description of Method and Comments 9           Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Particulate Emissions from Stationary Sources (In-Stack Filtration Method)
Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning: a. only gaseous fuel(s); or b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or c. only liquid fuel(s) for less than 400 hours per year.[Rules 62-297.310(7)(a)3.  
Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, 19           Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.)
& 5., F.A.C.; and, ASP Number 97-B-01.]Recordkeeping and Reporting Requirements A.24. Reporting Schedule.
ASTM D2013-72,         Standard Methods by the American Society of Testing and Materials for Fuel ASTM D3177-75,         Analysis ASTM D4239-85, or latest ASTM edition methods The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rules 62-297.401, and 62-204.800, F.A.C., Permit No. 0170004-003-AC]
The following reports and notifications shall be submitted to the Compliance Authority:
A.15. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.3 10, F.A.C.]
Report Reporting Deadline Related Condition(s)
A.16. Annual Compliance Tests Required. Except as provided in Specific Condition A.23., during each federal fiscal year (October 1st to September 30th), each EUOO1 and EU002 shall be tested to demonstrate compliance with the emissions standards for PM and VE. [Rule 62-297.310(7), F.A.C.; OGC Case No. 86-1576; and Permit No. 0170004-003-AC]
Notice of Excess Emissions Quarterly A.25.A.25. Quarterly Reporting.
A.17. Compliance Tests Prior To Renewal. Except as provided in Specific Condition A.23., compliance tests shall be performed for PM and VE once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions A.5. - A.9.
The owners or operators shall submit to the Department a written report of emissions in excess of the emission limiting standards, for each calendar quarter. The nature and cause of the excessive emissions shall be explained.
[Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]
This report does not relieve the owner or operator of the legal liability for violations.
A.18. PM Emissions. The test methods for PM emissions shall be EPA Methods 17, 5, 5B, or 5F, incorporated by reference in Chapter 62-297, F.A.C. The minimum sample volume shall be 30 dry standard cubic feet.
All recorded data shall be maintained on file by the facility for a period of five years.[Rules 62-213.440 and 62-296.405(g), F.A.C.]A.26. Other Reporting Requirements.
EPA Method 5 may be used with filter temperature no more than 320 degrees Fahrenheit. For EPA Method 17, stack temperature shall be less than 375 degrees Fahrenheit. The owner or operator may use EPA Method 5 to demonstrate compliance. EPA Method 3 or 3A with Orsat analysis shall be used when the oxygen based F-factor, computed according to EPA Method 19, is used in lieu of heat input. Acetone wash shall be used with EPA Method 5 or 17. [Rules 62-213.440, 62-296.405(1)(e)2., and 62-297.401, F.A.C.; Permit No.
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
0170004-003-AC]
A.19. VE. The test method for VE shall be EPA Method 9, incorporated in Chapter 62-297, F.A.C. In lieu of Method 9 testing, a transmissometer utilizing a 6-minute block average for opacity measurement may be used, provided such transmissometer is installed, certified, calibrated, operated and maintained in accordance with the provisions of 40 CFR 75. [Rules 62-296.405(1)(e)1. and 62-297.401, F.A.C.; Permit No. 0170004-003-AC]
A.20. SO2. The test methods for SO 2 emissions shall be EPA Methods 6, 6A, 6B, or 6C, incorporated by reference in Chapter 62-297, F.A.C. Fuel sampling and analysis may be used as an alternate sampling procedure. The Department will retain the authority to require EPA Method 6 or 6C if it has reason to believe that exceedences of the sulfur dioxide emissions limiting standard are occurring. Results of an approved fuel Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 9 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection A. Emissions Units 001, 002 sampling and analysis program shall have the same effect as EPA Method 6 test results for purposes of demonstrating compliance or noncompliance with sulfur dioxide standards. The permittee may use the EPA test methods, referenced above, to demonstrate compliance; however, as an alternate sampling procedure authorized by permit, the permittee may demonstrate compliance using fuel sampling and analysis. If the permittee elects to discontinue fuel sampling and analysis, it shall perform a stack test for sulfur dioxide at the time of the next particulate matter test, and annually thereafter until fuel sampling and analysis is resumed. [Rules 62-213.440, 62-296.405(1)(e)3. and 62-297.401, F.A.C.; Permit No. 0170004-003-AC; PA 77-09]
A.21. SO? - Fuel Analysis. The owner or operator may demonstrate compliance with the SO 2 limitation using fuel sampling and analysis. This protocol is allowed because the emissions unit does not have an operating flue gas desulfurization device. See specific conditions A.20. and A.22. [Rule 62-296.405(1)(f)1.b., F.A.C.;
Permit Nos. 0170004-003-AC and 0170004-006-AC]
A.22. SO? - Alternate Fuel Sampling. The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the SO2 standard:
: a. Method. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.
: b. Recordkeeping. Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.
: c. Calculations. Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.
[Rules 62-213.440, 62-296.405(1)(e)3., 62-296.405(1)(f) 1.b. and 62-297.440, F.A.C.; Permit Nos. 0170004-003-AC and 0170004-006-AC]
A.23. When PM Tests Not Required. Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning:
: a. only gaseous fuel(s); or
: b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or
: c. only liquid fuel(s) for less than 400 hours per year.
[Rules 62-297.310(7)(a)3. & 5., F.A.C.; and, ASP Number 97-B-01.]
Recordkeeping and Reporting Requirements A.24. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority:
Report                             Reporting Deadline                     Related Condition(s)
Notice of Excess Emissions                           Quarterly                                 A.25.
A.25. Quarterly Reporting. The owners or operators shall submit to the Department a written report of emissions in excess of the emission limiting standards, for each calendar quarter. The nature and cause of the excessive emissions shall be explained. This report does not relieve the owner or operator of the legal liability for violations. All recorded data shall be maintained on file by the facility for a period of five years.
[Rules 62-213.440 and 62-296.405(g), F.A.C.]
A.26. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Other Requirements A.27. These emissions units are also subject to conditions contained in Subsection J. Used Oil Common Condition.
Other Requirements A.27. These emissions units are also subject to conditions contained in Subsection J. Used Oil Common Condition.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 10 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 10 of 54
Subsection B. Emissions Units 003, 004 The specific conditions in this section apply to the following emissions units: EU No. Brief Description 003 FFSG, Unit 5 004 FFSG, Unit 4 Emissions units 003 and 004 (EU003 and EU004) are pulverized coal, dry bottom, wall-fired boilers. Both are rated at 760 MW. Emissions are exhausted through their own stacks. Each stack is 600 feet stack with a 25.5 feet exit diameter, 253 'F exit temperature and 2,979 acfm actual volumetric flow rate. Emissions are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Combustion Engineering.
 
[Permitting Notes: These emissions units are regulated under Acid Rain, Phase I and H and Rule 62-210.300, F.A.C., Permits Required; 40 CFR 60 Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction Is Commenced After August 17, 1971; PSD-FL-007 issued by EPA in February 1978 and, Power Plant Siting Certification PA 77-09 conditions.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Fossilfuel fired steam generator Unit 4 began commercial operation in 1982. Fossil fuelfired steam generator Unit 5 began commercial operation in 1984.]Essential Potential to Emit (PTE) Parameters B.1. Permitted Capacity.
Subsection B. Emissions Units 003, 004 The specific conditions in this section apply to the following emissions units:
The maximum allowable heat input rate is as follows: Unit No. MMBtu/hr Heat Input Fuel Type Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330, F.A.C.]B.2. Methods of Operation  
EU No. Brief Description 003       FFSG, Unit 5 004       FFSG, Unit 4 Emissions units 003 and 004 (EU003 and EU004) are pulverized coal, dry bottom, wall-fired boilers. Both are rated at 760 MW. Emissions are exhausted through their own stacks. Each stack is 600 feet stack with a 25.5 feet exit diameter, 253 'F exit temperature and 2,979 acfm actual volumetric flow rate. Emissions are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Combustion Engineering.
-Fuels. The fuels that are allowed to be burned in these units are: a. Bituminous coal, b. Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and natural gas may be used as a startup and low load flame stabilization fuel.c. Used oil in accordance with the specific conditions of this permit (See Subsection J.).[Rule 62-213.410, F.A.C.; Permit No. 0170004-006-AC; PPSC PA-77-09 and modified conditions]
[PermittingNotes: These emissions units are regulated underAcid Rain, Phase I and H and Rule 62-210.300, F.A.C., Permits Required; 40 CFR 60 Subpart D, Standardsof Performancefor Fossil-Fuel-FiredSteam Generatorsfor Which ConstructionIs Commenced After August 17, 1971; PSD-FL-007 issued by EPA in February 1978 and, Power Plant Siting CertificationPA 77-09 conditions. Fossilfuelfired steam generator Unit 4 began commercial operation in 1982. Fossilfuelfired steam generatorUnit 5 began commercial operationin 1984.]
B.3. Flue Gas Desulfurization (FGD) Equipment.
Essential Potential to Emit (PTE) Parameters B.1.     Permitted Capacity. The maximum allowable heat input rate is as follows:
Prior to the installation of any FGD equipment, plans and specifications for such equipment shall be submitted to the Department for review and approval.  
Unit No.     MMBtu/hr Heat Input         Fuel Type Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture
[PPSC PA 77-09]B.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330, F.A.C.]
[Rule 62-297.310(2), F.A.C.]B.5. Hours of Operation.
B.2.     Methods of Operation - Fuels. The fuels that are allowed to be burned in these units are:
The emissions units may operate continuously, i.e., 8,760 hours/year.  
: a. Bituminous coal,
[Rule 62-210.200(PTE), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions B.6. -B.10. are based on the specified averaging time of the applicable test method.B.6. PM Emissions.
: b. Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and natural gas may be used as a startup and low load flame stabilization fuel.
No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which: a. Contain PM in excess of 43 nanograms per joule heat input (0.10 lb per million Btu) derived from fossil fuel.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 11 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: c. Used oil in accordance with the specific conditions of this permit (See Subsection J.).
Subsection B. Emissions Units 003, 004 b. Exhibit greater than 20 percent opacity, six minute average, except for one six-minute period per hour of not more than 27 percent opacity.[40 CFR 60.42(a)(1)  
[Rule 62-213.410, F.A.C.; Permit No. 0170004-006-AC; PPSC PA-77-09 and modified conditions]
& (2)]B.7. SO1 Emissions.
B.3.     Flue Gas Desulfurization (FGD) Equipment. Prior to the installation of any FGD equipment, plans and specifications for such equipment shall be submitted to the Department for review and approval. [PPSC PA 77-09]
No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain SO 2 in excess of: a. 340 nanograms per joule heat input (0.80 lb per million Btu), 24-hour average, derived from liquid fossil fuel.b. 520 nanograms per joule heat input (1.2 lb per million Btu), 24-hour average, derived from solid fossil fuel.c. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) shall be determined by proration using the following formula: PSS 0 2 = [y(340) +z(520)]/(y+z) where: PSS 0 2 is the prorated standard for sulfur dioxide when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired, y is the percentage of total heat input derived from liquid fossil fuel, and z is the percentage of total heat input derived from solid fossil fuel.d. Compliance shall be based on the total heat input from all fossil fuels burned, including gaseous fuels.[40 CFR 60.43(a), (b) and (c); and, PPSC PA 77-09]B.8. SO, -Sulfur Content.a. The maximum percent sulfur content of the coal/briquette mixture shall not exceed 0.68%, by weight, averaged on an annual basis. [Rule 62-213.440, F.A.C.; and, Permit No. 0170004-006-AC]
B.4.     Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
B.5.     Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions B.6. - B.10. are based on the specified averaging time of the applicable test method.
B.6.     PM Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which:
: a. Contain PM in excess of 43 nanograms per joule heat input (0.10 lb per million Btu) derived from fossil fuel.
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 11 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection B. Emissions Units 003, 004
: b. Exhibit greater than 20 percent opacity, six minute average, except for one six-minute period per hour of not more than 27 percent opacity.
[40 CFR 60.42(a)(1) & (2)]
B.7. SO1 Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain SO 2 in excess of:
: a. 340 nanograms per joule heat input (0.80 lb per million Btu), 24-hour average, derived from liquid fossil fuel.
: b. 520 nanograms per joule heat input (1.2 lb per million Btu), 24-hour average, derived from solid fossil fuel.
: c. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) shall be determined by proration using the following formula:
PSS 0 2 = [y(340) +z(520)]/(y+z) where:
PSS0 2 is the prorated standard for sulfur dioxide when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired, y is the percentage of total heat input derived from liquid fossil fuel, and z is the percentage of total heat input derived from solid fossil fuel.
: d. Compliance shall be based on the total heat input from all fossil fuels burned, including gaseous fuels.
[40 CFR 60.43(a), (b) and (c); and, PPSC PA 77-09]
B.8. SO, - Sulfur Content.
: a. The maximum percent sulfur content of the coal/briquette mixture shall not exceed 0.68%, by weight, averaged on an annual basis. [Rule 62-213.440, F.A.C.; and, Permit No. 0170004-006-AC]
: b. Fuel oil shall not contain more than 0.73% sulfur by weight. (See Specific Condition B.2.) [Rule 62-213.410, F.A.C.; PPSC PA-77-09 and modified conditions]
: b. Fuel oil shall not contain more than 0.73% sulfur by weight. (See Specific Condition B.2.) [Rule 62-213.410, F.A.C.; PPSC PA-77-09 and modified conditions]
B.9. Nitrogen Oxides (NOx) Emissions.
B.9. Nitrogen Oxides (NOx) Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain nitrogen oxides, expressed as NO 2 , in excess of:
No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain nitrogen oxides, expressed as NO 2 , in excess of: a. 86 nanograms per joule heat input (0.20 lb per million Btu), 30-day rolling average, derived from gaseous fossil fuel.b. 129 nanograms per joule heat input (0.30 lb per million Btu), 30-day rolling average, derived from liquid fossil fuel.c. 300 nanograms per joule heat input (0.70 lb per million Btu), 30-day rolling average, derived from solid fossil fuel.d. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) is determined by proration using the following formula: PSNOx = x(86)+y(130)+z(300) x+y+z where: PSNOx = is the prorated standard for nitrogen oxides when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels fired;x = is the percentage of total heat input derived from gaseous fossil fuel;y = is the percentage of total heat input derived from liquid fossil fuel; and, z = is the percentage of total heat input derived from solid fossil fuel.[40 CFR 60.44(a)(2) and (3), and (b); and, PPSC PA 77-09]Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 12 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: a. 86 nanograms per joule heat input (0.20 lb per million Btu), 30-day rolling average, derived from gaseous fossil fuel.
Subsection B. Emissions Units 003, 004 B.10. Unit Specific State Only Limit For NOx. A unit specific, state-only average annual NOx emission limit of 0.50 lb/MMBtu applies. Compliance shall be demonstrated within the Annual Operating Report (AOR).[Rule 62-4.070(3), F.A.C.]Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
: b. 129 nanograms per joule heat input (0.30 lb per million Btu), 30-day rolling average, derived from liquid fossil fuel.
B.11. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
: c. 300 nanograms per joule heat input (0.70 lb per million Btu), 30-day rolling average, derived from solid fossil fuel.
[Rule 62-210.700(1), F.A.C.]B.12. Excess Emissions Prohibited.
: d. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) is determined by proration using the following formula:
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
PSNOx = x(86)+y(130)+z(300) x+y+z where:
[Rule 62-210.700(4), F.A.C.]B.13. NSPS Excess Emissions.
PSNOx = is the prorated standard for nitrogen oxides when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels fired; x = is the percentage of total heat input derived from gaseous fossil fuel; y = is the percentage of total heat input derived from liquid fossil fuel; and, z = is the percentage of total heat input derived from solid fossil fuel.
Excess emissions shall be as defined in 40 CFR 60.45(g), Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced After August 17, 1971. [40 CFR 60.45(g)]Monitorine of Operations B.14. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM)requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64;Rules 62-204.800 and 62-213.440(1)(b)l.a., F.A.C.]B.15. Ambient Air Monitoring.
[40 CFR 60.44(a)(2) and (3), and (b); and, PPSC PA 77-09]
An ambient monitoring station located on site (Site No. 2) includes monitors for particulate matter less than 10 micrometers in diameter (PM 1 0), particulate matter 2.5 micrometers in diameter and smaller (PM 2 5), and SO 2.All monitors located at Site No. 2 will continue to be operated by Progress Energy Florida (PEF) and PEF will continue reporting data from these monitors as required by Special Condition 1.A.2 of the Conditions of Certification.
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                            Title V Air Operation Permit Renewal Page 12 of 54
New or existing monitoring devices shall be located as designated by the Department.
 
The monitoring devices for sulfur dioxide shall meet the requirements of 40 CFR 53. [PPSC PA 77-09, and order modifying conditions of certification, OGC Case No. 83-0818, dated February 2, 1984, and Rules 62-213.440 and 62-296.405(1)(c)3., F.A.C.; Department letter dated July 23, 2008]Continuous Monitoring Requirements B.16. Required Continuous Monitoring Systems (CMS). Continuous monitoring systems are required for SO 2 , NOx, CO 2 and opacity. CMS shall be in accordance with the requirements of 40 CFR 60.45. [40 CFR 60.45;and PPSC PA 77-09]B.17. COMS for Periodic Monitoring:
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Periodic monitoring for opacity shall be COMS, which are maintained and operated in conformance with 40 CFR Part 75. [Rule 62-213.440, F.A.C.]Test Methods and Procedures B.18. Test Methods. Required tests shall be performed in accordance with the following reference methods: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 13 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection B. Emissions Units 003, 004 B.10. Unit Specific State Only Limit For NOx. A unit specific, state-only average annual NOx emission limit of 0.50 lb/MMBtu applies. Compliance shall be demonstrated within the Annual Operating Report (AOR).
Subsection B. Emissions Units 003, 004 Method Description of Method and Comments Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 5 Determination of Particulate Emissions from Stationary Sources 5B Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6B Determination of Sulfur Dioxide Emissions from Stationary Sources 6C Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Nitrogen Oxide Emissions from Stationary Sources -Ion Chromatographic Method Determination of Nitrogen Oxide Emissions from Stationary Sources -Alkaline-Permanganate/Colormetric Method Determination of Nitrogen Oxide Emissions from Stationary Sources (Instrument Analyzer Procedure)
[Rule 62-4.070(3), F.A.C.]
Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 7E Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Sulfuric Acid Mist and Sulfur Dioxide Emission from Stationary Sources 9 Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.)ASTM Method D2015- Standard Methods by the American Society of Testing and Materials for fuel 77, D240-76, D1826-77, analysis ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.  
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
[Rule 62-297.401, F.A.C.; 40 CFR 60 Subpart D]Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 14 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
B.11. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
Subsection B. Emissions Units 003, 004 B.19. Common Testing Requirements.
B.12. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]B.20. Annual Compliance Tests Required.
B.13. NSPS Excess Emissions. Excess emissions shall be as defined in 40 CFR 60.45(g), Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced After August 17, 1971. [40 CFR 60.45(g)]
Except as provided in Specific Condition B.27., during each federal fiscal year (October 1st to September 3 0 th), each EU003 and EU004 shall be tested to demonstrate compliance with the emissions standards for PM, VE, SO 2 and NOx. [Rule 62-297.310(7), F.A.C.]B.21. Compliance Tests Prior To Renewal. Except as provided in Specific Condition B.27., compliance tests shall be performed for PM, VE, SO 2 and NOx once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions B.6. -B.10. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]B.22. Compliance Testing Required.
Monitorine of Operations B.14. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM) requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64; Rules 62-204.800 and 62-213.440(1)(b)l.a., F.A.C.]
The owner or operator shall conduct emission testing in accordance with the requirements of 40 CFR 60.46. [40 CFR 60.46]B.23. Annual RATA Tests May Substitute for Annual NOx and SO) Tests. Annual RATA tests performed for NOx and SO 2 may be substituted for the annual compliance tests for these pollutants.
B.15. Ambient Air Monitoring. An ambient monitoring station located on site (Site No. 2) includes monitors for particulate matter less than 10 micrometers in diameter (PM 10), particulate matter 2.5 micrometers in diameter and smaller (PM 2 5), and SO 2 . All monitors located at Site No. 2 will continue to be operated by Progress Energy Florida (PEF) and PEF will continue reporting data from these monitors as required by Special Condition 1.A.2 of the Conditions of Certification. New or existing monitoring devices shall be located as designated by the Department. The monitoring devices for sulfur dioxide shall meet the requirements of 40 CFR 53. [PPSC PA 77-09, and order modifying conditions of certification, OGC Case No. 83-0818, dated February 2, 1984, and Rules 62-213.440 and 62-296.405(1)(c)3., F.A.C.; Department letter dated July 23, 2008]
To substitute for the annual compliance tests, the owner or operator must notify the Department of the RATA tests at least 15 days prior to the date on which each formal compliance test is to begin and the results must be submitted as the compliance tests no later than 45 days after the last sampling run of each test is completed.
Continuous Monitoring Requirements B.16. Required Continuous Monitoring Systems (CMS). Continuous monitoring systems are required for SO 2, NOx, CO 2 and opacity. CMS shall be in accordance with the requirements of 40 CFR 60.45. [40 CFR 60.45; and PPSC PA 77-09]
The test runs shall be consecutively completed in a manner that fulfills the test length requirements of the EPA test methods. [40 CFR 75; Request of applicant, February 11, 1998]B.24. SO, -Fuel Analysis.
B.17. COMS for Periodic Monitoring: Periodic monitoring for opacity shall be COMS, which are maintained and operated in conformance with 40 CFR Part 75. [Rule 62-213.440, F.A.C.]
The permittee shall demonstrate compliance with the SO 2 limit in specific condition B.8.a. by means of a fuel analysis provided by the vendor or the permittee upon each fuel delivery.
Test Methods and Procedures B.18. Test Methods. Required tests shall be performed in accordance with the following reference methods:
See specific condition B.25. [Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC]
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 13 of 54
B.25. SO -Alternate Fuel Sampling.
 
The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the fuel sulfur standard: a. Methods. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.b. Recordkeeping.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.c. Calculations.
Subsection B. Emissions Units 003, 004 Method         Description of Method and Comments Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 5           Determination of Particulate Emissions from Stationary Sources 5B           Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6B           Determination of Sulfur Dioxide Emissions from Stationary Sources 6C           Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Nitrogen Oxide Emissions from Stationary Sources - Ion Chromatographic Method Determination of Nitrogen Oxide Emissions from Stationary Sources -
Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.[Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC]
Alkaline-Permanganate/Colormetric Method Determination of Nitrogen Oxide Emissions from Stationary Sources (Instrument Analyzer Procedure)
B.26. VE. The test method for VE shall be EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Chapter 62-297, F.A.C. [Rules 62-296.405(1)(e)1.
Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 7E           Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Sulfuric Acid Mist and Sulfur Dioxide Emission from Stationary Sources 9           Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.)
and 62-297.401, F.A.C.]B.27. When PM Tests Not Required.
ASTM Method D2015- Standard Methods by the American Society of Testing and Materials for fuel 77, D240-76, D1826-77, analysis ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C.; 40 CFR 60 Subpart D]
Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning: a. only gaseous fuel(s); or b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or c. only liquid fuel(s) for less than 400 hours per year.[Rules 62-297.310(7)(a)3.  
Progress Energy Florida, Inc.                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                    Title V Air Operation Permit Renewal Page 14 of 54
& 5., F.A.C.; and, ASP Number 97-B-01.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 15 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
 
Subsection B. Emissions Units 003, 004 Recordkeeping and Reporting Requirements B.28. Reporting Schedule.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
The following reports and notifications shall be submitted to the Compliance Authority:
Subsection B. Emissions Units 003, 004 B.19. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]
Report Reporting Deadline Related Condition(s)
B.20. Annual Compliance Tests Required. Except as provided in Specific Condition B.27., during each federal fiscal year (October 1st to September 3 0 th), each EU003 and EU004 shall be tested to demonstrate compliance with the emissions standards for PM, VE, SO 2 and NOx. [Rule 62-297.310(7), F.A.C.]
Notice of Excess Emissions Postmarked by the 3 0 th day following the B.13. and B.29 end of each six-month period B.29. Excess Emission Reports. Excess emissions, as defined in 40 CFR 60.45(g), shall be reported in accordance with the requirements of 40 CFR 60.45(g).  
B.21. Compliance Tests Prior To Renewal. Except as provided in Specific Condition B.27., compliance tests shall be performed for PM, VE, SO 2 and NOx once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions B.6. -
[40 CFR 60.45(g)]B.30. Other Reporting Requirements.
B.10. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
B.22. Compliance Testing Required. The owner or operator shall conduct emission testing in accordance with the requirements of 40 CFR 60.46. [40 CFR 60.46]
B.23. Annual RATA Tests May Substitute for Annual NOx and SO) Tests. Annual RATA tests performed for NOx and SO 2 may be substituted for the annual compliance tests for these pollutants. To substitute for the annual compliance tests, the owner or operator must notify the Department of the RATA tests at least 15 days prior to the date on which each formal compliance test is to begin and the results must be submitted as the compliance tests no later than 45 days after the last sampling run of each test is completed. The test runs shall be consecutively completed in a manner that fulfills the test length requirements of the EPA test methods. [40 CFR 75; Request of applicant, February 11, 1998]
B.24. SO, - Fuel Analysis. The permittee shall demonstrate compliance with the SO 2 limit in specific condition B.8.a. by means of a fuel analysis provided by the vendor or the permittee upon each fuel delivery. See specific condition B.25. [Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC]
B.25. SO - Alternate Fuel Sampling. The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the fuel sulfur standard:
: a. Methods. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.
: b. Recordkeeping. Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.
: c. Calculations. Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.
[Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC]
B.26. VE. The test method for VE shall be EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Chapter 62-297, F.A.C. [Rules 62-296.405(1)(e)1. and 62-297.401, F.A.C.]
B.27. When PM Tests Not Required. Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning:
: a. only gaseous fuel(s); or
: b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or
: c. only liquid fuel(s) for less than 400 hours per year.
[Rules 62-297.310(7)(a)3. & 5., F.A.C.; and, ASP Number 97-B-01.]
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                       Title V Air Operation Permit Renewal Page 15 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection B. Emissions Units 003, 004 Recordkeeping and Reporting Requirements B.28. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority:
Report                           Reporting Deadline                               Related Condition(s)
Notice of Excess Emissions       Postmarked by the 3 0 th day following the       B.13. and B.29 end of each six-month period B.29. Excess Emission Reports. Excess emissions, as defined in 40 CFR 60.45(g), shall be reported in accordance with the requirements of 40 CFR 60.45(g). [40 CFR 60.45(g)]
B.30. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Other Requirements B.31. These emissions units are also subject to condition J.1. contained in Subsection J. Used Oil Common Condition.
Other Requirements B.31. These emissions units are also subject to condition J.1. contained in Subsection J. Used Oil Common Condition.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 16 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                      Title V Air Operation Permit Renewal Page 16 of 54
Subsection C. Emissions Units 006, 008, 009, 010 The specific conditions in this section apply to the following emissions units:.EU No. Brief Description 006 Fly ash transfer (Source 1) from FFSG Unit 1 008 Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009 Fly ash transfer (Source 4) from FFSG Unit 2 010 Fly ash transfer (Source 5) from FFSG Unit 2 Emissions unit 006 (EU006) is a fly ash transfer (Source 1) from FFSG Unit 1. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 1 electrostatic precipitator (ESP) to the fly ash storage silo (Source 3) at a design transfer rate of 44 tons per hour.PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 1,820 acfm.Emissions unit 008 (EU008) is a fly ash storage silo (Source 3) for FFSG Units 1 and 2. This emissions unit consists of the fly ash storage silo used to store fly ash from the ESP of FFSG Units 1 and 2. Fly ash is pneumatically conveyed from the FFSG Units 1 and 2 ESPs at a combined transfer rate of 174 tons per hour. PM emissions are controlled by a Pulse King Model M 100 S baghouse at a design air flow of 2,546 acfm. Fly ash from the storage silo is disposed of either in a dry form by loading into enclosed tanker trucks or in a wet form by loading wet ash into open trucks.Emissions unit 009 (EU009) is a fly ash transfer (Source 4) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2C to the fly ash storage silo (Source 3) at a design transfer rate of 60 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,200 acfm.Emissions unit 010 (EU010) is a fly ash transfer (Source 5) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2A and 2B to the fly ash storage silo (Source 3) at a maximum design transfer rate of 70 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,800 acfm.(Permitting note(s): These emissions units are regulated under Best Available Control Technology (BACT)Determinations ordered 2/5/79 (proposed 1/26/79) and 8/16/79.]Essential Potential to Emit (PTE) Parameters C.1. Permitted Capacity.
 
The transfer rates shall not exceed: EU No. Transfer Rate (tons per hour)006 44 008 174 009 60 010 70[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.]C.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
[Rule 62-297.310(2), F.A.C.]C.3. Hours of Operation.
Subsection C. Emissions Units 006, 008, 009, 010 The specific conditions in this section apply to the following emissions units:.
The emissions units may operate continuously, i.e., 8,760 hours/year.  
EU No.       Brief Description 006       Fly ash transfer (Source 1) from FFSG Unit 1 008       Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009       Fly ash transfer (Source 4) from FFSG Unit 2 010       Fly ash transfer (Source 5) from FFSG Unit 2 Emissions unit 006 (EU006) is a fly ash transfer (Source 1) from FFSG Unit 1. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 1 electrostatic precipitator (ESP) to the fly ash storage silo (Source 3) at a design transfer rate of 44 tons per hour.
[Rule 62-210.200(PTE), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 17 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 1,820 acfm.
Subsection C. Emissions Units 006, 008, 009, 010 C.4. Additional Reasonable Precautions for Control of PM Emissions.
Emissions unit 008 (EU008) is a fly ash storage silo (Source 3) for FFSG Units 1 and 2. This emissions unit consists of the fly ash storage silo used to store fly ash from the ESP of FFSG Units 1 and 2. Fly ash is pneumatically conveyed from the FFSG Units 1 and 2 ESPs at a combined transfer rate of 174 tons per hour. PM emissions are controlled by a Pulse King Model M 100 S baghouse at a design air flow of 2,546 acfm. Fly ash from the storage silo is disposed of either in a dry form by loading into enclosed tanker trucks or in a wet form by loading wet ash into open trucks.
The owner or operator shall take the following reasonable precautions to control emissions of PM from transport of ash from EU008 for disposal or use: a. Ash for transport shall be wetted before loading into open trucks, b. Dry ash shall be transferred to enclosed tanker trucks.[Permit No. AC09-256791]
Emissions unit 009 (EU009) is a fly ash transfer (Source 4) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2C to the fly ash storage silo (Source 3) at a design transfer rate of 60 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,200 acfm.
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions C.5. -C.6.. are based on the specified averaging time of the applicable test method.C.5. PM Emission Limitations.
Emissions unit 010 (EU010) is a fly ash transfer (Source 5) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2A and 2B to the fly ash storage silo (Source 3) at a maximum design transfer rate of 70 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,800 acfm.
Emissions of particulate matter from the following emissions units shall not exceed: EU No. Emission Limit Emission Limit (pounds per hour) (tons per year)006 3.5 15.4 008 0.6 2.6 009 2.2 9.6 010 2.2 9.6[Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79]C.6. VE. VE from each of the Units 1 and 2 flyash handling system baghouse exhaust stacks shall not exceed 5% opacity. See Specific Condition C.13. [Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79]Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
(Permittingnote(s): These emissions units are regulated under Best Available Control Technology (BACT)
C.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
Determinationsordered2/5/79 (proposed1/26/79) and 8/16/79.]
[Rule 62-210.700(1), F.A.C.]C.8. Excess Emissions Prohibited.
Essential Potential to Emit (PTE) Parameters C.1. Permitted Capacity. The transfer rates shall not exceed:
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
EU No.             Transfer Rate (tons per hour) 006                               44 008                             174 009                               60 010                               70
[Rule 62-210.700(4), F.A.C.]Test Methods and Procedures C.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources Visual Determination of Fugitive Emissions from material Sources and Smoke Emissions 2 from Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.  
[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.]
[62-297.401, F.A.C., Permit No. AC09-256791]
C.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 18 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
C.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
Subsection C. Emissions Units 006, 008, 009, 010 C.10. Testing Requirements.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                           Title V Air Operation Permit Renewal Page 17 of 54
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.[Rule 62-297.310, F.A.C.]C.11. Annual Compliance Tests Required.
 
During each federal fiscal year (October 1 sI to September 3 0 th), each EU006, EU008, EU009 and EU010 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7), F.A.C. and Permit No. AC09-256791]
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
C.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years.The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions C.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]C.13. VE in Lieu of Stack Test. Due to the expense and complexity of conducting a stack test on minor sources of PM and because the ash handling system emissions units are controlled with baghouses, the Department, pursuant to Rule 62-297.620(4), F.A.C. will consider compliance with 5% VE limitation (See Specific Condition C.6.) as reasonable assurance of compliance with the PM emission limitations in Specific Condition C.5. in lieu of particulate stack tests. If the Department has reason to believe that the particulate emission standard applicable to each emissions unit (006, 008, 009 and 010) is not being met, it may require that compliance be demonstrated by stack testing in accordance with Chapter 62-297, F.A.C. [Permit No.AC09-256791; BACT Determination dated 2/5/79]C.14. VE. Compliance for VE shall be demonstrated using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Rule 62-297, F.A.C.C.15. Specific VE Test Requirements.
Subsection C. Emissions Units 006, 008, 009, 010 C.4.     Additional Reasonable Precautions for Control of PM Emissions. The owner or operator shall take the following reasonable precautions to control emissions of PM from transport of ash from EU008 for disposal or use:
Each test shall be a minimum of thirty minutes in duration.
: a. Ash for transport shall be wetted before loading into open trucks,
Separate VE tests shall be conducted on each of the baghouse filter/separate exhausts (total of four emission points to be tested). VE testing shall be conducted while transferring fly ash from both FFSG Units 1 and 2 to the silo (EU008) at the same time. The tests shall be conducted during a period when both FFSG Units 1 and 2 are operating at 90 to 100% of full load while sootblowing.
: b. Dry ash shall be transferred to enclosed tanker trucks.
A statement of the FFSG unit loads, verifying the tests were conducted during sootblowing, shall be submitted with the test reports. [Permit No. AC09-256791]
[Permit No. AC09-256791]
[Permitting note: For those emissions points containing a baghouse, the permittee shall perform and record the results of weekly qualitative observations of VE checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormal VE.]Recordkeeping and Reporting Reqiuirements C.16. Other Reporting Requirements.
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions C.5. - C.6.. are based on the specified averaging time of the applicable test method.
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
C.5.     PM Emission Limitations. Emissions of particulate matter from the following emissions units shall not exceed:
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 19 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
EU No.                 Emission Limit                 Emission Limit (pounds per hour)               (tons per year) 006                         3.5                           15.4 008                         0.6                           2.6 009                         2.2                           9.6 010                         2.2                           9.6
Subsection D. Emissions Unit 014 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 014 Bottom Ash Storage Silo for FFSG Units 1 and 2 Emissions unit 014 (EU014) is a bottom ash storage silo for FFSG Units 1 and 2, with associated vacuum blower exhausts and bin vent filter (total of three emission points). This emissions unit consists of the system to collect and store bottom ash and economizer ash from both FFSG Units 1 and 2 at a total rate of 16 tons per hour (8 tons per hour from each FFSG unit) at an airflow rate of 2,200 standard cubic feet per minute (scfm) from each unit.Ash is conveyed by vacuum from each FFSG unit by a separate vacuum blower, with air and ash passing through a baghouse (filter/separator) where ash is deposited in the silo and air is exhausted through the vacuum blower.Air displaced in the silo is vented through an additional bag filter (the bin vent filter) at an airflow rate of 2,400 scfm. Ash stored in the silo is unloaded into trucks for sale, use or disposal at the on-site ash disposal facility.Ash will be wet via a pug mill before loading into open trucks, or dry ash will be transferred to enclosed tanker trucks.[Permitting note(s): This emissions unit is regulated under Rule 62-296.320, F.A. C., and by applicable requirements of AC09-235915.}
[Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79]
Essential Potential to Emit (PTE) Parameters D.A. Permitted Capacity.
C.6.     VE. VE from each of the Units 1 and 2 flyash handling system baghouse exhaust stacks shall not exceed 5% opacity. See Specific Condition C.13. [Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79]
The maximum rate of transfer of ash from Units 1 and 2 to the ash storage silo shall not exceed 16 tons per hour (8 tons per hour from each FFSG unit). [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C.; Permit No. AC09-235915]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
D.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
C.7.     Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
[Rule 62-297.310(2), F.A.C.]D.3. Hours of Operation.
C.8.     Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
The emissions units may operate continuously, i.e., 8,760 hours/year.  
Test Methods and Procedures C.9.     Test Methods. Required tests shall be performed in accordance with the following reference methods:
[Rule 62-210.200(PTE), F.A.C.]D.4. Additional Reasonable Precautions for Control of PM Emissions.
Method     Description of Method and Comments 9       Visual Determination of the Opacity of Emissions from Stationary Sources Visual Determination of Fugitive Emissions from material Sources and Smoke Emissions 2from Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [62-297.401, F.A.C., Permit No. AC09-256791]
The owner or operator shall take the following reasonable precautions to control emissions of particulate matter from transport of ash from EU014 for disposal or use: a. Ash for transport shall be wet via a pug mill before loading into open trucks, b. Dry ash shall be transferred to enclosed tanker trucks.[Permit No. AC09-235915]
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                       Title V Air Operation Permit Renewal Page 18 of 54
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions D.5. -D.6. are based on the specified averaging time of the applicable test method.D.5. PM Emissions.
 
The maximum allowable emission rate of PM from the bottom/economizer ash handling system for a maximum process transfer rate of 8 tons per hour per unit is 13.03 pounds per hour as set by the Process Weight Table contained within Rule 62-296.320(4), F.A.C. At lesser process rates the allowable emission rates can be determined front the appropriate equation.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
This limitation represents total combined PM emissions from the two filter/separator exhausts and the bin vent filter exhaust. [Permit No. AC09-235915]
Subsection C. Emissions Units 006, 008, 009, 010 C.10. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.
D.6. VE Limitation.
[Rule 62-297.310, F.A.C.]
Due to the expense and complexity of conducting a stack test on minor sources of PM, and because this ash handling system is equipped with baghouse control devices, the Department, pursuant to Rule 62-297.620(4), F.A.C., establishes a VE limitation not to exceed an opacity of 5% in lieu of a PM stack test. This limitation applies to emissions from the two filter/separator exhausts and to the bin vent filter exhaust. [Permit No. AC09-235915]
C.11. Annual Compliance Tests Required. During each federal fiscal year (October 1 sI to September 3 0 th), each EU006, EU008, EU009 and EU010 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7), F.A.C. and Permit No. AC09-256791]
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 20 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
C.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years.
The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions C.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.]
C.13. VE in Lieu of Stack Test. Due to the expense and complexity of conducting a stack test on minor sources of PM and because the ash handling system emissions units are controlled with baghouses, the Department, pursuant to Rule 62-297.620(4), F.A.C. will consider compliance with 5% VE limitation (See Specific Condition C.6.) as reasonable assurance of compliance with the PM emission limitations in Specific Condition C.5. in lieu of particulate stack tests. If the Department has reason to believe that the particulate emission standard applicable to each emissions unit (006, 008, 009 and 010) is not being met, it may require that compliance be demonstrated by stack testing in accordance with Chapter 62-297, F.A.C. [Permit No.
AC09-256791; BACT Determination dated 2/5/79]
C.14. VE. Compliance for VE shall be demonstrated using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Rule 62-297, F.A.C.
C.15. Specific VE Test Requirements. Each test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each of the baghouse filter/separate exhausts (total of four emission points to be tested). VE testing shall be conducted while transferring fly ash from both FFSG Units 1 and 2 to the silo (EU008) at the same time. The tests shall be conducted during a period when both FFSG Units 1 and 2 are operating at 90 to 100% of full load while sootblowing. A statement of the FFSG unit loads, verifying the tests were conducted during sootblowing, shall be submitted with the test reports. [Permit No. AC09-256791]
[Permitting note: Forthose emissions points containing a baghouse, the permittee shall perform and record the results of weekly qualitative observations of VE checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormal VE.]
Recordkeeping and Reporting Reqiuirements C.16. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 19 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection D. Emissions Unit 014 The specific conditions in this section apply to the following emissions unit:
EU No. Brief Description 014       Bottom Ash Storage Silo for FFSG Units 1 and 2 Emissions unit 014 (EU014) is a bottom ash storage silo for FFSG Units 1 and 2, with associated vacuum blower exhausts and bin vent filter (total of three emission points). This emissions unit consists of the system to collect and store bottom ash and economizer ash from both FFSG Units 1 and 2 at a total rate of 16 tons per hour (8 tons per hour from each FFSG unit) at an airflow rate of 2,200 standard cubic feet per minute (scfm) from each unit.
Ash is conveyed by vacuum from each FFSG unit by a separate vacuum blower, with air and ash passing through a baghouse (filter/separator) where ash is deposited in the silo and air is exhausted through the vacuum blower.
Air displaced in the silo is vented through an additional bag filter (the bin vent filter) at an airflow rate of 2,400 scfm. Ash stored in the silo is unloaded into trucks for sale, use or disposal at the on-site ash disposal facility.
Ash will be wet via a pug mill before loading into open trucks, or dry ash will be transferred to enclosed tanker trucks.
[Permittingnote(s): This emissions unit is regulatedunder Rule 62-296.320, F.A. C., and by applicable requirements of AC09-235915.}
Essential Potential to Emit (PTE) Parameters D.A.     Permitted Capacity. The maximum rate of transfer of ash from Units 1 and 2 to the ash storage silo shall not exceed 16 tons per hour (8 tons per hour from each FFSG unit). [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C.; Permit No. AC09-235915]
D.2.     Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
D.3.     Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
D.4.     Additional Reasonable Precautions for Control of PM Emissions. The owner or operator shall take the following reasonable precautions to control emissions of particulate matter from transport of ash from EU014 for disposal or use:
: a. Ash for transport shall be wet via a pug mill before loading into open trucks,
: b. Dry ash shall be transferred to enclosed tanker trucks.
[Permit No. AC09-235915]
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions D.5. - D.6. are based on the specified averaging time of the applicable test method.
D.5.     PM Emissions. The maximum allowable emission rate of PM from the bottom/economizer ash handling system for a maximum process transfer rate of 8 tons per hour per unit is 13.03 pounds per hour as set by the Process Weight Table contained within Rule 62-296.320(4), F.A.C. At lesser process rates the allowable emission rates can be determined front the appropriate equation. This limitation represents total combined PM emissions from the two filter/separator exhausts and the bin vent filter exhaust. [Permit No. AC09-235915]
D.6.     VE Limitation. Due to the expense and complexity of conducting a stack test on minor sources of PM, and because this ash handling system is equipped with baghouse control devices, the Department, pursuant to Rule 62-297.620(4), F.A.C., establishes a VE limitation not to exceed an opacity of 5% in lieu of a PM stack test. This limitation applies to emissions from the two filter/separator exhausts and to the bin vent filter exhaust. [Permit No. AC09-235915]
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 20 of 54
 
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection D. Emissions Unit 014 Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Subsection D. Emissions Unit 014 Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
D.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
D.7.     Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
[Rule 62-210.700(1), F.A.C.]D.8. Excess Emissions Prohibited.
D.8.     Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
Test Methods and Procedures D.9.     Test Methods. Required tests shall be performed in accordance with the following reference methods:
[Rule 62-210.700(4), F.A.C.]Test Methods and Procedures D.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.  
Method       Description of Method and Comments 9       Visual Determination of the Opacity of Emissions from Stationary Sources The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C.; Permit No. AC09-235915]
[Rule 62-297.401, F.A.C.; Permit No. AC09-235915]
D.10. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]
D.10. Common Testing Requirements.
DA.L Annual Compliance Tests Required. During each federal fiscal year (October 1s to September 3 0 th),
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]DA.L Annual Compliance Tests Required.
EU014 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7),
During each federal fiscal year (October 1s to September 3 0 th), EU014 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7), F.A.C.; Permit No. AC09-235915]
F.A.C.; Permit No. AC09-235915]
D.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years.The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions D.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.; Permit No.AC09-235915]
D.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years.
The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions D.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.; Permit No.
AC09-235915]
D.13. VE. Each emission point of EU014 shall demonstrate compliance using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C., and referenced in Chapter 62-297, F.A.C. The minimum requirements for stationary point source emission test procedures shall be in accordance with Rule 62-297, F.A.C. and 40 CFR 60 Appendix A. [Permit No. AC09-235915]
D.13. VE. Each emission point of EU014 shall demonstrate compliance using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C., and referenced in Chapter 62-297, F.A.C. The minimum requirements for stationary point source emission test procedures shall be in accordance with Rule 62-297, F.A.C. and 40 CFR 60 Appendix A. [Permit No. AC09-235915]
D.14. Specific VE Test Requirements.
D.14. Specific VE Test Requirements. The visible emissions test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statement of the approximate ash transfer rate during the test shall be submitted with each test report. Failure to submit the process transfer rate and or operation under conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance. [Permit No. AC09-235915]
The visible emissions test shall be a minimum of thirty minutes in duration.
Recordkeepin2 and Reporting Requirements D.15. Reporting Ash Transfer Rate. A statement of the approximate ash transfer rate during the test shall be submitted with each compliance test report. Failure to submit the process transfer rate and or operation under Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 21 of 54
Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statement of the approximate ash transfer rate during the test shall be submitted with each test report. Failure to submit the process transfer rate and or operation under conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance.  
 
[Permit No. AC09-235915]
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Recordkeepin2 and Reporting Requirements D.15. Reporting Ash Transfer Rate. A statement of the approximate ash transfer rate during the test shall be submitted with each compliance test report. Failure to submit the process transfer rate and or operation under Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 21 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection D. Emissions Unit 014 conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance. [Permit No. AC09-235915]
Subsection D. Emissions Unit 014 conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance.  
D.16. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
[Permit No. AC09-235915]
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                      Title V Air Operation Permit Renewal Page 22 of 54
D.16. Other Reporting Requirements.
 
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 22 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection E. Emissions Unit 012 The specific conditions in this section apply to the following emissions unit:
Subsection E. Emissions Unit 012 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 012 Three relocatable diesel generator(s)
EU No. Brief Description 012     Three relocatable diesel generator(s)
Emissions unit 012 (EU012) consists of three relocatable Caterpillar Model 3508-DITA 820 kilowatt (kW) diesel generators.
Emissions unit 012 (EU012) consists of three relocatable Caterpillar Model 3508-DITA 820 kilowatt (kW) diesel generators. Each relocatable diesel generator has a maximum heat input of 8.58 MMBtu/hr. Each generator is fueled by new No. 2 fuel oil per hour with a maximum rating of 820 kilowatts. Each generator has its own stack.
Each relocatable diesel generator has a maximum heat input of 8.58 MMBtu/hr.
Emissions from the generators are uncontrolled, and therefore, are not subject to CAM.
Each generator is fueled by new No. 2 fuel oil per hour with a maximum rating of 820 kilowatts.
(Permittingnotes: These emissions units are regulated under Rule 62-210.300, F.A.C., PermitsRequired. This section of the permit is only applicablewhen the generatorsare located at the Crystal River Power Plant. These relocatablegeneratorswere permitted in 1991 under permit No. AC09-202080.]
Each generator has its own stack.Emissions from the generators are uncontrolled, and therefore, are not subject to CAM.(Permitting notes: These emissions units are regulated under Rule 62-210.300, F.A.C., Permits Required.
Essential Potential to Emit (PTE) Parameters E.1. Permitted Capacity. The maximum (combined) allowable heat input rate and fuel firing rate is as follows:
This section of the permit is only applicable when the generators are located at the Crystal River Power Plant. These relocatable generators were permitted in 1991 under permit No. AC09-202080.]
EU No.           MMHetuIhr        Gallons/hour     Fuel Type Heat Input 012             8.58 (each           62.1       New No. 2 Fuel Oil generator)
Essential Potential to Emit (PTE) Parameters E.1. Permitted Capacity.
The maximum (combined) allowable heat input rate and fuel firing rate is as follows: EU No. MMHe tuIhr Gallons/hour Fuel Type Heat Input 012 8.58 (each 62.1 New No. 2 Fuel Oil generator)
[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.; and, Permit No. AC09-202080.]
[Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.; and, Permit No. AC09-202080.]
E.2. Methods of Operation  
E.2. Methods of Operation - Fuels. Only new No. 2 fuel oil with a maximum sulfur content of 0.5%, by weight, shall be burned in this unit. [Permit No. AC09-202080]
-Fuels. Only new No. 2 fuel oil with a maximum sulfur content of 0.5%, by weight, shall be burned in this unit. [Permit No. AC09-202080]
E.3. Hours of Operation. The hours of operation expressed as "engine-hours" shall not exceed 2,970 hours in any consecutive 12 month period. The total hours of operation expressed as "engine-hours" shall be the summation of the individual hours of operation of each generator. [Rules 62-4.160(2) and 62-210.200(PTE),
E.3. Hours of Operation.
F.A.C.; Permit No. AC09-202080.]
The hours of operation expressed as "engine-hours" shall not exceed 2,970 hours in any consecutive 12 month period. The total hours of operation expressed as "engine-hours" shall be the summation of the individual hours of operation of each generator.  
E.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
[Rules 62-4.160(2) and 62-210.200(PTE), F.A.C.; Permit No. AC09-202080.]
Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition E.5. is based on the specified averaging time of the applicable test method.
E.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
E.5. VE. VE shall not be equal to or greater than 20 percent opacity. [Rule 62-296.320(4)(b)1, F.A.C.; Permit No. AC09-202080]
[Rule 62-297.310(2), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition E.5. is based on the specified averaging time of the applicable test method.E.5. VE. VE shall not be equal to or greater than 20 percent opacity. [Rule 62-296.320(4)(b)1, F.A.C.; Permit No. AC09-202080]
E.6. S02 - Sulfur Content. The new No. 2 fuel oil sulfur content shall not exceed 0.5%, by weight. [Permit No. AC09-202080]
E.6. S02 -Sulfur Content. The new No. 2 fuel oil sulfur content shall not exceed 0.5%, by weight. [Permit No. AC09-202080]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
E.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
E.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
[Rule 62-210.700(1), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 23 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                       Title V Air Operation Permit Renewal Page 23 of 54
Subsection E. Emissions Unit 012 E.8. Excess Emissions Prohibited.
 
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
[Rule 62-210.700(4), F.A.C.]Test Methods and Procedures E.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources ASTM D1552-90 or later Standard Test Methods for Sulfur in Petroleum Products editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.  
Subsection E. Emissions Unit 012 E.8. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
[Rules 62-204.800, 62-297.401 and 62-297.440, F.A.C.]E.10. Common Testing Requirements.
Test Methods and Procedures E.9. Test Methods. Required tests shall be performed in accordance with the following reference methods:
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]E.11. Annual Compliance Tests. During each federal fiscal year (October 1st to September 3 0 th), EU012 shall be tested to demonstrate compliance with the emissions standards for VE. Annual emissions compliance testing for visible emissions is not required for these emissions units while burning liquid fuels for less than 400 hours per year. [Rules 62-297.310(7), and 62-297.310(7)(a)4.  
Method             Description of Method and Comments 9               Visual Determination of the Opacity of Emissions from Stationary Sources ASTM D1552-90 or later Standard Test Methods for Sulfur in Petroleum Products editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rules 62-204.800, 62-297.401 and 62-297.440, F.A.C.]
& 8., F.A.C.]E.12. Compliance Tests Prior to Renewal. Except as provided for in condition TR7. of Appendix TR, Testing Requirements, EU012 shall be tested for the following pollutant prior to obtaining a renewed operation permit: VE. [Rule 62-297.310(7)(a)3., F.A.C.]E.13. VE. The test method for VE shall be EPA Method 9, incorporated and adopted by reference in Rule 62-204.800. F.A.C., and referenced in Chapter 62-297, F.A.C. [Rule 62-297.310(4), F.A.C.; Permit No. AC09-202080]E.14. SO -Sulfur Content Testing. The fuel sulfur content, percent by weight, for liquid fuels shall be evaluated using either ASTM D1552-90 or later editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions.
E.10. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]
In addition, any ASTM method (or later editions) referenced in Rule 62-297-440(1)
E.11. Annual Compliance Tests. During each federal fiscal year (October 1st to September 3 0 th), EU012 shall be tested to demonstrate compliance with the emissions standards for VE. Annual emissions compliance testing for visible emissions is not required for these emissions units while burning liquid fuels for less than 400 hours per year. [Rules 62-297.310(7), and 62-297.310(7)(a)4. & 8., F.A.C.]
F.A.C., or in 40 CFR 60.335 (b)(10) is acceptable, [Rules 62-213.440 and 62-297.440, F.A.C.]E.15. Fuel Sulfur Analysis.
E.12. Compliance Tests Prior to Renewal. Except as provided for in condition TR7. of Appendix TR, Testing Requirements, EU012 shall be tested for the following pollutant prior to obtaining a renewed operation permit:
The permittee shall demonstrate compliance with the liquid fuel sulfur limit by means of a fuel analysis provided by the vendor or permittee upon each fuel delivery.  
VE. [Rule 62-297.310(7)(a)3., F.A.C.]
[Rule 62-213.440, F.A.C.]E.16. Testing after Relocation.
E.13. VE. The test method for VE shall be EPA Method 9, incorporated and adopted by reference in Rule 62-204.800. F.A.C., and referenced in Chapter 62-297, F.A.C. [Rule 62-297.310(4), F.A.C.; Permit No. AC09-202080]
After each relocation, each generator shall be tested within 30 days of startup for opacity and the fuel shall be analyzed for the sulfur content to demonstrate compliance with the permit limits in this section. [Rules 62-4.070(3) and 62-297.310(7)(b),F.A.C.;
E.14. SO - Sulfur Content Testing. The fuel sulfur content, percent by weight, for liquid fuels shall be evaluated using either ASTM D1552-90 or later editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions. In addition, any ASTM method (or later editions) referenced in Rule 62-297-440(1) F.A.C., or in 40 CFR 60.335 (b)(10) is acceptable, [Rules 62-213.440 and 62-297.440, F.A.C.]
Permit No. AC09-202080]
E.15. Fuel Sulfur Analysis. The permittee shall demonstrate compliance with the liquid fuel sulfur limit by means of a fuel analysis provided by the vendor or permittee upon each fuel delivery. [Rule 62-213.440, F.A.C.]
E.16. Testing after Relocation. After each relocation, each generator shall be tested within 30 days of startup for opacity and the fuel shall be analyzed for the sulfur content to demonstrate compliance with the permit limits in this section. [Rules 62-4.070(3) and 62-297.310(7)(b),F.A.C.; Permit No. AC09-202080]
E.17. Testing Operating Rate. Testing of each diesel generator emissions must be accomplished while operating the diesel generator within + 10% of the maximum fuel firing rate of 62.1 gallons per hour. Failure to submit the actual operating rate may invalidate the test. [Permit No. AC09-202080]
E.17. Testing Operating Rate. Testing of each diesel generator emissions must be accomplished while operating the diesel generator within + 10% of the maximum fuel firing rate of 62.1 gallons per hour. Failure to submit the actual operating rate may invalidate the test. [Permit No. AC09-202080]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 24 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 24 of 54
Subsection E. Emissions Unit 012 Recordkeeping and Reporting Requirements E.18. Recordkeeping.
 
The owner or operator shall maintain the following records: a. the daily hours of operation for each of the generators, b. the daily hours of operation expressed as "engine- hours", c. the cumulative total hours of operation expressed as "engine-hours" for each month, and d. the sulfur content, in percent by weight, of all the fuel burned shall be kept based on either vendor provided as-delivered or as-received fuel sample analysis.[Rules 62-213.440 and 62-297.310(8), F.A.C.; Permit No. AC09-202080]
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
E.19. Relocation Notification.
Subsection E. Emissions Unit 012 Recordkeeping and Reporting Requirements E.18. Recordkeeping. The owner or operator shall maintain the following records:
The permittee shall notify the compliance authority, in writing, at least 15 days prior to the date on which any diesel generator is to be relocated.
: a. the daily hours of operation for each of the generators,
The notification shall specify the following;
: b. the daily hours of operation expressed as "engine- hours",
: a. which generator, by serial number, is being relocated, b. which location the generator is being relocated from and which location it is being relocated to, and c. the approximate startup date at the new location.[Permit No. AC09-202080]
: c. the cumulative total hours of operation expressed as "engine-hours" for each month, and
E.20. Other Reporting Requirements.
: d. the sulfur content, in percent by weight, of all the fuel burned shall be kept based on either vendor provided as-delivered or as-received fuel sample analysis.
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
[Rules 62-213.440 and 62-297.310(8), F.A.C.; Permit No. AC09-202080]
Other Requirements E.21. PSD Avoidance.
E.19. Relocation Notification. The permittee shall notify the compliance authority, in writing, at least 15 days prior to the date on which any diesel generator is to be relocated. The notification shall specify the following;
Specific conditions in construction permit AC09-202080, limiting the "engine hours", were accepted by the applicant to escape Prevention of Significant Deterioration review. If Progress Energy Florida, Inc. requests a relaxation of any of the federally enforceable emission limits in this permit, the relaxation of limits may be subject to the preconstruction review requirements of Rule 62-212.400(4)  
: a. which generator, by serial number, is being relocated,
-(12), F.A.C., as though construction had not yet begun. [Rule 62-212.400(12), F.A.C.; Permit No. AC09-202080].
: b. which location the generator is being relocated from and which location it is being relocated to, and
Progress Energy Florida, Inc.Crystal River Power Plant Page 25 of 54 Permit No. 0170004-024-AV Title V Air Operation Permit Renewal SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: c. the approximate startup date at the new location.
Subsection F. Emissions Unit 013 The specific conditions in this section apply to the following emissions unit: EU No.1 Brief Description 013 Cooling Towers for FFSG Units 1, 2 and Nuclear Unit 3 Emissions unit 013 (EU013) is cooling towers for FFSG units 1, 2 and nuclear unit 3, used to reduce plant discharge water temperature. (This emissions unit may be referred to as "helper cooling towers.")
[Permit No. AC09-202080]
This emissions unit consists of four towers with nine cells per tower, with high efficiency (99.8%) drift eliminators, operating at a maximum seawater flow rate of 735,000 gallons per minute for all nine cells combined, with a design airflow rate of 1.46 x 106 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by high efficiency drift eliminators.
E.20. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
[Permitting note(s): This emissions unit is regulated under Prevention of Significant Deterioration (PSD) (PSD permit ACO9-162037/PSD-FL-139 issued 8/29/90) and Best Available Control Technology (BACT), Determination dated 8/29/90, which set a drift emission rate of 0.004%.)Essential Potential to Emit (PTE) Parameters F.1. Hours of Operation.
Other Requirements E.21. PSD Avoidance. Specific conditions in construction permit AC09-202080, limiting the "engine hours",
The operating hours for each cooling tower pump shall not exceed 4,320 hours per year (12-month rolling total). [Rule 62-210.200(PTE), F.A.C.; and, Permit No. AC09-162037/PSD-FL-139]
were accepted by the applicant to escape Prevention of Significant Deterioration review. If Progress Energy Florida, Inc. requests a relaxation of any of the federally enforceable emission limits in this permit, the relaxation of limits may be subject to the preconstruction review requirements of Rule 62-212.400(4) - (12),
F.2. Drift Eliminators.
F.A.C., as though construction had not yet begun. [Rule 62-212.400(12), F.A.C.; Permit No. AC09-202080].
Drift eliminators shall be installed and maintained so that minimum bypass occurs.Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators.  
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 25 of 54
[Rule 62-213.440, F.A.C.; and, Permit No. AC09-162037/PSD-FL-139)]
 
[Permitting Note: This emissions unit is not subject to a visible emissions limitation.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Emissions from this emissions unit include water droplets so visible emissions testing is not possible.]
Subsection F. Emissions Unit 013 The specific conditions in this section apply to the following emissions unit:
F.3. Pump Run Time Meters Required.
EU No.1 Brief Description 013       Cooling Towers for FFSG Units 1, 2 and Nuclear Unit 3 Emissions unit 013 (EU013) is cooling towers for FFSG units 1, 2 and nuclear unit 3, used to reduce plant discharge water temperature. (This emissions unit may be referred to as "helper cooling towers.") This emissions unit consists of four towers with nine cells per tower, with high efficiency (99.8%) drift eliminators, operating at a maximum seawater flow rate of 735,000 gallons per minute for all nine cells combined, with a design airflow rate of 1.46 x 106 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by high efficiency drift eliminators.
Each cooling tower seawater pump shall be equipped each with a run-hour meters. [Rule 62-213.440, F.A.C.; and, AC09-162037/PSD-FL-139]
[Permittingnote(s): This emissions unit is regulated under Prevention of Significant Deterioration(PSD)(PSD permit ACO9-162037/PSD-FL-139 issued 8/29/90) and Best Available Control Technology (BACT),
F.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
Determinationdated 8/29/90, which set a drift emission rate of 0.004%.)
[Rule 62-297.310(2), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Conditions F.5. is based on the specified averaging time of the applicable test method.F.5. Cooling Tower Emission Limit. The maximum allowable emissions of particulate matter form each cell (stack) is 11.89 lb/hr. This is based on a 0.004% drift rate (ratio of drift to the circulate rate) and the following table: Total PM (from all 36 cells) PM 1 0 Flow Rate (gpm)lbs/hr TPY lbs/hr TPY 735,000 428 925 214 462 (PM 1 0 is approximately 50% of total PM)[Permit No. AC09-162037/PSD-FL-139, BACT]Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Essential Potential to Emit (PTE) Parameters F.1.     Hours of Operation. The operating hours for each cooling tower pump shall not exceed 4,320 hours per year (12-month rolling total). [Rule 62-210.200(PTE), F.A.C.; and, Permit No. AC09-162037/PSD-FL-139]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 26 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
F.2.     Drift Eliminators. Drift eliminators shall be installed and maintained so that minimum bypass occurs.
Subsection F. Emissions Unit 013 F.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.
Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators. [Rule 62-213.440, F.A.C.; and, Permit No. AC09-162037/PSD-FL-139)]
[Rule 62-210.700(1), F.A.C.]F.7. Excess Emissions Prohibited.
[PermittingNote: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets so visible emissions testing is not possible.]
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.
F.3.     Pump Run Time Meters Required. Each cooling tower seawater pump shall be equipped each with a run-hour meters. [Rule 62-213.440, F.A.C.; and, AC09-162037/PSD-FL-139]
[Rule 62-210.700(4), F.A.C.]Test Methods and Procedures F.8. Testing Requirements.
F.4.     Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.[Rule 62-297.3 10, F.A.C.]F.9. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators.
Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Conditions F.5. is based on the specified averaging time of the applicable test method.
During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate): a. Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).b. Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.c. Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
F.5.     Cooling Tower Emission Limit. The maximum allowable emissions of particulate matter form each cell (stack) is 11.89 lb/hr. This is based on a 0.004% drift rate (ratio of drift to the circulate rate) and the following table:
[Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139);
Flow Rate (gpm)              Total PM (from all 36 cells)                                 PM 10 lbs/hr                 TPY                     lbs/hr                   TPY 735,000                         428                   925                       214                     462 (PM 10 is approximately 50% of total PM)
and, ASP No. 00-E-01 dated June 7, 2000]Recordkeeping and Reporting Requirements F.10. Pump Run Logs. A log shall be maintained of the hours of operation of each pump supplying salt water to the helper cooling towers. Pump flow rates shall be determined from the manufacturer's certified pump curves, or any other equivalent method approved by the Department.
[Permit No. AC09-162037/PSD-FL-139, BACT]
[Rule 62-213.440, F.A.C.; Permit No.AC09-162037/PSD-FL-139]F.11. Other Reporting Requirements.
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 27 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection G. Emissions Unit 015 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 015 Cooling Towers for FFSG Units 4 and 5 Emissions unit 015 (EU015) is cooling towers for FFSG Units 4 and 5 used to reduce plant discharge water temperature. (These towers are hyperbolic cooling towers.) Seawater is sprayed through the towers where induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted.Drift emissions controlled by high efficiency drift eliminators.
Seawater flow rate is 331,000 gallons per minute.[Permitting note(s): This emissions unit is regulated under Prevention of Significant Deterioration (PSD) (PSD permit PSD-FL-007 issued by EPA as modified by EPA on 11/30/88.))
Essential Potential to Emit (PTE) Parameters G.1. Permitted Capacity.
The maximum seawater flow rate shall not exceed 331,000 gallons per minute per cooling tower. [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C., 62-204.800, F.A.C.]G.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.
[Rule 62-297.310(2), F.A.C.]G.3. Hours of Operation.
The emissions units may operate continuously, i.e., 8,760 hours/year.
[Rule 62-210.200(PTE), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition(s)
G.4. is based on the specified averaging time of the applicable test method.G.4. PM Emissions
-Cooling Tower Emission Limit. PM emissions shall not exceed 175 lb/hr from each cooling tower. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88][Permitting Note: The emission limit is based on a BACT Determination requiring control of drift emissions with drift eliminators.
The modified PSD permit removed a limitation on drift rate, substituting an emissions limit in pounds per hour. PM emissions are assumed to be all PM 1 0.][Permitting Note: This emissions unit is not subject to a visible emissions limitation.
Emissions from this emissions unit include water droplets so visible emissions testing is not possible.]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
G.5. Excess Emissions.
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                            Title V Air Operation Permit Renewal Page 26 of 54
Should either tower emission rate exceed 175 lb/hr, the permittee shall: a. Notify EPA and the Department within 10 days of becoming aware of the exceedance.
 
: b. Provide an assessment of necessary corrective actions and a proposed schedule of implementation within an additional 20 days.c. Expeditiously complete corrective actions.d. Retest the tower within three months after the correction is completed.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: e. Submit the testing report within 45 days after completion of said tests.[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]G.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
Subsection F. Emissions Unit 013 F.6.     Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
[Rule 62-210.700(1), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 28 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
F.7.     Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
Subsection G. Emissions Unit 015 G.7. Excess Emissions Prohibited.
Test Methods and Procedures F.8.     Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
[Rule 62-297.3 10, F.A.C.]
[Rule 62-210.700(4), F.A.C.]Monitoring of Operations G.8. Inspection.
F.9.     Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate):
The drift eliminators of both towers shall be inspected from the concrete walkways not less than every three months by Progress Energy Florida staff or representatives to assure that the drift eliminators are clean and in good working order. Not less than annually, a complete inspection of the towers shall be conducted by a qualified inspector with recognized expertise in the field. Certification that the drift eliminators are properly installed and in good working order shall be provided in the record keeping and reporting requirements noted below. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88].
: a. Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).
Test Methods and Procedures G.9. Testing Requirements.
: b. Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.[Rule 62-297.310, F.A.C.]G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012). [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]G.11. PM Emission Test Method. Testing shall be in accordance with following requirements:
: c. Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
: a. PM emissions shall be measured by the sensitive paper method.b. Testing shall be conducted either at the drift eliminator level within the tower or at the tower exit plane.(The sampling locations at the drift eliminator level and apparatus are shown in diagrams attached as Appendix P.)c. No less than three test runs shall be conducted for each test and all valid data from each of these test runs shall be averaged to demonstrate compliance.
[Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7, 2000]
No individual test run result shall determine compliance or noncompliance.
Recordkeeping and Reporting Requirements F.10. Pump Run Logs. A log shall be maintained of the hours of operation of each pump supplying salt water to the helper cooling towers. Pump flow rates shall be determined from the manufacturer's certified pump curves, or any other equivalent method approved by the Department. [Rule 62-213.440, F.A.C.; Permit No.
The emission rate reported as a percent of the circulating water, as well as lb/hr., and total dissolved solids in the cooling tower basin and intake water, shall be reported for each test run.[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]Recordkeepin2 and Reporting Requirements G.12. Reporting.
AC09-162037/PSD-FL- 139]
Reports on tower testing and inspection shall be handled as follows: a. Maintained within onsite files within 30 days after all visual inspections of the drift eliminators.
F.11. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
: b. Agency Submittal within 45 days after the compliance testing of either tower.[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]G.13. Other Reporting Requirements.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 27 of 54
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
 
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 29 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection H. Emissions Unit 016 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 016 Material handling activities for coal-fired steam units.Emissions unit 016 (EU016) is material handling activities for coal-fired steam units. This emissions unit consists of a crane-operated clam-shell bucket mounted on a traveling gantry, enclosed conveyor belts, coal crushers and storage bunkers used for the storage and transport of coal, for FFSG Units 1, 2, 4 and 5. The barge unloading capabilities are 2,500 tons per hour and 32,000 tons per day. The speed of the conveyors and the crusher associated with boilers 1 and 2 is 900 tons per hour. This unit also encompasses fly ash and bottom ash handling equipment associated with Units 4 and 5 which are not addressed by other emissions units.(Permitting notes: This emissions unit is regulated partially under Power Plant Siting Certification PA 77-09 (Units 4 and 5 only) and, is subject to NSPS 40 CFR 60 Subpart Y. This emissions unit is also regulated under permit number 0170004-014-AC (issued concurrently with this revised permit number 0170004-015-AV), which authorized the replacement of the barge unloading equipment to decrease the time required to unload coal barges, and the increase in conveying and crushing speeds of the equipment feeding coal to units I and 2.]Essential Potential to Emit (PTE) Parameters H.1. Containment of Fugitive Emissions.
Subsection G. Emissions Unit 015 The specific conditions in this section apply to the following emissions unit:
To the extent possible, the equipment that comprises the coal processing equipment at this facility (crushers, conveyors, drop points, and storage bunkers) shall be covered or enclosed at all times when the equipment is in operation.
EU No.     Brief Description 015        Cooling Towers for FFSG Units 4 and 5 Emissions unit 015 (EU015) is cooling towers for FFSG Units 4 and 5 used to reduce plant discharge water temperature. (These towers are hyperbolic cooling towers.) Seawater is sprayed through the towers where induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted.
Except for the barge load-out and the stacker re-claimer sections of the conveying system that are required by design to be open, and which are not specifically subject to regulation under 40 CFR 60 Subpart Y, any other open section of the coal processing equipment shall be required to have any annual emission test conducted upon it. [Permit No. 0170004-014-AC]H.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
Drift emissions controlled by high efficiency drift eliminators. Seawater flow rate is 331,000 gallons per minute.
[Rule 62-297.310(2), F.A.C.]H.3. Hours of Operation.
[Permittingnote(s): This emissions unit is regulatedunder Prevention of Significant Deterioration(PSD) (PSD permit PSD-FL-007 issued by EPA as modified by EPA on 11/30/88.))
The emissions units may operate continuously, i.e., 8,760 hours/year.  
Essential Potential to Emit (PTE) Parameters G.1. Permitted Capacity. The maximum seawater flow rate shall not exceed 331,000 gallons per minute per cooling tower. [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C., 62-204.800, F.A.C.]
[Rule 62-210.200(PTE), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition H.4 is based on the specified averaging time of the applicable test method.H.4. VE. The owner or operator shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater, six minute average. [PPSC PA 77-09 (coal facilities associated with Units 1, 2, 4 and 5); and, Permit No. 0170004-014-AC]
G.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
G.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition(s) G.4. is based on the specified averaging time of the applicable test method.
G.4. PM Emissions - Cooling Tower Emission Limit. PM emissions shall not exceed 175 lb/hr from each cooling tower. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
[PermittingNote: The emission limit is based on a BACT Determinationrequiring control of drift emissions with drift eliminators. The modified PSD permit removed a limitation on drift rate, substituting an emissions limit in pounds per hour. PM emissions are assumed to be all PM1 0.]
[PermittingNote: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets so visible emissions testing is not possible.]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
H.5. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
G.5. Excess Emissions. Should either tower emission rate exceed 175 lb/hr, the permittee shall:
[Rule 62-210.700(1), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 30 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
: a. Notify EPA and the Department within 10 days of becoming aware of the exceedance.
Subsection H. Emissions Unit 016 H.6. Excess Emissions Prohibited.
: b. Provide an assessment of necessary corrective actions and a proposed schedule of implementation within an additional 20 days.
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.
: c. Expeditiously complete corrective actions.
[Rule 62-210.700(4), F.A.C.]Test Methods and Procedures H.7. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources 22 Visual Determination of Fugitive Emissions from Material Sources and Smoke Emissions form Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department.
: d. Retest the tower within three months after the correction is completed.
[Rule 62-297.401, F.A.C., Permit No. 0170004-014-AC]
: e. Submit the testing report within 45 days after completion of said tests.
H.8. Testing Requirements.
[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.[Rule 62-297.310, F.A.C.]H.9. VE. (This condition applies to coal facilities associated with emissions units 001, 002, 004 and 003 --FFSG Units 1, 2, 4 and 5.) When required by the Department, or annually as specified in Specific Condition H.1., EPA Method 9 and the procedures in 40 CFR 60.11 shall be used to determine opacity. [40 CFR 60.254; and, Permit No. 0170004-014-AC](Permitting Note: Except as specified in Specific Condition H.9., annual testing is not being required because the regulated emissions points are either enclosed or confined within a building.](Permitting note: For those emissions points containing a baghouse (ash silos), the permittee shall perform and record the results of weekly qualitative observations of visible emissions checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormal visible emissions.]
G.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
Recordkeeping and Reporting Requirements H.10. Other Reporting Requirements.
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                         Title V Air Operation Permit Renewal Page 28 of 54
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 31 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection I. Emission Unit 020 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 020 Cooling towers for FFSG Units 1 and 2 used to reduce plant discharge water temperature.
Emissions unit 020 (EU020) is cooling towers for FFSG Units 1 and 2, used to reduce plant discharge water temperature. (This emission unit may be referred to as "portable cooling towers.")
This emissions unit consists of 71 or 72 cells (dependent upon manufacturer), is 12' wide and 11' high, includes drift eliminators, operates at a maximum circulating seawater flow rate of 180,000 gallons per minute for all cells combined, and a design airflow rate of 25,000 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by drift eliminators.(Permitting note(s): This emissions unit is regulated under Prevention of Significant Deterioration (PSD) (permit 0170004-010-AC) and includes a Best Available Control Technology (BACT) Determination, which allows for a drift emission rate of 0.0015% with limited usage.]Essential Potential to Emit (PTE) Parameters


===1.1. Hours===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
of Operation.
Subsection G. Emissions Unit 015 G.7. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
The operating hours for the portable cooling towers shall not exceed an equivalent of 2,920 hours per year of operation (12-month rolling total). This condition shall be complied with by limiting the circulating water flow usage through the portable cooling towers to 31.5 x 109 gallons per calendar year.[Rule 62-210.200(PTE), F.A.C.; Permit No. 0170004-010-AC)]
Monitoring of Operations G.8. Inspection. The drift eliminators of both towers shall be inspected from the concrete walkways not less than every three months by Progress Energy Florida staff or representatives to assure that the drift eliminators are clean and in good working order. Not less than annually, a complete inspection of the towers shall be conducted by a qualified inspector with recognized expertise in the field. Certification that the drift eliminators are properly installed and in good working order shall be provided in the record keeping and reporting requirements noted below. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88].
Test Methods and Procedures G.9. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.
[Rule 62-297.310, F.A.C.]
G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012). [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
G.11. PM Emission Test Method. Testing shall be in accordance with following requirements:
: a. PM emissions shall be measured by the sensitive paper method.
: b. Testing shall be conducted either at the drift eliminator level within the tower or at the tower exit plane.
(The sampling locations at the drift eliminator level and apparatus are shown in diagrams attached as Appendix P.)
: c. No less than three test runs shall be conducted for each test and all valid data from each of these test runs shall be averaged to demonstrate compliance. No individual test run result shall determine compliance or noncompliance. The emission rate reported as a percent of the circulating water, as well as lb/hr., and total dissolved solids in the cooling tower basin and intake water, shall be reported for each test run.
[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
Recordkeepin2 and Reporting Requirements G.12. Reporting. Reports on tower testing and inspection shall be handled as follows:
: a. Maintained within onsite files within 30 days after all visual inspections of the drift eliminators.
: b. Agency Submittal within 45 days after the compliance testing of either tower.
[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]
G.13. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc.                                                              Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 29 of 54


===1.2. Drift===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Eliminators.
Subsection H. Emissions Unit 016 The specific conditions in this section apply to the following emissions unit:
Drift eliminators shall be installed and maintained as per the manufacturer's specifications.
EU No. Brief Description 016        Material handling activities for coal-fired steam units.
Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators.
Emissions unit 016 (EU016) is material handling activities for coal-fired steam units. This emissions unit consists of a crane-operated clam-shell bucket mounted on a traveling gantry, enclosed conveyor belts, coal crushers and storage bunkers used for the storage and transport of coal, for FFSG Units 1, 2, 4 and 5. The barge unloading capabilities are 2,500 tons per hour and 32,000 tons per day. The speed of the conveyors and the crusher associated with boilers 1 and 2 is 900 tons per hour. This unit also encompasses fly ash and bottom ash handling equipment associated with Units 4 and 5 which are not addressed by other emissions units.
[Rule 62-213.440, F.A.C.; Permit No. 0170004-010-AC)](Permitting Note: This emissions unit is not subject to a visible emissions limitation.
(Permittingnotes: This emissions unit is regulatedpartially under Power Plant Siting CertificationPA 77-09 (Units 4 and 5 only) and, is subject to NSPS 40 CFR 60 Subpart Y. This emissions unit is also regulated under permit number 0170004-014-AC (issued concurrently with this revised permit number 0170004-015-AV), which authorized the replacementof the barge unloading equipment to decrease the time requiredto unload coal barges, and the increase in conveying and crushing speeds of the equipmentfeeding coal to units I and 2.]
Emissions from this emissions unit include water droplets, so visible emission testing is not possible.]
Essential Potential to Emit (PTE) Parameters H.1. Containment of Fugitive Emissions. To the extent possible, the equipment that comprises the coal processing equipment at this facility (crushers, conveyors, drop points, and storage bunkers) shall be covered or enclosed at all times when the equipment is in operation. Except for the barge load-out and the stacker re-claimer sections of the conveying system that are required by design to be open, and which are not specifically subject to regulation under 40 CFR 60 Subpart Y, any other open section of the coal processing equipment shall be required to have any annual emission test conducted upon it. [Permit No. 0170004-014-AC]
H.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
H.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.]
Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition H.4 is based on the specified averaging time of the applicable test method.
H.4. VE. The owner or operator shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater, six minute average. [PPSC PA 77-09 (coal facilities associated with Units 1, 2, 4 and 5); and, Permit No. 0170004-014-AC]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
H.5. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
Progress Energy Florida, Inc.                                                            Permit No. 0170004-024-AV Crystal River Power Plant                                                        Title V Air Operation Permit Renewal Page 30 of 54


===1.3. Emissions===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection H. Emissions Unit 016 H.6. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
Test Methods and Procedures H.7. Test Methods. Required tests shall be performed in accordance with the following reference methods:
Method      Description of Method and Comments 9      Visual Determination of the Opacity of Emissions from Stationary Sources 22      Visual Determination of Fugitive Emissions from Material Sources and Smoke Emissions form Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C., Permit No. 0170004-014-AC]
H.8. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit.
[Rule 62-297.310, F.A.C.]
H.9. VE. (This condition applies to coal facilities associated with emissions units 001, 002, 004 and 003 --
FFSG Units 1, 2, 4 and 5.) When required by the Department, or annually as specified in Specific Condition H.1., EPA Method 9 and the procedures in 40 CFR 60.11 shall be used to determine opacity. [40 CFR 60.254; and, Permit No. 0170004-014-AC]
(Permitting Note: Except as specified in Specific Condition H.9., annual testing is not being required because the regulated emissions points are either enclosed or confined within a building.]
(Permittingnote: For those emissions points containing a baghouse (ash silos), the permittee shall perform and record the results of weekly qualitative observations of visible emissions checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormalvisible emissions.]
Recordkeeping and Reporting Requirements H.10. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc.                                                            Permit No. 0170004-024-AV Crystal River Power Plant                                                      Title V Air Operation Permit Renewal Page 31 of 54


Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements.  
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
[Rule 62-297.310(2), F.A.C.]Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions 1.4. -1.5.. are based on the specified averaging time of the applicable test method.1.4. Drift Rate. The portable cooling towers shall be designed, operated and maintained to achieve a drift rate of no more than 0.0015% of the circulating water flow. [Permit No. 0170004-010-AC]
Subsection I. Emission Unit 020 The specific conditions in this section apply to the following emissions unit:
1.5. PM Emissions.
EU No. Brief Description 020      Cooling towers for FFSG Units 1 and 2 used to reduce plant discharge water temperature.
The drift rate standard in Specific Condition  
Emissions unit 020 (EU020) is cooling towers for FFSG Units 1 and 2, used to reduce plant discharge water temperature. (This emission unit may be referred to as "portable cooling towers.") This emissions unit consists of 71 or 72 cells (dependent upon manufacturer), is 12' wide and 11' high, includes drift eliminators, operates at a maximum circulating seawater flow rate of 180,000 gallons per minute for all cells combined, and a design airflow rate of 25,000 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by drift eliminators.
(Permittingnote(s): This emissions unit is regulatedunder Prevention of Significant Deterioration(PSD) (permit 0170004-010-AC) and includes a Best Available Control Technology (BACT) Determination,which allows for a drift emission rate of 0.0015% with limited usage.]
Essential Potential to Emit (PTE) Parameters 1.1. Hours of Operation. The operating hours for the portable cooling towers shall not exceed an equivalent of 2,920 hours per year of operation (12-month rolling total). This condition shall be complied with by limiting the circulating water flow usage through the portable cooling towers to 31.5 x 109 gallons per calendar year.
[Rule 62-210.200(PTE), F.A.C.; Permit No. 0170004-010-AC)]
1.2. Drift Eliminators. Drift eliminators shall be installed and maintained as per the manufacturer's specifications. Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators.
[Rule 62-213.440, F.A.C.; Permit No. 0170004-010-AC)]
(Permitting Note: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets, so visible emission testing is not possible.]
1.3. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.]
Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions 1.4. - 1.5.. are based on the specified averaging time of the applicable test method.
1.4. Drift Rate. The portable cooling towers shall be designed, operated and maintained to achieve a drift rate of no more than 0.0015% of the circulating water flow. [Permit No. 0170004-010-AC]
1.5. PM Emissions. The drift rate standard in Specific Condition 1.4. equates to an estimated emission rate of particulate matter (PM) from the cooling tower at 35.1 pounds per hour. [Permit No. 0170004-010-AC]
(Permitting Note: The emission limit is based on a BACT Determinationsetting the maximum drift emissions at 0.0015%. PM1O emissions are estimated to be approximately 6% of the particulatematter emission rate.]
Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
1.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
Progress Energy Florida, Inc.                                                              Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 32 of 54


===1.4. equates===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
to an estimated emission rate of particulate matter (PM) from the cooling tower at 35.1 pounds per hour. [Permit No. 0170004-010-AC](Permitting Note: The emission limit is based on a BACT Determination setting the maximum drift emissions at 0.0015%. PM1O emissions are estimated to be approximately 6% of the particulate matter emission rate.]Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision.
Subsection I. Emission Unit 020 1.7.      Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.]
Monitoring of Operations 1.8.      Inspection Log. Any problems detected during the work practice inspections identified in Specific Condition 1.10. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000]
Test Methods and Procedures 1.9.      Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]
1.10.      Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During those calendar days when the portable cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.0015% drift rate):
: a. Walkdown Inspections. Daily "walkdown" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).
: b. Visual Inspections. Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.
: c. Weekly Inspections. Weekly visual inspections of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
[Rule 62-213.440, F.A.C., Permit No. 0170004-010-AC; and ASP No. 00-E-01 dated June 7, 2000]
Recordkeeping and Reportin2 Requirements 1.11.      Circulating Water Flow-Meters Required. Circulating water flow will be measured by monitoring the hours of each circulating water pump. For each hour of operation, each north pump will flow 15 thousand gallons per minute (kgpm) (900 thousand gallons per hour (kgph)) and each south pump will flow 4 kgpm (240 khph). The fans in bank C1 through C15 will be monitored for operation. If any of the fans are operating in those cells, the circulating water flow will be 39 kgpm (2,340 kgph). Partial hours of operation shall be prorated. Records of circulating water flow shall be maintained for each calendar month. [Rule 62-213.440, F.A.C.; Permit No. 0170004-10-AC]
1.12      Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc.                                                              Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 33 of 54


===1.6. Excess===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration.  
Subsection J. Common Conditions The specific conditions in this section apply to the following emissions units:
[Rule 62-210.700(1), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 32 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
EU No. Brief Description 001        Fossil Fuel Steam Generator, Unit 1 002        Fossil Fuel Steam Generator, Unit 2 004        Fossil Fuel Steam Generator, Unit 4 003        Fossil Fuel Steam Generator, Unit 5
Subsection I. Emission Unit 020 1.7. Excess Emissions Prohibited.
{Permitting Notes: The emissions units above are subject to the following condition which allows the burning of on-specification used oil pursuant to the requirements of this permit and this subsection.)
Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited.  
J.1. Used Oil. Burning of on-specification used oil is allowed in emissions units 001, 002, 004 and 003 in accordance with all other conditions of this permit and the following conditions:
[Rule 62-210.700(4), F.A.C.]Monitoring of Operations
: a. On-specification Used Oil Allowed as Fuel. This permit allows the burning of used oil fuel meeting EPA "on-specification" used oil specifications, with a PCB concentration of less than 50 ppm. Used oil that does not meet the specifications for on-specification used oil shall not be burned at this facility. On-specification used oil shall meet the following specifications: [40 CFR 279, Subpart B.]
(1) Arsenic shall not exceed 5.0 ppm, (2) Cadmium shall not exceed 2.0 ppm, (3) Chromium shall not exceed 10.0 ppm, (4) Lead shall not exceed 100.0 ppm, (5) Total halogens shall not exceed 1000 ppm, (6) Flash point shall not be less than 100 degrees F.
: b. Quantity Limited. The maximum quantity of on-specification used oil that may be burned in all four emissions units combined is 10 million gallons in any consecutive 12-month period.
: c. Used Oil ContainingPCBs Not Allowed. Used oil containing a PCB concentration of 50 or more ppm shall not be burned at this facility. Used oil shall not be blended to meet this requirement.
: d. PCB Concentrationof 2 to less than 50 ppm. On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall be burned only at normal source operating temperatures. On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall not be burned during periods of startup or shutdown.
Before accepting from each marketer the first shipment of on-specification used oil with a PCB concentration of 2 to 49 ppm, the owner or operator shall provide each marketer with a one-time written and signed notice certifying that the owner or operator will burn the used oil in a qualified combustion device and must identify the class of combustion device. The notice must state that EPA or a RCRA-delegated state agency has been given a description of the used oil management activities at the facility and that an industrial boiler or furnace will be used to burn the used oil with a PCB concentration of 2 to 49 ppm. The description of the used oil management activities shall be submitted to the EPA or may be submitted to the Administrator, Hazardous Waste Regulation Section, Florida Department of Environmental Protection, 2600 Blair Stone Road, Tallahassee, FL 32399-2400. A copy of the notice provided to each marketer shall be maintained at the facility. [40 CFR 279.61 and 761.20(e)]
: e. CertificationRequired. The owner or operator shall receive from the marketer, for each load of used oil received, a certification that the used oil meets the specifications for on-specification used oil and contains a PCB concentration of less than 50 ppm. This certification shall also describe the basis for the certification, such as analytical results.
Used oil to be burned for energy recovery is presumed to contain quantifiable levels (2 ppm) of PCB unless the marketer obtains analyses (testing) or other information that the used oil fuel does not contain quantifiable levels of PCBs. Note that a claim that used oil does not contain quantifiable levels of PCBs (that is, that the used oil contains less than 2 ppm of PCBs) must be documented by analysis or other Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                          Title V Air Operation Permit Renewal Page 34 of 54


===1.8. Inspection===
SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection J. Common Conditions information. The first person making the claim that the used oil does not contain PCBs is responsible for furnishing the documentation. The documentation can be tests, personal or special knowledge of the source and composition of the used oil, or a certification from the person generating the used oil claiming that the used oil contains no detectable PCBs.
: f. Testing Required. The owner or operator shall sample and analyze each batch of used oil to be burned for the following parameters:
(1) Arsenic, cadmium, chromium, lead, total halogens, flash point, PCBs*, and specific gravity.
(2) Testing (sampling, extraction and analysis) shall be performed using approved methods specified in EPA Publication SW-846 (Test Methods for Evaluating Solid Waste, Physical/Chemical Methods),
latest edition.
* Analysis for PCBs is not required if a claim is made that the used oil does not contain quantifiable levels of PCBs.
: g. Record Keeping Required. The owner or operator shall obtain, make, and keep the following records related to the use of used oil in a form suitable for inspection at the facility by the Department: [40 CFR 279.61 and 761.20(e)]
(1) The gallons of on-specification used oil accepted and burned each month in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.)
(2)The total gallons of on-specification used oil burned in the preceding consecutive 12-month period in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.)
(3) Results of the analyses required above, including documentation if a claim is made that the used oil does not contain quantifiable levels of PCBs.
(4) The source and quantity of each batch of used oil received each month, including the name, address and EPA identification number (if applicable) of all marketers that delivered used oil to the facility, and the quantity delivered.
(5) Records of the operating rate of each unit while burning used oil and the dates and time periods each unit burns used oil.
: h. Reporting Required The owner or operator shall submit to the Department's Southwest District office, with the Annual Operation Report form, an attachment showing the total amount of on-specification used oil burned during the previous calendar year. The quantity of used oil shall be individually reported and shall not be combined with other fuels.
[Rule 62-213.440, F.A.C.; 40 CFR 279 and 40 CFR 761; and Permit No. 0170004-002-AO]
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                            Title V Air Operation Permit Renewal Page 35 of 54


Log. Any problems detected during the work practice inspections identified in Specific Condition 1.10. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000]Test Methods and Procedures
SECTION IV. ACID RAIN PART.
 
Federal Acid Rain Provisions Operated by: Florida Power Corporation dba Progress Energy Florida ORIS Code: 0628 The emissions units listed below are regulated under Acid Rain, Phase I.
===1.9. Common===
E.U. No.           EPA ID#       Brief Description 001               1         FFSG, Unit 1.
Testing Requirements.
002               2         FFSG, Unit 2 003               5         FFSG, Unit 5, 004               4         FFSG, Unit 4, A.1.     The Phase II Acid Rain Part application submitted for this facility, as approved by the Department, is a part of this permit. The owners and operators of these Phase II acid rain units must comply with the standard requirements and special provisions set forth in the applications listed below:
Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.]1.10. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators.
: a. DEP Form No. 62-210.900(1)(a), dated 08/25/09, received 10/08/2009.
During those calendar days when the portable cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.0015% drift rate): a. Walkdown Inspections.
Daily "walkdown" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).b. Visual Inspections.
Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.c. Weekly Inspections.
Weekly visual inspections of the inlet water screens and prompt correction when broken sections or pluggage is discovered.
[Rule 62-213.440, F.A.C., Permit No. 0170004-010-AC; and ASP No. 00-E-01 dated June 7, 2000]Recordkeeping and Reportin2 Requirements 1.11. Circulating Water Flow-Meters Required.
Circulating water flow will be measured by monitoring the hours of each circulating water pump. For each hour of operation, each north pump will flow 15 thousand gallons per minute (kgpm) (900 thousand gallons per hour (kgph)) and each south pump will flow 4 kgpm (240 khph). The fans in bank C1 through C15 will be monitored for operation.
If any of the fans are operating in those cells, the circulating water flow will be 39 kgpm (2,340 kgph). Partial hours of operation shall be prorated.
Records of circulating water flow shall be maintained for each calendar month. [Rule 62-213.440, F.A.C.; Permit No. 0170004-10-AC]
1.12 Other Reporting Requirements.
See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 33 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection J. Common Conditions The specific conditions in this section apply to the following emissions units: EU No. Brief Description 001 Fossil Fuel Steam Generator, Unit 1 002 Fossil Fuel Steam Generator, Unit 2 004 Fossil Fuel Steam Generator, Unit 4 003 Fossil Fuel Steam Generator, Unit 5{Permitting Notes: The emissions units above are subject to the following condition which allows the burning of on-specification used oil pursuant to the requirements of this permit and this subsection.)
J.1. Used Oil. Burning of on-specification used oil is allowed in emissions units 001, 002, 004 and 003 in accordance with all other conditions of this permit and the following conditions:
: a. On-specification Used Oil Allowed as Fuel. This permit allows the burning of used oil fuel meeting EPA"on-specification" used oil specifications, with a PCB concentration of less than 50 ppm. Used oil that does not meet the specifications for on-specification used oil shall not be burned at this facility.
On-specification used oil shall meet the following specifications:
[40 CFR 279, Subpart B.](1) Arsenic shall not exceed 5.0 ppm, (2) Cadmium shall not exceed 2.0 ppm, (3) Chromium shall not exceed 10.0 ppm, (4) Lead shall not exceed 100.0 ppm, (5) Total halogens shall not exceed 1000 ppm, (6) Flash point shall not be less than 100 degrees F.b. Quantity Limited. The maximum quantity of on-specification used oil that may be burned in all four emissions units combined is 10 million gallons in any consecutive 12-month period.c. Used Oil Containing PCBs Not Allowed. Used oil containing a PCB concentration of 50 or more ppm shall not be burned at this facility.
Used oil shall not be blended to meet this requirement.
: d. PCB Concentration of 2 to less than 50 ppm. On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall be burned only at normal source operating temperatures.
On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall not be burned during periods of startup or shutdown.Before accepting from each marketer the first shipment of on-specification used oil with a PCB concentration of 2 to 49 ppm, the owner or operator shall provide each marketer with a one-time written and signed notice certifying that the owner or operator will burn the used oil in a qualified combustion device and must identify the class of combustion device. The notice must state that EPA or a RCRA-delegated state agency has been given a description of the used oil management activities at the facility and that an industrial boiler or furnace will be used to burn the used oil with a PCB concentration of 2 to 49 ppm. The description of the used oil management activities shall be submitted to the EPA or may be submitted to the Administrator, Hazardous Waste Regulation Section, Florida Department of Environmental Protection, 2600 Blair Stone Road, Tallahassee, FL 32399-2400.
A copy of the notice provided to each marketer shall be maintained at the facility.
[40 CFR 279.61 and 761.20(e)]
: e. Certification Required.
The owner or operator shall receive from the marketer, for each load of used oil received, a certification that the used oil meets the specifications for on-specification used oil and contains a PCB concentration of less than 50 ppm. This certification shall also describe the basis for the certification, such as analytical results.Used oil to be burned for energy recovery is presumed to contain quantifiable levels (2 ppm) of PCB unless the marketer obtains analyses (testing) or other information that the used oil fuel does not contain quantifiable levels of PCBs. Note that a claim that used oil does not contain quantifiable levels of PCBs (that is, that the used oil contains less than 2 ppm of PCBs) must be documented by analysis or other Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 34 of 54 SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS.
Subsection J. Common Conditions information.
The first person making the claim that the used oil does not contain PCBs is responsible for furnishing the documentation.
The documentation can be tests, personal or special knowledge of the source and composition of the used oil, or a certification from the person generating the used oil claiming that the used oil contains no detectable PCBs.f. Testing Required.
The owner or operator shall sample and analyze each batch of used oil to be burned for the following parameters:
(1) Arsenic, cadmium, chromium, lead, total halogens, flash point, PCBs*, and specific gravity.(2) Testing (sampling, extraction and analysis) shall be performed using approved methods specified in EPA Publication SW-846 (Test Methods for Evaluating Solid Waste, Physical/Chemical Methods), latest edition.* Analysis for PCBs is not required if a claim is made that the used oil does not contain quantifiable levels of PCBs.g. Record Keeping Required.
The owner or operator shall obtain, make, and keep the following records related to the use of used oil in a form suitable for inspection at the facility by the Department:
[40 CFR 279.61 and 761.20(e)]
(1) The gallons of on-specification used oil accepted and burned each month in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.)(2)The total gallons of on-specification used oil burned in the preceding consecutive 12-month period in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.)(3) Results of the analyses required above, including documentation if a claim is made that the used oil does not contain quantifiable levels of PCBs.(4) The source and quantity of each batch of used oil received each month, including the name, address and EPA identification number (if applicable) of all marketers that delivered used oil to the facility, and the quantity delivered.
(5) Records of the operating rate of each unit while burning used oil and the dates and time periods each unit burns used oil.h. Reporting Required The owner or operator shall submit to the Department's Southwest District office, with the Annual Operation Report form, an attachment showing the total amount of on-specification used oil burned during the previous calendar year. The quantity of used oil shall be individually reported and shall not be combined with other fuels.[Rule 62-213.440, F.A.C.; 40 CFR 279 and 40 CFR 761; and Permit No. 0170004-002-AO]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 35 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Operated by: Florida Power Corporation dba Progress Energy Florida ORIS Code: 0628 The emissions units listed below are regulated under Acid Rain, Phase I.E.U. No. EPA ID# Brief Description 001 1 FFSG, Unit 1.002 2 FFSG, Unit 2 003 5 FFSG, Unit 5, 004 4 FFSG, Unit 4, A.1. The Phase II Acid Rain Part application submitted for this facility, as approved by the Department, is a part of this permit. The owners and operators of these Phase II acid rain units must comply with the standard requirements and special provisions set forth in the applications listed below: a. DEP Form No. 62-210.900(1)(a), dated 08/25/09, received 10/08/2009.
: b. DEP Form No. 62-210.900(1)(a)1, dated 08/25/09, received 10/08/2009.
: b. DEP Form No. 62-210.900(1)(a)1, dated 08/25/09, received 10/08/2009.
: c. EPA Form 7610-28 (12-03), dated 08/25/09, received 10/08/2009.
: c. EPA Form 7610-28 (12-03), dated 08/25/09, received 10/08/2009.
[Chapter 62-213, F.A.C. and Rule 62-214.320, F.A.C.]A.2. Nitrogen oxide (NOx) requirements for each Acid Rain Phase 1I unit are as follows: E.U. ID # EPA ID NOx Limit 001 1 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu.
[Chapter 62-213, F.A.C. and Rule 62-214.320, F.A.C.]
In addition, this unit shall not have an annual heat input greater than 37,112,400 MMBtu.Also, see Additional Requirements a., b. and c., below.002 2 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu.
A.2.     Nitrogen oxide (NOx) requirements for each Acid Rain Phase 1I unit are as follows:
In addition, this unit shall not have an annual heat input greater than 42,602,400 MMBtu.Also, see Additional Requirements a., b. and c., below.003 5 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu.
E.U. ID #     EPA ID                                         NOx Limit 001             1   Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.
In addition, this unit shall not have an annual heat input greater than 74,334,600 MMBtu.Also, see Additional Requirements a., b. and c., below.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 36 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions E.U. ID # EPA ID NOx Limit 004 4 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu.
Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 37,112,400 MMBtu.
In addition, this unit shall not have an annual heat input greater than 79,385,400 MMBtu.Also, see Additional Requirements a., b. and c., below.Additional Requirements
Also, see Additional Requirements a., b. and c., below.
: a. Under the plan (NOx Phase 1I averaging plan), the actual Btu-weighted annual average NOx emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NOx emission rate for the same units had they each been operated, during the same period of time, in compliance with the applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 76.1 l(d)(1)(ii)(A))
002           2     Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.
is met for a year under the plan, then this unit shall be deemed to be in compliance for that year with its alternative contemporaneous annual emission limitation and annual heat input limit.b. In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only after the North Carolina Department of Environmental and Natural Resources  
Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 42,602,400 MMBtu.
-Bureau of Air Quality, the Western North Carolina Regional Air Pollution Control Agency, and the South Carolina Department of Health and Environmental Control, have also approved this averaging plan.c. In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions.
Also, see Additional Requirements a., b. and c., below.
A.3. Sulfur dioxide (SO,) Emission Allowances.
003             5   Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.
SO 2 emissions from sources subject to the Federal Acid Rain Program (Title IV) shall not exceed any allowances that the source lawfully holds under the Federal Acid Rain Program. Allowances shall not be used to demonstrate compliance with a non-Title IV applicable requirement of the Act.a. No permit revision shall be required for increases in emissions that are authorized by allowances acquired pursuant to the Federal Acid Rain Program, provided that such increases do not require a permit revision pursuant to Rule 62-213.400(3), F.A.C.b. No limit shall be placed on the number of allowances held by the source under the Federal Acid Rain Program.c. Allowances shall be accounted for under the Federal Acid Rain Program.[Rule 62-213.440(1)(c)1., 2. & 3., F.A.C.]A.4. Comments, notes, and justifications:
Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 74,334,600 MMBtu.
None.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 37 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Acid Rain Part Application For more intormation.
Also, see Additional Requirements a., b. and c., below.
see instructions and refer to 40 CFR 72.30, 72.31, and 74: and Chapter 02-214, F.A.G.This submission is: 10 New 0 Revised 1A Renewal Crystal River Fl. 628 Plant name State ORIS/Plant Code STEP I Identify the source by plant name, state, and ORIS or plant code.STEP 2 Enter the unit ID#for every Acid Rain unit at the Acid Rain source In column.a., If unit a SO2 Opt-in unit, enter "yea" In column "b".For new units or SOz Opt-In units, enter the requested information in columns "d" and"e." a b c d a Unit ID' .50 Opt-In Unit will New or 502 Opt-In New or 302 Opt-tn Unit? hold Units Units allowances (Yes or No) in accordance Commence Monitor with 40 CFR Operation Date Certification 72.9(c)(1)
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                        Title V Air Operation Permit Renewal Page 36 of 54
Deadline I No N/A N/A Yes 2 NO N/A NIA Yes 4 No N/A NIA Yes 5 No IN/A N/A Yes Yes Yes Yes Yes Yes Yes __________
 
__________
SECTION IV. ACID RAIN PART.
Yes ___________________
Federal Acid Rain Provisions E.U. ID #       EPA ID                                           NOx Limit 004             4       Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014.
Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 79,385,400 MMBtu.
Also, see Additional Requirements a., b. and c., below.
Additional Requirements
: a. Under the plan (NOx Phase 1I averaging plan), the actual Btu-weighted annual average NOx emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NOx emission rate for the same units had they each been operated, during the same period of time, in compliance with the applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 76.1 l(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in compliance for that year with its alternative contemporaneous annual emission limitation and annual heat input limit.
: b. In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only after the North Carolina Department of Environmental and Natural Resources - Bureau of Air Quality, the Western North Carolina Regional Air Pollution Control Agency, and the South Carolina Department of Health and Environmental Control, have also approved this averaging plan.
: c. In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions.
A.3. Sulfur dioxide (SO,) Emission Allowances. SO 2 emissions from sources subject to the Federal Acid Rain Program (Title IV) shall not exceed any allowances that the source lawfully holds under the Federal Acid Rain Program. Allowances shall not be used to demonstrate compliance with a non-Title IV applicable requirement of the Act.
: a. No permit revision shall be required for increases in emissions that are authorized by allowances acquired pursuant to the Federal Acid Rain Program, provided that such increases do not require a permit revision pursuant to Rule 62-213.400(3), F.A.C.
: b. No limit shall be placed on the number of allowances held by the source under the Federal Acid Rain Program.
: c. Allowances shall be accounted for under the Federal Acid Rain Program.
[Rule 62-213.440(1)(c)1., 2. & 3., F.A.C.]
A.4. Comments, notes, and justifications: None.
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                           Title V Air Operation Permit Renewal Page 37 of 54
 
SECTION IV. ACID RAIN PART.
Federal Acid Rain Provisions Acid Rain Part Application For more intormation. see instructions and refer to 40 CFR 72.30, 72.31, and 74: and Chapter 02-214, F.A.G.
This submission is: 10 New           0 Revised       1A Renewal STEP I                  Crystal River                                                               Fl.                   628 Identify the source Plant name                                                                   State                 ORIS/Plant Code by plant name, state, and ORIS or plant code.
STEP 2                           a              b                c                    d                        a Enter the unit ID#
for every Acid Rain         Unit ID'       .50 Opt-In         Unit will     New or 502 Opt-In         New or 302 Opt-tn unit at the Acid Rain                          Unit?             hold                 Units                   Units source In column                                            allowances
        .a.,                                        (Yes or No)     in accordance         Commence                   Monitor with 40 CFR         Operation Date             Certification If unit a SO2 Opt-in                                          72.9(c)(1)                                     Deadline unit, enter "yea" In    I                     No                           N/A                     N/A column "b".                                                      Yes 2                     NO                           N/A                     NIA For new units or                                                  Yes SOz Opt-In units,        4                     No                           N/A                     NIA enter the requested                                              Yes information in          5                     No                           IN/A                   N/A Yes columns "d" and "e."                                                              Yes Yes Yes Yes Yes Yes                               __________
__________       Yes         ___________________
_________
_________
________ Yes _________________
________               Yes         _________________
DEP Forn No. 62-210.900Dl  
DEP Forn No. 62-210.900Dl )(a) - Form Effective: 3/1/08 Progress Energy Florida, Inc.                                                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                              Title V Air Operation Permit Renewal Page 38 of 54
)(a) -Form Effective:
 
3/1/08 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 38 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1)STEP 3 Acid Rain Part Reauirements.
SECTION IV. ACID RAIN PART.
(1) The desirgated representative of each Acid Rain source and each Acid Rain unit at the source shal"t Read the (i) Submit a complete Acd Rain Part appnclion (including a compliance plan) under 40 CFR Part 72 and RUate 02-214.320 and 330.standard F.A.C.. In accordance with the deadlines specified in Rule 62-214.320, FAC.; and (i) Submi in a timely manner any supplemental information that the DEP determines Is necessary in order to review an Acid Rain Part requirements.
Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1)
application and Issue or deny an Acid Rain Part;(2) The owners end operators of each Acid Rain source and eacth Acid Rain unit at the source sthag: (i) Oporate the unit in with a complete Acid Rain Part application or a auperseding Acid Rain Part isaued by the DEP; and (it) Have an Acid Rain Part.Monitoring Requirements.
STEP 3                 Acid Rain Part Reauirements.
(1) The owners and operators and, to the extent designated representative of-h Ac]d Rain aource and each Acid Rein unit at the source shall comply with the monitoring requirements as provided in 40 CFR Part 75. and Rule 02-214.420, FA.C.(2) The emissions measurements recorded and reported In accordance with 40 CFR Part 75 shall be used to deterrntine compliance byi the unit with the Acid Rain emlssions limitations and emissions reduction requirements for sulfur dioxide and nilrogen oxides under the Acid Rain Program.(3) The requirements of 40 CFR Part 75 shall not affect the responsibility of the owners and operators to monitax emissions of other pollJtanits or other emissions characleristcs at the unit under other applicable requirements of the Ad and other provisions ot the operating permit for the source.(4) For applicationa including a SO&#xfd; Opt-er unit, a monitoring plan tfo each SOZ Opt-in unit must be submitted with this application pursuant to 40 CFR 74.14(a).
(1) The desirgated representative of each Acid Rain source and each AcidRain unit at the source shal"t Read the                     (i) Submit a complete Acd Rain Part appnclion (including a compliance plan) under 40 CFR Part 72 and RUate02-214.320 and 330.
For renewal applicetions for SO 0 Opt-in units incude arn updated monitoring plan If applicable under 40 CFR 75.53(b).Sulfur Dioxide Requirements.
standard                     F.A.C..Inaccordance with the deadlines specified in Rule 62-214.320, FAC.; and (i) Submi in a timely manner any supplemental information that the DEP determines Is necessary in order to review an Acid Rain Part requirements.               application and Issue or deny an AcidRain Part; (2) The owners end operators of each Acid Rain source andeacth Acid Rain unit at the source sthag:
(1) The owners and operators of each source and each Acid Rain unit at the source shall: (I) Hold allowances.
(i) Oporate the unit in compr*iancwith a complete Acid Rain Part application or a auperseding Acid Rain Part isaued by the DEP; and (it) Have an Acid Rain Part.
as of the allowance transfer deadline, in the unit's compliance subaccount (after deductions under 40 CFR 73.34(c)).
Monitoring Requirements.
or In the compsi uce subaaccunt af another Acid Rain ulit at the are sou-.e i the -stent provided in 40 CFR 73.35(b)3)3.
(1) The owners and operators and, to the extent app*cable, designated representative of-h Ac]dRain aource and each Acid Rein unit at the source shall comply with the monitoring requirements as provided in 40 CFR Part 75. andRule 02-214.420, FA.C.
not tess than the total annual emissions of sulfur dioxide ftr the previous calendar year from the unit; and (ii) Comply with the applcable Acid Rain emissions limilations for sulftr dioxide.(7) Eaci ton of sultur dioxide emned in excess of the Acid Rain emissions timitatlons tfr sulfur dioxide snall constitute a separate violation of the Act.(3) An Acid Rain cri1 shalt be sece tlo the requirementn under Paragraph (1) of the rciaut dioxide requorementsi as fellows: (i) Starting January 1. 2000. an Acid Rain unit under 40 CFR 72.6(a}(2);
(2) The emissions measurements recorded and reportedInaccordance with 40 CFR Part 75 shall be used to deterrntine compliance byithe unit with the Acid Rain emlssions limitations and emissions reduction requirements forsulfur dioxide and nilrogen oxides under the Acid Rain Program.
or (i) Starting on the later of January 1, 2000, or the deasine for monitor cedfication under 40 CFR Pan 75, an Acid Rain unit under 40 CFR 72.6(aX2).
(3) The requirements of 40 CFR Part 75 shall not affect the responsibility of the owners and operators to monitax emissions of other pollJtanits or other emissions characleristcs at the unit under other applicable requirements of the Ad and other provisions ot the operating permit for the source.
(4) Altowances shell be held in. deducted from, or transferred amtong Allowance Trcking System accounts in accordance with the Acid Rain Program.(5) An aliowance shau not be deducted in order to comply with the requimrernts under paragraph (1) of the sugtur dioxide requirements prior to the calendar year for which the allowance was altocated.
(4) For applicationa including a SO&#xfd;Opt-er unit, a monitoring plan tfo each SOZOpt-in unit must be submitted with this application pursuant to40 CFR 74.14(a). For renewal applicetions for SO0 Opt-in units incude arnupdated monitoring plan Ifapplicable under 40 CFR 75.53(b).
(6) An aliowence ellocated by the Aclsinisthraor under the Adid Rain Program is a limited authorization to eint sulfur dioxide in ocoordance with the Acid Rain Program. No provision of the Acid Rain Program, ge Acid Rain Part application.
Sulfur Dioxide Requirements.
the Acid Rain Part or an exemption under 40 CFR 7W7 or 72.8 and no provision of law shall be construed to limit the authority of 01h United States to terninate or limit such authorization.
(1) The owners and operators of each source and each Acid Rain unit at the source shall:
(7) An aliowance atlocated by the Administrator under the Acid Rain Program does not constitute a property ight Nitrogen Oxides The owners end operators ot the source and each Add Rain unit at the sotrce shalt comply with the applicable Acid Rain amissions limitation for nitrogen oxides.Excess Emissions Requirements.(t) The deigtated tepresentalive of an Acid Rain writ that has excess emrisons in any calendar year shag submft a proposed offset plan, as required under 40 CFR Pat 77.(2) The owners arnd operators ctan Acid Rain unit that has exciess emissions in any calendar year shalt (I) Pay without demand the penalty required.
(I) Hold allowances. as of the allowance transfer deadline, in the unit's compliance subaccount (after deductions under 40 CFR 73.34(c)). or Inthe compsi       subaaccunt uce         af another Acid Rain ulit at the are sou-.e i the -stent provided in 40 CFR 73.35(b)3)3.not tess than the total annual emissions of sulfur dioxide ftr the previouscalendar year from the unit; and (ii) Comply with the applcable Acid Rain emissions limilations for sulftr dioxide.
and pay upon demand the interest on tgat penalty, as rertuired by40 CFR Part 77: and (ii) Comply with the terms of an approved offset plan, as required by 40 CFR Parl 77.Recordkeeoing and Reporting Requirements.
(7) Eaci ton of sultur dioxide emned in excess of theAcid Rain emissions timitatlons tfr sulfur dioxide snall constitute a separate violation of theAct.
(1) Unless otherwise provided, the owners and operators of thi scurce and eaich Acd Rain unit at the source shallt eep on site at the source each of the following documents fo e period of 5 years from the date the document is created. This period may be extended for cause. at any time pior to the end of p years, In writig by the EPA or trw DEP: (i} The certificale of representation for the designated reprensentative for the source and each Add Rain ursl at the source and all documents that demonstrate the truth of the stetements in the certificate of representatior.
(3) AnAcid Rain cri1 shalt be sece tlothe requirementn under Paragraph         (1) ofthe rciaut dioxide requorementsiasfellows:
In accordance with Rule 62-214.350.
(i) Starting January 1. 2000. an AcidRain unit under 40 CFR 72.6(a}(2); or (i) Starting on the later of January 1, 2000, or the deasine for monitor cedfication under 40 CFR Pan 75, an Acid Rain unit under 40 CFR 72.6(aX2).
F.A.C.: Provided that the certificate and documents shetl be retained on site at the source beyond such 5-year period until such documents are superseded because of the submiltsion of a new ceritficate of representation changing the designated representative; (1) All enissions monitoring information, in with 40 CFR Part 75, provided that to the "rent thait 40 CFR Pait 75 provides fr a 3-year period for recordheoping.
(4) Altowances shell be held in. deducted from, or transferred   amtong Allowance Trcking System accounts in accordance with the Acid Rain Program.
the 3-year period shall apply;, (Si) Copies of all reports, conmpliance certifcationes.
(5) An aliowance shau not be deducted in order to comply with the requimrernts under paragraph (1) of the sugtur dioxide requirements prior to the calendar year for which the allowance was altocated.
and other sutsmissionis and all records made or required under the Acid Rain Program;and.DEP Form No. 62-210.900(1Xa)-
(6) An aliowence ellocated by the Aclsinisthraor under the AdidRain Program is a limited authorization to eint sulfur dioxide in ocoordance with the Acid Rain Program. No provision of the AcidRain Program, ge Acid Rain Part application. the Acid Rain Part or an exemption under 40 CFR 7W7or 72.8 and no provision of law shall be construed to limitthe authority of   01h United States to terninate or limitsuch authorization.
Form Effective:
(7) An aliowance atlocated by the Administrator under the Acid Rain Program does not constitute a property ight Nitrogen Oxides Reouirelment.* The owners endoperators ot the source and each Add Rain unit at the sotrce shalt comply                   with the applicable Acid Rain amissions limitation for nitrogen oxides.
3/161/08 2 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 39 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1)STEP 3, Conitnued.
Excess Emissions Requirements.
Recordkeepina and Reporting Requirements (contj (iv) Copies of alt documents used to complete an Acid Rain Part application and any other submnissln under the Acid Rain Program or to Oemonstrate omplirace with the requirements of Me Acid Rain Program.(2) The deslgnated representative of an Acid Rain source and each Acid Rain unit at the source shait submit the reports and compiance certillcatiorna required under the Acid Rain Program, inrluding those under 40 CFR Part 72, Subpart I, and 40 CFR Part 75.Liability.
(t) The deigtated tepresentalive of an Acid Rain writ that has excess emrisons in any calendar year shag submft a proposed offset plan, as required under 40 CFR Pat 77.
(1) Any person wnto knoweigly violates any requirement or Orothition of the Acid Rain"Prooram.
(2) The owners arndoperators ctan Acid Rain unit that has exciess emissions in any calendar year shalt (I) Pay without demand the penalty required. and pay upon demand the interest on tgat penalty, as rertuired by40 CFR Part 77: and (ii) Comply with the terms of an approved offset plan, as required by 40 CFR Parl 77.
a complete Acid Rain Part appication.
Recordkeeoing and Reporting Requirements.
an Acid Rain Part. or an exemption under 40 CFR 72. or 72.8, including any requirement for the payment of any penalty owed to the Uniled States, shall be subject to enforcement pursuant to section 113(c) of the Act.(2) Any person who knowingly makes a talse. material statement in arty record, subrmdnslvn, or report under the Acid Rain Program shall be subjet to criminal enforcement purthirruttO section `113(c0) of the Act and 18 U.S.C. 1001.(3) No oemnit revision shal easuse any violation of the requirements of the Acid Rain Program that occurs prior to the date that the revision takes effact.(4) Each Acid Rain source and each Acid Rain unit shall meet the requirements of the Acid Rain Program.(5) Any provisionr of the Acid Rain Program that applies to an Acid Rain sJurce (inokdtna a provlslon appliahiloa to the designated representative of an Add Rain source) shall also apply to the owners and operators of such source and of the Acid Rain units at the source.(6) Any provision of the Acid Rain Program that applies to an Acid Rain unit (including a provision epplicable to tre designated representative of an Acid Rain unit) shat also apply to the owners and operators of such urit. Except as provided under 40 CFR 72.44 (Phase I repowering extension plans) and 40 CFR 76.11 (NOx averaging plans), and except with regard to the requirements applicabte to units with a common stack under 40 CFR Part 75 (including 40 CFR 75.16, 75.17, and 75.18), the owners and operators exn the designated reproeuntative of one Aidd Rain unit shah not be liable for any violation by any other Acid Rain unit o( which they are not owners or operators or the designaled representative and that is located at a source of which they are not owners or operators or the designated representative.
(1) Unless otherwise provided, the owners and operators of thi scurce and eaichAcd Rain unit at thesource shallt eep on site at the source each of the following documents fo e period of 5 years fromthe date the document is created. This period may be extended forcause. at any timepior to the end of p   years, Inwritig by the EPA or trwDEP:
(7) Each violatlo of a provision of 40 CFR Podrs 72.73, 74, 75,76. 77. and 78 by an Acd Rain source or Acid Rain unit. or by an owner or operator or designated representative of such source or unit shell be a separate violation of the Act.Effect on Other Authorities.
(i} The certificale of representation forthe designated reprensentative for the source and each Add Rain ursl at the source and all documents that demonstrate the truth ofthe stetements in the certificate of representatior.In accordance with Rule 62-214.350. F.A.C.: Provided that the certificate and documents shetl be retained on site at the sourcebeyond such 5-year period until such documents are superseded because of the submiltsion ofa new ceritficate ofrepresentation changing the designated representative; (1) All enissions monitoring information, in acc*rdance with 40 CFR Part 75, provided that to the "rent thait40 CFR Pait 75 provides fr a 3-year period for recordheoping. the 3-year period shall apply;,
No provision of the Acid Rain Program, an Acti Rain Part application.
(Si)Copies of allreports,   conmpliance certifcationes.
an Acid Rain Part, or an exemption under 40 CFR 72.7or 72.8 shall be constnred as: (1) Except as epmesry provided in ttle IV of"lhe Act. exampling or ex'ring the sowner end operaton; and, to the extent applicabl.
and other sutsmissionis and all records made or required under the Acid Rain Program; and.
the designated representative of an Acid Rain source or Acid Rain unit from conrliance with any other provision of the Act, including the provisions of dine I of the Act relating to Nations] Ambient Air Quality Standards or State Implemrentalion Plans;(2) Uriting the number of allowances a urit can hold; provided, that the number of allowances held by the urit shal not aftect the sources obligation to comply with any other provisions of the Act;(3) Requiring a change of any kind In any state law regulating electric utility rates and charges, affecting any state tow regarding such state regulation.
DEP Form No. 62-210.900(1Xa)- Form Effective: 3/161/08                                                               2 Progress Energy Florida, Inc.                                                                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                               Title V Air Operation Permit Renewal Page 39 of 54
or limiting such stlte reguteiton, inrcudieg any prudence review requirements urnder such slate law;(4) Modifying the Federal Power Act or affecting the aut0ority of the Federal Energy Regulatory Commission under the Federal Power Act; or.(5) Interfering with or Irnpaldrsg any program tor competitive bidding for power supply In a stale In whicf such program in eslablilsted.
 
f g h (not required for renewal application)
SECTION IV. ACID RAIN PART.
Number of hours unit operated In the six Unit ID# Description of the combustion unit months preceding initial applicatior STEP 4 For SOz Opt-in units only.In column -'" enter the unit IDa for every SO0 Opt-In unit Identified In columul "a" of STEP 2.For column "g" describe the combustion unit and attach Information and diagrams on the combustion unit's configuration.
Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1)
In column "h" enter the hours.DEP Form No. 62-210.900( )(a)- Form Effective:
STEP 3, Recordkeepina and Reporting Requirements (contj Conitnued.
3116/08 3 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 40 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1i STEP 5 For SO Opt-In units only.Voo required for 10ptin renewall applications.)
(iv) Copies of alt documents used to complete an Acid Rain Part application and any other submnissln under the Acid Rain Program or to Oemonstrate omplirace with therequirements of Me Acid Rain Program.
In column "i" enter the unit ID# for every SO 2 Opt-in unit Identified In column "a" (and In column. "f").For columns "j" through "n," enter the information required under 40 CFR 74.20-74-25 and attach all supporting documentation required by 40 CFR 74.20-74.25.
(2) The deslgnated representative of an Acid Rain source and each Acid Rain unit at the source shait submit the reports and compiance certillcatiorna required under the Acid Rain Program, inrluding those under 40 CFR Part 72, Subpart I, and 40 CFR Part 75.
STEP 6 For SO 2 Opt-n units only.Attach additional requirements, certify and sign.STEP 7 Read the certification statement; provide name, title, owner company name, phone, and e-mall address; sign, and date.j k I m n Current Current --Actual SO 0  Allowable 1985 Allowable SO, Promulgated Baseline or Alternative Emissions Rate SO 2 Emissions Emissions Rate SO 2 Emissions.
Liability.
Unit ID# Baseline under under Rate under under Rate under 40 CFR 74.20 40 CFR 74.22 40 CFR 74.23 40 CFR 74.24 40 CFR 74.25 (mmBtu) (Ibs/mmBtu) (Ibs/mmBtlu) (lbslmmfBtu) (lba/mmBtu) 2 4 5 A. It the combustion source seeks to qualify for a transfer of allowances from the replacement of thermal energy, a thermal energy plan as provided in 40 CFR 74.47 for combustion sources must be attached.B. A statement whether the combustion unit was previouzly an affected unit under 40 CFR 74.C. A statement that the combustion unit is not an affected unit under 40 CFR 72.6 and does not have an exemption under 40 CFR 72.7, 72.8, or 72.14.D. Attach a complete compliance plan for SO0 under 40CFR 72.40.E. The designated representative of the combustion unit shall submit a monitoring plan in accordance with 40 CFR 74.61. For renewal application, submit an updated monitoring plan if applicable under 40 CFR 75.53(b).F. The following statement must be signed by the designated representative or altemate designated representative of the combustion source: 'I certify that the data submitted under 40 CFR Part 74, Subpart C, reflects actual operations of the combustion source and has not been adjusted In any way." Signature I Date Certification (for designated representative or alternate designated representative only)I am authorized to make this on behan of tie owners and operators of the Add Rain source or Acid Rain units or which the rubmnission Is made. Icertify under penalty Ot Iaw Sat I have personallyeaMined, and am faretiar wia, the statements end Intmation submitted in this document and en itS asachmenta.
(1) Any person wntoknoweigly violates any requirement or Orothition of the Acid Rain"Prooram. a complete Acid Rain Part appication. an Acid Rain Part. or an exemption under 40 CFR 72. or 72.8, including any requirement for the payment of any penalty owed to the Uniled States, shall be subjectto enforcement pursuant to section 113(c) of theAct.
eased orn my inquiry os Item individuals with primary respnalit~ity for obaining thu ifonknaon.
(2) Any person who knowingly makes a talse. material statement in artyrecord, subrmdnslvn,       orreport under the Acid Rain Program shall be subjet to criminal enforcement purthirruttO section `113(c0) of the Act and18 U.S.C. 1001.
I crtify that the statements and informatlon are to the best of my knowledge and belief true. accurate, and complete.
(3) No oemnit revision shal easuse any violation of the requirements of the Acid Rain Program that occurs prior to the date that the revision takes effact.
I am aware that there are significant penalties for subititting false statements and Infonrmaton or omitting mqubied statemerts and information, including the possbility of fine or imprisonment.
(4) Each Acid Rain source and each Acid Rain unit shall meet the requirements of the Acid Rain Program.
Name Brenda E. Brickhouse I Title Director -Environmental Health and Safety Owner Company Name Florida Power Corporation dba Progress Energy Florida, Inc.Phone 727 820 5153 I E-mail address Brenda.brickhousetOpnmail.com Signature /---2C DEP Form No. 62-210.900(1)(a)-
(5) Any provisionrof the AcidRain Program that applies to an Acid Rain sJurce (inokdtna a provlslon appliahiloa to the designated representative of an Add Rain source) shall also apply to the owners and operators of such source andof the Acid Rain units at the source.
Form Effective:
(6) Any provision of the AcidRain Program that applies to an Acid Rain unit (including a provision epplicable to tre designated representative of an Acid Rain unit) shat also apply to the owners and operators of such urit. Except as provided under 40 CFR 72.44 (Phase I repowering extension plans) and 40 CFR 76.11 (NOx averaging plans), and except with regard to the requirements applicabte to units with a common stack under 40 CFR Part 75 (including 40 CFR 75.16, 75.17, and 75.18), the owners and operators exn the designated reproeuntative of one AiddRain unit shah not be liable for any violation by any other Acid Rain unit o( which they are not owners or operators or the designaled representative and that is located at a source ofwhich they are not owners or operators or the designated representative.
3/16108 4, Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 41 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions STEP 1 Indicate plant name, State, and ORIS code from NADB.if applicable STEP 2 (a) Standard annual average emission Imitallon of 0.50 IflhmBtu (for Phae I dry bottom wall-firod boilars)(b) Standard annual average emission lImitation ot o.45 tbImmetu (for PhAse(j tangentially fired boilersl(c) EPA-approved early eletion plan under 40 CFR 7 A through 12,31107 (also Indicate above emission limit specified In plan)d) Standard annual average emission limI.ttton of 1.40 lbmmBtu (Ifor Phasg dry bottom wall-fired bolters)(a) Standard annual average emission limitation of 0G4 IIbmmatu Ifor Pelit tangentially fired boilers)1I) Standard annual average emission Ihbtation of 0.88 tbimrnm tu (For cell burner boIlers)(g) Standard annual average emission limitation of 0.86 lblmmBtu (for cyclone boilers)(h) Standard annual average emission limitation of 0.81 Ib/mmBtu l(for vertically fired boilers)(I) Standard annual average emission limitation of 0.84 Ib/mmntu (for wet bottom boilers)(J) NO. Averaging Plan (include NO%Averaging form)(k) Common stack pursuant to 40 CFR 75.17(a)(2X1)(A)(check the standard emission limitation box above for most stringent lImitation appIlcable to any unit utilizing stack)(I) Common stack pursuant to 40 CFR 76.17(a)(2)(i)(B) with NO.AversgLng (check the NO.Averaging Plan box and include NO, Averaging form)EPA Form 7610-28 (12-03)United States Environmental Protection Agency OMB No. 2060-0258 Acid Rain Program Phase I! NOx Compliance Plan For more information, see instructions and refer to 40 CFR 76.11 NO. Compliance  
(7) Each violatlo of a provision of 40 CFR Podrs72.73, 74, 75,76. 77. and 78 by an Acd Rain source or Acid Rain unit. or by an owner or operator or designated representative of such source or unit shell be a separate violation of the Act.
-Page 1 This submission Is: [] New [E] Revised Page [] of Crystal River F1 628 Plant Name State ORIS Code Identify each affected Group I and Group 2 boiler using the boiler to# from NADB, If applicable, Indicate bolter type: "CiB" for cell burner. "C" for wcyclone.
Effect on Other Authorities.
"0DW" for dry bottom wall-fired, "r, for tangentially fired. "V" for vertically fired,=d-"W- for w"t bottom. the com lien. ution selected for .o-h unit.El~I yp / TyeT ITpeDW I /Typ DBW Typ Type__LI[][ W][][F-LI.D-Ml F-1 LI LI LI LI E-1 LI LI MI EI El LI C1 LI LI Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 42 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Crystal River Plant Name (from step "11 NO, Compliance
No provision of the AcidRain Program, an Acti Rain Part application. an Acid Rain Part, or an exemption under 40 CFR 72.7or 72.8 shall be constnred as:
-Page 2 Page n2 of R2 STEP 2, cont'd m) EPA-approved common stack apportionment me(hod pursuant to 40 CFR 7&.17 (t)()pIIXC), (a)(2X111t)(1) or (b)(2)(n) AFL include Phase It AEL Demonstrallon Period. Final AEL Petilton.
(1) Except as epmesry provided in ttle IV of"lheAct. exampling or ex'ring the sownerend operaton; and, to the extent applicabl. the designated representative of an Acid Rain source or Acid Rain unit from conrliance with any other provision of the Act, including the provisions of dine   Iof the Act relating to app*ceble Nations] Ambient AirQuality Standards or State Implemrentalion Plans; (2) Uriting the number of allowances a urit can hold; provided, that the number of allowances held by the urit shal not aftect the sources obligation to comply with any other provisions of the Act; (3) Requiring a change of any kind In any state law regulating electric utilityrates and charges, affecting any state towregarding such state regulation.or limiting such stlte reguteiton, inrcudieg any prudence review requirements urnder such slate law; (4) Modifying the Federal Power Act or affecting the aut0ority of the Federal Energy Regulatory Commission under the Federal Power Act; or.
or AEL Renewal ferm as approprlats)(o) Petition for AEL demonstrlaton period or final AEL under revieow by U.S. EPA ar demonstration perlod ongoing (p) Repowering extension plan approved or under review lD# IEl F7 Ei Li1 Li Li MI Li El Li STEP 3 Read the standard requirements and certificatton, enter the name of the designated representative, sign & date.Standard Requirements Genera. This source is subject to the standard requirements in 40 CFR 72.9 (consistent with 40 CFR 76.8(e)(1)(i)).
(5) Interfering with or Irnpaldrsg any program torcompetitive bidding for power supply In a stale In whicf such program in eslablilsted.
These requirements are listed in this source's Acid Rain Permit.Special Provisions for Early Election Units Nitrooen Oxides. A unit that Is governed by an approved early election plan shall be subject to an emissions limItation for NO. as provided under 40 CFR 76.8(a)(2) except as provided under 40 CFR T6.8(e)(lil).
STEP 4 For SOz Opt-in                      f                                                         g                                                     h (not required for units only.                                                                                                                                          renewal application)
Liabili .The owners and operators of a unit governed by an approved early election plan shall be liable for any violation of the plan or 40 CFR 76.8 at that unit. The owners and operators shall be liable, beginning January 1, 2000, for fulfilling the obligations specified in 40 CFR Part 77.Teirnination.
In column -'" enter                                                                                                                              Number of hours unit the unit IDa for                                                                                                                                operated In the six every SO0 Opt-In              Unit ID#                                     Description of the combustion unit                                   months preceding initial unit Identified In                                                                                                                                applicatior columul "a" of STEP 2.
An approved ealdy election plan shall be In effect only until the earlier of January 1, 2008 of January A of the calendar year for which a termination of the plan takes effect. If the designated representative of the unit under an approved early election plan fails to dernonsitrte complianic with the applicable emissions limitation under 40 CFR 76.5 for any year during the period beginning January 1 of the first year the early election takes effect and ending December 31. 2007. the permitting authority will terminate the plan. The termination will take effect beginning January I of the year after the year for which there is a failure to demonstrate compliance, and the designated representative may not submit a new early election plan. The designated representative of the unit under an approved early election plan may terminate the plan any year prior to 2008 but may not submit a new early election plan. In order Io terminate the plan, the designated representative must submit a notice under 40 CFR 72.40(d) by January 1 of the year for which the termination is to take affect, If an early election plan is terminated any year prior to 2000, the unit shall meet, beginning January 1. 2000, the applicable emissions limitation for NO, for Phase II units with Group I boilers under 40 CFR 76.7, If an early election plan Is terminaled on or after 2000, the unit shall meet, beginning on the effective dale of the termination, the applicable emissions limitation for NO, for Phase II units with Group 1 boilers under 40 CFR 76.7.CerMfIcation I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission Is made. I certify under penalty of law that I have personally examined, and am familiar with, the statements and information submitted in this document and all Its attachments.
For column "g" describe the combustion unit and attach Information and diagrams on the combustion unit's configuration.
Based on my Inquiry of those Individuals with primary responsibility for obtaining the Information.
In column "h" enter the hours.
I certify that the statements and information are to the best of my knowledge and belief true, accurate.
DEP Form No. 62-210.900( )(a)- Form Effective: 3116/08                                                                 3 Progress Energy Florida, Inc.                                                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                              Title V Air Operation Permit Renewal Page 40 of 54
and complete.
 
I am aware that there are significant penalties for submitting false statements and information or omitting required statements and Information.
SECTION IV. ACID RAIN PART.
Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1i STEP 5 j                            k                      I                      m                        n For SO Opt-In units only.
Voo required for                                                                                                                       Current                  Current    --
10ptin renewall                                                                 Actual SO0        Allowable 1985            Allowable SO,            Promulgated applications.)                                   Baseline or Alternative        Emissions Rate        SO2 Emissions            Emissions Rate            SO 2 Emissions.
Unit ID#                Baseline under                    under              Rate under                  under                Rate under In column "i" enter                                   40 CFR 74.20                40 CFR 74.22          40 CFR 74.23            40 CFR 74.24            40 CFR 74.25 the unit ID# for (mmBtu)                    (Ibs/mmBtu)          (Ibs/mmBtlu)            (lbslmmfBtu)            (lba/mmBtu) every SO 2 Opt-in unit Identified In column "a" (and In column. "f").           2 For columns "j"       4 through "n," enter the information         5 required under 40 CFR 74.20-74-25 and attach all supporting documentation required by 40 CFR 74.20-74.25.
STEP 6                 A. It the combustion source seeks to qualify for a transfer of allowances from the replacement of thermal energy, a thermal energy plan as provided in 40 CFR 74.47 for combustion sources must be attached.
B. A statement whether the combustion unit was previouzly an affected unit under 40 CFR 74.
For SO 2 Opt-n        C. A statement that the combustion unit is not an affected unit under 40 CFR 72.6 and does not have an units only.                 exemption under 40 CFR 72.7, 72.8, or 72.14.
D. Attach a complete compliance plan for SO0 under 40CFR 72.40.
Attach additional      E. The designated representative of the combustion unit shall submit a monitoring plan in accordance with 40 requirements,              CFR 74.61. For renewal application, submit an updated monitoring plan if applicable under 40 CFR 75.53(b).
certify and sign.      F. The following statement must be signed by the designated representative or altemate designated representative of the combustion source: 'I certify that the data submitted under 40 CFR Part 74, Subpart C, reflects actual operations of the combustion source and has not been adjusted In any way."
Signature                                                                                    I Date STEP 7                  Certification (for designated representative or alternate designated representative only)
Iam authorized tomake this sub*nssion on behan of tie owners and operators of the Add Rain source or Acid Rain units or which the rubmnission Read the              Is made. Icertify under penalty OtIaw Sat I have personallyeaMined, and am faretiar wia, the statements end Intmation submitted in this certification          document and en itSasachmenta. eased ornmy inquiry os Item individuals with primaryrespnalit~ity for obaining thu ifonknaon. Icrtify that the statement; provide      statements and informatlon are to the best of my knowledge and belieftrue. accurate, and complete. I am aware that thereare significant penalties name, title, owner      for subititting false statements and Infonrmaton or omitting mqubied statemerts and information, including the possbility of fine or imprisonment.
company name, phone, and e-mall address; sign, and date.                   Name          Brenda E. Brickhouse                                      I Title      Director - Environmental Health and Safety Owner Company Name                  Florida Power Corporation dba Progress Energy Florida, Inc.
Phone        727 820 5153                            IE-mail address      Brenda.brickhousetOpnmail.com Signature       .Date*A                                                                                  /---2C DEP Form No. 62-210.900(1)(a)-      Form Effective: 3/16108                                                                4, Progress Energy Florida, Inc.                                                                                                                        Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                            Title V Air Operation Permit Renewal Page 41 of 54
 
SECTION IV. ACID RAIN PART.
Federal Acid Rain Provisions United States Environmental Protection Agency                                                                        OMB No. 2060-0258 Acid Rain Program Phase I! NOx Compliance Plan For more information, see instructions and refer to 40 CFR 76.11                              NO. Compliance        - Page 1 This submission Is:        []    New            [E]    Revised                            Page            []    of STEP 1 Indicate plant name, State,        Crystal River                                                                      F1                628 and ORIS code from NADB.
if applicable                      Plant Name                                                                          State            ORIS Code STEP 2                            Identify each affected Group I and Group 2 boiler using the boiler to# from NADB,If applicable, Indicate bolter type: "CiB" for cell burner. "C" forwcyclone. "0DW" for dry bottom wall-fired, "r, for tangentially fired. "V"for vertically fired,
                                            =d-"W- for w"t bottom. Ind*sate the com lien. ution selected for .o-h unit.
I yp/    TyeT              ITpeDW          I      /Typ    DBW            Typ                    Type__
El~
(a) Standard annual average emission Imitallon of 0.50 LI[][                                        W][][
IflhmBtu (for Phae I dry bottom wall-firod boilars)
(b) Standard annual average emission lImitation ot o.45 tbImmetu (for PhAse(j tangentially F-                                                                                          LI.
fired boilersl (c) EPA-approved early eletion plan under 40 CFR 7 A through 12,31107 (also Indicate above D-                                          Ml                                          F-1 emission limit specified In plan) d) Standard annual average emission limI.ttton of1.40                                     LI lbmmBtu (Ifor Phasg dry bottom wall-fired bolters)
(a) Standard annual average emission limitation of 0G4 IIbmmatu Ifor Pelit tangentially LI                                                                    E-1 fired boilers) 1I)Standard annual average emission Ihbtation of 0.88 tbimrnmtu (Forcell burner boIlers)
LI (g) Standard annual average emission limitation of 0.86 lblmmBtu (for cyclone boilers)
LI                      LI                    MI (h) Standard annual average emission limitation of 0.81               EI                                                                LI Ib/mmBtul(for vertically fired boilers)
(I) Standard annual average emission limitation of 0.84                                   El                                                                  LI Ib/mmntu (for wet bottom boilers)
(J)NO. Averaging Plan (include NO%
Averaging form)
(k) Common stack pursuant to 40 CFR 75.17(a)(2X1)(A)
(check the standard emission C1                                            LI limitation box above for most stringent lImitation appIlcable to any unit utilizing stack)
(I) Common stack pursuant to 40 CFR 76.17(a)(2)(i)(B) with NO.
AversgLng (check the NO.
LI Averaging Plan box and include NO, Averaging form)
EPA Form 7610-28 (12-03)
Progress Energy Florida, Inc.                                                                                                                Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                    Title V Air Operation Permit Renewal Page 42 of 54
 
SECTION IV. ACID RAIN PART.
Federal Acid Rain Provisions NO, Compliance - Page 2 Crystal River Page n2      of      R2 Plant Name (from step "11 STEP 2, cont'd lD#                                           IEl m) EPA-approved common stack apportionment me(hod pursuant to 40 CFR 7&.17 (t)()pIIXC), (a)(2X111t)(1) or (b)(2)
(n) AFL include Phase ItAEL Demonstrallon Period. Final AEL                                F7                                        Ei                    Li1                  MI Petilton. or AEL Renewal ferm as approprlats)
(o) Petition for AEL demonstrlaton period or final AEL under revieowby U.S. EPA ar Li demonstration perlod  ongoing (p) Repowering extension plan            Li                                                                El                   Li                    Li approved or under review STEP 3                            Standard Requirements Read the standard requirements and                  Genera. This source is subject to the standard requirements in 40 CFR 72.9 (consistent with 40 CFR 76.8(e)(1)(i)).
certificatton, enter the          These requirements are listed in this source's Acid Rain Permit.
name of the designated representative, sign & date.      Special Provisions for Early Election Units Nitrooen Oxides. A unit that Is governed by an approved early election plan shall be subject to an emissions limItation for NO. as provided under 40 CFR 76.8(a)(2) except as provided under 40 CFR T6.8(e)(lil).
Liabili . The owners and operators of a unit governed by an approved early election plan shall be liable for any violation of the plan or 40 CFR 76.8 at that unit. The owners and operators shall be liable, beginning January 1, 2000, for fulfilling the obligations specified in 40 CFR Part 77.
Teirnination. An approved ealdy election plan shall be In effect only until the earlier of January 1, 2008 of January A of the calendar year for which a termination of the plan takes effect. If the designated representative of the unit under an approved early election plan fails to dernonsitrte complianic with the applicable emissions limitation under 40 CFR 76.5 for any year during the period beginning January 1 of the first year the early election takes effect and ending December 31. 2007. the permitting authority will terminate the plan. The termination will take effect beginning January I of the year after the year for which there is a failure to demonstrate compliance, and the designated representative may not submit a new early election plan. The designated representative of the unit under an approved early election plan may terminate the plan any year prior to 2008 but may not submit a new early election plan. In order Io terminate the plan, the designated representative must submit a notice under 40 CFR 72.40(d) by January 1 of the year for which the termination is to take affect, If an early election plan is terminated any year prior to 2000, the unit shall meet, beginning January 1. 2000, the applicable emissions limitation for NO, for Phase II units with Group I boilers under 40 CFR 76.7, If an early election plan Is terminaled on or after 2000, the unit shall meet, beginning on the effective dale of the termination, the applicable emissions limitation for NO, for Phase II units with Group 1 boilers under 40 CFR 76.7.
CerMfIcation I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission Is made. I certify under penalty of law that I have personally examined, and am familiar with, the statements and information submitted in this document and all Its attachments. Based on my Inquiry of those Individuals with primary responsibility for obtaining the Information. I certify that the statements and information are to the best of my knowledge and belief true, accurate. and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and Information.
including the possibility of fine or Imprisonment.
including the possibility of fine or Imprisonment.
EPA Form 7610-28 (12-03)Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 43 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Florida Department of Environmental Protection Phase II NOx Averaging Plan For more Information, refer to 40 CFR 76.11 This submission is: Ii New x x Revised STEP 1 Identity the units participating in this averaging plan by plant name, state, and boiler ID# from MADS. In column (a), fill in each units applicable emission limitation from 40 CFR 76.5, 76.6, or 76.7.In column (b), assign an altemative contemporaneous annual emissions limitation In lb/mmBtu to each unit. In column (c), assign an annual eat input limitaUon In mmBtu to each unit Continua to page 3 if necessary.(a) (b) (ci Plant Name Ait. Contemp.Emission Emission Annual Heat Input State ID# Limitation Limitation Limit Asheville N,4 6 U.53 , 1I0,i, (Asheville NL; z 0.4b U.10 I.bzt51j 6,185,400 Cape I-ear NU b U.40 6.1U5,4 7,612,800 H. I-. Lee -T- -U7 U.60 U, tou78,U9 H. F. Lee NU; -OU.45 U0 5,4J epU H. F. Lee rNU 3 U U.7/ 1J.411 .=U STEP 2 Use the formula to enter the Btu.weighted annual emission rate averaged over the units If they are operated in accordance with the proposed averaging plan and the Btu-weighted annual average emission rate for the same units If they are operated in compliance with 40 CFR 76.5, 76.6, or 76.7. The former must.be less thanor equal to the latter.Btu-welghted annual emission rate averaged over the units if they are operated In accordance with the proposed averaging plan 0.44 er, =, Hx Btu-weighted annual average emission rate for same units operated in compliance with 40 CFR 76.5, 76.6 or 76.7 0.44< [R[R, xHI,]ynj=l Hji Where, Ru RHI HIj Alternative contemporaneous annual emissions limitation for unit i. in 16lmmBtu, as specified in column (b) of Step 1;Applicable emission limitation for unit I, in Ib/mmBtu, as specified In column (a) of Step 1: Annual heat input for unit i, in mmBtu, as specified in column (c) of Step 1;Number of units In the averaging plan DEP F'orrn No. 62-210.900(i)(a)1.
EPA Form 7610-28 (12-03)
Effective:
Progress Energy Florida, Inc.                                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                  Title V Air Operation Permit Renewal Page 43 of 54
31-16010 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 44 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions STEP 3 Mark one of the two options and enter dates.STEP 4 Read the special provisions and certification, enter the name of the designated representative.
 
and sign and date.Crystal River Power Plant Piant Name (from Step 1) 1 0 X This plan is effective for calendar year 2010 through calendar year 2014 unless notification to terminate the plan is given.Q Treat this plan as 0) identical planseach effective for one calendar year for the following calendar years: .. .. .. .and __ unless notification to terminate one or more of these plans is given.Special Provisions Emission Limitations Each affected unit in an approved averag in plan. is in compliance with the Acid Rain emission limitation for NO, under the plan only if the following requirements are met: For each unit, the unit's actual -annual average emission rate for the calendar year, in rnmBtu is less than or equal to its alternative contemporaneous annual emission limitation in the averaging plan, and (a) For each unit with an alternative contemporaneous emission limitation less stringent than the applicable emission limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year does not exceed the annual heat Input limit in the ave in plan, (b) For each unigt wt an eitemailve contemporaneous emission limitation more stringent than the applicable emission limittion in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year is not less than the annual heat input limit in mte averaging plan, or (ii) If one or more of&deg;the units does not meet the requirements of (i), the designated representative shall demonstrate, in accordance with 40 CFR 76.11(d)(1  
SECTION IV. ACID RAIN PART.
)(ii)(A) and (B)that the actual Btu-weighted annual average emission rate for the units in the p len is oless than or equal 1o the Btu-weighted annual average rate for the same units had they each been operated, duri ng the same period of timein compliance with the applicable emission limitations in 40l CFR 75.5, 75.5, or 76.7.(iii) If there is a successful grou'p showing of compliance under 40 CFR 76,11(d)(1)(ii)(A) and (B) for a calendar year then all unitesn the averaging plan shall be deemed to be in compliance for thai year with their alternative contemporaneous emission limitations and annual heat Input limits under (i).The owners and operators of a unit governed by an approved averaging plan shall be liable for any violation of the plan or this section at that unit or any other unit in the plan, including liability forfulfilling the obligations specified in part 77 of this chapter and sections 113 and 41 -of the Act.Termination The designated representative may submit a notification to terminate an approved averaging plan, in accordance with 40 CFR 72.40(d).
Federal Acid Rain Provisions Florida Department of Environmental Protection Phase II NOx Averaging Plan For more Information, refer to 40 CFR 76.11 This submission is:   Ii   New                 x Revised (a)                  (b)                  (ci STEP 1                                       Plant Name Ait. Contemp.
no later than October I of the calendar year for which the plan is to be terminated.
Identity the units participating in this averaging plan by                                                         Emission          Emission          Annual Heat Input plant name, state,                                               State      ID#   Limitation        Limitation              Limit Asheville              N,4                      6      U.53 1I0,i,              ,      (
Certification I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission is ma de. I certify under penalty of law that F have personally examined and am familiar with, the statements and information submitted in this document and all Its altachments.
and boiler ID# from MADS. In column (a),
Based on my Inquiry of those individuals with primary responsibility for obtaining the information, I certify that the statements and Information are to the best of mf knowledge and belief true, accurate, and complete.
fill in each units                     Asheville                NL;        z    0.4b              I.bzt51j U.10 applicable emission limitation from 40 CFR 76.5, 76.6, or 76.7.
I am aware that there are significant penalties for submitting false statements and information or omitting required statements and information, including the possibility oftfine or imprisonment.
In column (b), assign an                                                                                               6,185,400 altemative contemporaneous             Cape I-ear              NU          b                  U.40                  6.1U5,4 annual emissions limitation In lb/mmBtu                                                                                                 7,612,800 to each unit. In column               H. I-. Lee (c), assign an annual                                                     -T-    -U7            U.60U,                tou78,U9 eat input limitaUon In mmBtu to each unit                 H. F. Lee                NU;      -      OU.45          U0                    5,4J  epU Continua to page 3 if necessary.                             H. F. Lee                rNU        3    U              U.7/                  1J.411 .=U Btu-welghted annual emission rate                          Btu-weighted annual average STEP 2                                      averaged over the units if they are                        emission rate for same units Use the formula to enter the                operated In accordance with the                            operated in compliance with 40 Btu.weighted annual                          proposed averaging plan                                    CFR 76.5, 76.6 or 76.7 emission rate averaged over the units If they are operated in accordance with the proposed averaging plan and the Btu-weighted annual average emission rate                           0.44                                                          0.44 for the same units If they are operated in compliance with 40 CFR 76.5, 76.6, or 76.7. The former must.
Name Brenda E. Brickhouse Signature f--' f -, -Date f g,5 ]c.. .DEP Form No. 62-210.900(1Xa)i.
be less thanor equal to the latter.                                                                                     <                          [R[R, xHI,]
Effective:
ynj=l     Hji er,      =,  Hx Where, Ru             Alternative contemporaneous annual emissions limitation for unit i. in 16lmmBtu, as specified in column (b) of Step 1; RHI            Applicable emission limitation for unit I, in Ib/mmBtu, as specified In column (a) of Step 1:
3161/08 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 45 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions Crystal River Power Plant Plant Name (from Step 1)STEP 1 Continue the Identlflcation of units from Stop 1, page 1, here.(a) (b) (c)Alt.Contemp.Eislsion Emission Annual Heat Input Plant Name State ID# Umitation Limitation Limit Mayo NC I A 0.46 0.15 16,685,025 Mayo NC IB 0.46 0.1.5 16,685,025 H.B. Robinson SC 1 0.40 0.525 12,879,540 Roxboro NC 1 0.46 0.145 16,254,975 Roxboro NC .2 0.40 0.145 32,789,S49 Roxboro NC 3A 0.46 0.235 17,651,860 Roxboro NC 3B 0.46 0.235 17,651,860 Roxboro NC 4A 0.46 0.225 17,928,281 Roxboro NC 4B 0.46 0.225 17,928,281 L.V. Sutton NC 1 0.40 0.605 6,536,531 L.V. Sutton NC 2 0.46 0.605 6,725,250 L.V. Sutton NC 3 0.46 0.50 28,232,325 Weatherspoon NC 1 0.46 1.00 3,746,925 Weatherspoon.
HIj              Annual heat input for unit i, in mmBtu, as specified in column (c) of Step 1;
NC 2 0.46 1.00 3,798,165 Weatherspoon NC 3 0.40 0.65 6,141,480 Crystal River FL 1 0.40 0.57 37,112,400 Crystal River FL 2 0.40 0.57 42,602,400 Crystal River FL 4 0.46 0.59 79,385,400 Crystal River FL 5 0.46 0.59 74,334,600 DEP Form No. 62-210.900(i)(a)1.
Number of units In the averaging plan DEP F'orrn No. 62-210.900(i)(a)1.
Effective:
Effective: 31-16010 Progress Energy Florida, Inc.                                                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                                            Title V Air Operation Permit Renewal Page 44 of 54
3/16/08 3 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 46 of 54 SECTION IV. ACID RAIN PART.Federal Acid Rain Provisions rysta v-er Power Ilant Plant Name (from Step 1)STEP I Continue the Identification of units from Stop 1, page 1, here.(a) (b) (c)All.Contemp. Annual Heat Input Emission Emission Limit Plant Name State ID# Limitation Limitation 4 .4- 4 .4.4 .4- 4 +I 4- +DEP Foffn Na. 62-210.900(l)(a)l.
 
Effective:
SECTION IV. ACID RAIN PART.
3/16108 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 47 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions Operated by: Florida Power Corporation dba Progress Energy Florida Plant: Crystal River Power Plant ORIS Code: 628 The emissions units below are regulated under the Clean Air Interstate Rule.EU No. EPA Unit ID# Brief Description 001 1 Fossil Fuel Steam Generator (FFSG) Unit 1 002 2 FFSG Unit 2 003 5 FFSG Unit 3 004 4 FFSG Unit 4 1. Clean Air Interstate Rule Application.
Federal Acid Rain Provisions Crystal River Power Plant Piant Name (from Step 1)                                           1 0   X This plan is effective for calendar year         2010             through calendar year STEP 3                                2014                   unless notification to terminate the plan is given.
The Clean Air Interstate Rule Part Form submitted for this facility is a part of this permit. The owners and operators of these CAIR units as identified in this form must comply with the standard requirements and special provisions set forth in the CAIR Part Form (DEP Form No. 62-210.900(1)(b))
Mark one of the two options                      Q Treat this plan as 0) identical planseach effective for one calendar year for the following and enter dates.                  calendar years:           ..       ..       ..       . and __       unless notification to terminate one or more of these plans is given.
dated March 16, 2008, which is attached at the end of this section. [Chapter 62-213, F.A.C.and Rule 62-210.200, F.A.C.]Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 48 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions
STEP 4                            Special Provisions Read the special                  Emission Limitations provisions and certification, enter the name of the              Each affected unit in an approved averag in plan. is in compliance with the Acid Rain emission designated representative. and    limitation for NO, under the plan only if the following requirements are met:
* Clean Air Interstate Rule (CAIR) Part For more Infonrnaton.
sign and date.
see n0tNuSc&ons and refer l 40 CFR 96.121,98.122,96.221, 96.222, 96.321 and 96.322; and Rule 62-296.470, F.A.C.This vuxisaloon is: 03 New fffRviaed 13"Renewal STEP 1 Plant Name: CRYSTAL RIVER POWER PLANT State: Florid ORIS or EtA Plant Code Ideiffy the source by -2 plant name and ORI8 or EIA plant code STEP 2 In column "a" enter the unit I10 for every CAIR unit at the CAIR source.In columns "b," "c," and "d," Indicate to which CAIR program(s) each unit Is subject by placing an "X" in the column(s).
For each unit, the unit's actual -annualaverage emission rate for the calendar year, in rnmBtu is less than or equal to its alternative contemporaneous annual emission limitation in the averaging plan, and (a) For each unit with an alternative contemporaneous emission limitation less stringent than the applicable emission limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year does not exceed the annual heat Input (b) limit For  each in the aveunigtwt plan, in    an eitemailve contemporaneous emission limitation more stringent than the applicable emission limittion in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year is not less than the annual heat input limit If one averaging (ii) in mte      or more of&deg;the plan,units or does not meet the requirements of (i), the designated representative that                shall demonstrate, the actual Btu-weighted    annualin average accordance with 40 emission    CFR rate for 76.11(d)(1 the units in)(ii)(A) andis(B) the plen      oless than or equal 1o the Btu-weighted annual average rate for the same units had they each been operated, duri ng the same period of timein compliance with the applicable emission limitations in 40l CFR 75.5, 75.5, or 76.7.
* For new units, enter the requested informntlon in columns "e" and "f.a b c d e f Unit Will Unit will Unit will hold nitWgen hold sulfur hold NOx Ozone New Units New Units adds (NOx) dioxide (SO2) Season aalwlowe aewances afwinoes Expected F In accordance In accordance In aordance Commence Monitor with 40 CFR wtih 40 CFR with 40 CFR Ceruication Unit ID# 96.106(c1) g96.206(cXl) 96.306(cXl)
(iii) If there is a successful grou'p showing of compliance under 40 CFR 76,11(d)(1)(ii)(A) and (B) for a calendar year then all unitesn the averaging plan shall be deemed to be in compliance for thai year with their alternative contemporaneous emission limitations and annual heat Input limits under (i).
Operation Daft Oeadline I or E.U.-01 x x x 2 or E.U.-002 5 or E.U.-003 X X X 4 or E.U.-004 0 DEP Form No. 62-210.900(i)(b)
The owners and operators of a unit governed by an approved averaging plan shall be liable for any violation of the plan or this section at that unit or any other unit in the plan, including liability forfulfilling the obligations specified in part 77 of this chapter and sections 113 and 41 -of the Act.
-Formi Effectve:
Termination The designated representative may submit a notification to terminate an approved averaging plan, in accordance with 40 CFR 72.40(d). no later than October I of the calendar year for which the plan is to be terminated.
3/16M8 I m Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 49 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions 0 CRYSTAL RIVER POWER PLANT I plaruNormn (USTEP1)STEP 3 CAIR NOx ANNUAL TRADING PROGRAM Rad ihe stwx d CAmR Padt Reaimmmt.requirements.
Certification I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission is ma de. I certify under penalty of law that F have personally examined and am familiar with, the statements and information submitted in this document and all Its altachments. Based on my Inquiry of those individuals with primary responsibility for obtaining the information, I certify that the statements and Information are to the best of mf knowledge and belief true, accurate, and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and information, including the possibility oftfine or imprisonment.
(1) Thi CAIR dod represnlebe of each CAIR NOR scums sld each CAIR NOx rai at ft aawrn sl W) hI M OEPs a pnlelte and celied CAIR Part form under 40 CFR 96.122 and Rule 62-296.470.
Name       Brenda E. Brickhouse Signature     f--'       f   -, -Date                     .                        g,5 ]c..
FAC., in ith Om dede specidied in Rue 62-213.42D, FAC.; and (2) The oners and operaln' t eich CAIR NO. souc and auch CAIR NO. unt am the scure 9Who a CAR Part d Mu Te V qaIhqpg issued by #* DEP uwder 40 CFR Padl 96. SiupM CC, and opena M souc and the u n i i wth such CAIR Monitonf .Recorft .and Reoordkeeolna Reautmnienta.
DEP Form No. 62-210.900(1Xa)i.
(1) The owners mid operatml.
Effective: 3161/08 Progress Energy Florida, Inc.                                                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Air Operation Permit Renewal Page 45 of 54
end Mt CAIR des- nale repesernll of each CAIR NO sucue aind each CAIR NOr at ft auew diai Coon lsyw modnaitlrg.
 
repornMiand requumnt of 40 CFR Pat 906. Subpat Ward Rule 02.29.470.
SECTION IV. ACID RAIN PART.
F.AC.(2)The ensmsoms n uasmmrnns recorded and repored In accordance wh 40 CFR Po 96, HK ld be used to delem ee oenimi- by ch CAR NOx nul- I CAR NOx rnsn RPettnen.Emisslon Reaukements.
Federal Acid Rain Provisions Crystal River Power Plant Plant Name (from Step 1)
(1) As of ft -Innce rimu er deene tra condol peeod, the ownam and a edi CARNO mideaAAIRN OR W at Mtsuscwedaldhold infu acuree ceplanoacousnut, CAIR NO 4 dloomies avelable fo cnnyence dedualona for t Mu hio perlod uider 40CM 95.154(a) h nanewait fbIlsdun muhinaihibNORi amwslor'Mu nib pearldfrornalCAJR NOR mlatatfteu 506w.dean6ld I accordance wmi 40 CFR Pall o. S n HK 2) ACAIR NOx wrllid be oeathd the Mumquksmsnl d tide.psz-waph (I) toh NO% Requiremens atnn fM ber of Jumy 1. 20M.or f d 1ehi for enesof Mufts niesmnilot ,rtd1a8 -requiremif uider 40 CFA 96.170(bX1) or (2) and foreach --, pertod asftim .(3) A CAIR NOA m*ance slidl not be deduded. bo mIpIlm i Muf under par-a ;ph (1) d tie NOR RAqunmitw, fo a..i .parid ia imii yest eorihe ndwe bwhich i CAIR NO xa i b ie ioccale (4) CAIR NOx adlman OWil be held in. deduCld from. or tranele io or Mmao i CAIR NO Aowaim Ttadh ymm t hi acrdance vmh 40 CFR Pt 96. Subart FF and GG (5) A CAIR NOA doeaicelis a Unied to ant one ton ao NO in aci a ne with ftMu CAIR NOx Arniui Trafi Ptuin. No haM CAR NOR Annual Traing Progamn, Mu CAIR oran ide 40 CR95.10w m nopo a law beto Ibat Mu of Mfu Of or VMu UnbEd Steels io amni* or birt sch sulhoezllon (6) A CAIR NO allomance does no corslbde a propety ofth (7) Upon byfte Adrntabo under 40 CFR 95, Subpart EE. FF. r GGO, ams u acaon, b .lsr. or dedtcdo of aCAR NOx cna hio or frtm a CAIR NOR unt's compliance accnt Is' Ficorp aulhd matonoy In any CAIR Pamt of OMu same. Sel hdde Me CAIR NOR mEt E e Emissions ReoieMenIs.
(a)         (b)             (c)
I a CAR NOR so-ce ernis NOx uding any oonh parod in m olto CAu R NOh .b l (1) The Oreers and operaor, ao fMurce and easch CAJR NOR unita Muf sme aunmrdered.
STEP 1 Alt.
CAIR NOR 4 slowanboss rufo f dedubion unde 40 CFR 96.154(d(1) and pay any fne. penay, ora nmma or md any u r a. b sam videllona, under It Clean AirAct or appktafrle sate low. and M2 Each lon of such excess aridsalon arid each day of such car" period dial consitulsa separate violation of 40 CFR Pert 96. Subpart AA ft Clean Air Act. sand OPicste SIRe 10W..Be n and Reoftnm Reirements.
Continue the                                                                          Contemp.
(1) Unless otuwise provided.
Identlflcation of                                                          Eislsion   Emission     Annual Heat Input units from Stop 1,          Plant Name                 State         ID# Umitation   Limitation         Limit page 1, here.
Mheowwrs and operatorsdofe CAR NOR scums and each CAR NO. unk at El scum slMW keep on sOte a Mhesuroe eacho. eiM Iou ng doceunla brora pwaod of S torn Mt d Mu docum l os crauld. Trl pearod may be foed r causm, anne beore Mu ed c 5 f m n, ,melng IbyMu DEP o*rf AdMtn .0) The, -erh1wofapreawwJ unide40 CAR 96.113 f Uw CAIR daeignso represenwive r ft scums end each CAR NOR uit at ft source aid all donmincels at dnnsab Mu "'utdV ofto I -m-ds hinu One ,10,1c o alrepeuentaticnprode Wv at Mu csth e s , mi 11ad doceaunle slibe 'abhe n siebaltie soure. beyoid such Syserpemod till such dooorenhi ar superseded bernie is Mu ettinbaesion of a new ,e 1c a11 epeof 1 under 40 CFR 96 113 dhhngi Mu CAIR deielnabd teprosenbtdWo Ol) AM m a notog It nemti, in raccodance w1i40 CFR Pawt9 9, Sutpml H.K afkpMtpu.
Mayo                   NC             IA    0.46       0.15         16,685,025 Mayo                   NC             IB     0.46       0.1.5         16,685,025 H.B. Robinson         SC             1     0.40       0.525         12,879,540 Roxboro               NC             1     0.46       0.145         16,254,975 Roxboro               NC           .2     0.40       0.145         32,789,S49 Roxboro               NC             3A     0.46       0.235         17,651,860 Roxboro               NC             3B     0.46       0.235         17,651,860 Roxboro               NC             4A     0.46       0.225         17,928,281 Roxboro               NC             4B     0.46       0.225         17,928,281 L.V. Sutton           NC             1     0.40       0.605         6,536,531 L.V. Sutton           NC             2     0.46       0.605         6,725,250 L.V. Sutton           NC             3     0.46       0.50         28,232,325 Weatherspoon           NC             1     0.46         1.00         3,746,925 Weatherspoon.         NC             2     0.46       1.00         3,798,165 Weatherspoon           NC             3     0.40       0.65         6,141,480 Crystal River         FL             1     0.40       0.57         37,112,400 Crystal River         FL             2     0.40       0.57         42,602,400 Crystal River         FL             4     0.46       0.59         79,385,400 Crystal River         FL             5     0.46       0.59         74,334,600 DEP Form No. 62-210.900(i)(a)1.
prodded h M e ! R Per 06Suapet 14,prvide.
Effective: 3/16/08                                             3 Progress Energy Florida, Inc.                                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                      Title V Air Operation Permit Renewal Page 46 of 54
forea 3-V-rperiod fo socriueephirg Mu 3-yw- perld helWly.(11) Copies ofall reports. ooniqtabn-ce welldreid
 
~sulier s ubsaoeend al meodsnde or required uider die CAIR NOR Annua Treft Proponi v) Copis at1 dolacnte uaednli o e nlo t e CAIR Pm iorm and any olier mlesibsio unde rie CAIR NO, Annual Trafi Provanonto dmondie -, nce -wl M rw eem nw e atCAIR NOx Ania Trsin ProemL (2) The CAIR dasignaod represento's.
SECTION IV. ACID RAIN PART.
of a CAR NOx soure. nd each CAIR NO. atr at Mu w-. sclu subtn* f % under Mu CAR NO Trang Prog.
Federal Acid Rain Provisions rysta   v-er Power Ilant Plant Name (from Step 1)
w der4o CFR Pt 6 SeAd9 p H DEP Form No. 02-210.900(1 Xb) -Form311600 2 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 50 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions 10 CRYSTAL RIVER POWER PLANT Plant Momni Mfom STEP 1)STEP 3.ConUnued UaI.(1) EuIi CAR NOx Wju=e and each CAIR NOx unit sha t meet of thqulnm'ml dime CAIR NO 8 Annual Troun Piopam (2) Any provion o Ie CAIR NOx Annual Tradn Piroganie mt i0 a CAIR NOx a xmie CAIR fe Ca CR NO, souce alo appylaf towns and operas o such source ad ofi CAR NOA al ourc.(3) Any provision o it CAR NO, Annarl Phroarn Pu appies to a CAR NOHwx w or to CAR prsenmive da CAIR NOx urt &W abo apply to the owners ard opera; s of such uit.Efctd on O00e Authodfies No prvision of die CAR NO, Annual Tradng Progrm a CAR oran empdon wider 40 CFR .O1 " oh be o daa me or eaarogudt fhsowne and opemrto and ie CAIR designated presamadve, of a CAIR NO, swim or CAR NOx unit frm compliance vant army om Is u apcl d Stlae Ilnmrton Pan. a lederally mnforable permi or do Ciem AIr Ac.CAIR SO TRADING PROGRAM CNR Part Roursments.
STEP I                                                                           (a)           (b)             (c)
(1) The CAIR desiged reprevendsae of each CAIR S(h aource and each CAIR S01 unit at th source sIi: 0) Subnt bI DOEP a npleme aind c'lled CAJR Part forn under 40 CFR 96.222 and Rule 82-M.4 FAC.. In a c m P dumIll specillied In Rule 62-213.4M0.
All.
FAC.: arid (i) (2) Th owners ad operatoe d eac CNR soume and each CAR SO unat the so se al a CAIR t Me V operalng permt Ismed by fth DEP under 40 CFR Part 96. CCC. for t soue and operat so ad each CAR rad In-I' idilli si CAR Pat Monftorimn.
Continue the                                                                                Contemp. Annual Heat Input Identification of                                                            Emission       Emission           Limit units from Stop 1,            Plant Name                   State     ID#   Limitation     Limitation page 1, here.
Reoortino.
4          .4-     4           .4.
and Recordkeedona ReaWrements.
4         .4-     4           +
(1) Rhe oners ard operatorl, and Pue CAIR designled repreeenalve, of each CAIR S0 souce and each SOh CAIR unit at me aource 09 wmplyiti reporft. and racordkeepift reqirements of 40 CFR Part 0,Subpart HH. and Rule 62-298.470.
I           4-             +
FAC.(2) The emIsna meneement recorded and up otd i n accordance whlh 40 CFR Part 96. Subpart IFl sll be ued to deer corpllaice by each CAIR SO 8 source wit hmhe oUowfg CAR SOQ Ensalon Raqukernents.
DEP Foffn Na. 62-210.900(l)(a)l.
Effective: 3/16108 Progress Energy Florida, Inc.                                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                          Title V Air Operation Permit Renewal Page 47 of 54
 
SECTION V. CAIR PART.
Clean Air Interstate Rule Provisions Operated by: Florida Power Corporation dba Progress Energy Florida Plant: Crystal River Power Plant ORIS Code: 628 The emissions units below are regulated under the Clean Air Interstate Rule.
EU No.       EPA Unit ID#                           Brief Description 001               1       Fossil Fuel Steam Generator (FFSG) Unit 1 002               2       FFSG   Unit 2 003               5       FFSG   Unit 3 004               4       FFSG   Unit 4
: 1. Clean Air Interstate Rule Application. The Clean Air Interstate Rule Part Form submitted for this facility is a part of this permit. The owners and operators of these CAIR units as identified in this form must comply with the standard requirements and special provisions set forth in the CAIR Part Form (DEP Form No. 62-210.900(1)(b)) dated March 16, 2008, which is attached at the end of this section. [Chapter 62-213, F.A.C.
and Rule 62-210.200, F.A.C.]
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                      Title V Air Operation Permit Renewal Page 48 of 54
 
SECTION V. CAIR PART.
Clean Air Interstate Rule Provisions
* Clean Air Interstate Rule (CAIR) Part For more Infonrnaton. see n0tNuSc&ons and refer l 40 CFR 96.121,98.122,96.221, 96.222, 96.321 and 96.322; and Rule 62-296.470, F.A.C.
This vuxisaloon is:   03 New       fffRviaed   13"Renewal STEP 1                         Plant Name: CRYSTAL RIVER POWER PLANT                                 State: Florid     ORIS or EtA Plant Code Ideiffy the source by                                                                                                               -2 plant name and ORI8 or EIA plant code STEP 2                                 a                  b                    c                d                    e                  f Unit Will          Unit will        Unit will In column "a" enter the                             hold nitWgen        hold sulfur    hold NOx Ozone        New Units            New Units unit I10 for every CAIR                             adds (NOx)          dioxide (SO2)        Season aalwlowe            aewances          afwinoes            Expected            F unit at the CAIR source.                           In accordance      In accordance    In aordance          Commence                Monitor with 40 CFR        wtih 40 CFR      with 40 CFR        Comnunen*al          Ceruication In columns "b," "c,"               Unit ID#        96.106(c1)         g96.206(cXl)      96.306(cXl)        Operation Daft          Oeadline and "d," Indicate to                                      x                  x which CAIR program(s)
I or E.U.-01                                                    x each unit Is subject by        2 or E.U.-002 placing an "X" in the column(s).                     5 or E.U.-003            X                  X                X
* For new units, enter the        4 or E.U.-004 requested informntlon in columns "e" and "f.
0 DEP Form No. 62-210.900(i)(b) - Formi m
Effectve: 3/16M8                                                            I Progress Energy Florida, Inc.                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Air Operation Permit Renewal Page 49 of 54
 
SECTION V. CAIR PART.
Clean Air Interstate Rule Provisions 0                          CRYSTAL RIVER POWER PLANT I  plaruNormn  (USTEP1)
STEP 3 CAIR NOx ANNUAL TRADING PROGRAM Rad ihe stwx d                  CAmR Padt Reaimmmt.
requirements.
(1) Thi CAIR dod              represnlebe of each CAIR NORscums sld each CAIR NOx rai at ft aawrn sl W)Subn* hI M    OEPsa              and celied CAIR Part form under 40 CFR 96.122 and Rule 62-296.470. FAC., in pnlelte                                                                                                  ith Om dede specidied in Rue 62-213.42D, FAC.; and (2) The oners and operaln' t eich CAIR NO. souc and auch CAIR NO. unt              am the scure9Who          aCAR Part            d Mu Te V qaIhqpg p*eni issued by #* DEP uwder 40 CFR Padl 96. SiupM CC, and opena M souc and                    the un i            i  wth such CAIR Monitonf        . Recorft . and Reoordkeeolna Reautmnienta.
(1) The owners midoperatml. end Mt CAIR des- nale repesernll of each CAIR NO sucue aind each CAIR NOr at ft auew diai Coon        lsyw modnaitlrg. repornMiand -ec*-eeplgrequumnt of 40 CFR Pat 906.               Subpat Ward Rule 02.29.470. F.AC.
(2)The ensmsoms        n uasmmrnns recorded and repored Inaccordance wh 40 CFR Po 96, Subpa*tH.HK ld be used to delemee oenimi- by ch CAR NOx nul- *ithte                  I    CAR NOx rnsn RPettnen.
N*x Emisslon Reaukements.
(1) As of ft -Innce      rimu er deene tra condol peeod, the ownam and *atm a edi CARNO                          mideaAAIRN ORW at Mtsuscwedaldhold infu acuree ceplanoacousnut,CAIR NO4 dloomies avelable fo cnnyence dedualona fortMu hioperlod uider 40CM 95.154(a) h nanewait fbIlsdunmuhinaihibNORiamwslor'Mu nib pearldfrornalCAJR NORmlatatfteu506w.
dean6ld I accordance wmi40 CFR Pall o. S                  n HK
: 2) ACAIR NOx wrllid beoeathd theMumquksmsnl tide.psz-waph    d              (I) toh NO%Requiremens          atnn fMber of Jumy 1.20M.
or f d 1ehifor enesof Muftsniesmnilot ,rtd1a8- requiremif uider 40 CFA 96.170(bX1) or (2) and foreach - - , pertod asftim .
(3) A CAIR NOA m*ance slidl not be deduded. bo mIpIlm                  i Mufrequu*eieuts under par-a ;ph(1) d tie NORRAqunmitw, fo a
                              ..i . parid ia imii yest eorihe          ndwe    bwhich i CAIR NO xab          i    ie ioccale (4) CAIR NOx adlman            OWil be heldin.deduCld from. or tranele      io or Mmaoi CAIR NO Aowaim Ttadh                ymm        t hi acrdance vmh 40 CFR Pt 96. Subart FF and GG (5) A CAIR NOAdoeaicelis aUnied *Aiortioion to ant one ton aoNO in aci a ne with ftMu              CAIR NOx Arniui Trafi Ptuin. No proaleo*nl haM      CAR NORAnnual Traing Progamn,Mu CAIR P*, oran *mopkn ide 40 CR95.10w mnopo a                                  law
* be
                                  *uead to Ibat Mu *ii*lty of MfuOf or VMu        UnbEd Steels io amni* or birt sch sulhoezllon (6) A CAIR NO allomance does no corslbde a propety ofth (7) Upon rcordati*n byfte Adrntabo under 40 CFR P*t 95, Subpart EE. FF. r GGO,                u ams    acaon, b     lsr.. or dedtcdo of aCAR NOx cna      hioor frtm aCAIR NORunt's compliance accnt Is'              aulhd Ficorp    matonoy Inany CAIR Pamt    of OMu  same. Sel hdde Me CAIR NORmEt E e          Emissions ReoieMenIs.
I a CAR NOR so-ce ernis NOx uding any oonh parod in m olto CAu                  R NOh.           b        l (1) The Oreers and operaor, ao      fMurce and easch CAJR NORunita Muf sme s*ld aunmrdered. CAIR NOR            4 slowanboss rufo        f dedubion unde 40 CFR 96.154(d(1) and pay any fne. penay, ora              nmmaor          md any u r                  a. b        sam videllona, under It Clean AirAct or appktafrle sate low. and M2Each lon of such excess aridsalon arid each day of such car" period dial consitulsa separate violation of 40 CFR Pert 96.Subpart AA ft Clean Air Act. sand  OPicste SIRe 10W..
Be                n and Reoftnm          Reirements.
(1) Unless otuwise provided. Mheowwrs and operatorsdofe CAR NORscums and each CAR NO. unk at El scum slMWkeep on sOtea Mhesuroe eacho. eiM Ioung doceunla brorapwaod of S)*mmtornMt d Mu docum l os                      crauld. Trl pearod may be                  foed r
causm,*a anne beore Mu        f ed c 5 m n, ,melng    IbyMu DEP o*rf AdMtn              .
: 0) The, -erh1wofapreawwJ unide40 CAR 96.113 f UwCAIR daeignso represenwive r ft scums end each CAR NORuit at ft source aid all donmincels at    dnnsab      Mu
                                                                            "'utdV      ofto I -m-dshinu    One,10,1c alrepeuentaticnprode o                Wv          atMu csth
                                                                                                                                                                , e 11ad  s mi doceaunle slibe                  n siebaltie soure. beyoid such Syserpemod till such dooorenhi ar superseded bernie is Muettinbaesion of
                                                              'abhe a new ,e1c        a11 epeof 1       under 40 CFR 96 113 dhhngi Mu CAIR deielnabd teprosenbtdWo Ol) AM m          a notog It nemti, in raccodance w1i40 CFR Pawt99, Sutpml H.K afkpMtpu.             prodded          hM e            ! 40* R Per 06Suapet  14,prvide. forea 3-V-rperiod fo socriueephirg Mu3-yw-perldhelWly.
(11)Copies ofall reports. ooniqtabn-ce                welldreidubsaoeend
                                                                                              ~sulier  s          al              or required uider die CAIR NOR meodsnde                                Annua Treft Proponi v) Copis at1 dolacnte uaednlieo nlot e CAIR Pm iorm and any olier mlesibsio underie CAIR NO, Annual Trafi Provanonto dmondie    -, -           nce wl M rw  eem nw atCAIR e          NOx Ania Trsin ProemL (2) The CAIR dasignaod represento's. of a CAR NOx soure. nd each CAIR NO. atrat Mu w-. sclu subtn* f %                                  under Mu CAR NO
* Trang Prog.
                                                  *ual                *r*d*emee w der4o CFR Pt 6 SeAd9          p H DEP Form No. 02-210.900(1 Xb) - Form Eflac*v: 311600                                                                    2 Progress Energy Florida, Inc.                                                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                  Title V Air Operation Permit Renewal Page 50 of 54
 
SECTION V. CAIR PART.
Clean Air Interstate Rule Provisions 10 CRYSTAL RIVER POWER PLANT Plant Momni    Mfom STEP 1)
STEP 3.
ConUnued UaI.
(1) EuIi CAR NOx Wju=e and each CAIR NOx unit sha meet t                                 dime  CAIR NO8 Annual Troun Piopam of thqulnm'ml (2) Any provion o Ie CAIR NOx Annual Tradn Piroganiemt                          i0 a CAIR NOx a xmie*we    CAIR de*          *rapreartn      feCa CR NO, soucea*l alo appylaf              towns and operas o such source ad ofi CAR NOA                    al *te ourc.
(3) Any provision o it CAR NO, Annarl Tr*dino Phroarn Pu appies toa CAR NOHwx                  w or to CAR
                                                                                                                                      *e                  prsenmive da CAIR NOx urt &Waboapply to the owners ard opera; s of such uit.
Efctd on O00e Authodfies No prvision ofdie CAR NO, Annual Tradng Progrm a CAR P*t oran empdon wider                          40 CFR .O1 " beoh o daa me                      or eaarogudt fhsowne and opemrto and ie CAIR designated presamadve, of a CAIR NO, swim or CAR NOx unit frm compliance vantarmy om Is                    u apcl                d Stlae Ilnmrton Pan. a lederally mnforable permi or do Ciem AIr Ac.
CAIR SO TRADING PROGRAM CNR Part Roursments.
(1) The CAIR desiged reprevendsae of each CAIR S(h aource and each CAIR S01 unit atth source sIi:
: 0)  Subnt bI DOEP            a npleme    aindc'lled CAJR Part forn under 40 CFR 96.222 and Rule 82-M.4 dumIll specillied InRule 62-213.4M0. FAC.: arid FAC.. Ina          c mP (i)      *tnrvedm; (2) Th owners ad operatoe d eac CNR SO* soume and each CAR SO unat the so se al                                  a CAIR P**d          in*t    Me V operalng permt Ismed by fthDEP under 40 CFR Part 96. Subp*rt CCC. for t soue and operat                        so    ad each CAR rad In I'-        idilli si CAR Pat Monftorimn.        Reoortino. and Recordkeedona ReaWrements.
(1) Rhe oners ard operatorl, and Pue          CAIR designled repreeenalve, of each CAIR S0 souce and each SOh CAIR unit at me aource 09 wmplyiti Punh*r*torg, reporft. and racordkeepift reqirements of 40 CFR Part 0,Subpart HH. and Rule 62-298.470. FAC.
(2) The emIsna meneement recorded and up otdi naccordance whlh 40 CFR Part 96. Subpart IFl sll be ued to deernui*
corpllaice by each CAIR SO8 source withmhe oUowfg CAR SOQ                 Ensalon Raqukernents.
SO, Emission Reoutrements.
SO, Emission Reoutrements.
(1) Asmo faoac IInsfadealc bra conrm pei me iowsm and operators d each CAR SO2 source arid each CAR SO at fe source shel hoK, In ft sources acoplierc accunt a orage equivalar in CAIR SO, alowanns available for compliance deductiona fr feort period, as delswiftm In acoordance with 40 CFR 96.254(s) arid ft not raless Pun ft tonao di latl slA~r dbodde ermissions for ft ceni period kom al CAIR SO3, units at Pu souce. ned In c I ii 40 CFA Part 96. tH.(2) A CAR SO h shall be lorbjtlame muremepntw (1) ime Suiw Diode Emilon Reirementerits gon ft low of Jsriwhy 1.2010 or to d1edl1ne for meetig t units- morito cartiication requirements under 40 CFR 96.270(bX) or (2) a-rid 1 each control (3) A CAUR SO, alowainc shal not bededticted.
(1) Asmo faoac                 IInsfadealcbra conrmpei me iowsm                 and operators d each CAR SO2 *,nit source arid each CAR SO         at fe source shel hoK, In ft sourcesacoplierc accunt a orage equivalar inCAIR SO, alowanns available for compliance deductiona fr feort         period, as delswiftm       Inacoordance with 40 CFR 96.254(s) arid ft notraless Pun ft tonaodi latl slA~r dbodde ermissions for ft ceni period kom al CAIR SO3,units at Pu souce. asdl* ned In                         cI ii 40 CFA Part 96.       *5Subpm tH.
fot r-gilance  
(2) ACAR SOh                shall be         lorbjtlame muremepntw   underpa*raaph (1) ime Suiw Diode Emilon Reirementerits                 gon ft low of Jsriwhy 1.2010 or to d1edl1ne for meetig t units-morito cartiication requirements under 40 CFR 96.270(bX) or (2) a-rid1 each control (3) ACAURSO, alowainc shal not bededticted. fot           r-gilance
",ii Pu requirenmes under peragraph (1) Pu t SO, Emilalort Raquirkennts.
                                                                                                ",ii       Pu requirenmes under peragraph (1) Pu   t SO, Emilalort Raquirkennts.
frma crn period ins dasride year be* ahe Puw otr m ti CPRu R SO, allowance vas allocaled.
frma crn period ins dasride             year be* ahePuw otr m         ti CPRu R SO, allowance vas allocaled.
(4) CAR SOa -oI lbe hld dad- fon, ort ambard into Moreamo CAJR SO, AMmnc Tracug System acon In accordance an i 40 CFR Per 96. &ulert FFF aid GGG.(5) A CAIR S i, lowerie Isa lnmied aulhi0taion tlo enit auifudorcke h accodance wilhf CAR SOz TradT ProWgram o provision dito CAIR SOl Tradng PRogram, Ph CAIR Part, or an arranllon under 40 CFR 96.205 arnd no provision od tow WW be conatrued to nt Pu sihafaty of fit stm or lie ULnitd Stewa to minat or biit msch aufulzatlon.
(4) CAR SOa -oI                       lbe hld i*. dad- fon, ort ambard intoMoreamo CAJR SO, AMmnc Tracug System acon In accordance an i 40 CFR Per 96. &ulertFFF aid GGG.
(6) A CAIR SO, dowanice does nol omoatble a property rghlt (7) Upon recmrdude by fte under 40 CFR Pnt 95. Subpart FFF or GGG. every a .n vansl. or deUcondo a CAR SO, d~nm m a CAIR SOa utilte compitonce acoumt r inororated autor cally hi sny CAIR Part d th souce Oa incldo to CAIR SO, uit ExOes EmLssions Pmreowmns.
(5) ACAIR S i,lowerie Isa lnmied aulhi0taiontlo enit auifudorcke h accodance wilhf CAR SOz TradT ProWgram                             o provision dito CAIR SOl Tradng PRogram, Ph CAIR Part, or an arranllon under 40 CFR 96.205 arnd no provision odtow WW be conatrued to nt Pu sihafaty of fit stm or lie ULnitd Stewa to minat or biit msch aufulzatlon.
era CAR SOsource anftS$08 durNWin nycni period inaon iuCA O rimos iito.Prc (1) TIh owners and operators ofme som ard each CAJR SO, unit at tm source shml smursnde the CAR SO, allowances reqired fo dedction under 40 CFR 9N.254(dXt) and pey any In. penmlty, or asseamaent or comply with any othe remedy imposed. for th e sne v~idaiona.
(6) ACAIR SO, dowanice does nol omoatble aproperty rghlt (7) Upon recmrdude by fte Adni*ihtiu under 40 CFR Pnt 95. Subpart FFF or GGG. every a                         .nvansl. or deUcondo a CAR SO, d~nm m           Irotn* a CAIR SOa utilte compitonce acoumt inororated      r     autor cally hisny CAIR Part d th souce Oa incldo to CAIR SO, uit ExOes EmLssions Pmreowmns.
under me Cleanr Air Act or applicable sumlatow.
eraCAR SOsource anftS$08 durNWin               nycni period inaon iuCA O rimos iito.Prc (1) TIhowners and operators ofme som ard each CAJR SO, unit at tm source shml smursnde the CAR SO, allowances reqired fo dedction under 40 CFR 9N.254(dXt) and pey any In. penmlty, or asseamaent or comply with any othe remedy imposed. for the sne v~idaiona. underme Cleanr       Air Act orapplicable sumlatow. arid (2) Each ton d such excess amnis asrd each day of such oontbol             period miW ronsimemapvriolation 0140 CPaPr, Subpart AAA PueClem Air Act and applicable sae loa.
arid (2) Each ton d such excess amnis asrd each day of such oontbol period miW ronsime mapvriolation 0140 CPa Pr, Subpart AAA Pue Clem Air Act and applicable sae loa.DEP Form No. 82-210.900(l Xb) -FormI Efectve: 3/168 3 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 51 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions CRYSTAL RIVER POWER PLANT Plat Mem (Im STEP 1 6 STEP 3. DM&NUMMEN WND MNL M mn M Uw!IMLS CoQltnuWo (1) oIeIe proviOdd, do mmeI aid opoalr of ft CAR SO, s arc med eich CAM SO, uni at dwo aumc aW keep oof at 0**w umsme catholiOokeing domaneiu perodd of S.mu from w dale th docment IS ThN* roday be fdrcaudse.
DEP Form No. 82-210.900(l Xb) - FormI Efectve: 3/168                                                                         3 Progress Energy Florida, Inc.                                                                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                     Title V Air Operation Permit Renewal Page 51 of 54
at any tirm bter 1 ie and @15 yens In wili by Depm; 'or li Adinistror.
 
M) The cmowte of u under 40 CFR 213 0r le CAR dWsnlted spsetied fr iourmed esch CAIR SOrumta soi -mid edonw0um ldo li -, the Wilto ti e-ea I In ft 10 1e of , p -- --, piraMdsid 1* x111, a id doaainift doll be oned on sift at lio sums beyon Such 51mor period utwil ach Sperseded because of 1w Submission of a Noe 't11 f osr,'ea -, under 40 CFR 98.213 dwn lie CAR desigled .epresmielue.(i) ANl e msing ineielni hin amrmie wbio 40 CytR Pe 6 1.0.. b tte pofiitw pL Med dlisot i t -W40 CFA Pet W, Subpart HH1. providee foa 3" w period for recordleeping.
SECTION V. CAIR PART.
tor3-jr perad ll aply.(i) Capin of at repote compiance oml~waonl and aha eujrrdsiar.
Clean Air Interstate Rule Provisions CRYSTAL RIVER POWER PLANT 6
andaN r bouda mde o requied unde the CJR S0 T P age-Ov) Copieo as docmime umed to am CAJR Pint tern and ohler subiseso under iho CAR SOQ, Treeing pgMmig or to dm11nem m maom i 1wh mruqusamimf de CAR SO, Trading Prioui.(2) 11T CAIR deosigated .uprmiecim s, a CAIR SO, scums and each CAIR SO undi at to scums shag eubrd lie roem II 'udder th CAIR SO, Traing Prowas indig oe under 40 CFR Pet 96. Subpart HHH.(1) Each CAIR SO, ecu mid each CAR SO ndit sdil meot On requimeoits e @ft CAIR SO, Trdlng Pragmo.M2) Any rouslmOn ho 1wCAR SO, TredMg Prrm h pla gme toa CAR SO, emc nr th1 CAIR dedI d V -agmemane a CAIR SO, ecum eoll soo apply mh; g otnn and operator@
Plat Mem (Im STEP 1 STEP 3.                 DM&NUMMEN WND MNL                     Mmn M Uw!IMLS CoQltnuWo             (1) unte* oIeIe proviOdd, do mmeI aid opoalr of ft CAR SO, s                                     arcmedeich CAM SO, uni at dwo aumc aW keepoof at0**w umsme catholiOokeing domaneiu               *ra perodd of S.mu from w dale th docment IS                             ThN*       rodaybe            fdrcaudse. at any tirm bter   1     ie and @15yens Inwili by                 Depm;       'or li Adinistror.
o muc earch m d od@o CAR SO, units ot S eums (3) Any praomi of fth CAR SO0 TrtiMg Pro e a Volin to a CAIR SO unit or e CAIR desad repeeerallm ofa CAIR SO, uit etl ioap aply te ie ame aid aper, olo hdi udl Effect on Ofher Authorfte.
M) The cmowte of                 u       under 40 CFR 213 0r le CAR dWsnlted spsetied fr iourmed esch CAIR SOrumta soi- mid edonw0um             ldo                 li Wilto ti e-ea
No prowslon of 1o CANR O, Trading Progam. a CAMR Part, or ann enplia under 40 CFR 91.05 shag be awabud a rn or excludig lie oiersmnd aper I andri desi c ropmoee tata, Va CAIR SO, Sm or CA R SO, unit *oni ;- with ay allow pravli oa to alppicale, awroved Stle krolmwimllao Plan. a Iedraly IV -m. or le Cleam Air AcL CAIR NO. OZONE SEASON TRADING PROGRAM CAIR Part ReMAirements.
                                                                                    -, the                          IIn ft       10 1e of , p -- - -, piraMdsid             1* x111, a id doaainift doll be oned on sift at lio sums beyon Such 51morperiod utwil ach doagfrismweu* Sperseded becauseof 1w Submission of a Noe 't11 osr,'ea     f              -, under 40 CFR 98.213 dwn               lie CAR desigled                           .epresmielue.
(1) Thi CAIR doesinalad repmerdatim of each CAIR NO. Ozone Seamoan mcane wed each CAIR NOx Ozone Smonc umna at So scums shea 0) Sub"it lo 1 DEP a .ipIw mand camled CAIR Paod te under 40 CFR 96.322 and Rule 62-M.470.
(i) ANl e             msing ineielni hin         amrmie wbio40            CytR Pe 6 OSubpa*-t            b    1.0.. tte pofiitw     pL Med dlisot i           t -W40 CFA Pet W, Subpart HH1. providee foa 3" w period for recordleeping. tor3-jr perad                                 ll aply.
FAC., In Ae f dmiineas apeled in Rue 62-213.420.
(i) Capin of at repote compiance oml~waonl                   andaha eujrrdsiar. andaN r                   mde bouda o requied unde the CJR S0 T P age-Ov) Copieo as docmime umed to                         amCAJR Pint tern and ohler subiseso under ihoCAR SOQ,Treeing pgMmig or to dm11nem                     m maom i 1wh mruqusamimf de         CAR SO, Trading Prioui.
FAC.; and (at) (RawvedJ (2) The ioners aid a frra each CAR NO. Oza ums aq oed hwae a Tile V opeag pari or air ctrui pan, aid each CAR NOxCree eamoan uma fo ham a TOl V oareang i peri or sir masalnon perivit at go source Shae a CAIR Paot khidedd I le Tto e V operating peartal or on parim* isaued by lie DEP under 40 CFR Pad 90. Subpart CCCC. fo li and o aI do Sms mid w unat in In. wth such CAOR Pat.Monttblko.
(2) 11T CAIR deosigated .uprmiecim s,               a CAIR SO, scums and each CAIR SO undi               at to scums shag       eubrd lie roem         II 'udder       th CAIR SO, Traing Prowas indig oe under40 CFR Pet 96. Subpart HHH.
Repudft. and Recoidkeeplma Reouiefmmeits.
(1) Each CAIR SO, ecu mid each CAR SO nditsdil meot On requimeoits                             e @ft CAIR SO, Trdlng Pragmo.
(1) The omers mnd operetand On CAIR degnated reprem ie. of each CAR NO. Ozone Season ecm@ and each CAIR NO. Ozone Seaeai mt a 1 mer a c y i 1 rrrg. ropontth and rkei u rm rr 1o40 CFR Padr .Subpwt HN Rul 62-2M.470. (2) TI er ismici mneaarti recoded mid spod In Widm to 40 CFR Put 91. Subpart 1*M dol be ueed to doain0.mqr eu by each CAIR NO. Omze Seaman 1w the ftual CAR NO. Owm Seaeon Eii N06 Ozone 66880 Eateo Reaulmments.
M2)Any rouslmOn 1wCAR      ho         SO, TredMg Prrm h plagmetoa CAR SO, emc nr th1 CAIR dedIV -agmemane                       d                    a CAIR SO, ecum eoll soo apply mh;           g otnn and operator@ o muc earch           m       d od@oCAR SO, units ot             eums S
(1) As 0of Onm 1we 0 enrs I -lore ao -peiod. So m mid opman d 1 eao CAIR NO, Ozone Season eurc mid -1 CAR NO, 0 0n Seeman unl at tho so siae, hold. In So amums's cntgnce socunrt CAJR NO. ona Samoan aeawmoes waedble tr ooIenmoa daductons fort coo bel prmod under 40 CFR 11.364(a) in an mooued not bas tmo te Iwna told NO, anhiatons tor t coanmb peod ftn CAIR NO, Ozm Seacsn ums It ato smore. as domeied 0 ina, -l, 40 CFR Part 96. Subpart 501*.M A C-R NO, Owe S1en w s b eubjedt 1w reqsn-enl wide peagraph (I) o0 f NO. O=wo Seoon I n Re**anb.o 1w l@1 oa 1. 1. or 1w deen fa meaig aie mioe unors ywleon req- rimia ider 40 CFR )or(S)end ioreedi , p1led 1w'esem.(3) A CAIR NO. Ozone Seeman alaomna Stell noi be deducted. imoean 1wi under paupeph (1) d* hNOA Ow Semman Erson Raquir e toronida period ina Ca yaw before to yew fo uhdi On CAR NO, Ozne Seemon macewa (4) CAIR NO, Owe Smoa n be hm iin.o umed n ortanaero d or aweg CAIR NO, Ozor oSemenA nc Tradd"g SaoM mm In amdarmlih 40 CFR Palt 9. Subpeft FFFF mid GGG-.(5) A CAR NO. Ooie Season Itsn I tid atM -l'aaao toar oitson n t NO, in aoda mi CAR t NO n Season Traing Prapsor NH roAiami@1f1w CAJ R INO Ozone Seem Tradkg ProIartr.
(3) Any praomi of fth CAR SO0 TrtiMg Pro e aVolin                            to a CAIR SO unit or e CAIR desad repeeerallm ofa CAIR SO, uit etl ioap       aply te ie ame aid aper,               olo hdi udl Effect on Ofher Authorfte.
1w CAIR Paot r an g'pl unde a 40 CFR 9. on md twuedi @loo almws be amelued hfi Maiw uauliorly  
No prowslon of 1o CANR O, Trading Progam. a CAMRPart, or annenplia under 40 CFR 91.05 shag be awabud a                                             rn       or excludig lieoiersmnd aper I andri CA*R desi                             c ropmoeetata, Va CAIR SO, Sm                   or CA R SO, unit *oni       ;-         with ay allow pravli oato alppicale, awroved Stle krolmwimllao Plan. a Iedraly                         IV -               m. or le CleamAir AcL CAIR NO. OZONE SEASON TRADING PROGRAM CAIR Part ReMAirements.
@11w ort* 1w UntdSistee hterminat or Winilc miitarizaio~n.
(1) Thi CAIR doesinalad repmerdatim ofeach CAIR NO. Ozone Seamoan mcane wed each CAIR NOx Ozone Smonc umna                                       at So scums shea
(6) A CAIR NO, Ozon Sean -dams nrt consomme a poperty (7) UP- .9m ' toy to Aiinrnr uidoe 40 CFR Pot 91. Subart EEEE. FFF or GGGG. evey almio. bwt. r. n n deducion on a CAN O, Oz on Season aw to a fom a CAIR NO. Samoa n amplce eccil -incoportd snay in y CR Pint of11w scums li Includes to CAIR NO, Owone Seamson mnit 00P Fonn No. 82-210.g00(1Xb)  
: 0) Sub"it lo 1 DEP a             .ipIwmandcamled CAIR Paodte under 40 CFR 96.322 and Rule 62-M.470. FAC., In                                     Ae f dmiineas apeled in Rue 62-213.420. FAC.; and (at)(RawvedJ (2) The ioners aid a                     frra CAR NO. Oza Sa*son ums aq each                                                      oedhwae a Tile V opeag pari or air ctrui                   pan, aid each CAR NOxCree eamoanuma u*qi fo ham a TOl V oareang iperi or sir masalnon perivit at go source                                           Shae       a CAIR Paot khidedd I le Ttoe V operating peartal or                         on parim*isaued by lie DEP under 40 CFR Pad 90. Subpart CCCC. fo li and o         aI do Sms mid w unatin                In.       wth such CAORPat.
-Pnii E&0cnivo:
Monttblko. Repudft. and Recoidkeeplma Reouiefmmeits.
31606 4 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 52 of 54 SECTION V. CAIR PART.Clean Air Interstate Rule Provisions I CRYSTAL RIVER POWER PLANT IPart Name (MraM Sr1 1)1 IExces Emissions Rmeaurments.
(1) The omers mnd operetand OnCAIR degnated repremie. of each CAR NO. Ozone Season ecm@ and each CAIR NO. Ozone Seaeaimt a 1mer                  a c         y i 1 rrrg.               ropontth and         rkei           urm      rr     1o40 CFR Padr . Subpwt HN Rul 62-2M.470.             *AC.
ST1EP 3 If a CAR NO. Oane See sm&mu ft enits NO, diwwg Wny osnfrl putod in mum of Uhe CAIR NOOn.Samenmsabiftan livnr: Continued (1)1e omer a opera; s oft I he source d each CAR NOx Ozo Season unita the source sal sumaredwlte CAIR NO. Ozo. Season-l*'anmm mqhd tor dmdu&a.on unde40 CFR and pay any , penalty. or assssment or comply ih " cow amedy Imposed. for I. same under the Clean Air Act or applicable state law &nd (2) Each ton of such excess emissaions and each day of such conbif period stai cobutla a aeparate violation of 40 CFR Part 96. Subpart the, d Clean Air Act. and applicable SUNa low Recordkeecpin and Reportlna Reauimmets.(I) Urnea ohamdise promded, h ,weris w1d operAtr-m of te CAIR NO Ozne Seaman surce ard each CAIR NO,, Ow Season unit a t t arnw Sat eepon lt g~ soaw achof 3 ollek~ doanmiefor a period of 5 yeam from to date Ins docuners Is ratd Tt~apeitod may be a ornded tcr caee at any use o b.1m Vih and of S !uaInsing by te DEP or f tAdrninlator.(I) The wrialt of -a .' under 40 CFR 96.313 for the CAIR deagnt ruprea itatas hor t msoe arid each CAR N Oustne Season unit the source and Oallonn tat docmmna Ole istdh of t t e ru mtama in Ihe i enthecata of rlepfulliauoont ai l da 3-k, I and documents dog be netalnad on at at mu msor- beyond such 5"ar period unti such docuaenta superseded because af the submiloi of a new "allflc, of s.prmeno und ,d40 CFR 96.113 chagngng di CAIR desinted representativ
(2) TI er ismici mneaarti                 recoded mid spod In                           to 40 CFR Put 91. Subpart 1*M dol be ueed to doain0 Widm
(,) All -a1alw o1m Ifritnallm In ,ao 1- with 40 CFR Part U, Subpart HHHW. of Vlf pat. p Mvid t to th m 40 CFR PonE9. Suiar Meffi, provier;lsa a 31me period for rcordkeping der 3,ye eripaod "*3 apply.(0i) Copis of d rept. ON ompanca c-Ist- and owh" subtlssiosi and all ramoudl n.e or raqiulired wnder ev CAM NO. OzR Seaaon Tradft P ogiani (Qv) Copies of all docaras used to omliea a CAIR Par in an w ay ow submission under ieo CAJR NO Ozons Samoan Traai Program o to denorasata womprian we Uthdr arquiVers of Ift CAJR NO, Ozan Season Tradin Pmagna.(2) The CAIR designated representative ofa CAR NOx Ozone Samson source and each CAIR NO% One Seaaonit at the sowos OW eubdf I3he reports required uwder the CAR NO% Ozone Seasm Tmdeln Program. inckldng hose under 40 CFR Pwt 9, Subpert HHWL Uawbltr.(1) Each CAAR NO. Ozone Season asume and each CAR NO% Ozone Seaso unit slil time tth nertesm of the CAIR NO, OWne Seeson Trading PRogram.(2) Any prIs-on at to CAIR NO% ozone Semon Tradf0 PmrWam Oit applies 0o a CAIR NOx Ozone Seaaon aource orB CAIR d g a rspreseue ofa CAMR NO,, COons Season mo s also apply to the asm and olper~wo of sums e id of heCAR NO. Ozone SeA unfta of source.(3) Any pmviaon of sh CAJR NOx Ozone Season Tradig Progrum tal applies to a CAIR NOx Ozone Season undt or ft CAR gea.upanmwtv ofa CAJR NO, Oaie Seaon unit " als eo apply to to owners and opeal o such unwL Effect on 00we Aufthoties No provialon of lit CAR NO. Ozone Season Trading Pmoginis, a CAIR Part, or an exemption under 40 CAR 96306 shall be coeudas-FIn or ~mod 1 owner endg opras aid "i CAJR desiprieted represenfabve.
                              .mqr eu by each CAIR NO. Omze Seamana*=u                            1w the ftual CAR NO. Owm SeaeonEii                              Requ*en.tent.
ofa CAIR NOx Ourie Season source or CAR~ NO,, Ozone Seao wlt from copino1 with any ows provision of e applicable, appmoved State Implemenation Plan a federally uderosabla permi. or th Clean Air Ac.STEP 4 Certification (for designated representative or altemat. designated represanatalve only)Read 01w I am adhotaed to mnakn fti submission on behalf of th owner aid operators of te CAR mums or CAIR units for ~t thre su bnsion is ,ne".I Nobwi of lawie I32 lieu. personoyamairond, aid an butmler w^it, staemenlets and informullon submitted In Oft cmti3tir Based an my lqusy of Inose viduaswt rmr lU~ reaponutial for #0*l 1W nfmeOWi. I Muytat stat~~~mef aniin f arlto 1 beat f my knowledge aid bellel'ir.
N06 Ozone 66880 Eateo Reaulmments.
anmd oit.Ia w,02Oeaea~cn ststmanntt provide ioo, roilldngiftfad e sden aiad kirni, ,, kdid the posiltyo company name, Manager, Env mentl S i o phone, and @.-mall Name: Patricia Q. West Florida address; sign, and data. Company Owner Name FLORIDA POWER CORPORATION DBA PROGRESS ENERGY FLORIDA, INC.Phone: 727.820.5739 E-mailAdrs:p icaw t pgm lco Addressurebc Datwes pg aico DEP Form No. 62-210.9000(Xb)-
(1) As 0ofOnm                  1we 0         I - loreao-enrs                    peiod. So m           midd opman 1eao CAIR NO, Ozone Season eurc mid - 1 CAR NO, 0         0n Seemanunl at tho so           siae,hold. InSo              cntgnce socunrt CAJR NO. ona Samoan aeawmoes waedble tr amums's ooIenmoa daductons fort coobel prmod under 40 CFR 11.364(a) in an mooued not bas tmo te Iwna told NO, anhiatons tor t coanmb peod ftn           CAIR NO, Ozm Seacsn ums It ato smore.as domeied                 0     ina, -             l, 40 CFR Part 96. Subpart 501*.
Form Effecilve:
M A C-R NO, Owe S1en w s                         b eubjedt 1w reqsn-enl wide peagraph (I) o0f                          NO. O=wo Seoon         I n Re**anb
3/10M 5 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 53 of 54 SECTION VI. APPENDICES.
                                .       o 1w l@1       oa     1. 1. or 1w deen farimia ywleon                        meaig aie mioe unors                           req-             ider 40 CFR 96.370*bX                    )or(S) end ioreedi             , p1led 1w'esem.
The Following Appendices Are Enforceable Parts of This Permit: Appendix A, Glossary.Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997).Appendix CAM, Compliance Assurance Monitoring Plan.Appendix I, List of Insignificant Emissions Units and/or Activities.
(3) A CAIR NO. Ozone Seeman alaomna Stell noi be deducted. fa*twc imoean 1wirheqiprnm*t under paupeph (1) d* hNOA Ow Semman       Erson Raquir           e toronida period ina Ca                   yaw beforeto yew fo uhdi On CAR NO, Ozne Seemon                             macewa (4) CAIR NO, Owe Smoa n                                   be hmiin.o       umed n ortanaero d                 or aweg CAIR NO, Ozor oSemenA                     nc Tradd"g SaoM mm                   In amdarmlih 40 CFR Palt 9. Subpeft FFFF mid GGG-.
Appendix NSPS, Subpart A -General Provisions.
(5) A CAR NO. Ooie Season                           ItsnItid    atM -l'aaao       oitson *nn t NO, in aoda toar                                        mi       CARt NO       n Season Traing Prapsor NH roAiami@1f1w CAJ R INO Ozone Seem Tradkg ProIartr. 1w CAIR Paot r an                                                 a g'pl unde   40 CFR 9.           onmd twuedi @loo almws           be amelued hfiMaiw uauliorly@11w                   ort*
Appendix NSPS, Subpart D -Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971.Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.Appendix NSPS, Subpart Y -Standards of Performance for Coal Preparation Plants.Appendix NESHAP, Subpart A -General Provisions.
1w UntdSistee hterminat or Winilcmiitarizaio~n.
Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.Appendix RR, Facility-wide Reporting Requirements.
(6) A CAIR NO, Ozon Sean -                         dams nrt consomme     a poperty r*
(7) UP-             .9m' toyto Aiinrnr             uidoe 40 CFR Pot 91. Subart EEEE. FFF or GGGG. evey almio.                           bwt.
n n r.     deducion on a CAN O, Oz on Season                         toaw fom a CAIR NO. Ow*e Samoa n                   amplce
                                                                                                                                -            eccil incoportd snay                     in y CR Pint of11w scums li Includes to CAIR NO, OwoneSeamson                    mnit 00P Fonn No. 82-210.g00(1Xb) - Pnii E&0cnivo: 31606                                                                           4 Progress Energy Florida, Inc.                                                                                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                                         Title V Air Operation Permit Renewal Page 52 of 54
 
SECTION V. CAIR PART.
Clean Air Interstate Rule Provisions I CRYSTAL RIVER POWER PLANT IPart Name (MraM Sr1 1) 1 IExces                             Emissions Rmeaurments.
ST1EP 3                   If a CAR NO. Oane See sm&mu enits            ft NO, diwwg   Wnyosnfrl  putod in mum of UheCAIR NOOn.Samenmsabiftan                               livnr:
Continued                 (1)1e omer a opera; s oftIhe source                 d each CAR NOx Ozo Season unita the source sal sumaredwlte CAIR NO. Ozo. Season mqhd
                                              -l*'anmmtor dmdu&a.on unde40 CFR 95.364(dX*l) and pay any           , penalty. or assssment or comply ih " cow amedy Imposed. for I. same vidalon*. under the Clean Air Act or applicable state law &nd (2)Each ton ofsuch excess emissaions and each day of such conbif period         stai cobutla a aeparate violation of40 CFR Part 96. Subpart d Clean Air Act. and applicable SUNa the,                                      low Recordkeecpin         and Reportlna Reauimmets.
(I) Urnea ohamdise promded, h ,werisw1d operAtr-m               of te CAIR NO Ozne Seamansurce ard each CAIR NO,, Ow Season unit at t arnwltSatg~ eeponsoaw achof 3 ollek~ doanmiefor a period             of 5 yeam from to date Ins docuners Is ratd Tt~apeitod may be a             tcr caee ornded  use at any o b.1m Vihandof S !uaInsing by te DEP or ftAdrninlator.
(I) The wrialt of -a               .' under 40 CFR 96.313 for the CAIR deagnt ruprea               itatas thormsoe arid each CAR N       Oustne Season unit the source and Oallonn                 tat docmmna tOle ruistdht of e mtama       iin Ihe enthecata   of rlepfulliauoont ai   l da 3
                                - k, I and documents dog be                     on at at netalnad          mumsor-beyond such 5"ar period unti such docuaenta               superseded because af the submiloi of a new           "allflc, of s.prmeno und,d40CFR 96.113 chagngng di CAIR desinted representativ
(,) All -a1alw o1m Ifritnallm In ,ao 1- with 40 CFR Part U, Subpart HHHW.                           of Vlf pat. p     Mvid t to th   m a*    40 CFR PonE9.Suiar Meffi, provier;lsaa 31me period for rcordkeping der 3,ye eripaod"*3 apply.
(0i) Copis of ONd rept. ompanca c-Ist-                 and owh" subtlssiosi and all ramoudl n.e       or raqiulired wnder ev CAM NO. OzR Seaaon Tradft P ogiani (Qv)Copies of all docaras used to omliea a CAIR Par in anw ay ow submission under ieoCAJR NO Ozons Samoan Traai Program o to denorasata womprian we Uthdr           arquiVers of Ift CAJR NO, Ozan Season Tradin Pmagna.
(2) The CAIR designated representative ofa CAR NOx Ozone Samson source and each CAIR NO%One Seaaonit at the sowos OW eubdf I3he reports required uwder the CAR NO%Ozone Seasm Tmdeln Program. inckldng hose under 40 CFR Pwt 9, Subpert HHWL Uawbltr.
(1) Each CAARNO. Ozone Season asume and each CAR NO%Ozone Seaso unit slil                             timetth              of the CAIR NO, OWne Seeson nertesm Trading PRogram.
(2) Any prIs-on at to CAIR NO%ozone Semon Tradf0 PmrWam Oit applies 0oa CAIR NOx Ozone Seaaon aource orB CAIR d g a rspreseue ofa CAMRNO,, COons Season mo s                       also apply to the asm and olper~wo of a*h sumse id of heCAR NO. Ozone SeA         unftaof    source.
(3) Any pmviaon of sh CAJR NOx Ozone Season Tradig Progrum tal applies to a CAIR NOx Ozone Season undtor ft CAR                             gea
                              .upanmwtv ofa CAJR NO, Oaie Seaon unit " als                 eo apply to to owners and opeal         o such unwL Effect on 00we Aufthoties No provialon of lit CAR NO. Ozone Season Trading Pmoginis,           a CAIR Part, or an exemption under 40 CAR 96306 shall be coeudas
                                  - FIn or   ~mod       1 owner endg     opras aid "i CAJRdesiprieted represenfabve. ofa CAIR NOx Ourie Season source or CAR~                   NO,,
Ozone Seao wlt from copino1 with any ows provision of e applicable, appmoved State Implemenation Plan afederally uderosabla permi.or th Clean Air Ac.
STEP 4                   Certification (for designated representative or altemat. designated represanatalve only)
Read 01w                 I amadhotaed to mnakn fti submission on behalf of th owner aid operators of te CAR mums or CAIR units for ~t thresubnsion is
                            ,ne".I                     Nobwiof lawie I32   lieu. personoyamairond, aid an butmler w^it, staemenlets and informullon submitted InOft cmti3tir                                                   Based an my lqusyof              viduaswtlU~ rmrreaponutial for Inose                                                  1W nfmeOWi.
                                                                                                                                                            #0*l             I Muytat stat~~~mef                         aniin         f arlto 1 beat f my knowledge aid bellel'ir.
sden                                            anmd oit.Ia               w,02Oeaea~cn ststmanntt     provide     ioo,                         e                  kiue*n roilldngiftfad                     aiadkirni, kdid          ,,   the posiltyo company name,                                                                                                         Manager, Env                     mentl S           i       o phone, and @.-mall       Name: Patricia Q. West                                                                       Florida address; sign, and data.                   Company Owner Name FLORIDA POWER CORPORATION DBA PROGRESS ENERGY FLORIDA, INC.
Phone: 727.820.5739                                               E-mailAdrs:p                     icaw           t       pgm lco Addressurebc                       Datwes   pg     aico DEP Form No. 62-210.9000(Xb)-         Form Effecilve: 3/10M                                                                       5 Progress Energy Florida, Inc.                                                                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                           Title V Air Operation Permit Renewal Page 53 of 54
 
SECTION VI. APPENDICES.
The Following Appendices Are Enforceable Parts of This Permit:
Appendix A, Glossary.
Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997).
Appendix CAM, Compliance Assurance Monitoring Plan.
Appendix I, List of Insignificant Emissions Units and/or Activities.
Appendix NSPS, Subpart A - General Provisions.
Appendix NSPS, Subpart D - Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971.
Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.
Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.
Appendix NSPS, Subpart Y - Standards of Performance for Coal Preparation Plants.
Appendix NESHAP, Subpart A - General Provisions.
Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.
Appendix RR, Facility-wide Reporting Requirements.
Appendix TR, Facility-wide Testing Requirements.
Appendix TR, Facility-wide Testing Requirements.
Appendix TV, Title V General Conditions.
Appendix TV, Title V General Conditions.
Appendix U, List of Unregulated Emissions Units and/or Activities.
Appendix U, List of Unregulated Emissions Units and/or Activities.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Air Operation Permit Renewal Page 54 of 54 APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Abbreviations and Acronyms: o F: degrees Fahrenheit acfm: actual cubic feet per minute AOR: Annual Operating Report ARMS: Air Resource Management System (Department's database)BACT: best available control technology Btu: British thermal units CAM: compliance assurance monitoring CEMS: continuous emissions monitoring system cfm: cubic feet per minute CFR: Code of Federal Regulations CO: carbon monoxide COMS: continuous opacity monitoring system DARM: Division of Air Resources Management DCA: Department of Community Affairs DEP: Department of Environmental Protection Department:
Progress Energy Florida, Inc.                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                  Title V Air Operation Permit Renewal Page 54 of 54
Department of Environmental Protection dscfm: dry standard cubic feet per minute EPA: Environmental Protection Agency ESP: electrostatic precipitator (control system for reducing particulate matter)EU: emissions unit F.A.C.: Florida Administrative Code F.D.: forced draft F.S.: Florida Statutes FGR: flue gas recirculation FI: fluoride ft 2: square feet ft 3: cubic feet gpm: gallons per minute gr: grains HAP: hazardous air pollutant Hg: mercury I.D.: induced draft ID: identification ISO: International Standards Organization (refers to those conditions at 288 Kelvin, 60% relative humidity and 101.3 kilopascals pressure.)
 
kPa: kilopascals LAT: Latitude Ib: pound lbs/hr: pounds per hour LONG: Longitude MACT: maximum achievable technology mm: millimeter MMBtu: million British thermal units MSDS: material safety data sheets MW: megawatt NESHAP: National Emissions Standards for Hazardous Air Pollutants NOx: nitrogen oxides NSPS: New Source Performance Standards O&M: operation and maintenance 02: oxygen ORIS: Office of Regulatory Information Systems OS: Organic Solvent Pb: lead PM: particulate matter PM 1 0: particulate matter with a mean aerodynamic diameter of 10 microns or less PSD: prevention of significant deterioration psi: pounds per square inch PTE: potential to emit RACT: reasonably available control technology RATA: relative accuracy test audit RMP: Risk Management Plan RO: Responsible Official SAM: sulfuric acid mist scf: standard cubic feet scfm: standard cubic feet per minute SIC: standard industrial classification code SNCR: selective non-catalytic reduction (control system used for reducing emissions of nitrogen oxides)SOA: Specific Operating Agreement SO 2: sulfur dioxide TPH: tons per hour TPY: tons per year UTM: Universal Transverse Mercator coordinate system VE: visible emissions VOC: volatile organic compounds x: By or times Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page A -1 of 2 APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Citations:
APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Abbreviations and Acronyms:
The following examples illustrate the methods used in this permit to abbreviate and cite the references of rules, regulations, guidance memorandums, permit numbers and ID numbers.Code of Federal Regulations:
o F: degrees Fahrenheit                                       lbs/hr: pounds per hour acfm: actual cubic feet per minute                             LONG: Longitude AOR: Annual Operating Report                                   MACT: maximum achievable technology ARMS: Air Resource Management System                           mm: millimeter (Department's database)                                         MMBtu: million British thermal units BACT: best available control technology                         MSDS: material safety data sheets Btu: British thermal units                                     MW: megawatt CAM: compliance assurance monitoring                           NESHAP: National Emissions Standards for CEMS: continuous emissions monitoring system                   Hazardous Air Pollutants cfm: cubic feet per minute                                     NOx: nitrogen oxides CFR: Code of Federal Regulations                               NSPS: New Source Performance Standards CO: carbon monoxide                                             O&M: operation and maintenance COMS: continuous opacity monitoring system                     02: oxygen DARM: Division of Air Resources Management                     ORIS: Office of Regulatory Information Systems DCA: Department of Community Affairs                           OS:      Organic Solvent DEP: Department of Environmental Protection                     Pb: lead Department: Department of Environmental                         PM: particulate matter Protection                                                      PM10 : particulate matter with a mean aerodynamic dscfm: dry standard cubic feet per minute                       diameter of 10 microns or less EPA: Environmental Protection Agency                           PSD: prevention of significant deterioration ESP: electrostatic precipitator (control system for             psi: pounds per square inch reducing particulate matter)                                   PTE: potential to emit EU: emissions unit                                             RACT: reasonably available control technology F.A.C.: Florida Administrative Code                             RATA: relative accuracy test audit F.D.: forced draft                                             RMP: Risk Management Plan F.S.: Florida Statutes                                         RO:      Responsible Official FGR: flue gas recirculation                                     SAM: sulfuric acid mist FI: fluoride                                                   scf: standard cubic feet ft 2: square feet                                               scfm: standard cubic feet per minute ft3: cubic feet                                                 SIC: standard industrial classification code gpm: gallons per minute                                         SNCR: selective non-catalytic reduction (control gr: grains                                                     system used for reducing emissions of nitrogen HAP: hazardous air pollutant                                   oxides)
Example: [40 CFR 60.334]Where: 40 CFR 60 60.334 refers to refers to refers to refers to Title 40 Code of Federal Regulations Part 60 Regulation 60.334 Florida Administrative Code (F.A.C.) Rules: Example: [Rule 62-213.205, F.A.C.]Where: 62 62-213 62-213.205 refers to refers to refers to Title 62 Chapter 62-213 Rule 62-213.205, F.A.C.Identification Numbers: Facility Identification (ID) Number: Example: Facility ID No.: 1050221 Where: 105 = 3-digit number code identifying the facility is located in Polk County 0221 = 4-digit number assigned by state database.Permit Numbers: Example: 1050221-002-AV, or 1050221-001-AC Where: AC = Air Construction Permit AV = Air Operation Permit (Title V Source)105 = 3-digit number code identifying the facility is located in Polk County 0221= 4-digit number assigned by permit tracking database 001 or 002= 3-digit sequential project number assigned by permit tracking database Example: PSD-FL-185 PA95-01 AC53-208321 Where: PSD = Prevention of Significant Deterioration Permit PA = Power Plant Siting Act Permit AC53 = old Air Construction Permit numbering identifying the facility is located in Polk County Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page A -2 of 2 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of ))Florida Electric Power Coordinating Group, Inc., ))Petitioner.  
Hg: mercury                                                     SOA: Specific Operating Agreement I.D.: induced draft                                             SO 2: sulfur dioxide ID: identification                                             TPH: tons per hour ISO: International Standards Organization (refers to           TPY: tons per year those conditions at 288 Kelvin, 60% relative                   UTM: Universal Transverse Mercator coordinate humidity and 101.3 kilopascals pressure.)                       system kPa: kilopascals                                               VE: visible emissions LAT: Latitude                                                   VOC: volatile organic compounds Ib: pound                                                       x:     By or times Progress Energy Florida, Inc.                                                            Permit No. 0170004-024-AV Crystal River Power Plant                                                                      Title V Permit Renewal Page A - 1 of 2
)ASP No. 97-13-01 ORDER ON REOQUE51 ALTENATE PROCEDURES AND REOUrREM-_QLi Pursuant to Rule 62-297.620, Florida Administrative Code (F.AC.), the Florida Electric Coordinating Group, Incorporated, (FCG) petitioned for approval to: (1) Exempt fossil fuel steam generators which burn liquid and/or solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter complianee test; and, (2) Exempt fossil fuel steam generators which burn liquid andlor solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter compliance test during the year prior to renewal of an operation permit. This Order is intended to clarify particulate testing requirements for those fossil fuel steam generators which primarily burn gaseous fuels including but not necessarily limited to natural gas.Having considered the provisions ofRule 62-296.40S(Il), F.A.C., Rule 62-297.310(7), F.A.C., and all supporting documentation, the following Findings of Fact, Conclusions of Law, and Order are entered: FINDINGS OF FACT 1. The Florida Electric Power Coordinating Grqo&#xfd;; Incorporated, petitioned the Department to exempt those fossil fuel steam generatord'which have a heat input of more than 250 million Btu per hour and burn solid and/or liquid fuel less than 400 hours during the year from the requirement to conduct an annual particulate matter compliance test [Exhibit 1)2. Rule 62-296.405(l)(a), F.A.C., applies to those fossil fuel steam generators that are not subject to the federal standards of performance for new stationary sources (NSPS) in 40 CFR 60 and which have a heat input of more than 250 million Btu per hour.3. Rule 62-296.405(I)(a), F.A.C., limits visible emissions from affected fossil fuel steam generators to, "20 percent opacity except for either one six-miaute period per hour during which Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page ASP-1 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)not exceed 40 percent. The option selected shall be specified in the emissions unt's construction and operation permits. Emissions units governed by this visible emission limit shall test for particulate emission compliance annually and as otherwise required by Rule 62-297, F.A.C." 4. Rule 6 2-296.405(1)(a), F.A.C, further states, "Emissions units electing to test for particulate matter emission compliance quarterly shall be allowed visible emissions of 40 percent opacity. The results of such tests shall be submitted to the Department.
 
Upon demonstration that the particulate standard has been regularly complied with, the Secretary, upon petition by the applicant, shall reduce the frequency of particulate testing to no less than once annually.5. Rule 297.310(7)(a)l., F.A.C., states, "The owner or operator of a new or modified.emissions unit that is subject to an emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission linilting standard prior to obtaining an operation permit for such emissions unit." 6. Rule 297,310(7)(a)3., F.A.C., states, "The owner or operator of an emissions unit that is subject to any emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission limiting standard prior to obtaining a renewed operation permit. Emissions units that are required to conduct an annual compliance test may submit the most recent annual compliance test to satisfy the requirements of this provision.
APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Citations:
: 7. Rule 297.310(7)(a)3., F.A.C., further states, "In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or d., F.A.C., the Department shall not require submission of emission compliance test results for any emissions unit that, during the year prior to renewal: a. Did not operate; or, b. In the case of a fuel burning emissions unit, burned liquid and/or solid fuel for a total of no more than 400 hours," 8. Rule 297.3 10(7)(a)4., F.AC., states, "During each federal fiscal year (October 1 -September 30), unless otherwise specified by rule, order, or permit, the owner or operator of each emissions unit shall have a formal compliance test conducted for: a. Visible emissions, if there is an applicable standard;
The following examples illustrate the methods used in this permit to abbreviate and cite the references of rules, regulations,guidance memorandums, permit numbers and ID numbers.
: b. Each of the following pollutants, if there is an applicable standard, aid if the emissions unit emits or has the potential to emit: 5 tons per year or more of lead or lead compounds measured as elemental lead; 30 tons per year,6r.more of acrylonitrile; or 100 tons per year or more of any other regulated air pollutant..." 9. Rule 297.310(7)(a)5., F.A.C., states, "An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unit that, in a federal fiscal year, does not bum liquid and/or solid fuel, other than during startup, for a total oFmore than 400 hours." 10. Rule 297.3 10(7)(a)6., F.A.C., states, "For fossil fuel steam generators on a semi-annual particulate matter emission compliance testing schedule, a compliance test shall not be2 of '-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-2 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup." 1I. Rule 297.310(7)(a)7., F.A.C., states, "For emissions units electing to conduct particulate matter emission compliance testing quarterly pursuant to Rule 6 2-2 96.4 0 5(2)(a), F.KC., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than duing startup." [Note: The reference should be to Rule 62-296,405(l)(a), F.A.C., rather than Rule 62-29 6.405(2)(a), F.A.C.]12. The fifth edition of the U. S. Environmental Protection Agency's q9_mJ igtign ofAkr Pollutant Emission Factors, AP-42, that ernmissions ofilterable particulate from Sas-fired fossil fuel steam generators with a heat input of more than about 10 million Btu per hour may be expected to range from 0.001 to 0.006 pound per million Btu. [Exhibit 21 13. Rule 62-296.405(f)(b), F.A.C. and the federal standards of performance for new stationary sources in 40 CFR 60.42) Subpart D, limit particulate emissions from uncontrolled fossil fuel fired steam generators with a heat input of more than 250 million Btu to 0.1 pound per million Btu.CONCLUSIONS OF LAW 1. The Department hasjurisdiction to consider the matter pursuant to Section 403.061, Florida Statutes (F.S.), and Rule 62-297.620, F.A.C.2. Pursuant to Rule 62-297.310(7), F.A.C., the Department may require Petitioner to conduct compliance tests that identify the nature and quantity ofpollutant emissions, ig after investigation, it is believed that any applicable emission standard or condition of the applicable permits is being violated.3. There is reason to believe that a fossil fuel steam generator which does not burn liquid and/or solid fuel (other than during starmup) for a total ofmore than 400 hours in a federal fiscal year and complies with all other applicable limits and permit conditions is in compliance with the applicable particulate mass emission limiting standard.ORDER Having considered the requirements of Rule 62-296.405, F.AG.C, Rule 62-297.310, F.A-C., and supporting documentation, it is hereby ordered that-1. An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unitthat, in a federal fiscal year, does not burn liquid and/or solid fuel, other than during startup, for a total of more than 400 hours;--Page 3 of 8--Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page ASP-3 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)2. For Fossil fitel steam generators on a serri-annual particulate matter emisLion compliance testing schedule, a compliance test shall not be required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup;3. For emissions units electing to conduct paxtuculate matter emission compliance testing quarterly pursuant to Rule 62-296405(l)(a), F.A.C., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than during startup;4. In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or di., F.A.C., the Department shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal.5. Pursuant to Rule 62-297.310(7), F.A.C., owners of affected fossil fuel steam generators may be required to conduct compliance tests that identify the nature and quantity of pollutant emissions, if, after investigation, it is believed that any applicable emission standard or enndition of the applicable permits is being violated.6. Pursuant to Rule 62-297.310(8).
Code of Federal Regulations:
F.A.C., owners of affected fossil fuel steam generators shall subunit the compliance test report to the District Director of the Department district office having jurisdiction over the emissions unit and, where applicable, the Air Program Administrator of the appropriate Department-approved local air program wAtbin 45 days of completion of the test.PETITMON FOR ADMINMSTRATfVE REVIEW The Department will take the action described in this Order unless a timely petition for an administrative hearing is filed pursuant to sections 120.569 and 120.57 of the Florida Statutes, or a party requests mediation as an alternative remedy under section 120.573 before the deadline for filing a petition.
Example: [40 CFR 60.334]
Choosing mediation will not adversely affect the right to a hearing if mediation does not result in a settlement-The procedures for petitioning for a hearing are set forth below, followed by the procedures for requesting medialion.
Where:     40          refers to          Title 40 CFR        refers to          Code of Federal Regulations 60        refers to          Part 60 60.334    refers to          Regulation 60.334 Florida Administrative Code (F.A.C.) Rules:
A. person whose substantial interests are affet.ed by the Department's proposed decision may petition for an administrative hearing in accordance with sections 120.569 and 120.57 of the Florida Statutes.
Example: [Rule 62-213.205, F.A.C.]
The petition must contain the information set forth below and must be filed (received) in the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000.
Where:     62                    refers to          Title 62 62-213              refers to         Chapter 62-213 62-213.205          refers to          Rule 62-213.205, F.A.C.
Petitions must be filed within 21 days of receipt of this Order. A petitioner must mail a copy of the petition to the applicant at the address indicated above, at the time of filing. The falure of any person to file a petition (or a request for mediation, as discussed below) within the appropriate time period shall constitute a waiver of that person's right to request an administrative determination (hearing) under sectionas 120.569 and 120.57 of--Page 4 tf 8--Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-4 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)the Florida Statutes, or to intervene in this proceeding and participate as a party to it. Any subsequent intervention will be only at the approval of the presiding officer upon the filing of a motion in compliance with Rule 28-5.207 of the Florida Administrative Code.A petition must contain the following information: (a) The name, address, and telephone number of each petitioner, the applicant's name and address, the Department File Number, and the county in which the project is proposed;(b) A statement of how and when each petitioner received notice of the Department's action or proposed action;(c) A statement of how each petitioner's substantial interests are affected by the Department's action or proposed action;(d) A statement of the material facts disputed by each petitioner, if any;(e) A statement of facts that the petitioner contends warrant reversal or modification of the Department's action or proposed action;(f) A statement identifying the rules or statutes each petitioner contends require reversal or modification of the Department's action or proposed action; and, (g) A statement of the relief sought by each petitioner, stating precisely the action each petitioner wants the Department to take with respect to the Department's action or proposed action in the notice of intent.Because the administrative hearing process is designed to formulate final agency action, the filing of a petition means that the Department's final action may be different from the position taken by it in this Order. Persons whose substantial interests will be affected by any such final decision of the Department on the application have the right to petition to become a party to the proeeding, in accordance with the requirements set forth above.A person whose substantial interests are affected by the Department's proposed decision, may elect to pursue mediation by asking all parties to the proceeding to agree to such mediation and by filing with the Department a request for mediation and the written agreement of all such parties to mediate the dispute. The request and agreement must be filed in (received by) the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000, by the same deadline as set forth above for the filing of a petition.A request for mediation must contain the following information:
Identification Numbers:
--Page 5 of 8-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-5 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)(a) The namre address, and telephone number of the person requesting mediation a~nd that person's representative, if any, (b) A statement of the preliminary agency action;(c) A statement of the relief sought; and (d) Either an explanation of how the requester's substantial interests will be affected by the action or proposed action addressed in this notice of intent or a statement clearly identifying the petition for hearing that the requester has already filed, and incorporating it by reference.
Facility Identification (ID) Number:
The agreement to mediate must include the following: (a) The names, addresses, and telephone numbers of any persons who may attend the mediation;(b) The name, address, and telephone number of the mediator selected by the parties, or a provision for selecting a mediator within a specified time;(c) The agreed allocation of the costs and fees associated with the mediation;(d) The agreement of the parties on the confidentiality of discussions and documents introduced during mediation;(c) The date, time, and place of the first mediation session, or a deadline for holding the first session, if no mediator has yet been chosen;(f) The name of each party's representative who shall have authority to settle or recommend settlement; and (g) The siignatures of all parties or their authorized representatives.
Example: Facility ID No.: 1050221 Where:
As provided in section 120.573 of the Florida StV'tes, the timely agreement of all parties to mediate will toll the tima lirmitations imposed by sectiorti 120.569 and 120.57 for requesting and holding an administrative hearing Unless otherwis'agreed by the parties, the mediation must be concluded within sixty days of the execution of the agreement.
105  =      3-digit number code identifying the facility is located in Polk County 0221    =      4-digit number assigned by state database.
If mediation results in settlement of the administrative dispute, the Department must enter a final order incorporating the agreement of the parties. Persons whose substantial interests will be affected by such a modified final decision of the Department have a right to petition for a hearing only in accordance with the requirements for such petitions set forth above, If mediation terminates without settlement of the dispute, the Department shall notify all parties in writing that the administrative hearing processes under sections 120.569 and 120,57 remain available for disposition of the dispute, and the notice will--.ge 6 of e-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-6 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)specify the deadlines that then will apply for challenging the agency action and electing remedies under those two statutes.In addition to the above, a person subject to regulation has a right to apply for a variance from or waiver of the requirements of particular rules, on certain conditions, under section 120.542 of the Florida Statutes.
Permit Numbers:
The relief provided by this state statute applies only to state rules, not statutes, and not to any federal regulatory requirements.
Example: 1050221-002-AV, or 1050221-001-AC Where:
Applying for a variance or waiver does not substitute or extend the time for filing a petition for an administrative hearing or exercising any other right that a person may have in relation to the action proposed in this notice of intent.The application for a variance or waiver is made by filing a petition with the Office of General Counsel of the Department, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000.
AC =          Air Construction Permit AV =          Air Operation Permit (Title V Source) 105 =        3-digit number code identifying the facility is located in Polk County 0221=          4-digit number assigned by permit tracking database 001 or 002=  3-digit sequential project number assigned by permit tracking database Example: PSD-FL-185 PA95-01 AC53-208321 Where:
The petition must specify tie following inlormation;(a) The nami, address, and telephone number of the petitioner;(h) The name, address, and telephone number of the attorney or qualified representative of the petitioner, if any, (c) Each rule or portion of a rule from which a variance or waiver is requested;(d) The citation to the statute underlying (implemented by) the rule identilied in (c) above;(c) The type of action requested;(f) The specific facts that would justify a variance or waiver for the petitioner;(g) The reason why the variance or waiver would serve the purposes of'the underlying statute (implemented by the rule); and (h) A statement whether the variance or waiver'isjermanent or temporary and, if temporary, a statement of the dates showing the duration of the variance or waiver requested.
PSD      =    Prevention of Significant Deterioration Permit PA      =    Power Plant Siting Act Permit AC53    =    old Air Construction Permit numbering identifying the facility is located in Polk County Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                        Title V Permit Renewal Page A - 2 of 2
The Department will grant a variance or waiver, when the petition demonstrates both that the application of the rule would create a substantial hardship or violate principles of fairness, as each of those terms is defined in section 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner.
 
Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or waivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully-Page 7 of S-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-7 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)each of those terms is defined in section 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner.
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)
Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or w'aivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully enforceable by the Administrator of the EPA and by any person under the Clian Air Act unless and until the Administrator separately approves any variance or waiver in accordance with the procedures of the federal program.This Order constitutes final agency action unless a petition is filed in accordance with the above paragraphs.
STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of                                    )
Upon timely filing of a petition, this Order will not be effective until further Order of the Department.
                                                                      )
Florida Electric Power Coordinating Group, Inc.,    )              ASP No. 97-13-01 Petitioner.                                         ))
ORDER ON REOQUE51 ALTENATE PROCEDURES AND REOUrREM-_QLi Pursuant to Rule 62-297.620, Florida Administrative Code (F.AC.), the Florida Electric Coordinating Group, Incorporated, (FCG) petitioned for approval to: (1) Exempt fossil fuel steam generators which burn liquid and/or solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter complianee test; and, (2) Exempt fossil fuel steam generators which burn liquid andlor solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter compliance test during the year prior to renewal of an operation permit. This Order is intended to clarify particulate testing requirements for those fossil fuel steam generators which primarily burn gaseous fuels including but not necessarily limited to natural gas.
Having considered the provisions ofRule 62-296.40S(Il), F.A.C., Rule 62-297.310(7), F.A.C.,
and all supporting documentation, the following Findings of Fact, Conclusions of Law, and Order are entered:
FINDINGS OF FACT
: 1. The Florida Electric Power Coordinating Grqo&#xfd;; Incorporated, petitioned the Department to exempt those fossil fuel steam generatord'which have a heat input of more than 250 million Btu per hour and burn solid and/or liquid fuel less than 400 hours during the year from the requirement to conduct an annual particulate matter compliance test [Exhibit 1)
: 2. Rule 62-296.405(l)(a), F.A.C., applies to those fossil fuel steam generators that are not subject to the federal standards of performance for new stationary sources (NSPS) in 40 CFR 60 and which have a heat input of more than 250 million Btu per hour.
: 3. Rule 62-296.405(I)(a), F.A.C., limits visible emissions from affected fossil fuel steam generators to, "20 percent opacity except for either one six-miaute period per hour during which Progress Energy Florida, Inc.                                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                                        Title V Permit Renewal Page ASP-1 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) not exceed 40 percent. The option selected shall be specified in the emissions unt's construction and operation permits. Emissions units governed by this visible emission limit shall test for particulate emission compliance annually and as otherwise required by Rule 62-297, F.A.C."
: 4. Rule 6 2-296.405(1)(a), F.A.C, further states, "Emissions units electing to test for particulate matter emission compliance quarterly shall be allowed visible emissions of 40 percent opacity. The results of such tests shall be submitted to the Department. Upon demonstration that the particulate standard has been regularly complied with, the Secretary, upon petition by the applicant, shall reduce the frequency of particulate testing to no less than once annually.
: 5. Rule 297.310(7)(a)l., F.A.C., states, "The owner or operator of a new or modified.
emissions unit that is subject to an emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission linilting standard prior to obtaining an operation permit for such emissions unit."
: 6. Rule 297,310(7)(a)3., F.A.C., states, "The owner or operator of an emissions unit that is subject to any emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission limiting standard prior to obtaining a renewed operation permit. Emissions units that are required to conduct an annual compliance test may submit the most recent annual compliance test to satisfy the requirements of this provision.
: 7. Rule 297.310(7)(a)3., F.A.C., further states, "In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or d., F.A.C., the Department shall not require submission of emission compliance test results for any emissions unit that, during the year prior to renewal: a. Did not operate; or, b. In the case of a fuel burning emissions unit, burned liquid and/or solid fuel for a total of no more than 400 hours,"
: 8. Rule 297.3 10(7)(a)4., F.AC., states, "During each federal fiscal year (October 1 -
September 30), unless otherwise specified by rule, order, or permit, the owner or operator of each emissions unit shall have a formal compliance test conducted for: a. Visible emissions, if there is an applicable standard; b. Each of the following pollutants, if there is an applicable standard, aid if the emissions unit emits or has the potential to emit: 5 tons per year or more of lead or lead compounds measured as elemental lead; 30 tons per year,6r.more of acrylonitrile; or 100 tons per year or more of any other regulated air pollutant..."
: 9. Rule 297.310(7)(a)5., F.A.C., states, "An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unit that, in a federal fiscal year, does not bum liquid and/or solid fuel, other than during startup, for a total oFmore than 400 hours."
: 10. Rule 297.3 10(7)(a)6., F.A.C., states, "For fossil fuel steam generators on a semi-annual particulate matter emission compliance testing schedule, a compliance test shall not be
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Progress Energy Florida, Inc.                                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Permit Renewal Page ASP-2 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup."
1I. Rule 297.310(7)(a)7., F.A.C., states, "For emissions units electing to conduct particulate matter emission compliance testing quarterly pursuant to Rule 6 2 -2 96. 40 5(2)(a),
F.KC., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than duing startup." [Note: The reference should be to Rule 62-296,405(l)(a), F.A.C., rather than Rule 62-29 6 .405(2)(a), F.A.C.]
: 12. The fifth edition of the U. S. Environmental Protection Agency's q9_mJigtign ofAkr Pollutant Emission Factors, AP-42, that ernmissions ofilterable particulate from Sas-fired fossil fuel steam generators with a heat input of more than about 10 million Btu per hour may be expected to range from 0.001 to 0.006 pound per million Btu. [Exhibit 21
: 13. Rule 62-296.405(f)(b), F.A.C. and the federal standards of performance for new stationary sources in 40 CFR 60.42) Subpart D, limit particulate emissions from uncontrolled fossil fuel fired steam generators with a heat input of more than 250 million Btu to 0.1 pound per million Btu.
CONCLUSIONS OF LAW
: 1. The Department hasjurisdiction to consider the matter pursuant to Section 403.061, Florida Statutes (F.S.), and Rule 62-297.620, F.A.C.
: 2. Pursuant to Rule 62-297.310(7), F.A.C., the Department may require Petitioner to conduct compliance tests that identify the nature and quantity ofpollutant emissions, ig after investigation, it is believed that any applicable emission standard or condition of the applicable permits is being violated.
: 3. There is reason to believe that a fossil fuel steam generator which does not burn liquid and/or solid fuel (other than during starmup) for a total ofmore than 400 hours in a federal fiscal year and complies with all other applicable limits and permit conditions is in compliance with the applicable particulate mass emission limiting standard.
ORDER Having considered the requirements of Rule 62-296.405, F.AG.C, Rule 62-297.310, F.A-C.,
and supporting documentation, it is hereby ordered that-
: 1. An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unitthat, in a federal fiscal year, does not burn liquid and/or solid fuel, other than during startup, for a total of more than 400 hours;
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Progress Energy Florida, Inc.                                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Permit Renewal Page ASP-3 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)
: 2. For Fossil fitel steam generators on a serri-annual particulate matter emisLion compliance testing schedule, a compliance test shall not be required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup;
: 3. For emissions units electing to conduct paxtuculate matter emission compliance testing quarterly pursuant to Rule 62-296405(l)(a), F.A.C., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than during startup;
: 4. In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or di.,
F.A.C., the Department shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal.
: 5. Pursuant to Rule 62-297.310(7), F.A.C., owners of affected fossil fuel steam generators may be required to conduct compliance tests that identify the nature and quantity of pollutant emissions, if, after investigation, it is believed that any applicable emission standard or enndition of the applicable permits is being violated.
: 6. Pursuant to Rule 62-297.310(8). F.A.C., owners of affected fossil fuel steam generators shall subunit the compliance test report to the District Director of the Department district office having jurisdiction over the emissions unit and, where applicable, the Air Program Administrator of the appropriate Department-approved local air program wAtbin 45 days of completion of the test.
PETITMON FOR ADMINMSTRATfVE REVIEW The Department will take the action described in this Order unless a timely petition for an administrative hearing is filed pursuant to sections 120.569 and 120.57 of the Florida Statutes, or a party requests mediation as an alternative remedy under section 120.573 before the deadline for filing a petition. Choosing mediation will not adversely affect the right to a hearing if mediation does not result in a settlement- The procedures for petitioning for a hearing are set forth below, followed by the procedures for requesting medialion.
A.person whose substantial interests are affet.ed by the Department's proposed decision may petition for an administrative hearing in accordance with sections 120.569 and 120.57 of the Florida Statutes. The petition must contain the information set forth below and must be filed (received) in the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000. Petitions must be filed within 21 days of receipt of this Order. A petitioner must mail a copy of the petition to the applicant at the address indicated above, at the time of filing. The falure of any person to file a petition (or a request for mediation, as discussed below) within the appropriate time period shall constitute a waiver of that person's right to request an administrative determination (hearing) under sectionas 120.569 and 120.57 of
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Progress Energy Florida, Inc.                                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Permit Renewal Page ASP-4 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) the Florida Statutes, or to intervene in this proceeding and participate as a party to it. Any subsequent intervention will be only at the approval of the presiding officer upon the filing of a motion in compliance with Rule 28-5.207 of the Florida Administrative Code.
A petition must contain the following information:
(a) The name, address, and telephone number of each petitioner, the applicant's name and address, the Department File Number, and the county in which the project is proposed; (b) A statement of how and when each petitioner received notice of the Department's action or proposed action; (c) A statement of how each petitioner's substantial interests are affected by the Department's action or proposed action; (d) A statement of the material facts disputed by each petitioner, if any; (e) A statement of facts that the petitioner contends warrant reversal or modification of the Department's action or proposed action; (f) A statement identifying the rules or statutes each petitioner contends require reversal or modification of the Department's action or proposed action; and, (g) A statement of the relief sought by each petitioner, stating precisely the action each petitioner wants the Department to take with respect to the Department's action or proposed action in the notice of intent.
Because the administrative hearing process is designed to formulate final agency action, the filing of a petition means that the Department's final action may be different from the position taken by it in this Order. Persons whose substantial interests will be affected by any such final decision of the Department on the application have the right to petition to become a party to the proeeding, in accordance with the requirements set forth above.
A person whose substantial interests are affected by the Department's proposed decision, may elect to pursue mediation by asking all parties to the proceeding to agree to such mediation and by filing with the Department a request for mediation and the written agreement of all such parties to mediate the dispute. The request and agreement must be filed in (received by) the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000, by the same deadline as set forth above for the filing of a petition.
A request for mediation must contain the following information:
                                                              -- Page 5 of 8-Progress Energy Florida, Inc.                                                                                Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Permit Renewal Page ASP-5 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)
(a) The namre address, and telephone number of the person requesting mediation a~nd that person's representative, if any, (b) A statement of the preliminary agency action; (c) A statement of the relief sought; and (d) Either an explanation of how the requester's substantial interests will be affected by the action or proposed action addressed in this notice of intent or a statement clearly identifying the petition for hearing that the requester has already filed, and incorporating it by reference.
The agreement to mediate must include the following:
(a) The names, addresses, and telephone numbers of any persons who may attend the mediation; (b) The name, address, and telephone number of the mediator selected by the parties, or a provision for selecting a mediator within a specified time; (c) The agreed allocation of the costs and fees associated with the mediation; (d) The agreement of the parties on the confidentiality of discussions and documents introduced during mediation; (c) The date, time, and place of the first mediation session, or a deadline for holding the first session, if no mediator has yet been chosen; (f) The name of each party's representative who shall have authority to settle or recommend settlement; and (g) The siignatures of all parties or their authorized representatives.
As provided in section 120.573 of the Florida StV'tes, the timely agreement of all parties to mediate will toll the tima lirmitations imposed by sectiorti 120.569 and 120.57 for requesting and holding an administrative hearing Unless otherwis'agreed by the parties, the mediation must be concluded within sixty days of the execution of the agreement. If mediation results in settlement of the administrative dispute, the Department must enter a final order incorporating the agreement of the parties. Persons whose substantial interests will be affected by such a modified final decision of the Department have a right to petition for a hearing only in accordance with the requirements for such petitions set forth above, If mediation terminates without settlement of the dispute, the Department shall notify all parties in writing that the administrative hearing processes under sections 120.569 and 120,57 remain available for disposition of the dispute, and the notice will
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APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) specify the deadlines that then will apply for challenging the agency action and electing remedies under those two statutes.
In addition to the above, a person subject to regulation has a right to apply for a variance from or waiver of the requirements of particular rules, on certain conditions, under section 120.542 of the Florida Statutes. The relief provided by this state statute applies only to state rules, not statutes, and not to any federal regulatory requirements. Applying for a variance or waiver does not substitute or extend the time for filing a petition for an administrative hearing or exercising any other right that a person may have in relation to the action proposed in this notice of intent.
The application for a variance or waiver is made by filing a petition with the Office of General Counsel of the Department, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000.
The petition must specify tie following inlormation; (a) The nami, address, and telephone number of the petitioner; (h) The name, address, and telephone number of the attorney or qualified representative of the petitioner, if any, (c) Each rule or portion of a rule from which a variance or waiver is requested; (d) The citation to the statute underlying (implemented by) the rule identilied in (c) above; (c) The type of action requested; (f) The specific facts that would justify a variance or waiver for the petitioner; (g) The reason why the variance or waiver would serve the purposes of'the underlying statute (implemented by the rule); and (h) A statement whether the variance or waiver'isjermanent or temporary and, if temporary, a statement of the dates showing the duration of the variance or waiver requested.
The Department will grant a variance or waiver, when the petition demonstrates both that the application of the rule would create a substantial hardship or violate principles of fairness, as each of those terms is defined in section 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner. Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or waivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully
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APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) each of those terms is defined insection 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner. Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or w'aivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully enforceable by the Administrator of the EPA and by any person under the Clian Air Act unless and until the Administrator separately approves any variance or waiver in accordance with the procedures of the federal program.
This Order constitutes final agency action unless a petition is filed in accordance with the above paragraphs. Upon timely filing of a petition, this Order will not be effective until further Order of the Department.
RIGHT TO APPEAL Any party to this Order has the right to seek judicial review of the Order pursuant to Section 120.68, F.S., by the filing of a Notice of Appeal pursuant to Rule 9.110, Florida Rules of Appellate Procedure, with the Clerk of the Department in the Office of General Counsel, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000; and, by filing a copy of the Notice of Appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The Notice of Appeal must be filed within 30 days from the date the Notice of Agency Action is filed with the Clerk of the Department.
RIGHT TO APPEAL Any party to this Order has the right to seek judicial review of the Order pursuant to Section 120.68, F.S., by the filing of a Notice of Appeal pursuant to Rule 9.110, Florida Rules of Appellate Procedure, with the Clerk of the Department in the Office of General Counsel, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000; and, by filing a copy of the Notice of Appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The Notice of Appeal must be filed within 30 days from the date the Notice of Agency Action is filed with the Clerk of the Department.
DONE AND ORDERED this J&#xfd;j day of -W -- 1997 in Tallahassee, Florida.STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION HOWARDI J P HODES, Director Division of Ar Re-sources Management Twin To'*ers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114-Page 8 of .-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-8 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)CERTIMCATF OF SERVICE The undersigned duly designated deputy clerk hereby certifies that a copy of the foregoing was mailed to Rich Piper, Chair, Florida Power Coordinatin, Group, Inc., 405 Reo Street, Suite 100, Tampa, Florida 33609-1004, 'on this day of March 1997.Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to&sect;120.52C7), Florida Statutes, with the designated Department Clerk, receipt of which is hereby acknowledged.
DONE AND ORDERED this           J&#xfd;j day of -W             -- 1997 in Tallahassee, Florida.
Cl6k Date Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page ASP-9 of 10 APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of: ))Florida Electric Power Coordinating Group, Inc., ))ASP No. 97-B-01 Petitioner.
STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION HOWARDI P J HODES, Director Division of Ar Re-sources Management Twin To'*ers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114
)ORDER CORRECTING SCRIVENER'S ERROR\ The Order which authorizes owners of natural gas fired fossil fuel steam generators to forgo particulate matter compliance testing on an annual basis and prior to renewal of an operation permit entered on the 17th day of March, 1997, is hereby corrected on page 4, paragraph number 4, by deleting the words "pursuant to Rule 62-210.300(2)(a)3.b., c., or d., F,.A. C,": 4. In renewing an air operation permit pUSant--t-Rulc 62 210.3 -.b,,the Department, shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal.DONE AND ORDERED this c day of 1997 in Tallahassee, Florida.I (j (7 STATE OFFLORIDA DEPARTMENT OF ENVIRONWMENTAL PROTECTION HOWARD L. RHODES, Director Division of Air Resources Management Twin Towers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page ASP-10 of 10 APPENDIX CAM Compliance Assurance Monitoring Plan Pursuant to Rule 62-213.440(1)(b)l.a., F.A.C., the CAM plans that are included in this appendix contain the monitoring requirements necessary to satisfy 40 CFR 64. Conditions  
                                                            -Page 8 of .-
: 1. -17. are generic conditions applicable to all emissions units that are subject to the CAM requirements.
Progress Energy Florida, Inc.                                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                                       Title V Permit Renewal Page ASP-8 of 10
Specific requirements related to each emissions unit are contained in the attached tables, as submitted by the applicant and approved by the Department.
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)
CERTIMCATF OF SERVICE The undersigned duly designated deputy clerk hereby certifies that a copy of the foregoing was mailed to Rich Piper, Chair, Florida Power Coordinatin, Group, Inc.,
405 Reo Street, Suite 100, Tampa, Florida 33609-1004, 'on this
* day of March 1997.
Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to
                                                                &sect;120.52C7), Florida Statutes, with the designated Department Clerk, receipt of which is hereby acknowledged.
Cl6k               Date Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                Title V Permit Renewal Page ASP-9 of 10
 
APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)
STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of:                                     )
Florida Electric Power Coordinating Group, Inc.,
                                                            ))
ASP No. 97-B-01
                                                            )
Petitioner.                                           )
ORDER CORRECTING SCRIVENER'S ERROR
            \ The Order which authorizes owners of natural gas fired fossil fuel steam generators to forgo particulate matter compliance testing on an annual basis and prior to renewal of an operation permit entered on the 17th day of March, 1997, is hereby corrected on page 4, paragraph number 4, by deleting the words "pursuant to Rule 62-210.300(2)(a)3.b., c., or d.,
F,.A. C,":
: 4. In renewing an air operation permit pUSant--t-Rulc 62 210.3 00(24(*c, -.b,,
iA*-k. the Department, shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal.
DONE AND ORDERED this c I  day of (j (7        1997 in Tallahassee, Florida.
STATE OFFLORIDA DEPARTMENT OF ENVIRONWMENTAL PROTECTION HOWARD L. RHODES, Director Division of Air Resources Management Twin Towers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114 Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                      Title V Permit Renewal Page ASP-10 of 10
 
APPENDIX CAM Compliance Assurance Monitoring Plan Pursuant to Rule 62-213.440(1)(b)l.a., F.A.C., the CAM plans that are included in this appendix contain the monitoring requirements necessary to satisfy 40 CFR 64. Conditions 1. - 17. are generic conditions applicable to all emissions units that are subject to the CAM requirements. Specific requirements related to each emissions unit are contained in the attached tables, as submitted by the applicant and approved by the Department.
40 CFR 64.6 Approval of Monitoring.
40 CFR 64.6 Approval of Monitoring.
: 1. The attached CAM plan(s), as submitted by the applicant, is/are approved for the purposes of satisfying the requirements of 40 CFR 64.3. [40 CFR 64.6(a)]2. The attached CAM plan(s) include the following information:
: 1. The attached CAM plan(s), as submitted by the applicant, is/are approved for the purposes of satisfying the requirements of 40 CFR 64.3. [40 CFR 64.6(a)]
: 2. The attached CAM plan(s) include the following information:
: a. The indicator(s) to be monitored (such as temperature, pressure drop, emissions, or similar parameter);
: a. The indicator(s) to be monitored (such as temperature, pressure drop, emissions, or similar parameter);
: b. The means or device to be used to measure the indicator(s) (such as temperature measurement device, visual observation, or CEMS); and c. The performance requirements established to satisfy 40 CFR 64.3(b) or (d), as applicable.
: b. The means or device to be used to measure the indicator(s) (such as temperature measurement device, visual observation, or CEMS); and
: c. The performance requirements established to satisfy 40 CFR 64.3(b) or (d), as applicable.
[40 CFR 64.6(c)(1)]
[40 CFR 64.6(c)(1)]
: 3. The attached CAM plan(s) describe the means by which the owner or operator will define an exceedance of the permitted limits or an excursion from the stated indicator ranges and averaging periods for purposes of responding to (see CAM Conditions  
: 3. The attached CAM plan(s) describe the means by which the owner or operator will define an exceedance of the permitted limits or an excursion from the stated indicator ranges and averaging periods for purposes of responding to (see CAM Conditions 5. - 9.) and reporting exceedances or excursions (see CAM Conditions
: 5. -9.) and reporting exceedances or excursions (see CAM Conditions
: 10. - 14.). [40 CFR 64.6(c)(2)]
: 10. -14.). [40 CFR 64.6(c)(2)]
: 4. The permittee is required to conduct the monitoring specified in the attached CAM plan(s) and shall fulfill the obligations specified in the conditions below (see CAM Conditions 5. - 17.). [40 CFR 64.6(c)(3)]
: 4. The permittee is required to conduct the monitoring specified in the attached CAM plan(s) and shall fulfill the obligations specified in the conditions below (see CAM Conditions  
: 5. -17.). [40 CFR 64.6(c)(3)]
40 CFR 64.7 Operation of Approved Monitorin2.
40 CFR 64.7 Operation of Approved Monitorin2.
: 5. Commencement of Operation.
: 5. Commencement of Operation. The owner or operator shall conduct the monitoring required under this appendix upon the effective date of this Title V permit. [40 CFR 64.7(a)]
The owner or operator shall conduct the monitoring required under this appendix upon the effective date of this Title V permit. [40 CFR 64.7(a)]6. Proper Maintenance.
: 6. Proper Maintenance. At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment. [40 CFR 64.7(b)]
At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment.  
: 7. Continued Operation. Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of this part, including data averages and calculations, or fulfilling a minimum data availability requirement, if applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions. [40 CFR 64.7(c)]
[40 CFR 64.7(b)]7. Continued Operation.
: 8. Response To Excursions or Exceedances.
Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating.
: a. Upon detecting an excursion or exceedance, the owner or operator shall restore operation of the pollutant-specific emissions unit (including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions. The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance (other than those caused by excused startup or shutdown conditions, if allowed by this permit). Such actions may include initial inspection and evaluation, recording that operations returned to normal without operator action (such as through response by a computerized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the applicable emission limitation or standard, as applicable.
Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of this part, including data averages and calculations, or fulfilling a minimum data availability requirement, if applicable.
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                                           Title V Permit Renewal Page CAM-1 of 4
The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions.  
 
[40 CFR 64.7(c)]8. Response To Excursions or Exceedances.
APPENDIX CAM Compliance Assurance Monitoring Plan
: a. Upon detecting an excursion or exceedance, the owner or operator shall restore operation of the pollutant-specific emissions unit (including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions.
: b. Determination of whether the owner or operator has used acceptable procedures in response to an excursion or exceedance will be based on information available, which may include but is not limited to, monitoring results, review of operation and maintenance procedures and records, and inspection of the control device, associated capture system, and the process.
The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance (other than those caused by excused startup or shutdown conditions, if allowed by this permit). Such actions may include initial inspection and evaluation, recording that operations returned to normal without operator action (such as through response by a computerized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the applicable emission limitation or standard, as applicable.
[40 CFR 64.7(d)(1) & (2)]
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-1 of 4 APPENDIX CAM Compliance Assurance Monitoring Plan b. Determination of whether the owner or operator has used acceptable procedures in response to an excursion or exceedance will be based on information available, which may include but is not limited to, monitoring results, review of operation and maintenance procedures and records, and inspection of the control device, associated capture system, and the process.[40 CFR 64.7(d)(1)  
: 9. Documentation of Need for Improved Monitoring. If the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the permitting authority and, if necessary, submit a proposed modification to the Title V permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions, modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters. [40 CFR 64.7(e)]
& (2)]9. Documentation of Need for Improved Monitoring.
40 CFR 64.8 Quality Improvement Plan (QIP) Requirements.
If the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the permitting authority and, if necessary, submit a proposed modification to the Title V permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions, modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters.  
: 10. Based on the results of a determination made under CAM Condition 8.a., above, the permitting authority may require the owner or operator to develop and implement a QIP. Consistent with CAM Condition 4., an accumulation of exceedances or excursions exceeding 5 percent duration of a pollutant-specific emissions unit's operating time for a reporting period, may require the implementation of a QIP. The threshold may be set at a higher or lower percent or may rely on other criteria for purposes of indicating whether a pollutant-specific emissions unit is being maintained and operated in a manner consistent with good air pollution control practices. [40 CFR 64.8(a)]
[40 CFR 64.7(e)]40 CFR 64.8 Quality Improvement Plan (QIP) Requirements.
: 11. Elements of a QIP:
: 10. Based on the results of a determination made under CAM Condition 8.a., above, the permitting authority may require the owner or operator to develop and implement a QIP. Consistent with CAM Condition 4., an accumulation of exceedances or excursions exceeding 5 percent duration of a pollutant-specific emissions unit's operating time for a reporting period, may require the implementation of a QIP. The threshold may be set at a higher or lower percent or may rely on other criteria for purposes of indicating whether a pollutant-specific emissions unit is being maintained and operated in a manner consistent with good air pollution control practices.  
: a. The owner or operator shall maintain a written QIP, if required, and have it available for inspection.
[40 CFR 64.8(a)]11. Elements of a QIP: a. The owner or operator shall maintain a written QIP, if required, and have it available for inspection.
: b. The plan initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate:
: b. The plan initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate:
(1) Improved preventive maintenance practices.
(1) Improved preventive maintenance practices.
(2) Process operation changes.(3) Appropriate improvements to control methods.(4) Other steps appropriate to correct control performance.
(2) Process operation changes.
(5) More frequent or improved monitoring (only in conjunction with one or more steps under CAM Condition 11.b(i) through (iv), above).[40 CFR 64.8(b)]12. If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the permitting authority if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined.  
(3) Appropriate improvements to control methods.
[40 CFR 64.8(c)]13. Following implementation of a QIP, upon any subsequent determination pursuant to CAM Condition 8.b., the permitting authority may require that an owner or operator make reasonable changes to the QIP if the QIP is found to have: a. Failed to address the cause of the control device performance problems; or b. Failed to provide adequate procedures for correcting control device performance problems as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions.
(4) Other steps appropriate to correct control performance.
[40 CFR 64.8(d)]14. Implementation of a QIP shall not excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. [40 CFR 64.8(e)]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-2 of 4 APPENDIX CAM Compliance Assurance Monitoring Plan 40 CFR 64.9 Reporting And Recordkeeping Requirements.
(5) More frequent or improved monitoring (only in conjunction with one or more steps under CAM Condition 11.b(i) through (iv), above).
[40 CFR 64.8(b)]
: 12. If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the permitting authority if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined. [40 CFR 64.8(c)]
: 13. Following implementation of a QIP, upon any subsequent determination pursuant to CAM Condition 8.b.,
the permitting authority may require that an owner or operator make reasonable changes to the QIP if the QIP is found to have:
: a. Failed to address the cause of the control device performance problems; or
: b. Failed to provide adequate procedures for correcting control device performance problems as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions.
[40 CFR 64.8(d)]
: 14. Implementation of a QIP shall not excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. [40 CFR 64.8(e)]
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page CAM-2 of 4
 
APPENDIX CAM Compliance Assurance Monitoring Plan 40 CFR 64.9 Reporting And Recordkeeping Requirements.
: 15. General reporting requirements.
: 15. General reporting requirements.
: a. On and after the date specified in CAM Condition  
: a. On and after the date specified in CAM Condition 5. by which the owner or operator must use monitoring that meets the requirements of this appendix, the owner or operator shall submit monitoring reports semi-annually to the permitting authority in accordance with Rule 62-213.440(1)(b)3.a., F.A.C.
: 5. by which the owner or operator must use monitoring that meets the requirements of this appendix, the owner or operator shall submit monitoring reports semi-annually to the permitting authority in accordance with Rule 62-213.440(1)(b)3.a., F.A.C.b. A report for monitoring under this part shall include, at a minimum, the information required under Rule 62-213.440(1)(b)3.a., F.A.C., and the following information, as applicable:
: b. A report for monitoring under this part shall include, at a minimum, the information required under Rule 62-213.440(1)(b)3.a., F.A.C., and the following information, as applicable:
(1) Summary information on the number, duration and cause (including unknown cause, if applicable) of excursions or exceedances, as applicable, and the corrective actions taken;(2) Summary information on the number, duration and cause (including unknown cause, if applicable) for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable);
(1) Summary information on the number, duration and cause (including unknown cause, if applicable) of excursions or exceedances, as applicable, and the corrective actions taken; (2) Summary information on the number, duration and cause (including unknown cause, if applicable) for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable); and (3) A description of the actions taken to implement a QIP during the reporting period as specified in CAM Conditions 10. through 14. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring.
and (3) A description of the actions taken to implement a QIP during the reporting period as specified in CAM Conditions  
[40 CFR 64.9(a)]
: 10. through 14. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring.
: 16. General recordkeeping requirements.
[40 CFR 64.9(a)]16. General recordkeeping requirements.
: a. The owner or operator shall comply with the recordkeeping requirements specified in Rule 62-213.440(1)(b)2., F.A.C. The owner or operator shall maintain records of monitoring data, monitor performance data, corrective actions taken, any written quality improvement plan required pursuant to CAM Conditions 10. through 14., and any activities undertaken to implement a quality improvement plan, and other supporting information required to be maintained under this part (such as data used to document the adequacy of monitoring, or records of monitoring maintenance or corrective actions).
: a. The owner or operator shall comply with the recordkeeping requirements specified in Rule 62-213.440(1)(b)2., F.A.C. The owner or operator shall maintain records of monitoring data, monitor performance data, corrective actions taken, any written quality improvement plan required pursuant to CAM Conditions  
: b. Instead of paper records, the owner or operator may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements.
: 10. through 14., and any activities undertaken to implement a quality improvement plan, and other supporting information required to be maintained under this part (such as data used to document the adequacy of monitoring, or records of monitoring maintenance or corrective actions).b. Instead of paper records, the owner or operator may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements.
[40 CFR 64.9(b)]
[40 CFR 64.9(b)]40 CFR 64.10 Savings Provisions.
40 CFR 64.10 Savings Provisions.
: 17. It should be noted that nothing in this appendix shall: a. Excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. The requirements of this appendix shall not be used to justify the approval of monitoring less stringent than the monitoring which is required under separate legal authority and are not intended to establish minimum requirements for the purpose of determining the monitoring to be imposed under separate authority under the Act, including monitoring in permits issued pursuant to Title I of the Act. The purpose of this part is to require, as part of the issuance of a permit under Title V of the Act, improved or new monitoring at those emissions units where monitoring requirements do not exist or are inadequate to meet the requirements of this part.b. Restrict or abrogate the authority of the Administrator or the permitting authority to impose additional or more stringent monitoring, recordkeeping, testing, or reporting requirements on any owner or operator of a source under any provision of the Act, including but not limited to sections 1 14(a)(1) and 504(b), or state law, as applicable.
: 17. It should be noted that nothing in this appendix shall:
: c. Restrict or abrogate the authority of the Administrator or permitting authority to take any enforcement action under the Act for any violation of an applicable requirement or of any person to take action under section 304 of the Act.[40 CFR 64.10]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-3 of 4 APPENDIX CAM Compliance Assurance Monitoring Plan Emissions Units 001, 002, 003 & 004 Two tangentially fired coal units and two dry bottom wall-fired units;Particulate Matter emissions controlled by Electrostatic Precipitators Monitoring Approach Indicator 1. Indicator Opacity.Measurement Approach Continuous opacity monitoring system (COMS).II. Indicator Range For Units 2, 4 and 5, an excursion is defined as any 1 hour of opacity greater than 15% (other than startup, shutdown, "load-changing" and sootblowing periods).For Unit 1, an excursion is defined as any 1 hour of opacity greater than 22%(other than startup, shutdown, "load-changing" and sootblowing periods).Load-changing occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more.An excursion will trigger an evaluation of operation of the boiler(s) and ESP(s). Corrective action will be taken as necessary.
: a. Excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. The requirements of this appendix shall not be used to justify the approval of monitoring less stringent than the monitoring which is required under separate legal authority and are not intended to establish minimum requirements for the purpose of determining the monitoring to be imposed under separate authority under the Act, including monitoring in permits issued pursuant to Title I of the Act. The purpose of this part is to require, as part of the issuance of a permit under Title V of the Act, improved or new monitoring at those emissions units where monitoring requirements do not exist or are inadequate to meet the requirements of this part.
Any excursion will trigger recordkeeping and reporting requirements.
: b. Restrict or abrogate the authority of the Administrator or the permitting authority to impose additional or more stringent monitoring, recordkeeping, testing, or reporting requirements on any owner or operator of a source under any provision of the Act, including but not limited to sections 1 14(a)(1) and 504(b), or state law, as applicable.
III. Performance Criteria A. Data Based on available opacity data while stack testing, the representative stack Representativeness opacity of units 2, 4 and 5 is in the range of 2 to 12%. Based upon available opacity data while stack testing, the representative stack opacity of Unit 1 is in the range of 5 to 20%.B. Verification of Annual testing during normal operation is used to verify particulate mass Operational Status loading. The COM system is audited quarterly.
: c. Restrict or abrogate the authority of the Administrator or permitting authority to take any enforcement action under the Act for any violation of an applicable requirement or of any person to take action under section 304 of the Act.
C. QA/QC Practices and Operate COMS according to 40 CFR Part 60 Appendix B, Performance Criteria Specification 1 and general provisions 60.13. The COMS is automatically calibrated every 24 hours. Calibration information is recorded through a data acquisition system (DAS). A neutral density filter test is performed quarterly as well as preventive maintenance items; replace filters, clean optics, etc., as prescribed by the manufacturer.
[40 CFR 64.10]
D. Monitoring Frequency Opacity is monitored continuously.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                       Title V Permit Renewal Page CAM-3 of 4
E. Data Collection The COMS collects data that are reduced to 6-minute averages.
 
Consecutive Procedures 6-minute averages are tracked through the Distributed Control System (DAS)and CEM software.
APPENDIX CAM Compliance Assurance Monitoring Plan Emissions Units 001, 002, 003 & 004 Two tangentially fired coal units and two dry bottom wall-fired units; Particulate Matter emissions controlled by Electrostatic Precipitators Monitoring Approach Indicator
Daily reports with all six-minute averages are generated.
: 1. Indicator                   Opacity.
F. Averaging Period Ten consecutive 6-minute averages.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page CAM-4 of 4 APPENDIX I LIST OF INSIGNIFICANT EMISSIONS UNITS AND/OR ACTIVITIES The facilities, emissions units, or pollutant-emitting activities listed in Rule 62-210.300(3)(a), F.A.C., Categorical Exemptions, or that meet the criteria specified in Rule 62-210.300(3)(b)1., F.A.C., Generic Emissions Unit Exemption, are exempt from the permitting requirements of Chapters 62-210, 62-212 and 62-4, F.A.C.; provided, however, that exempt emissions units shall be subject to any applicable emission limiting standards and the emissions from exempt emissions units or activities shall be considered in determining the potential emissions of the facility containing such emissions units. Emissions units and pollutant-emitting activities exempt from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., shall not be exempt from the permitting requirements of Chapter 62-213, F.A.C., if they are contained within a Title V source; however, such emissions units and activities shall be considered insignificant for Title V purposes provided they also meet the criteria of Rule 62-213.430(6)(b), F.A.C. No emissions unit shall be entitled to an exemption from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., if its emissions, in combination with the emissions of other units and activities at the facility, would cause the facility to emit or have the potential to emit any pollutant in such amount as to make the facility a Title V source.The below listed emissions units and/or activities are considered insignificant pursuant to Rule 62-213.430(6), F.A.C.Brief Description of Emissions Units and/or Activities
Measurement Approach       Continuous opacity monitoring system (COMS).
: 1. Vehicle diesel and gasoline tanks.2.
II. Indicator Range             For Units 2, 4 and 5, an excursion is defined as any 1 hour of opacity greater than 15% (other than startup, shutdown, "load-changing" and sootblowing periods).
* Diesel fire pump and tank at Unit 3 (FWP-7).3.
For Unit 1, an excursion is defined as any 1 hour of opacity greater than 22%
* Diesel pump driver for emergency feedwater (1,670 BHP).4.
(other than startup, shutdown, "load-changing" and sootblowing periods).
* Diesel generator for security bldg and system (backup).5.
Load-changing occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more.
* 260 kW emergency diesel generator at Unit 3 technical support center.6.
An excursion will trigger an evaluation of operation of the boiler(s) and ESP(s). Corrective action will be taken as necessary. Any excursion will trigger recordkeeping and reporting requirements.
III. Performance Criteria A. Data                   Based on available opacity data while stack testing, the representative stack Representativeness     opacity of units 2, 4 and 5 is in the range of 2 to 12%. Based upon available opacity data while stack testing, the representative stack opacity of Unit 1 is in the range of 5 to 20%.
B. Verification of         Annual testing during normal operation is used to verify particulate mass Operational Status     loading. The COM system is audited quarterly.
C. QA/QC Practices and     Operate COMS according to 40 CFR Part 60 Appendix B, Performance Criteria               Specification 1 and general provisions 60.13. The COMS is automatically calibrated every 24 hours. Calibration information is recorded through a data acquisition system (DAS). A neutral density filter test is performed quarterly as well as preventive maintenance items; replace filters, clean optics, etc., as prescribed by the manufacturer.
D. Monitoring Frequency   Opacity is monitored continuously.
E. Data Collection         The COMS collects data that are reduced to 6-minute averages. Consecutive Procedures             6-minute averages are tracked through the Distributed Control System (DAS) and CEM software. Daily reports with all six-minute averages are generated.
F. Averaging Period       Ten consecutive 6-minute averages.
Progress Energy Florida, Inc.                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                    Title V Permit Renewal Page CAM-4 of 4
 
APPENDIX I LIST OF INSIGNIFICANT EMISSIONS UNITS AND/OR ACTIVITIES The facilities, emissions units, or pollutant-emitting activities listed in Rule 62-210.300(3)(a), F.A.C., Categorical Exemptions, or that meet the criteria specified in Rule 62-210.300(3)(b)1., F.A.C., Generic Emissions Unit Exemption, are exempt from the permitting requirements of Chapters 62-210, 62-212 and 62-4, F.A.C.; provided, however, that exempt emissions units shall be subject to any applicable emission limiting standards and the emissions from exempt emissions units or activities shall be considered in determining the potential emissions of the facility containing such emissions units. Emissions units and pollutant-emitting activities exempt from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., shall not be exempt from the permitting requirements of Chapter 62-213, F.A.C., if they are contained within a Title V source; however, such emissions units and activities shall be considered insignificant for Title V purposes provided they also meet the criteria of Rule 62-213.430(6)(b), F.A.C. No emissions unit shall be entitled to an exemption from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., if its emissions, in combination with the emissions of other units and activities at the facility, would cause the facility to emit or have the potential to emit any pollutant in such amount as to make the facility a Title V source.
The below listed emissions units and/or activities are considered insignificant pursuant to Rule 62-213.430(6),
F.A.C.
Brief Description of Emissions Units and/or Activities
: 1. Vehicle diesel and gasoline tanks.
: 2.
* Diesel fire pump and tank at Unit 3 (FWP-7).
: 3.
* Diesel pump driver for emergency feedwater (1,670 BHP).
: 4.
* Diesel generator for security bldg and system (backup).
: 5.
* 260 kW emergency diesel generator at Unit 3 technical support center.
: 6.
* Unit 3 diesel generator air compressors.
* Unit 3 diesel generator air compressors.
: 7. Unit 3 halon fire protection system.8.
: 7. Unit 3 halon fire protection system.
* Fire pump house emergency diesel generator units and electric generator units.9. Laboratory facilities.
: 8.
: 10. CEM equipment and calibration gas storage and venting.11. Surface coating of less than 6.0 gallons per day.12. Brazing, soldering and welding.13. Grounds maintenance.
* Fire pump house emergency diesel generator units and electric generator units.
: 9. Laboratory facilities.
: 10. CEM equipment and calibration gas storage and venting.
: 11. Surface coating of less than 6.0 gallons per day.
: 12. Brazing, soldering and welding.
: 13. Grounds maintenance.
: 14.
: 14.
* Miscellaneous gas and diesel engines (under 500 hp).15. Miscellaneous material handling activities.
* Miscellaneous gas and diesel engines (under 500 hp).
: 16. Part waster.17. Miscellaneous material cleaning equipment (e.g., self contained sand blasting).
: 15. Miscellaneous material handling activities.
: 16. Part waster.
: 17. Miscellaneous material cleaning equipment (e.g., self contained sand blasting).
: 18.
: 18.
* 175 kW emergency diesel generator for the Site Administration building.19. Sand Blasting.20. One concrete batch plant.21. Two grout batch plants.* These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page I-1 of 1 APPENDIX ICE REQUIREMENTS FOR INTERNAL COMBUSTION ENGINES This Title V facility contains stationary internal combustion engines that have been exempted from the requirement to obtain an air construction permit because they qualify for one of the categorical exemptions listed in Rule 62-210.300(3)(a), Florida Administrative Code (F.A.C.).
* 175 kW emergency diesel generator for the Site Administration building.
However, they are included in this permit as regulated emissions units because they are subject to one or more of the following federal rules:* 40 CFR 60, Subpart IIII-Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.* 40 CFR 60, Subpart JJJJ-Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.* 40 CFR 63, Subpart ZZZZ-National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.The below listed engines are subject to the specified federal rules.In- Displacement Rule E.U. No. Brief Description of Engine Service Applicability Date 028 3500 kW diesel generator associated with Unit 3 03/2006 12,443 in 3  ZZZZ 029 Diesel fire pump, south yard 08/2009 14.5 L ZZZZ, 1III 030 Emergency generator (meteorological weather 09/2009 992 CC ZZZZ, JJJJ station) 1 031 Fire Pump, Trailer Mounted, Unit 3 02/2008 8700 CC ZZZZ, IIII The engines listed above are currently demonstrating compliance with the emissions limitations of the applicable federal rule through the retention of a manufacturer's certification statement.
: 19. Sand Blasting.
So long as that certification is able to be retained, no additional compliance demonstration is required.
: 20. One concrete batch plant.
At such time that the manufacturer's certification is no longer valid (i.e. due to operation or maintenance practices that are inconsistent with the manufacturer's recommendations), the permittee shall begin demonstrating compliance with the standards listed in the applicable federal rule (included in the appendices as an enforceable part of this permit) in a manner that is prescribed by that rule.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page ICE-1 of 1 APPENDIX NSPS SUBPART A General Conditions Title 40: Protection of Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES Federal Regulations Adopted by Reference In accordance with Rule 62-204.800, F.A.C., the following federal regulation in Title 40 of the Code of Federal Regulations (CFR) was adopted by reference.
: 21. Two grout batch plants.
The original federal rule numbering has been retained.Federal Revision Date: June 13, 2007 Rule Effective Date: October 1, 2007 Standardized Conditions Revision Date: October 9, 2008 40 CFR Part 60, Subpart A -General Provisions
* These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.
&sect; 60.1 Applicability.(a) Except as provided in subparts B and C, the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility.(b) Any new or revised standard of performance promulgated pursuant to section 11 1(b) of the Act shall apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of such new or revised standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility.(c) In addition to complying with the provisions of this part, the owner or operator of an affected facility may be required to obtain an operating permit issued to stationary sources by an authorized State air pollution control agency or by the Administrator of the U.S. Environmental Protection Agency (EPA) pursuant to Title V of the Clean Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more information about obtaining an operating permit see part 70 of this chapter.(d) Site-specific standard for Merck & Co., Inc. 's Stonewall Plant in Elkton, Virginia. (Not Applicable]
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                       Title V Permit Renewal Page I-1 of 1
 
APPENDIX ICE REQUIREMENTS FOR INTERNAL COMBUSTION ENGINES This Title V facility contains stationary internal combustion engines that have been exempted from the requirement to obtain an air construction permit because they qualify for one of the categorical exemptions listed in Rule 62-210.300(3)(a), Florida Administrative Code (F.A.C.). However, they are included in this permit as regulated emissions units because they are subject to one or more of the following federal rules:
* 40 CFR 60, Subpart IIII-Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.
* 40 CFR 60, Subpart JJJJ-Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.
* 40 CFR 63, Subpart ZZZZ-National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.
The below listed engines are subject to the specified federal rules.
In-       Displacement             Rule E.U. No.               Brief Description of Engine                   Service                         Applicability Date 028       3500 kW diesel generator associated with Unit 3         03/2006   12,443 in3            ZZZZ 029       Diesel fire pump, south yard                           08/2009   14.5 L               ZZZZ, 1III 030       Emergency generator (meteorological weather           09/2009     992 CC               ZZZZ, JJJJ station)                                                         1 031       Fire Pump, Trailer Mounted, Unit 3                     02/2008     8700 CC               ZZZZ, IIII The engines listed above are currently demonstrating compliance with the emissions limitations of the applicable federal rule through the retention of a manufacturer's certification statement. So long as that certification is able to be retained, no additional compliance demonstration is required. At such time that the manufacturer's certification is no longer valid (i.e. due to operation or maintenance practices that are inconsistent with the manufacturer's recommendations), the permittee shall begin demonstrating compliance with the standards listed in the applicable federal rule (included in the appendices as an enforceable part of this permit) in a manner that is prescribed by that rule.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                        Title V Permit Renewal Page ICE-1 of 1
 
APPENDIX NSPS SUBPART A General Conditions Title 40: Protectionof Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES FederalRegulations Adopted by Reference In accordance with Rule 62-204.800, F.A.C., the following federal regulation in Title 40 of the Code of FederalRegulations (CFR) was adopted by reference. The originalfederal rule numbering has been retained.
Federal Revision Date: June 13, 2007 Rule Effective Date: October 1, 2007 Standardized Conditions Revision Date: October 9, 2008 40 CFR Part 60, Subpart A - GeneralProvisions
&sect; 60.1 Applicability.
(a) Except as provided in subparts B and C, the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility.
(b) Any new or revised standard of performance promulgated pursuant to section 11 1(b) of the Act shall apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of such new or revised standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility.
(c) In addition to complying with the provisions of this part, the owner or operator of an affected facility may be required to obtain an operating permit issued to stationary sources by an authorized State air pollution control agency or by the Administrator of the U.S. Environmental Protection Agency (EPA) pursuant to Title V of the Clean Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more information about obtaining an operating permit see part 70 of this chapter.
(d) Site-specific standardfor Merck & Co., Inc. 's Stonewall Plant in Elkton, Virginia. (Not Applicable]
&sect; 60.2 Definitions.
&sect; 60.2 Definitions.
The terms used in this part are defined in the Act or in this section as follows: Act means the Clean Air Act (42 U.S.C. 7401 et seq. )Administrator means the Administrator of the Environmental Protection Agency or his authorized representative.
The terms used in this part are defined in the Act or in this section as follows:
Act means the Clean Air Act (42 U.S.C. 7401 et seq. )
Administratormeans the Administrator of the Environmental Protection Agency or his authorized representative.
Affected facility means, with reference to a stationary source, any apparatus to which a standard is applicable.
Affected facility means, with reference to a stationary source, any apparatus to which a standard is applicable.
Alternative method means any method of sampling and analyzing for an air pollutant which is not a reference or equivalent method but which has been demonstrated to the Administrator's satisfaction to, in specific cases, produce results adequate for his determination of compliance.
Alternative method means any method of sampling and analyzing for an air pollutant which is not a reference or equivalent method but which has been demonstrated to the Administrator's satisfaction to, in specific cases, produce results adequate for his determination of compliance.
Approved permit program means a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to Title V of the Act (42 U.S.C. 7661).Capital expenditure means an expenditure for a physical or operational change to an existing facility which exceeds the product of the applicable "annual asset guideline repair allowance percentage" specified in the latest edition of Internal Revenue Service (IRS) Publication 534 and the existing facility's basis, as defined by section 1012 of the Internal Revenue Code. However, the total expenditure for a physical or operational change to an existing facility must not be reduced by any"excluded additions" as defined in IRS Publication 534, as would be done for tax purposes.Clean coal technology demonstration project means a project using funds appropriated under the heading 'Department of Energy-Clean Coal Technology', up to a total amount of $2,500,000,000 for commercial demonstrations of clean coal technology, or similar projects funded through appropriations for the Environmental Protection Agency.Commenced means, with respect to the definition of new source in section 111 (a)(2) of the Act, that an owner or operator has undertaken a continuous program of construction or modification or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or modification.
Approved permit program means a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to Title V of the Act (42 U.S.C. 7661).
Construction means fabrication, erection, or installation of an affected facility.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-1 of 29 APPENDIX NSPS SUBPART A General Conditions Continuous monitoring system means the total equipment, required under the emission monitoring sections in applicable subparts, used to sample and condition (if applicable), to analyze, and to provide a permanent record of emissions or process parameters.
Capital expenditure means an expenditure for a physical or operational change to an existing facility which exceeds the product of the applicable "annual asset guideline repair allowance percentage" specified in the latest edition of Internal Revenue Service (IRS) Publication 534 and the existing facility's basis, as defined by section 1012 of the Internal Revenue Code. However, the total expenditure for a physical or operational change to an existing facility must not be reduced by any "excluded additions" as defined in IRS Publication 534, as would be done for tax purposes.
Electric utility steam generating unit means any steam electric generating unit that is constructed for the purpose of supplying more than one-third of its potential electric output capacity and more than 25 MW electrical output to any utility power distribution system for sale. Any steam supplied to a steam distribution system for the purpose of providing steam to a steam-electric generator that would produce electrical energy for sale is also considered in determining the electrical energy output capacity of the affected facility.Equivalent method means any method of sampling and analyzing for an air pollutant which has been demonstrated to the Administrator's satisfaction to have a consistent and quantitatively known relationship to the reference method, under specified conditions.
Clean coal technology demonstrationproject means a project using funds appropriated under the heading 'Department of Energy-Clean Coal Technology', up to a total amount of $2,500,000,000 for commercial demonstrations of clean coal technology, or similar projects funded through appropriations for the Environmental Protection Agency.
Excess Emissions and Monitoring Systems Performance Report is a report that must be submitted periodically by a source in order to provide data on its compliance with stated emission limits and operating parameters, and on the performance of its monitoring systems.Existing facility means, with reference to a stationary source, any apparatus of the type for which a standard is promulgated in this part, and the construction or modification of which was commenced before the date of proposal of that standard; or any apparatus which could be altered in such a way as to be of that type.Force majeure means, for purposes of &sect;60.8, an event that will be or has been caused by circumstances beyond the control of the affected facility, its contractors, or any entity controlled by the affected facility that prevents the owner or operator from complying with the regulatory requirement to conduct performance tests within the specified timeframe despite the affected facility's best efforts to fulfill the obligation.
Commenced means, with respect to the definition of new source in section 111(a)(2) of the Act, that an owner or operator has undertaken a continuous program of construction or modification or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or modification.
Examples of such events are acts of nature, acts of war or terrorism, or equipment failure or safety hazard beyond the control of the affected facility.Isokinetic sampling means sampling in which the linear velocity of the gas entering the sampling nozzle is equal to that of the undisturbed gas stream at the sample point.Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a Title V permit occurs immediately after the EPA takes final action on the final permit.Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
Construction means fabrication, erection, or installation of an affected facility.
Modification means any physical change in, or change in the method of operation of, an existing facility which increases the amount of any air pollutant (to which a standard applies) emitted into the atmosphere by that facility or which results in the emission of any air pollutant (to which a standard applies) into the atmosphere not previously emitted.Monitoring device means the total equipment, required under the monitoring of operations sections in applicable subparts, used to measure and record (if applicable) process parameters.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-1 of 29
Nitrogen oxides means all oxides of nitrogen except nitrous oxide, as measured by test methods set forth in this part.One-hour period means any 60-minute period commencing on the hour.Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background.
 
Owner or operator means any person who owns, leases, operates, controls, or supervises an affected facility or a stationary source of which an affected facility is a part.Part 70 permit means any permit issued, renewed, or revised pursuant to part 70 of this chapter.Particulate matter means any finely divided solid or liquid material, other than uncombined water, as measured by the reference methods specified under each applicable subpart, or an equivalent or alternative method.Permit program means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C.7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter.Permitting authority means: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-2 of 29 APPENDIX NSPS SUBPART A General Conditions (1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661).Proportional sampling means sampling at a rate that produces a constant ratio of sampling rate to stack gas flow rate.Reactivation of a very clean coal-fired electric utility steam generating unit means any physical change or change in the method of operation associated with the commencement of Commercial operations by a coal-fired utility unit after a period of discontinued operation where the unit: (1) Has not been in operation for the two-year period prior to the enactment of the Clean Air Act Amendments of 1990, and the emissions from such unit continue to be carried in the permitting authority's emissions inventory at the time of enactment; (2) Was equipped prior to shut-down with a continuous system of emissions control that achieves a removal efficiency for sulfur dioxide of no less than 85 percent and a removal efficiency for particulates of no less than 98 percent;(3) Is equipped with low-NOx burners prior to the time of commencement of operations following reactivation; and (4) Is otherwise in compliance with the requirements of the Clean Air Act.Reference method means any method of sampling and analyzing for an air pollutant as specified in the applicable subpart.Repowering means replacement of an existing coal-fired boiler with one of the following clean coal technologies:
APPENDIX NSPS SUBPART A General Conditions Continuous monitoring system means the total equipment, required under the emission monitoring sections in applicable subparts, used to sample and condition (if applicable), to analyze, and to provide a permanent record of emissions or process parameters.
atmospheric or pressurized fluidized bed combustion, integrated gasification combined cycle, magnetohydrodynamics, direct and indirect coal-fired turbines, integrated gasification fuel cells, or as determined by the Administrator, in consultation with the Secretary of Energy, a derivative of one or more of these technologies, and any other technology capable of controlling multiple combustion emissions simultaneously with improved boiler or generation efficiency and with significantly greater waste reduction relative to the performance of technology in widespread commercial use as of November 15, 1990.Repowering shall also include any oil and/or gas-fired unit which has been awarded clean coal technology demonstration funding as of January 1, 1991, by the Department of Energy.Run means the net period of time during which an emission sample is collected.
Electric utility steam generating unit means any steam electric generating unit that is constructed for the purpose of supplying more than one-third of its potential electric output capacity and more than 25 MW electrical output to any utility power distribution system for sale. Any steam supplied to a steam distribution system for the purpose of providing steam to a steam-electric generator that would produce electrical energy for sale is also considered in determining the electrical energy output capacity of the affected facility.
Unless otherwise specified, a run may be either intermittent or continuous within the limits of good engineering practice.Shutdown means the cessation of operation of an affected facility for any purpose.Six-minute period means any one of the 10 equal parts of a one-hour period.Standard means a standard of performance proposed or promulgated under this part.Standard conditions means a temperature of 293 K (68F) and a pressure of 101.3 kilopascals (29.92 in Hg).Startup means the setting in operation of an affected facility for any purpose.State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement:  
Equivalent method means any method of sampling and analyzing for an air pollutant which has been demonstrated to the Administrator's satisfaction to have a consistent and quantitatively known relationship to the reference method, under specified conditions.
(1) The provisions of this part; and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context.Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant.
Excess Emissions and Monitoring Systems PerformanceReport is a report that must be submitted periodically by a source in order to provide data on its compliance with stated emission limits and operating parameters, and on the performance of its monitoring systems.
Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part.Volatile Organic Compound means any organic compound which participates in atmospheric photochemical reactions; or which is measured by a reference method, an equivalent method, an alternative method, or which is determined by procedures specified under any subpart.[44 FR 55173, Sept. 25, 1979, as amended at 45 FR 5617, Jan. 23, 1980; 45 FR 85415, Dec. 24, 1980; 54 FR 6662, Feb. 14, 1989; 55 FR 51382, Dec. 13, 1990; 57 FR 32338, July 21, 1992; 59 FR 12427, Mar. 16, 1994; 72 FR 27442, May 16, 2007]&sect; 60.3 Units and abbreviations.
Existing facility means, with reference to a stationary source, any apparatus of the type for which a standard is promulgated in this part, and the construction or modification of which was commenced before the date of proposal of that standard; or any apparatus which could be altered in such a way as to be of that type.
Used in this part are abbreviations and symbols of units of measure. These are defined as follows: (a) System International (SI) units of measure: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-3 of 29 APPENDIX NSPS SUBPART A General Conditions A-ampere g-gram Hz-hertz J-joule K-degree Kelvin kg-kilogram mi-meter m 3 --cubic meter mg-milligram-i 0-3gram mm-millimeter 3 meter Mg-megagram--10 6 gram mol-mole N-newton ng-nanogram-10-9 gram nm-nanometer-10-9meter Pa-pascal s-second V-volt W-watt n-ohm pg-microgram-1 0-6gram (b) Other units of measure: Btu-British thermal unit'C-degree Celsius (centigrade) cal-calorie cfm---cubic feet per minute cu ft--cubic feet dcf-dry cubic feet dcm--dry cubic meter dscf-dry cubic feet at standard conditions dscm-dry cubic meter at standard conditions eq-equivalent
Force majeure means, for purposes of &sect;60.8, an event that will be or has been caused by circumstances beyond the control of the affected facility, its contractors, or any entity controlled by the affected facility that prevents the owner or operator from complying with the regulatory requirement to conduct performance tests within the specified timeframe despite the affected facility's best efforts to fulfill the obligation. Examples of such events are acts of nature, acts of war or terrorism, or equipment failure or safety hazard beyond the control of the affected facility.
'F--degree Fahrenheit ft-feet gal-gallon gr-grain g-eq-gram equivalent hr-hour Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-4 of 29 APPENDIX NSPS SUBPART A General Conditions in-inch k-1,000 I-liter lpm-liter per minute lb-pound meq-milliequivalent min-minute ml-milliliter mol. wt.-molecular weight ppb-parts per billion ppm-parts per million psia-pounds per square inch absolute psig-pounds per square inch gage&deg;R--degree Rankine scf--cubic feet at standard conditions scfh-cubic feet per hour at standard conditions scm-cubic meter at standard conditions sec-second sq ft-square feet std-at standard conditions (c) Chemical nomenclature:
Isokinetic sampling means sampling in which the linear velocity of the gas entering the sampling nozzle is equal to that of the undisturbed gas stream at the sample point.
CdS-cadmium sulfide CO-carbon monoxide CO 2--carbon dioxide HCl-hydrochloric acid Hg-mercury H 2 0-water H 2 S-hydrogen sulfide H 2 SO 4--sulfuric acid N 2-nitrogen NO-nitric oxide N0 2-nitrogen dioxide NOx-nitrogen oxides O 2-oxygen SO 2-sulfur dioxide S0 3-sulfur trioxide SOx-sulfur oxides (d) Miscellaneous:
Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a Title V permit occurs immediately after the EPA takes final action on the final permit.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-5 of 29 APPENDIX NSPS SUBPART A General Conditions A.S.T.M.-American Society for Testing and Materials[42 FR 37000, July 19, 1977; 42 FR 38178, July 27, 1977]&sect; 60.4 Address.All addresses that pertain to Florida have been incorporated.
Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
To see the complete list of addresses please go to http://ecfr.jzpoaccess.gov/cgzilt/textltext-idx?c=ecfr&r_-n=div6&view=text&node=40:6.0.
Modification means any physical change in, or change in the method of operation of, an existing facility which increases the amount of any air pollutant (to which a standard applies) emitted into the atmosphere by that facility or which results in the emission of any air pollutant (to which a standard applies) into the atmosphere not previously emitted.
1.1. 1.1 &idno=40.Link to an amendment published at 73 FR 18164, Apr. 3, 2008.(a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted in duplicate to the appropriate Regional Office of the U.S. Environmental Protection Agency to the attention of the Director of the Division indicated in the following list of EPA Regional Offices.Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee), Director, Air and Waste Management Division, U.S. Environmental Protection Agency, 345 Courtland Street, NE., Atlanta, GA 30365.(b) Section I 11(c) directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards of performance for new stationary sources located in such State. All information required to be submitted to EPA under paragraph (a) of this section, must also be submitted to the appropriate State Agency of any State to which this authority has been delegated (provided, that each specific delegation may except sources from a certain Federal or State reporting requirement).
Monitoring device means the total equipment, required under the monitoring of operations sections in applicable subparts, used to measure and record (if applicable) process parameters.
The appropriate mailing address for those States whose delegation request has been approved is as follows: (K) Bureau of Air Quality Management, Department of Environmental Regulation, Twin Towers Office Building, 2600 Blair Stone Road, Tallahassee, FL 32301.[40 FR 18169, Apr. 25, 1975]Editorial Note: For Federal Register citations affecting  
Nitrogen oxides means all oxides of nitrogen except nitrous oxide, as measured by test methods set forth in this part.
&sect;60.4 see the List of CFR Sections Affected which appears in the Finding Aids section of the printed volume and on GPO Access.&sect; 60.5 Determination of construction or modification.(a) When requested to do so by an owner or operator, the Administrator will make a determination of whether action taken or intended to be taken by such owner or operator constitutes construction (including reconstruction) or modification or the commencement thereof within the meaning of this part.(b) The Administrator will respond to any request for a determination under paragraph (a) of this section within 30 days of receipt of such request.[40 FR 58418, Dec. 16, 1975]&sect; 60.6 Review of plans.(a) When requested to do so by an owner or operator, the Administrator will review plans for construction or modification for the purpose of providing technical advice to the owner or operator.(b)(1) A separate request shall be submitted for each construction or modification project.(2) Each request shall identify the location of such project, and be accompanied by technical information describing the proposed nature, size, design, and method of operation of each affected facility involved in such project, including information on any equipment to be used for measurement or control of emissions.(c) Neither a request for plans review nor advice furnished by the Administrator in response to such request shall (1) relieve an owner or operator of legal responsibility for compliance with any provision of this part or of any applicable State or local requirement, or (2) prevent the Administrator from implementing or enforcing any provision of this part or taking any other action authorized by the Act.[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974]&sect; 60.7 Notification and record keeping.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-6 of 29 APPENDIX NSPS SUBPART A General Conditions (a) Any owner or operator subject to the provisions of this part shall furnish the Administrator written notification or, if acceptable to both the Administrator and the owner or operator of a source, electronic notification, as follows: (1) A notification of the date construction (or reconstruction as defined under &sect;60.15) of an affected facility is commenced postmarked no later than 30 days after such date. This requirement shall not apply in the case of mass-produced facilities which are purchased in completed form.(2) [Reserved]
One-hour period means any 60-minute period commencing on the hour.
(3) A notification of the actual date of initial startup of an affected facility postmarked within 15 days after such date.(4) A notification of any physical or operational change to an existing facility which may increase the emission rate of any air pollutant to which a standard applies, unless that change is specifically exempted under an applicable subpart or in &sect;60.14(e).
Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background.
This notice shall be postmarked 60 days or as soon as practicable before the change is commenced and shall include information describing the precise nature of the change, present and proposed emission control systems, productive capacity of the facility before and after the change, and the expected completion date of the change. The Administrator may request additional relevant information subsequent to this notice.(5) A notification of the date upon which demonstration of the continuous monitoring system performance commences in accordance with &sect;60.13(c).
Owner or operatormeans any person who owns, leases, operates, controls, or supervises an affected facility or a stationary source of which an affected facility is a part.
Notification shall be postmarked not less than 30 days prior to such date.(6) A notification of the anticipated date for conducting the opacity observations required by &sect;60.11(e)(1) of this part.The notification shall also include, if appropriate, a request for the Administrator to provide a visible emissions reader during a performance test. The notification shall be postmarked not less than 30 days prior to such date.(7) A notification that continuous opacity monitoring system data results will be used to determine compliance with the applicable opacity standard during a performance test required by &sect;60.8 in lieu of Method 9 observation data as allowed by &sect;60.11(e)(5) of this part. This notification shall be postmarked not less than 30 days prior to the date of the performance test.(b) Any owner or operator subject to the provisions of this part shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative.(c) Each owner or operator required to install a continuous monitoring device shall submit excess emissions and monitoring systems performance report (excess emissions are defined in applicable subparts) and-or summary report form (see paragraph (d) of this section) to the Administrator semiannually, except when: more frequent reporting is specifically required by an applicable subpart; or the Administrator, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. All reports shall be postmarked by the 30th day following the end of each six-month period. Written reports of excess emissions shall include the following information:
Part 70 permit means any permit issued, renewed, or revised pursuant to part 70 of this chapter.
(1) The magnitude of excess emissions computed in accordance with &sect;60.13(h), any conversion factor(s) used, and the date and time of commencement and completion of each time period of excess emissions.
Particulatematter means any finely divided solid or liquid material, other than uncombined water, as measured by the reference methods specified under each applicable subpart, or an equivalent or alternative method.
The process operating time during the reporting period.(2) Specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the affected facility.
Permitprogram means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C.
The nature and cause of any malfunction (if known), the corrective action taken or preventative measures adopted.(3) The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and span checks and the nature of the system repairs or adjustments.
7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter.
(4) When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.(d) The summary report form shall contain the information and be in the format shown in figure 1 unless otherwise specified by the Administrator.
Permittingauthority means:
One summary report form shall be submitted for each pollutant monitored at each affected facility.(1) If the total duration of excess emissions for the reporting period is less than 1 percent of the total operating time for the reporting period and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report form shall be submitted and the excess emission report described in&sect;60.7(c) need not be submitted unless requested by the Administrator.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-2 of 29
(2) If the total duration of excess emissions for the reporting period is 1 percent or greater of the total operating time for the reporting period or the total CMS downtime for the reporting period is 5 percent or greater of the total operating Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-7 of 29 APPENDIX NSPS SUBPART A General Conditions time for the reporting period, the summary report form and the excess emission report described in &sect;60.7(c) shall both be submitted.
 
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page A-8 of 29 APPENDIX NSPS SUBPART A General Conditions Figure 1-Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance Pollutant (Circle One-SO 2/NOx/TRS/H 2 S/CO/Opacity)
APPENDIX NSPS SUBPART A General Conditions (1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661).
Reporting period dates: From to Company: Emission Limitation Address: Monitor Manufacturer and Model No.Date of Latest CMS Certification or Audit Process Unit(s)
Proportionalsampling means sampling at a rate that produces a constant ratio of sampling rate to stack gas flow rate.
Reactivation of a very clean coal-fired electric utility steam generatingunit means any physical change or change in the method of operation associated with the commencement of Commercial operations by a coal-fired utility unit after a period of discontinued operation where the unit:
(1) Has not been in operation for the two-year period prior to the enactment of the Clean Air Act Amendments of 1990, and the emissions from such unit continue to be carried in the permitting authority's emissions inventory at the time of enactment; (2) Was equipped prior to shut-down with a continuous system of emissions control that achieves a removal efficiency for sulfur dioxide of no less than 85 percent and a removal efficiency for particulates of no less than 98 percent; (3) Is equipped with low-NOx burners prior to the time of commencement of operations following reactivation; and (4) Is otherwise in compliance with the requirements of the Clean Air Act.
Reference method means any method of sampling and analyzing for an air pollutant as specified in the applicable subpart.
Repowering means replacement of an existing coal-fired boiler with one of the following clean coal technologies:
atmospheric or pressurized fluidized bed combustion, integrated gasification combined cycle, magnetohydrodynamics, direct and indirect coal-fired turbines, integrated gasification fuel cells, or as determined by the Administrator, in consultation with the Secretary of Energy, a derivative of one or more of these technologies, and any other technology capable of controlling multiple combustion emissions simultaneously with improved boiler or generation efficiency and with significantly greater waste reduction relative to the performance of technology in widespread commercial use as of November 15, 1990.
Repowering shall also include any oil and/or gas-fired unit which has been awarded clean coal technology demonstration funding as of January 1, 1991, by the Department of Energy.
Run means the net period of time during which an emission sample is collected. Unless otherwise specified, a run may be either intermittent or continuous within the limits of good engineering practice.
Shutdown means the cessation of operation of an affected facility for any purpose.
Six-minute period means any one of the 10 equal parts of a one-hour period.
Standard means a standard of performance proposed or promulgated under this part.
Standardconditions means a temperature of 293 K (68F) and a pressure of 101.3 kilopascals (29.92 in Hg).
Startup means the setting in operation of an affected facility for any purpose.
State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement: (1) The provisions of this part; and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context.
Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant.
Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part.
Volatile Organic Compound means any organic compound which participates in atmospheric photochemical reactions; or which is measured by a reference method, an equivalent method, an alternative method, or which is determined by procedures specified under any subpart.
[44 FR 55173, Sept. 25, 1979, as amended at 45 FR 5617, Jan. 23, 1980; 45 FR 85415, Dec. 24, 1980; 54 FR 6662, Feb. 14, 1989; 55 FR 51382, Dec. 13, 1990; 57 FR 32338, July 21, 1992; 59 FR 12427, Mar. 16, 1994; 72 FR 27442, May 16, 2007]
&sect; 60.3 Units and abbreviations.
Used in this part are abbreviations and symbols of units of measure. These are defined as follows:
(a)       System International (SI) units of measure:
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-3 of 29
 
APPENDIX NSPS SUBPART A General Conditions A-ampere g-gram Hz-hertz J-joule K-degree Kelvin kg-kilogram mi-meter m3 -- cubic meter mg-milligram-i 0-3gram mm-millimeter 3 meter Mg-megagram--10 6 gram mol-mole N-newton ng-nanogram-     10- 9gram nm-nanometer-       10-9meter Pa-pascal s-second V-volt W-watt n-ohm pg-microgram-1 0-6gram (b)     Other units of measure:
Btu-British thermal unit
    'C-degree Celsius (centigrade) cal-calorie cfm---cubic feet per minute cu ft--cubic feet dcf-dry cubic feet dcm--dry cubic meter dscf-dry cubic feet at standard conditions dscm-dry cubic meter at standard conditions eq-equivalent
    'F--degree Fahrenheit ft-feet gal-gallon gr-grain g-eq-gram equivalent hr-hour Progress Energy Florida, Inc.                                       Permit No. 0170004-024-AV Crystal River Power Plant                                               Title V Permit Renewal Page A-4 of 29
 
APPENDIX NSPS SUBPART A General Conditions in-inch k-1,000 I-liter lpm-liter per minute lb-pound meq-milliequivalent min-minute ml-milliliter mol. wt.-molecular weight ppb-parts per billion ppm-parts per million psia-pounds per square inch absolute psig-pounds per square inch gage
    &deg;R--degree Rankine scf--cubic feet at standard conditions scfh-cubic feet per hour at standard conditions scm-cubic meter at standard conditions sec-second sq ft-square feet std-at standard conditions (c)     Chemical nomenclature:
CdS-cadmium sulfide CO-carbon monoxide CO 2-- carbon dioxide HCl-hydrochloric acid Hg-mercury H2 0-water H2 S-hydrogen sulfide H2 SO 4-- sulfuric acid N 2-nitrogen NO-nitric oxide N0 2-nitrogen     dioxide NOx-nitrogen oxides O 2-oxygen SO 2-sulfur dioxide S0 3-sulfur   trioxide SOx-sulfur oxides (d)     Miscellaneous:
Progress Energy Florida, Inc.                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                   Title V Permit Renewal Page A-5 of 29
 
APPENDIX NSPS SUBPART A General Conditions A.S.T.M.-American Society for Testing and Materials
[42 FR 37000, July 19, 1977; 42 FR 38178, July 27, 1977]
&sect; 60.4 Address.
All addresses that pertainto Floridahave been incorporated. To see the complete list of addressesplease go to http://ecfr.jzpoaccess.gov/cgzilt/textltext-idx?c=ecfr&r_-n=div6&view=text&node=40:6.0.     1.1. 1.1 &idno=40.
Link to an amendment published at 73 FR 18164, Apr. 3, 2008.
(a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted in duplicate to the appropriate Regional Office of the U.S. Environmental Protection Agency to the attention of the Director of the Division indicated in the following list of EPA Regional Offices.
Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee), Director, Air and Waste Management Division, U.S. Environmental Protection Agency, 345 Courtland Street, NE., Atlanta, GA 30365.
(b) Section I 11(c) directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards of performance for new stationary sources located in such State. All information required to be submitted to EPA under paragraph (a) of this section, must also be submitted to the appropriate State Agency of any State to which this authority has been delegated (provided, that each specific delegation may except sources from a certain Federal or State reporting requirement). The appropriate mailing address for those States whose delegation request has been approved is as follows:
(K) Bureau of Air Quality Management, Department of Environmental Regulation, Twin Towers Office Building, 2600 Blair Stone Road, Tallahassee, FL 32301.
[40 FR 18169, Apr. 25, 1975]
Editorial Note: For Federal Register citations affecting &sect;60.4 see the List of CFR Sections Affected which appears in the Finding Aids section of the printed volume and on GPO Access.
&sect; 60.5 Determination of construction or modification.
(a) When requested to do so by an owner or operator, the Administrator will make a determination of whether action taken or intended to be taken by such owner or operator constitutes construction (including reconstruction) or modification or the commencement thereof within the meaning of this part.
(b) The Administrator will respond to any request for a determination under paragraph (a) of this section within 30 days of receipt of such request.
[40 FR 58418, Dec. 16, 1975]
&sect; 60.6 Review ofplans.
(a) When requested to do so by an owner or operator, the Administrator will review plans for construction or modification for the purpose of providing technical advice to the owner or operator.
(b)
(1) A separate request shall be submitted for each construction or modification project.
(2) Each request shall identify the location of such project, and be accompanied by technical information describing the proposed nature, size, design, and method of operation of each affected facility involved in such project, including information on any equipment to be used for measurement or control of emissions.
(c) Neither a request for plans review nor advice furnished by the Administrator in response to such request shall (1) relieve an owner or operator of legal responsibility for compliance with any provision of this part or of any applicable State or local requirement, or (2) prevent the Administrator from implementing or enforcing any provision of this part or taking any other action authorized by the Act.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974]
&sect; 60.7 Notification and recordkeeping.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-6 of 29
 
APPENDIX NSPS SUBPART A General Conditions (a) Any owner or operator subject to the provisions of this part shall furnish the Administrator written notification or, if acceptable to both the Administrator and the owner or operator of a source, electronic notification, as follows:
(1) A notification of the date construction (or reconstruction as defined under &sect;60.15) of an affected facility is commenced postmarked no later than 30 days after such date. This requirement shall not apply in the case of mass-produced facilities which are purchased in completed form.
(2) [Reserved]
(3) A notification of the actual date of initial startup of an affected facility postmarked within 15 days after such date.
(4) A notification of any physical or operational change to an existing facility which may increase the emission rate of any air pollutant to which a standard applies, unless that change is specifically exempted under an applicable subpart or in &sect;60.14(e). This notice shall be postmarked 60 days or as soon as practicable before the change is commenced and shall include information describing the precise nature of the change, present and proposed emission control systems, productive capacity of the facility before and after the change, and the expected completion date of the change. The Administrator may request additional relevant information subsequent to this notice.
(5) A notification of the date upon which demonstration of the continuous monitoring system performance commences in accordance with &sect;60.13(c). Notification shall be postmarked not less than 30 days prior to such date.
(6) A notification of the anticipated date for conducting the opacity observations required by &sect;60.11(e)(1) of this part.
The notification shall also include, if appropriate, a request for the Administrator to provide a visible emissions reader during a performance test. The notification shall be postmarked not less than 30 days prior to such date.
(7) A notification that continuous opacity monitoring system data results will be used to determine compliance with the applicable opacity standard during a performance test required by &sect;60.8 in lieu of Method 9 observation data as allowed by &sect;60.11(e)(5) of this part. This notification shall be postmarked not less than 30 days prior to the date of the performance test.
(b) Any owner or operator subject to the provisions of this part shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative.
(c) Each owner or operator required to install a continuous monitoring device shall submit excess emissions and monitoring systems performance report (excess emissions are defined in applicable subparts) and-or summary report form (see paragraph (d) of this section) to the Administrator semiannually, except when: more frequent reporting is specifically required by an applicable subpart; or the Administrator, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. All reports shall be postmarked by the 30th day following the end of each six-month period. Written reports of excess emissions shall include the following information:
(1) The magnitude of excess emissions computed in accordance with &sect;60.13(h), any conversion factor(s) used, and the date and time of commencement and completion of each time period of excess emissions. The process operating time during the reporting period.
(2) Specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the affected facility. The nature and cause of any malfunction (if known), the corrective action taken or preventative measures adopted.
(3) The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and span checks and the nature of the system repairs or adjustments.
(4) When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report.
(d) The summary report form shall contain the information and be in the format shown in figure 1 unless otherwise specified by the Administrator. One summary report form shall be submitted for each pollutant monitored at each affected facility.
(1) If the total duration of excess emissions for the reporting period is less than 1 percent of the total operating time for the reporting period and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report form shall be submitted and the excess emission report described in
        &sect;60.7(c) need not be submitted unless requested by the Administrator.
(2) If the total duration of excess emissions for the reporting period is 1 percent or greater of the total operating time for the reporting period or the total CMS downtime for the reporting period is 5 percent or greater of the total operating Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-7 of 29
 
APPENDIX NSPS SUBPART A General Conditions time for the reporting period, the summary report form and the excess emission report described in &sect;60.7(c) shall both be submitted.
Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                            Title V Permit Renewal Page A-8 of 29
 
APPENDIX NSPS SUBPART A General Conditions Figure 1-Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance Pollutant (Circle One-SO2/NOx/TRS/H 2S/CO/Opacity)
Reporting period dates: From           to Company:
Emission Limitation Address:
Monitor Manufacturer and Model No.
Date of Latest CMS Certification or Audit Process Unit(s)


== Description:==
== Description:==


Total source operating time in reporting period'Emission data summary' CMS performance summary 1 1. Duration of excess emissions in reporting period due to: 1. CMS downtime in reporting period due to: a. Startup/shutdown  
Total source operating time in reporting period' 1
: a. Monitor equipment malfunctions
Emission data summary'                                         CMS performance summary
: b. Control equipment problems b. Non-Monitor equipment malfunctions
: 1. Duration of excess emissions in reporting period due to:             1. CMS downtime in reporting period due to:
: c. Process problems c. Quality assurance calibration
: a. Startup/shutdown                                                 a. Monitor equipment malfunctions
: d. Other known causes d. Other known causes e. Unknown causes e. Unknown causes 2. Total duration of excess emission 2. Total CMS Downtime 3. Total duration of excess emissions x (100) [Total source %2 3. [Total CMS Downtime]
: b. Control equipment problems                                       b. Non-Monitor equipment malfunctions
x (100) [Total source %2 operating time] operating time]'For opacity, record all times in minutes. For gases, record all times in hours.2For the reporting period: If the total duration of excess emissions is 1 percent or greater of the total operating time or the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in &sect;60.7(c) shall be submitted.
: c. Process problems                                                 c. Quality assurance calibration
On a separate page, describe any changes since last quarter in CMS, process or controls.
: d. Other known causes                                               d. Other known causes
I certify that the information contained in this report is true, accurate, and complete.Name Signature Title Date Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-9 of 29 APPENDIX NSPS SUBPART A General Conditions (e)(1) Notwithstanding the frequency of reporting requirements specified in paragraph (c) of this section, an owner or operator who is required by an applicable subpart to submit excess emissions and monitoring systems performance reports (and summary reports) on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met: (i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected facility's excess emissions and monitoring systems reports submitted to comply with a standard under this part continually demonstrate that the facility is in compliance with the applicable standard;(ii) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the applicable standard; and (iii) The Administrator does not object to a reduced frequency of reporting for the affected facility, as provided in paragraph (e)(2) of this section.(2) The frequency of reporting of excess emissions and monitoring systems performance (and summary) reports may be reduced only after the owner or operator notifies the Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the required recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements.
: e. Unknown causes                                                   e. Unknown causes
Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention.
: 2. Total duration of excess emission                                   2. Total CMS Downtime
The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted.(3) As soon as monitoring data indicate that the affected facility is not in compliance with any emission limitation or operating parameter specified in the applicable standard, the frequency of reporting shall revert to the frequency specified in the applicable standard, and the owner or operator shall submit an excess emissions and monitoring systems performance report (and summary report, if required) at the next appropriate reporting period following the noncomplying event. After demonstrating compliance with the applicable standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard as provided for in paragraphs (e)(1) and (e)(2) of this section.(f) Any owner or operator subject to the provisions of this part shall maintain a file of all measurements, including continuous monitoring system, monitoring device, and performance testing measurements; all continuous monitoring system performance evaluations; all continuous monitoring system or monitoring device calibration checks; adjustments and maintenance performed on these systems or devices; and all other information required by this part recorded in a permanent form suitable for inspection.
: 3. Total duration of excess emissions x (100) [Total source         %2 3. [Total CMS Downtime] x (100) [Total source           %2 operating time]                                                         operating time]
The file shall be retained for at least two years following the date of such measurements, maintenance, reports, and records, except as follows: (1) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS)where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction.
'For opacity, record all times in minutes. For gases, record all times in hours.
An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard.(2) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction.
2For the reporting period: If the total duration of excess emissions is 1 percent or greater of the total operating time or the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in &sect;60.7(c) shall be submitted.
In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator.
On a separate page, describe any changes since last quarter in CMS, process or controls. I certify that the information contained in this report is true, accurate, and complete.
(3) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (f) of this section, if the Administrator or the delegated Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-10 of 29 APPENDIX NSPS SUBPART A General Conditions authority determines these records are required to more accurately assess the compliance status of the affected source.(g) If notification substantially similar to that in paragraph (a) of this section is required by any other State or local agency, sending the Administrator a copy of that notification will satisfy the requirements of paragraph (a) of this section.(h) Individual subparts of this part may include specific provisions which clarify or make inapplicable the provisions set forth in this section.[36 FR 24877, Dec. 28, 1971, as amended at 40 FR 46254, Oct. 6, 1975; 40 FR 58418, Dec. 16, 1975; 45 FR 5617, Jan. 23, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 52 FR 9781, Mar. 26, 1987; 55 FR 51382, Dec. 13, 1990; 59 FR 12428, Mar. 16, 1994; 59 FR 47265, Sep. 15, 1994; 64 FR 7463, Feb. 12, 1999]&sect; 60.8 Performance tests.(a) Except as specified in paragraphs (a)(1),(a)(2), (a)(3), and (a)(4) of this section, within 60 days after achieving the maximum production rate at which the affected facility will be operated, but not later than 180 days after initial startup of such facility, or at such other times specified by this part, and at such other times as may be required by the Administrator under section 114 of the Act, the owner or operator of such facility shall conduct performance test(s) and furnish the Administrator a written report of the results of such performance test(s).(1) If a force majeure is about to occur, occurs, or has occurred for which the affected owner or operator intends to assert a claim of force majeure, the owner or operator shall notify the Administrator, in writing as soon as practicable following the date the owner or operator first knew, or through due diligence should have known that the event may cause or caused a delay in testing beyond the regulatory deadline, but the notification must occur before the performance test deadline unless the initial force majeure or a subsequent force majeure event delays the notice, and in such cases, the notification shall occur as soon as practicable.
Name Signature Title Date Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-9 of 29
(2) The owner or operator shall provide to the Administrator a written description of the force majeure event and a rationale for attributing the delay in testing beyond the regulatory deadline to the force majeure; describe the measures taken or to be taken to minimize the delay; and identify a date by which the owner or operator proposes to conduct the performance test. The performance test shall be conducted as soon as practicable after the force majeure occurs.(3) The decision as to whether or not to grant an extension to the performance test deadline is solely within the discretion of the Administrator.
 
The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an extension as soon as practicable.
APPENDIX NSPS SUBPART A General Conditions (e)
(4) Until an extension of the performance test deadline has been approved by the Administrator under paragraphs (a)(1), (2), and (3) of this section, the owner or operator of the affected facility remains strictly subject to the requirements of this part.(b) Performance tests shall be conducted and data reduced in accordance with the test methods and procedures contained in each applicable subpart unless the Administrator (1) specifies or approves, in specific cases, the use of a reference method with minor changes in methodology, (2) approves the use of an equivalent method, (3) approves the use of an alternative method the results of which he has determined to be adequate for indicating whether a specific source is in compliance, (4) waives the requirement for performance tests because the owner or operator of a source has demonstrated by other means to the Administrator's satisfaction that the affected facility is in compliance with the standard, or (5) approves shorter sampling times and smaller sample volumes when necessitated by process variables or other factors. Nothing in this paragraph shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act.(c) Performance tests shall be conducted under such conditions as the Administrator shall specify to the plant operator based on representative performance of the affected facility.
(1) Notwithstanding the frequency of reporting requirements specified in paragraph (c) of this section, an owner or operator who is required by an applicable subpart to submit excess emissions and monitoring systems performance reports (and summary reports) on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met:
The owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of the performance tests. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test nor shall emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and malfunction be considered a violation of the applicable emission limit unless otherwise specified in the applicable standard.(d) The owner or operator of an affected facility shall provide the Administrator at least 30 days prior notice of any performance test, except as specified under other subparts, to afford the Administrator the opportunity to have an observer present. If after 30 days notice for an initially scheduled performance test, there is a delay (due to operational Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-1I of 29 APPENDIX NSPS SUBPART A General Conditions problems, etc.) in conducting the scheduled performance test, the owner or operator of an affected facility shall notify the Administrator (or delegated State or local agency) as soon as possible of any delay in the original test date, either by providing at least 7 days prior notice of the rescheduled date of the performance test, or by arranging a rescheduled date with the Administrator (or delegated State or local agency) by mutual agreement.(e) The owner or operator of an affected facility shall provide, or cause to be provided, performance testing facilities as follows: (1) Sampling ports adequate for test methods applicable to such facility.
(i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected facility's excess emissions and monitoring systems reports submitted to comply with a standard under this part continually demonstrate that the facility is in compliance with the applicable standard; (ii) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the applicable standard; and (iii) The Administrator does not object to a reduced frequency of reporting for the affected facility, as provided in paragraph (e)(2) of this section.
This includes (i) constructing the air pollution control system such that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures and (ii) providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures.
(2) The frequency of reporting of excess emissions and monitoring systems performance (and summary) reports may be reduced only after the owner or operator notifies the Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the required recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements. Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention. The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted.
(3) As soon as monitoring data indicate that the affected facility is not in compliance with any emission limitation or operating parameter specified in the applicable standard, the frequency of reporting shall revert to the frequency specified in the applicable standard, and the owner or operator shall submit an excess emissions and monitoring systems performance report (and summary report, if required) at the next appropriate reporting period following the noncomplying event. After demonstrating compliance with the applicable standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard as provided for in paragraphs (e)(1) and (e)(2) of this section.
(f) Any owner or operator subject to the provisions of this part shall maintain a file of all measurements, including continuous monitoring system, monitoring device, and performance testing measurements; all continuous monitoring system performance evaluations; all continuous monitoring system or monitoring device calibration checks; adjustments and maintenance performed on these systems or devices; and all other information required by this part recorded in a permanent form suitable for inspection. The file shall be retained for at least two years following the date of such measurements, maintenance, reports, and records, except as follows:
(1) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard.
(2) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator.
(3) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (f) of this section, if the Administrator or the delegated Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-10 of 29
 
APPENDIX NSPS SUBPART A General Conditions authority determines these records are required to more accurately assess the compliance status of the affected source.
(g) If notification substantially similar to that in paragraph (a) of this section is required by any other State or local agency, sending the Administrator a copy of that notification will satisfy the requirements of paragraph (a) of this section.
(h) Individual subparts of this part may include specific provisions which clarify or make inapplicable the provisions set forth in this section.
[36 FR 24877, Dec. 28, 1971, as amended at 40 FR 46254, Oct. 6, 1975; 40 FR 58418, Dec. 16, 1975; 45 FR 5617, Jan. 23, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 52 FR 9781, Mar. 26, 1987; 55 FR 51382, Dec. 13, 1990; 59 FR 12428, Mar. 16, 1994; 59 FR 47265, Sep. 15, 1994; 64 FR 7463, Feb. 12, 1999]
&sect; 60.8 Performancetests.
(a) Except as specified in paragraphs (a)(1),(a)(2), (a)(3), and (a)(4) of this section, within 60 days after achieving the maximum production rate at which the affected facility will be operated, but not later than 180 days after initial startup of such facility, or at such other times specified by this part, and at such other times as may be required by the Administrator under section 114 of the Act, the owner or operator of such facility shall conduct performance test(s) and furnish the Administrator a written report of the results of such performance test(s).
(1) If a force majeure is about to occur, occurs, or has occurred for which the affected owner or operator intends to assert a claim of force majeure, the owner or operator shall notify the Administrator, in writing as soon as practicable following the date the owner or operator first knew, or through due diligence should have known that the event may cause or caused a delay in testing beyond the regulatory deadline, but the notification must occur before the performance test deadline unless the initial force majeure or a subsequent force majeure event delays the notice, and in such cases, the notification shall occur as soon as practicable.
(2) The owner or operator shall provide to the Administrator a written description of the force majeure event and a rationale for attributing the delay in testing beyond the regulatory deadline to the force majeure; describe the measures taken or to be taken to minimize the delay; and identify a date by which the owner or operator proposes to conduct the performance test. The performance test shall be conducted as soon as practicable after the force majeure occurs.
(3) The decision as to whether or not to grant an extension to the performance test deadline is solely within the discretion of the Administrator. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an extension as soon as practicable.
(4) Until an extension of the performance test deadline has been approved by the Administrator under paragraphs (a)(1),
(2), and (3) of this section, the owner or operator of the affected facility remains strictly subject to the requirements of this part.
(b) Performance tests shall be conducted and data reduced in accordance with the test methods and procedures contained in each applicable subpart unless the Administrator (1) specifies or approves, in specific cases, the use of a reference method with minor changes in methodology, (2) approves the use of an equivalent method, (3) approves the use of an alternative method the results of which he has determined to be adequate for indicating whether a specific source is in compliance, (4) waives the requirement for performance tests because the owner or operator of a source has demonstrated by other means to the Administrator's satisfaction that the affected facility is in compliance with the standard, or (5) approves shorter sampling times and smaller sample volumes when necessitated by process variables or other factors. Nothing in this paragraph shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act.
(c) Performance tests shall be conducted under such conditions as the Administrator shall specify to the plant operator based on representative performance of the affected facility. The owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of the performance tests. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test nor shall emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and malfunction be considered a violation of the applicable emission limit unless otherwise specified in the applicable standard.
(d) The owner or operator of an affected facility shall provide the Administrator at least 30 days prior notice of any performance test, except as specified under other subparts, to afford the Administrator the opportunity to have an observer present. If after 30 days notice for an initially scheduled performance test, there is a delay (due to operational Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-1I of 29
 
APPENDIX NSPS SUBPART A General Conditions problems, etc.) in conducting the scheduled performance test, the owner or operator of an affected facility shall notify the Administrator (or delegated State or local agency) as soon as possible of any delay in the original test date, either by providing at least 7 days prior notice of the rescheduled date of the performance test, or by arranging a rescheduled date with the Administrator (or delegated State or local agency) by mutual agreement.
(e) The owner or operator of an affected facility shall provide, or cause to be provided, performance testing facilities as follows:
(1) Sampling ports adequate for test methods applicable to such facility. This includes (i) constructing the air pollution control system such that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures and (ii) providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures.
(2) Safe sampling platform(s).
(2) Safe sampling platform(s).
(3) Safe access to sampling platform(s).
(3) Safe access to sampling platform(s).
(4) Utilities for sampling and testing equipment.(f) Unless otherwise specified in the applicable subpart, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the applicable standard.
(4) Utilities for sampling and testing equipment.
For the purpose of determining compliance with an applicable standard, the arithmetic means of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the Administrator's approval, be determined using the arithmetic mean of the results of the two other runs.[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974; 42 FR 57126, Nov. 1, 1977; 44 FR 33612, June 11, 1979; 54 FR 6662, Feb. 14, 1989; 54 FR 21344, May 17, 1989; 64 FR 7463, Feb. 12, 1999; 72 FR 27442, May 16, 2007]&sect; 60.9 Availability of information.
(f) Unless otherwise specified in the applicable subpart, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the applicable standard. For the purpose of determining compliance with an applicable standard, the arithmetic means of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the Administrator's approval, be determined using the arithmetic mean of the results of the two other runs.
The availability to the public of information provided to, or otherwise obtained by, the Administrator under this part shall be governed by part 2 of this chapter. (Information submitted voluntarily to the Administrator for the purposes of &sect;&sect;60.5 and 60.6 is governed by &sect;&sect;2.201 through 2.213 of this chapter and not by &sect;2.301 of this chapter.)&sect; 60.10 State authority.
[36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974; 42 FR 57126, Nov. 1, 1977; 44 FR 33612, June 11, 1979; 54 FR 6662, Feb. 14, 1989; 54 FR 21344, May 17, 1989; 64 FR 7463, Feb. 12, 1999; 72 FR 27442, May 16, 2007]
The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from: (a) Adopting and enforcing any emission standard or limitation applicable to an affected facility, provided that such emission standard or limitation is not less stringent than the standard applicable to such facility.(b) Requiring the owner or operator of an affected facility to obtain permits, licenses, or approvals prior to initiating construction, modification, or operation of such facility.&sect; 60.11 Compliance with standards and maintenance requirements.(a) Compliance with standards in this part, other than opacity standards, shall be determined in accordance with performance tests established by &sect;60.8, unless otherwise specified in the applicable standard.(b) Compliance with opacity standards in this part shall be determined by conducting observations in accordance with Method 9 in appendix A of this part, any alternative method that is approved by the Administrator, or as provided in paragraph (e)(5) of this section. For purposes of determining initial compliance, the minimum total time of observations shall be 3 hours (30 6-minute averages) for the performance test or other set of observations (meaning those fugitive-type emission sources subject only to an opacity standard).(c) The opacity standards set forth in this part shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard.(d) At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions.
&sect; 60.9 Availability of information.
Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-12 of 29 APPENDIX NSPS SUBPART A General Conditions (e)(1) For the purpose of demonstrating initial compliance, opacity observations shall be conducted concurrently with the initial performance test required in &sect;60.8 unless one of the following conditions apply. If no performance test under&sect;60.8 is required, then opacity observations shall be conducted within 60 days after achieving the maximum production rate at which the affected facility will be operated but no later than 180 days after initial startup of the facility.
The availability to the public of information provided to, or otherwise obtained by, the Administrator under this part shall be governed by part 2 of this chapter. (Information submitted voluntarily to the Administrator for the purposes of &sect;&sect;60.5 and 60.6 is governed by &sect;&sect;2.201 through 2.213 of this chapter and not by &sect;2.301 of this chapter.)
If visibility or other conditions prevent the opacity observations from being conducted concurrently with the initial performance test required under &sect;60.8, the source owner or operator shall reschedule the opacity observations as soon after the initial performance test as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. In these cases, the 30-day prior notification to the Administrator required in&sect;60.7(a)(6) shall be waived. The rescheduled opacity observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under &sect;60.8. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity observations from being made concurrently with the initial performance test in accordance with procedures contained in Method 9 of appendix B of this part. Opacity readings of portions of plumes which contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity standards.
&sect; 60.10 State authority.
The owner or operator of an affected facility shall make available, upon request by the Administrator, such records as may be necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification.
The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from:
Except as provided in paragraph (e)(5) of this section, the results of continuous monitoring by transmissometer which indicate that the opacity at the time visual observations were made was not in excess of the standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the source shall meet the burden of proving that the instrument used meets (at the time of the alleged violation)
(a) Adopting and enforcing any emission standard or limitation applicable to an affected facility, provided that such emission standard or limitation is not less stringent than the standard applicable to such facility.
Performance Specification 1 in appendix B of this part, has been properly maintained and (at the time of the alleged violation) that the resulting data have not been altered in any way.(2) Except as provided in paragraph (e)(3) of this section, the owner or operator of an affected facility to which an opacity standard in this part applies shall conduct opacity observations in accordance with paragraph (b) of this section, shall record the opacity of emissions, and shall report to the Administrator the opacity results along with the results of the initial performance test required under &sect;60.8. The inability of an owner or operator to secure a visible emissions observer shall not be considered a reason for not conducting the opacity observations concurrent with the initial performance test.(3) The owner or operator of an affected facility to which an opacity standard in this part applies may request the Administrator to determine and to record the opacity of emissions from the affected facility during the initial performance test and at such times as may be required.
(b) Requiring the owner or operator of an affected facility to obtain permits, licenses, or approvals prior to initiating construction, modification, or operation of such facility.
The owner or operator of the affected facility shall report the opacity results. Any request to the Administrator to determine and to record the opacity of emissions from an affected facility shall be included in the notification required in &sect;60.7(a)(6).
&sect; 60.11 Compliance with standards and maintenance requirements.
If, for some reason, the Administrator cannot determine and record the opacity of emissions from the affected facility during the performance test, then the provisions of paragraph (e)(1) of this section shall apply.(4) An owner or operator of an affected facility using a continuous opacity monitor (transmissometer) shall record the monitoring data produced during the initial performance test required by &sect;60.8 and shall furnish the Administrator a written report of the monitoring results along with Method 9 and &sect;60.8 performance test results.(5) An owner or operator of an affected facility subject to an opacity standard may submit, for compliance purposes, continuous opacity monitoring system (COMS) data results produced during any performance test required under&sect;60.8 in lieu of Method 9 observation data. If an owner or operator elects to submit COMS data for compliance with the opacity standard, he shall notify the Administrator of that decision, in writing, at least 30 days before any performance test required under &sect;60.8 is conducted.
(a) Compliance with standards in this part, other than opacity standards, shall be determined in accordance with performance tests established by &sect;60.8, unless otherwise specified in the applicable standard.
Once the owner or operator of an affected facility has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent tests required under &sect;60.8 until the owner or operator notifies the Administrator, in writing, to the contrary.
(b) Compliance with opacity standards in this part shall be determined by conducting observations in accordance with Method 9 in appendix A of this part, any alternative method that is approved by the Administrator, or as provided in paragraph (e)(5) of this section. For purposes of determining initial compliance, the minimum total time of observations shall be 3 hours (30 6-minute averages) for the performance test or other set of observations (meaning those fugitive-type emission sources subject only to an opacity standard).
For the purpose of determining compliance with the opacity standard during a performance test required under &sect;60.8 using COMS data, the minimum total time of COMS data collection shall be averages of all 6-minute continuous periods within the duration of the mass emission performance test. Results of the COMS opacity determinations shall be submitted along with the results of the performance test required under &sect;60.8. The owner or operator of an affected facility using a COMS for compliance purposes is responsible for demonstrating that the COMS meets the requirements specified in &sect;60.13(c) of this part, that the COMS has been properly maintained and operated, and that the resulting data have not been altered in any way. If COMS data results are submitted for compliance with the opacity standard for a period of time during which Method 9 data indicates noncompliance, the Method 9 data will be used to determine compliance with the opacity standard.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A- 13 of 29 APPENDIX NSPS SUBPART A General Conditions (6) Upon receipt from an owner or operator of the written reports of the results of the performance tests required by&sect;60.8, the opacity observation results and observer certification required by &sect;60.11(e)(1), and the COMS results, if applicable, the Administrator will make a finding concerning compliance with opacity and other applicable standards.
(c) The opacity standards set forth in this part shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard.
If COMS data results are used to comply with an opacity standard, only those results are required to be submitted along with the performance test results required by &sect;60.8. If the Administrator finds that an affected facility is in compliance with all applicable standards for which performance tests are conducted in accordance with&sect;60.8 of this part but during the time such performance tests are being conducted fails to meet any applicable opacity standard, he shall notify the owner or operator and advise him that he may petition the Administrator within 10 days of receipt of notification to make appropriate adjustment to the opacity standard for the affected facility.(7) The Administrator will grant such a petition upon a demonstration by the owner or operator that the affected facility and associated air pollution control equipment was operated and maintained in a manner to minimize the opacity of emissions during the performance tests; that the performance tests were performed under the conditions established by the Administrator; and that the affected facility and associated air pollution control equipment were incapable of being adjusted or operated to meet the applicable opacity standard.(8) The Administrator will establish an opacity standard for the affected facility meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity standard at all times during which the source is meeting the mass or concentration emission standard.
(d) At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source.
The Administrator will promulgate the new opacity standard in the Federal Register.(f) Special provisions set forth under an applicable subpart shall supersede any conflicting provisions in paragraphs (a)through (e) of this section.(g) For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in this part, nothing in this part shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-12 of 29
[38 FR 28565, Oct. 15, 1973, as amended at 39 FR 39873, Nov. 12, 1974; 43 FR 8800, Mar. 3, 1978; 45 FR 23379, Apr. 4, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 51 FR 1790, Jan. 15, 1986; 52 FR 9781, Mar. 26, 1987; 62 FR 8328, Feb. 24, 1997; 65 FR 61749, Oct. 17, 2000]&sect; 60.12 Circumvention.
 
No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard.
APPENDIX NSPS SUBPART A General Conditions (e)
Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere.
(1) For the purpose of demonstrating initial compliance, opacity observations shall be conducted concurrently with the initial performance test required in &sect;60.8 unless one of the following conditions apply. If no performance test under
[39 FR 9314, Mar. 8, 1974]&sect; 60.13 Monitoring requirements.(a) For the purposes of this section, all continuous monitoring systems required under applicable subparts shall be subject to the provisions of this section upon promulgation of performance specifications for continuous monitoring systems under appendix B to this part and, if the continuous monitoring system is used to demonstrate compliance with emission limits on a continuous basis, appendix F to this part, unless otherwise specified in an applicable subpart or by the Administrator.
          &sect;60.8 is required, then opacity observations shall be conducted within 60 days after achieving the maximum production rate at which the affected facility will be operated but no later than 180 days after initial startup of the facility. If visibility or other conditions prevent the opacity observations from being conducted concurrently with the initial performance test required under &sect;60.8, the source owner or operator shall reschedule the opacity observations as soon after the initial performance test as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. In these cases, the 30-day prior notification to the Administrator required in
Appendix F is applicable December 4, 1987.(b) All continuous monitoring systems and monitoring devices shall be installed and operational prior to conducting performance tests under &sect;60.8. Verification of operational status shall, as a minimum, include completion of the manufacturer's written requirements or recommendations for installation, operation, and calibration of the device.(c) If the owner or operator of an affected facility elects to submit continuous opacity monitoring system (COMS) data for compliance with the opacity standard as provided under &sect;60.11(e)(5), he shall conduct a performance evaluation of the COMS as specified in Performance Specification 1, appendix B, of this part before the performance test required under&sect;60.8 is conducted.
        &sect;60.7(a)(6) shall be waived. The rescheduled opacity observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under &sect;60.8. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity observations from being made concurrently with the initial performance test in accordance with procedures contained in Method 9 of appendix B of this part. Opacity readings of portions of plumes which contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity standards. The owner or operator of an affected facility shall make available, upon request by the Administrator, such records as may be necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification. Except as provided in paragraph (e)(5) of this section, the results of continuous monitoring by transmissometer which indicate that the opacity at the time visual observations were made was not in excess of the standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the source shall meet the burden of proving that the instrument used meets (at the time of the alleged violation) Performance Specification 1 in appendix B of this part, has been properly maintained and (at the time of the alleged violation) that the resulting data have not been altered in any way.
Otherwise, the owner or operator of an affected facility shall conduct a performance evaluation of the COMS or continuous emission monitoring system (CEMS) during any performance test required under &sect;60.8 or within 30 days thereafter in accordance with the applicable performance specification in appendix B of this part, The owner or operator of an affected facility shall conduct COMS or CEMS performance evaluations at such other times as may be required by the Administrator under section 114 of the Act.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-14 of 29 APPENDIX NSPS SUBPART A General Conditions (1) The owner or operator of an affected facility using a COMS to determine opacity compliance during any performance test required under &sect;60.8 and as described in &sect;60.11(e)(5) shall furnish the Administrator two or, upon request, more copies of a written report of the results of the COMS performance evaluation described in paragraph (c) of this section at least 10 days before the performance test required under &sect;60.8 is conducted.
(2) Except as provided in paragraph (e)(3) of this section, the owner or operator of an affected facility to which an opacity standard in this part applies shall conduct opacity observations in accordance with paragraph (b) of this section, shall record the opacity of emissions, and shall report to the Administrator the opacity results along with the results of the initial performance test required under &sect;60.8. The inability of an owner or operator to secure a visible emissions observer shall not be considered a reason for not conducting the opacity observations concurrent with the initial performance test.
(2) Except as provided in paragraph (c)(1) of this section, the owner or operator of an affected facility shall furnish the Administrator within 60 days of completion two or, upon request, more copies of a written report of the results of the performance evaluation.(d)(1) Owners and operators of a CEMS installed in accordance with the provisions of this part, must check the zero (or low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily in accordance with a written procedure.
(3) The owner or operator of an affected facility to which an opacity standard in this part applies may request the Administrator to determine and to record the opacity of emissions from the affected facility during the initial performance test and at such times as may be required. The owner or operator of the affected facility shall report the opacity results. Any request to the Administrator to determine and to record the opacity of emissions from an affected facility shall be included in the notification required in &sect;60.7(a)(6). If, for some reason, the Administrator cannot determine and record the opacity of emissions from the affected facility during the performance test, then the provisions of paragraph (e)(1) of this section shall apply.
The zero and span must, as a minimum, be adjusted whenever either the 24-hour zero drift or the 24-hour span drift exceeds two times the limit of the applicable performance specification in appendix B of this part. The system must allow the amount of the excess zero and span drift to be recorded and quantified whenever specified.
(4) An owner or operator of an affected facility using a continuous opacity monitor (transmissometer) shall record the monitoring data produced during the initial performance test required by &sect;60.8 and shall furnish the Administrator a written report of the monitoring results along with Method 9 and &sect;60.8 performance test results.
Owners and operators of a COMS installed in accordance with the provisions of this part, must automatically, intrinsic to the opacity monitor, check the zero and upscale (span) calibration drifts at least once daily. For a particular COMS, the acceptable range of zero and upscale calibration materials is as defined in the applicable version of PS-1 in appendix B of this part. For a COMS, the optical surfaces, exposed to the effluent gases, must be cleaned before performing the zero and upscale drift adjustments, except for systems using automatic zero adjustments.
(5) An owner or operator of an affected facility subject to an opacity standard may submit, for compliance purposes, continuous opacity monitoring system (COMS) data results produced during any performance test required under
The optical surfaces must be cleaned when the cumulative automatic zero compensation exceeds 4 percent opacity.(2) Unless otherwise approved by the Administrator, the following procedures must be followed for a COMS. Minimum procedures must include an automated method for producing a simulated zero opacity condition and an upscale opacity condition using a certified neutral density filter or other related technique to produce a known obstruction of the light beam. Such procedures must provide a system check of all active analyzer internal optics with power or curvature, all active electronic circuitry including the light source and photodetector assembly, and electronic or electro-mechanical systems and hardware and or software used during normal measurement operation.(e) Except for system breakdowns, repairs, calibration checks, and zero and span adjustments required under paragraph (d)of this section, all continuous monitoring systems shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: (1) All continuous monitoring systems referenced by paragraph (c) of this section for measuring opacity of emissions shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.(2) All continuous monitoring systems referenced by paragraph (c) of this section for measuring emissions, except opacity, shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period.(f) All continuous monitoring systems or monitoring devices shall be installed such that representative measurements of emissions or process parameters from the affected facility are obtained.
        &sect;60.8 in lieu of Method 9 observation data. If an owner or operator elects to submit COMS data for compliance with the opacity standard, he shall notify the Administrator of that decision, in writing, at least 30 days before any performance test required under &sect;60.8 is conducted. Once the owner or operator of an affected facility has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent tests required under &sect;60.8 until the owner or operator notifies the Administrator, in writing, to the contrary. For the purpose of determining compliance with the opacity standard during a performance test required under &sect;60.8 using COMS data, the minimum total time of COMS data collection shall be averages of all 6-minute continuous periods within the duration of the mass emission performance test. Results of the COMS opacity determinations shall be submitted along with the results of the performance test required under &sect;60.8. The owner or operator of an affected facility using a COMS for compliance purposes is responsible for demonstrating that the COMS meets the requirements specified in &sect;60.13(c) of this part, that the COMS has been properly maintained and operated, and that the resulting data have not been altered in any way. If COMS data results are submitted for compliance with the opacity standard for a period of time during which Method 9 data indicates noncompliance, the Method 9 data will be used to determine compliance with the opacity standard.
Additional procedures for location of continuous monitoring systems contained in the applicable Performance Specifications of appendix B of this part shall be used.(g) When the effluents from a single affected facility or two or more affected facilities subject to the same emission standards are combined before being released to the atmosphere, the owner or operator may install applicable continuous monitoring systems on each effluent or on the combined effluent.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A- 13 of 29
When the affected facilities are not subject to the same emission standards, separate continuous monitoring systems shall be installed on each effluent.
 
When the effluent from one affected facility is released to the atmosphere through more than one point, the owner or operator shall install an applicable continuous monitoring system on each separate effluent unless the installation of fewer systems is approved by the Administrator.
APPENDIX NSPS SUBPART A General Conditions (6) Upon receipt from an owner or operator of the written reports of the results of the performance tests required by
When more than one continuous monitoring system is used to measure the emissions from one affected facility (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required from each continuous monitoring system.(h)(1) Owners or operators of all continuous monitoring systems for measurement of opacity shall reduce all data to 6-minute averages and for continuous monitoring systems other than opacity to 1-hour averages for time periods as defined in &sect;60.2. Six-minute opacity averages shall be calculated from 36 or more data points equally spaced over each 6-minute period.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-15 of 29 APPENDIX NSPS SUBPART A General Conditions (2) For continuous monitoring systems other than opacity, 1-hour averages shall be computed as follows, except that the provisions pertaining to the validation of partial operating hours are only applicable for affected facilities that are required by the applicable subpart to include partial hours in the emission calculations: (i) Except as provided under paragraph (h)(2)(iii) of this section, for a full operating hour (any clock hour with 60 minutes of unit operation), at least four valid data points are required to calculate the hourly average, i.e. , one data point in each of the 15-minute quadrants of the hour.(ii) Except as provided under paragraph (h)(2)(iii) of this section, for a partial operating hour (any clock hour with less than 60 minutes of unit operation), at least one valid data point in each 15-minute quadrant of the hour in which the unit operates is required to calculate the hourly average.(iii) For any operating hour in which required maintenance or quality-assurance activities are performed: (A) If the unit operates in two or more quadrants of the hour, a minimum of two valid data points, separated by at least 15 minutes, is required to calculate the hourly average; or (B) If the unit operates in only one quadrant of the hour, at least one valid data point is required to calculate the hourly average.(iv) If a daily calibration error check is failed during any operating hour, all data for that hour shall be invalidated, unless a subsequent calibration error test is passed in the same hour and the requirements of paragraph (h)(2)(iii) of this section are met, based solely on valid data recorded after the successful calibration.(v) For each full or partial operating hour, all valid data points shall be used to calculate the hourly average.(vi) Except as provided under paragraph (h)(2)(vii) of this section, data recorded during periods of continuous monitoring system breakdown, repair, calibration checks, and zero and span adjustments shall not be included in the data averages computed under this paragraph.(vii)Owners and operators complying with the requirements of &sect;60.7(f)(1) or (2) must include any data recorded during periods of monitor breakdown or malfunction in the data averages.(viii) When specified in an applicable subpart, hourly averages for certain partial operating hours shall not be computed or included in the emission averages ( e.g. hours with < 30 minutes of unit operation under&sect;60.47b(d)).(ix) Either arithmetic or integrated averaging of all data may be used to calculate the hourly averages.
          &sect;60.8, the opacity observation results and observer certification required by &sect;60.11(e)(1), and the COMS results, if applicable, the Administrator will make a finding concerning compliance with opacity and other applicable standards. If COMS data results are used to comply with an opacity standard, only those results are required to be submitted along with the performance test results required by &sect;60.8. If the Administrator finds that an affected facility is in compliance with all applicable standards for which performance tests are conducted in accordance with
The data may be recorded in reduced or nonreduced form ( e.g. , ppm pollutant and percent O 2 or ng/J of pollutant).
          &sect;60.8 of this part but during the time such performance tests are being conducted fails to meet any applicable opacity standard, he shall notify the owner or operator and advise him that he may petition the Administrator within 10 days of receipt of notification to make appropriate adjustment to the opacity standard for the affected facility.
(3) All excess emissions shall be converted into units of the standard using the applicable conversion procedures specified in the applicable subpart. After conversion into units of the standard, the data may be rounded to the same number of significant digits used in the applicable subpart to specify the emission limit.(i) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring procedures or requirements of this part including, but not limited to the following:
(7) The Administrator will grant such a petition upon a demonstration by the owner or operator that the affected facility and associated air pollution control equipment was operated and maintained in a manner to minimize the opacity of emissions during the performance tests; that the performance tests were performed under the conditions established by the Administrator; and that the affected facility and associated air pollution control equipment were incapable of being adjusted or operated to meet the applicable opacity standard.
(1) Alternative monitoring requirements when installation of a continuous monitoring system or monitoring device specified by this part would not provide accurate measurements due to liquid water or other interferences caused by substances in the effluent gases.(2) Alternative monitoring requirements when the affected facility is infrequently operated.(3) Alternative monitoring requirements to accommodate continuous monitoring systems that require additional measurements to correct for stack moisture conditions.
(8) The Administrator will establish an opacity standard for the affected facility meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity standard at all times during which the source is meeting the mass or concentration emission standard. The Administrator will promulgate the new opacity standard in the Federal Register.
(f) Special provisions set forth under an applicable subpart shall supersede any conflicting provisions in paragraphs (a) through (e) of this section.
(g) For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in this part, nothing in this part shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed.
[38 FR 28565, Oct. 15, 1973, as amended at 39 FR 39873, Nov. 12, 1974; 43 FR 8800, Mar. 3, 1978; 45 FR 23379, Apr. 4, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 51 FR 1790, Jan. 15, 1986; 52 FR 9781, Mar. 26, 1987; 62 FR 8328, Feb. 24, 1997; 65 FR 61749, Oct. 17, 2000]
&sect; 60.12 Circumvention.
No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere.
[39 FR 9314, Mar. 8, 1974]
&sect; 60.13 Monitoringrequirements.
(a) For the purposes of this section, all continuous monitoring systems required under applicable subparts shall be subject to the provisions of this section upon promulgation of performance specifications for continuous monitoring systems under appendix B to this part and, if the continuous monitoring system is used to demonstrate compliance with emission limits on a continuous basis, appendix F to this part, unless otherwise specified in an applicable subpart or by the Administrator. Appendix F is applicable December 4, 1987.
(b) All continuous monitoring systems and monitoring devices shall be installed and operational prior to conducting performance tests under &sect;60.8. Verification of operational status shall, as a minimum, include completion of the manufacturer's written requirements or recommendations for installation, operation, and calibration of the device.
(c) If the owner or operator of an affected facility elects to submit continuous opacity monitoring system (COMS) data for compliance with the opacity standard as provided under &sect;60.11(e)(5), he shall conduct a performance evaluation of the COMS as specified in Performance Specification 1, appendix B, of this part before the performance test required under
    &sect;60.8 is conducted. Otherwise, the owner or operator of an affected facility shall conduct a performance evaluation of the COMS or continuous emission monitoring system (CEMS) during any performance test required under &sect;60.8 or within 30 days thereafter in accordance with the applicable performance specification in appendix B of this part, The owner or operator of an affected facility shall conduct COMS or CEMS performance evaluations at such other times as may be required by the Administrator under section 114 of the Act.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-14 of 29
 
APPENDIX NSPS SUBPART A General Conditions (1) The owner or operator of an affected facility using a COMS to determine opacity compliance during any performance test required under &sect;60.8 and as described in &sect;60.11(e)(5) shall furnish the Administrator two or, upon request, more copies of a written report of the results of the COMS performance evaluation described in paragraph (c) of this section at least 10 days before the performance test required under &sect;60.8 is conducted.
(2) Except as provided in paragraph (c)(1) of this section, the owner or operator of an affected facility shall furnish the Administrator within 60 days of completion two or, upon request, more copies of a written report of the results of the performance evaluation.
(d)
(1) Owners and operators of a CEMS installed in accordance with the provisions of this part, must check the zero (or low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily in accordance with a written procedure. The zero and span must, as a minimum, be adjusted whenever either the 24-hour zero drift or the 24-hour span drift exceeds two times the limit of the applicable performance specification in appendix B of this part. The system must allow the amount of the excess zero and span drift to be recorded and quantified whenever specified. Owners and operators of a COMS installed in accordance with the provisions of this part, must automatically, intrinsic to the opacity monitor, check the zero and upscale (span) calibration drifts at least once daily. For a particular COMS, the acceptable range of zero and upscale calibration materials is as defined in the applicable version of PS-1 in appendix B of this part. For a COMS, the optical surfaces, exposed to the effluent gases, must be cleaned before performing the zero and upscale drift adjustments, except for systems using automatic zero adjustments. The optical surfaces must be cleaned when the cumulative automatic zero compensation exceeds 4 percent opacity.
(2) Unless otherwise approved by the Administrator, the following procedures must be followed for a COMS. Minimum procedures must include an automated method for producing a simulated zero opacity condition and an upscale opacity condition using a certified neutral density filter or other related technique to produce a known obstruction of the light beam. Such procedures must provide a system check of all active analyzer internal optics with power or curvature, all active electronic circuitry including the light source and photodetector assembly, and electronic or electro-mechanical systems and hardware and or software used during normal measurement operation.
(e) Except for system breakdowns, repairs, calibration checks, and zero and span adjustments required under paragraph (d) of this section, all continuous monitoring systems shall be in continuous operation and shall meet minimum frequency of operation requirements as follows:
(1) All continuous monitoring systems referenced by paragraph (c) of this section for measuring opacity of emissions shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.
(2) All continuous monitoring systems referenced by paragraph (c) of this section for measuring emissions, except opacity, shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period.
(f) All continuous monitoring systems or monitoring devices shall be installed such that representative measurements of emissions or process parameters from the affected facility are obtained. Additional procedures for location of continuous monitoring systems contained in the applicable Performance Specifications of appendix B of this part shall be used.
(g) When the effluents from a single affected facility or two or more affected facilities subject to the same emission standards are combined before being released to the atmosphere, the owner or operator may install applicable continuous monitoring systems on each effluent or on the combined effluent. When the affected facilities are not subject to the same emission standards, separate continuous monitoring systems shall be installed on each effluent. When the effluent from one affected facility is released to the atmosphere through more than one point, the owner or operator shall install an applicable continuous monitoring system on each separate effluent unless the installation of fewer systems is approved by the Administrator. When more than one continuous monitoring system is used to measure the emissions from one affected facility (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required from each continuous monitoring system.
(h)
(1) Owners or operators of all continuous monitoring systems for measurement of opacity shall reduce all data to 6-minute averages and for continuous monitoring systems other than opacity to 1-hour averages for time periods as defined in &sect;60.2. Six-minute opacity averages shall be calculated from 36 or more data points equally spaced over each 6-minute period.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-15 of 29
 
APPENDIX NSPS SUBPART A General Conditions (2) For continuous monitoring systems other than opacity, 1-hour averages shall be computed as follows, except that the provisions pertaining to the validation of partial operating hours are only applicable for affected facilities that are required by the applicable subpart to include partial hours in the emission calculations:
(i) Except as provided under paragraph (h)(2)(iii) of this section, for a full operating hour (any clock hour with 60 minutes of unit operation), at least four valid data points are required to calculate the hourly average, i.e. , one data point in each of the 15-minute quadrants of the hour.
(ii) Except as provided under paragraph (h)(2)(iii) of this section, for a partial operating hour (any clock hour with less than 60 minutes of unit operation), at least one valid data point in each 15-minute quadrant of the hour in which the unit operates is required to calculate the hourly average.
(iii) For any operating hour in which required maintenance or quality-assurance activities are performed:
(A) If the unit operates in two or more quadrants of the hour, a minimum of two valid data points, separated by at least 15 minutes, is required to calculate the hourly average; or (B) If the unit operates in only one quadrant of the hour, at least one valid data point is required to calculate the hourly average.
(iv) If a daily calibration error check is failed during any operating hour, all data for that hour shall be invalidated, unless a subsequent calibration error test is passed in the same hour and the requirements of paragraph (h)(2)(iii) of this section are met, based solely on valid data recorded after the successful calibration.
(v) For each full or partial operating hour, all valid data points shall be used to calculate the hourly average.
(vi) Except as provided under paragraph (h)(2)(vii) of this section, data recorded during periods of continuous monitoring system breakdown, repair, calibration checks, and zero and span adjustments shall not be included in the data averages computed under this paragraph.
(vii)Owners and operators complying with the requirements of &sect;60.7(f)(1) or (2) must include any data recorded during periods of monitor breakdown or malfunction in the data averages.
(viii)     When specified in an applicable subpart, hourly averages for certain partial operating hours shall not be computed or included in the emission averages ( e.g. hours with < 30 minutes of unit operation under
                &sect;60.47b(d)).
(ix) Either arithmetic or integrated averaging of all data may be used to calculate the hourly averages. The data may be recorded in reduced or nonreduced form ( e.g. , ppm pollutant and percent O 2or ng/J of pollutant).
(3) All excess emissions shall be converted into units of the standard using the applicable conversion procedures specified in the applicable subpart. After conversion into units of the standard, the data may be rounded to the same number of significant digits used in the applicable subpart to specify the emission limit.
(i) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring procedures or requirements of this part including, but not limited to the following:
(1) Alternative monitoring requirements when installation of a continuous monitoring system or monitoring device specified by this part would not provide accurate measurements due to liquid water or other interferences caused by substances in the effluent gases.
(2) Alternative monitoring requirements when the affected facility is infrequently operated.
(3) Alternative monitoring requirements to accommodate continuous monitoring systems that require additional measurements to correct for stack moisture conditions.
(4) Alternative locations for installing continuous monitoring systems or monitoring devices when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements.
(4) Alternative locations for installing continuous monitoring systems or monitoring devices when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements.
(5) Alternative methods of converting pollutant concentration measurements to units of the standards.
(5) Alternative methods of converting pollutant concentration measurements to units of the standards.
(6) Alternative procedures for performing daily checks of zero and span drift that do not involve use of span gases or test cells.(7) Alternatives to the A.S.T.M. test methods or sampling procedures specified by any subpart.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A- 16 of 29 APPENDIX NSPS SUBPART A General Conditions (8) Alternative continuous monitoring systems that do not meet the design or performance requirements in Performance Specification 1, appendix B, but adequately demonstrate a definite and consistent relationship between its measurements and the measurements of opacity by a system complying with the requirements in Performance Specification  
(6) Alternative procedures for performing daily checks of zero and span drift that do not involve use of span gases or test cells.
: 1. The Administrator may require that such demonstration be performed for each affected facility.(9) Alternative monitoring requirements when the effluent from a single affected facility or the combined effluent from two or more affected facilities is released to the atmosphere through more than one point.(j) An alternative to the relative accuracy (RA) test specified in Performance Specification 2 of appendix B may be requested as follows: (1) An alternative to the reference method tests for determining RA is available for sources with emission rates demonstrated to be less than 50 percent of the applicable standard.
(7) Alternatives to the A.S.T.M. test methods or sampling procedures specified by any subpart.
A source owner or operator may petition the Administrator to waive the RA test in Section 8.4 of Performance Specification 2 and substitute the procedures in Section 16.0 if the results of a performance test conducted according to the requirements in &sect;60.8 of this subpart or other tests performed following the criteria in &sect;60.8 demonstrate that the emission rate of the pollutant of interest in the units of the applicable standard is less than 50 percent of the applicable standard.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page A- 16 of 29
For sources subject to standards expressed as control efficiency levels, a source owner or operator may petition the Administrator to waive the RA test and substitute the procedures in Section 16.0 of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement.
 
The alternative procedures do not apply if the continuous emission monitoring system is used to determine compliance continuously with the applicable standard.
APPENDIX NSPS SUBPART A General Conditions (8) Alternative continuous monitoring systems that do not meet the design or performance requirements in Performance Specification 1, appendix B, but adequately demonstrate a definite and consistent relationship between its measurements and the measurements of opacity by a system complying with the requirements in Performance Specification 1. The Administrator may require that such demonstration be performed for each affected facility.
The petition to waive the RA test shall include a detailed description of the procedures to be applied. Included shall be location and procedure for conducting the alternative, the concentration or response levels of the alternative RA materials, and the other equipment checks included in the alternative procedure.
(9) Alternative monitoring requirements when the effluent from a single affected facility or the combined effluent from two or more affected facilities is released to the atmosphere through more than one point.
The Administrator will review the petition for completeness and applicability.
(j) An alternative to the relative accuracy (RA) test specified in Performance Specification 2 of appendix B may be requested as follows:
The determination to grant a waiver will depend on the intended use of the CEMS data (e.g., data collection purposes other than NSPS) and may require specifications more stringent than in Performance Specification 2 (e.g., the applicable emission limit is more stringent than NSPS).(2) The waiver of a CEMS RA test will be reviewed and may be rescinded at such time, following successful completion of the alternative RA procedure, that the CEMS data indicate that the source emissions are approaching the level. The criterion for reviewing the waiver is the collection of CEMS data showing that emissions have exceeded 70 percent of the applicable standard for seven, consecutive, averaging periods as specified by the applicable regulation(s).
(1) An alternative to the reference method tests for determining RA is available for sources with emission rates demonstrated to be less than 50 percent of the applicable standard. A source owner or operator may petition the Administrator to waive the RA test in Section 8.4 of Performance Specification 2 and substitute the procedures in Section 16.0 if the results of a performance test conducted according to the requirements in &sect;60.8 of this subpart or other tests performed following the criteria in &sect;60.8 demonstrate that the emission rate of the pollutant of interest in the units of the applicable standard is less than 50 percent of the applicable standard. For sources subject to standards expressed as control efficiency levels, a source owner or operator may petition the Administrator to waive the RA test and substitute the procedures in Section 16.0 of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement. The alternative procedures do not apply if the continuous emission monitoring system is used to determine compliance continuously with the applicable standard. The petition to waive the RA test shall include a detailed description of the procedures to be applied. Included shall be location and procedure for conducting the alternative, the concentration or response levels of the alternative RA materials, and the other equipment checks included in the alternative procedure. The Administrator will review the petition for completeness and applicability. The determination to grant a waiver will depend on the intended use of the CEMS data (e.g., data collection purposes other than NSPS) and may require specifications more stringent than in Performance Specification 2 (e.g., the applicable emission limit is more stringent than NSPS).
For sources subject to standards expressed as control efficiency levels, the criterion for reviewing the waiver is the collection of CEMS data showing that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for seven, consecutive, averaging periods as specified by the applicable regulation(s)  
(2) The waiver of a CEMS RA test will be reviewed and may be rescinded at such time, following successful completion of the alternative RA procedure, that the CEMS data indicate that the source emissions are approaching the level. The criterion for reviewing the waiver is the collection of CEMS data showing that emissions have exceeded 70 percent of the applicable standard for seven, consecutive, averaging periods as specified by the applicable regulation(s). For sources subject to standards expressed as control efficiency levels, the criterion for reviewing the waiver is the collection of CEMS data showing that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for seven, consecutive, averaging periods as specified by the applicable regulation(s) [e.g., &sect;60.45(g) (2) and (3), &sect;60.73(e), and &sect;60.84(e)]. It is the responsibility of the source operator to maintain records and determine the level of emissions relative to the criterion on the waiver of RA testing. If this criterion is exceeded, the owner or operator must notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increasing emissions. The Administrator will review the notification and may rescind the waiver and require the owner or operator to conduct a RA test of the CEMS as specified in Section 8.4 of Performance Specification 2.
[e.g., &sect;60.45(g)  
[40 FR 46255, Oct. 6, 1975; 40 FR 59205, Dec. 22, 1975, as amended at 41 FR 35185, Aug. 20, 1976; 48 FR 13326, Mar. 30, 1983; 48 FR 23610, May 25, 1983; 48 FR 32986, July 20, 1983; 52 FR 9782, Mar. 26, 1987; 52 FR 17555, May 11, 1987; 52 FR 21007, June 4, 1987; 64 FR 7463, Feb. 12, 1999; 65 FR 48920, Aug. 10, 2000; 65 FR 61749, Oct. 17, 2000; 66 FR 44980, Aug. 27, 2001; 71 FR 31102, June 1, 2006; 72 FR 32714, June 13, 2007]
(2) and (3), &sect;60.73(e), and &sect;60.84(e)].
Editorial Note: At 65 FR 61749, Oct. 17, 2000, &sect;60.13 was amended by revising the words "ng/J of pollutant" to read "ng of pollutant per J of heat input" in the sixth sentence of paragraph (h). However, the amendment could not be incorporated because the words "ng/J of pollutant" do not exist in the sixth sentence of paragraph (h).
It is the responsibility of the source operator to maintain records and determine the level of emissions relative to the criterion on the waiver of RA testing. If this criterion is exceeded, the owner or operator must notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increasing emissions.
&sect; 60.14 Modification.
The Administrator will review the notification and may rescind the waiver and require the owner or operator to conduct a RA test of the CEMS as specified in Section 8.4 of Performance Specification 2.[40 FR 46255, Oct. 6, 1975; 40 FR 59205, Dec. 22, 1975, as amended at 41 FR 35185, Aug. 20, 1976; 48 FR 13326, Mar. 30, 1983; 48 FR 23610, May 25, 1983; 48 FR 32986, July 20, 1983; 52 FR 9782, Mar. 26, 1987; 52 FR 17555, May 11, 1987; 52 FR 21007, June 4, 1987; 64 FR 7463, Feb. 12, 1999; 65 FR 48920, Aug. 10, 2000; 65 FR 61749, Oct. 17, 2000; 66 FR 44980, Aug. 27, 2001; 71 FR 31102, June 1, 2006; 72 FR 32714, June 13, 2007]Editorial Note: At 65 FR 61749, Oct. 17, 2000, &sect;60.13 was amended by revising the words "ng/J of pollutant" to read "ng of pollutant per J of heat input" in the sixth sentence of paragraph (h). However, the amendment could not be incorporated because the words "ng/J of pollutant" do not exist in the sixth sentence of paragraph (h).&sect; 60.14 Modification.(a) Except as provided under paragraphs (e) and (f) of this section, any physical or operational change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which a standard applies shall be considered a modification within the meaning of section 111 of the Act. Upon modification, an existing facility shall become an affected facility for each pollutant to which a standard applies and for which there is an increase in the emission rate to the atmosphere.(b) Emission rate shall be expressed as kg/hr of any pollutant discharged into the atmosphere for which a standard is applicable.
(a) Except as provided under paragraphs (e) and (f) of this section, any physical or operational change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which a standard applies shall be considered a modification within the meaning of section 111 of the Act. Upon modification, an existing facility shall become an affected facility for each pollutant to which a standard applies and for which there is an increase in the emission rate to the atmosphere.
The Administrator shall use the following to determine emission rate: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-17 of 29 APPENDIX NSPS SUBPART A General Conditions (1) Emission factors as specified in the latest issue of "Compilation of Air Pollutant Emission Factors," EPA Publication No. AP-42, or other emission factors determined by the Administrator to be superior to AP-42 emission factors, in cases where utilization of emission factors demonstrates that the emission level resulting from the physical or operational change will either clearly increase or clearly not increase.(2) Material balances, continuous monitor data, or manual emission tests in cases where utilization of emission factors as referenced in paragraph (b)(1) of this section does not demonstrate to the Administrator's satisfaction whether the emission level resulting from the physical or operational change will either clearly increase or clearly not increase, or where an owner or operator demonstrates to the Administrator's satisfaction that there are reasonable grounds to dispute the result obtained by the Administrator utilizing emission factors as referenced in paragraph (b)(1) of this section. When the emission rate is based on results from manual emission tests or continuous monitoring systems, the procedures specified in appendix C of this part shall be used to determine whether an increase in emission rate has occurred.
(b) Emission rate shall be expressed as kg/hr of any pollutant discharged into the atmosphere for which a standard is applicable. The Administrator shall use the following to determine emission rate:
Tests shall be conducted under such conditions as the Administrator shall specify to the owner or operator based on representative performance of the facility.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-17 of 29
At least three valid test runs must be conducted before and at least three after the physical or operational change. All operating parameters which may affect emissions must be held constant to the maximum feasible degree for all test runs.(c) The addition of an affected facility to a stationary source as an expansion to that source or as a replacement for an existing facility shall not by itself bring within the applicability of this part any other facility within that source.(d) [Reserved](e) The following shall not, by themselves, be considered modifications under this part: (1) Maintenance, repair, and replacement which the Administrator determines to be routine for a source category, subject to the provisions of paragraph (c) of this section and &sect;60.15.(2) An increase in production rate of an existing facility, if that increase can be accomplished without a capital expenditure on that facility.(3) An increase in the hours of operation.
 
APPENDIX NSPS SUBPART A General Conditions (1) Emission factors as specified in the latest issue of "Compilation of Air Pollutant Emission Factors," EPA Publication No. AP-42, or other emission factors determined by the Administrator to be superior to AP-42 emission factors, in cases where utilization of emission factors demonstrates that the emission level resulting from the physical or operational change will either clearly increase or clearly not increase.
(2) Material balances, continuous monitor data, or manual emission tests in cases where utilization of emission factors as referenced in paragraph (b)(1) of this section does not demonstrate to the Administrator's satisfaction whether the emission level resulting from the physical or operational change will either clearly increase or clearly not increase, or where an owner or operator demonstrates to the Administrator's satisfaction that there are reasonable grounds to dispute the result obtained by the Administrator utilizing emission factors as referenced in paragraph (b)(1) of this section. When the emission rate is based on results from manual emission tests or continuous monitoring systems, the procedures specified in appendix C of this part shall be used to determine whether an increase in emission rate has occurred. Tests shall be conducted under such conditions as the Administrator shall specify to the owner or operator based on representative performance of the facility. At least three valid test runs must be conducted before and at least three after the physical or operational change. All operating parameters which may affect emissions must be held constant to the maximum feasible degree for all test runs.
(c) The addition of an affected facility to a stationary source as an expansion to that source or as a replacement for an existing facility shall not by itself bring within the applicability of this part any other facility within that source.
(d) [Reserved]
(e) The following shall not, by themselves, be considered modifications under this part:
(1) Maintenance, repair, and replacement which the Administrator determines to be routine for a source category, subject to the provisions of paragraph (c) of this section and &sect;60.15.
(2) An increase in production rate of an existing facility, if that increase can be accomplished without a capital expenditure on that facility.
(3) An increase in the hours of operation.
(4) Use of an alternative fuel or raw material if, prior to the date any standard under this part becomes applicable to that source type, as provided by &sect;60.1, the existing facility was designed to accommodate that alternative use. A facility shall be considered to be designed to accommodate an alternative fuel or raw material if that use could be accomplished under the facility's construction specifications as amended prior to the change. Conversion to coal required for energy considerations, as specified in section 111(a)(8) of the Act, shall not be considered a modification.
(4) Use of an alternative fuel or raw material if, prior to the date any standard under this part becomes applicable to that source type, as provided by &sect;60.1, the existing facility was designed to accommodate that alternative use. A facility shall be considered to be designed to accommodate an alternative fuel or raw material if that use could be accomplished under the facility's construction specifications as amended prior to the change. Conversion to coal required for energy considerations, as specified in section 111(a)(8) of the Act, shall not be considered a modification.
(5) The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial.
(5) The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial.
(6) The relocation or change in ownership of an existing facility.(f) Special provisions set forth under an applicable subpart of this part shall supersede any conflicting provisions of this section.(g) Within 180 days of the completion of any physical or operational change subject to the control measures specified in paragraph (a) of this section, compliance with all applicable standards must be achieved.(h) No physical change, or change in the method of operation, at an existing electric utility steam generating unit shall be treated as a modification for the purposes of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the 5 years prior to the change.(i) Repowering projects that are awarded funding from the Department of Energy as permanent clean coal technology demonstration projects (or similar projects funded by EPA) are exempt from the requirements of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the five years prior to the change.(j)(1) Repowering projects that qualify for an extension under section 409(b) of the Clean Air Act are exempt from the requirements of this section, provided that such change does not increase the actual hourly emissions of any Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-18 of 29 APPENDIX NSPS SUBPART A General Conditions pollutant regulated under this section above the actual hourly emissions achievable at that unit during the 5 years prior to the change.(2) This exemption shall not apply to any new unit that: (i) Is designated as a replacement for an existing unit;(ii) Qualifies under section 409(b) of the Clean Air Act for an extension of an emission limitation compliance date under section 405 of the Clean Air Act; and (iii) Is located at a different site than the existing unit.(k) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project is exempt from the requirements of this section. A temporary clean coal control technology demonstration project, for the purposes of this section is a clean coal technology demonstration project that is operated for a period of 5 years or less, and which complies with the State implementation plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated.
(6) The relocation or change in ownership of an existing facility.
(1) The reactivation of a very clean coal-fired electric utility steam generating unit is exempt from the requirements of this section.[40 FR 58419, Dec. 16, 1975, as amended at 43 FR 34347, Aug. 3, 1978; 45 FR 5617, Jan. 23, 1980; 57 FR 32339, July 21, 1992; 65 FR 61750, Oct. 17, 2000]&sect; 60.15 Reconstruction.(a) An existing facility, upon reconstruction, becomes an affected facility, irrespective of any change in emission rate.(b) "Reconstruction" means the replacement of components of an existing facility to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part.(c) "Fixed capital cost" means the capital needed to provide all the depreciable components.(d) If an owner or operator of an existing facility proposes to replace components, and the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, he shall notify the Administrator of the proposed replacements.
(f) Special provisions set forth under an applicable subpart of this part shall supersede any conflicting provisions of this section.
The notice must be postmarked 60 days (or as soon as practicable) before construction of the replacements is commenced and must include the following information:
(g) Within 180 days of the completion of any physical or operational change subject to the control measures specified in paragraph (a) of this section, compliance with all applicable standards must be achieved.
(1) Name and address of the owner or operator.(2) The location of the existing facility.(3) A brief description of the existing facility and the components which are to be replaced.(4) A description of the existing air pollution control equipment and the proposed air pollution control equipment.
(h) No physical change, or change in the method of operation, at an existing electric utility steam generating unit shall be treated as a modification for the purposes of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the 5 years prior to the change.
(5) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new facility.(6) The estimated life of the existing facility after the replacements.
(i) Repowering projects that are awarded funding from the Department of Energy as permanent clean coal technology demonstration projects (or similar projects funded by EPA) are exempt from the requirements of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the five years prior to the change.
(7) A discussion of any economic or technical limitations the facility may have in complying with the applicable standards of performance after the proposed replacements.(e) The Administrator will determine, within 30 days of the receipt of the notice required by paragraph (d) of this section and any additional information he may reasonably require, whether the proposed replacement constitutes reconstruction.(f) The Administrator's determination under paragraph (e) shall be based on: (1) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new facility;(2) The estimated life of the facility after the replacements compared to the life of a comparable entirely new facility;(3) The extent to which the components being replaced cause or contribute to the emissions from the facility; and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-19 of 29 APPENDIX NSPS SUBPART A General Conditions (4) Any economic or technical limitations on compliance with applicable standards of performance which are inherent in the proposed replacements.(g) Individual subparts of this part may include specific provisions which refine and delimit the concept of reconstruction set forth in this section.[40 FR 58420, Dec. 16, 1975]&sect; 60.16 Priority list.A list ofprioritized major source categories may be found at the following EPA web site: http://ecfr.gjpoaccess.gov/cgi/tltext/text-idx?c=ecfr&rn-n=div6&view=text&node=40:6.0.1.1.1.1&idno=40
(j)
&sect; 60.17 Incorporations by reference.
(1) Repowering projects that qualify for an extension under section 409(b) of the Clean Air Act are exempt from the requirements of this section, provided that such change does not increase the actual hourly emissions of any Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page A-18 of 29
The materials listed below are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register on the date listed. These materials are incorporated as they exist on the date of the approval, and a notice of any change in these materials will be published in the Federal Register.
 
The materials are available for purchase at the corresponding address noted below, and all are available for inspection at the Library (C267-01), U.S. EPA, Research Triangle Park, NC or at the National Archives and Records Administration (NARA).For information on the availability of this material at NARA, call 202-741-6030, or go to: http://Www.archives.gov/federal register/code-ofjederal regulations/ibrlocations, html.(a) The following materials are available for purchase from at least one of the following addresses:
APPENDIX NSPS SUBPART A General Conditions pollutant regulated under this section above the actual hourly emissions achievable at that unit during the 5 years prior to the change.
American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106.(1) ASTM A99-76, 82 (Reapproved 1987), Standard Specification for Ferromanganese, incorporation by reference (IBR) approved for &sect;60.261.(2) ASTM A100-69, 74, 93, Standard Specification for Ferrosilicon, IBR approved for &sect;60.261.(3) ASTM A101-73, 93, Standard Specification for Ferrochromium, IBR approved for &sect;60.261.(4) ASTM A482-76, 93, Standard Specification for Ferrochromesilicon, IBR approved for &sect;60.261.(5) ASTM A483-64, 74 (Reapproved 1988), Standard Specification for Silicomanganese, IBR approved for &sect;60.261.(6) ASTM A495-76, 94, Standard Specification for Calcium-Silicon and Calcium Manganese-Silicon, IBR approved for &sect;60.261.(7) ASTM D86-78, 82, 90, 93, 95, 96, Distillation of Petroleum Products, IBR approved for &sect;&sect;60.562-2(d), 60.593(d), 60.593a(d), and 60.633(h).
(2) This exemption shall not apply to any new unit that:
(i) Is designated as a replacement for an existing unit; (ii) Qualifies under section 409(b) of the Clean Air Act for an extension of an emission limitation compliance date under section 405 of the Clean Air Act; and (iii) Is located at a different site than the existing unit.
(k) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project is exempt from the requirements of this section. A temporary clean coal control technology demonstrationproject, for the purposes of this section is a clean coal technology demonstration project that is operated for a period of 5 years or less, and which complies with the State implementation plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated.
(1) The reactivation of a very clean coal-fired electric utility steam generating unit is exempt from the requirements of this section.
[40 FR 58419, Dec. 16, 1975, as amended at 43 FR 34347, Aug. 3, 1978; 45 FR 5617, Jan. 23, 1980; 57 FR 32339, July 21, 1992; 65 FR 61750, Oct. 17, 2000]
&sect; 60.15 Reconstruction.
(a) An existing facility, upon reconstruction, becomes an affected facility, irrespective of any change in emission rate.
(b) "Reconstruction" means the replacement of components of an existing facility to such an extent that:
(1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part.
(c) "Fixed capital cost" means the capital needed to provide all the depreciable components.
(d) If an owner or operator of an existing facility proposes to replace components, and the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, he shall notify the Administrator of the proposed replacements. The notice must be postmarked 60 days (or as soon as practicable) before construction of the replacements is commenced and must include the following information:
(1) Name and address of the owner or operator.
(2) The location of the existing facility.
(3) A brief description of the existing facility and the components which are to be replaced.
(4) A description of the existing air pollution control equipment and the proposed air pollution control equipment.
(5) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new facility.
(6) The estimated life of the existing facility after the replacements.
(7) A discussion of any economic or technical limitations the facility may have in complying with the applicable standards of performance after the proposed replacements.
(e) The Administrator will determine, within 30 days of the receipt of the notice required by paragraph (d) of this section and any additional information he may reasonably require, whether the proposed replacement constitutes reconstruction.
(f) The Administrator's determination under paragraph (e) shall be based on:
(1) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new facility; (2) The estimated life of the facility after the replacements compared to the life of a comparable entirely new facility; (3) The extent to which the components being replaced cause or contribute to the emissions from the facility; and Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page A-19 of 29
 
APPENDIX NSPS SUBPART A General Conditions (4) Any economic or technical limitations on compliance with applicable standards of performance which are inherent in the proposed replacements.
(g) Individual subparts of this part may include specific provisions which refine and delimit the concept of reconstruction set forth in this section.
[40 FR 58420, Dec. 16, 1975]
&sect; 60.16 Priority list.
A list ofprioritizedmajor source categoriesmay be found at the following EPA web site:
http://ecfr.gjpoaccess.gov/cgi/tltext/text-idx?c=ecfr&rn-n=div6&view=text&node=40:6.0.1.1.1.1&idno=40
&sect; 60.17 Incorporationsby reference.
The materials listed below are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register on the date listed. These materials are incorporated as they exist on the date of the approval, and a notice of any change in these materials will be published in the Federal Register. The materials are available for purchase at the corresponding address noted below, and all are available for inspection at the Library (C267-01), U.S. EPA, Research Triangle Park, NC or at the National Archives and Records Administration (NARA).
For information on the availability of this material at NARA, call 202-741-6030, or go to:
http://Www.archives.gov/federal register/code-ofjederal regulations/ibrlocations,       html.
(a) The following materials are available for purchase from at least one of the following addresses: American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106.
(1) ASTM A99-76, 82 (Reapproved 1987), Standard Specification for Ferromanganese, incorporation by reference (IBR) approved for &sect;60.261.
(2) ASTM A100-69, 74, 93, Standard Specification for Ferrosilicon, IBR approved for &sect;60.261.
(3) ASTM A101-73, 93, Standard Specification for Ferrochromium, IBR approved for &sect;60.261.
(4) ASTM A482-76, 93, Standard Specification for Ferrochromesilicon, IBR approved for &sect;60.261.
(5) ASTM A483-64, 74 (Reapproved 1988), Standard Specification for Silicomanganese, IBR approved for &sect;60.261.
(6) ASTM A495-76, 94, Standard Specification for Calcium-Silicon and Calcium Manganese-Silicon, IBR approved for &sect;60.261.
(7) ASTM D86-78, 82, 90, 93, 95, 96, Distillation of Petroleum Products, IBR approved for &sect;&sect;60.562-2(d), 60.593(d),
60.593a(d), and 60.633(h).
(8) ASTM D129-64, 78, 95, 00, Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for &sect;&sect;60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, 12.5.2.2.3.
(8) ASTM D129-64, 78, 95, 00, Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for &sect;&sect;60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, 12.5.2.2.3.
(9) ASTM D129-00 (Reapproved 2005), Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for &sect;60.4415(a)(1)(i).
(9) ASTM D129-00 (Reapproved 2005), Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for &sect;60.4415(a)(1)(i).
(10) ASTM D240-76, 92, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter, IBR approved for &sect;&sect;60.46(c), 60.296(b), and Appendix A: Method 19, Section 12.5.2.2.3.
(10) ASTM D240-76, 92, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter, IBR approved for &sect;&sect;60.46(c), 60.296(b), and Appendix A: Method 19, Section 12.5.2.2.3.
(11) ASTM D270-65, 75, Standard Method of Sampling Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.1.
(11) ASTM D270-65, 75, Standard Method of Sampling Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.1.
(12) ASTM D323-82, 94, Test Method for Vapor Pressure of Petroleum Products (Reid Method), IBR approved for&sect;&sect;60.111(1), 60.11 la(g), 60.11 lb(g), and 60.116b(f)(2)(ii).
(12) ASTM D323-82, 94, Test Method for Vapor Pressure of Petroleum Products (Reid Method), IBR approved for
(13)ASTM D388-77, 90, 91, 95, 98a, 99 (Reapproved 2004)E' , Standard Specification for Classification of Coals by Rank, IBR approved for &sect;&sect;60.24(h)(8), 60.41 of subpart D of this part, 60.45(f)(4)(i), 60.45(f)(4)(ii), 60.45(f)(4)(vi), 60.41Da of subpart Da of this part, 60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, and 60.4102.(14)ASTM D388-77, 90, 91, 95, 98a, Standard Specification for Classification of Coals by Rank, IBR approved for&sect;&sect;60.251(b) and (c) of subpart Y of this part.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-20 of 29 APPENDIX NSPS SUBPART A General Conditions (15)ASTM D396-78, 89, 90, 92, 96, 98, Standard Specification for Fuel Oils, IBR approved for &sect;&sect;60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, 60.11 l(b) of subpart K of this part, and 60.111 a(b) of subpart Ka of this part.(16)ASTM D975-78, 96, 98a, Standard Specification for Diesel Fuel Oils, IBR approved for &sect;&sect;60.11 l(b) of subpart K of this part and 60.111 a(b) of subpart Ka of this part.(17) ASTM D1072-80, 90 (Reapproved 1994), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for&sect;60.335(b)(10)(ii).
          &sect;&sect;60.111(1), 60.11 la(g), 60.11 lb(g), and 60.116b(f)(2)(ii).
(18) ASTM D1072-90 (Reapproved 1999), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for&sect;60.4415(a)(1)(ii).
(13)ASTM D388-77, 90, 91, 95, 98a, 99 (Reapproved 2004)E' , Standard Specification for Classification of Coals by Rank, IBR approved for &sect;&sect;60.24(h)(8), 60.41 of subpart D of this part, 60.45(f)(4)(i), 60.45(f)(4)(ii), 60.45(f)(4)(vi),
60.41Da of subpart Da of this part, 60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, and 60.4102.
(14)ASTM D388-77, 90, 91, 95, 98a, Standard Specification for Classification of Coals by Rank, IBR approved for
          &sect;&sect;60.251(b) and (c) of subpart Y of this part.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page A-20 of 29
 
APPENDIX NSPS SUBPART A General Conditions (15)ASTM D396-78, 89, 90, 92, 96, 98, Standard Specification for Fuel Oils, IBR approved for &sect;&sect;60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, 60.11 l(b) of subpart K of this part, and 60.111 a(b) of subpart Ka of this part.
(16)ASTM D975-78, 96, 98a, Standard Specification for Diesel Fuel Oils, IBR approved for &sect;&sect;60.11 l(b) of subpart K of this part and 60.111 a(b) of subpart Ka of this part.
(17) ASTM D1072-80, 90 (Reapproved 1994), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for
        &sect;60.335(b)(10)(ii).
(18) ASTM D1072-90 (Reapproved 1999), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for
        &sect;60.4415(a)(1)(ii).
(19) ASTM D1137-53, 75, Standard Method for Analysis of Natural Gases and Related Types of Gaseous Mixtures by the Mass Spectrometer, IBR approved for &sect;60.45(O(5)(i).
(19) ASTM D1137-53, 75, Standard Method for Analysis of Natural Gases and Related Types of Gaseous Mixtures by the Mass Spectrometer, IBR approved for &sect;60.45(O(5)(i).
(20) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 5, Section 7.1.3; Method 5E, Section 7.2.1; Method 5F, Section 7.2.1; Method 6, Section 7.1.1; Method 7, Section 7.1.1;Method 7C, Section 7.1.1; Method 7D, Section 7.1.1; Method 10A, Section 7.1.1; Method 11, Section 7.1.3; Method 12, Section 7.1.3; Method 13A, Section 7.1.2; Method 26, Section 7.1.2; Method 26A, Section 7.1.2; and Method 29, Section 7.2.2.(21)ASTM D1266-87, 91, 98, Standard Test Method for Sulfur in Petroleum Products (Lamp Method), IBR approved for &sect;&sect;60.1060)(2) and 60.335(b)(10)(i).
(20) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 5, Section 7.1.3; Method 5E, Section 7.2.1; Method 5F, Section 7.2.1; Method 6, Section 7.1.1; Method 7, Section 7.1.1; Method 7C, Section 7.1.1; Method 7D, Section 7.1.1; Method 10A, Section 7.1.1; Method 11, Section 7.1.3; Method 12, Section 7.1.3; Method 13A, Section 7.1.2; Method 26, Section 7.1.2; Method 26A, Section 7.1.2; and Method 29, Section 7.2.2.
(22) ASTM D1266-98 (Reapproved 2003)el, Standard Test Method for Sulfur in Petroleum Products (Lamp Method), IBR approved for &sect;60.4415(a)(1)(i).
(21)ASTM D1266-87, 91, 98, Standard Test Method for Sulfur in Petroleum Products (Lamp Method), IBR approved for &sect;&sect;60.1060)(2) and 60.335(b)(10)(i).
(23)ASTM D1475-60 (Reapproved 1980), 90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for &sect;60.435(d)(1), Appendix A: Method 24, Section 6.1; and Method 24A, Sections 6.5 and 7.1.(24)ASTM D1552-83, 95, 01, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method), IBR approved for &sect;&sect;60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, Section 12.5.2.2.3.
(22) ASTM D1266-98 (Reapproved 2003)el, Standard Test Method for Sulfur in Petroleum Products (Lamp Method),
IBR approved for &sect;60.4415(a)(1)(i).
(23)ASTM D1475-60 (Reapproved 1980), 90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for &sect;60.435(d)(1), Appendix A: Method 24, Section 6.1; and Method 24A, Sections 6.5 and 7.1.
(24)ASTM D1552-83, 95, 01, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method),
IBR approved for &sect;&sect;60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, Section 12.5.2.2.3.
(25)ASTM D1552-03, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method), IBR approved for &sect;60.4415(a)(1)(i).
(25)ASTM D1552-03, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method), IBR approved for &sect;60.4415(a)(1)(i).
(26)ASTM D1826-77, 94, Standard Test Method for Calorific Value of Gases in Natural Gas Range by Continuous Recording Calorimeter, IBR approved for &sect;&sect;60.45(f)(5)(ii), 60.46(c)(2), 60.296(b)(3), and Appendix A: Method 19, Section 12.3.2.4.(27)ASTM D1835-87, 91, 97, 03a, Standard Specification for Liquefied Petroleum (LP) Gases, IBR approved for&sect;&sect;60.4lDa of subpart Da of this part, 60.41b of subpart Db of this part, and 60.41c of subpart Dc of this part.(28)ASTM D1945-64, 76, 91, 96, Standard Method for Analysis of Natural Gas by Gas Chromatography, IBR approved for &sect;60.45(f)(5)(i).
(26)ASTM D1826-77, 94, Standard Test Method for Calorific Value of Gases in Natural Gas Range by Continuous Recording Calorimeter, IBR approved for &sect;&sect;60.45(f)(5)(ii), 60.46(c)(2), 60.296(b)(3), and Appendix A: Method 19, Section 12.3.2.4.
(29) ASTM D1946-77, 90 (Reapproved 1994), Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for &sect;&sect;60.18(f)(3), 60.45(f)(5)(i), 60.564(f)(1), 60.614(e)(2)(ii), 60.614(e)(4), 60.664(e)(2)(ii), 60.664(e)(4), 60.704(d)(2)(ii), and 60.704(d)(4).
(27)ASTM D1835-87, 91, 97, 03a, Standard Specification for Liquefied Petroleum (LP) Gases, IBR approved for
(30) ASTM D2013-72, 86, Standard Method of Preparing Coal Samples for Analysis, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
        &sect;&sect;60.4lDa of subpart Da of this part, 60.41b of subpart Db of this part, and 60.41c of subpart Dc of this part.
(28)ASTM D1945-64, 76, 91, 96, Standard Method for Analysis of Natural Gas by Gas Chromatography, IBR approved for &sect;60.45(f)(5)(i).
(29) ASTM D1946-77, 90 (Reapproved 1994), Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for &sect;&sect;60.18(f)(3), 60.45(f)(5)(i), 60.564(f)(1), 60.614(e)(2)(ii), 60.614(e)(4), 60.664(e)(2)(ii),
60.664(e)(4), 60.704(d)(2)(ii), and 60.704(d)(4).
(30) ASTM D2013-72, 86, Standard Method of Preparing Coal Samples for Analysis, IBR approved for Appendix A:
Method 19, Section 12.5.2.1.3.
(31)ASTM D2015-77 (Reapproved 1978), 96, Standard Test Method for Gross Calorific Value of Solid Fuel by the Adiabatic Bomb Calorimeter, IBR approved for &sect;60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3.
(31)ASTM D2015-77 (Reapproved 1978), 96, Standard Test Method for Gross Calorific Value of Solid Fuel by the Adiabatic Bomb Calorimeter, IBR approved for &sect;60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3.
(32) ASTM D2016-74, 83, Standard Test Methods for Moisture Content of Wood, IBR approved for Appendix A: Method 28, Section 16.1.1.(33)ASTM D2234-76, 96, 97b, 98, Standard Methods for Collection of a Gross Sample of Coal, IBR approved for Appendix A: Method 19, Section 12.5.2.1.1.
(32) ASTM D2016-74, 83, Standard Test Methods for Moisture Content of Wood, IBR approved for Appendix A:
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-21 of 29 APPENDIX NSPS SUBPART A General Conditions (34) ASTM D2369-81, 87, 90, 92, 93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for Appendix A: Method 24, Section 6.2.(35)ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for &sect;&sect;60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3), 60.614(e)(4), 60.664(e)(4), and 60.704(d)(4).
Method 28, Section 16.1.1.
(33)ASTM D2234-76, 96, 97b, 98, Standard Methods for Collection of a Gross Sample of Coal, IBR approved for Appendix A: Method 19, Section 12.5.2.1.1.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page A-21 of 29
 
APPENDIX NSPS SUBPART A General Conditions (34) ASTM D2369-81, 87, 90, 92, 93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for Appendix A: Method 24, Section 6.2.
(35)ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method),
IBR approved for &sect;&sect;60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3), 60.614(e)(4), 60.664(e)(4), and 60.704(d)(4).
(36)ASTM D2504-67, 77, 88 (Reapproved 1993), Noncondensable Gases in C3 and Lighter Hydrocarbon Products by Gas Chromatography, IBR approved for &sect;&sect;60.485(g)(5) and 60.485a(g)(5).
(36)ASTM D2504-67, 77, 88 (Reapproved 1993), Noncondensable Gases in C3 and Lighter Hydrocarbon Products by Gas Chromatography, IBR approved for &sect;&sect;60.485(g)(5) and 60.485a(g)(5).
(37) ASTM D2584-68 (Reapproved 1985), 94, Standard Test Method for Ignition Loss of Cured Reinforced Resins, IBR approved for &sect;60.685(c)(3)(i).
(37) ASTM D2584-68 (Reapproved 1985), 94, Standard Test Method for Ignition Loss of Cured Reinforced Resins, IBR approved for &sect;60.685(c)(3)(i).
Line 970: Line 1,868:
(39) ASTM D2622-87, 94, 98, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;&sect;60.1060)(2) and 60.335(b)(10)(i).
(39) ASTM D2622-87, 94, 98, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;&sect;60.1060)(2) and 60.335(b)(10)(i).
(40) ASTM D2622-05, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.4415(a)(1)(i).
(40) ASTM D2622-05, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.4415(a)(1)(i).
(41)ASTM D2879-83, 96, 97, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for &sect;&sect;60.11 lb(f)(3), 60.116b(e)(3)(ii), 60.116b(f)(2)(i), 60.485(e)(1), and 60.485a(e)(1).
(41)ASTM D2879-83, 96, 97, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for &sect;&sect;60.11 lb(f)(3), 60.116b(e)(3)(ii), 60.116b(f)(2)(i),
(42) ASTM D2880-78, 96, Standard Specification for Gas Turbine Fuel Oils, IBR approved for &sect;&sect;60.11 l(b), 60.11 la(b), and 60.335(d).
60.485(e)(1), and 60.485a(e)(1).
(42) ASTM D2880-78, 96, Standard Specification for Gas Turbine Fuel Oils, IBR approved for &sect;&sect;60.11 l(b), 60.11 la(b),
and 60.335(d).
(43)ASTM D2908-74, 91, Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, IBR approved for &sect;60.564(j).
(43)ASTM D2908-74, 91, Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, IBR approved for &sect;60.564(j).
(44)ASTM D2986-71, 78, 95a, Standard Method for Evaluation of Air, Assay Media by the Monodisperse DOP (Dioctyl Phthalate)
(44)ASTM D2986-71, 78, 95a, Standard Method for Evaluation of Air, Assay Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke Test, IBR approved for Appendix A: Method 5, Section 7.1.1; Method 12, Section 7.1.1; and Method 13A, Section 7.1.1.2.
Smoke Test, IBR approved for Appendix A: Method 5, Section 7.1.1; Method 12, Section 7.1.1;and Method 13A, Section 7.1.1.2.(45)ASTM D3173-73, 87, Standard Test Method for Moisture in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(45)ASTM D3173-73, 87, Standard Test Method for Moisture in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(46) ASTM D3176-74, 89, Standard Method for Ultimate Analysis of Coal and Coke, IBR approved for &sect;60.45(f)(5)(i) and Appendix A: Method 19, Section 12.3.2.3.(47) ASTM D3177-75, 89, Standard Test Method for Total Sulfur in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(46) ASTM D3176-74, 89, Standard Method for Ultimate Analysis of Coal and Coke, IBR approved for &sect;60.45(f)(5)(i) and Appendix A: Method 19, Section 12.3.2.3.
(47) ASTM D3177-75, 89, Standard Test Method for Total Sulfur in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(48) ASTM D3178-73 (Reapproved 1979), 89, Standard Test Methods for Carbon and Hydrogen in the Analysis Sample of Coal and Coke, IBR approved for &sect;60.45(f)(5)(i).
(48) ASTM D3178-73 (Reapproved 1979), 89, Standard Test Methods for Carbon and Hydrogen in the Analysis Sample of Coal and Coke, IBR approved for &sect;60.45(f)(5)(i).
(49)ASTM D3246-81, 92, 96, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for &sect;60.335(b)(10)(ii).
(49)ASTM D3246-81, 92, 96, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for &sect;60.335(b)(10)(ii).
(50)ASTM D3246-05, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for &sect;60.4415(a)(1)(ii).
(50)ASTM D3246-05, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for &sect;60.4415(a)(1)(ii).
(51) ASTM D3270-73T, 80, 91, 95, Standard Test Methods for Analysis for Fluoride Content of the Atmosphere and Plant Tissues (Semiautomated Method), IBR approved for Appendix A: Method 13A, Section 16.1.(52)ASTM D3286-85, 96, Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(51) ASTM D3270-73T, 80, 91, 95, Standard Test Methods for Analysis for Fluoride Content of the Atmosphere and Plant Tissues (Semiautomated Method), IBR approved for Appendix A: Method 13A, Section 16.1.
(52)ASTM D3286-85, 96, Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3.
(53) ASTM D3370-76, 95a, Standard Practices for Sampling Water, IBR approved for &sect;60.564(j).
(53) ASTM D3370-76, 95a, Standard Practices for Sampling Water, IBR approved for &sect;60.564(j).
(54) ASTM D3792-79, 91, Standard Test Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.3.(55) ASTM D4017-81, 90, 96a, Siandard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for Appendix A: Method 24, Section 6.4.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-22 of 29 APPENDIX NSPS SUBPART A General Conditions (56)ASTM D4057-81, 95, Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.3.
(54) ASTM D3792-79, 91, Standard Test Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.3.
(55) ASTM D4017-81, 90, 96a, Siandard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for Appendix A: Method 24, Section 6.4.
Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                             Title V Permit Renewal Page A-22 of 29
 
APPENDIX NSPS SUBPART A General Conditions (56)ASTM D4057-81, 95, Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.3.
(57) ASTM D4057-95 (Reapproved 2000), Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for &sect;60.4415(a)(1).
(57) ASTM D4057-95 (Reapproved 2000), Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for &sect;60.4415(a)(1).
(58)ASTM D4084-82, 94, Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR approved for &sect;60.334(h)(1).
(58)ASTM D4084-82, 94, Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR approved for &sect;60.334(h)(1).
Line 990: Line 1,896:
(63)ASTM D4294-02, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.335(b)(10)(i).
(63)ASTM D4294-02, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.335(b)(10)(i).
(64) ASTM D4294-03, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.4415(a)(1)(i).
(64) ASTM D4294-03, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for &sect;60.4415(a)(1)(i).
(65) ASTM D4442-84, 92, Standard Test Methods for Direct Moisture Content Measurement in Wood and Wood-base Materials, IBR approved for Appendix A: Method 28, Section 16.1.1.(66) ASTM D4444-92, Standard Test Methods for Use and Calibration of Hand-Held Moisture Meters, IBR approved for Appendix A: Method 28, Section 16.1.1.(67) ASTM D4457-85 (Reapproved 1991), Test Method for Determination of Dichloromethane and 1, 1, 1-Trichloroethane in Paints and Coatings by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.5.(68)ASTM D4468-85 (Reapproved 2000), Standard Test Method for Total Sulfur in Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry, IBR approved for &sect;&sect;60.335(b)(10)(ii) and 60.4415(a)(1)(ii).
(65) ASTM D4442-84, 92, Standard Test Methods for Direct Moisture Content Measurement in Wood and Wood-base Materials, IBR approved for Appendix A: Method 28, Section 16.1.1.
(66) ASTM D4444-92, Standard Test Methods for Use and Calibration of Hand-Held Moisture Meters, IBR approved for Appendix A: Method 28, Section 16.1.1.
(67) ASTM D4457-85 (Reapproved 1991), Test Method for Determination of Dichloromethane and 1, 1, 1-Trichloroethane in Paints and Coatings by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.5.
(68)ASTM D4468-85 (Reapproved 2000), Standard Test Method for Total Sulfur in Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry, IBR approved for &sect;&sect;60.335(b)(10)(ii) and 60.4415(a)(1)(ii).
(69) ASTM D4629-02, Standard Test Method for Trace Nitrogen in Liquid Petroleum Hydrocarbons by Syringe/Inlet Oxidative Combustion and Chemiluminescence Detection, IBR approved for &sect;&sect;60.49b(e) and 60.335(b)(9)(i).
(69) ASTM D4629-02, Standard Test Method for Trace Nitrogen in Liquid Petroleum Hydrocarbons by Syringe/Inlet Oxidative Combustion and Chemiluminescence Detection, IBR approved for &sect;&sect;60.49b(e) and 60.335(b)(9)(i).
(70)ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for &sect;&sect;60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3), 60.614(d)(4), 60.664(e)(4), and 60.704(d)(4).
(70)ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for &sect;&sect;60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3),
60.614(d)(4), 60.664(e)(4), and 60.704(d)(4).
(71)ASTM D4810-88 (Reapproved 1999), Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length of Stain Detector Tubes, IBR approved for &sect;&sect;60.4360 and 60.4415(a)(1)(ii).
(71)ASTM D4810-88 (Reapproved 1999), Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length of Stain Detector Tubes, IBR approved for &sect;&sect;60.4360 and 60.4415(a)(1)(ii).
(72)ASTM D5287-97 (Reapproved 2002), Standard Practice for Automatic Sampling of Gaseous Fuels, IBR approved for &sect;60.4415(a)(1).
(72)ASTM D5287-97 (Reapproved 2002), Standard Practice for Automatic Sampling of Gaseous Fuels, IBR approved for &sect;60.4415(a)(1).
(73) ASTM D5403-93, Standard Test Methods for Volatile Content of Radiation Curable Materials, IBR approved for Appendix A: Method 24, Section 6.6.(74) ASTM D5453-00, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for &sect;60.335(b)(10)(i).
(73) ASTM D5403-93, Standard Test Methods for Volatile Content of Radiation Curable Materials, IBR approved for Appendix A: Method 24, Section 6.6.
(74) ASTM D5453-00, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for &sect;60.335(b)(10)(i).
(75) ASTM D5453-05, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for &sect;60.4415(a)(1)(i).
(75) ASTM D5453-05, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for &sect;60.4415(a)(1)(i).
(76) ASTM D5504-01, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Chemiluminescence, IBR approved for &sect;&sect;60.334(h)(1) and 60.4360.(77)ASTM D5762-02, Standard Test Method for Nitrogen in Petroleum and Petroleum Products by Boat-Inlet Chemiluminescence, IBR approved for &sect;60.335(b)(9)(i).
(76) ASTM D5504-01, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Chemiluminescence, IBR approved for &sect;&sect;60.334(h)(1) and 60.4360.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-23 of 29 APPENDIX NSPS SUBPART A General Conditions (78) ASTM D5865-98, Standard Test Method for Gross Calorific Value of Coal and Coke, IBR approved for&sect;60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3.
(77)ASTM D5762-02, Standard Test Method for Nitrogen in Petroleum and Petroleum Products by Boat-Inlet Chemiluminescence, IBR approved for &sect;60.335(b)(9)(i).
(79) ASTM D6216-98, Standard Practice for Opacity Monitor Manufacturers to Certify Conformance with Design and Performance Specifications, IBR approved for Appendix B, Performance Specification 1.(80)ASTM D6228-98, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for &sect;60.334(h)(1).
Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                                           Title V Permit Renewal Page A-23 of 29
(81) ASTM D6228-98 (Reapproved 2003), Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for &sect;&sect;60.4360 and 60.4415.(82) ASTM D6348-03, Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, IBR approved for table 7 of Subpart IIII of this part and table 2 of subpart JJJJ of this part.(83) ASTM D6366-99, Standard Test Method for Total Trace Nitrogen and Its Derivatives in Liquid Aromatic Hydrocarbons by Oxidative Combustion and Electrochemical Detection, IBR approved for &sect;60.335(b)(9)(i).
 
(84) ASTM D6420-99 (Reapproved 2004) Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for table 2 of subpart JJJJ of this part.(85) ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for &sect;60.335(a).
APPENDIX NSPS SUBPART A General Conditions (78) ASTM D5865-98, Standard Test Method for Gross Calorific Value of Coal and Coke, IBR approved for
(86)ASTM D6522-00 (Reapproved 2005), Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for table 2 of subpart JJJJ of this part.(87)ASTM D6667-01, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for &sect;60.335(b)(10)(ii).
        &sect;60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3.
(79) ASTM D6216-98, Standard Practice for Opacity Monitor Manufacturers to Certify Conformance with Design and Performance Specifications, IBR approved for Appendix B, Performance Specification 1.
(80)ASTM D6228-98, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for &sect;60.334(h)(1).
(81) ASTM D6228-98 (Reapproved 2003), Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for &sect;&sect;60.4360 and 60.4415.
(82) ASTM D6348-03, Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, IBR approved for table 7 of Subpart IIII of this part and table 2 of subpart JJJJ of this part.
(83) ASTM D6366-99, Standard Test Method for Total Trace Nitrogen and Its Derivatives in Liquid Aromatic Hydrocarbons by Oxidative Combustion and Electrochemical Detection, IBR approved for &sect;60.335(b)(9)(i).
(84) ASTM D6420-99 (Reapproved 2004) Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for table 2 of subpart JJJJ of this part.
(85) ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for &sect;60.335(a).
(86)ASTM D6522-00 (Reapproved 2005), Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for table 2 of subpart JJJJ of this part.
(87)ASTM D6667-01, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for &sect;60.335(b)(10)(ii).
(88) ASTM D6667-04, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for &sect;60.4415(a)(1)(ii).
(88) ASTM D6667-04, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for &sect;60.4415(a)(1)(ii).
(89)ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound and Tbtal Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method), IBR approved for Appendix B to part 60, Performance Specification 12A, Section 8.6.2.(90)ASTM E168-67, 77, 92, General Techniques of Infrared Quantitative Analysis, IBR approved for &sect;&sect;60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f).
(89)ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound and Tbtal Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method), IBR approved for Appendix B to part 60, Performance Specification 12A, Section 8.6.2.
(91) ASTM E169-63, 77, 93, General Techniques of Ultraviolet Quantitative Analysis, IBR approved for&sect;&sect;60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f).
(90)ASTM E168-67, 77, 92, General Techniques of Infrared Quantitative Analysis, IBR approved for &sect;&sect;60.485a(d)(1),
(92) ASTM E260-73, 91, 96, General Gas Chromatography Procedures, IBR approved for &sect;&sect;60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f).(b) The following material is available for purchase from the Association of Official Analytical Chemists, 1111 North 19th Street, Suite 210, Arlington, VA 22209.(1) AOAC Method 9, Official Methods of Analysis of the Association of Official Analytical Chemists, 11 th edition, 1970, pp. 11-12, IBR approved January 27, 1983 for &sect;&sect;60.204(b)(3), 60.214(b)(3), 60.224(b)(3), 60.234(b)(3).(c) The following material is available for purchase from the American Petroleum Institute, 1220 L Street NW., Washington, DC 20005.(1) API Publication 2517, Evaporation Loss from External Floating Roof Tanks, Second Edition, February 1980, IBR approved January 27, 1983, for &sect;&sect;60.111(i), 60.11 la(f), 60.11 la(f)(1) and 60.116b(e)(2)(i).(d) The following material is available for purchase from the Technical Association of the Pulp and Paper Industry (TAPPI), Dunwoody Park, Atlanta, GA 30341.(1) TAPPI Method T624 os-68, IBR approved January 27, 1983 for &sect;60.285(d)(3).
60.593(b)(2), 60.593a(b)(2), and 60.632(f).
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-24 of 29 APPENDIX NSPS SUBPART A General Conditions (e) The following material is available for purchase from the Water Pollution Control Federation (WPCF), 2626 Pennsylvania Avenue NW., Washington, DC 20037.(1) Method 209A, Total Residue Dried at 103-105 'C, in Standard Methods for the Examination of Water and Wastewater, 15th Edition, 1980, IBR approved February 25, 1985 for &sect;60.683(b).(f) The following material is available for purchase from the following address: Underwriter's Laboratories, Inc. (UL), 333 Pfingsten Road, Northbrook, IL 60062.(1) UL 103, Sixth Edition revised as of September 3, 1986, Standard for Chimneys, Factory-built, Residential Type and Building Heating Appliance.(g) The following material is available for purchase from the following address: West Coast Lumber Inspection Bureau, 6980 SW. Barnes Road, Portland, OR 97223.(1) West Coast Lumber Standard Grading Rules No. 16, pages 5-21 and 90 and 91, September 3, 1970, revised 1984.(h) The following material is available for purchase from the American Society of Mechanical Engineers (ASME), Three Park Avenue, New York, NY 10016-5990.
(91) ASTM E169-63, 77, 93, General Techniques of Ultraviolet Quantitative Analysis, IBR approved for
        &sect;&sect;60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f).
(92) ASTM E260-73, 91, 96, General Gas Chromatography Procedures, IBR approved for &sect;&sect;60.485a(d)(1),
60.593(b)(2), 60.593a(b)(2), and 60.632(f).
(b) The following material is available for purchase from the Association of Official Analytical Chemists, 1111 North 19th Street, Suite 210, Arlington, VA 22209.
(1) AOAC Method 9, Official Methods of Analysis of the Association of Official Analytical Chemists, 11th edition, 1970, pp. 11-12, IBR approved January 27, 1983 for &sect;&sect;60.204(b)(3), 60.214(b)(3), 60.224(b)(3), 60.234(b)(3).
(c) The following material is available for purchase from the American Petroleum Institute, 1220 L Street NW.,
Washington, DC 20005.
(1) API Publication 2517, Evaporation Loss from External Floating Roof Tanks, Second Edition, February 1980, IBR approved January 27, 1983, for &sect;&sect;60.111(i), 60.11 la(f), 60.11 la(f)(1) and 60.116b(e)(2)(i).
(d) The following material is available for purchase from the Technical Association of the Pulp and Paper Industry (TAPPI),
Dunwoody Park, Atlanta, GA 30341.
(1) TAPPI Method T624 os-68, IBR approved January 27, 1983 for &sect;60.285(d)(3).
Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                             Title V Permit Renewal Page A-24 of 29
 
APPENDIX NSPS SUBPART A General Conditions (e) The following material is available for purchase from the Water Pollution Control Federation (WPCF), 2626 Pennsylvania Avenue NW., Washington, DC 20037.
(1) Method 209A, Total Residue Dried at 103-105 'C, in Standard Methods for the Examination of Water and Wastewater, 15th Edition, 1980, IBR approved February 25, 1985 for &sect;60.683(b).
(f) The following material is available for purchase from the following address: Underwriter's Laboratories, Inc. (UL), 333 Pfingsten Road, Northbrook, IL 60062.
(1) UL 103, Sixth Edition revised as of September 3, 1986, Standard for Chimneys, Factory-built, Residential Type and Building Heating Appliance.
(g) The following material is available for purchase from the following address: West Coast Lumber Inspection Bureau, 6980 SW. Barnes Road, Portland, OR 97223.
(1) West Coast Lumber Standard Grading Rules No. 16, pages 5-21 and 90 and 91, September 3, 1970, revised 1984.
(h) The following material is available for purchase from the American Society of Mechanical Engineers (ASME), Three Park Avenue, New York, NY 10016-5990.
(1) ASME QRO-1-1994, Standard for the Qualification and Certification of Resource Recovery Facility Operators, IBR approved for &sect;&sect;60.56a, 60.54b(a), 60.54b(b), 60.1185(a), 60.1185(c)(2), 60.1675(a), and 60.1675(c)(2).
(1) ASME QRO-1-1994, Standard for the Qualification and Certification of Resource Recovery Facility Operators, IBR approved for &sect;&sect;60.56a, 60.54b(a), 60.54b(b), 60.1185(a), 60.1185(c)(2), 60.1675(a), and 60.1675(c)(2).
(2) ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test Codes: Test Code for Steam Generating Units (with 1968 and 1969 Addenda), IBR approved for &sect;&sect;60.46b of subpart Db of this part, 60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)(3) and 60.1810(a)(3).
(2) ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test Codes: Test Code for Steam Generating Units (with 1968 and 1969 Addenda), IBR approved for &sect;&sect;60.46b of subpart Db of this part, 60.58a(h)(6)(ii), 60.58b(i)(6)(ii),
(3) ASME Interim Supplement 19.5 on Instruments.and Apparatus:
60.1320(a)(3) and 60.1810(a)(3).
Application, Part II of Fluid Meters, 6th Edition (1971), EBR approved for &sect;&sect;60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)4), and 60.1810(a)(4).
(3) ASME Interim Supplement 19.5 on Instruments.and Apparatus: Application, Part II of Fluid Meters, 6th Edition (1971), EBR approved for &sect;&sect;60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)4), and 60.1810(a)(4).
(4) ANSI/ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus], IBR approved for Tables 1 and 3 of subpart EEEE, Tables 2 and 4 of subpart FFFF, Table 2 of subpart JJJJ, and&sect;&sect;60.4415(a)(2) and 60.4415(a)(3) of subpart KKKK of this part.(i) Test Methods for Evaluating Solid Waste, Physical/Chemical Methods," EPA Publication SW-846 Third Edition (November 1986), as amended by Updates I (July 1992), II (September 1994), IIA (August, 1993), JIB (January 1995), and III (December 1996). This document may be obtained from the U.S. EPA, Office of Solid Waste and Emergency Response, Waste Characterization Branch, Washington, DC 20460, and is incorporated by reference for appendix A to part 60, Method 29, Sections 7.5.34; 9.2.1; 9.2.3; 10.2; 10.3; 11.1.1; 11.1.3; 13.2.1; 13.2.2; 13.3.1; and Table 29-3.(j) "Standard Methods for the Examination of Water and Wastewater," 16th edition, 1985. Method 303F: "Determination of Mercury by the Cold Vapor Technique." This document may be obtained from the American Public Health Association, 1015 18th Street, NW., Washington, DC 20036, and is incorporated by reference for appendix A to part 60, Method 29, Sections 9.2.3; 10.3; and 11.1.3.(k) This material is available for purchase from the American Hospital Association (AHA) Service, Inc., Post Office Box 92683, Chicago, Illinois 60675-2683.
(4) ANSI/ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus], IBR approved for Tables 1 and 3 of subpart EEEE, Tables 2 and 4 of subpart FFFF, Table 2 of subpart JJJJ, and
You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-124), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC.(1) An Ounce of Prevention:
        &sect;&sect;60.4415(a)(2) and 60.4415(a)(3) of subpart KKKK of this part.
Waste Reduction Strategies for Health Care Facilities.
(i) Test Methods for Evaluating Solid Waste, Physical/Chemical Methods," EPA Publication SW-846 Third Edition (November 1986), as amended by Updates I (July 1992), II (September 1994), IIA (August, 1993), JIB (January 1995),
American Society for Health Care Environmental Services of the American Hospital Association.
and III (December 1996). This document may be obtained from the U.S. EPA, Office of Solid Waste and Emergency Response, Waste Characterization Branch, Washington, DC 20460, and is incorporated by reference for appendix A to part 60, Method 29, Sections 7.5.34; 9.2.1; 9.2.3; 10.2; 10.3; 11.1.1; 11.1.3; 13.2.1; 13.2.2; 13.3.1; and Table 29-3.
Chicago, Illinois.
(j) "Standard Methods for the Examination of Water and Wastewater," 16th edition, 1985. Method 303F: "Determination of Mercury by the Cold Vapor Technique." This document may be obtained from the American Public Health Association, 1015 18th Street, NW., Washington, DC 20036, and is incorporated by reference for appendix A to part 60, Method 29, Sections 9.2.3; 10.3; and 11.1.3.
1993. AHA Catalog No. 057007.ISBN 0-87258-673-5.
(k) This material is available for purchase from the American Hospital Association (AHA) Service, Inc., Post Office Box 92683, Chicago, Illinois 60675-2683. You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-124), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC.
IBR approved for &sect;60.35e and &sect;60.55c.(1) This material is available for purchase from the National Technical Information Services, 5285 Port Royal Road, Springfield, Virginia 22161. You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-125), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC.(1) OMB Bulletin No. 93-17: Revised Statistical Definitions for Metropolitan Areas. Office of Management and Budget, June 30, 1993. NTIS No. PB 93-192-664.
(1) An Ounce of Prevention: Waste Reduction Strategies for Health Care Facilities. American Society for Health Care Environmental Services of the American Hospital Association. Chicago, Illinois. 1993. AHA Catalog No. 057007.
IBR approved for &sect;60.31e.(m) This material is available for purchase from at least one of the following addresses:
ISBN 0-87258-673-5. IBR approved for &sect;60.35e and &sect;60.55c.
The Gas Processors Association, 6526 East 60th Street, Tulsa, OK, 74145; or Information Handling Services, 15 Inverness Way East, PO Box 1154, Englewood, CO 80150-1154.
(1) This material is available for purchase from the National Technical Information Services, 5285 Port Royal Road, Springfield, Virginia 22161. You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-125), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC.
You may inspect a copy at EPA's Air and Radiation Docket and Information Center, Room B 108, 1301 Constitution Ave., NW., Washington, DC 20460.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-25 of 29 APPENDIX NSPS SUBPART A General Conditions (1) Gas Processors Association Method 2377-86, Test for Hydrogen Sulfide and Carbon Dioxide in Natural Gas Using Length of Stain Tubes, IBR approved for &sect;&sect;60.334(h)(1), 60.4360, and 60.4415(a)(1)(ii).
(1) OMB Bulletin No. 93-17: Revised Statistical Definitions for Metropolitan Areas. Office of Management and Budget, June 30, 1993. NTIS No. PB 93-192-664. IBR approved for &sect;60.31e.
(2) [Reserved](n) This material is available for purchase from IHS Inc., 15 Inverness Way East, Englewood, CO 80112.(1) International Organization for Standards 8178-4: 1996(E), Reciprocating Internal Combustion Engines-Exhaust Emission Measurement-Part 4: Test Cycles for Different Engine Applications, IBR approved for &sect;60.4241(b).
(m) This material is available for purchase from at least one of the following addresses: The Gas Processors Association, 6526 East 60th Street, Tulsa, OK, 74145; or Information Handling Services, 15 Inverness Way East, PO Box 1154, Englewood, CO 80150-1154. You may inspect a copy at EPA's Air and Radiation Docket and Information Center, Room B 108, 1301 Constitution Ave., NW., Washington, DC 20460.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page A-25 of 29
 
APPENDIX NSPS SUBPART A General Conditions (1) Gas Processors Association Method 2377-86, Test for Hydrogen Sulfide and Carbon Dioxide in Natural Gas Using Length of Stain Tubes, IBR approved for &sect;&sect;60.334(h)(1), 60.4360, and 60.4415(a)(1)(ii).
(2) [Reserved]
(2) [Reserved]
[48 FR 3735, Jan. 27, 1983]Editorial Note: For Federal Register citations affecting
(n) This material is available for purchase from IHS Inc., 15 Inverness Way East, Englewood, CO 80112.
&sect;60.17, see the List of CFR Sections Affected,
(1) International Organization for Standards 8178-4: 1996(E), Reciprocating Internal Combustion Engines-Exhaust Emission Measurement-Part 4: Test Cycles for Different Engine Applications, IBR approved for &sect;60.4241(b).
(2) [Reserved]
[48 FR 3735, Jan. 27, 1983]
Editorial Note: For Federal Register citations affecting &sect;60.17, see the List of CFR Sections Affected, which appears in the Finding Aids section of the printed volume and on GPO Access.
&sect; 60.18 Generalcontrol device requirements.
(a) Introduction.This section contains requirements for control devices used to comply with applicable subparts of parts 60 and 61. The requirements are placed here for administrative convenience and only apply to facilities covered by subparts referring to this section.
(b) Flares.Paragraphs (c) through (f) apply to flares.
(c)
(1) Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f)
(3) For each digital opacity compliance system, the owner or operator shall maintain records and submit reports according to the requirements specified in the site-specific monitoring plan approved by the Administrator.
(3) For each digital opacity compliance system, the owner or operator shall maintain records and submit reports according to the requirements specified in the site-specific monitoring plan approved by the Administrator.
[60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5077, Jan. 28, 2009]&sect; 60.46 Test methods and procedures.(a) In conducting the performance tests required in &sect;60.8, and subsequent performance tests as requested by the EPA Administrator, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in &sect;60.8(b).
[60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5077, Jan. 28, 2009]
Acceptable alternative methods and procedures are given in paragraph (d) of this section.(b) The owner or operator shall determine compliance with the PM, SO 2 , and NOx standards in &sect;&sect;60.42, 60.43, and 60.44 as follows: (1) The emission rate (E) of PM, SO 2 , or NOx shall be computed for each run using the following equation: E = CF, 20.9 ( : (209 -%0,)Where: E = Emission rate of pollutant, ng/J (lb/million Btu);C = Concentration of pollutant, ng/dscm (lb/dscf);
&sect; 60.46 Test methods and procedures.
%02= O 2 concentration, percent dry basis; and Fd= Factor as determined from Method 19 of appendix A of this part.(2) Method 5 of appendix A of this part shall be used to determine the PM concentration (C) at affected facilities without wet flue-gas-desulfurization (FGD) systems and Method 5B of appendix A of this part shall be used to determine the PM concentration (C) after FGD systems.(i) The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder heating systems in the sampling train shall be set to provide an average gas temperature of 160+/-14 &deg;C (320+/-25 OF).(ii) The emission rate correction factor, integrated or grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration  
(a) In conducting the performance tests required in &sect;60.8, and subsequent performance tests as requested by the EPA Administrator, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in &sect;60.8(b). Acceptable alternative methods and procedures are given in paragraph (d) of this section.
(%02). The O 2 sample shall be obtained simultaneously with, and at the same traverse points as, the particulate sample. If the grab sampling procedure is used, the O 2 concentration for the run shall be the arithmetic mean of the sample O 2 concentrations at all traverse points.(iii) If the particulate run has more than 12 traverse points, the O 2 traverse points may be reduced to 12 provided that Method 1 of appendix A of this part is used to locate the 12 O 2 traverse points.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-10 of 12 APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (3) Method 9 of appendix A of this part and the procedures in &sect;60.11 shall be used to determine opacity.(4) Method 6 of appendix A of this part shall be used to determine the SO 2 concentration.(i) The sampling site shall be the same as that selected for the particulate sample. The sampling location in the duct shall be at the centroid of the cross section or at a point no closer to the walls than 1 m (3.28 ft). The sampling time and sample volume for each sample run shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two samples shall be taken during a 1-hour period, with each sample taken within a 30-minute interval.(ii) The emission rate correction factor, integrated sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration  
(b) The owner or operator shall determine compliance with the PM, SO 2, and NOx standards in &sect;&sect;60.42, 60.43, and 60.44 as follows:
(%02). The O 2 sample shall be taken simultaneously with, and at the same point as, the SO 2 sample. The SO 2 emission rate shall be computed for each pair of SO 2 and O 2 samples. The SO 2 emission rate (E) for each run shall be the arithmetic mean of the results of the two pairs of samples.(5) Method 7 of appendix A of this part shall be used to determine the NOx concentration.(i) The sampling site and location shall be the same as for the SO 2 sample. Each run shall consist of four grab samples, with each sample taken at about 15-minute intervals.(ii) For each NOx sample, the emission rate correction factor, grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration  
(1) The emission rate (E) of PM, SO 2 , or NOx shall be computed for each run using the following equation:
(%02). The sample shall be taken simultaneously with, and at the same point as, the NOx sample.(iii) The NOx emission rate shall be computed for each pair of NOx and O 2 samples. The NOx emission rate (E) for each run shall be the arithmetic mean of the results of the four pairs of samples.(c) When combinations of fossil fuels or fossil fuel and wood residue are fired, the owner or operator (in order to compute the prorated standard as shown in &sect;&sect;60.43(b) and 60.44(b))
E = CF,: ((20920.9-%0,)
shall determine the percentage (w, x, y, or z) of the total heat input derived from each type of fuel as follows: (1) The heat input rate of each fuel shall be determined by multiplying the gross calorific value of each fuel fired by the rate of each fuel burned.(2) ASTM Methods D2015, or D5865 (solid fuels), D240 (liquid fuels), or D1826 (gaseous fuels) (all of these methods are incorporated by reference, see &sect;60.17) shall be used to determine the gross calorific values of the fuels. The method used to determine the calorific value of wood residue must be approved by the Administrator.
Where:
(3) Suitable methods shall be used to determine the rate of each fuel burned during each test period, and a material balance over the steam generating system shall be used to confirm the rate.(d) The owner or operator may use the following as alternatives to the reference methods and procedures in this section or in other sections as specified:
E = Emission rate of pollutant, ng/J (lb/million Btu);
(1) The emission rate (E) of PM, SO 2 and NOx may be determined by using the F, factor, provided that the following procedure is used: (i) The emission rate (E) shall be computed using the following equation: E =CF&#xfd; 0%C0 2)Where: E = Emission rate of pollutant, ng/J (lb/MMBtu);
C = Concentration of pollutant, ng/dscm (lb/dscf);
%02= O 2concentration, percent dry basis; and Fd= Factor as determined from Method 19 of appendix A of this part.
(2) Method 5 of appendix A of this part shall be used to determine the PM concentration (C) at affected facilities without wet flue-gas-desulfurization (FGD) systems and Method 5B of appendix A of this part shall be used to determine the PM concentration (C) after FGD systems.
(i) The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder heating systems in the sampling train shall be set to provide an average gas temperature of 160+/-14 &deg;C (320+/-25 OF).
(ii) The emission rate correction factor, integrated or grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration (%02). The O 2sample shall be obtained simultaneously with, and at the same traverse points as, the particulate sample. If the grab sampling procedure is used, the O 2 concentration for the run shall be the arithmetic mean of the sample O 2 concentrations at all traverse points.
(iii) If the particulate run has more than 12 traverse points, the O 2traverse points may be reduced to 12 provided that Method 1 of appendix A of this part is used to locate the 12 O2traverse points.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page D-10 of 12
 
APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (3) Method 9 of appendix A of this part and the procedures in &sect;60.11 shall be used to determine opacity.
(4) Method 6 of appendix A of this part shall be used to determine the SO 2concentration.
(i) The sampling site shall be the same as that selected for the particulate sample. The sampling location in the duct shall be at the centroid of the cross section or at a point no closer to the walls than 1 m (3.28 ft). The sampling time and sample volume for each sample run shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two samples shall be taken during a 1-hour period, with each sample taken within a 30-minute interval.
(ii) The emission rate correction factor, integrated sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration (%02). The O 2sample shall be taken simultaneously with, and at the same point as, the SO 2 sample. The SO 2emission rate shall be computed for each pair of SO 2and O 2samples. The SO 2emission rate (E) for each run shall be the arithmetic mean of the results of the two pairs of samples.
(5) Method 7 of appendix A of this part shall be used to determine the NOx concentration.
(i) The sampling site and location shall be the same as for the SO 2sample. Each run shall consist of four grab samples, with each sample taken at about 15-minute intervals.
(ii) For each NOx sample, the emission rate correction factor, grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O2 concentration (%02). The sample shall be taken simultaneously with, and at the same point as, the NOx sample.
(iii) The NOx emission rate shall be computed for each pair of NOx and O2 samples. The NOx emission rate (E) for each run shall be the arithmetic mean of the results of the four pairs of samples.
(c) When combinations of fossil fuels or fossil fuel and wood residue are fired, the owner or operator (in order to compute the prorated standard as shown in &sect;&sect;60.43(b) and 60.44(b)) shall determine the percentage (w, x, y, or z) of the total heat input derived from each type of fuel as follows:
(1) The heat input rate of each fuel shall be determined by multiplying the gross calorific value of each fuel fired by the rate of each fuel burned.
(2) ASTM Methods D2015, or D5865 (solid fuels), D240 (liquid fuels), or D1826 (gaseous fuels) (all of these methods are incorporated by reference, see &sect;60.17) shall be used to determine the gross calorific values of the fuels. The method used to determine the calorific value of wood residue must be approved by the Administrator.
(3) Suitable methods shall be used to determine the rate of each fuel burned during each test period, and a material balance over the steam generating system shall be used to confirm the rate.
(d) The owner or operator may use the following as alternatives to the reference methods and procedures in this section or in other sections as specified:
(1) The emission rate (E) of PM, SO 2 and NOx may be determined by using the F, factor, provided that the following procedure is used:
(i) The emission rate (E) shall be computed using the following equation:
E =CF&#xfd;         0
            %C0 2 )
Where:
E = Emission rate of pollutant, ng/J (lb/MMBtu);
C = Concentration of pollutant, ng/dscm (lb/dscf);
C = Concentration of pollutant, ng/dscm (lb/dscf);
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-I1 of 12 APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971%C0 2= CO 2 concentration, percent dry basis; and Fc= Factor as determined in appropriate sections of Method 19 of appendix A of this part.(ii) If and only if the average F, factor in Method 19 of appendix A of this part is used to calculate E and either E is from 0.97 to 1.00 of the emission standard or the relative accuracy of a continuous emission monitoring system is from 17 to 20 percent, then three runs of Method 3B of appendix A of this part shall be used to determine the O 2 and CO 2 concentration according to the procedures in paragraph (b)(2)(ii), (4)(ii), or (5)(ii) of this section. Then if F, (average of three runs), as calculated from the equation in Method 3B of appendix A of this part, is more than +/-3 percent than the average Fo value, as determined from the average values of Fd and F, in Method 19 of appendix A of this part, i.e. , Fo.a = 0.209 (Fda/Faa), then the following procedure shall be followed: (A) When Fo is less than 0.97 Fo,, then E shall be increased by that proportion under 0.97 Faa, e.g. , if Fo is 0.95 Foa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the emission standard.(B) When F 0 is less than 0.97 F., and when the average difference (d) between the continuous monitor minus the reference methods is negative, then E shall be increased by that proportion under 0.97 Fma, e.g. , if F. is 0.95 Fwa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification.(C) When F. is greater than 1.03 Foa and when the average difference d is positive, then E shall be decreased by that proportion over 1.03 F.., e.g., if F. is 1.05 Faa, E shall be decreased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page D-I1 of 12
(2) For Method 5 or 5B of appendix A-3 of this part, Method 17 of appendix A-6 of this part may be used at facilities with or without wet FGD systems if the stack gas temperature at the sampling location does not exceed an average temperature of 160 'C (320 'F). The procedures of sections 8.1 and 11.1 of Method 5B of appendix A-3 of this part may be used with Method 17 of appendix A-6 of this part only if it is used after wet FGD systems. Method 17 of appendix A-6 of this part shall not be used after wet FGD systems if the effluent gas is saturated or laden with water droplets.(3) Particulate matter and SO 2 may be determined simultaneously with the Method 5 of appendix A of this part train provided that the following changes are made: (i) The filter and impinger apparatus in sections 2.1.5 and 2.1.6 of Method 8 of appendix A of this part is used in place of the condenser (section 2.1.7) of Method 5 of appendix A of this part.(ii) All applicable procedures in Method 8 of appendix A of this part for the determination of S0 2 (including moisture) are used: (4) For Method 6 of appendix A of this part, Method 6C of appendix A of this part may be used. Method 6A of appendix A of this part may also be used whenever Methods 6 and 3B of appendix A of this part data are specified to determine the'SO 2 emission rate, under the conditions in paragraph (d)(1) of this section.(5) For Method 7 of appendix A of this part, Method 7A, 7C, 7D, or 7E of appendix A of this part may be used. If Method 7C, 7D, or 7E of appendix A of this part is used, the sampling time for each run shall be at least 1 hour and the integrated sampling approach shall be used to determine the O 2 concentration  
 
(%02) for the emission rate correction factor.(6) For Method 3 of appendix A of this part, Method 3A or 3B of appendix A of this part may be used.(7) For Method 3B of appendix A of this part, Method 3A of appendix A of this part may be used.[60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5078, Jan. 28, 2009]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-12 of 12 APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants Title 40: Protection of Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES Subpart Y-Standards of Performance for Coal Preparation Plants&sect; 60.250 Applicability and designation of affectedfacility.(a) The provisions of this subpart are applicable to any of the following affected facilities in coal preparation plants which process more than 181 Mg (200 tons) per day: Thermal dryers, pneumatic coal-cleaning equipment (air tables), coal processing and conveying equipment (including breakers and crushers), coal storage systems, and coal transfer and loading systems.(b) Any facility under paragraph (a) of this section that commences construction or modification after October 24, 1974, is subject to the requirements of this subpart.[42 FR 37938, July 25, 1977; 42 FR 44812, Sept. 7, 1977, as amended at 65 FR 61757, Oct. 17, 2000]&sect; 60.251 Definitions.
APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971
As used in this subpart, all terms not defined herein have the meaning given them in the Act and in subpart A of this part.(a) Coal preparation plant means any facility (excluding underground mining operations) which prepares coal by one or more of the following processes:
%C0 2= CO 2concentration, percent dry basis; and Fc= Factor as determined in appropriate sections of Method 19 of appendix A of this part.
breaking, crushing, screening, wet or dry cleaning, and thermal drying.(b) Bituminous coal means solid fossil fuel classified as bituminous coal by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see  
(ii) If and only if the average F, factor in Method 19 of appendix A of this part is used to calculate E and either E is from 0.97 to 1.00 of the emission standard or the relative accuracy of a continuous emission monitoring system is from 17 to 20 percent, then three runs of Method 3B of appendix A of this part shall be used to determine the O 2and CO 2concentration according to the procedures in paragraph (b)(2)(ii), (4)(ii), or (5)(ii) of this section. Then if F, (average of three runs), as calculated from the equation in Method 3B of appendix A of this part, is more than +/-3 percent than the average Fo value, as determined from the average values of Fd and F, in Method 19 of appendix A of this part, i.e. , Fo.a = 0.209 (Fda/Faa), then the following procedure shall be followed:
&sect;60.17).(c) Coal means all solid fossil fuels classified as anthracite, bituminous, subbituminous, or lignite by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see  
(A) When Fo is less than 0.97 Fo,, then E shall be increased by that proportion under 0.97 Faa, e.g. , if Fo is 0.95 Foa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the emission standard.
&sect;60.17).(d) Cyclonic flow means a spiraling movement of exhaust gases within a duct or stack.(e) Thermal dryer means any facility in which the moisture content of bituminous coal is reduced by contact with a heated gas stream which is exhausted to the atmosphere.(f) Pneumatic coal-cleaning equipment means any facility which classifies bituminous coal by size or separates bituminous coal from refuse by application of air stream(s).(g) Coal processing and conveying equipment means any machinery used to reduce the size of coal or to separate coal from refuse, and the equipment used to convey coal to or remove coal and refuse from the machinery.
(B) When F0 is less than 0.97 F., and when the average difference (d) between the continuous monitor minus the reference methods is negative, then E shall be increased by that proportion under 0.97 Fma, e.g. , if F. is 0.95 Fwa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification.
This includes, but is not limited to, breakers, crushers, screens, and conveyor belts.(h) Coal storage system means any facility used to store coal except for open storage piles.(i) Transfer and loading system means any facility used to transfer and load coal for shipment.[41 FR 2234, Jan. 15, 1976, as amended at 48 FR 3738, Jan. 27, 1983; 65 FR 61757, Oct. 17, 2000]&sect; 60.252 Standards for particulate matter.(a) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any thermal dryer gases which: (1) Contain particulate matter in excess of 0.070 g/dscm (0.031 gr/dscf).(2) Exhibit 20 percent opacity or greater.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page Y-1 of 2 APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants (b) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any pneumatic coal cleaning equipment, gases which: (1) Contain particulate matter in excess of 0.040 g/dscm (0.017 gr/dscf).(2) Exhibit 10 percent opacity or greater.(c) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater.[41 FR 2234, Jan. 15, 1976, as amended at 65 FR 61757, Oct. 17, 2000]&sect; 60.253 Monitoring of operations.(a) The owner or operator of any thermal dryer shall install, calibrate, maintain, and continuously operate monitoring devices as follows: (1) A monitoring device for the measurement of the temperature of the gas stream at the exit of the thermal dryer on a continuous basis. The monitoring device is to be certified by the manufacturer to be accurate within +/-1.7 'C (+/-3 &deg;F).(2) For affected facilities that use venturi scrubber emission control equipment: (i) A monitoring device for the continuous measurement of the pressure loss through the venturi constriction of the control equipment.
(C) When F. is greater than 1.03 Foa and when the average difference d is positive, then E shall be decreased by that proportion over 1.03 F.., e.g., if F. is 1.05 Faa, E shall be decreased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification.
The monitoring device is to be certified by the manufacturer to be accurate within +/-1 inch water gauge.(ii) A monitoring device for the continuous measurement of the water supply pressure to the control equipment.
(2) For Method 5 or 5B of appendix A-3 of this part, Method 17 of appendix A-6 of this part may be used at facilities with or without wet FGD systems if the stack gas temperature at the sampling location does not exceed an average temperature of 160 'C (320 'F). The procedures of sections 8.1 and 11.1 of Method 5B of appendix A-3 of this part may be used with Method 17 of appendix A-6 of this part only if it is used after wet FGD systems. Method 17 of appendix A-6 of this part shall not be used after wet FGD systems if the effluent gas is saturated or laden with water droplets.
The monitoring device is to be certified by the manufacturer to be accurate within +/-5 percent of design water supply pressure.
(3) Particulate matter and SO 2 may be determined simultaneously with the Method 5 of appendix A of this part train provided that the following changes are made:
The pressure sensor or tap must be located close to the water discharge point. The Administrator may be consulted for approval of alternative locations.(b) All monitoring devices under paragraph (a) of this section are to be recalibrated annually in accordance with procedures under &sect;60.13(b).
(i) The filter and impinger apparatus in sections 2.1.5 and 2.1.6 of Method 8 of appendix A of this part is used in place of the condenser (section 2.1.7) of Method 5 of appendix A of this part.
[41 FR 2234, Jan. 15, 1976, as amended at 54 FR 6671, Feb. 14, 1989; 65 FR 61757, Oct. 17, 2000]&sect; 60.254 Test methods and procedures.(a) In conducting the performance tests required in &sect;60.8, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in &sect;60.8(b).(b) The owner or operator shall determine compliance with the particular matter standards in &sect;60.252 as follows: (1) Method 5 shall be used to determine the particulate matter concentration.
(ii) All applicable procedures in Method 8 of appendix A of this part for the determination of S0 2(including moisture) are used:
The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). Sampling shall begin no less than 30 minutes after startup and shall terminate before shutdown procedures begin.(2) Method 9 and the procedures in &sect;60.11 shall be used to determine opacity.[54 FR 6671, Feb. 14, 1989]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page Y-2 of 2 APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart IIIl-Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Source: 71 FR 39172, July 11, 2006, unless otherwise noted.What This Subpart Covers&sect; 60.4200 Am I subject to this subpart?(a) The provisions of this subpart are applicable to manufacturers, owners, and operators of stationary compression ignition (CI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (3) of this section. For the purposes of this subpart, the date that construction commences is the date the engine is ordered by the owner or operator.(1) Manufacturers of stationary CI ICE with a displacement of less than 30 liters per cylinder where the model year is: (i) 2007 or later, for engines that are not fire pump engines, (ii) The model year listed in table 3 to this subpart or later model year, for fire pump engines.(2) Owners and operators of stationary CI ICE that commence construction after July 11, 2005 where the stationary CI ICE are: (i) Manufactured after April 1, 2006 and are not fire pump engines, or (ii) Manufactured as a certified National Fire Protection Association (NFPA) fire pump engine after July 1, 2006.(3) Owners and operators of stationary CI ICE that modify or reconstruct their stationary CI ICE after July 11, 2005.(b) The provisions of this subpart are not applicable to stationary CI ICE being tested at a stationary CI ICE test cell/stand.(c) If you are an owner or operator of an area source subject to this subpart, you are exempt from the obligation to obtain a permit under 40 CFR part 70 or 40 CFR part 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart applicable to area sources.(d) Stationary CI ICE may be eligible for exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C (or the exemptions described in 40 CFR part 89, subpart J and 40 CFR part 94, subpart J, for engines that would need to be certified to standards in those parts), except that owners and operators, as well as manufacturers, may be eligible to request an exemption for national security.Emission Standards for Manufacturers
(4) For Method 6 of appendix A of this part, Method 6C of appendix A of this part may be used. Method 6A of appendix A of this part may also be used whenever Methods 6 and 3B of appendix A of this part data are specified to determine the' SO 2emission rate, under the conditions in paragraph (d)(1) of this section.
&sect; 60.4201 What emission standards must I meet for non-emergency engines if I am a stationary CI internal combustion engine manufacturer?(a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 kilowatt (KW) (3,000 horsepower (HP)) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 89.112, 40 CFR 89.113, 40 CFR 1039.101, 40 CFR 1039.102, 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same model year and maximum engine power.(b) Stationary CI internal combustion engine manufacturers must certify their 2007 through 2010 model year non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power.(c) Stationary CI internal combustion engine manufacturers must certify their 2011 model year and later non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 1039.101, 40 CFR 1039.102, 40 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-1 of 19 APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same maximum engine power.(d) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power.&sect; 60.4202 What emission standards must I meet for emergency engines if I am a stationary CI internal combustion engine manufacturer?(a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (a)(1) through (2) of this section.(1) For engines with a maximum engine power less than 37 KW (50 HP): (i) The certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants for model year 2007 engines, and (ii) The certification emission standards for new nonroad CI engines in 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, 40 CFR 1039.115, and table 2 to this subpart, for 2008 model year and later engines.(2) For engines with a maximum engine power greater than or equal to 37 KW (50 HP), the certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants beginning in model year 2007.(b) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (b)(1) through (2) of this section.(1) For 2007 through 2010 model years, the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power.(2) For 2011 model year and later, the certification emission standards for new nonroad CI engines for engines of the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants.(c) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power.(d) Beginning with the model years in table 3 to this subpart, stationary CI internal combustion engine manufacturers must certify their fire pump stationary CI ICE to the emission standards in table 4 to this subpart, for all pollutants, for the same model year and NFPA nameplate power.&sect; 60.4203 How long must my engines meet the emission standards if I am a stationary CI internal combustion engine manufacturer?
(5) For Method 7 of appendix A of this part, Method 7A, 7C, 7D, or 7E of appendix A of this part may be used. If Method 7C, 7D, or 7E of appendix A of this part is used, the sampling time for each run shall be at least 1 hour and the integrated sampling approach shall be used to determine the O 2 concentration (%02) for the emission rate correction factor.
Engines manufactured by stationary CI internal combustion engine manufacturers must meet the emission standards as required in &sect;&sect;60.4201 and 60.4202 during the useful life of the engines.Emission Standards for Owners and Operators&sect; 60.4204 What emission standards must I meet for non-emergency engines if I am an owner or operator of a stationary CI internal combustion engine?Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-2 of 19 APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of less than 10 liters per cylinder must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder must comply with the emission standards in 40 CFR 94.8(a)(1).(b) Owners and operators of 2007 model year and later non-emergency stationary CI ICE with a displacement of less than 30 liters per cylinder must comply with the emission standards for new CI engines in &sect;60.4201 for their 2007 model year and later stationary CI ICE, as applicable.(c) Owners and operators of non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (c)(1) and (2) of this section.(1) Reduce nitrogen oxides (NOx) emissions by 90 percent or more, or limit the emissions of NOxin the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (g/KW-hr)  
(6) For Method 3 of appendix A of this part, Method 3A or 3B of appendix A of this part may be used.
(1.2 grams per HP-hour (g/HP-hr)).
(7) For Method 3B of appendix A of this part, Method 3A of appendix A of this part may be used.
(2) Reduce particulate matter (PM) emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr).&sect; 60.4205 What emission standards must I meet for emergency engines if I am an owner or operator of a stationary CI internal combustion engine?(a) Owners and operators of pre-2007 model year emergency stationary CI ICE with a displacement of less than 10 liters per cylinder that are not fire pump engines must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards in 40 CFR 94.8(a)(1).(b) Owners and operators of 2007 model year and later emergency stationary CI ICE with a displacement of less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards for new nonroad CI engines in&sect;60.4202, for all pollutants, for the same model year and maximum engine power for their 2007 model year and later emergency stationary CI ICE.(c) Owners and operators of fire pump engines with a displacement of less than 30 liters per cylinder must comply with the emission standards in table 4 to this subpart, for all pollutants.(d) Owners and operators of emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (d)(1) and (2) of this section.(1) Reduce NOx emissions by 90 percent or more, or limit the emissions of NOx in the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (1.2 grams per HP-hour).(2) Reduce PM emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr).&sect; 60.4206 How long must I meet the emission standards if I am an owner or operator of a stationary CI internal combustion engine?Owners and operators of stationary CI ICE must operate and maintain stationary CI ICE that achieve the emission standards as required in &sect;&sect;60.4204 and 60.4205 according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer, over the entire life of the engine.Fuel Requirements for Owners and Operators&sect; 60.4207 What fuel requirements must I meet if I am an owner or operator of a stationary CI internal combustion engine subject to this subpart?Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-3 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Beginning October 1, 2007, owners and operators of stationary CI ICE subject to this subpart that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.5 10(a).(b) Beginning October 1, 2010, owners and operators of stationary CI ICE subject to this subpart with a displacement of less than 30 liters per cylinder that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.510(b) for nonroad diesel fuel.(c) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart may petition the Administrator for approval to use remaining non-compliant fuel that does not meet the fuel requirements of paragraphs (a) and (b) of this section beyond the dates required for the purpose of using up existing fuel inventories.
[60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5078, Jan. 28, 2009]
If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator.(d) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart that are located in areas of Alaska not accessible by the Federal Aid Highway System may petition the Administrator for approval to use any fuels mixed with used lubricating oil that do not meet the fuel requirements of paragraphs (a) and (b) of this section. Owners and operators must demonstrate in their petition to the Administrator that there is no other place to use the lubricating oil. If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator.(e) Stationary CI ICE that have a national security exemption under &sect;60.4200(d) are also exempt from the fuel requirements in this section.Other Requirements for Owners and Operators&sect; 60.4208 What is the deadline for importing or installing stationary CI ICE produced in the previous model year?(a) After December 31, 2008, owners and operators may not install stationary CI ICE (excluding fire pump engines) that do not meet the applicable requirements for 2007 model year engines.(b) After December 31, 2009, owners and operators may not install stationary CI ICE with a maximum engine power of less than 19 KW (25 HP) (excluding fire pump engines) that do not meet the applicable requirements for 2008 model year engines.(c) After December 31, 2014, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 19 KW (25 HP) and less than 56 KW (75 HP) that do not meet the applicable requirements for 2013 model year non-emergency engines.(d) After December 31, 2013, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 56 KW (75 HP) and less than 130 KW (175 HP) that do not meet the applicable requirements for 2012 model year non-emergency engines.(e) After December 31, 2012, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 130 KW (175 HP), including those above 560 KW (750 HP), that do not meet the applicable requirements for 2011 model year non-emergency engines.(f) After December 31, 2016, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 560 KW (750 HP) that do not meet the applicable requirements for 2015 model year non-emergency engines.(g) In addition to the requirements specified in &sect;&sect;60.4201, 60.4202, 60.4204, and 60.4205, it is prohibited to import stationary CI ICE with a displacement of less than 30 liters per cylinder that do not meet the applicable requirements specified in paragraphs (a) through (f) of this section after the dates specified in paragraphs (a) through (f) of this section.(h) The requirements of this section do not apply to owners or operators of stationary CI ICE that have been modified, reconstructed, and do not apply to engines that were removed from one existing location and reinstalled at a new location.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-4 of 19 APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines&sect; 60.4209 What are the monitoring requirements if I am an owner or operator of a stationary CI internal combustion engine?If you are an owner or operator, you must meet the monitoring requirements of this section. In addition, you must also meet the monitoring requirements specified in &sect;60.4211.(a) If you are an owner or operator of an emergency stationary CI internal combustion engine, you must install a non-resettable hour meter prior to startup of the engine.(b) If you are an owner or operator of a stationary CI internal combustion engine equipped with a diesel particulate filter to comply with the emission standards in &sect;60.4204, the diesel particulate filter must be installed with a backpressure monitor that notifies the owner or operator when the high backpressure limit of the engine is approached.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page D-12 of 12
 
APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants Title 40: Protectionof Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES Subpart Y-Standards of Performancefor CoalPreparationPlants
&sect; 60.250 Applicability and designation of affectedfacility.
(a) The provisions of this subpart are applicable to any of the following affected facilities in coal preparation plants which process more than 181 Mg (200 tons) per day: Thermal dryers, pneumatic coal-cleaning equipment (air tables), coal processing and conveying equipment (including breakers and crushers), coal storage systems, and coal transfer and loading systems.
(b) Any facility under paragraph (a) of this section that commences construction or modification after October 24, 1974, is subject to the requirements of this subpart.
[42 FR 37938, July 25, 1977; 42 FR 44812, Sept. 7, 1977, as amended at 65 FR 61757, Oct. 17, 2000]
&sect; 60.251   Definitions.
As used in this subpart, all terms not defined herein have the meaning given them in the Act and in subpart A of this part.
(a) Coal preparationplant means any facility (excluding underground mining operations) which prepares coal by one or more of the following processes: breaking, crushing, screening, wet or dry cleaning, and thermal drying.
(b) Bituminous coal means solid fossil fuel classified as bituminous coal by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see &sect;60.17).
(c) Coal means all solid fossil fuels classified as anthracite, bituminous, subbituminous, or lignite by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see &sect;60.17).
(d) Cyclonic flow means a spiraling movement of exhaust gases within a duct or stack.
(e) Thermal dryer means any facility in which the moisture content of bituminous coal is reduced by contact with a heated gas stream which is exhausted to the atmosphere.
(f) Pneumatic coal-cleaning equipment means any facility which classifies bituminous coal by size or separates bituminous coal from refuse by application of air stream(s).
(g) Coal processingand conveying equipment means any machinery used to reduce the size of coal or to separate coal from refuse, and the equipment used to convey coal to or remove coal and refuse from the machinery. This includes, but is not limited to, breakers, crushers, screens, and conveyor belts.
(h) Coal storage system means any facility used to store coal except for open storage piles.
(i) Transferand loading system means any facility used to transfer and load coal for shipment.
[41 FR 2234, Jan. 15, 1976, as amended at 48 FR 3738, Jan. 27, 1983; 65 FR 61757, Oct. 17, 2000]
&sect; 60.252 Standardsfor particulatematter.
(a) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any thermal dryer gases which:
(1) Contain particulate matter in excess of 0.070 g/dscm (0.031 gr/dscf).
(2) Exhibit 20 percent opacity or greater.
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APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants (b) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any pneumatic coal cleaning equipment, gases which:
(1) Contain particulate matter in excess of 0.040 g/dscm (0.017 gr/dscf).
(2) Exhibit 10 percent opacity or greater.
(c) On and after the date on which the performance test required to be conducted by &sect;60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater.
[41 FR 2234, Jan. 15, 1976, as amended at 65 FR 61757, Oct. 17, 2000]
&sect; 60.253 Monitoringof operations.
(a) The owner or operator of any thermal dryer shall install, calibrate, maintain, and continuously operate monitoring devices as follows:
(1) A monitoring device for the measurement of the temperature of the gas stream at the exit of the thermal dryer on a continuous basis. The monitoring device is to be certified by the manufacturer to be accurate within +/-1.7 'C (+/-3 &deg;F).
(2) For affected facilities that use venturi scrubber emission control equipment:
(i) A monitoring device for the continuous measurement of the pressure loss through the venturi constriction of the control equipment. The monitoring device is to be certified by the manufacturer to be accurate within +/-1 inch water gauge.
(ii) A monitoring device for the continuous measurement of the water supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer to be accurate within +/-5 percent of design water supply pressure. The pressure sensor or tap must be located close to the water discharge point. The Administrator may be consulted for approval of alternative locations.
(b) All monitoring devices under paragraph (a) of this section are to be recalibrated annually in accordance with procedures under &sect;60.13(b).
[41 FR 2234, Jan. 15, 1976, as amended at 54 FR 6671, Feb. 14, 1989; 65 FR 61757, Oct. 17, 2000]
&sect; 60.254 Test methods and procedures.
(a) In conducting the performance tests required in &sect;60.8, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in &sect;60.8(b).
(b) The owner or operator shall determine compliance with the particular matter standards in &sect;60.252 as follows:
(1) Method 5 shall be used to determine the particulate matter concentration. The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). Sampling shall begin no less than 30 minutes after startup and shall terminate before shutdown procedures begin.
(2) Method 9 and the procedures in &sect;60.11 shall be used to determine opacity.
[54 FR 6671, Feb. 14, 1989]
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APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart IIIl-Standardsof Performancefor Stationary CompressionIgnition Internal Combustion Engines Source: 71 FR 39172, July 11, 2006, unless otherwise noted.
What This Subpart Covers
&sect; 60.4200 Am I subject to this subpart?
(a) The provisions of this subpart are applicable to manufacturers, owners, and operators of stationary compression ignition (CI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (3) of this section. For the purposes of this subpart, the date that construction commences is the date the engine is ordered by the owner or operator.
(1) Manufacturers of stationary CI ICE with a displacement of less than 30 liters per cylinder where the model year is:
(i) 2007 or later, for engines that are not fire pump engines, (ii) The model year listed in table 3 to this subpart or later model year, for fire pump engines.
(2) Owners and operators of stationary CI ICE that commence construction after July 11, 2005 where the stationary CI ICE are:
(i) Manufactured after April 1, 2006 and are not fire pump engines, or (ii) Manufactured as a certified National Fire Protection Association (NFPA) fire pump engine after July 1, 2006.
(3) Owners and operators of stationary CI ICE that modify or reconstruct their stationary CI ICE after July 11, 2005.
(b) The provisions of this subpart are not applicable to stationary CI ICE being tested at a stationary CI ICE test cell/stand.
(c) If you are an owner or operator of an area source subject to this subpart, you are exempt from the obligation to obtain a permit under 40 CFR part 70 or 40 CFR part 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart applicable to area sources.
(d) Stationary CI ICE may be eligible for exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C (or the exemptions described in 40 CFR part 89, subpart J and 40 CFR part 94, subpart J, for engines that would need to be certified to standards in those parts), except that owners and operators, as well as manufacturers, may be eligible to request an exemption for national security.
Emission Standardsfor Manufacturers
&sect; 60.4201 What emission standards must I meet for non-emergency engines if I am a stationary CI internalcombustion engine manufacturer?
(a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 kilowatt (KW) (3,000 horsepower (HP)) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 89.112, 40 CFR 89.113, 40 CFR 1039.101, 40 CFR 1039.102, 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same model year and maximum engine power.
(b) Stationary CI internal combustion engine manufacturers must certify their 2007 through 2010 model year non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power.
(c) Stationary CI internal combustion engine manufacturers must certify their 2011 model year and later non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 1039.101, 40 CFR 1039.102, 40 Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page 1111-1 of 19
 
APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same maximum engine power.
(d) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power.
&sect; 60.4202 What emission standardsmust I meet for emergency engines if I am a stationaryCI internalcombustion engine manufacturer?
(a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (a)(1) through (2) of this section.
(1) For engines with a maximum engine power less than 37 KW (50 HP):
(i) The certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants for model year 2007 engines, and (ii) The certification emission standards for new nonroad CI engines in 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, 40 CFR 1039.115, and table 2 to this subpart, for 2008 model year and later engines.
(2) For engines with a maximum engine power greater than or equal to 37 KW (50 HP), the certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants beginning in model year 2007.
(b) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (b)(1) through (2) of this section.
(1) For 2007 through 2010 model years, the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power.
(2) For 2011 model year and later, the certification emission standards for new nonroad CI engines for engines of the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants.
(c) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power.
(d) Beginning with the model years in table 3 to this subpart, stationary CI internal combustion engine manufacturers must certify their fire pump stationary CI ICE to the emission standards in table 4 to this subpart, for all pollutants, for the same model year and NFPA nameplate power.
&sect; 60.4203 How long must my engines meet the emission standardsif I am a stationary CI internalcombustion engine manufacturer?
Engines manufactured by stationary CI internal combustion engine manufacturers must meet the emission standards as required in &sect;&sect;60.4201 and 60.4202 during the useful life of the engines.
Emission Standardsfor Owners and Operators
&sect; 60.4204 What emission standardsmust I meetfor non-emergency engines if I am an owner or operatorof a stationary CI internalcombustion engine?
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APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of less than 10 liters per cylinder must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder must comply with the emission standards in 40 CFR 94.8(a)(1).
(b) Owners and operators of 2007 model year and later non-emergency stationary CI ICE with a displacement of less than 30 liters per cylinder must comply with the emission standards for new CI engines in &sect;60.4201 for their 2007 model year and later stationary CI ICE, as applicable.
(c) Owners and operators of non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (c)(1) and (2) of this section.
(1) Reduce nitrogen oxides (NOx) emissions by 90 percent or more, or limit the emissions of NOxin the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (g/KW-hr) (1.2 grams per HP-hour (g/HP-hr)).
(2) Reduce particulate matter (PM) emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr).
&sect; 60.4205 What emission standardsmust I meet for emergency engines if I am an owner or operatorof a stationaryCI internalcombustion engine?
(a) Owners and operators of pre-2007 model year emergency stationary CI ICE with a displacement of less than 10 liters per cylinder that are not fire pump engines must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards in 40 CFR 94.8(a)(1).
(b) Owners and operators of 2007 model year and later emergency stationary CI ICE with a displacement of less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards for new nonroad CI engines in
&sect;60.4202, for all pollutants, for the same model year and maximum engine power for their 2007 model year and later emergency stationary CI ICE.
(c) Owners and operators of fire pump engines with a displacement of less than 30 liters per cylinder must comply with the emission standards in table 4 to this subpart, for all pollutants.
(d) Owners and operators of emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (d)(1) and (2) of this section.
(1) Reduce NOx emissions by 90 percent or more, or limit the emissions of NOx in the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (1.2 grams per HP-hour).
(2) Reduce PM emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr).
&sect; 60.4206 How long must I meet the emission standardsif I am an owner or operatorof a stationary CI internal combustion engine?
Owners and operators of stationary CI ICE must operate and maintain stationary CI ICE that achieve the emission standards as required in &sect;&sect;60.4204 and 60.4205 according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer, over the entire life of the engine.
Fuel Requirements for Owners and Operators
&sect; 60.4207 Whatfuel requirements must I meet if I am an owner or operatorof a stationaryCI internal combustion engine subject to this subpart?
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APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Beginning October 1, 2007, owners and operators of stationary CI ICE subject to this subpart that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.5 10(a).
(b) Beginning October 1, 2010, owners and operators of stationary CI ICE subject to this subpart with a displacement of less than 30 liters per cylinder that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.510(b) for nonroad diesel fuel.
(c) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart may petition the Administrator for approval to use remaining non-compliant fuel that does not meet the fuel requirements of paragraphs (a) and (b) of this section beyond the dates required for the purpose of using up existing fuel inventories. If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator.
(d) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart that are located in areas of Alaska not accessible by the Federal Aid Highway System may petition the Administrator for approval to use any fuels mixed with used lubricating oil that do not meet the fuel requirements of paragraphs (a) and (b) of this section. Owners and operators must demonstrate in their petition to the Administrator that there is no other place to use the lubricating oil. If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator.
(e) Stationary CI ICE that have a national security exemption under &sect;60.4200(d) are also exempt from the fuel requirements in this section.
Other Requirements for Owners and Operators
&sect; 60.4208 What is the deadlinefor importingor installing stationary CI ICE produced in the previous model year?
(a) After December 31, 2008, owners and operators may not install stationary CI ICE (excluding fire pump engines) that do not meet the applicable requirements for 2007 model year engines.
(b) After December 31, 2009, owners and operators may not install stationary CI ICE with a maximum engine power of less than 19 KW (25 HP) (excluding fire pump engines) that do not meet the applicable requirements for 2008 model year engines.
(c) After December 31, 2014, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 19 KW (25 HP) and less than 56 KW (75 HP) that do not meet the applicable requirements for 2013 model year non-emergency engines.
(d) After December 31, 2013, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 56 KW (75 HP) and less than 130 KW (175 HP) that do not meet the applicable requirements for 2012 model year non-emergency engines.
(e) After December 31, 2012, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 130 KW (175 HP), including those above 560 KW (750 HP), that do not meet the applicable requirements for 2011 model year non-emergency engines.
(f) After December 31, 2016, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 560 KW (750 HP) that do not meet the applicable requirements for 2015 model year non-emergency engines.
(g) In addition to the requirements specified in &sect;&sect;60.4201, 60.4202, 60.4204, and 60.4205, it is prohibited to import stationary CI ICE with a displacement of less than 30 liters per cylinder that do not meet the applicable requirements specified in paragraphs (a) through (f) of this section after the dates specified in paragraphs (a) through (f) of this section.
(h) The requirements of this section do not apply to owners or operators of stationary CI ICE that have been modified, reconstructed, and do not apply to engines that were removed from one existing location and reinstalled at a new location.
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APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines
&sect; 60.4209 What are the monitoring requirements if I am an owner or operatorof a stationary CI internalcombustion engine?
If you are an owner or operator, you must meet the monitoring requirements of this section. In addition, you must also meet the monitoring requirements specified in &sect;60.4211.
(a) If you are an owner or operator of an emergency stationary CI internal combustion engine, you must install a non-resettable hour meter prior to startup of the engine.
(b) If you are an owner or operator of a stationary CI internal combustion engine equipped with a diesel particulate filter to comply with the emission standards in &sect;60.4204, the diesel particulate filter must be installed with a backpressure monitor that notifies the owner or operator when the high backpressure limit of the engine is approached.
Compliance Requirements
Compliance Requirements
&sect; 60.4210 What are my compliance requirements if I am a stationary CI internal combustion engine manufacturer?(a) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of less than 10 liters per cylinder to the emission standards specified in &sect;60.4201(a) through (c) and &sect;60.4202(a), (b) and (d) using the certification procedures required in 40 CFR part 89, subpart B, or 40 CFR part 1039, subpart C, as applicable, and must test their engines as specified in those parts. For the purposes of this subpart, engines certified to the standards in table I to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89. For the purposes of this subpart, engines certified to the standards in table 4 to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89, except that engines with NFPA nameplate power of less than 37 KW (50 HP) certified to model year 2011 or later standards shall be subject to the same requirements as engines certified to the standards in 40 CFR part 1039.(b) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the emission standards specified in&sect;60.4201(d) and &sect;60.4202(c) using the certification procedures required in 40 CFR part 94 subpart C, and must test their engines as specified in 40 CFR part 94.(c) Stationary CI internal combustion engine manufacturers must meet the requirements of 40 CFR 1039.120, 40 CFR 1039.125, 40 CFR 1039.130, 40 CFR 1039.135, and 40 CFR part 1068 for engines that are certified to the emission standards in 40 CFR part 1039. Stationary CI internal combustion engine manufacturers must meet the corresponding provisions of 40 CFR part 89 or 40 CFR part 94 for engines that would be covered by that part if they were nonroad (including marine)engines. Labels on such engines must refer to stationary engines, rather than or in addition to nonroad or marine engines, as appropriate.
&sect; 60.4210 What are my compliance requirementsif I am a stationary CI internalcombustion engine manufacturer?
Stationary CI internal combustion engine manufacturers must label their engines according to paragraphs (c)(1)through (3) of this section.(1) Stationary CI internal combustion engines manufactured from January 1, 2006 to March 31, 2006 (January 1, 2006 to June 30, 2006 for fire pump engines), other than those that are part of certified engine families under the nonroad CI engine regulations, must be labeled according to 40 CFR 1039.20.(2) Stationary CI internal combustion engines manufactured from April 1, 2006 to December 31, 2006 (or, for fire pump engines, July 1, 2006 to December 31 of the year preceding the year listed in table 3 to this subpart) must be labeled according to paragraphs (c)(2)(i) through (iii) of this section: (i) Stationary CI internal combustion engines that are part of certified engine families under the nonroad regulations must meet the labeling requirements for nonroad CI engines, but do not have to meet the labeling requirements in 40 CFR 1039.20.(ii) Stationary CI internal combustion engines that meet Tier 1 requirements (or requirements for fire pumps) under this subpart, but do not meet the requirements applicable to nonroad CI engines must be labeled according to 40 CFR 1039.20.The engine manufacturer may add language to the label clarifying that the engine meets Tier 1 requirements (or requirements for fire pumps) of this subpart.(iii) Stationary CI internal combustion engines manufactured after April 1, 2006 that do not meet Tier 1 requirements of this subpart, or fire pumps engines manufactured after July 1, 2006 that do not meet the requirements for fire pumps under this Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-5 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines subpart, may not be used in the U.S. If any such engines are manufactured in the U.S. after April 1, 2006 (July 1, 2006 for fire pump engines), they must be exported or must be brought into compliance with the appropriate standards prior to initial operation.
(a) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of less than 10 liters per cylinder to the emission standards specified in &sect;60.4201(a) through (c) and &sect;60.4202(a), (b) and (d) using the certification procedures required in 40 CFR part 89, subpart B, or 40 CFR part 1039, subpart C, as applicable, and must test their engines as specified in those parts. For the purposes of this subpart, engines certified to the standards in table I to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89. For the purposes of this subpart, engines certified to the standards in table 4 to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89, except that engines with NFPA nameplate power of less than 37 KW (50 HP) certified to model year 2011 or later standards shall be subject to the same requirements as engines certified to the standards in 40 CFR part 1039.
The export provisions of 40 CFR 1068.230 would apply to engines for export and the manufacturers must label such engines according to 40 CFR 1068.230.(3) Stationary CI internal combustion engines manufactured after January 1, 2007 (for fire pump engines, after January 1 of the year listed in table 3 to this subpart, as applicable) must be labeled according to paragraphs (c)(3)(i) through (iii) of this section.(i) Stationary CI internal combustion engines that meet the requirements of this subpart and the corresponding requirements for nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate.(ii) Stationary CI internal combustion engines that meet the requirements of this subpart, but are not certified to the standards applicable to nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate, but the words "stationary" must be included instead of "nonroad" or "marine" on the label. In addition, such engines must be labeled according to 40 CFR 1039.20.(iii) Stationary CI internal combustion engines that do not meet the requirements of this subpart must be labeled according to 40 CFR 1068.230 and must be exported under the provisions of 40 CFR 1068.230.(d) An engine manufacturer certifying an engine family or families to standards under this subpart that are identical to standards applicable under parts 89, 94, or 1039 for that model year may certify any such family that contains both nonroad (including marine) and stationary engines as a single engine family and/or may include any such family containing stationary engines in the averaging, banking and trading provisions applicable for such engines under those parts.(e) Manufacturers of engine families discussed in paragraph (d) of this section may meet the labeling requirements referred to in paragraph (c) of this section for stationary CI ICE by either adding a separate label containing the information required in paragraph (c) of this section or by adding the words "and stationary" after the word "nonroad" or "marine," as appropriate, to the label.(f) Starting with the model years shown in table 5 to this subpart, stationary CI internal combustion engine manufacturers must add a permanent label stating that the engine is for stationary emergency use only to each new emergency stationary CI internal combustion engine greater than or equal to 19 KW (25 HP) that meets all the emission standards for emergency engines in &sect;60.4202 but does not meet all the emission standards for non-emergency engines in &sect;60.4201.
(b) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the emission standards specified in
The label must be added according to the labeling requirements specified in 40 CFR 1039.135(b).
&sect;60.4201(d) and &sect;60.4202(c) using the certification procedures required in 40 CFR part 94 subpart C, and must test their engines as specified in 40 CFR part 94.
Engine manufacturers must specify in the owner's manual that operation of emergency engines is limited to emergency operations and required maintenance and testing.(g) Manufacturers of fire pump engines may use the test cycle in table 6 to this subpart for testing fire pump engines and may test at the NFPA certified nameplate HP, provided that the engine is labeled as "Fire Pump Applications Only".(h) Engine manufacturers, including importers, may introduce into commerce uncertified engines or engines certified to earlier standards that were manufactured before the new or changed standards took effect until inventories are depleted, as long as such engines are part of normal inventory.
(c) Stationary CI internal combustion engine manufacturers must meet the requirements of 40 CFR 1039.120, 40 CFR 1039.125, 40 CFR 1039.130, 40 CFR 1039.135, and 40 CFR part 1068 for engines that are certified to the emission standards in 40 CFR part 1039. Stationary CI internal combustion engine manufacturers must meet the corresponding provisions of 40 CFR part 89 or 40 CFR part 94 for engines that would be covered by that part if they were nonroad (including marine) engines. Labels on such engines must refer to stationary engines, rather than or in addition to nonroad or marine engines, as appropriate. Stationary CI internal combustion engine manufacturers must label their engines according to paragraphs (c)(1) through (3) of this section.
For example, if the engine manufacturers' normal industry practice is to keep on hand a one-month supply of engines based on its projected sales, and a new tier of standards starts to apply for the 2009 model year, the engine manufacturer may manufacture engines based on the normal inventory requirements late in the 2008 model year, and sell those engines for installation.
(1) Stationary CI internal combustion engines manufactured from January 1, 2006 to March 31, 2006 (January 1, 2006 to June 30, 2006 for fire pump engines), other than those that are part of certified engine families under the nonroad CI engine regulations, must be labeled according to 40 CFR 1039.20.
The engine manufacturer may not circumvent the provisions of&sect;&sect;60.4201 or 60.4202 by stockpiling engines that are built before new or changed standards take effect. Stockpiling of such engines beyond normal industry practice is a violation of this subpart.(i) The replacement engine provisions of 40 CFR 89.1003(b)(7), 40 CFR 94.1103(b)(3), 40 CFR 94.1103(b)(4) and 40 CFR&#xfd;1068.240 are applicable to stationary CI engines replacing existing equipment that is less than 15 years old.&sect; 60.4211 What are my compliance requirements if I am an owner or operator of a stationary CI internal combustion engine?Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-6 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) If you are an owner or operator and must comply with the emission standards specified in this subpart, you must operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer.
(2) Stationary CI internal combustion engines manufactured from April 1, 2006 to December 31, 2006 (or, for fire pump engines, July 1, 2006 to December 31 of the year preceding the year listed in table 3 to this subpart) must be labeled according to paragraphs (c)(2)(i) through (iii) of this section:
In addition, owners and operators may only change those settings that are permitted by the manufacturer.
(i) Stationary CI internal combustion engines that are part of certified engine families under the nonroad regulations must meet the labeling requirements for nonroad CI engines, but do not have to meet the labeling requirements in 40 CFR 1039.20.
You must also meet the requirements of 40 CFR parts 89, 94 and/or 1068, as they apply to you.(b) If you are an owner or operator of a pre-2007 model year stationary CI internal combustion engine and must comply with the emission standards specified in &sect;&sect;60.4204(a) or 60.4205(a), or if you are an owner or operator of a CI fire pump engine that is manufactured prior to the model years in table 3 to this subpart and must comply with the emission standards specified in &sect;60.4205(c), you must demonstrate compliance according to one of the methods specified in paragraphs (b)(1) through (5)of this section.(1) Purchasing an engine certified according to 40 CFR part 89 or 40 CFR part 94, as applicable, for the same model year and maximum engine power. The engine must be installed and configured according to the manufacturer's specifications.
(ii) Stationary CI internal combustion engines that meet Tier 1 requirements (or requirements for fire pumps) under this subpart, but do not meet the requirements applicable to nonroad CI engines must be labeled according to 40 CFR 1039.20.
The engine manufacturer may add language to the label clarifying that the engine meets Tier 1 requirements (or requirements for fire pumps) of this subpart.
(iii) Stationary CI internal combustion engines manufactured after April 1, 2006 that do not meet Tier 1 requirements of this subpart, or fire pumps engines manufactured after July 1, 2006 that do not meet the requirements for fire pumps under this Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page 1111-5 of 19
 
APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines subpart, may not be used in the U.S. If any such engines are manufactured in the U.S. after April 1, 2006 (July 1, 2006 for fire pump engines), they must be exported or must be brought into compliance with the appropriate standards prior to initial operation. The export provisions of 40 CFR 1068.230 would apply to engines for export and the manufacturers must label such engines according to 40 CFR 1068.230.
(3) Stationary CI internal combustion engines manufactured after January 1, 2007 (for fire pump engines, after January 1 of the year listed in table 3 to this subpart, as applicable) must be labeled according to paragraphs (c)(3)(i) through (iii) of this section.
(i) Stationary CI internal combustion engines that meet the requirements of this subpart and the corresponding requirements for nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate.
(ii) Stationary CI internal combustion engines that meet the requirements of this subpart, but are not certified to the standards applicable to nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate, but the words "stationary" must be included instead of "nonroad" or "marine" on the label. In addition, such engines must be labeled according to 40 CFR 1039.20.
(iii) Stationary CI internal combustion engines that do not meet the requirements of this subpart must be labeled according to 40 CFR 1068.230 and must be exported under the provisions of 40 CFR 1068.230.
(d) An engine manufacturer certifying an engine family or families to standards under this subpart that are identical to standards applicable under parts 89, 94, or 1039 for that model year may certify any such family that contains both nonroad (including marine) and stationary engines as a single engine family and/or may include any such family containing stationary engines in the averaging, banking and trading provisions applicable for such engines under those parts.
(e) Manufacturers of engine families discussed in paragraph (d) of this section may meet the labeling requirements referred to in paragraph (c) of this section for stationary CI ICE by either adding a separate label containing the information required in paragraph (c) of this section or by adding the words "and stationary" after the word "nonroad" or "marine," as appropriate, to the label.
(f) Starting with the model years shown in table 5 to this subpart, stationary CI internal combustion engine manufacturers must add a permanent label stating that the engine is for stationary emergency use only to each new emergency stationary CI internal combustion engine greater than or equal to 19 KW (25 HP) that meets all the emission standards for emergency engines in &sect;60.4202 but does not meet all the emission standards for non-emergency engines in &sect;60.4201. The label must be added according to the labeling requirements specified in 40 CFR 1039.135(b). Engine manufacturers must specify in the owner's manual that operation of emergency engines is limited to emergency operations and required maintenance and testing.
(g) Manufacturers of fire pump engines may use the test cycle in table 6 to this subpart for testing fire pump engines and may test at the NFPA certified nameplate HP, provided that the engine is labeled as "Fire Pump Applications Only".
(h) Engine manufacturers, including importers, may introduce into commerce uncertified engines or engines certified to earlier standards that were manufactured before the new or changed standards took effect until inventories are depleted, as long as such engines are part of normal inventory. For example, if the engine manufacturers' normal industry practice is to keep on hand a one-month supply of engines based on its projected sales, and a new tier of standards starts to apply for the 2009 model year, the engine manufacturer may manufacture engines based on the normal inventory requirements late in the 2008 model year, and sell those engines for installation. The engine manufacturer may not circumvent the provisions of
&sect;&sect;60.4201 or 60.4202 by stockpiling engines that are built before new or changed standards take effect. Stockpiling of such engines beyond normal industry practice is a violation of this subpart.
(i) The replacement engine provisions of 40 CFR 89.1003(b)(7), 40 CFR 94.1103(b)(3), 40 CFR 94.1103(b)(4) and 40 CFR&#xfd; 1068.240 are applicable to stationary CI engines replacing existing equipment that is less than 15 years old.
&sect; 60.4211 What are my compliance requirements if I am an owner or operatorof a stationaryCI internalcombustion engine?
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APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) If you are an owner or operator and must comply with the emission standards specified in this subpart, you must operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer. In addition, owners and operators may only change those settings that are permitted by the manufacturer. You must also meet the requirements of 40 CFR parts 89, 94 and/or 1068, as they apply to you.
(b) If you are an owner or operator of a pre-2007 model year stationary CI internal combustion engine and must comply with the emission standards specified in &sect;&sect;60.4204(a) or 60.4205(a), or if you are an owner or operator of a CI fire pump engine that is manufactured prior to the model years in table 3 to this subpart and must comply with the emission standards specified in &sect;60.4205(c), you must demonstrate compliance according to one of the methods specified in paragraphs (b)(1) through (5) of this section.
(1) Purchasing an engine certified according to 40 CFR part 89 or 40 CFR part 94, as applicable, for the same model year and maximum engine power. The engine must be installed and configured according to the manufacturer's specifications.
(2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly.
(2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly.
(3) Keeping records of engine manufacturer data indicating compliance with the standards.
(3) Keeping records of engine manufacturer data indicating compliance with the standards.
(4) Keeping records of control device vendor data indicating compliance with the standards.
(4) Keeping records of control device vendor data indicating compliance with the standards.
(5) Conducting an initial performance test to demonstrate compliance with the emission standards according to the requirements specified in &sect;60.4212, as applicable.(c) If you are an owner or operator of a 2007 model year and later stationary CI internal combustion engine and must comply with the emission standards specified in &sect;60.4204(b) or &sect;60.4205(b), or if you are an owner or operator of a CI fire pump engine that is manufactured during or after the model year that applies to your fire pump engine power rating in table 3 to this subpart and must comply with the emission standards specified in &sect;60.4205(c), you must comply by purchasing an engine certified to the emission standards in &sect;60.4204(b), or &sect;60.4205(b) or (c), as applicable, for the same model year and maximum (or in the case of fire pumps, NFPA nameplate) engine power. The engine must be installed and configured according to the manufacturer's specifications.(d) If you are an owner or operator and must comply with the emission standards specified in &sect;60.4204(c) or &sect;60.4205(d), you must demonstrate compliance according to the requirements specified in paragraphs (d)(1) through (3) of this section.(1) Conducting an initial performance test to demonstrate initial compliance with the emission standards as specified in&sect;60.4213.(2) Establishing operating parameters to be monitored continuously to ensure the stationary internal combustion engine continues to meet the emission standards.
(5) Conducting an initial performance test to demonstrate compliance with the emission standards according to the requirements specified in &sect;60.4212, as applicable.
The owner or operator must petition the Administrator for approval of operating parameters to be monitored continuously.
(c) If you are an owner or operator of a 2007 model year and later stationary CI internal combustion engine and must comply with the emission standards specified in &sect;60.4204(b) or &sect;60.4205(b), or if you are an owner or operator of a CI fire pump engine that is manufactured during or after the model year that applies to your fire pump engine power rating in table 3 to this subpart and must comply with the emission standards specified in &sect;60.4205(c), you must comply by purchasing an engine certified to the emission standards in &sect;60.4204(b), or &sect;60.4205(b) or (c), as applicable, for the same model year and maximum (or in the case of fire pumps, NFPA nameplate) engine power. The engine must be installed and configured according to the manufacturer's specifications.
The petition must include the information described in paragraphs (d)(2)(i) through (v) of this section.(i) Identification of the specific parameters you propose to monitor continuously;(ii) A discussion of the relationship between these parameters and NOxand PM emissions, identifying how the emissions of these pollutants change with changes in these parameters, and how limitations on these parameters will serve to limit NOxand PM emissions;(iii) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations;(iv) A discussion identifying the methods and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (v) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters.
(d) If you are an owner or operator and must comply with the emission standards specified in &sect;60.4204(c) or &sect;60.4205(d),
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-7 of 19 APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (3) For non-emergency engines with a displacement of greater than or equal to 30 liters per cylinder, conducting annual performance tests to demonstrate continuous compliance with the emission standards as specified in &sect;60.4213.(e) Emergency stationary ICE may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State, or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. There is no time limit on the use of emergency stationary ICE in emergency situations.
you must demonstrate compliance according to the requirements specified in paragraphs (d)(1) through (3) of this section.
Anyone may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency ICE beyond 100 hours per year. For owners and operators of emergency engines meeting standards under&sect;60.4205 but not &sect;60.4204, any operation other than emergency operation, and maintenance and testing as permitted in this section, is prohibited.
(1) Conducting an initial performance test to demonstrate initial compliance with the emission standards as specified in
Testing Requirements for Owners and Operators&sect; 60.4212 What test methods and other procedures must I use if I am an owner or operator of a stationary CI internal combustion engine with a displacement of less than 30 liters per cylinder?Owners and operators of stationary CI ICE with a displacement of less than 30 liters per cylinder who conduct performance tests pursuant to this subpart must do so according to paragraphs (a) through (d) of this section.(a) The performance test must be conducted according to the in-use testing procedures in 40 CFR part 1039, subpart F.(b) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR part 1039 must not exceed the not-to-exceed (NTE) standards for the same model year and maximum engine power as required in 40 CFR 1039.101(e) and 40 CFR 1039.102(g)(1), except as specified in 40 CFR 1039.104(d).
&sect;60.4213.
This requirement starts when NTE requirements take effect for nonroad diesel engines under 40 CFR part 1039.(c) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8, as applicable, must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in 40 CFR 89.112 or 40 CFR 94.8, as applicable, determined from the following equation: NTE requirem eit for each pollutant  
(2) Establishing operating parameters to be monitored continuously to ensure the stationary internal combustion engine continues to meet the emission standards. The owner or operator must petition the Administrator for approval of operating parameters to be monitored continuously. The petition must include the information described in paragraphs (d)(2)(i) through (v) of this section.
= (1 .25) x (STD) (Ecq. 1)Where: STD = The standard specified for that pollutant in 40 CFR 89.112 or 40 CFR 94.8, as applicable.
(i) Identification of the specific parameters you propose to monitor continuously; (ii) A discussion of the relationship between these parameters and NOxand PM emissions, identifying how the emissions of these pollutants change with changes in these parameters, and how limitations on these parameters will serve to limit NOxand PM emissions; (iii) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations; (iv) A discussion identifying the methods and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (v) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters.
Alternatively, stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8 may follow the testing procedures specified in &sect;60.4213 of this subpart, as appropriate.(d) Exhaust emissions from stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c) must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c), determined from the equation in paragraph (c) of this section.Where: STD = The standard specified for that pollutant in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c).
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Alternatively, stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in&sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c) may follow the testing procedures specified in &sect;60.4213, as appropriate.
 
&sect; 60.4213 What test methods and other procedures must I use if I am an owner or operator of a stationary CI internal combustion engine with a displacement of greater than or equal to 30 liters per cylinder?Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-8 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Owners and operators of stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must conduct performance tests according to paragraphs (a) through (d) of this section.(a) Each performance test must be conducted according to the requirements in &sect;60.8 and under the specific conditions that this subpart specifies in table 7. The test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load.(b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;60.8(c).(c) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;60.8(f).
APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (3) For non-emergency engines with a displacement of greater than or equal to 30 liters per cylinder, conducting annual performance tests to demonstrate continuous compliance with the emission standards as specified in &sect;60.4213.
Each test run must last at least 1 hour.(d) To determine compliance with the percent reduction requirement, you must follow the requirements as specified in paragraphs (d)(1) through (3) of this section.(1) You must use Equation 2 of this section to determine compliance with the percent reduction requirement:
(e) Emergency stationary ICE may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State, or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. There is no time limit on the use of emergency stationary ICE in emergency situations. Anyone may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency ICE beyond 100 hours per year. For owners and operators of emergency engines meeting standards under
C-C* x 100=R (Eq. 2)Ci Where: C 1 = concentration of NOx or PM at the control device inlet, Co = concentration of NOx or PM at the control device outlet, and R = percent reduction of NOx or PM emissions.
&sect;60.4205 but not &sect;60.4204, any operation other than emergency operation, and maintenance and testing as permitted in this section, is prohibited.
(2) You must normalize the NOx or PM concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen (02) using Equation 3 of this section, or an equivalent percent carbon dioxide (C0 2) using the procedures described in paragraph (d)(3) of this section.5.9 Caj = C' 5.9(Eq. 3)20.9 -%0O2 Where: Cadj = Calculated NOx or PM concentration adjusted to 15 percent 02.Cd = Measured concentration of NOx or PM, uncorrected.
Testing Requirementsfor Owners and Operators
5.9 = 20.9 percent 02-15 percent 02, the defined O 2 correction value, percent.%02= Measured O 2 concentration, dry basis, percent.(3) If pollutant concentrations are to be corrected to 15 percent O 2 and CO 2 concentration is measured in lieu of O 2 concentration measurement, a CO 2 correction factor is needed. Calculate the CO 2 correction factor as described in paragraphs (d)(3)(i) through (iii) of this section.(i) Calculate the fuel-specific F 0 value for the fuel burned during the test using values obtained from Method 19, Section 5.2, and the following equation:F. -&#xfd; (Eq. 4)Where: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-9 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Fo= Fuel factor based on the ratio of O 2 volume to the ultimate C0 2 volume produced by the fuel at zero percent excess air.0.209 = Fraction of air that is 02, percent/100.
&sect; 60.4212 What test methods and otherprocedures must I use if I am an owner or operatorof a stationary CI internal combustion engine with a displacementof less than 30 liters per cylinder?
Fd= Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).F,= Ratio of the volume of C0 2 produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).(ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent 02, as follows: 5.9-(Eq. 5 Where: Xco2= C0 2 correction factor, percent.5.9 = 20.9 percent 02-15 percent 02, the defined O 2 correction value, percent.(iii) Calculate the NOx and PM gas concentrations adjusted to 15 percent O 2 using CO 2 as follows:= C. -- (Eq. 6)%C0 2 Where: Cadj = Calculated NOx or PM concentration adjusted to 15 percent 02.Cd = Measured concentration of NOx or PM, uncorrected.
Owners and operators of stationary CI ICE with a displacement of less than 30 liters per cylinder who conduct performance tests pursuant to this subpart must do so according to paragraphs (a) through (d) of this section.
%C0 2= Measured C0 2 concentration, dry basis, percent.(e) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 7 of this section: ER = C.x 1.912 x 10-3 x Q x T (Eq- 7)KW-hoi(Where: ER = Emission rate in grams per KW-hour.Cd = Measured NOx concentration in ppm.1.912x10-3= Conversion constant for ppm NOx to grams per standard cubic meter at 25 degrees Celsius.Q = Stack gas volumetric flow rate, in standard cubic meter per hour.T = Time of test run, in hours.KW-hour = Brake work of the engine, in KW-hour.(f) To determine compliance with the PM mass per unit output emission limitation, convert the concentration of PM in the engine exhaust using Equation 8 of this section: ER = 4x Q x T KW-hour Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-10 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Where: ER = Emission rate in grams per KW-hour.C~dj = Calculated PM concentration in grams per standard cubic meter.Q = Stack gas volumetric flow rate, in standard cubic meter per hour.T = Time of test run, in hours.KW-hour = Energy output of the engine, in KW.Notification, Reports, and Records for Owners and Operators&sect; 60.4214 What are my notification, reporting, and recordkeeping requirements if I am an owner or operator of a stationary CI internal combustion engine?(a) Owners and operators of non-emergency stationary CI ICE that are greater than 2,237 KW (3,000 HP), or have a displacement of greater than or equal to 10 liters per cylinder, or are pre-2007 model year engines that are greater than 130 KW (175 HP) and not certified, must meet the requirements of paragraphs (a)(1) and (2) of this section.(1) Submit an initial notification as required in &sect;60.7(a)(1).
(a) The performance test must be conducted according to the in-use testing procedures in 40 CFR part 1039, subpart F.
The notification must include the information in paragraphs (a)(1)(i) through (v) of this section.(i) Name and address of the owner or operator;(ii) The address of the affected source;(iii) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement;(iv) Emission control equipment; and (v) Fuel used.(2) Keep records of the information in paragraphs (a)(2)(i) through (iv) of this section.(i) All notifications submitted to comply with this subpart and all documentation supporting any notification.(ii) Maintenance conducted on the engine.(iii) If the stationary CI internal combustion is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards.(iv) If the stationary CI internal combustion is not a certified engine, documentation that the engine meets the emission standards.(b) If the stationary CI internal combustion engine is an emergency stationary internal combustion engine, the owner or operator is not required to submit an initial notification.
(b) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR part 1039 must not exceed the not-to-exceed (NTE) standards for the same model year and maximum engine power as required in 40 CFR 1039.101(e) and 40 CFR 1039.102(g)(1), except as specified in 40 CFR 1039.104(d). This requirement starts when NTE requirements take effect for nonroad diesel engines under 40 CFR part 1039.
Starting with the model years in table 5 to this subpart, if the emergency engine does not meet the standards applicable to non-emergency engines in the applicable model year, the owner or operator must keep records of the operation of the engine in emergency and non-emergency service that are recorded through the non-resettable hour meter. The owner must record the time of operation of the engine and the reason the engine was in operation during that time.(c) If the stationary CI internal combustion engine is equipped with a diesel particulate filter, the owner or operator must keep records of any corrective action taken after the backpressure monitor has notified the owner or operator that the high backpressure limit of the engine is approached.
(c) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8, as applicable, must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in 40 CFR 89.112 or 40 CFR 94.8, as applicable, determined from the following equation:
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NTE requirem eit for each pollutant = (1 .25) x (STD)       (Ecq. 1)
&sect; 60.4215 What requirements must I meet for engines used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands?(a) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are required to meet the applicable emission standards in &sect;60.4205.
Where:
Non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder, must meet the applicable emission standards in &sect;60.4204(c).(b) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are not required to meet the fuel requirements in &sect;60.4207.&sect; 60.4216 What requirements must I meet for engines used in Alaska?(a) Prior to December 1, 2010, owners and operators of stationary CI engines located in areas of Alaska not accessible by the Federal Aid Highway System should refer to 40 CFR part 69 to determine the diesel fuel requirements applicable to such engines.(b) The Governor of Alaska may submit for EPA approval, by no later than January 11, 2008, an alternative plan for implementing the requirements of 40 CFR part 60, subpart IIII, for public-sector electrical utilities located in rural areas of Alaska not accessible by the Federal Aid Highway System. This alternative plan must be based on the requirements of section 111 of the Clean Air Act including any increased risks to human health and the environment and must also be based on the unique circumstances related to remote power generation, climatic conditions, and serious economic impacts resulting from implementation of 40 CFR part 60, subpart II. If EPA approves by rulemaking process an alternative plan, the provisions as approved by EPA under that plan shall apply to the diesel engines used in new stationary internal combustion engines subject to this paragraph.
STD = The standard specified for that pollutant in 40 CFR 89.112 or 40 CFR 94.8, as applicable.
&sect; 60.4217 What emission standards must I meet ifI am an owner or operator of a stationary internal combustion engine using specialfuels?(a) Owners and operators of stationary CI ICE that do not use diesel fuel, or who have been given authority by the Administrator under &sect;60.4207(d) of this subpart to use fuels that do not meet the fuel requirements of paragraphs (a) and (b)of &sect;60.4207, may petition the Administrator for approval of alternative emission standards, if they can demonstrate that they use a fuel that is not the fuel on which the manufacturer of the engine certified the engine and that the engine cannot meet the applicable standards required in &sect;60.4202 or &sect;60.4203 using such fuels.(b) [Reserved]
Alternatively, stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8 may follow the testing procedures specified in &sect;60.4213 of this subpart, as appropriate.
General Provisions
(d) Exhaust emissions from stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c) must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c), determined from the equation in paragraph (c) of this section.
&sect; 60.4218 What parts of the General Provisions apply to me?Table 8 to this subpart shows which parts of the General Provisions in &sect;&sect;60.1 through 60.19 apply to you.Definitions
Where:
&sect; 60.4219 What definitions apply to this subpart?As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part.Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page IIII-12 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.Diesel fuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil.Diesel particulate filter means an emission control technology that reduces PM emissions by trapping the particles in a flow filter substrate and periodically removes the collected particles by either physical action or by oxidizing (burning off) the particles in a process called regeneration.
STD = The standard specified for that pollutant in &sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c).
Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance.
Alternatively, stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in
Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary CI ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines.Engine manufacturer means the manufacturer of the engine. See the definition of "manufacturer" in this section.Fire pump engine means an emergency stationary internal combustion engine certified to NFPA requirements that is used to provide power to pump water for fire suppression or protection.
&sect;60.4204(a), &sect;60.4205(a), or &sect;60.4205(c) may follow the testing procedures specified in &sect;60.4213, as appropriate.
Manufacturer has the meaning given in section 216(1) of the Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for sale or resale.Maximum engine power means maximum engine power as defined in 40 CFR 1039.801.Model year means either: (1) The calendar year in which the engine was originally produced, or (2) The annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced.Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine.Reciprocating internal combustion engine means any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work.Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work.Spark ignition means relating to a gasoline, natural gas, or liquefied petroleum gas fueled engine or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation.
&sect; 60.4213 What test methods and otherproceduresmust I use if I am an owner or operatorof a stationaryCI internal combustion engine with a displacementof greaterthan or equal to 30 liters per cylinder?
Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.Stationary internal combustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition.
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Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-13 of 19 APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart IIII.Useful life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for useful life for stationary CI ICE with a displacement of less than 10 liters per cylinder are given in 40 CFR 1039.101(g).
 
The values for useful life for stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder are given in 40 CFR 94.9(a).Table 1 to Subpart IIII of Part 60-Emission Standards for Stationary Pre-2007 Model Year Engines With a Displacement of <10 Liters per Cylinder and 2007-2010 Model Year Engines >2,237 KW (3,000 HP) and With a Displacement of <10 Liters per Cylinder[As stated in &sect;&sect;60.4201(b), 60.4202(b), 60.4204(a), and 60.4205(a), you must comply with the following emission standards]
APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Owners and operators of stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must conduct performance tests according to paragraphs (a) through (d) of this section.
Emission standards for stationary pre-2007 model year engines with a displacement of <10 liters per cylinder and 2007-2010 model year engines >2,237 KW (3,000 HP) and with a displacement of Maximum engine <10 liters per cylinder in g/KW-hr (g/HP-hr)power NMHC + NOx HC NOx CO PM KW<8 (HP< 11) 10.5 (7.8) 8.0 (6.0) 1.0 (0.75)8_<KW<19 9.5 (7.1) 6.6 (4.9) 0.80 (0.60)(1 1<HP<25)19_<KW<37 9.5 (7.1) 5.5 (4.1) 0.80 (0.60)(25<HP<50) 37<KW<56 9.2 (6.9)(50<HP<75) 56<KW<75 9.2 (6.9)(75<HP<100) 75<KW<130 9.2 (6.9)(100<HP<175) 130<KW<225 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54 (0.40)(175<HP<300) 225<KW<450 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54(0.40)
(a) Each performance test must be conducted according to the requirements in &sect;60.8 and under the specific conditions that this subpart specifies in table 7. The test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load.
(300<HP<600) 450<KW<560 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54(0.40)
(b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;60.8(c).
(c) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;60.8(f). Each test run must last at least 1 hour.
(d) To determine compliance with the percent reduction requirement, you must follow the requirements as specified in paragraphs (d)(1) through (3) of this section.
(1) You must use Equation 2 of this section to determine compliance with the percent reduction requirement:
C-C* x 100=R               (Eq. 2)
Ci Where:
C1 = concentration of NOx or PM at the control device inlet, Co = concentration of NOx or PM at the control device outlet, and R = percent reduction of NOx or PM emissions.
(2) You must normalize the NOx or PM concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen (02) using Equation 3 of this section, or an equivalent percent carbon dioxide (C0 2) using the procedures described in paragraph (d)(3) of this section.
5.9 Caj = C' 20.9 5.9(Eq.
                - %0O2             3)
Where:
Cadj = Calculated NOx or PM concentration adjusted to 15 percent       02.
Cd = Measured concentration of NOx or PM, uncorrected.
5.9 = 20.9 percent 02-15 percent     02, the defined O 2correction value, percent.
%02=   Measured O2 concentration, dry basis, percent.
(3) If pollutant concentrations are to be corrected to 15 percent O 2and CO 2 concentration is measured in lieu of O2concentration measurement, a CO 2 correction factor is needed. Calculate the CO 2correction factor as described in paragraphs (d)(3)(i) through (iii) of this section.
(i) Calculate the fuel-specific F0 value for the fuel burned during the test using values obtained from Method 19, Section 5.2, and the following equation:
0.209*
F. -       &#xfd;       (Eq. 4)
Where:
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APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Fo= Fuel factor based on the ratio of O 2 volume to the ultimate C0 2volume produced by the fuel at zero percent excess air.
0.209 = Fraction of air that is 02, percent/100.
Fd= Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).
F,= Ratio of the volume of C0 2produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).
(ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent 02, as follows:
5.9
            -       (Eq. 5 Where:
Xco2= C0 2correction factor, percent.
5.9 = 20.9 percent 02-15 percent 02, the defined O 2correction value, percent.
(iii) Calculate the NOx and PM gas concentrations adjusted to 15 percent O2 using CO 2as follows:
      = C.     --       (Eq. 6)
              %C0 2 Where:
Cadj = Calculated NOx or PM concentration adjusted to 15 percent 02.
Cd = Measured concentration of NOx or PM, uncorrected.
%C0 2= Measured C0 2concentration, dry basis, percent.
(e) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 7 of this section:
ER = C.x 1.912 x 10-3 x Q x T               (Eq- 7)
KW-hoi(
Where:
ER   = Emission   rate in grams per KW-hour.
Cd =   Measured NOx concentration in ppm.
1.912x10- 3= Conversion constant for ppm NOx to grams per standard cubic meter at 25 degrees Celsius.
Q = Stack gas volumetric flow rate, in standard cubic meter per hour.
T = Time of test run, in hours.
KW-hour = Brake work of the engine, in KW-hour.
(f) To determine compliance with the PM mass per unit output emission limitation, convert the concentration of PM in the engine exhaust using Equation 8 of this section:
ER   =     4x Q x T KW-hour Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page 1111-10 of 19
 
APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Where:
ER = Emission rate in grams per KW-hour.
C~dj =   Calculated PM concentration in grams per standard cubic meter.
Q = Stack gas volumetric flow rate, in standard cubic meter per hour.
T = Time of test run, in hours.
KW-hour = Energy output of the engine, in KW.
Notification, Reports, and Recordsfor Owners and Operators
&sect; 60.4214 What are my notification, reporting,and recordkeepingrequirements if I am an owner or operatorof a stationary CI internalcombustion engine?
(a) Owners and operators of non-emergency stationary CI ICE that are greater than 2,237 KW (3,000 HP), or have a displacement of greater than or equal to 10 liters per cylinder, or are pre-2007 model year engines that are greater than 130 KW (175 HP) and not certified, must meet the requirements of paragraphs (a)(1) and (2) of this section.
(1) Submit an initial notification as required in &sect;60.7(a)(1). The notification must include the information in paragraphs (a)(1)(i) through (v) of this section.
(i) Name and address of the owner or operator; (ii) The address of the affected source; (iii) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (iv) Emission control equipment; and (v) Fuel used.
(2) Keep records of the information in paragraphs (a)(2)(i) through (iv) of this section.
(i) All notifications submitted to comply with this subpart and all documentation supporting any notification.
(ii) Maintenance conducted on the engine.
(iii) If the stationary CI internal combustion is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards.
(iv) If the stationary CI internal combustion is not a certified engine, documentation that the engine meets the emission standards.
(b) If the stationary CI internal combustion engine is an emergency stationary internal combustion engine, the owner or operator is not required to submit an initial notification. Starting with the model years in table 5 to this subpart, if the emergency engine does not meet the standards applicable to non-emergency engines in the applicable model year, the owner or operator must keep records of the operation of the engine in emergency and non-emergency service that are recorded through the non-resettable hour meter. The owner must record the time of operation of the engine and the reason the engine was in operation during that time.
(c) If the stationary CI internal combustion engine is equipped with a diesel particulate filter, the owner or operator must keep records of any corrective action taken after the backpressure monitor has notified the owner or operator that the high backpressure limit of the engine is approached.
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APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines SpecialRequirements
&sect; 60.4215 What requirements must I meetfor engines used in Guam, American Samoa, or the Commonwealth of the Northern MarianaIslands?
(a) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are required to meet the applicable emission standards in &sect;60.4205. Non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder, must meet the applicable emission standards in &sect;60.4204(c).
(b) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are not required to meet the fuel requirements in &sect;60.4207.
&sect; 60.4216 What requirements must I meet for engines used in Alaska?
(a) Prior to December 1, 2010, owners and operators of stationary CI engines located in areas of Alaska not accessible by the Federal Aid Highway System should refer to 40 CFR part 69 to determine the diesel fuel requirements applicable to such engines.
(b) The Governor of Alaska may submit for EPA approval, by no later than January 11, 2008, an alternative plan for implementing the requirements of 40 CFR part 60, subpart IIII, for public-sector electrical utilities located in rural areas of Alaska not accessible by the Federal Aid Highway System. This alternative plan must be based on the requirements of section 111 of the Clean Air Act including any increased risks to human health and the environment and must also be based on the unique circumstances related to remote power generation, climatic conditions, and serious economic impacts resulting from implementation of 40 CFR part 60, subpart II. If EPA approves by rulemaking process an alternative plan, the provisions as approved by EPA under that plan shall apply to the diesel engines used in new stationary internal combustion engines subject to this paragraph.
&sect; 60.4217 What emission standardsmust I meet ifI am an owner or operatorof a stationaryinternalcombustion engine using specialfuels?
(a) Owners and operators of stationary CI ICE that do not use diesel fuel, or who have been given authority by the Administrator under &sect;60.4207(d) of this subpart to use fuels that do not meet the fuel requirements of paragraphs (a) and (b) of &sect;60.4207, may petition the Administrator for approval of alternative emission standards, if they can demonstrate that they use a fuel that is not the fuel on which the manufacturer of the engine certified the engine and that the engine cannot meet the applicable standards required in &sect;60.4202 or &sect;60.4203 using such fuels.
(b) [Reserved]
GeneralProvisions
&sect; 60.4218 What parts of the General Provisionsapply to me?
Table 8 to this subpart shows which parts of the General Provisions in &sect;&sect;60.1 through 60.19 apply to you.
Definitions
&sect; 60.4219 What definitions apply to this subpart?
As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part.
Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system.
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APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.
Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil.
Diesel particulatefilter means an emission control technology that reduces PM emissions by trapping the particles in a flow filter substrate and periodically removes the collected particles by either physical action or by oxidizing (burning off) the particles in a process called regeneration.
Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary CI ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines.
Engine manufacturermeans the manufacturer of the engine. See the definition of "manufacturer" in this section.
Firepump engine means an emergency stationary internal combustion engine certified to NFPA requirements that is used to provide power to pump water for fire suppression or protection.
Manufacturerhas the meaning given in section 216(1) of the Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for sale or resale.
Maximum engine power means maximum engine power as defined in 40 CFR 1039.801.
Model year means either:
(1) The calendar year in which the engine was originally produced, or (2) The annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced.
Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine.
Reciprocatinginternal combustion engine means any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work.
Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work.
Spark ignition means relating to a gasoline, natural gas, or liquefied petroleum gas fueled engine or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.
Stationary internalcombustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition. Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines.
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APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart IIII.
Useful life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for useful life for stationary CI ICE with a displacement of less than 10 liters per cylinder are given in 40 CFR 1039.101(g). The values for useful life for stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder are given in 40 CFR 94.9(a).
Table 1 to SubpartIIII of Part60-Emission Standardsfor StationaryPre-2007Model Year Engines With a Displacementof <10 Liters per Cylinder and 2007-2010 Model Year Engines >2,237 KW (3,000 HP)and With a Displacement of <10 Liters per Cylinder
[As stated in &sect;&sect;60.4201(b), 60.4202(b), 60.4204(a), and 60.4205(a), you must comply with the following emission standards]
Emission standards for stationary pre-2007 model year engines with a displacement of <10 liters per cylinder and 2007-2010 model year engines >2,237 KW (3,000 HP) and with a displacement of Maximum engine                                       <10 liters per cylinder in g/KW-hr (g/HP-hr) power                 NMHC + NOx                       HC             NOx               CO                   PM KW<8 (HP<11)                                 10.5 (7.8)                                             8.0 (6.0)           1.0 (0.75) 8_<KW<19                                     9.5 (7.1)                                             6.6 (4.9)         0.80 (0.60)
(1 1<HP<25) 19_<KW<37                                     9.5 (7.1)                                             5.5 (4.1)         0.80 (0.60)
(25<HP<50) 37<KW<56                                                                           9.2 (6.9)
(50<HP<75) 56<KW<75                                                                           9.2 (6.9)
(75<HP<100) 75<KW<130                                                                         9.2 (6.9)
(100<HP<175) 130<KW<225                                                       1.3 (1.0)       9.2 (6.9)       11.4 (8.5)           0.54 (0.40)
(175<HP<300) 225<KW<450                                                       1.3 (1.0)       9.2 (6.9)       11.4 (8.5)           0.54(0.40)
(300<HP<600) 450<KW<560                                                       1.3 (1.0)       9.2 (6.9)       11.4 (8.5)           0.54(0.40)
(600<HP<750)
(600<HP<750)
KW>560 (HP>750) 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54 (0.40)Table 2 to Subpart IIII of Part 60-Emission Standards for 2008 Model Year
KW>560 (HP>750)                                                  1.3 (1.0)        9.2 (6.9)        11.4 (8.5)          0.54 (0.40)
Table 2 to SubpartIIII of Part60-Emission Standardsfor 2008 Model Year and LaterEmergency Stationary CI ICE
<37 KW (50 HP) With a Displacement of <10 Liters per Cylinder
[As stated in &sect;60.4202(a)(1), you must comply with the following emission standards]
Emission standards for 2008 model year and later emergency stationary CI ICE <37 KW (50 HP) with a displacement of <10 liters per cylinder in g/KW-hr (g/HP-hr)
Engine power                Model year(s)                      NOx+ NMHC                    CO                    PM KW<8 (HP<1 1)                                    2008+][                      7.5 (5.6)1        8.0 (6.0)            0.40 (0.30)
_8<_KW<19                                        2008+11                      7.5 (5.6)        6.6 (419)              0.4. (0.3
(2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly.
(2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly.
(3) Keeping records of engine manufacturer data indicating compliance with the standards.
(3) Keeping records of engine manufacturer data indicating compliance with the standards.
(4) Keeping records of control device vendor data indicating compliance with the standards.
(4) Keeping records of control device vendor data indicating compliance with the standards.
Testing Requirements for Owners and Operators&sect; 60.4244 What test methods and other procedures must I use if I am an owner or operator of a stationary SI internal combustion engine?Owners and operators of stationary SI ICE who conduct performance tests must follow the procedures in paragraphs (a)through (f) of this section.(a) Each performance test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and according to the requirements in &sect;60.8 and under the specific conditions that are specified by Table 2 to this subpart.(b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;60.8(c).
Testing Requirementsfor Owners and Operators
If your stationary SI internal combustion engine is non-operational, you do not need to startup the engine solely to conduct a performance test; however, you must conduct the performance test immediately upon startup of the engine.(c) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;60.8(f).
&sect; 60.4244 What test methods and otherprocedures must I use if I am an owner or operatorof a stationarySI internal combustion engine?
Each test run must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and last at least 1 hour.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-10 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (d) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 1 of this section: ER-Cax 1.912 x 10-3x Q x T HP -hr Where: ER = Emission rate of NOx in g/HP-hr.Cd = Measured NOx concentration in parts per million by volume (ppmv).1.912x10-3 = Conversion constant for ppm NOx to grams per standard cubic meter at 20 degrees Celsius.Q = Stack gas volumetric flow rate, in standard cubic meter per hour, dry basis.T = Time of test run, in hours.HP-hr = Brake work of the engine, horsepower-hour (HP-hr).(e) To determine compliance with the CO mass per unit output emission limitation, convert the concentration of CO in the engine exhaust using Equation 2 of this section: ER = Ca x 1.164 x 10-3 x Q x T HP -hr Where: ER = Emission rate of CO in g/HP-hr.Cd = Measured CO concentration in ppmv.1.164x10-3 = Conversion constant for ppm CO to grams per standard cubic meter at 20 degrees Celsius.Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis.T = Time of test run, in hours.HP-hr = Brake work of the engine, in HP-hr.(f) For purposes of this subpart, when calculating emissions of VOC, emissions of formaldehyde should not be included.
Owners and operators of stationary SI ICE who conduct performance tests must follow the procedures in paragraphs (a) through (f) of this section.
To determine compliance with the VOC mass per unit output emission limitation, convert the concentration of VOC in the engine exhaust using Equation 3 of this section: ER= Ca x 1.833 x 10-3x Q x T HP-hr(Eq.
(a) Each performance test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and according to the requirements in &sect;60.8 and under the specific conditions that are specified by Table 2 to this subpart.
3)HP -hr Where: ER = Emission rate of VOC in g/HP-hr.Cd = VOC concentration measured as propane in ppmv.1.833x 10-3 = Conversion constant for ppm VOC measured as propane, to grams per standard cubic meter at 20 degrees Celsius.Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-1 1 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines T = Time of test run, in hours.HP-hr = Brake work of the engine, in HP-hr.(g) If the owner/operator chooses to measure VOC emissions using either Method 18 of 40 CFR part 60, appendix A, or Method 320 of 40 CFR part 63, appendix A, then it has the option of correcting the measured VOC emissions to account for the potential differences in measured values between these methods and Method 25A. The results from Method 18 and Method 320 can be corrected for response factor differences using Equations 4 and 5 of this section. The corrected VOC concentration can then be placed on a propane basis using Equation 6 of this section.C RF&#xfd; -E q -4)CkM Where: RFi = Response factor of compound i when measured with EPA Method 25A.CMi = Measured concentration of compound i in ppmv as carbon.CAi = True concentration of compound i in ppmv as carbon.C,_ RFCixC (Eq. 5)Where: Cicorr = Concentration of compound i corrected to the value that would have been measured by EPA Method 25A, ppmv as carbon.Cimeas = Concentration of compound i measured by EPA Method 320, ppmv as carbon.Cr,: 0.6098 xCi. (Eq. 6)Where: CPeq = Concentration of compound i in mg of propane equivalent per DSCM.Notification, Reports, and Records for Owners and Operators&sect; 60.4245 What are my notification, reporting, and recordkeeping requirements if Iam an owner or operator of a stationary SI internal combustion engine?Owners or operators of stationary SI ICE must meet the following notification, reporting and recordkeeping requirements.(a) Owners and operators of all stationary SI ICE must keep records of the information in paragraphs (a)(1) through (4) of this section.(1) All notifications submitted to comply with this subpart and all documentation supporting any notification.
(b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;60.8(c). If your stationary SI internal combustion engine is non-operational, you do not need to startup the engine solely to conduct a performance test; however, you must conduct the performance test immediately upon startup of the engine.
(2) Maintenance conducted on the engine.(3) If the stationary SI internal combustion engine is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards and information as required in 40 CFR parts 90, 1048, 1054, and 1060, as applicable.
(c) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;60.8(f). Each test run must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and last at least 1 hour.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page JJJJ-10 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (d) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 1 of this section:
ER-Cax       1.912 x 10-3x Q x T HP -hr Where:
ER = Emission rate of NOx in g/HP-hr.
Cd = Measured NOx concentration in parts per million by volume (ppmv).
1.912x10- 3 = Conversion constant for ppm NOx to grams per standard cubic meter at 20 degrees Celsius.
Q = Stack gas volumetric flow rate, in standard cubic meter per hour, dry basis.
T = Time of test run, in hours.
HP-hr = Brake work of the engine, horsepower-hour (HP-hr).
(e) To determine compliance with the CO mass per unit output emission limitation, convert the concentration of CO in the engine exhaust using Equation 2 of this section:
ER = Ca x 1.164 x 10-3 x Q x T HP -hr Where:
ER = Emission rate of CO in g/HP-hr.
Cd = Measured CO concentration in ppmv.
1.164x10- 3 = Conversion constant for ppm CO to grams per standard cubic meter at 20 degrees Celsius.
Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis.
T = Time of test run, in hours.
HP-hr = Brake work of the engine, in HP-hr.
(f) For purposes of this subpart, when calculating emissions of VOC, emissions of formaldehyde should not be included. To determine compliance with the VOC mass per unit output emission limitation, convert the concentration of VOC in the engine exhaust using Equation 3 of this section:
ER= Ca x 1.833HPx 3xHP-hr(Eq.
hr    Q xT            3)
Where:
ER = Emission rate of VOC in g/HP-hr.
Cd = VOC concentration measured as propane in ppmv.
1.833x 10- 3 = Conversion constant for ppm VOC measured as propane, to grams per standard cubic meter at 20 degrees Celsius.
Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis.
Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                           Title V Permit Renewal Page JJJJ-1 1 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines T = Time of test run, in hours.
HP-hr = Brake work of the engine, in HP-hr.
(g) If the owner/operator chooses to measure VOC emissions using either Method 18 of 40 CFR part 60, appendix A, or Method 320 of 40 CFR part 63, appendix A, then it has the option of correcting the measured VOC emissions to account for the potential differences in measured values between these methods and Method 25A. The results from Method 18 and Method 320 can be corrected for response factor differences using Equations 4 and 5 of this section. The corrected VOC concentration can then be placed on a propane basis using Equation 6 of this section.
RF&#xfd; - C          Eq-4)
CkM Where:
RFi = Response factor of compound i when measured with EPA Method 25A.
CMi = Measured concentration of compound i in ppmv as carbon.
CAi = True concentration of compound i in ppmv as carbon.
C,_     RFCixC         (Eq. 5)
Where:
Cicorr = Concentration of compound i corrected to the value that would have been measured by EPA Method 25A, ppmv as carbon.
Cimeas = Concentration of compound i measured by EPA Method 320, ppmv as carbon.
Cr,: 0.6098 xCi.           (Eq. 6)
Where:
CPeq = Concentration of compound i in mg of propane equivalent per DSCM.
Notification, Reports, and Records for Owners and Operators
&sect; 60.4245 What are my notification, reporting,and recordkeeping requirements if Iam an owner or operatorof a stationarySI internalcombustion engine?
Owners or operators of stationary SI ICE must meet the following notification, reporting and recordkeeping requirements.
(a) Owners and operators of all stationary SI ICE must keep records of the information in paragraphs (a)(1) through (4) of this section.
(1) All notifications submitted to comply with this subpart and all documentation supporting any notification.
(2) Maintenance conducted on the engine.
(3) If the stationary SI internal combustion engine is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards and information as required in 40 CFR parts 90, 1048, 1054, and 1060, as applicable.
(4) If the stationary SI internal combustion engine is not a certified engine or is a certified engine operating in a non-certified manner and subject to &sect;60.4243(a)(2), documentation that the engine meets the emission standards.
(4) If the stationary SI internal combustion engine is not a certified engine or is a certified engine operating in a non-certified manner and subject to &sect;60.4243(a)(2), documentation that the engine meets the emission standards.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-12 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (b) For all stationary SI emergency ICE greater than or equal to 500 HP manufactured on or after July 1, 2010, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than or equal to 130 HP and less than 500 HP manufactured on or after July 1, 2011 that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than 25 HP and less than 130 HP manufactured on or after July 1, 2008, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter.The owner or operator must document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non-emergency operation.(c) Owners and operators of stationary SI ICE greater than or equal to 500 HP that have not been certified by an engine manufacturer to meet the emission standards in &sect;60.4231 must submit an initial notification as required in &sect;60.7(a)(1).
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page JJJJ-12 of 21
The notification must include the information in paragraphs (c)(1) through (5) of this section.(1) Name and address of the owner or operator;(2) The address of the affected source;(3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used.(d) Owners and operators of stationary SI ICE that are subject to performance testing must submit a copy of each performance test as conducted in &sect;60.4244 within 60 days after the test has been completed.
 
[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]General Provisions
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (b) For all stationary SI emergency ICE greater than or equal to 500 HP manufactured on or after July 1, 2010, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than or equal to 130 HP and less than 500 HP manufactured on or after July 1, 2011 that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than 25 HP and less than 130 HP manufactured on or after July 1, 2008, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter.
&sect; 60.4246 What parts of the General Provisions apply to me?Table 3 to this subpart shows which parts of the General Provisions in &sect;&sect;60.1 through 60.19 apply to you.Mobile Source Provisions
The owner or operator must document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non-emergency operation.
&sect; 60.4247 What parts of the mobile source provisions apply to me if I am a manufacturer of stationary SI internal combustion engines or a manufacturer of equipment containing such engines?(a) Manufacturers certifying to emission standards in 40 CFR part 90, including manufacturers certifying emergency engines below 130 HP, must meet the provisions of 40 CFR part 90. Manufacturers certifying to emission standards in 40 CFR part 1054 must meet the provisions of 40 CFR part 1054. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060 to the extent they apply to equipment manufacturers.(b) Manufacturers required to certify to emission standards in 40 CFR part 1048 must meet the provisions of 40 CFR part 1048. Manufacturers certifying to emission standards in 40 CFR part 1048 pursuant to the voluntary certification program must meet the requirements in Table 4 to this subpart as well as the standards in 40 CFR 1048.101.(c) For manufacturers of stationary SI internal combustion engines participating in the voluntary certification program and certifying engines to Table I to this subpart, Table 4 to this subpart shows which parts of the mobile source provisions in 40 CFR parts 1048, 1065, and 1068 apply to you. Compliance with the deterioration factor provisions under 40 CFR 1048.205(n) and 1048.240 will be required for engines built new on and after January 1, 2010. Prior to January 1, 2010, Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ- 13 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines manufacturers of stationary internal combustion engines participating in the voluntary certification program have the option to develop their own deterioration factors based on an engineering analysis.[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]Definitions
(c) Owners and operators of stationary SI ICE greater than or equal to 500 HP that have not been certified by an engine manufacturer to meet the emission standards in &sect;60.4231 must submit an initial notification as required in &sect;60.7(a)(1). The notification must include the information in paragraphs (c)(1) through (5) of this section.
&sect; 60.4248 What definitions apply to this subpart?As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part.Certified emissions life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for certified emissions life for stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP) are given in 40 CFR 90.105, 40 CFR 1054.107, and 40 CFR 1060.101, as appropriate.
(1) Name and address of the owner or operator; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used.
The values for certified emissions life for stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) certified to 40 CFR part 1048 are given in 40 CFR 1048.101(g).
(d) Owners and operators of stationary SI ICE that are subject to performance testing must submit a copy of each performance test as conducted in &sect;60.4244 within 60 days after the test has been completed.
The certified emissions life for stationary SI ICE with a maximum engine power greater than 75 KW (100 HP) certified under the voluntary manufacturer certification program of this subpart is 5,000 hours or 7 years, whichever comes first.Certified stationary internal combustion engine means an engine that belongs to an engine family that has a certificate of conformity that complies with the emission standards and requirements in this part, or of 40 CFR part 90, 40 CFR part 1048, or 40 CFR part 1054, as appropriate.
[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]
Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system.Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.Diesel fuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil.Digester gas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and carbon dioxide (C02).Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance.
GeneralProvisions
Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary SI ICE used for peak shaving are not considered emergency stationary ICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines.Engine manufacturer means the manufacturer of the engine. See the definition of "manufacturer" in this section.Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution.
&sect; 60.4246 What parts of the General Provisionsapply to me?
Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline.Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-14 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich bum engine.Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production.
Table 3 to this subpart shows which parts of the General Provisions in &sect;&sect;60.1 through 60.19 apply to you.
Manufacturer has the meaning given in section 216(1) of the Clean Air Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for resale.Maximum engine power means maximum engine power as defined in 40 CFR 1048.801.Model year means either: The calendar year in which the engine was originally produced, or the annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year, and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced.Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality.Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine.Pipeline-quality natural gas means a naturally occurring fluid mixture of hydrocarbons (e.g., methane, ethane, or propane)produced in geological formations beneath the Earth's surface that maintains a gaseous state at standard atmospheric temperature and pressure under ordinary conditions, and which is provided by a supplier through a pipeline.
Mobile Source Provisions
Pipeline-quality natural gas must either be composed of at least 70 percent methane by volume or have a gross calorific value between 950 and 1,100 British thermal units per standard cubic foot.Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to June 12, 2006, with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich bum engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent.Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work.Spark ignition means relating to either: a gasoline-fueled engine; or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation.
&sect; 60.4247 What parts of the mobile source provisions apply to me if I am a manufacturerof stationarySI internal combustion engines or a manufacturer of equipment containingsuch engines?
Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.Stationary internal combustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition.
(a) Manufacturers certifying to emission standards in 40 CFR part 90, including manufacturers certifying emergency engines below 130 HP, must meet the provisions of 40 CFR part 90. Manufacturers certifying to emission standards in 40 CFR part 1054 must meet the provisions of 40 CFR part 1054. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060 to the extent they apply to equipment manufacturers.
Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines.Stationary internal combustion engine test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that test stationary ICE.Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion.
(b) Manufacturers required to certify to emission standards in 40 CFR part 1048 must meet the provisions of 40 CFR part 1048. Manufacturers certifying to emission standards in 40 CFR part 1048 pursuant to the voluntary certification program must meet the requirements in Table 4 to this subpart as well as the standards in 40 CFR 1048.101.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-15 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart JJJJ.Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric.
(c) For manufacturers of stationary SI internal combustion engines participating in the voluntary certification program and certifying engines to Table I to this subpart, Table 4 to this subpart shows which parts of the mobile source provisions in 40 CFR parts 1048, 1065, and 1068 apply to you. Compliance with the deterioration factor provisions under 40 CFR 1048.205(n) and 1048.240 will be required for engines built new on and after January 1, 2010. Prior to January 1, 2010, Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page JJJJ- 13 of 21
Volatile organic compounds means volatile organic compounds as defined in 40 CFR 5 1.100(s).Voluntary certification program means an optional engine certification program that manufacturers of stationary SI internal combustion engines with a maximum engine power greater than 19 KW (25 HP) that do not use gasoline and are not rich burn engines that use LPG can choose to participate in to certify their engines to the emission standards in &sect;60.4231(d) or (e), as applicable.
 
[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]Table I to Subpart JJJJ of Part 60-NOx, CO, and VOC Emission Standards for Stationary Non-Emergency SI Engines>100 HP (Except Gasoline and Rich Burn LPG), Stationary SI Landfill/Digester Gas Engines, and Stationary Emergency Engines >25 HP Emission Standards' ppmvd at 15%g/HP-hr ] 02 Maximum engine Manufacture irnr 02 Engine type and fuel power date N c CO FVO NOx O Non-Emergency SI Natural Gasb and Non- 100<HP<500 7/1/2008 2.0 4.0 1.0 160 540 86 Emergency SI Lean Burn LPG b 1/1/2011[
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines manufacturers of stationary internal combustion engines participating in the voluntary certification program have the option to develop their own deterioration factors based on an engineering analysis.
1.0 120 [ 0.7 82 270 60]Non-Emergency SI Lean Burn Natural Gas and 500>HP<1,350 1/1/20081 2.0 4. 0 1.0 1601 540 86 LPG 7/1/2010 1 1.0 1 3i 0.7 82 270] 60 Non-Emergency SI Natural Gas and Non- HP>500 7/1/2007 2.0 4.1 1.0 161 540 86 Emergency SI Lean Burn LPG (except lean burn HP2500 7/1/201007 82 270 60 500=>-HP<1,350)
[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]
Landfill/Digester Gas (except lean burn HP<500 7/1/20081 3.0 5.00 1.0 220 610 80 500>HP<1,350) 1/1/2011 2.0 [5.0 1.0] 150] 610 80 HP>s500 7/1/2007 3.0 5.0] 1.0 220] 610 80 7/1/2010 2.0 5.0] 1.0 150] 610 80 Landfill/Digester Gas Lean Burn 500>HP<1,350 1/1/20081 3]0[5.1 1.0 220] 610 80 7/1/201 0 5.0]1 1.01150] 610 80 Emergency 25>HP<130 1/1/2009 Cl 387 N/A N/A N/A N/A 1J2.0[4. 1.0 160] 540 86 HP> 130 1L aOwners and operators of stationary non-certified SI engines may choose to comply with the emission standards in units of either g/HP-hr or ppmvd at 15 percent 02.bOwners and operators of new or reconstructed non-emergency lean burn SI stationary engines with a site rating of greater than or equal to 250 brake HP located at a major source that are meeting the requirements of 40 CFR part 63, subpart ZZZZ, Table 2A do not have to comply with the CO emission standards of Table 1 of this subpart.cThe emission standards applicable to emergency engines between 25 HP and 130 HP are in terms of NOx+HC.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page JJJJ-16 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines dFor purposes of this subpart, when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included.Table 2 to Subpart JJJJ of Part 60-Requirements for Performance Tests[As stated in &sect;60.4244, you must comply with the following requirements for performance tests within 10 percent of 100 percent peak (or the highest achievable) load]According to the Complying with the following For each requirement to You must Using requirements
Definitions
: 1. Stationary SI a. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a internal combustion concentration of NOxin location and the number of 40 CFR part 60, control device, the engine the stationary SI internal traverse points; appendix A or ASTM sampling site must demonstrating combustion engine Method D6522- be located at the compliance exhaust. 00(2005)a.
&sect; 60.4248 What definitions apply to this subpart?
outlet of the control according to device.&sect;60.4244.ii. Determine the (2) Method 3, 3A, or 3Bbof 40 (b) Measurements to%2 concentration of the CFR part 60, appendix A or determine stationary internal ASTM Method D6522- O 2 concentration must combustion engine 00(2005)'.
As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part.
be made at the same exhaust at the sampling time as the port location; measurements for NOx concentration.
Certified emissions life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for certified emissions life for stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP) are given in 40 CFR 90.105, 40 CFR 1054.107, and 40 CFR 1060.101, as appropriate. The values for certified emissions life for stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) certified to 40 CFR part 1048 are given in 40 CFR 1048.101(g). The certified emissions life for stationary SI ICE with a maximum engine power greater than 75 KW (100 HP) certified under the voluntary manufacturer certification program of this subpart is 5,000 hours or 7 years, whichever comes first.
iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60.stationary internal combustion engine exhaust;iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see &sect;60.17). measurement for NOx sampling port location; concentration.
Certified stationaryinternal combustion engine means an engine that belongs to an engine family that has a certificate of conformity that complies with the emission standards and requirements in this part, or of 40 CFR part 90, 40 CFR part 1048, or 40 CFR part 1054, as appropriate.
and v. Measure NOx at the (5) Method 7E of 40 CFR part 60, (d) Results of this test exhaust of the stationary appendix A, Method D6522- consist of the average of internal combustion 00(2005)', Method 320 of 40 the three 1-hour or engine. CFR part 63, appendix A, or longer runs.ASTM D6348-03 (incorporated by reference, see &sect;60.17).b. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a concentration of CO in location and the number of 40 CFR part 60, control device, the the stationary SI internal traverse points; appendix A. sampling site must combustion engine be located at the exhaust. outlet of the control device.ii. Determine the (2) Method 3, 3A, or 3Bb of 40 (b) Measurements to O 2 concentration of the CFR part 60, appendix A or determine stationary internal ASTM Method D6522- O 2 concentration must Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page JJJJ-17 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines combustion engine 00(2005)a.
Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system.
be made at the same exhaust at the sampling time as the port location; measurements for CO concentration.
Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.
iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60.stationary internal combustion engine exhaust;iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see &sect;60.17). measurement for CO sampling port location; concentration.
Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil.
and v. Measure CO at the (5) Method 10 of 40 CFR part 60, (d) Results of this test exhaust of the stationary appendix A, ASTM Method consist of the average of internal combustion D6522-00(2005)a, Method 320 of the three 1-hour or engine. 40 CFR part 63, appendix A, or longer runs.ASTM D 6348-03 (incorporated by reference, see &sect;60.17).c. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a concentration of VOC location and the number of 40 CFR part 60, control device, the in the stationary SI traverse points; appendix A. sampling site must internal combustion be located at the engine exhaust. outlet of the control device.ii. Determine the (2) Method 3, 3A, or 3Bbof 40 (b) Measurements to O 2 concentration of the CFR part 60, appendix A or determine stationary internal ASTM Method D6522- O 2 concentration must combustion engine 00(2005)'.
Digestergas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and carbon dioxide (C02).
be made at the same exhaust at the sampling time as the port location; measurements for VOC concentration.
Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary SI ICE used for peak shaving are not considered emergency stationary ICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines.
iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60.stationary internal combustion engine exhaust;iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see &sect;60.17). measurement for VOC sampling port location; concentration.
Engine manufacturermeans the manufacturer of the engine. See the definition of "manufacturer" in this section.
and v. Measure VOC at the (5) Methods 25A and 18 of 40 (d) Results of this test exhaust of the stationary CFR part 60, appendix A, Method consist of the average of internal combustion 25A with the use of a methane the three 1-hour or engine, cutter as described in 40 CFR longer runs.1065.265, Method 18 or 40 CFR Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page JJJJ-18 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines part 60, appendix A,cd Method 320 of 40 CFR part 63, appendix A, or ASTM D6348-03 (incorporated by reference, see&sect;60.17).'ASTM D6522-00 is incorporated by reference; see 40 CFR 60.17. Also, you may petition the Administrator for approval to use alternative methods for portable analyzer.byou may use ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses, for measuring the O 2 content of the exhaust gas as an alternative to EPA Method 3B.cYou may use EPA Method 18 of 40 CFR part 60, appendix A, provided that you conduct an adequate presurvey test prior to the emissions test, such as the one described in OTM 11 on EPA's Web site ( http://www.epa.gov/ttn/emc/prelim/otmll.pdf).
Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution.
dYou may use ASTM D6420-99 (2004), Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography/Mass Spectrometry as an alternative to EPA Method 18 for measuring total nonmethane organic.Table 3 to Subpart JJJJ of Part 60-Applicability of General Provisions to Subpart JJJJ[As stated in &sect;60.4246, you must comply with the following applicable General Provisions]
Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline.
General provisions Applies to citation Subject of citation subpart Explanation
Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2.
&sect;60.1 General applicability of the Yes General Provisions
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&sect;60.2 [Definitions Yes Additional terms defined in &sect;60.4248.&sect;60.3 Units and abbreviations Yes&sect;60.4 [Address ][Yes&sect;60.5 Determination of construction or Yes_ _ modification
 
_[&sect;60.6 [Review of plans Yes[&sect;60.7 [Notification and Recordkeeping Yes Except that &sect;60.7 only applies as specified in &sect;60.4245.&sect;60.8 Performance tests 1Yes Except that &sect;60.8 only applies to owners and operators&sect;60.8 Performance_
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich bum engine.
tests -]who are subject to performance testing in subpart JJJJ.[&sect;60.9 [Availability of information Yes[&sect;60.10 State Authority Yes&sect;60.11 Compliance with standards and Yes [Requirements are specified in subpart JJJJ._maintenance requirements
Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production.
&sect;60.12 [Circumvention  
Manufacturer has the meaning given in section 216(1) of the Clean Air Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for resale.
]IYes IF&sect;60.13 Monitoring requirements No&sect;60.14 Modification Yes&sect;60.15 Reconstruction Yes I Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page JJJJ-19 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines&sect;60.16 Priority list Yes&sect;60.17 Incorporations by reference Yes&sect;60.18 General control device No requirements
Maximum engine power means maximum engine power as defined in 40 CFR 1048.801.
&sect;60.19 General notification and reporting Yes]requirements
Model year means either: The calendar year in which the engine was originally produced, or the annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year, and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced.
___ _Table 4 to Subpart JJJJ of Part 60-Applicability of Mobile Source Provisions for Manufacturers Participating in the Voluntary Certification Program and Certifying Stationary SI ICE to Emission Standards in Table I of Subpart JJJJ[As stated in &sect;60.4247, you must comply with the following applicable mobile source provisions if you are a manufacturer participating in the voluntary certification program and certifying stationary SI ICE to emission standards in Table 1 of subpart JJJJ]Mobile source provisions Applies to citation Subject of citation subpart Explanation 1048 subpart A Overview and Applicability Yes 1048 subpart B Emission Standards and Related Requirements Yes Except for the specific sections below.1048.101 Exhaust Emission Standards No 1048.105 Evaporative Emission Standards No 1048.110 Diagnosing Malfunctions No 1048.140 Certifying Blue Sky Series Engines No 1048.145 Interim Provisions No 1048 subpart C Certifying Engine Families Yes Except for the specific sections below.1048.205(b)
Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality.
AECD reporting Yes 1048.205(c)
Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine.
OBD Requirements No 1048.205(n)
Pipeline-qualitynaturalgas means a naturally occurring fluid mixture of hydrocarbons (e.g., methane, ethane, or propane) produced in geological formations beneath the Earth's surface that maintains a gaseous state at standard atmospheric temperature and pressure under ordinary conditions, and which is provided by a supplier through a pipeline. Pipeline-quality natural gas must either be composed of at least 70 percent methane by volume or have a gross calorific value between 950 and 1,100 British thermal units per standard cubic foot.
Deterioration Factors Yes Except as indicated in 60.4247(c).
Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to June 12, 2006, with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich bum engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent.
1048.205(p)(1)
Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work.
Deterioration Factor Discussion Yes 1048.205(p)(2)
Spark ignition means relating to either: a gasoline-fueled engine; or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.
Liquid Fuels as they require No 1048.240(b)(c)(d)
Stationary internal combustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition. Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines.
Deterioration Factors Yes 1048 subpart D Testing Production-Line Engines Yes 1048 subpart E Testing In-Use Engines No 1048 subpart F Test Procedures Yes 1065.5(a)(4)
Stationary internal combustion engine test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that test stationary ICE.
Raw sampling (refers reader back to the specific Yes emissions regulation for guidance)1048 subpart G Compliance Provisions Yes 1048 subpart H Reserved Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 01 70004-024-AV Title V Permit Renewal Page JJJJ-20 of 21 APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 1048 subpart I Definitions and Other Reference Information Yes 1048 appendix I and II Yes 1065 (all subparts)
Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion.
Engine Testing Procedures Yes Except for the specific section below.1065.715 Test Fuel Specifications for Natural Gas No 1068 (all subparts)
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General Compliance Provisions for Nonroad Programs Yes Except for the specific sections below.1068.245 Hardship Provisions for Unusual Circumstances No 1068.250 Hardship Provisions for Small-Volume Manufacturers No 1068.255 Hardship Provisions for Equipment Manufacturers and Secondary Engine Manufacturers Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page JJJJ-21 of 21 APPENDIX NESHAP SUBPART A General Provisions 40 CFR 63 Subpart A -General Provisions
 
&sect; 63.1 Applicability.(a) General.(1) Terms used throughout this part are defined in &sect; 63.2 or in the Clean Air Act (Act)as amended in 1990, except that individual subparts of this part may include specific definitions in addition to or that supersede definitions in &sect; 63.2.(2) This part contains national emission standards for hazardous air pollutants (NESHAP) established pursuant to section 112 of the Act as amended November 15, 1990. These standards regulate specific categories of stationary sources that emit (or have the potential to emit) one or more hazardous air pollutants listed in this part pursuant to section 112(b) of the Act. This section explains the applicability of such standards to sources affected by them. The standards in this part are independent of NESHAP contained in 40 CFR part 61. The NESHAP in part 61 promulgated by signature of the Administrator before November 15, 1990 (i.e., the date of enactment of the Clean Air Act Amendments of 1990) remain in effect until they are amended, if appropriate, and added to this part.(3) No emission standard or other requirement established under this part shall be interpreted, construed, or applied to diminish or replace the requirements of a more stringent emission limitation or other applicable requirement established by the Administrator pursuant to other authority of the Act (section 111, part C or D or any other authority of this Act), or a standard issued under State authority.
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart JJJJ.
The Administrator may specify in a specific standard under this part that facilities subject to other provisions under the Act need only comply with the provisions of that standard.(4) (i) Each relevant standard in this part 63 must identify explicitly whether each provision in this subpart A is or is not included in such relevant standard.(ii) If a relevant part 63 standard incorporates the requirements of 40 CFR part 60, part 61, or other part 63 standards, the relevant part 63 standard must identify explicitly the applicability of each corresponding part 60,part 61, or other part 63 subpart A (General)
Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric.
Provision.(iii) The General Provisions in this Subpart A do not apply to regulations developed pursuant to section 112(r) of the amended Act., unless otherwise specified in those regulations.
Volatile organic compounds means volatile organic compounds as defined in 40 CFR 5 1.100(s).
Voluntary certificationprogram means an optional engine certification program that manufacturers of stationary SI internal combustion engines with a maximum engine power greater than 19 KW (25 HP) that do not use gasoline and are not rich burn engines that use LPG can choose to participate in to certify their engines to the emission standards in &sect;60.4231(d) or (e),
as applicable.
[73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008]
Table I to Subpart JJJJof Part 60-NOx, CO, and VOC Emission Standardsfor StationaryNon-Emergency SI Engines
>100 HP (Except Gasoline and Rich Burn LPG), StationarySI Landfill/DigesterGas Engines, and Stationary Emergency Engines >25 HP Emission Standards' Maximum engine        Manufacture    irnr g/HP-hr       ]ppmvd at 15%
02 02 Engine type and fuel                       power               date       N     cCO FVO     NOx     O Non-Emergency SI Natural Gasb and Non-               100<HP<500                   7/1/2008 2.0 4.0         1.0   160 540     86 Emergency SI Lean Burn LPG b                                                     1/1/2011[ 1.0 120 [       0.7   82 270     60]
Non-Emergency SI Lean Burn Natural Gas and           500>HP<1,350                 1/1/20081 2.0 4.       0 1.0 1601 540       86 LPG                                                                               7/1/2010 1     1.0 1 3i 0.7 82             270] 60 Non-Emergency SI Natural Gas and Non-               HP>500                       7/1/2007 2.0     4.1     1.0 161 540       86 Emergency SI Lean Burn LPG (except lean burn         HP2500                       7/1/201007                       82 270     60 500=>-HP<1,350)
Landfill/Digester Gas (except lean burn             HP<500                       7/1/20081   3.0 5.00     1.0 220 610       80 500>HP<1,350)                                                                     1/1/2011   2.0 [5.0     1.0] 150] 610     80 HP>s500                     7/1/2007   3.0 5.0]     1.0 220] 610     80 7/1/2010   2.0 5.0]     1.0   150] 610     80 Landfill/Digester Gas Lean Burn                     500>HP<1,350                 1/1/20081   3]0[5.1       1.0 220] 610       80 7/1/201       0 5.0]1 1.01150] 610         80 Emergency                                           25>HP<130                   1/1/2009 1J2.0[4.
Cl   387   N/A N/A N/A 1.0 160] 540 N/A 86 HP> 130             1L aOwners and operators of stationary non-certified SI engines may choose to comply with the emission standards in units of either g/HP-hr or ppmvd at 15 percent 02.
bOwners and operators of new or reconstructed non-emergency lean burn SI stationary engines with a site rating of greater than or equal to 250 brake HP located at a major source that are meeting the requirements of 40 CFR part 63, subpart ZZZZ, Table 2A do not have to comply with the CO emission standards of Table 1 of this subpart.
cThe emission standards applicable to emergency engines between 25 HP and 130 HP are in terms of NOx+HC.
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APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines dFor purposes of this subpart, when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included.
Table 2 to SubpartJJJJof Part60-Requirementsfor Performance Tests
[As stated in &sect;60.4244, you must comply with the following requirements for performance tests within 10 percent of 100 percent peak (or the highest achievable) load]
According to the Complying with the                                                                           following For each             requirement to                     You must                       Using               requirements
: 1. Stationary SI     a. limit the               i. Select the sampling port       (1) Method 1 or 1A of     (a) If using a internal combustion   concentration of NOxin location and the number of             40 CFR part 60,           control device, the engine               the stationary SI internal traverse points;                   appendix A or ASTM         sampling site must demonstrating         combustion engine                                             Method D6522-             be located at the compliance           exhaust.                                                       00(2005)a.                 outlet of the control according to                                                                                                   device.
&sect;60.4244.
ii. Determine the         (2) Method 3, 3A, or 3Bbof 40     (b) Measurements to
                    %2concentration of the     CFR part 60, appendix A or         determine stationary internal         ASTM Method D6522-                 O 2concentration must combustion engine           00(2005)'.                         be made at the same exhaust at the sampling                                       time as the port location;                                                 measurements for NOx concentration.
iii. Determine the         (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60.
stationary internal combustion engine exhaust; iv. If necessary,           (4) Method 4 of 40 CFR part 60,   (c) Measurements to measure moisture           appendix A, Method 320 of 40       determine moisture content of the stationary   CFR part 63, appendix A, or       must be made at the internal combustion         ASTM D6348-03 (incorporated       same time as the engine exhaust at the       by reference, see &sect;60.17).         measurement for NOx sampling port location;                                       concentration.
and
: v. Measure NOx at the       (5) Method 7E of 40 CFR part 60,   (d) Results of this test exhaust of the stationary   appendix A, Method D6522-         consist of the average of internal combustion         00(2005)', Method 320 of 40       the three 1-hour or engine.                     CFR part 63, appendix A, or       longer runs.
ASTM D6348-03 (incorporated by reference, see &sect;60.17).
: b. limit the               i. Select the sampling port       (1) Method 1 or 1A of     (a) If using a concentration of CO in location and the number of             40 CFR part 60,           control device, the the stationary SI internal traverse points;                   appendix A.               sampling site must combustion engine                                                                         be located at the exhaust.                                                                                 outlet of the control device.
ii. Determine the           (2) Method 3, 3A, or 3Bb of 40     (b) Measurements to O2 concentration of the     CFR part 60, appendix A or         determine stationary internal         ASTM Method D6522-                 O 2concentration must Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page JJJJ-17 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines combustion engine         00(2005)a.                       be made at the same exhaust at the sampling                                   time as the port location;                                             measurements for CO concentration.
iii. Determine the       (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60.
stationary internal combustion engine exhaust; iv. If necessary,         (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture         appendix A, Method 320 of 40     determine moisture content of the stationary CFR part 63, appendix A, or     must be made at the internal combustion       ASTM D6348-03 (incorporated     same time as the engine exhaust at the     by reference, see &sect;60.17).       measurement for CO sampling port location;                                   concentration.
and
: v. Measure CO at the     (5) Method 10 of 40 CFR part 60, (d) Results of this test exhaust of the stationary appendix A, ASTM Method         consist of the average of internal combustion       D6522-00(2005)a, Method 320 of   the three 1-hour or engine.                   40 CFR part 63, appendix A, or   longer runs.
ASTM D 6348-03 (incorporated by reference, see &sect;60.17).
: c. limit the             i. Select the sampling port     (1) Method 1 or 1A of     (a) If using a concentration of VOC     location and the number of       40 CFR part 60,           control device, the in the stationary SI     traverse points;                 appendix A.               sampling site must internal combustion                                                                   be located at the engine exhaust.                                                                       outlet of the control device.
ii. Determine the         (2) Method 3, 3A, or 3Bbof 40   (b) Measurements to O 2concentration of the   CFR part 60, appendix A or       determine stationary internal       ASTM Method D6522-               O 2 concentration must combustion engine         00(2005)'.                       be made at the same exhaust at the sampling                                     time as the port location;                                             measurements for VOC concentration.
iii. Determine the         (3) Method 2 or 19 of 40 CFR exhaust flowrate of the   part 60.
stationary internal combustion engine exhaust; iv. If necessary,         (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture           appendix A, Method 320 of 40     determine moisture content of the stationary CFR part 63, appendix A, or     must be made at the internal combustion       ASTM D6348-03 (incorporated     same time as the engine exhaust at the     by reference, see &sect;60.17).       measurement for VOC sampling port location;                                     concentration.
and
: v. Measure VOC at the     (5) Methods 25A and 18 of 40     (d) Results of this test exhaust of the stationary CFR part 60, appendix A, Method consist of the average of internal combustion       25A with the use of a methane   the three 1-hour or engine,                   cutter as described in 40 CFR   longer runs.
1065.265, Method 18 or 40 CFR Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                            Title V Permit Renewal Page JJJJ-18 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines part 60, appendix A,cd Method 320 of 40 CFR part 63, appendix A, or ASTM D6348-03 (incorporated by reference, see
                                                    &sect;60.17).
  'ASTM D6522-00 is incorporated by reference; see 40 CFR 60.17. Also, you may petition the Administrator for approval to use alternative methods for portable analyzer.
byou   may use ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses, for measuring the O 2content of the exhaust gas as an alternative to EPA Method 3B.
cYou may use EPA Method 18 of 40 CFR part 60, appendix A, provided that you conduct an adequate presurvey test prior to the emissions test, such as the one described in OTM 11 on EPA's Web site ( http://www.epa.gov/ttn/emc/prelim/otmll.pdf).
dYou may use ASTM D6420-99 (2004), Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography/Mass Spectrometry as an alternative to EPA Method 18 for measuring total nonmethane organic.
Table 3 to Subpart JJJJof Part 60-Applicabilityof GeneralProvisions to SubpartJJJJ
[As stated in &sect;60.4246, you must comply with the following applicable General Provisions]
General provisions                                             Applies to citation               Subject of citation             subpart                         Explanation
  &sect;60.1                 General applicability of the         Yes General Provisions
  &sect;60.2               [Definitions                           Yes         Additional terms defined in &sect;60.4248.
  &sect;60.3               Units and abbreviations               Yes
  &sect;60.4               [Address                             ][Yes
  &sect;60.5                 Determination of construction or     Yes
_modification
_                                  _
[&sect;60.6               [Review of plans                       Yes
[&sect;60.7               [Notification and Recordkeeping       Yes         Except that &sect;60.7 only applies as specified in &sect;60.4245.
  &sect;60.8
  &sect;60.8                Performance tests Performance_  tests 1Yes           Except that &sect;60.8 only applies to owners and operators
                                                                        -]who are subject to performance testing in subpart JJJJ.
I
[&sect;60.9               [Availability of information           Yes
[&sect;60.10               State Authority                       Yes
  &sect;60.11               Compliance with standards and         Yes         [Requirements are specified in subpart JJJJ.
_maintenance   requirements
  &sect;60.12               [Circumvention                     ]IYes         IF
  &sect;60.13               Monitoring requirements               No
  &sect;60.14               Modification                           Yes
  &sect;60.15               Reconstruction                         Yes Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                Title V Permit Renewal Page JJJJ-19 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines
&sect;60.16               Priority list                       Yes
&sect;60.17               Incorporations by reference         Yes
&sect;60.18               General control device               No requirements
&sect;60.19
                  ]requirements General notification and reporting Yes
___                                     _
Table 4 to SubpartJJJJof Part 60-Applicability of Mobile Source Provisionsfor ManufacturersParticipatingin the Voluntary CertificationProgramand Certifying Stationary SI ICE to Emission Standards in Table I of SubpartJJJJ
[As stated in &sect;60.4247, you must comply with the following applicable mobile source provisions if you are a manufacturer participating in the voluntary certification program and certifying stationary SI ICE to emission standards in Table 1 of subpart JJJJ]
Mobile source provisions                                                               Applies to citation                             Subject of citation                     subpart           Explanation 1048 subpart A                 Overview and Applicability                             Yes 1048 subpart B                 Emission Standards and Related Requirements             Yes           Except for the specific sections below.
1048.101                       Exhaust Emission Standards                             No 1048.105                       Evaporative Emission Standards                         No 1048.110                       Diagnosing Malfunctions                                 No 1048.140                       Certifying Blue Sky Series Engines                     No 1048.145                       Interim Provisions                                     No 1048 subpart C                 Certifying Engine Families                             Yes           Except for the specific sections below.
1048.205(b)                   AECD reporting                                         Yes 1048.205(c)                   OBD Requirements                                       No 1048.205(n)                   Deterioration Factors                                   Yes           Except as indicated in 60.4247(c).
1048.205(p)(1)                 Deterioration Factor Discussion                         Yes 1048.205(p)(2)                 Liquid Fuels as they require                           No 1048.240(b)(c)(d)             Deterioration Factors                                   Yes 1048 subpart D                 Testing Production-Line Engines                         Yes 1048 subpart E                 Testing In-Use Engines                                 No 1048 subpart F                 Test Procedures                                         Yes 1065.5(a)(4)                   Raw sampling (refers reader back to the specific       Yes emissions regulation for guidance) 1048 subpart G                 Compliance Provisions                                   Yes 1048 subpart H                 Reserved Progress Energy Florida, Inc.                                                                     Permit No. 01 70004-024-AV Crystal River Power Plant                                                                                Title V Permit Renewal Page JJJJ-20 of 21
 
APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 1048 subpart I             Definitions and Other Reference Information           Yes 1048 appendix I and II     Yes 1065 (all subparts)         Engine Testing Procedures                             Yes         Except for the specific section below.
1065.715                   Test Fuel Specifications for Natural Gas               No 1068 (all subparts)         General Compliance Provisions for Nonroad Programs Yes             Except for the specific sections below.
1068.245                   Hardship Provisions for Unusual Circumstances         No 1068.250                   Hardship Provisions for Small-Volume Manufacturers No 1068.255                   Hardship Provisions for Equipment Manufacturers and Secondary Engine Manufacturers Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                                          Title V Permit Renewal Page JJJJ-21 of 21
 
APPENDIX NESHAP SUBPART A General Provisions 40 CFR 63 Subpart A - General Provisions
&sect; 63.1 Applicability.
(a) General.
(1) Terms used throughout this part are defined in &sect; 63.2 or in the Clean Air Act (Act) as amended in 1990, except that individual subparts of this part may include specific definitions in addition to or that supersede definitions in &sect; 63.2.
(2) This part contains national emission standards for hazardous air pollutants (NESHAP) established pursuant to section 112 of the Act as amended November 15, 1990. These standards regulate specific categories of stationary sources that emit (or have the potential to emit) one or more hazardous air pollutants listed in this part pursuant to section 112(b) of the Act. This section explains the applicability of such standards to sources affected by them. The standards in this part are independent of NESHAP contained in 40 CFR part 61. The NESHAP in part 61 promulgated by signature of the Administrator before November 15, 1990 (i.e., the date of enactment of the Clean Air Act Amendments of 1990) remain in effect until they are amended, if appropriate, and added to this part.
(3) No emission standard or other requirement established under this part shall be interpreted, construed, or applied to diminish or replace the requirements of a more stringent emission limitation or other applicable requirement established by the Administrator pursuant to other authority of the Act (section 111, part C or D or any other authority of this Act), or a standard issued under State authority. The Administrator may specify in a specific standard under this part that facilities subject to other provisions under the Act need only comply with the provisions of that standard.
(4)       (i) Each relevant standard in this part 63 must identify explicitly whether each provision in this subpart A is or is not included in such relevant standard.
(ii) If a relevant part 63 standard incorporates the requirements of 40 CFR part 60, part 61, or other part 63 standards, the relevant part 63 standard must identify explicitly the applicability of each corresponding part 60,part 61, or other part 63 subpart A (General) Provision.
(iii) The General Provisions in this Subpart A do not apply to regulations developed pursuant to section 112(r) of the amended Act., unless otherwise specified in those regulations.
(5) [Reserved]
(5) [Reserved]
(6) To obtain the most current list of categories of sources to be regulated under section 112 of the Act, or to obtain the most recent regulation promulgation schedule established pursuant to section 112(e) of the Act, contact the Office of the Director, Emission Standards Division, Office of Air Quality Planning and Standards, U.S. EPA (MD-13), Research Triangle Park, North Carolina 27711.(7) [Reserved]
(6) To obtain the most current list of categories of sources to be regulated under section 112 of the Act, or to obtain the most recent regulation promulgation schedule established pursuant to section 112(e) of the Act, contact the Office of the Director, Emission Standards Division, Office of Air Quality Planning and Standards, U.S. EPA (MD-13), Research Triangle Park, North Carolina 27711.
(7) [Reserved]
(8) [Reserved]
(8) [Reserved]
(9) [Reserved]
(9) [Reserved]
(10) For the purposes of this part, time periods specified in days shall be measured in calendar days, even if the word"calendar" is absent, unless otherwise specified in an applicable requirement.
(10) For the purposes of this part, time periods specified in days shall be measured in calendar days, even if the word "calendar" is absent, unless otherwise specified in an applicable requirement.
(11) For the purposes of this part, if an explicit postmark deadline is not specified in an applicable requirement for the submittal of a notification, application, test plan, report, or other written communication to the Administrator, the owner or operator shall postmark the submittal on or before the number of days specified in the applicable requirement.
(11) For the purposes of this part, if an explicit postmark deadline is not specified in an applicable requirement for the submittal of a notification, application, test plan, report, or other written communication to the Administrator, the owner or operator shall postmark the submittal on or before the number of days specified in the applicable requirement. For example, if a notification must be submitted 15 days before a particular event is scheduled to take place, the notification shall be postmarked on or before 15 days preceding the event; likewise, if a notification must be submitted 15 days after a particular event takes place, the notification shall be postmarked on or before 15 days following the end of the event. The use of reliable non-Government mail carriers that provide indications of verifiable delivery of information required to be submitted to the Administrator, similar to the postmark provided by the U.S. Postal Service, or alternative means of delivery agreed to by the permitting authority, is acceptable.
For example, if a notification must be submitted 15 days before a particular event is scheduled to take place, the notification shall be postmarked on or before 15 days preceding the event; likewise, if a notification must be submitted 15 days after a particular event takes place, the notification shall be postmarked on or before 15 days following the end of the event. The use of reliable non-Government mail carriers that provide indications of verifiable delivery of information required to be submitted to the Administrator, similar to the postmark provided by the U.S. Postal Service, or alternative means of delivery agreed to by the permitting authority, is acceptable.
(12) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. Procedures governing the implementation of this provision are specified in &sect; 63.9(i).
(12) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator.
(13) [Reserved]
Procedures governing the implementation of this provision are specified in &sect; 63.9(i).(13) [Reserved]
(14) [Reserved]
(14) [Reserved](b) Initial applicability determination for this part.(1) The provisions of this part apply to the owner or operator of any stationary source that -(i) Emits or has the potential to emit any hazardous air pollutant listed in or pursuant to section 112(b) of the Act; and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-1 of 45 APPENDIX NESHAP SUBPART A General Provisions (ii) Is subject to any standard, limitation, prohibition, or other federally enforceable requirement established pursuant to this part.(2) [Reserved]
(b) Initial applicabilitydeterminationfor this part.
(3) An owner or operator of a stationary source who is in the relevant source category and who determines that the source is not subject to a relevant standard or other requirement established under this part, must keep a record as specified in&sect; 63.10(b)(3).(c) Applicability of this part after a relevant standard has been set under this part.(1) If a relevant standard has been established under this part, the owner or operator of an affected source must comply with the provisions of that standard and of this subpart as provided in paragraph (a)(4) of this section.(2) Except as provided in &sect; 63.10(b)(3), if a relevant standard has been established under this part, the owner or operator of an affected source may be required to obtain a title V permit from a permitting authority in the State in which the source is located. Emission standards promulgated in this part for area sources pursuant to section 112(c)(3) of the Act will specify whether -(i) States will have the option to exclude area sources affected by that standard from the requirement to obtain a title V permit (i.e., the standard will exempt the category of area sources altogether from the permitting requirement);(ii) States will have the option to defer permitting of area sources in that category until the Administrator takes rulemaking action to determine applicability of the permitting requirements; or (iii) If a standard fails to specify what the permitting requirements will be for area sources affected by such a standard, then area sources that are subject to the standard will be subject to the requirement to obtain a title V permit without any deferral.(3) [Reserved]
(1) The provisions of this part apply to the owner or operator of any stationary source that -
(i) Emits or has the potential to emit any hazardous air pollutant listed in or pursuant to section 112(b) of the Act; and Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-1 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (ii) Is subject to any standard, limitation, prohibition, or other federally enforceable requirement established pursuant to this part.
(2) [Reserved]
(3) An owner or operator of a stationary source who is in the relevant source category and who determines that the source is not subject to a relevant standard or other requirement established under this part, must keep a record as specified in
&sect; 63.10(b)(3).
(c) Applicability of this part after a relevant standardhas been set under this part.
(1) If a relevant standard has been established under this part, the owner or operator of an affected source must comply with the provisions of that standard and of this subpart as provided in paragraph (a)(4) of this section.
(2) Except as provided in &sect; 63.10(b)(3), if a relevant standard has been established under this part, the owner or operator of an affected source may be required to obtain a title V permit from a permitting authority in the State in which the source is located. Emission standards promulgated in this part for area sources pursuant to section 112(c)(3) of the Act will specify whether -
(i) States will have the option to exclude area sources affected by that standard from the requirement to obtain a title V permit (i.e., the standard will exempt the category of area sources altogether from the permitting requirement);
(ii) States will have the option to defer permitting of area sources in that category until the Administrator takes rulemaking action to determine applicability of the permitting requirements; or (iii) If a standard fails to specify what the permitting requirements will be for area sources affected by such a standard, then area sources that are subject to the standard will be subject to the requirement to obtain a title V permit without any deferral.
(3) [Reserved]
(4) [Reserved]
(4) [Reserved]
(5) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source also shall be subject to the notification requirements of this subpart.(d) [Reserved](e) If the Administrator promulgates an emission standard under section 112(d) or (h) of the Act that is applicable to a source subject to an emission limitation by permit established under section 112(j) of the Act, and the requirements under the section 1120) emission limitation are substantially as effective as the promulgated emission standard, the owner or operator may request the permitting authority to revise the source's title V permit to reflect that the emission limitation in the permit satisfies the requirements of the promulgated emission standard.
(5) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source also shall be subject to the notification requirements of this subpart.
The process by which the permitting authority determines whether the section 112(j) emission limitation is substantially as effective as the promulgated emission standard must include, consistent with part 70 or 71 of this chapter, the opportunity for full public, EPA, and affected State review (including the opportunity for EPA's objection) prior to the permit revision being finalized.
(d) [Reserved]
A negative determination by the permitting authority constitutes final action for purposes of review and appeal under the applicable title V operating permit program.&sect; 63.2 Definitions.
(e) If the Administrator promulgates an emission standard under section 112(d) or (h) of the Act that is applicable to a source subject to an emission limitation by permit established under section 112(j) of the Act, and the requirements under the section 1120) emission limitation are substantially as effective as the promulgated emission standard, the owner or operator may request the permitting authority to revise the source's title V permit to reflect that the emission limitation in the permit satisfies the requirements of the promulgated emission standard. The process by which the permitting authority determines whether the section 112(j) emission limitation is substantially as effective as the promulgated emission standard must include, consistent with part 70 or 71 of this chapter, the opportunity for full public, EPA, and affected State review (including the opportunity for EPA's objection) prior to the permit revision being finalized. A negative determination by the permitting authority constitutes final action for purposes of review and appeal under the applicable title V operating permit program.
The terms used in this part are defined in the Act or in this section as follows: Act means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Pub. L. 101-549, 104 Stat. 2399).Actual emissions is defined in subpart D of this part for the purpose of granting a compliance extension for an early reduction of hazardous air pollutants.
&sect; 63.2 Definitions.
Administrator means the Administrator of the United States Environmental Protection Agency or his or her authorized representative (e.g., a State that has been delegated the authority to implement the provisions of this part).Affected source, for the purposes of this part, means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory for which a section 112(d) standard or other relevant standard is established pursuant to section 112 of the Act. Each relevant standard will define the "affected source," as defined in this paragraph unless a different definition is warranted based on a published justification as to why this definition would result in significant administrative, practical, or implementation problems and why the different definition would resolve those problems.
The terms used in this part are defined in the Act or in this section as follows:
The term "affected source," as used in this part, is separate and distinct from any other use of that term in EPA regulations such as those implementing title IV of the Act. Affected source Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-2 of 45 APPENDIX NESHAP SUBPART A General Provisions may be defined differently for part 63 than affected facility and stationary source in parts 60 and 61, respectively.
Act means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Pub. L. 101-549, 104 Stat. 2399).
This definition of "affected source," and the procedures for adopting an alternative definition of "affected source," shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002.Alternative emission limitation means conditions established pursuant to sections 112(i)(5) or 112(i)(6) of the Act by the Administrator or by a State with an approved permit program.Alternative emission standard means an alternative means of emission limitation that, after notice and opportunity for public comment, has been demonstrated by an owner or operator to the Administrator's satisfaction to achieve a reduction in emissions of any air pollutant at least equivalent to the reduction in emissions of such pollutant achieved under a relevant design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act.Alternative test method means any method of sampling and analyzing for an air pollutant that is not a test method in this chapter and that has been demonstrated to the Administrator's satisfaction, using Method 301 in Appendix A of this part, to produce results adequate for the Administrator's determination that it may be used in place of a test method specified in this part.Approved permit program means a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to title V of the Act (42 U.S.C.7661).Area source means any stationary source of hazardous air pollutants that is not a major source as defined in this part.Commenced means, with respect to construction or reconstruction of an affected source, that an owner or operator has undertaken a continuous program of construction or reconstruction or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or reconstruction.
Actual emissions is defined in subpart D of this part for the purpose of granting a compliance extension for an early reduction of hazardous air pollutants.
Compliance date means the date by which an affected source is required to be in compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established by the Administrator (or a State with an approved permit program) pursuant to section 112 of the Act.Compliance schedule means: (1) In the case of an affected source that is in compliance with all applicable requirements established under this part, a statement that the source will continue to comply with such requirements; or (2) In the case of an affected source that is required to comply with applicable requirements by a future date, a statement that the source will meet such requirements on a timely basis and, if required by an applicable requirement, a detailed schedule of the dates by which each step toward compliance will be reached; or (3) In the case of an affected source not in compliance with all applicable requirements established under this part, a schedule of remedial measures, including an enforceable sequence of actions or operations with milestones and a schedule for the submission of certified progress reports, where applicable, leading to compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established pursuant to section 112 of the Act for which the affected source is not in compliance.
Administratormeans the Administrator of the United States Environmental Protection Agency or his or her authorized representative (e.g., a State that has been delegated the authority to implement the provisions of this part).
This compliance schedule shall resemble and be at least as stringent as that contained in any judicial consent decree or administrative order to which the source is subject. Any such schedule of compliance shall be supplemental to, and shall not sanction non-compliance with, the applicable requirements on which it is based.Construction means the on-site fabrication, erection, or installation of an affected source. Construction does not include the removal of all equipment comprising an affected source from an existing location and reinstallation of such equipment at a new location.
Affected source, for the purposes of this part, means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory for which a section 112(d) standard or other relevant standard is established pursuant to section 112 of the Act. Each relevant standard will define the "affected source," as defined in this paragraph unless a different definition is warranted based on a published justification as to why this definition would result in significant administrative, practical, or implementation problems and why the different definition would resolve those problems. The term "affected source," as used in this part, is separate and distinct from any other use of that term in EPA regulations such as those implementing title IV of the Act. Affected source Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-2 of 45
The owner or operator of an existing affected source that is relocated may elect not to reinstall minor ancillary equipment including, but not limited to, piping, ductwork, and valves. However, removal and reinstallation of an affected source will be construed as reconstruction if it satisfies the criteria for reconstruction as defined in this section.The costs of replacing minor ancillary equipment must be considered in determining whether the existing affected source is reconstructed.
 
APPENDIX NESHAP SUBPART A General Provisions may be defined differently for part 63 than affected facility and stationary source in parts 60 and 61, respectively. This definition of "affected source," and the procedures for adopting an alternative definition of "affected source," shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002.
Alternative emission limitation means conditions established pursuant to sections 112(i)(5) or 112(i)(6) of the Act by the Administrator or by a State with an approved permit program.
Alternative emission standardmeans an alternative means of emission limitation that, after notice and opportunity for public comment, has been demonstrated by an owner or operator to the Administrator's satisfaction to achieve a reduction in emissions of any air pollutant at least equivalent to the reduction in emissions of such pollutant achieved under a relevant design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act.
Alternative test method means any method of sampling and analyzing for an air pollutant that is not a test method in this chapter and that has been demonstrated to the Administrator's satisfaction, using Method 301 in Appendix A of this part, to produce results adequate for the Administrator's determination that it may be used in place of a test method specified in this part.
Approved permit programmeans a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to title V of the Act (42 U.S.C.
7661).
Area source means any stationary source of hazardous air pollutants that is not a major source as defined in this part.
Commenced means, with respect to construction or reconstruction of an affected source, that an owner or operator has undertaken a continuous program of construction or reconstruction or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or reconstruction.
Compliance date means the date by which an affected source is required to be in compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established by the Administrator (or a State with an approved permit program) pursuant to section 112 of the Act.
Compliance schedule means:
(1) In the case of an affected source that is in compliance with all applicable requirements established under this part, a statement that the source will continue to comply with such requirements; or (2) In the case of an affected source that is required to comply with applicable requirements by a future date, a statement that the source will meet such requirements on a timely basis and, if required by an applicable requirement, a detailed schedule of the dates by which each step toward compliance will be reached; or (3) In the case of an affected source not in compliance with all applicable requirements established under this part, a schedule of remedial measures, including an enforceable sequence of actions or operations with milestones and a schedule for the submission of certified progress reports, where applicable, leading to compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established pursuant to section 112 of the Act for which the affected source is not in compliance. This compliance schedule shall resemble and be at least as stringent as that contained in any judicial consent decree or administrative order to which the source is subject. Any such schedule of compliance shall be supplemental to, and shall not sanction non-compliance with, the applicable requirements on which it is based.
Construction means the on-site fabrication, erection, or installation of an affected source. Construction does not include the removal of all equipment comprising an affected source from an existing location and reinstallation of such equipment at a new location. The owner or operator of an existing affected source that is relocated may elect not to reinstall minor ancillary equipment including, but not limited to, piping, ductwork, and valves. However, removal and reinstallation of an affected source will be construed as reconstruction if it satisfies the criteria for reconstruction as defined in this section.
The costs of replacing minor ancillary equipment must be considered in determining whether the existing affected source is reconstructed.
Continuous emission monitoring system (CEMS) means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of emissions.
Continuous emission monitoring system (CEMS) means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of emissions.
Continuous monitoring system (CMS) is a comprehensive term that may include, but is not limited to, continuous emission monitoring systems, continuous opacity monitoring systems, continuous parameter monitoring systems, or other manual or automatic monitoring that is used for demonstrating compliance with an applicable regulation on a continuous basis as defined by the regulation.
Continuous monitoring system (CMS) is a comprehensive term that may include, but is not limited to, continuous emission monitoring systems, continuous opacity monitoring systems, continuous parameter monitoring systems, or other manual or automatic monitoring that is used for demonstrating compliance with an applicable regulation on a continuous basis as defined by the regulation.
Continuous opacity monitoring system (COMS) means a continuous monitoring system that measures the opacity of emissions.
Continuous opacity monitoring system (COMS) means a continuous monitoring system that measures the opacity of emissions.
Continuous parameter monitoring system means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of process or control system parameters.
Continuous parametermonitoring system means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of process or control system parameters.
Effective date means: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-3 of 45 APPENDIX NESHAP SUBPART A General Provisions (1) With regard to an emission standard established under this part, the date of promulgation in the FEDERAL REGISTER of such standard; or (2) With regard to an alternative emission limitation or equivalent emission limitation determined by the Administrator (or a State with an approved permit program), the date that the alternative emission limitation or equivalent emission limitation becomes effective according to the provisions of this part.Emission standard means a national standard, limitation, prohibition, or other regulation promulgated in a subpart of this part pursuant to sections 112(d), 112(h), or 112(f) of the Act.Emissions averaging is a way to comply with the emission limitations specified in a relevant standard, whereby an affected source, if allowed under a subpart of this part, may create emission credits by reducing emissions from specific points to a level below that required by the relevant standard, and those credits are used to offset emissions from points that are not controlled to the level required by the relevant standard.EPA means the United States Environmental Protection Agency.Equivalent emission limitation means any maximum achievable control technology emission limitation or requirements which are applicable to a major source of hazardous air pollutants and are adopted by the Administrator (or a State with an approved permit program) on a case-by-case basis, pursuant to section 112(g) or (j) of the Act.Excess emissions and continuous monitoring system performance report is a report that must be submitted periodically by an affected source in order to provide data on its compliance with relevant emission limits, operating parameters, and the performance of its continuous parameter monitoring systems.Existing source means any affected source that is not a new source.Federally enforceable means all limitations and conditions that are enforceable by the Administrator and citizens under the Act or that are enforceable under other statutes administered by the Administrator.
Effective date means:
Examples of federally enforceable limitations and conditions include, but are not limited to: (1) Emission standards, alternative emission standards, alternative emission limitations, and equivalent emission limitations established pursuant to section 112 of the Act as amended in 1990;(2) New source performance standards established pursuant to section 111 of the Act, and emission standards established pursuant to section 112 of the Act before it was amended in 1990;(3) All terms and conditions in a title V permit, including any provisions that limit a source's potential to emit, unless expressly designated as not federally enforceable; (4) Limitations and conditions that are part of an approved State Implementation Plan (SIP) or a Federal Implementation Plan (FIP);(5) Limitations and conditions that are part of a Federal construction permit issued under 40 CFR 52.21 or any construction permit issued under regulations approved by the EPA in accordance with 40 CFR part 51;(6) Limitations and conditions that are part of an operating permit where the permit and the permitting program pursuant to which it was issued meet all of the following criteria: (i) The operating permit program has been submitted to and approved by EPA into a State implementation plan (SIP) under section 110 of the CAA;(ii) The SIP imposes a legal obligation that operating permit holders adhere to the terms and limitations of such permits and provides that permits which do not conform to the operating permit program requirements and the requirements of EPA's underlying regulations may be deemed not "federally enforceable" by EPA;(iii) The operating permit program requires that all emission limitations, controls, and other requirements imposed by such permits will be at least as stringent as any other applicable limitations and requirements contained in the SIP or enforceable under the SIP, and that the program may not issue permits that waive, or make less stringent, any limitations or requirements contained in or issued pursuant to the SIP, or that are otherwise "federally enforceable";(iv) The limitations, controls, and requirements in the permit in question are permanent, quantifiable, and otherwise enforceable as a practical matter; and (v) The permit in question was issued only after adequate and timely notice and opportunity for comment for EPA and the public.(7) Limitations and conditions in a State rule or program that has been approved by the EPA under subpart E of this part for the purposes of implementing and enforcing section 112; and (8) Individual consent agreements that the EPA has legal authority to create.Fixed capital cost means the capital needed to provide all the depreciable components of an existing source.Fugitive emissions means those emissions from a stationary source that could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. Under section 112 of the Act, all fugitive emissions are to be considered in determining whether a stationary source is a major source.Hazardous air pollutant means any air pollutant listed in or pursuant to section 112(b) of the Act.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-4 of 45 APPENDIX NESHAP SUBPART A General Provisions Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a title V permit occurs immediately after the EPA takes final action on the final permit.Major source means any stationary source or group of stationary sources located within a contiguous area and under common control that emits or has the potential to emit considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants, unless the Administrator establishes a lesser quantity, or in the case of radionuclides, different criteria from those specified in this sentence.Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control and monitoring equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-3 of 45
Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
 
Monitoring means the collection and use of measurement data or other information to control the operation of a process or pollution control device or to verify a work practice standard relative to assuring compliance with applicable requirements.
APPENDIX NESHAP SUBPART A General Provisions (1) With regard to an emission standard established under this part, the date of promulgation in the FEDERAL REGISTER of such standard; or (2) With regard to an alternative emission limitation or equivalent emission limitation determined by the Administrator (or a State with an approved permit program), the date that the alternative emission limitation or equivalent emission limitation becomes effective according to the provisions of this part.
Monitoring is composed of four elements: (1) Indicator(s) of performance  
Emission standardmeans a national standard, limitation, prohibition, or other regulation promulgated in a subpart of this part pursuant to sections 112(d), 112(h), or 112(f) of the Act.
-- the parameter or parameters you measure or observe for demonstrating proper operation of the pollution control measures or compliance with the applicable emissions limitation or standard.
Emissions averaging is a way to comply with the emission limitations specified in a relevant standard, whereby an affected source, if allowed under a subpart of this part, may create emission credits by reducing emissions from specific points to a level below that required by the relevant standard, and those credits are used to offset emissions from points that are not controlled to the level required by the relevant standard.
Indicators of performance may include direct or predicted emissions measurements (including opacity), operational parametric values that correspond to process or control device (and capture system) efficiencies or emissions rates, and recorded findings of inspection of work practice activities, materials tracking, or design characteristics.
EPA means the United States Environmental Protection Agency.
Indicators may be expressed as a single maximum or minimum value, a function of process variables (for example, within a range of pressure drops), a particular operational or work practice status (for example, a damper position, completion of a waste recovery task, materials tracking), or an interdependency between two or among more than two variables.
Equivalent emission limitation means any maximum achievable control technology emission limitation or requirements which are applicable to a major source of hazardous air pollutants and are adopted by the Administrator (or a State with an approved permit program) on a case-by-case basis, pursuant to section 112(g) or (j) of the Act.
(2) Measurement techniques  
Excess emissions and continuous monitoring system performance report is a report that must be submitted periodically by an affected source in order to provide data on its compliance with relevant emission limits, operating parameters, and the performance of its continuous parameter monitoring systems.
-- the means by which you gather and record information of or about the indicators of performance.
Existing source means any affected source that is not a new source.
The components of the measurement technique include the detector type, location and installation specifications, inspection procedures, and quality assurance and quality control measures.
Federally enforceable means all limitations and conditions that are enforceable by the Administrator and citizens under the Act or that are enforceable under other statutes administered by the Administrator. Examples of federally enforceable limitations and conditions include, but are not limited to:
Examples of measurement techniques include continuous emission monitoring systems, continuous opacity monitoring systems, continuous parametric monitoring systems, and manual inspections that include making records of process conditions or work practices.
(1) Emission standards, alternative emission standards, alternative emission limitations, and equivalent emission limitations established pursuant to section 112 of the Act as amended in 1990; (2) New source performance standards established pursuant to section 111 of the Act, and emission standards established pursuant to section 112 of the Act before it was amended in 1990; (3) All terms and conditions in a title V permit, including any provisions that limit a source's potential to emit, unless expressly designated as not federally enforceable; (4) Limitations and conditions that are part of an approved State Implementation Plan (SIP) or a Federal Implementation Plan (FIP);
(3) Monitoring frequency  
(5) Limitations and conditions that are part of a Federal construction permit issued under 40 CFR 52.21 or any construction permit issued under regulations approved by the EPA in accordance with 40 CFR part 51; (6) Limitations and conditions that are part of an operating permit where the permit and the permitting program pursuant to which it was issued meet all of the following criteria:
-- the number of times you obtain and record monitoring data over a specified time interval.
(i) The operating permit program has been submitted to and approved by EPA into a State implementation plan (SIP) under section 110 of the CAA; (ii) The SIP imposes a legal obligation that operating permit holders adhere to the terms and limitations of such permits and provides that permits which do not conform to the operating permit program requirements and the requirements of EPA's underlying regulations may be deemed not "federally enforceable" by EPA; (iii) The operating permit program requires that all emission limitations, controls, and other requirements imposed by such permits will be at least as stringent as any other applicable limitations and requirements contained in the SIP or enforceable under the SIP, and that the program may not issue permits that waive, or make less stringent, any limitations or requirements contained in or issued pursuant to the SIP, or that are otherwise "federally enforceable";
Examples of monitoring frequencies include at least four points equally spaced for each hour for continuous emissions or parametric monitoring systems, at least every 10 seconds for continuous opacity monitoring systems, and at least once per operating day (or week, month, etc.) for work practice or design inspections.
(iv) The limitations, controls, and requirements in the permit in question are permanent, quantifiable, and otherwise enforceable as a practical matter; and (v) The permit in question was issued only after adequate and timely notice and opportunity for comment for EPA and the public.
(4) Averaging time -- the period over which you average and use data to verify proper operation of the pollution control approach or compliance with the emissions limitation or standard.
(7) Limitations and conditions in a State rule or program that has been approved by the EPA under subpart E of this part for the purposes of implementing and enforcing section 112; and (8) Individual consent agreements that the EPA has legal authority to create.
Examples of averaging time include a 3-hour average in units of the emissions limitation, a 30-day rolling average emissions value, a daily average of a control device operational parametric range, and an instantaneous alarm.New affected source means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory that is subject to a section 112(d) or other relevant standard for new sources. This definition of "new affected source," and the criteria to be utilized in implementing it, shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002. Each relevant standard will define the term "new affected source," which will be the same as the "affected source" unless a different collection is warranted based on consideration of factors including:
Fixed capital cost means the capital needed to provide all the depreciable components of an existing source.
(1) Emission reduction impacts of controlling individual sources versus groups of sources;(2) Cost effectiveness of controlling individual equipment; (3) Flexibility to accommodate common control strategies; (4) Cost/benefits of emissions averaging; (5) Incentives for pollution prevention; (6) Feasibility and cost of controlling processes that share common equipment (e.g., product recovery devices);(7) Feasibility and cost of monitoring; and (8) Other relevant factors.New source means any affected source the construction or reconstruction of which is commenced after the Administrator first proposes a relevant emission standard under this part establishing an emission standard applicable to such source.Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background.
Fugitive emissions means those emissions from a stationary source that could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. Under section 112 of the Act, all fugitive emissions are to be considered in determining whether a stationary source is a major source.
For continuous opacity monitoring systems, opacity means the fraction of incident light that is attenuated by an optical medium.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-5 of 45 APPENDIX NESHAP SUBPART A General Provisions Owner or operator means any person who owns, leases, operates, controls, or supervises a stationary source..Performance audit means a procedure to analyze blind samples, the content of which is known by the Administrator, simultaneously with the analysis of performance test samples in order to provide a measure of test data quality.Performance evaluation means the conduct of relative accuracy testing, calibration error testing, and other measurements used in validating the continuous monitoring system data.Performance test means the collection of data resulting from the execution of a test method (usually three emission test runs) used to demonstrate compliance with a relevant emission standard as specified in the performance test section of the relevant standard.Permit modification means a change to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).Permit program means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C. 7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter.Permit revision means any permit modification or administrative permit amendment to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).Permitting authority means: (1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661).Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable.
Hazardousairpollutant means any air pollutant listed in or pursuant to section 112(b) of the Act.
Reconstruction means the replacement of components of an affected or a previously unaffected stationary source to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable new source; and (2) It is technologically and economically feasible for the reconstructed source to meet the relevant standard(s) established by the Administrator (or a State) pursuant to section 112 of the Act. Upon reconstruction, an affected source, or a stationary source that becomes an affected source, is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.Regulation promulgation schedule means the schedule for the promulgation of emission standards under this part, established by the Administrator pursuant to section 112(e) of the Act and published in the FEDERAL REGISTER.Relevant standard means: (1) An emission standard;(2) An alternative emission standard;(3) An alternative emission limitation; or (4) An equivalent emission limitation established pursuant to section 112 of the Act that applies to the collection of equipment, activities, or both regulated by such standard or limitation.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-4 of 45
A relevant standard may include or consist of a design, equipment, work practice, or operational requirement, or other measure, process, method, system, or technique (including prohibition of emissions) that the Administrator (or a State) establishes for new or existing sources to which such standard or limitation applies. Every relevant standard established pursuant to section 112 of the Act includes subpart A of this part, as provided by &sect; 63.1(a)(4), and all applicable appendices of this part or of other parts of this chapter that are referenced in that standard.Responsible official means one of the following:
 
(1) For a corporation:
APPENDIX NESHAP SUBPART A General Provisions Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a title V permit occurs immediately after the EPA takes final action on the final permit.
A president, secretary, treasurer, or vice president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision-making functions for the corporation, or a duly authorized representative of such person if the representative is responsible for the overall operation of one or more manufacturing, production, or operating facilities and either: (i) The facilities employ more than 250 persons or have gross annual sales or expenditures exceeding  
Major source means any stationary source or group of stationary sources located within a contiguous area and under common control that emits or has the potential to emit considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants, unless the Administrator establishes a lesser quantity, or in the case of radionuclides, different criteria from those specified in this sentence.
$25 million (in second quarter 1980 dollars);
Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control and monitoring equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded. Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
or (ii) The delegation of authority to such representative is approved in advance by the Administrator.
Monitoring means the collection and use of measurement data or other information to control the operation of a process or pollution control device or to verify a work practice standard relative to assuring compliance with applicable requirements. Monitoring is composed of four elements:
(2) For a partnership or sole proprietorship:
(1) Indicator(s) of performance -- the parameter or parameters you measure or observe for demonstrating proper operation of the pollution control measures or compliance with the applicable emissions limitation or standard. Indicators of performance may include direct or predicted emissions measurements (including opacity),
a general partner or the proprietor, respectively.
operational parametric values that correspond to process or control device (and capture system) efficiencies or emissions rates, and recorded findings of inspection of work practice activities, materials tracking, or design characteristics. Indicators may be expressed as a single maximum or minimum value, a function of process variables (for example, within a range of pressure drops), a particular operational or work practice status (for example, a damper position, completion of a waste recovery task, materials tracking), or an interdependency between two or among more than two variables.
(3) For a municipality, State, Federal, or other public agency: either a principal executive officer or ranking elected official.
(2) Measurement techniques -- the means by which you gather and record information of or about the indicators of performance. The components of the measurement technique include the detector type, location and installation specifications, inspection procedures, and quality assurance and quality control measures. Examples of measurement techniques include continuous emission monitoring systems, continuous opacity monitoring systems, continuous parametric monitoring systems, and manual inspections that include making records of process conditions or work practices.
For the purposes of this part, a principal executive officer of a Federal agency includes the chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency (e.g., a Regional Administrator of the EPA).Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-6 of 45 APPENDIX NESHAP SUBPART A General Provisions (4) For affected sources (as defined in this part) applying for or subject to a title V permit: "responsible official" shall have the same meaning as defined in part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever is applicable.
(3) Monitoring frequency -- the number of times you obtain and record monitoring data over a specified time interval. Examples of monitoring frequencies include at least four points equally spaced for each hour for continuous emissions or parametric monitoring systems, at least every 10 seconds for continuous opacity monitoring systems, and at least once per operating day (or week, month, etc.) for work practice or design inspections.
Run means one of a series of emission or other measurements needed to determine emissions for a representative operating period or cycle as specified in this part.Shutdown means the cessation of operation of an affected source or portion of an affected source for any purpose.Six-minute period means, with respect to opacity determinations, any one of the 10 equal parts of a 1-hour period.Standard conditions means a temperature of 293 'K (680 F) and a pressure of 101.3 kilopascals (29.92 in. Hg).Startup means the setting in operation of an affected source for any purpose.State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement:
(4) Averaging time -- the period over which you average and use data to verify proper operation of the pollution control approach or compliance with the emissions limitation or standard. Examples of averaging time include a 3-hour average in units of the emissions limitation, a 30-day rolling average emissions value, a daily average of a control device operational parametric range, and an instantaneous alarm.
(1) The provisions of this part and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context.Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant.
New affected source means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory that is subject to a section 112(d) or other relevant standard for new sources. This definition of "new affected source," and the criteria to be utilized in implementing it, shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002. Each relevant standard will define the term "new affected source," which will be the same as the "affected source" unless a different collection is warranted based on consideration of factors including:
Test method means the validated procedure for sampling, preparing, and analyzing for an air pollutant specified in a relevant standard as the performance test procedure.
(1) Emission reduction impacts of controlling individual sources versus groups of sources; (2) Cost effectiveness of controlling individual equipment; (3) Flexibility to accommodate common control strategies; (4) Cost/benefits of emissions averaging; (5) Incentives for pollution prevention; (6) Feasibility and cost of controlling processes that share common equipment (e.g., product recovery devices);
The test method may include methods described in an appendix of this chapter, test methods incorporated by reference in this part, or methods validated for an application through procedures in Method 301 of appendix A of this part.Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part.Visible emission means the observation of an emission of opacity or optical density above the threshold of vision.Working day means any day on which Federal Government offices (or State government offices for a State that has obtained delegation under section 112(1)) are open for normal business.
(7) Feasibility and cost of monitoring; and (8) Other relevant factors.
Saturdays, Sundays, and official Federal (or where delegated, State) holidays are not working days.&sect; 63.3 Units and abbreviations.
New source means any affected source the construction or reconstruction of which is commenced after the Administrator first proposes a relevant emission standard under this part establishing an emission standard applicable to such source.
Used in this part are abbreviations and symbols of units of measure. These are defined as follows: (a) System International (SI) units of measure: A = ampere g = gram Hz = hertz J =joule K= degree Kelvin kg = kilogram I = liter m = meter m3= cubic meter mg= milligram  
Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background. For continuous opacity monitoring systems, opacity means the fraction of incident light that is attenuated by an optical medium.
= 10 -3 gram ml = milliliter  
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-5 of 45
= 10 -3 liter mm = millimeter  
 
= 10 -3 meter Mg = megagram = 106 gram = metric ton MJ = megajoule mol = mole N = newton ng = nanogram = 10 -9_gram nm = nanometer  
APPENDIX NESHAP SUBPART A General Provisions Owner or operatormeans any person who owns, leases, operates, controls, or supervises a stationary source..
= 10 -meter Pa = pascal s = second V = volt W = watt= ohm g= microgram  
Performance audit means a procedure to analyze blind samples, the content of which is known by the Administrator, simultaneously with the analysis of performance test samples in order to provide a measure of test data quality.
= 10-6 gram tl= microliter  
Performance evaluation means the conduct of relative accuracy testing, calibration error testing, and other measurements used in validating the continuous monitoring system data.
= 10 -6 liter Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-7 of 45 APPENDIX NESHAP SUBPART A General Provisions (b) Other units of measure: Btu = British thermal unit'C = degree Celsius (centigrade) cal = calorie cfm = cubic feet per minute cc = cubic centimeter cu ft = cubic feet d = day dcf = dry cubic feet dcm = dry cubic meter dscf = dry cubic feet at standard conditions dscm = dry cubic meter at standard conditions eq = equivalent
Performancetest means the collection of data resulting from the execution of a test method (usually three emission test runs) used to demonstrate compliance with a relevant emission standard as specified in the performance test section of the relevant standard.
'F = degree Fahrenheit ft = feet ft 2 = square feet ft 3 = cubic feet gal = gallon gr = grain g-eq = gram equivalent g-mole = gram mole hr = hour in. = inch in. H 2 0 = inches of water K = 1,000 kcal = kilocalorie lb = pound 1pm = liter per minute meq = milliequivalent min = minute MW = molecular weight oz = ounces ppb = parts per billion ppbw = parts per billion by weight ppbv = parts per billion by volume ppm = parts per million ppmw = parts per million by weight ppmv = parts per million by volume psia = pounds per square inch absolute psig = pounds per square inch gage'R = degree Rankine scf = cubic feet at standard conditions scfh = cubic feet at standard conditions per hour scm = cubic meter at standard conditions scmm= cubic meter at standard conditions per minute sec = second sq ft = square feet std = at standard conditions v/v = volume per volume yd 2 = square yards yr = year (c) Miscellaneous:
Permit modification means a change to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).
act = actual avg = average I.D. = inside diameter M = molar N = normal Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-8 of 45 APPENDIX NESHAP SUBPART A General Provisions O.D. = outside diameter% = percent&sect; 63.4 Prohibited activities and circumvention.(a) Prohibited activities.
Permitprogram means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C. 7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter.
(1) No owner or operator subject to the provisions of this part must operate any affected source in violation of the requirements of this part. Affected sources subject to and in compliance with either an extension of compliance or an exemption from compliance are not in violation of the requirements of this part. An extension of compliance can be granted by the Administrator under this part; by a State with an approved permit program; or by the President under section 112(i)(4)of the Act.(2) No owner or operator subject to the provisions of this part shall fail to keep records, notify, report, or revise reports as required under this part.(3) [Reserved]
Permit revision means any permit modification or administrative permit amendment to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661).
Permittingauthority means:
(1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661).
Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable.
Reconstruction means the replacement of components of an affected or a previously unaffected stationary source to such an extent that:
(1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable new source; and (2) It is technologically and economically feasible for the reconstructed source to meet the relevant standard(s) established by the Administrator (or a State) pursuant to section 112 of the Act. Upon reconstruction, an affected source, or a stationary source that becomes an affected source, is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.
Regulation promulgationschedule means the schedule for the promulgation of emission standards under this part, established by the Administrator pursuant to section 112(e) of the Act and published in the FEDERAL REGISTER.
Relevant standardmeans:
(1) An emission standard; (2) An alternative emission standard; (3) An alternative emission limitation; or (4) An equivalent emission limitation established pursuant to section 112 of the Act that applies to the collection of equipment, activities, or both regulated by such standard or limitation. A relevant standard may include or consist of a design, equipment, work practice, or operational requirement, or other measure, process, method, system, or technique (including prohibition of emissions) that the Administrator (or a State) establishes for new or existing sources to which such standard or limitation applies. Every relevant standard established pursuant to section 112 of the Act includes subpart A of this part, as provided by &sect; 63.1(a)(4), and all applicable appendices of this part or of other parts of this chapter that are referenced in that standard.
Responsible official means one of the following:
(1) For a corporation: A president, secretary, treasurer, or vice president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision-making functions for the corporation, or a duly authorized representative of such person if the representative is responsible for the overall operation of one or more manufacturing, production, or operating facilities and either:
(i) The facilities employ more than 250 persons or have gross annual sales or expenditures exceeding $25 million (in second quarter 1980 dollars); or (ii) The delegation of authority to such representative is approved in advance by the Administrator.
(2) For a partnership or sole proprietorship: a general partner or the proprietor, respectively.
(3) For a municipality, State, Federal, or other public agency: either a principal executive officer or ranking elected official. For the purposes of this part, a principal executive officer of a Federal agency includes the chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency (e.g., a Regional Administrator of the EPA).
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-6 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (4) For affected sources (as defined in this part) applying for or subject to a title V permit: "responsible official" shall have the same meaning as defined in part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever is applicable.
Run means one of a series of emission or other measurements needed to determine emissions for a representative operating period or cycle as specified in this part.
Shutdown means the cessation of operation of an affected source or portion of an affected source for any purpose.
Six-minute period means, with respect to opacity determinations, any one of the 10 equal parts of a 1-hour period.
Standardconditions means a temperature of 293 'K (680 F) and a pressure of 101.3 kilopascals (29.92 in. Hg).
Startup means the setting in operation of an affected source for any purpose.
State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement:
(1) The provisions of this part and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context.
Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant.
Test method means the validated procedure for sampling, preparing, and analyzing for an air pollutant specified in a relevant standard as the performance test procedure. The test method may include methods described in an appendix of this chapter, test methods incorporated by reference in this part, or methods validated for an application through procedures in Method 301 of appendix A of this part.
Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part.
Visible emission means the observation of an emission of opacity or optical density above the threshold of vision.
Working day means any day on which Federal Government offices (or State government offices for a State that has obtained delegation under section 112(1)) are open for normal business. Saturdays, Sundays, and official Federal (or where delegated, State) holidays are not working days.
&sect; 63.3 Units and abbreviations.
Used in this part are abbreviations and symbols of units of measure. These are defined as follows:
(a) System International (SI) units of measure:
A = ampere g = gram Hz = hertz J =joule K= degree Kelvin kg = kilogram I = liter m = meter m3= cubic meter mg= milligram = 10 -3 gram ml = milliliter = 10 -3 liter mm = millimeter = 10 -3 meter Mg = megagram = 106 gram = metric ton MJ = megajoule mol = mole N = newton ng = nanogram = 10 -9_gram nm = nanometer = 10 - meter Pa = pascal s = second V = volt W = watt
            = ohm g= microgram = 10-6 gram tl= microliter = 10 -6 liter Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-7 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (b) Other units of measure:
Btu = British thermal unit
          'C = degree Celsius (centigrade) cal = calorie cfm = cubic feet per minute cc = cubic centimeter cu ft = cubic feet d = day dcf = dry cubic feet dcm = dry cubic meter dscf = dry cubic feet at standard conditions dscm = dry cubic meter at standard conditions eq = equivalent
          'F = degree Fahrenheit ft = feet ft 2 = square feet ft 3 = cubic feet gal = gallon gr = grain g-eq = gram equivalent g-mole = gram mole hr = hour in. = inch in. H 20 = inches of water K = 1,000 kcal = kilocalorie lb = pound 1pm = liter per minute meq = milliequivalent min = minute MW = molecular weight oz = ounces ppb = parts per billion ppbw = parts per billion by weight ppbv = parts per billion by volume ppm = parts per million ppmw = parts per million by weight ppmv = parts per million by volume psia = pounds per square inch absolute psig = pounds per square inch gage
        'R = degree Rankine scf = cubic feet at standard conditions scfh = cubic feet at standard conditions per hour scm = cubic meter at standard conditions scmm= cubic meter at standard conditions per minute sec = second sq ft = square feet std = at standard conditions v/v = volume per volume yd 2 = square yards yr = year (c) Miscellaneous:
act = actual avg = average I.D. = inside diameter M = molar N = normal Progress Energy Florida, Inc.                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                     Title V Permit Renewal Page NESHAPA-8 of 45
 
APPENDIX NESHAP SUBPART A General Provisions O.D. = outside diameter
          % = percent
&sect; 63.4 Prohibited activities and circumvention.
(a) Prohibitedactivities.
(1) No owner or operator subject to the provisions of this part must operate any affected source in violation of the requirements of this part. Affected sources subject to and in compliance with either an extension of compliance or an exemption from compliance are not in violation of the requirements of this part. An extension of compliance can be granted by the Administrator under this part; by a State with an approved permit program; or by the President under section 112(i)(4) of the Act.
(2) No owner or operator subject to the provisions of this part shall fail to keep records, notify, report, or revise reports as required under this part.
(3) [Reserved]
(4) [Reserved]
(4) [Reserved]
(5) [Reserved](b) Circumvention.
(5) [Reserved]
No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard.
(b) Circumvention. No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard. Such concealment includes, but is not limited to (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; (2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions; and (3) [Reserved]
Such concealment includes, but is not limited to (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; (2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions; and (3) [Reserved](c) Severability.
(c) Severability. Notwithstanding any requirement incorporated into a title V permit obtained by an owner or operator subject to the provisions of this part, the provisions of this part are federally enforceable.
Notwithstanding any requirement incorporated into a title V permit obtained by an owner or operator subject to the provisions of this part, the provisions of this part are federally enforceable.
&sect; 63.5 Preconstruction review and notification requirements.
&sect; 63.5 Preconstruction review and notification requirements.(a) Applicability.
(a) Applicability.
(1) This section implements the preconstruction review requirements of section 112(i)(1) for sources subject to a relevant emission standard that has been promulgated in this part. In addition, this section includes other requirements for constructed and reconstructed stationary sources that are or become subject to a relevant promulgated emission standard.(2) After the effective date of a relevant standard promulgated under this part, the requirements in this section apply to owners or operators who construct a new source or reconstruct a source after the proposal date of that standard.
(1) This section implements the preconstruction review requirements of section 112(i)(1) for sources subject to a relevant emission standard that has been promulgated in this part. In addition, this section includes other requirements for constructed and reconstructed stationary sources that are or become subject to a relevant promulgated emission standard.
New or reconstructed sources that start up before the standard's effective date are not subject to the preconstruction review requirements specified in paragraphs (b)(3), (d), and (e) of this section.(b) Requirements for existing, newly constructed, and reconstructed sources.(1) A new affected source for which construction commences after proposal of a relevant standard is subject to relevant standards for new affected sources, including compliance dates. An affected source for which reconstruction commences after proposal of a relevant standard is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.(2) [Reserved]
(2) After the effective date of a relevant standard promulgated under this part, the requirements in this section apply to owners or operators who construct a new source or reconstruct a source after the proposal date of that standard. New or reconstructed sources that start up before the standard's effective date are not subject to the preconstruction review requirements specified in paragraphs (b)(3), (d), and (e) of this section.
(3) After the effective date of any relevant standard promulgated by the Administrator under this part, no person may, without obtaining written approval in advance from the Administrator in accordance with the procedures specified in paragraphs (d) and (e) of this section, do any of the following: (i) Construct a new affected source that is major-emitting and subject to such standard;(ii) Reconstruct an affected source that is major-emitting and subject to such standard; or (iii) Reconstruct a major source such that the source becomes an affected source that is major-emitting and subject to the standard.(4) After the effective date of any relevant standard promulgated by the Administrator under this part, an owner or operator who constructs a new affected source that is not major-emitting or reconstructs an affected source that is not major-emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-9 of 45 APPENDIX NESHAP SUBPART A General Provisions the standard, must notify the Administrator of the intended construction or reconstruction.
(b) Requirementsfor existing, newly constructed, and reconstructedsources.
The notification must be submitted in accordance with the procedures in &sect; 63.9(b).(5) [Reserved]
(1) A new affected source for which construction commences after proposal of a relevant standard is subject to relevant standards for new affected sources, including compliance dates. An affected source for which reconstruction commences after proposal of a relevant standard is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source.
(6) After the effective date of any relevant standard promulgated by the Administrator under this part, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source.(c) [Reserved](d) Application for approval of construction or reconstruction.
The provisions of this paragraph implement section 1 12(i)(1)of the Act.(1) General application requirements.(i) An owner or operator who is subject to the requirements of paragraph (b)(3) of this section must submit to the Administrator an application for approval of the construction or reconstruction.
The application must be submitted as soon as practicable before actual construction or reconstruction begins. The application for approval of construction or reconstruction may be used to fulfill the initial notification requirements of &sect; 63.9(b)(5).
The owner or operator may submit the application for approval well in advance of the date actual construction or reconstruction begins in order to ensure a timely review by the Administrator and that the planned date to begin will not be delayed.(ii) A separate application shall be submitted for each construction or reconstruction.
Each application for approval of construction or reconstruction shall include at a minimum: (A) The applicant's name and address;(B) A notification of intention to construct a new major affected source or make any physical or operational change to a major affected source that may meet or has been determined to meet the criteria for a reconstruction, as defined in &sect; 63.2 or in the relevant standard;(C) The address (i.e., physical location) or proposed address of the source;(D) An identification of the relevant standard that is the basis of the application;(E) The expected date of the beginning of actual construction or reconstruction;(F) The expected completion date of the construction or reconstruction;(G) [Reserved](H) The type and quantity of hazardous air pollutants emitted by the source, reported in units and averaging times and in accordance with the test methods specified in the relevant standard, or if actual emissions data are not yet available, an estimate of the type and quantity of hazardous air pollutants expected to be emitted by the source reported in units and averaging times specified in the relevant standard.
The owner or operator may submit percent reduction information if a relevant standard is established in terms of percent reduction.
However, operating parameters, such as flow rate, shall be included in the submission to the extent that they demonstrate performance and compliance; and (I) [Reserved](J) Other information as specified in paragraphs (d)(2) and (d)(3) of this section.(iii) An owner or operator who submits estimates or preliminary information in place of the actual emissions data and analysis required in paragraphs (d)(1)(ii)(H) and (d)(2) of this section shall submit the actual, measured emissions data and other correct information as soon as available but no later than with the notification of compliance status required in &sect; 63.9(h) (see&sect; 63.9(h)(5)).
(2) Application for approval of construction.
Each application for approval of construction must include, in addition to the information required in paragraph (d)(1)(ii) of this section, technical information describing the proposed nature, size, design, operating design capacity, and method of operation of the source, including an identification of each type of emission point for each type of hazardous air pollutant that is emitted (or could reasonably be anticipated to be emitted) and a description of the planned air pollution control system (equipment or method) for each emission point. The description of the equipment to be used for the control of emissions must include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions must include an estimated control efficiency (percent) for that method. Such technical information must include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-10 of 45 APPENDIX NESHAP SUBPART A General Provisions (3) Application for approval of reconstruction.
Each application for approval of reconstruction shall include, in addition to the information required in paragraph (d)(1)(ii) of this section -(i) A brief description of the affected source and the components that are to be replaced;(ii) A description of present and proposed emission control systems (i.e., equipment or methods).
The description of the equipment to be used for the control of emissions shall include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions shall include an estimated control efficiency (percent) for that method. Such technical information shall include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations;(iii) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new source;(iv) The estimated life of the affected source after the replacements; and (v) A discussion of any economic or technical limitations the source may have in complying with relevant standards or other requirements after the proposed replacements.
The discussion shall be sufficiently detailed to demonstrate to the Administrator's satisfaction that the technical or economic limitations affect the source's ability to comply with the relevant standard and how they do so.(vi) If in the application for approval of reconstruction the owner or operator designates the affected source as a reconstructed source and declares that there are no economic or technical limitations to prevent the source from complying with all relevant standards or other requirements, the owner or operator need not submit the information required in paragraphs (d)(3)(iii) through (d)(3)(v) of this section.(4) Additional information.
The Administrator may request additional relevant information after the submittal of an application for approval of construction or reconstruction.(e) Approval of construction or reconstruction.
(1) (i) If the Administrator determines that, if properly constructed, or reconstructed, and operated, a new or existing source for which an application under paragraph (d) of this section was submitted will not cause emissions in violation of the relevant standard(s) and any other federally enforceable requirements, the Administrator will approve the construction or reconstruction.(ii) In addition, in the case of reconstruction, the Administrator's determination under this paragraph will be based on: (A) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new source;(B) The estimated life of the source after the re-placements compared to the life of a comparable entirely new source;(C) The extent to which the components being replaced cause or contribute to the emissions from the source; and (D) Any economic or technical limitations on compliance with relevant standards that are inherent in the proposed replacements.
(2) (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of construction or reconstruction within 60 calendar days after receipt of sufficient information to evaluate an application submitted under paragraph (d) of this section. The 60-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete.
The Administrator will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted.(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.
(3) Before denying any application for approval of construction or reconstruction, the Administrator will notify the applicant of the Administrator's intention to issue the denial together with -(i) Notice of the information and findings on which the intended denial is based; and (ii) Notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator to enable further action on the application.
(4) A final determination to deny any application for approval will be in writing and will specify the grounds on which the denial is based. The final determination will be made within 60 calendar days of presentation of additional information or arguments (if the application is complete), or within 60 calendar days after the final date specified for presentation if no presentation is made.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-11 of 45 APPENDIX NESHAP SUBPART A General Provisions (5) Neither the submission of an application for approval nor the Administrator's approval of construction or reconstruction shall -(i) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (ii) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.(f) Approval of construction or reconstruction based on prior State preconstruction review.(1) Preconstruction review procedures that a State utilizes for other purposes may also be utilized for purposes of this section if the procedures are substantially equivalent to those specified in this section. The Administrator will approve an application for construction or reconstruction specified in paragraphs (b)(3) and (d) of this section if the owner or operator of a new affected source or reconstructed affected source, who is subject to such requirement meets the following conditions: (i) The owner or operator of the new affected source or reconstructed affected source has undergone a preconstruction review and approval process in the State in which the source is (or would be) located and has received a federally enforceable construction permit that contains a finding that the source will meet the relevant promulgated emission standard, if the source is properly built and operated.(ii) Provide a statement from the State or other evidence (such as State regulations) that it considered the factors specified in paragraph (e)(1) of this section.(2) The owner or operator must submit to the Administrator the request for approval of construction or reconstruction under this paragraph (f)(2) no later than the application deadline specified in paragraph (d)(1) of this section (see also &sect; 63.9(b)(2)).
The owner or operator must include in the request information sufficient for the Administrator's determination.
The Administrator will evaluate the owner or operator's request in accordance with the procedures specified in paragraph (e) of this section. The Administrator may request additional relevant information after the submittal of a request for approval of construction or reconstruction under this paragraph (f)(2).&sect; 63.6 Compliance with standards and maintenance requirements.(a) Applicability.
(1) The requirements in this section apply to the owner or operator of affected sources for which any relevant standard has been established pursuant to section 112 of the Act and the applicability of such requirements is set out in accordance with &sect; 63.1(a)(4) unless --(i) The Administrator (or a State with an approved permit program) has granted an extension of compliance consistent with paragraph (i) of this section; or (ii) The President has granted an exemption from compliance with any relevant standard in accordance with section 112(i)(4) of the Act.(2) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source, such source shall be subject to the relevant emission standard or other requirement.(b) Compliance dates for new and reconstructed sources.(1) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source for which construction or reconstruction commences after proposal of a relevant standard that has an initial startup before the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard not later than the standard's effective date.(2) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source that has an initial startup after the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard upon startup of the source'(3) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established under this part pursuant to section 112(d), 112(f), or 112(h) of the Act but before the effective date (that is, promulgation) of such standard shall comply with the relevant emission standard not later than the date 3 years after the effective date if: (i) The promulgated standard (that is, the relevant standard) is more stringent than the proposed standard;for purposes of this paragraph, a finding that controls or compliance methods are "more stringent" must include control technologies or performance criteria and compliance or compliance assurance methods that are different but are substantially equivalent to those required by the promulgated rule, as determined by the Administrator (or his or her authorized representative);
and (ii) The owner or operator complies with the standard as proposed during the 3-year period immediately after the effective date.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-12 of 45 APPENDIX NESHAP SUBPART A General Provisions (4) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established pursuant to section 112(d) of the Act but before the proposal date of a relevant standard established pursuant to section 112(f) shall not be required to comply with the section 112(f) emission standard until the date 10 years after the date construction or reconstruction is commenced, except that, if the section 112(f)standard is promulgated more than 10 years after construction or reconstruction is commenced, the owner or operator must comply with the standard as provided in paragraphs (b)(1) and (2) of this section.(5) The owner or operator of a new source that is subject to the compliance requirements of paragraph (b)(3) or (4)of this section must notify the Administrator in accordance with &sect; 63.9(d).(6) [Reserved]
(7) When an area source becomes a major source by the addition of equipment or operations that meet the definition of new affected source in the relevant standard, the portion of the existing facility that is a new affected source must comply with all requirements of that standard applicable to new sources. The source owner or operator must comply with the relevant standard upon startup.(c) Compliance dates for existing sources.(1) After the effective date of a relevant standard established under this part pursuant to section 112(d) or 112(h) of the Act, the owner or operator of an existing source shall comply with such standard by the compliance date established by the Administrator in the applicable subpart(s) of this part. Except as otherwise provided for in section 112 of the Act, in no case will the compliance date established for an existing source in an applicable subpart of this part exceed 3 years after the effective date of such standard.(2) If an existing source is subject to a standard established under this part pursuant to section 112(f) of the Act, the owner or operator must comply with the standard by the date 90 days after the standard's effective date, or by the date specified in an extension granted to the source by the Administrator under paragraph (i)(4)(ii) of this section, whichever is later.(3)-(4) [Reserved]
(5) Except as provided in paragraph (b)(7) of this section, the owner or operator of an area source that increases its emissions of (or its potential to emit) hazardous air pollutants such that the source becomes a major source shall be subject to relevant standards for existing sources. Such sources must comply by the date specified in the standards for existing area sources that become major sources. If no such compliance date is specified in the standards, the source shall have a period of time to comply with the relevant emission standard that is equivalent to the compliance period specified in the relevant standard for existing sources in existence at the time the standard becomes effective.(d) [Reserved](e) Operation and maintenance requirements.
(1) (i) At all times, including periods of startup, shutdown, and malfunction, the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions.
During a period of startup, shutdown, or malfunction, this general duty to minimize emissions requires that the owner or operator reduce emissions from the affected source to the greatest extent which is consistent with safety and good air pollution control practices.
The general duty to minimize emissions during a period of startup, shutdown, or malfunction does not require the owner or operator to achieve emission levels that would be required by the applicable standard at other times if this is not consistent with safety and good air pollution control practices, nor does it require the owner or operator to make any further efforts to reduce emissions if levels required by the applicable standard have been achieved.
Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures (including the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section), review of operation and maintenance records, and inspection of the source.(ii) Malfunctions must be corrected as soon as practicable after their occurrence in accordance with the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section. To the extent that an unexpected event arises during a startup, shutdown, or malfunction, an owner or operator must comply by minimizing emissions during such a startup, shutdown, and malfunction event consistent with safety and good air pollution control practices.(iii) Operation and maintenance requirements established pursuant to section 112 of the Act are enforceable independent of emissions limitations or other requirements in relevant standards.
(2) [Reserved]
(2) [Reserved]
(3) Startup, shutdown, and malfunction plan.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-13 of 45 APPENDIX NESHAP SUBPART A General Provisions (i)The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan that describes, in detail, procedures for operating and maintaining the source during periods of startup, shutdown, and malfunction, and a program of corrective action for malfunctioning process and air pollution control and monitoring equipment used to comply with the relevant standard.(A) Ensure that, at all times, the owner or operator operates and maintains each affected source, including associated air pollution control and monitoring equipment, in a manner which satisfies the general duty to minimize emissions established by paragraph (e)(1)(i) of this section;(B) Ensure that owners or operators are prepared to correct malfunctions as soon as practicable after their occurrence in order to minimize excess emissions of hazardous air pollutants; and (C) Reduce the reporting burden associated with periods of startup, shutdown, and malfunction (including corrective action taken to restore malfunctioning process and air pollution control equipment to its normal or usual manner of operation).(ii) During periods of startup, shutdown, and malfunction, the owner or operator of an affected source must operate and maintain such source (including associated air pollution control and monitoring equipment) in accordance with the procedures specified in the startup, shutdown, and malfunction plan developed under paragraph (e)(3)(i) of this section.(iii) When actions taken by the owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) are consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, the owner or operator must keep records for that event which demonstrate that the procedures specified in the plan were followed.
(3) After the effective date of any relevant standard promulgated by the Administrator under this part, no person may, without obtaining written approval in advance from the Administrator in accordance with the procedures specified in paragraphs (d) and (e) of this section, do any of the following:
These records may take the form of a "checklist," or other effective form of recordkeeping that confirms conformance with the startup, shutdown, and malfunction plan for that event. In addition, the owner or operator must keep records of these events as specified in &sect; 63.10(b), including records of the occurrence and duration of each startup, shutdown, or malfunction of operation and each malfunction of the air pollution control and monitoring equipment.
(i) Construct a new affected source that is major-emitting and subject to such standard; (ii) Reconstruct an affected source that is major-emitting and subject to such standard; or (iii) Reconstruct a major source such that the source becomes an affected source that is major-emitting and subject to the standard.
Furthermore, the owner or operator shall confirm that actions taken during the relevant reporting period during periods of startup, shutdown, and malfunction were consistent with the affected source's startup, shutdown and malfunction plan in the semiannual (or more frequent) startup, shutdown, and malfunction report required in &sect; 63.10(d)(5).(iv) If an action taken by the owner or operator during a startup, shutdown, or malfunction (including an action taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, then the owner or operator must record the actions taken for that event and must report such actions within 2 working days after commencing actions inconsistent with the plan, followed by a letter within 7 working days after the end of the event, in accordance with Sec. 63.10(d)(5) (unless the owner or operator makes alternative reporting arrangements, in advance, with the Administrator).(v) The owner or operator must maintain at the affected source a current startup, shutdown, and malfunction plan and must make the plan available upon request for inspection and copying by the Administrator.
(4) After the effective date of any relevant standard promulgated by the Administrator under this part, an owner or operator who constructs a new affected source that is not major-emitting or reconstructs an affected source that is not major-emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to Progress Energy Florida, Inc.                                                                        Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPA-9 of 45
In addition, if the startup, shutdown, and malfunction plan is subsequently revised as provided in paragraph (e)(3)(viii) of this section, the owner or operator must maintain at the affected source each previous (i.e., superseded) version of the startup, shutdown, and malfunction plan, and must make each such previous version available for inspection and copying by the Administrator for a period of 5 years after revision of the plan. If at any time after adoption of a startup, shutdown, and malfunction plan the affected source ceases operation or is otherwise no longer subject to the provisions of this part, the owner or operator must retain a copy of the most recent plan for 5 years from the date the source ceases operation or is no longer subject to this part and must make the plan available upon request for inspection and copying by the Administrator.
 
The Administrator may at any time request in writing that the owner or operator submit a copy of any startup, shutdown, and malfunction plan (or a portion thereof) which is maintained at the affected source or in the possession of the owner or operator.
APPENDIX NESHAP SUBPART A General Provisions the standard, must notify the Administrator of the intended construction or reconstruction. The notification must be submitted in accordance with the procedures in &sect; 63.9(b).
Upon receipt of such a request, the owner or operator must promptly submit a copy of the requested plan (or a portion thereof) to the Administrator.
(5) [Reserved]
The Administrator must request that the owner or operator submit a particular startup, shutdown, or malfunction plan (or a portion thereof) whenever a member of the public submits a specific and reasonable request to examine or to receive a copy of that plan or portion of a plan. The owner or operator may elect to submit the required copy of any startup, shutdown, and malfunction plan to the Administrator in an electronic format. If the owner or operator claims that any portion of such a startup, shutdown, and malfunction plan is confidential business information entitled to protection from disclosure under section 114(c) of the Act or 40 CFR 2.30 1, the material which is claimed as confidential must be clearly designated in the submission.(vi) To satisfy the requirements of this section to develop a startup, shutdown, and malfunction plan, the owner or operator may use the affected source's standard operating procedures (SOP) manual, or an Occupational Safety and Health Administration (OSHA) or other plan, provided the alternative plans meet all the requirements of this section and are made available for inspection or submitted when requested by the Administrator.(vii) Based on the results of a determination made under paragraph (e)(1)(i) of this section, the Administrator may require that an owner or operator of an affected source make changes to the startup, shutdown, and Progress Energy Florida, Inc. Permit No.
(6) After the effective date of any relevant standard promulgated by the Administrator under this part, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source.
Crystal River Power Plant Title V Permit Renewal Page NESHAPA-14 of 45 APPENDIX NESHAP SUBPART A General Provisions malfunction plan for that source. The Administrator must require appropriate revisions to a startup, shutdown, and malfunction plan, if the Administrator finds that the plan: (A) Does not address a startup, shutdown, or malfunction event that has occurred;(B) Fails to provide for the operation of the source (including associated air pollution control and monitoring equipment) during a startup, shutdown, or malfunction event in a manner consistent with the general duty to minimize emissions established by paragraph (e)(1)(i) of this section;(C) Does not provide adequate procedures for correcting malfunctioning process and/or air pollution control and monitoring equipment as quickly as practicable; or (D) Includes an event that does not meet the definition of startup, shutdown, or malfunction listed in&sect; 63.2.(viii) The owner or operator may periodically revise the startup, shutdown, and malfunction plan for the affected source as necessary to satisfy the requirements of this part or to reflect changes in equipment or procedures at the affected source. Unless the permitting authority provides otherwise, the owner or operator may make such revisions to the startup, shutdown, and malfunction plan without prior approval by the Administrator or the permitting authority.
(c) [Reserved]
However, each such revision to a startup, shutdown, and malfunction plan must be reported in the semiannual report required by&sect; 63.10(d)(5).
(d) Applicationfor approval of construction or reconstruction.The provisions of this paragraph implement section 1 12(i)(1) of the Act.
If the startup, shutdown, and malfunction plan fails to address or inadequately addresses an event that meets the characteristics of a malfunction but was not included in the startup, shutdown, and malfunction plan at the time the owner or operator developed the plan, the owner or operator must revise the startup, shutdown, and malfunction plan within 45 days after the event to include detailed procedures for operating and maintaining the source during similar malfunction events and a program of corrective action for similar malfunctions of process or air pollution control and monitoring equipment.
(1) General application requirements.
In the event that the owner or operator makes any revision to the startup, shutdown, and malfunction plan which alters the scope of the activities at the source which are deemed to be a startup, shutdown, or malfunction, or otherwise modifies the applicability of any emission limit, work practice requirement, or other requirement in a standard established under this part, the revised plan shall not take effect until after the owner or operator has provided a written notice describing the revision to the permitting authority.(ix) The title V permit for an affected source must require that the owner or operator adopt a startup, shutdown, and malfunction plan which conforms to the provisions of this part, and that the owner or operator operate and maintain the source in accordance with the procedures specified in the current startup, shutdown, and malfunction plan.However, any revisions made to the startup, shutdown, and malfunction plan in accordance with the procedures established by this part shall not be deemed to constitute permit revisions under part 70 or part 71 of this chapter. Moreover, none of the procedures specified by the startup, shutdown, and malfunction plan for an affected source shall be deemed to fall within the permit shield provision in section 504(f) of the Act.(f) Compliance with nonopacity emission standards  
(i)       An owner or operator who is subject to the requirements of paragraph (b)(3) of this section must submit to the Administrator an application for approval of the construction or reconstruction. The application must be submitted as soon as practicable before actual construction or reconstruction begins. The application for approval of construction or reconstruction may be used to fulfill the initial notification requirements of &sect; 63.9(b)(5). The owner or operator may submit the application for approval well in advance of the date actual construction or reconstruction begins in order to ensure a timely review by the Administrator and that the planned date to begin will not be delayed.
-(1) Applicability.
(ii) A separate application shall be submitted for each construction or reconstruction. Each application for approval of construction or reconstruction shall include at a minimum:
The non-opacity emission standards set forth in this part shall apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the non-opacity emission standards set forth in this part, then that emission point must still be required to comply with the non-opacity emission standards and other applicable requirements.
(A) The applicant's name and address; (B) A notification of intention to construct a new major affected source or make any physical or operational change to a major affected source that may meet or has been determined to meet the criteria for a reconstruction, as defined in &sect; 63.2 or in the relevant standard; (C) The address (i.e., physical location) or proposed address of the source; (D) An identification of the relevant standard that is the basis of the application; (E) The expected date of the beginning of actual construction or reconstruction; (F) The expected completion date of the construction or reconstruction; (G) [Reserved]
(2) Methods for determining compliance.(i) The Administrator will determine compliance with nonopacity emission standards in this part based on the results of performance tests conducted according to the procedures in &sect; 63.7, unless otherwise specified in an applicable subpart of this part.(ii) The Administrator will determine compliance with nonopacity emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, including the evaluation of monitoring data, as specified in &sect; 63.6(e) and applicable subparts of this part.(iii) If an affected source conducts performance testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if -(A) The performance test was conducted within a reasonable amount of time before an initial performance test is required to be conducted under the relevant standard;(B) The performance test was conducted under representative operating conditions for the source;(C) The performance test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in &sect; 63.7(e) of this subpart; and (D) The performance test was appropriately quality-assured, as specified in &sect; 63.7(c).(iv) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by review of records, inspection of the source, and other procedures specified in applicable subparts of this part.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-15 of 45 APPENDIX NESHAP SUBPART A General Provisions (v) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, as specified in paragraph (e) of this section and applicable subparts of this part.(3) Finding of compliance.
(H) The type and quantity of hazardous air pollutants emitted by the source, reported in units and averaging times and in accordance with the test methods specified in the relevant standard, or if actual emissions data are not yet available, an estimate of the type and quantity of hazardous air pollutants expected to be emitted by the source reported in units and averaging times specified in the relevant standard. The owner or operator may submit percent reduction information if a relevant standard is established in terms of percent reduction.
The Administrator will make a finding concerning an affected source's compliance with a non-opacity emission standard, as specified in paragraphs (f)(1) and (2) of this section, upon obtaining all the compliance information required by the relevant standard (including the written reports of performance test results, monitoring results, and other information, if applicable), and information available to the Administrator pursuant to paragraph (e)(1)(i) of this section.(g) Use of an alternative nonopacity emission standard.(1) If, in the Administrator's judgment, an owner or operator of an affected source has established that an alternative means of emission limitation will achieve a reduction in emissions of a hazardous air pollutant from an affected source at least equivalent to the reduction in emissions of that pollutant from that source achieved under any design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act, the Administrator will publish in the FEDERAL REGISTER a notice permitting the use of the alternative emission standard for purposes of compliance with the promulgated standard.
However, operating parameters, such as flow rate, shall be included in the submission to the extent that they demonstrate performance and compliance; and (I) [Reserved]
Any FEDERAL REGISTER notice under this paragraph shall be published only after the public is notified and given the opportunity to comment. Such notice will restrict the permission to the stationary source(s) or category(ies) of sources from which the alternative emission standard will achieve equivalent emission reductions.
(J) Other information as specified in paragraphs (d)(2) and (d)(3) of this section.
The Administrator will condition permission in such notice on requirements to assure the proper operation and maintenance of equipment and practices required for compliance with the alternative emission standard and other requirements, including appropriate quality assurance and quality control requirements, that are deemed necessary.
(iii) An owner or operator who submits estimates or preliminary information in place of the actual emissions data and analysis required in paragraphs (d)(1)(ii)(H) and (d)(2) of this section shall submit the actual, measured emissions data and other correct information as soon as available but no later than with the notification of compliance status required in &sect; 63.9(h) (see
(2) An owner or operator requesting permission under this paragraph shall, unless otherwise specified in an applicable subpart, submit a proposed test plan or the results of testing and monitoring in accordance with &sect; 63.7 and &sect; 63.8, a description of the procedures followed in testing or monitoring, and a description of pertinent conditions during testing or monitoring.
&sect; 63.9(h)(5)).
Any testing or monitoring conducted to request permission to use an alternative nonopacity emission standard shall be appropriately quality assured and quality controlled, as specified in &sect; 63.7 and &sect; 63.8.(3) The Administrator may establish general procedures in an applicable subpart that accomplish the requirements of paragraphs (g)(1) and (g)(2) of this section.(h) Compliance with opacity and visible emission standards  
(2) Applicationfor approval of construction. Each application for approval of construction must include, in addition to the information required in paragraph (d)(1)(ii) of this section, technical information describing the proposed nature, size, design, operating design capacity, and method of operation of the source, including an identification of each type of emission point for each type of hazardous air pollutant that is emitted (or could reasonably be anticipated to be emitted) and a description of the planned air pollution control system (equipment or method) for each emission point. The description of the equipment to be used for the control of emissions must include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions must include an estimated control efficiency (percent) for that method. Such technical information must include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations.
-(1) Applicability.
Progress Energy Florida, Inc.                                                                          Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Permit Renewal Page NESHAPA-10 of 45
The opacity and visible emission standards set forth in this part must apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the opacity and visible emission standards set forth in this part, then that emission point shall still be required to comply with the opacity and visible emission standards and other applicable requirements.
 
(2) Methods for determining compliance.(i) The Administrator will determine compliance with opacity and visible emission standards in this part based on the results of the test method specified in an applicable subpart. Whenever a continuous opacity monitoring system (COMS) is required to be installed to determine compliance with numerical opacity emission standards in this part, compliance with opacity emission standards in this part shall be determined by using the results from the COMS. Whenever an opacity emission test method is not specified, compliance with opacity emission standards in this part shall be determined by conducting observations in accordance with Test Method 9 in appendix A of part 60 of this chapter or the method specified in paragraph (h)(7)(ii) of this section. Whenever a visible emission test method is not specified, compliance with visible emission standards in this part shall be determined by conducting observations in accordance with Test Method 22 in appendix A of part 60 of this chapter.(ii) [Reserved](iii) If an affected source undergoes opacity or visible emission testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if -(A) The opacity or visible emission test was conducted within a reasonable amount of time before a performance test is required to be conducted under the relevant standard;(B) The opacity or visible emission test was conducted under representative operating conditions for the source;(C) The opacity or visible emission test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in &sect; 63.7(e); and (D) The opacity or visible emission test was appropriately quality-assured, as specified in &sect;63.7(c) of this section.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-16 of 45 APPENDIX NESHAP SUBPART A General Provisions (3) [Reserved]
APPENDIX NESHAP SUBPART A General Provisions (3) Applicationfor approval of reconstruction.Each application for approval of reconstruction shall include, in addition to the information required in paragraph (d)(1)(ii) of this section -        (i) A brief description of the affected source and the components that are to be replaced; (ii) A description of present and proposed emission control systems (i.e., equipment or methods). The description of the equipment to be used for the control of emissions shall include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions shall include an estimated control efficiency (percent) for that method. Such technical information shall include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations; (iii) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new source; (iv) The estimated life of the affected source after the replacements; and (v) A discussion of any economic or technical limitations the source may have in complying with relevant standards or other requirements after the proposed replacements. The discussion shall be sufficiently detailed to demonstrate to the Administrator's satisfaction that the technical or economic limitations affect the source's ability to comply with the relevant standard and how they do so.
(4) Notification of opacity or visible emission observations.
(vi) If in the application for approval of reconstruction the owner or operator designates the affected source as a reconstructed source and declares that there are no economic or technical limitations to prevent the source from complying with all relevant standards or other requirements, the owner or operator need not submit the information required in paragraphs (d)(3)(iii) through (d)(3)(v) of this section.
The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting opacity or visible emission observations in accordance with &sect; 63.9(f), if such observations are required for the source by a relevant standard.(5) Conduct of opacity or visible emission observations.
(4) Additional information. The Administrator may request additional relevant information after the submittal of an application for approval of construction or reconstruction.
When a relevant standard under this part includes an opacity or visible emission standard, the owner or operator of an affected source shall comply with the following: (i) For the purpose of demonstrating initial compliance, opacity or visible emission observations shall be conducted concurrently with the initial performance test required in &sect; 63.7 unless one of the following conditions applies: (A) If no performance test under &sect; 63.7 is required, opacity or visible emission observations shall be conducted within 60 days after achieving the maximum production rate at which a new or reconstructed source will be operated, but not later than 120 days after initial startup of the source, or within 120 days after the effective date of the relevant standard in the case of new sources that start up before the standard's effective date. If no performance test under &sect;63.7 is required, opacity or visible emission observations shall be conducted within 120 days after the compliance date for an existing or modified source; or (B) If visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under &sect; 63.7, or within the time period specified in paragraph (h)(5)(i)(A) of this section, the source's owner or operator shall reschedule the opacity or visible emission observations as soon after the initial performance test, or time period, as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. The rescheduled opacity or visible emission observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under &sect; 63.7. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity or visible emission observations from being made concurrently with the initial performance test in accordance with procedures contained in Test Method 9 or Test Method 22 in appendix A of part 60 of this chapter.(ii) For the purpose of demonstrating initial compliance, the minimum total time of opacity observations shall be 3 hours (30 6-minute averages) for the performance test or other required set of observations (e.g., for fugitive-type emission sources subject only to an opacity emission standard).(iii) The owner or operator of an affected source to which an opacity or visible emission standard in this part applies shall conduct opacity or visible emission observations in accordance with the provisions of this section, record the results of the evaluation of emissions, and report to the Administrator the opacity or visible emission results in accordance with the provisions of &sect; 63.10(d).(iv) [Reserved](v) Opacity readings of portions of plumes that contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity emission standards.
(e) Approval of construction or reconstruction.
(1)      (i) If the Administrator determines that, if properly constructed, or reconstructed, and operated, a new or existing source for which an application under paragraph (d) of this section was submitted will not cause emissions in violation of the relevant standard(s) and any other federally enforceable requirements, the Administrator will approve the construction or reconstruction.
(ii) In addition, in the case of reconstruction, the Administrator's determination under this paragraph will be based on:
(A) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new source; (B) The estimated life of the source after the re-placements compared to the life of a comparable entirely new source; (C) The extent to which the components being replaced cause or contribute to the emissions from the source; and (D) Any economic or technical limitations on compliance with relevant standards that are inherent in the proposed replacements.
(2)      (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of construction or reconstruction within 60 calendar days after receipt of sufficient information to evaluate an application submitted under paragraph (d) of this section. The 60-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted.
(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.
(3) Before denying any application for approval of construction or reconstruction, the Administrator will notify the applicant of the Administrator's intention to issue the denial together with -                  (i) Notice of the information and findings on which the intended denial is based; and (ii) Notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator to enable further action on the application.
(4) A final determination to deny any application for approval will be in writing and will specify the grounds on which the denial is based. The final determination will be made within 60 calendar days of presentation of additional information or arguments (if the application is complete), or within 60 calendar days after the final date specified for presentation if no presentation is made.
Progress Energy Florida, Inc.                                                                          Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Permit Renewal Page NESHAPA-11 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (5) Neither the submission of an application for approval nor the Administrator's approval of construction or reconstruction shall -
(i) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or                (ii) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.
(f) Approval of construction or reconstructionbased on prior State preconstructionreview.
(1) Preconstruction review procedures that a State utilizes for other purposes may also be utilized for purposes of this section if the procedures are substantially equivalent to those specified in this section. The Administrator will approve an application for construction or reconstruction specified in paragraphs (b)(3) and (d) of this section if the owner or operator of a new affected source or reconstructed affected source, who is subject to such requirement meets the following conditions:
(i) The owner or operator of the new affected source or reconstructed affected source has undergone a preconstruction review and approval process in the State in which the source is (or would be) located and has received a federally enforceable construction permit that contains a finding that the source will meet the relevant promulgated emission standard, if the source is properly built and operated.
(ii) Provide a statement from the State or other evidence (such as State regulations) that it considered the factors specified in paragraph (e)(1) of this section.
(2) The owner or operator must submit to the Administrator the request for approval of construction or reconstruction under this paragraph (f)(2) no later than the application deadline specified in paragraph (d)(1) of this section (see also &sect; 63.9(b)(2)).
The owner or operator must include in the request information sufficient for the Administrator's determination. The Administrator will evaluate the owner or operator's request in accordance with the procedures specified in paragraph (e) of this section. The Administrator may request additional relevant information after the submittal of a request for approval of construction or reconstruction under this paragraph (f)(2).
&sect; 63.6 Compliance with standards and maintenance requirements.
(a) Applicability.
(1) The requirements in this section apply to the owner or operator of affected sources for which any relevant standard has been established pursuant to section 112 of the Act and the applicability of such requirements is set out in accordance with &sect; 63.1(a)(4) unless --
(i) The Administrator (or a State with an approved permit program) has granted an extension of compliance consistent with paragraph (i) of this section; or (ii) The President has granted an exemption from compliance with any relevant standard in accordance with section 112(i)(4) of the Act.
(2) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source, such source shall be subject to the relevant emission standard or other requirement.
(b) Compliance datesfor new and reconstructed sources.
(1) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source for which construction or reconstruction commences after proposal of a relevant standard that has an initial startup before the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard not later than the standard's effective date.
(2) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source that has an initial startup after the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard upon startup of the source' (3) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established under this part pursuant to section 112(d), 112(f), or 112(h) of the Act but before the effective date (that is, promulgation) of such standard shall comply with the relevant emission standard not later than the date 3 years after the effective date if:
(i) The promulgated standard (that is, the relevant standard) is more stringent than the proposed standard; for purposes of this paragraph, a finding that controls or compliance methods are "more stringent" must include control technologies or performance criteria and compliance or compliance assurance methods that are different but are substantially equivalent to those required by the promulgated rule, as determined by the Administrator (or his or her authorized representative); and (ii) The owner or operator complies with the standard as proposed during the 3-year period immediately after the effective date.
Progress Energy Florida, Inc.                                                                          Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Permit Renewal Page NESHAPA-12 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (4) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established pursuant to section 112(d) of the Act but before the proposal date of a relevant standard established pursuant to section 112(f) shall not be required to comply with the section 112(f) emission standard until the date 10 years after the date construction or reconstruction is commenced, except that, if the section 112(f) standard is promulgated more than 10 years after construction or reconstruction is commenced, the owner or operator must comply with the standard as provided in paragraphs (b)(1) and (2) of this section.
(5) The owner or operator of a new source that is subject to the compliance requirements of paragraph (b)(3) or (4) of this section must notify the Administrator in accordance with &sect; 63.9(d).
(6) [Reserved]
(7) When an area source becomes a major source by the addition of equipment or operations that meet the definition of new affected source in the relevant standard, the portion of the existing facility that is a new affected source must comply with all requirements of that standard applicable to new sources. The source owner or operator must comply with the relevant standard upon startup.
(c) Compliance datesfor existing sources.
(1) After the effective date of a relevant standard established under this part pursuant to section 112(d) or 112(h) of the Act, the owner or operator of an existing source shall comply with such standard by the compliance date established by the Administrator in the applicable subpart(s) of this part. Except as otherwise provided for in section 112 of the Act, in no case will the compliance date established for an existing source in an applicable subpart of this part exceed 3 years after the effective date of such standard.
(2) If an existing source is subject to a standard established under this part pursuant to section 112(f) of the Act, the owner or operator must comply with the standard by the date 90 days after the standard's effective date, or by the date specified in an extension granted to the source by the Administrator under paragraph (i)(4)(ii) of this section, whichever is later.
(3)-(4) [Reserved]
(5) Except as provided in paragraph (b)(7) of this section, the owner or operator of an area source that increases its emissions of (or its potential to emit) hazardous air pollutants such that the source becomes a major source shall be subject to relevant standards for existing sources. Such sources must comply by the date specified in the standards for existing area sources that become major sources. If no such compliance date is specified in the standards, the source shall have a period of time to comply with the relevant emission standard that is equivalent to the compliance period specified in the relevant standard for existing sources in existence at the time the standard becomes effective.
(d) [Reserved]
(e) Operation and maintenance requirements.
(1)          (i) At all times, including periods of startup, shutdown, and malfunction, the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. During a period of startup, shutdown, or malfunction, this general duty to minimize emissions requires that the owner or operator reduce emissions from the affected source to the greatest extent which is consistent with safety and good air pollution control practices. The general duty to minimize emissions during a period of startup, shutdown, or malfunction does not require the owner or operator to achieve emission levels that would be required by the applicable standard at other times if this is not consistent with safety and good air pollution control practices, nor does it require the owner or operator to make any further efforts to reduce emissions if levels required by the applicable standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures (including the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section), review of operation and maintenance records, and inspection of the source.
(ii)      Malfunctions must be corrected as soon as practicable after their occurrence in accordance with the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section. To the extent that an unexpected event arises during a startup, shutdown, or malfunction, an owner or operator must comply by minimizing emissions during such a startup, shutdown, and malfunction event consistent with safety and good air pollution control practices.
(iii) Operation and maintenance requirements established pursuant to section 112 of the Act are enforceable independent of emissions limitations or other requirements in relevant standards.
(2) [Reserved]
(3) Startup, shutdown, and malfunction plan.
Progress Energy Florida, Inc.                                                                        Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPA-13 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (i)The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan that describes, in detail, procedures for operating and maintaining the source during periods of startup, shutdown, and malfunction, and a program of corrective action for malfunctioning process and air pollution control and monitoring equipment used to comply with the relevant standard.
(A) Ensure that, at all times, the owner or operator operates and maintains each affected source, including associated air pollution control and monitoring equipment, in a manner which satisfies the general duty to minimize emissions established by paragraph (e)(1)(i) of this section; (B) Ensure that owners or operators are prepared to correct malfunctions as soon as practicable after their occurrence in order to minimize excess emissions of hazardous air pollutants; and (C) Reduce the reporting burden associated with periods of startup, shutdown, and malfunction (including corrective action taken to restore malfunctioning process and air pollution control equipment to its normal or usual manner of operation).
(ii) During periods of startup, shutdown, and malfunction, the owner or operator of an affected source must operate and maintain such source (including associated air pollution control and monitoring equipment) in accordance with the procedures specified in the startup, shutdown, and malfunction plan developed under paragraph (e)(3)(i) of this section.
(iii) When actions taken by the owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) are consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, the owner or operator must keep records for that event which demonstrate that the procedures specified in the plan were followed. These records may take the form of a "checklist," or other effective form of recordkeeping that confirms conformance with the startup, shutdown, and malfunction plan for that event. In addition, the owner or operator must keep records of these events as specified in &sect; 63.10(b), including records of the occurrence and duration of each startup, shutdown, or malfunction of operation and each malfunction of the air pollution control and monitoring equipment.
Furthermore, the owner or operator shall confirm that actions taken during the relevant reporting period during periods of startup, shutdown, and malfunction were consistent with the affected source's startup, shutdown and malfunction plan in the semiannual (or more frequent) startup, shutdown, and malfunction report required in &sect; 63.10(d)(5).
(iv) If an action taken by the owner or operator during a startup, shutdown, or malfunction (including an action taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, then the owner or operator must record the actions taken for that event and must report such actions within 2 working days after commencing actions inconsistent with the plan, followed by a letter within 7 working days after the end of the event, in accordance with Sec. 63.10(d)(5) (unless the owner or operator makes alternative reporting arrangements, in advance, with the Administrator).
(v) The owner or operator must maintain at the affected source a current startup, shutdown, and malfunction plan and must make the plan available upon request for inspection and copying by the Administrator. In addition, if the startup, shutdown, and malfunction plan is subsequently revised as provided in paragraph (e)(3)(viii) of this section, the owner or operator must maintain at the affected source each previous (i.e., superseded) version of the startup, shutdown, and malfunction plan, and must make each such previous version available for inspection and copying by the Administrator for a period of 5 years after revision of the plan. If at any time after adoption of a startup, shutdown, and malfunction plan the affected source ceases operation or is otherwise no longer subject to the provisions of this part, the owner or operator must retain a copy of the most recent plan for 5 years from the date the source ceases operation or is no longer subject to this part and must make the plan available upon request for inspection and copying by the Administrator.
The Administrator may at any time request in writing that the owner or operator submit a copy of any startup, shutdown, and malfunction plan (or a portion thereof) which is maintained at the affected source or in the possession of the owner or operator. Upon receipt of such a request, the owner or operator must promptly submit a copy of the requested plan (or a portion thereof) to the Administrator. The Administrator must request that the owner or operator submit a particular startup, shutdown, or malfunction plan (or a portion thereof) whenever a member of the public submits a specific and reasonable request to examine or to receive a copy of that plan or portion of a plan. The owner or operator may elect to submit the required copy of any startup, shutdown, and malfunction plan to the Administrator in an electronic format. If the owner or operator claims that any portion of such a startup, shutdown, and malfunction plan is confidential business information entitled to protection from disclosure under section 114(c) of the Act or 40 CFR 2.30 1, the material which is claimed as confidential must be clearly designated in the submission.
(vi) To satisfy the requirements of this section to develop a startup, shutdown, and malfunction plan, the owner or operator may use the affected source's standard operating procedures (SOP) manual, or an Occupational Safety and Health Administration (OSHA) or other plan, provided the alternative plans meet all the requirements of this section and are made available for inspection or submitted when requested by the Administrator.
(vii) Based on the results of a determination made under paragraph (e)(1)(i) of this section, the Administrator may require that an owner or operator of an affected source make changes to the startup, shutdown, and Progress Energy Florida, Inc.                                                                          Permit No. 0170004*024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPA-14 of 45
 
APPENDIX NESHAP SUBPART A General Provisions malfunction plan for that source. The Administrator must require appropriate revisions to a startup, shutdown, and malfunction plan, if the Administrator finds that the plan:
(A) Does not address a startup, shutdown, or malfunction event that has occurred; (B) Fails to provide for the operation of the source (including associated air pollution control and monitoring equipment) during a startup, shutdown, or malfunction event in a manner consistent with the general duty to minimize emissions established by paragraph (e)(1)(i) of this section; (C) Does not provide adequate procedures for correcting malfunctioning process and/or air pollution control and monitoring equipment as quickly as practicable; or (D) Includes an event that does not meet the definition of startup, shutdown, or malfunction listed in
      &sect; 63.2.
(viii) The owner or operator may periodically revise the startup, shutdown, and malfunction plan for the affected source as necessary to satisfy the requirements of this part or to reflect changes in equipment or procedures at the affected source. Unless the permitting authority provides otherwise, the owner or operator may make such revisions to the startup, shutdown, and malfunction plan without prior approval by the Administrator or the permitting authority. However, each such revision to a startup, shutdown, and malfunction plan must be reported in the semiannual report required by
&sect; 63.10(d)(5). If the startup, shutdown, and malfunction plan fails to address or inadequately addresses an event that meets the characteristics of a malfunction but was not included in the startup, shutdown, and malfunction plan at the time the owner or operator developed the plan, the owner or operator must revise the startup, shutdown, and malfunction plan within 45 days after the event to include detailed procedures for operating and maintaining the source during similar malfunction events and a program of corrective action for similar malfunctions of process or air pollution control and monitoring equipment. In the event that the owner or operator makes any revision to the startup, shutdown, and malfunction plan which alters the scope of the activities at the source which are deemed to be a startup, shutdown, or malfunction, or otherwise modifies the applicability of any emission limit, work practice requirement, or other requirement in a standard established under this part, the revised plan shall not take effect until after the owner or operator has provided a written notice describing the revision to the permitting authority.
(ix) The title V permit for an affected source must require that the owner or operator adopt a startup, shutdown, and malfunction plan which conforms to the provisions of this part, and that the owner or operator operate and maintain the source in accordance with the procedures specified in the current startup, shutdown, and malfunction plan.
However, any revisions made to the startup, shutdown, and malfunction plan in accordance with the procedures established by this part shall not be deemed to constitute permit revisions under part 70 or part 71 of this chapter. Moreover, none of the procedures specified by the startup, shutdown, and malfunction plan for an affected source shall be deemed to fall within the permit shield provision in section 504(f) of the Act.
(f) Compliance with nonopacity emission standards-(1) Applicability. The non-opacity emission standards set forth in this part shall apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the non-opacity emission standards set forth in this part, then that emission point must still be required to comply with the non-opacity emission standards and other applicable requirements.
(2) Methods for determining compliance.
(i) The Administrator will determine compliance with nonopacity emission standards in this part based on the results of performance tests conducted according to the procedures in &sect; 63.7, unless otherwise specified in an applicable subpart of this part.
(ii) The Administrator will determine compliance with nonopacity emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, including the evaluation of monitoring data, as specified in &sect; 63.6(e) and applicable subparts of this part.
(iii) If an affected source conducts performance testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if -
(A) The performance test was conducted within a reasonable amount of time before an initial performance test is required to be conducted under the relevant standard; (B) The performance test was conducted under representative operating conditions for the source; (C) The performance test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in &sect; 63.7(e) of this subpart; and (D) The performance test was appropriately quality-assured, as specified in &sect; 63.7(c).
(iv) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by review of records, inspection of the source, and other procedures specified in applicable subparts of this part.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-15 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (v) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, as specified in paragraph (e) of this section and applicable subparts of this part.
(3) Finding of compliance. The Administrator will make a finding concerning an affected source's compliance with a non-opacity emission standard, as specified in paragraphs (f)(1) and (2) of this section, upon obtaining all the compliance information required by the relevant standard (including the written reports of performance test results, monitoring results, and other information, if applicable), and information available to the Administrator pursuant to paragraph (e)(1)(i) of this section.
(g) Use of an alternative nonopacity emission standard.
(1) If, in the Administrator's judgment, an owner or operator of an affected source has established that an alternative means of emission limitation will achieve a reduction in emissions of a hazardous air pollutant from an affected source at least equivalent to the reduction in emissions of that pollutant from that source achieved under any design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act, the Administrator will publish in the FEDERAL REGISTER a notice permitting the use of the alternative emission standard for purposes of compliance with the promulgated standard. Any FEDERAL REGISTER notice under this paragraph shall be published only after the public is notified and given the opportunity to comment. Such notice will restrict the permission to the stationary source(s) or category(ies) of sources from which the alternative emission standard will achieve equivalent emission reductions. The Administrator will condition permission in such notice on requirements to assure the proper operation and maintenance of equipment and practices required for compliance with the alternative emission standard and other requirements, including appropriate quality assurance and quality control requirements, that are deemed necessary.
(2) An owner or operator requesting permission under this paragraph shall, unless otherwise specified in an applicable subpart, submit a proposed test plan or the results of testing and monitoring in accordance with &sect; 63.7 and &sect; 63.8, a description of the procedures followed in testing or monitoring, and a description of pertinent conditions during testing or monitoring. Any testing or monitoring conducted to request permission to use an alternative nonopacity emission standard shall be appropriately quality assured and quality controlled, as specified in &sect; 63.7 and &sect; 63.8.
(3) The Administrator may establish general procedures in an applicable subpart that accomplish the requirements of paragraphs (g)(1) and (g)(2) of this section.
(h) Compliance with opacity and visible emission standards -
(1) Applicability. The opacity and visible emission standards set forth in this part must apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the opacity and visible emission standards set forth in this part, then that emission point shall still be required to comply with the opacity and visible emission standards and other applicable requirements.
(2) Methods for determining compliance.
(i) The Administrator will determine compliance with opacity and visible emission standards in this part based on the results of the test method specified in an applicable subpart. Whenever a continuous opacity monitoring system (COMS) is required to be installed to determine compliance with numerical opacity emission standards in this part, compliance with opacity emission standards in this part shall be determined by using the results from the COMS. Whenever an opacity emission test method is not specified, compliance with opacity emission standards in this part shall be determined by conducting observations in accordance with Test Method 9 in appendix A of part 60 of this chapter or the method specified in paragraph (h)(7)(ii) of this section. Whenever a visible emission test method is not specified, compliance with visible emission standards in this part shall be determined by conducting observations in accordance with Test Method 22 in appendix A of part 60 of this chapter.
(ii) [Reserved]
(iii) If an affected source undergoes opacity or visible emission testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if -
(A) The opacity or visible emission test was conducted within a reasonable amount of time before a performance test is required to be conducted under the relevant standard; (B) The opacity or visible emission test was conducted under representative operating conditions for the source; (C) The opacity or visible emission test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in &sect; 63.7(e); and (D) The opacity or visible emission test was appropriately quality-assured, as specified in &sect; 63.7(c) of this section.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-16 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (3) [Reserved]
(4) Notification of opacity or visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting opacity or visible emission observations in accordance with &sect; 63.9(f), if such observations are required for the source by a relevant standard.
(5) Conduct of opacity or visible emission observations.When a relevant standard under this part includes an opacity or visible emission standard, the owner or operator of an affected source shall comply with the following:
(i) For the purpose of demonstrating initial compliance, opacity or visible emission observations shall be conducted concurrently with the initial performance test required in &sect; 63.7 unless one of the following conditions applies:
(A) If no performance test under &sect; 63.7 is required, opacity or visible emission observations shall be conducted within 60 days after achieving the maximum production rate at which a new or reconstructed source will be operated, but not later than 120 days after initial startup of the source, or within 120 days after the effective date of the relevant standard in the case of new sources that start up before the standard's effective date. If no performance test under &sect; 63.7 is required, opacity or visible emission observations shall be conducted within 120 days after the compliance date for an existing or modified source; or (B) If visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under &sect; 63.7, or within the time period specified in paragraph (h)(5)(i)(A) of this section, the source's owner or operator shall reschedule the opacity or visible emission observations as soon after the initial performance test, or time period, as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. The rescheduled opacity or visible emission observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under &sect; 63.7. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity or visible emission observations from being made concurrently with the initial performance test in accordance with procedures contained in Test Method 9 or Test Method 22 in appendix A of part 60 of this chapter.
(ii) For the purpose of demonstrating initial compliance, the minimum total time of opacity observations shall be 3 hours (30 6-minute averages) for the performance test or other required set of observations (e.g., for fugitive-type emission sources subject only to an opacity emission standard).
(iii) The owner or operator of an affected source to which an opacity or visible emission standard in this part applies shall conduct opacity or visible emission observations in accordance with the provisions of this section, record the results of the evaluation of emissions, and report to the Administrator the opacity or visible emission results in accordance with the provisions of &sect; 63.10(d).
(iv) [Reserved]
(v) Opacity readings of portions of plumes that contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity emission standards.
(6) Availability of records. The owner or operator of an affected source shall make available, upon request by the Administrator, such records that the Administrator deems necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification.
(6) Availability of records. The owner or operator of an affected source shall make available, upon request by the Administrator, such records that the Administrator deems necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification.
(7) Use of a continuous opacity monitoring system.(i) The owner or operator of an affected source required to use a continuous opacity monitoring system (COMS) shall record the monitoring data produced during a performance test required under &sect; 63.7 and shall furnish the Administrator a written report of the monitoring results in accordance with the provisions of &sect; 63.10(e)(4).(ii) Whenever an opacity emission test method has not been specified in an applicable subpart, or an owner or operator of an affected source is required to conduct Test Method 9 observations (see appendix A of part 60 of this chapter), the owner or operator may submit, for compliance purposes, COMS data results produced during any performance test required under &sect; 63.7 in lieu of Method 9 data. If the owner or operator elects to submit COMS data for compliance with the opacity emission standard, he or she shall notify the Administrator of that decision, in writing, simultaneously with the notification under &sect; 63.7(b) of the date the performance test is scheduled to begin. Once the owner or operator of an affected source has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent performance tests required under &sect; 63.7, unless the owner or operator notifies the Administrator in writing to the contrary not later than with the notification under &sect; 63.7(b) of the date the subsequent performance test is scheduled to begin.(iii) For the purposes of determining compliance with the opacity emission standard during a performance test required under &sect; 63.7 using COMS data, the COMS data shall be reduced to 6-minute averages over the duration of the mass emission performance test.(iv) The owner or operator of an affected source using a COMS for compliance purposes is responsible for demonstrating that he/she has complied with the performance evaluation requirements of &sect; 63.8(e), that the COMS has been properly maintained, operated, and data quality-assured, as specified in &sect; 63.8(c) and &sect; 63.8(d), and that the resulting data have not been altered in any way.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-17 of 45 APPENDIX NESHAP SUBPART A General Provisions (v) Except as provided in paragraph (h)(7)(ii) of this section, the results of continuous monitoring by a COMS that indicate that the opacity at the time visual observations were made was not in excess of the emission standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the affected source proves that, at the time of the alleged violation, the instrument used was properly maintained, as specified in &sect; 63.8(c), and met Performance Specification 1 in appendix B of part 60 of this chapter, and that the resulting data have not been altered in any way.(8) Finding of compliance.
(7) Use of a continuous opacity monitoring system.
The Administrator will make a finding concerning an affected source's compliance with an opacity or visible emission standard upon obtaining all the compliance information required by the relevant standard (including the written reports of the results of the performance tests required by &sect; 63.7, the results of Test Method 9 or another required opacity or visible emission test method, the observer certification required by paragraph (h)(6) of this section, and the continuous opacity monitoring system results, whichever is/are applicable) and any information available to the Administrator needed to determine whether proper operation and maintenance practices are being used.(9) Adjustment to an opacity emission standard.(i) If the Administrator finds under paragraph (h)(8) of this section that an affected source is in compliance with all relevant standards for which initial performance tests were conducted under &sect; 63.7, but during the time such performance tests were conducted fails to meet any relevant opacity emission standard, the owner or operator of such source may petition the Administrator~to make appropriate adjustment to the opacity emission standard for the affected source. Until the Administrator notifies the owner or operator of the appropriate adjustment, the relevant opacity emission standard remains applicable.(ii) The Administrator may grant such a petition upon a demonstration by the owner or operator that -(A) The affected source and its associated air pollution control equipment were operated and maintained in a manner to minimize the opacity of emissions during the performance tests;(B) The performance tests were performed under the conditions established by the Administrator; and (C) The affected source and its associated air pollution control equipment were incapable of being adjusted or operated to meet the relevant opacity emission standard.(iii) The Administrator will establish an adjusted opacity emission standard for the affected source meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity emission standard at all times during which the source is meeting the mass or concentration emission standard.The Administrator will promulgate the new opacity emission standard in the FEDERAL REGISTER.(iv) After the Administrator promulgates an adjusted opacity emission standard for an affected source, the owner or operator of such source shall be subject to the new opacity emission standard, and the new opacity emission standard shall apply to such source during any subsequent performance tests.(i) Extension of compliance with emission standards.
(i) The owner or operator of an affected source required to use a continuous opacity monitoring system (COMS) shall record the monitoring data produced during a performance test required under &sect; 63.7 and shall furnish the Administrator a written report of the monitoring results in accordance with the provisions of &sect; 63.10(e)(4).
(1) Until an extension of compliance has been granted by the Administrator (or a State with an approved permit program) under this paragraph, the owner or operator of an affected source subject to the requirements of this section shall comply with all applicable requirements of this part.(2) Extension of compliance for early reductions and other reductions (i) Early reductions.
(ii) Whenever an opacity emission test method has not been specified in an applicable subpart, or an owner or operator of an affected source is required to conduct Test Method 9 observations (see appendix A of part 60 of this chapter), the owner or operator may submit, for compliance purposes, COMS data results produced during any performance test required under &sect; 63.7 in lieu of Method 9 data. If the owner or operator elects to submit COMS data for compliance with the opacity emission standard, he or she shall notify the Administrator of that decision, in writing, simultaneously with the notification under &sect; 63.7(b) of the date the performance test is scheduled to begin. Once the owner or operator of an affected source has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent performance tests required under &sect; 63.7, unless the owner or operator notifies the Administrator in writing to the contrary not later than with the notification under &sect; 63.7(b) of the date the subsequent performance test is scheduled to begin.
Pursuant to section 112(i)(5) of the Act, if the owner or operator of an existing source demonstrates that the source has achieved a reduction in emissions of hazardous air pollutants in accordance with the provisions of subpart D of this part, the Administrator (or the State with an approved permit program) will grant the owner or operator an extension of compliance with specific requirements of this part, as specified in subpart D.(ii) Other reductions.
(iii) For the purposes of determining compliance with the opacity emission standard during a performance test required under &sect; 63.7 using COMS data, the COMS data shall be reduced to 6-minute averages over the duration of the mass emission performance test.
Pursuant to section 112(i)(6) of the Act, if the owner or operator of an existing source has installed best available control technology (BACT) (as defined in section 169(3) of the Act) or technology required to meet a lowest achievable emission rate (LAER) (as defined in section 171 of the Act) prior to the promulgation of an emission standard in this part applicable to such source and the same pollutant (or stream of pollutants) controlled pursuant to the BACT or LAER installation, the Administrator will grant the owner or operator an extension of compliance with such emission standard that will apply until the date 5 years after the date on which such installation was achieved, as determined by the Administrator.
(iv) The owner or operator of an affected source using a COMS for compliance purposes is responsible for demonstrating that he/she has complied with the performance evaluation requirements of &sect; 63.8(e), that the COMS has been properly maintained, operated, and data quality-assured, as specified in &sect; 63.8(c) and &sect; 63.8(d), and that the resulting data have not been altered in any way.
(3) Request for extension of compliance.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-17 of 45
Paragraphs (i)(4) through (i)(7) of this section concern requests for an extension of compliance with a relevant standard under this part (except requests for an extension of compliance under paragraph (i)(2)(i) of this section will be handled through procedures specified in subpart D of this part).(4) (i) (A) The owner or operator of an existing source who is unable to comply with a relevant standard established under this part pursuant to section 112(d) of the Act may request that the Administrator (or a State, when the State has an approved part 70 permit program and the source is required to obtain a part 70 permit under that program, or a State, when the State has been delegated the authority to implement and enforce the emission standard for that source) grant an extension allowing the source up to 1 additional year to comply with the standard, if such additional period is necessary for Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-18 of 45 APPENDIX NESHAP SUBPART A General Provisions the installation of controls.
 
An additional extension of up to 3 years may be added for mining waste operations, if the 1-year extension of compliance is insufficient to dry and cover mining waste in order to reduce emissions of any hazardous air pollutant.
APPENDIX NESHAP SUBPART A General Provisions (v) Except as provided in paragraph (h)(7)(ii) of this section, the results of continuous monitoring by a COMS that indicate that the opacity at the time visual observations were made was not in excess of the emission standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the affected source proves that, at the time of the alleged violation, the instrument used was properly maintained, as specified in &sect; 63.8(c), and met Performance Specification 1 in appendix B of part 60 of this chapter, and that the resulting data have not been altered in any way.
The owner or operator of an affected source who has requested an extension of compliance under this paragraph and who is otherwise required to obtain a title V permit shall apply for such permit or apply to have the source's title V permit revised to incorporate the conditions of the extension of compliance.
(8) Findingof compliance. The Administrator will make a finding concerning an affected source's compliance with an opacity or visible emission standard upon obtaining all the compliance information required by the relevant standard (including the written reports of the results of the performance tests required by &sect; 63.7, the results of Test Method 9 or another required opacity or visible emission test method, the observer certification required by paragraph (h)(6) of this section, and the continuous opacity monitoring system results, whichever is/are applicable) and any information available to the Administrator needed to determine whether proper operation and maintenance practices are being used.
The conditions of an extension of compliance granted under this paragraph will be incorporated into the affected source's title V permit according to the provisions of part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever are applicable.(B) Any request under this paragraph for an extension of compliance with a relevant standard must be submitted in writing to the appropriate authority no later than 120 days prior to the affected source's compliance date (as specified in paragraphs (b) and (c) of this section), except as provided for in paragraph (i)(4)(i)(C) of this section.Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the date of denial. Emission standards established under this part may specify alternative dates for the submittal of requests for an extension of compliance if alternatives are appropriate for the source categories affected by those standards.(C) An owner or operator may submit a compliance extension request after the date specified in paragraph (i)(4)(i)(B) of this section provided the need for the compliance extension arose after that date, and before the otherwise applicable compliance date and the need arose due to circumstances beyond reasonable control of the owner or operator.
(9) Adjustment to an opacity emission standard.
This request must include, in addition to the information required in paragraph (i)(6)(i) of this section, a statement of the reasons additional time is needed and the date when the owner or operator first learned of the problems.
(i) If the Administrator finds under paragraph (h)(8) of this section that an affected source is in compliance with all relevant standards for which initial performance tests were conducted under &sect; 63.7, but during the time such performance tests were conducted fails to meet any relevant opacity emission standard, the owner or operator of such source may petition the Administrator~to make appropriate adjustment to the opacity emission standard for the affected source. Until the Administrator notifies the owner or operator of the appropriate adjustment, the relevant opacity emission standard remains applicable.
Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the original compliance date.(ii) The owner or operator of an existing source unable to comply with a relevant standard established under this part pursuant to section 112(f) of the Act may request that the Administrator grant an extension allowing the source up to 2 years after the standard's effective date to comply with the standard.
(ii) The Administrator may grant such a petition upon a demonstration by the owner or operator that -
The Administrator may grant such an extension if he/she finds that such additional period is necessary for the installation of controls and that steps will be taken during the period of the extension to assure that the health of persons will be protected from imminent endangerment.
(A) The affected source and its associated air pollution control equipment were operated and maintained in a manner to minimize the opacity of emissions during the performance tests; (B) The performance tests were performed under the conditions established by the Administrator; and (C) The affected source and its associated air pollution control equipment were incapable of being adjusted or operated to meet the relevant opacity emission standard.
Any request for an extension of compliance with a relevant standard under this paragraph must be submitted in writing to the Administrator not later than 90 calendar days after the effective date of the relevant standard.(5) The owner or operator of an existing source that has installed BACT or technology required to meet LAER [as specified in paragraph (i)(2)(ii) of this section] prior to the promulgation of a relevant emission standard in this part may request that the Administrator grant an extension allowing the source 5 years from the date on which such installation was achieved, as determined by the Administrator, to comply with the standard.
(iii) The Administrator will establish an adjusted opacity emission standard for the affected source meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity emission standard at all times during which the source is meeting the mass or concentration emission standard.
Any request for an extension of compliance with a relevant standard under this paragraph shall be submitted in writing to the Administrator not later than 120 days after the promulgation date of the standard.
The Administrator will promulgate the new opacity emission standard in the FEDERAL REGISTER.
The Administrator may grant such an extension if he or she finds that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.(6) (i) The request for a compliance extension under paragraph (i)(4) of this section shall include the following information: (A) A description of the controls to be installed to comply with the standard;(B) A compliance schedule, including the date by which each step toward compliance will be reached. At a minimum, the list of dates shall include: (1) The date by which on-site construction, installation of emission control equipment, or a process change is planned to be initiated; and (2) The date by which final compliance is to be achieved;(C) [Reserved](D) [Reserved](ii) The request for a compliance extension under paragraph (i)(5) of this section shall include all information needed to demonstrate to the Administrator's satisfaction that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.(7) Advice on requesting an extension of compliance may be obtained from the Administrator (or the State with an approved permit program).(8) Approval of request for extension of compliance.
(iv) After the Administrator promulgates an adjusted opacity emission standard for an affected source, the owner or operator of such source shall be subject to the new opacity emission standard, and the new opacity emission standard shall apply to such source during any subsequent performance tests.
Paragraphs (i)(9) through (i)(14) of this section concern approval of an extension of compliance requested under paragraphs (i)(4) through (i)(6) of this section.(9) Based on the information provided in any request made under paragraphs (i)(4) through (i)(6) of this section, or other information, the Administrator (or the State with an approved permit program) may grant an extension of compliance with an emission standard, as specified in paragraphs (i)(4) and (i)(5) of this section.(10) The extension will be in writing and will -Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-19 of 45 APPENDIX NESHAP SUBPART A General Provisions (i) Identify each affected source covered by the extension;(ii) Specify the termination date of the extension;(iii) Specify the dates by which steps toward compliance are to be taken, if appropriate;(iv) Specify other applicable requirements to which the compliance extension applies (e.g., performance tests); and (v) (A) Under paragraph (i)(4), specify any additional conditions that the Administrator (or the State)deems necessary to assure installation of the necessary controls and protection of the health of persons during the extension period; or (B) Under paragraph (i)(5), specify any additional conditions that the Administrator deems necessary to assure the proper operation and maintenance of the installed controls during the extension period.(11) The owner or operator of an existing source that has been granted an extension of compliance under paragraph (i)(10) of this section may be required to submit to the Administrator (or the State with an approved permit program) progress reports indicating whether the steps toward compliance outlined in the compliance schedule have been reached. The contents of the progress reports and the dates by which they shall be submitted will be specified in the written extension of compliance granted under paragraph (i)(10) of this section.(12) (i) The Administrator (or the State with an approved permit program) will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(i) or (i)(5) of this section. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted.
(i) Extension of compliance with emission standards.
The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete.(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.(iii) Before denying any request for an extension of compliance, the Administrator (or the State with an approved permit program) will notify the owner or operator in writing of the Administrator's (or the State's) intention to issue the denial, together with -(A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator (or the State) before further action on the request.(iv) The Administrator's final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.(13) (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(ii) of this section. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete.
(1) Until an extension of compliance has been granted by the Administrator (or a State with an approved permit program) under this paragraph, the owner or operator of an affected source subject to the requirements of this section shall comply with all applicable requirements of this part.
The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 15 calendar days after receipt of the original application and within 15 calendar days after receipt of any supplementary information that is submitted.(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 15 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.(iii) Before denying any request for an extension of compliance, the Administrator will notify the owner or operator in writing of the Administrator's intention to issue the denial, together with -(A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator before further action on the request.(iv) A final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-20 of 45 APPENDIX NESHAP SUBPART A General Provisions presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.(14) The Administrator (or the State with an approved permit program) may terminate an extension of compliance at an earlier date than specified if any specification under paragraph (i)(10)(iii) or (iv) of this section is not met. Upon a determination to terminate, the Administrator will notify, in writing, the owner or operator of the Administrator's determination to terminate, together with: (i) Notice of the reason for termination; and (ii) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the determination to terminate, additional information or arguments to the Administrator before further action on the termination.(iii) A final determination to terminate an extension of compliance will be in writing and will set forth the specific grounds on which the termination is based. The final determination will be made within 30 calendar days after presentation of additional information or arguments, or within 30 calendar days after the final date specified for the presentation if no presentation is made.(15) [Reserved]
(2) Extension of compliance for early reductions and other reductions (i) Early reductions. Pursuant to section 112(i)(5) of the Act, if the owner or operator of an existing source demonstrates that the source has achieved a reduction in emissions of hazardous air pollutants in accordance with the provisions of subpart D of this part, the Administrator (or the State with an approved permit program) will grant the owner or operator an extension of compliance with specific requirements of this part, as specified in subpart D.
(16) The granting of an extension under this section shall not abrogate the Administrator's authority under section 114 of the Act.(j) Exemption from compliance with emission standards.
(ii) Other reductions. Pursuant to section 112(i)(6) of the Act, if the owner or operator of an existing source has installed best available control technology (BACT) (as defined in section 169(3) of the Act) or technology required to meet a lowest achievable emission rate (LAER) (as defined in section 171 of the Act) prior to the promulgation of an emission standard in this part applicable to such source and the same pollutant (or stream of pollutants) controlled pursuant to the BACT or LAER installation, the Administrator will grant the owner or operator an extension of compliance with such emission standard that will apply until the date 5 years after the date on which such installation was achieved, as determined by the Administrator.
The President may exempt any stationary source from compliance with any relevant standard established pursuant to section 112 of the Act for a period of not more than 2 years if the President determines that the technology to implement such standard is not available and that it is in the national security interests of the United States to do so. An exemption under this paragraph may be extended for 1 or more additional periods, each period not to exceed 2 years.&sect; 63.7 Performance testing requirements.(a) Applicability and performance test dates.(1) The applicability of this section is set out in &sect; 63.1(a)(4).
(3) Request for extension of compliance. Paragraphs (i)(4) through (i)(7) of this section concern requests for an extension of compliance with a relevant standard under this part (except requests for an extension of compliance under paragraph (i)(2)(i) of this section will be handled through procedures specified in subpart D of this part).
(2) If required to do performance testing by a relevant standard, and unless a waiver of performance testing is obtained under this section or the conditions of paragraph (c)(3)(ii)(B) of this section apply, the owner or operator of the affected source must perform such tests within 180 days of the compliance date for such source.(i)- (viii) [Reserved](ix) When an emission standard promulgated under this part is more stringent than the standard proposed (see &sect; 63.6(b)(3)), the owner or operator of a new or reconstructed source subject to that standard for which construction or reconstruction is commenced between the proposal and promulgation dates of the standard shall comply with performance testing requirements within 180 days after the standard's effective date, or within 180 days after startup of the source, whichever is later. If the promulgated standard is more stringent than the proposed standard, the owner or operator may choose to demonstrate compliance with either the proposed or the promulgated standard.
(4)       (i)       (A) The owner or operator of an existing source who is unable to comply with a relevant standard established under this part pursuant to section 112(d) of the Act may request that the Administrator (or a State, when the State has an approved part 70 permit program and the source is required to obtain a part 70 permit under that program, or a State, when the State has been delegated the authority to implement and enforce the emission standard for that source) grant an extension allowing the source up to 1 additional year to comply with the standard, if such additional period is necessary for Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-18 of 45
If the owner or operator chooses to comply with the proposed standard initially, the owner or operator shall conduct a second performance test within 3 years and 180 days after the effective date of the standard, or after startup of the source, whichever is later, to demonstrate compliance with the promulgated standard.(3) The Administrator may require an owner or operator to conduct performance tests at the affected source at any other time when the action is authorized by section 114 of the Act.(b) Notification of performance test.(1) The owner or operator of an affected source must notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is initially scheduled to begin to allow the Administrator, upon request, to review an approve the site-specific test plan required under paragraph (c) of this section and to have an observer present during the test.(2) In the event the owner or operator is unable to conduct the performance test on the date specified in the notification requirement specified in paragraph (b)(1) of this section due to unforeseeable circumstances beyond his or her control, the owner or operator must notify the Administrator as soon as practicable and without delay prior to the scheduled performance test date and specify the date when the performance test is rescheduled.
 
This notification of delay in conducting the performance test shall not relieve the owner or operator of legal responsibility for compliance with any other applicable provisions of this part or with any other applicable Federal, State, or local requirement, nor will it prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.(c) Quality assurance program.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-21 of 45 APPENDIX NESHAP SUBPART A General Provisions (1) The results of the quality assurance program required in this paragraph will be considered by the Administrator when he/she determines the validity of a performance test.(2) (i) Submission of site-specific test plan. Before conducting a required performance test, the owner or operator of an affected source shall develop and, if requested by the Administrator, shall submit a site-specific test plan to the Administrator for approval.
APPENDIX NESHAP SUBPART A General Provisions the installation of controls. An additional extension of up to 3 years may be added for mining waste operations, if the 1-year extension of compliance is insufficient to dry and cover mining waste in order to reduce emissions of any hazardous air pollutant. The owner or operator of an affected source who has requested an extension of compliance under this paragraph and who is otherwise required to obtain a title V permit shall apply for such permit or apply to have the source's title V permit revised to incorporate the conditions of the extension of compliance. The conditions of an extension of compliance granted under this paragraph will be incorporated into the affected source's title V permit according to the provisions of part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever are applicable.
The test plan shall include a test program summary, the test schedule, data quality objectives, and both an internal and external quality assurance (QA) program. Data quality objectives are the pretest expectations of precision, accuracy, and completeness of data.(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of test data precision; an example of internal QA is the sampling and analysis of replicate samples.(iii) The external QA program shall include, at a minimum, application of plans for a test method performance audit (PA) during the performance test. The PA's consist of blind audit samples provided by the Administrator and analyzed during the performance test in order to provide a measure of test data bias. The external QA program may also include systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities.(iv) The owner or operator of an affected source shall submit the site-specific test plan to the Administrator upon the Administrator's request at least 60 calendar days before the performance test is scheduled to take place, that is, simultaneously with the notification of intention to conduct a performance test required under paragraph (b) of this section, or on a mutually agreed upon date.(v) The Administrator may request additional relevant information after the submittal of a site-specific test plan.(3) Approval of site-specific test plan.(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the site-specific test plan (if review of the site-specific test plan is requested) within 30 calendar days after receipt of the original plan and within 30 calendar days after receipt of any supplementary information that is submitted under paragraph (c)(3)(i)(B) of this section. Before disapproving any site-specific test plan, the Administrator will notify the applicant of the Administrator's intention to disapprove the plan together with -(A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present, within 30 calendar days after he/she is notified of the intended disapproval, additional information to the Administrator before final action on the plan.(ii) In the event that the Administrator fails to approve or disapprove the site-specific test plan within the time period specified in paragraph (c)(3)(i) of this section, the following conditions shall apply: (A) If the owner or operator intends to demonstrate compliance using the test method(s) specified in the relevant standard or with only minor changes to those tests methods (see paragraph (e)(2)(i) of this section), the owner or operator must conduct the performance test within the time specified in this section using the specified method(s);(B) If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method when the Administrator approves the site-specific test plan (if review of the site-specific test plan is requested) or after the alternative method is approved (see paragraph (f) of this section).
(B) Any request under this paragraph for an extension of compliance with a relevant standard must be submitted in writing to the appropriate authority no later than 120 days prior to the affected source's compliance date (as specified in paragraphs (b) and (c) of this section), except as provided for in paragraph (i)(4)(i)(C) of this section.
However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval 45 days after submission of the site-specific test plan or request to use an alternative method. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.(iii) Neither the submission of a site-specific test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall -(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.(4) (i) Performance test method audit program. The owner or operator must analyze performance audit (PA)samples during each performance test. The owner or operator must request performance audit materials 30 days prior to the test date. Audit materials including cylinder audit gases may be obtained by contacting the appropriate EPA Regional Office or the responsible enforcement authority.(ii) The Administrator will have sole discretion to require any subsequent remedial actions of the owner or operator based on the PA results.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-22 of 45 APPENDIX NESHAP SUBPART A General Provisions (iii) If the Administrator fails to provide required PA materials to an owner or operator of an affected source in time to analyze the PA samples during a performance test, the requirement to conduct a PA under this paragraph shall be waived for such source for that performance test. Waiver under this paragraph of the requirement to conduct a PA for a particular performance test does not constitute a waiver of the requirement to conduct a PA for future required performance tests.(d) Performance testing facilities.
Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the date of denial. Emission standards established under this part may specify alternative dates for the submittal of requests for an extension of compliance if alternatives are appropriate for the source categories affected by those standards.
If required to do performance testing, the owner or operator of each new source and, at the request of the Administrator, the owner or operator of each existing source, shall provide performance testing facilities as follows: (1) Sampling ports adequate for test methods applicable to such source. This includes: (i) Constructing the air pollution control system such-that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures; and (ii) Providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures; (2) Safe sampling platform(s);
(C) An owner or operator may submit a compliance extension request after the date specified in paragraph (i)(4)(i)(B) of this section provided the need for the compliance extension arose after that date, and before the otherwise applicable compliance date and the need arose due to circumstances beyond reasonable control of the owner or operator. This request must include, in addition to the information required in paragraph (i)(6)(i) of this section, a statement of the reasons additional time is needed and the date when the owner or operator first learned of the problems. Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the original compliance date.
(ii) The owner or operator of an existing source unable to comply with a relevant standard established under this part pursuant to section 112(f) of the Act may request that the Administrator grant an extension allowing the source up to 2 years after the standard's effective date to comply with the standard. The Administrator may grant such an extension if he/she finds that such additional period is necessary for the installation of controls and that steps will be taken during the period of the extension to assure that the health of persons will be protected from imminent endangerment. Any request for an extension of compliance with a relevant standard under this paragraph must be submitted in writing to the Administrator not later than 90 calendar days after the effective date of the relevant standard.
(5) The owner or operator of an existing source that has installed BACT or technology required to meet LAER [as specified in paragraph (i)(2)(ii) of this section] prior to the promulgation of a relevant emission standard in this part may request that the Administrator grant an extension allowing the source 5 years from the date on which such installation was achieved, as determined by the Administrator, to comply with the standard. Any request for an extension of compliance with a relevant standard under this paragraph shall be submitted in writing to the Administrator not later than 120 days after the promulgation date of the standard. The Administrator may grant such an extension if he or she finds that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.
(6)       (i) The request for a compliance extension under paragraph (i)(4) of this section shall include the following information:
(A) A description of the controls to be installed to comply with the standard; (B) A compliance schedule, including the date by which each step toward compliance will be reached. At a minimum, the list of dates shall include:
(1) The date by which on-site construction, installation of emission control equipment, or a process change is planned to be initiated; and (2) The date by which final compliance is to be achieved; (C) [Reserved]
(D) [Reserved]
(ii) The request for a compliance extension under paragraph (i)(5) of this section shall include all information needed to demonstrate to the Administrator's satisfaction that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard.
(7) Advice on requesting an extension of compliance may be obtained from the Administrator (or the State with an approved permit program).
(8) Approval of requestfor extension of compliance. Paragraphs (i)(9) through (i)(14) of this section concern approval of an extension of compliance requested under paragraphs (i)(4) through (i)(6) of this section.
(9) Based on the information provided in any request made under paragraphs (i)(4) through (i)(6) of this section, or other information, the Administrator (or the State with an approved permit program) may grant an extension of compliance with an emission standard, as specified in paragraphs (i)(4) and (i)(5) of this section.
(10) The extension will be in writing and will -
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-19 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (i) Identify each affected source covered by the extension; (ii) Specify the termination date of the extension; (iii) Specify the dates by which steps toward compliance are to be taken, if appropriate; (iv) Specify other applicable requirements to which the compliance extension applies (e.g., performance tests); and (v)       (A) Under paragraph (i)(4), specify any additional conditions that the Administrator (or the State) deems necessary to assure installation of the necessary controls and protection of the health of persons during the extension period; or (B) Under paragraph (i)(5), specify any additional conditions that the Administrator deems necessary to assure the proper operation and maintenance of the installed controls during the extension period.
(11) The owner or operator of an existing source that has been granted an extension of compliance under paragraph (i)(10) of this section may be required to submit to the Administrator (or the State with an approved permit program) progress reports indicating whether the steps toward compliance outlined in the compliance schedule have been reached. The contents of the progress reports and the dates by which they shall be submitted will be specified in the written extension of compliance granted under paragraph (i)(10) of this section.
(12)     (i) The Administrator (or the State with an approved permit program) will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(i) or (i)(5) of this section. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete.
(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.
(iii) Before denying any request for an extension of compliance, the Administrator (or the State with an approved permit program) will notify the owner or operator in writing of the Administrator's (or the State's) intention to issue the denial, together with -
(A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator (or the State) before further action on the request.
(iv) The Administrator's final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.
(13)     (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(ii) of this section. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 15 calendar days after receipt of the original application and within 15 calendar days after receipt of any supplementary information that is submitted.
(ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 15 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application.
(iii) Before denying any request for an extension of compliance, the Administrator will notify the owner or operator in writing of the Administrator's intention to issue the denial, together with -
(A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator before further action on the request.
(iv) A final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-20 of 45
 
APPENDIX NESHAP SUBPART A General Provisions presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made.
(14) The Administrator (or the State with an approved permit program) may terminate an extension of compliance at an earlier date than specified if any specification under paragraph (i)(10)(iii) or (iv) of this section is not met. Upon a determination to terminate, the Administrator will notify, in writing, the owner or operator of the Administrator's determination to terminate, together with:
(i) Notice of the reason for termination; and (ii) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the determination to terminate, additional information or arguments to the Administrator before further action on the termination.
(iii) A final determination to terminate an extension of compliance will be in writing and will set forth the specific grounds on which the termination is based. The final determination will be made within 30 calendar days after presentation of additional information or arguments, or within 30 calendar days after the final date specified for the presentation if no presentation is made.
(15) [Reserved]
(16) The granting of an extension under this section shall not abrogate the Administrator's authority under section 114 of the Act.
(j) Exemption from compliance with emission standards.The President may exempt any stationary source from compliance with any relevant standard established pursuant to section 112 of the Act for a period of not more than 2 years if the President determines that the technology to implement such standard is not available and that it is in the national security interests of the United States to do so. An exemption under this paragraph may be extended for 1 or more additional periods, each period not to exceed 2 years.
&sect; 63.7 Performance testing requirements.
(a) Applicability andperformance test dates.
(1) The applicability of this section is set out in &sect; 63.1(a)(4).
(2) If required to do performance testing by a relevant standard, and unless a waiver of performance testing is obtained under this section or the conditions of paragraph (c)(3)(ii)(B) of this section apply, the owner or operator of the affected source must perform such tests within 180 days of the compliance date for such source.
(i)- (viii) [Reserved]
(ix) When an emission standard promulgated under this part is more stringent than the standard proposed (see &sect; 63.6(b)(3)), the owner or operator of a new or reconstructed source subject to that standard for which construction or reconstruction is commenced between the proposal and promulgation dates of the standard shall comply with performance testing requirements within 180 days after the standard's effective date, or within 180 days after startup of the source, whichever is later. If the promulgated standard is more stringent than the proposed standard, the owner or operator may choose to demonstrate compliance with either the proposed or the promulgated standard. If the owner or operator chooses to comply with the proposed standard initially, the owner or operator shall conduct a second performance test within 3 years and 180 days after the effective date of the standard, or after startup of the source, whichever is later, to demonstrate compliance with the promulgated standard.
(3) The Administrator may require an owner or operator to conduct performance tests at the affected source at any other time when the action is authorized by section 114 of the Act.
(b) Notification of performance test.
(1) The owner or operator of an affected source must notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is initially scheduled to begin to allow the Administrator, upon request, to review an approve the site-specific test plan required under paragraph (c) of this section and to have an observer present during the test.
(2) In the event the owner or operator is unable to conduct the performance test on the date specified in the notification requirement specified in paragraph (b)(1) of this section due to unforeseeable circumstances beyond his or her control, the owner or operator must notify the Administrator as soon as practicable and without delay prior to the scheduled performance test date and specify the date when the performance test is rescheduled. This notification of delay in conducting the performance test shall not relieve the owner or operator of legal responsibility for compliance with any other applicable provisions of this part or with any other applicable Federal, State, or local requirement, nor will it prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.
(c) Quality assuranceprogram.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-21 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (1) The results of the quality assurance program required in this paragraph will be considered by the Administrator when he/she determines the validity of a performance test.
(2)       (i) Submission of site-specific test plan. Before conducting a required performance test, the owner or operator of an affected source shall develop and, if requested by the Administrator, shall submit a site-specific test plan to the Administrator for approval. The test plan shall include a test program summary, the test schedule, data quality objectives, and both an internal and external quality assurance (QA) program. Data quality objectives are the pretest expectations of precision, accuracy, and completeness of data.
(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of test data precision; an example of internal QA is the sampling and analysis of replicate samples.
(iii) The external QA program shall include, at a minimum, application of plans for a test method performance audit (PA) during the performance test. The PA's consist of blind audit samples provided by the Administrator and analyzed during the performance test in order to provide a measure of test data bias. The external QA program may also include systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities.
(iv) The owner or operator of an affected source shall submit the site-specific test plan to the Administrator upon the Administrator's request at least 60 calendar days before the performance test is scheduled to take place, that is, simultaneously with the notification of intention to conduct a performance test required under paragraph (b) of this section, or on a mutually agreed upon date.
(v) The Administrator may request additional relevant information after the submittal of a site-specific test plan.
(3) Approval of site-specific test plan.
(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the site-specific test plan (if review of the site-specific test plan is requested) within 30 calendar days after receipt of the original plan and within 30 calendar days after receipt of any supplementary information that is submitted under paragraph (c)(3)(i)(B) of this section. Before disapproving any site-specific test plan, the Administrator will notify the applicant of the Administrator's intention to disapprove the plan together with -
(A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present, within 30 calendar days after he/she is notified of the intended disapproval, additional information to the Administrator before final action on the plan.
(ii) In the event that the Administrator fails to approve or disapprove the site-specific test plan within the time period specified in paragraph (c)(3)(i) of this section, the following conditions shall apply:
(A) If the owner or operator intends to demonstrate compliance using the test method(s) specified in the relevant standard or with only minor changes to those tests methods (see paragraph (e)(2)(i) of this section), the owner or operator must conduct the performance test within the time specified in this section using the specified method(s);
(B) If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method when the Administrator approves the site-specific test plan (if review of the site-specific test plan is requested) or after the alternative method is approved (see paragraph (f) of this section). However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval 45 days after submission of the site-specific test plan or request to use an alternative method. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.
(iii) Neither the submission of a site-specific test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall -
(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.
(4)       (i) Performance test method auditprogram. The owner or operator must analyze performance audit (PA) samples during each performance test. The owner or operator must request performance audit materials 30 days prior to the test date. Audit materials including cylinder audit gases may be obtained by contacting the appropriate EPA Regional Office or the responsible enforcement authority.
(ii) The Administrator will have sole discretion to require any subsequent remedial actions of the owner or operator based on the PA results.
Progress Energy Florida, Inc.                                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-22 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (iii) If the Administrator fails to provide required PA materials to an owner or operator of an affected source in time to analyze the PA samples during a performance test, the requirement to conduct a PA under this paragraph shall be waived for such source for that performance test. Waiver under this paragraph of the requirement to conduct a PA for a particular performance test does not constitute a waiver of the requirement to conduct a PA for future required performance tests.
(d) Performance testingfacilities. If required to do performance testing, the owner or operator of each new source and, at the request of the Administrator, the owner or operator of each existing source, shall provide performance testing facilities as follows:
(1) Sampling ports adequate for test methods applicable to such source. This includes:
(i) Constructing the air pollution control system such-that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures; and (ii) Providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures; (2) Safe sampling platform(s);
(3) Safe access to sampling platform(s);
(3) Safe access to sampling platform(s);
(4) Utilities for sampling and testing equipment; and (5) Any other facilities that the Administrator deems necessary for safe and adequate testing of a source.(e) Conduct of performance tests.(1) Performance tests shall be conducted under such conditions as the Administrator specifies to the owner or operator based on representative performance (i.e., performance based on normal operating conditions) of the affected source.Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test, nor shall emissions in excess of the level of the relevant standard during periods of startup, shutdown, and malfunction be considered a violation of the relevant standard unless otherwise specified in the relevant standard or a determination of noncompliance is made under&sect; 63.6(e). Upon request, the owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.(2) Performance tests shall be conducted and data shall be reduced in accordance with the test methods and procedures set forth in this section, in each relevant standard, and, if required, in applicable appendices of parts 51, 60, 61, and 63 of this chapter unless the Administrator  
(4) Utilities for sampling and testing equipment; and (5) Any other facilities that the Administrator deems necessary for safe and adequate testing of a source.
-(i) Specifies or approves, in specific cases, the use of a test method with minor changes in methodology (see definition in &sect; 63.90(a)).
(e) Conduct of performance tests.
Such changes may be approved in conjunction with approval of the site-specific test plan (see paragraph (c) of this section);
(1) Performance tests shall be conducted under such conditions as the Administrator specifies to the owner or operator based on representative performance (i.e., performance based on normal operating conditions) of the affected source.
or (ii) Approves the use of an intermediate or major change or alternative to a test method (see definitions in&sect; 63.90(a)), the results of which the Administrator has determined to be adequate for indicating whether a specific affected source is in compliance; or (iii) Approves shorter sampling times or smaller sample volumes when necessitated by process variables or other factors; or (iv) Waives the requirement for performance tests because the owner or operator of an affected source has demonstrated by other means to the Administrator's satisfaction that the affected source is in compliance with the relevant standard.(3) Unless otherwise specified in a relevant standard or test method, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the relevant standard.
Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test, nor shall emissions in excess of the level of the relevant standard during periods of startup, shutdown, and malfunction be considered a violation of the relevant standard unless otherwise specified in the relevant standard or a determination of noncompliance is made under
For the purpose of determining compliance with a relevant standard, the arithmetic mean of the results of the three runs shall apply. Upon receiving approval from the Administrator, results of a test run may be replaced with results of an additional test run in the event that (i) A sample is accidentally lost after the testing team leaves the site; or (ii) Conditions occur in which one of the three runs must be discontinued because of forced shutdown; or (iii) Extreme meteorological conditions occur; or (iv) Other circumstances occur that are beyond the owner or operator's control.(4) Nothing in paragraphs (e)(1) through (e)(3) of this section shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act.(f) Use of an alternative test method -(1) General. Until authorized to use an intermediate or major change or alternative to a test method, the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-23 of 45 APPENDIX NESHAP SUBPART A General Provisions (2) The owner or operator of an affected source required to do performance testing by a relevant standard may use an alternative test method from that specified in the standard provided that the owner or operator -(i) Notifies the Administrator of his or her intention to use an alternative test method at least 60 days before the performance test is scheduled to begin;(ii) Uses Method 301 in appendix A of this part to validate the alternative test method. This may include the use of specific procedures of Method 301 if use of such procedures are sufficient to validate the alternative test method;and (iii) Submits the results of the Method 301 validation process along with the notification of intention and the justification for not using the specified test method. The owner or operator may submit the information required in this paragraph well in advance of the deadline specified in paragraph (f)(2)(i) of this section to ensure a timely review by the Administrator in order to meet the performance test date specified in this section or the relevant standard.(3) The Administrator will determine whether the owner or operator's validation of the proposed alternative test method is adequate and issue an approval or disapproval of the alternative test method. If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method. However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval/disapproval 45 days after submission of the request to use an alternative method and the request satisfies the requirements in paragraph (f)(2) of this section. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.
&sect; 63.6(e). Upon request, the owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests.
(4) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative test method for the purposes of demonstrating compliance with a relevant standard, the Administrator may require the use of a test method specified in a relevant standard.(5) If the owner or operator uses an alternative test method for an affected source during a required performance test, the owner or operator of such source shall continue to use the alternative test method for subsequent performance tests at that affected source until he or she receives approval from the Administrator to use another test method as allowed under &sect;63.7(f).(6) Neither the validation and approval process nor the failure to validate an alternative test method shall abrogate the owner or operator's responsibility to comply with the requirements of this part.(g) Data analysis, recordkeeping, and reporting.
(2) Performance tests shall be conducted and data shall be reduced in accordance with the test methods and procedures set forth in this section, in each relevant standard, and, if required, in applicable appendices of parts 51, 60, 61, and 63 of this chapter unless the Administrator -
(1) Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Administrator in writing, results of a performance test shall include the analysis of samples, determination of emissions, and raw data. A performance test is "completed" when field sample collection is terminated.
(i) Specifies or approves, in specific cases, the use of a test method with minor changes in methodology (see definition in &sect; 63.90(a)). Such changes may be approved in conjunction with approval of the site-specific test plan (see paragraph (c) of this section); or (ii) Approves the use of an intermediate or major change or alternative to a test method (see definitions in
The owner or operator of an affected source shall report the results of the performance test to the Administrator before the, close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator (see &sect; 63.9(i)).
&sect; 63.90(a)), the results of which the Administrator has determined to be adequate for indicating whether a specific affected source is in compliance; or (iii) Approves shorter sampling times or smaller sample volumes when necessitated by process variables or other factors; or (iv) Waives the requirement for performance tests because the owner or operator of an affected source has demonstrated by other means to the Administrator's satisfaction that the affected source is in compliance with the relevant standard.
The results of the performance test shall be submitted as part of the notification of compliance status required under &sect; 63.9(h). Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the Administrator.
(3) Unless otherwise specified in a relevant standard or test method, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the relevant standard. For the purpose of determining compliance with a relevant standard, the arithmetic mean of the results of the three runs shall apply. Upon receiving approval from the Administrator, results of a test run may be replaced with results of an additional test run in the event that (i) A sample is accidentally lost after the testing team leaves the site; or (ii) Conditions occur in which one of the three runs must be discontinued because of forced shutdown; or (iii) Extreme meteorological conditions occur; or (iv) Other circumstances occur that are beyond the owner or operator's control.
After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the appropriate permitting authority.
(4) Nothing in paragraphs (e)(1) through (e)(3) of this section shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act.
(f) Use of an alternative test method -
(1) General. Until authorized to use an intermediate or major change or alternative to a test method, the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-23 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (2) The owner or operator of an affected source required to do performance testing by a relevant standard may use an alternative test method from that specified in the standard provided that the owner or operator -
(i) Notifies the Administrator of his or her intention to use an alternative test method at least 60 days before the performance test is scheduled to begin; (ii) Uses Method 301 in appendix A of this part to validate the alternative test method. This may include the use of specific procedures of Method 301 if use of such procedures are sufficient to validate the alternative test method; and (iii) Submits the results of the Method 301 validation process along with the notification of intention and the justification for not using the specified test method. The owner or operator may submit the information required in this paragraph well in advance of the deadline specified in paragraph (f)(2)(i) of this section to ensure a timely review by the Administrator in order to meet the performance test date specified in this section or the relevant standard.
(3) The Administrator will determine whether the owner or operator's validation of the proposed alternative test method is adequate and issue an approval or disapproval of the alternative test method. If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method. However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval/disapproval 45 days after submission of the request to use an alternative method and the request satisfies the requirements in paragraph (f)(2) of this section. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative.
(4) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative test method for the purposes of demonstrating compliance with a relevant standard, the Administrator may require the use of a test method specified in a relevant standard.
(5) If the owner or operator uses an alternative test method for an affected source during a required performance test, the owner or operator of such source shall continue to use the alternative test method for subsequent performance tests at that affected source until he or she receives approval from the Administrator to use another test method as allowed under &sect; 63.7(f).
(6) Neither the validation and approval process nor the failure to validate an alternative test method shall abrogate the owner or operator's responsibility to comply with the requirements of this part.
(g) Data analysis, recordkeeping, and reporting.
(1) Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Administrator in writing, results of a performance test shall include the analysis of samples, determination of emissions, and raw data. A performance test is "completed" when field sample collection is terminated. The owner or operator of an affected source shall report the results of the performance test to the Administrator before the, close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator (see &sect; 63.9(i)). The results of the performance test shall be submitted as part of the notification of compliance status required under &sect; 63.9(h). Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the appropriate permitting authority.
(2) [Reserved]
(2) [Reserved]
(3) For a minimum of 5 years after a performance test is conducted, the owner or operator shall retain and make available, upon request, for inspection by the Administrator the records or results of such performance test and other data needed to determine emissions from an affected source.(h) Waiver of performance tests.(1) Until a waiver of a performance testing requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.(2) Individual performance tests may be waived upon written application to the Administrator if, in the Administrator's judgment, the source is meeting the relevant standard(s) on a continuous basis, or the source is being operated under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.(3) Request to waive a performance test.(i) If a request is made for an extension of compliance under &sect; 63.6(i), the application for a waiver of an initial performance test shall accompany the information Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-24 of 45 APPENDIX NESHAP SUBPART A General Provisions required for the request for an extension of compliance.
(3) For a minimum of 5 years after a performance test is conducted, the owner or operator shall retain and make available, upon request, for inspection by the Administrator the records or results of such performance test and other data needed to determine emissions from an affected source.
If no extension of compliance is requested or if the owner or operator has requested an extension of compliance and the Administrator is still considering that request, the application for a waiver of an initial performance test shall be submitted at least 60 days before the performance test if the site-specific test plan under paragraph (c) of this section is not submitted.(ii) If an application for a waiver of a subsequent performance test is made, the application may accompany any required compliance progress report, compliance status report, or excess emissions and continuous monitoring system performance report [such as those required under &sect; 63.6(I), &sect; 63.9(h), and &sect; 63.10(e) or specified in a relevant standard or in the source's title V permit], but it shall be submitted at least 60 days before the performance test if the site-specific test plan required under paragraph (c) of this section is not submitted.(iii) Any application for a waiver of a performance test shall include information justifying the owner or operator's request for a waiver, such as the technical or economic infeasibility, or the impracticality, of the affected source performing the required test.(4) Approval of request to waive performance test. The Administrator will approve or deny a request for a waiver of a performance test made under paragraph (h)(3) of this section when he/she -(i) Approves or denies an extension of compliance under &sect; 63.6(i)(8);
(h) Waiver of performance tests.
or (ii) Approves or disapproves a site-specific test plan under &sect; 63.7(c)(3);
(1) Until a waiver of a performance testing requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.
or (iii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iv) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.
(2) Individual performance tests may be waived upon written application to the Administrator if, in the Administrator's judgment, the source is meeting the relevant standard(s) on a continuous basis, or the source is being operated under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.
(5) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.&sect; 63.8 Monitoring requirements.(a) Applicability.
(3) Request to waive a performance test.
(i) If a request is made for an extension of compliance under &sect; 63.6(i), the application for a waiver of an initial performance test shall accompany the information Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-24 of 45
 
APPENDIX NESHAP SUBPART A General Provisions required for the request for an extension of compliance. If no extension of compliance is requested or if the owner or operator has requested an extension of compliance and the Administrator is still considering that request, the application for a waiver of an initial performance test shall be submitted at least 60 days before the performance test if the site-specific test plan under paragraph (c) of this section is not submitted.
(ii) If an application for a waiver of a subsequent performance test is made, the application may accompany any required compliance progress report, compliance status report, or excess emissions and continuous monitoring system performance report [such as those required under &sect; 63.6(I), &sect; 63.9(h), and &sect; 63.10(e) or specified in a relevant standard or in the source's title V permit], but it shall be submitted at least 60 days before the performance test if the site-specific test plan required under paragraph (c) of this section is not submitted.
(iii) Any application for a waiver of a performance test shall include information justifying the owner or operator's request for a waiver, such as the technical or economic infeasibility, or the impracticality, of the affected source performing the required test.
(4) Approval of request to waive performance test. The Administrator will approve or deny a request for a waiver of a performance test made under paragraph (h)(3) of this section when he/she -
(i) Approves or denies an extension of compliance under &sect; 63.6(i)(8); or (ii) Approves or disapproves a site-specific test plan under &sect; 63.7(c)(3); or (iii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iv) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.
(5) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.
&sect; 63.8 Monitoring requirements.
(a) Applicability.
(1) The applicability of this section is set out in &sect; 63.1(a)(4).
(1) The applicability of this section is set out in &sect; 63.1(a)(4).
(2) For the purposes of this part, all CMS required under relevant standards shall be subject to the provisions of this section upon promulgation of performance specifications for CMS as specified in the relevant standard or otherwise by the Administrator.
(2) For the purposes of this part, all CMS required under relevant standards shall be subject to the provisions of this section upon promulgation of performance specifications for CMS as specified in the relevant standard or otherwise by the Administrator.
(3) [Reserved]
(3) [Reserved]
(4) Additional monitoring requirements for control devices used to comply with provisions in relevant standards of this part are specified in &sect; 63.11.(b) Conduct of monitoring.
(4) Additional monitoring requirements for control devices used to comply with provisions in relevant standards of this part are specified in &sect; 63.11.
(1) Monitoring shall be conducted as set forth in this section and the relevant standard(s) unless the Administrator  
(b) Conduct of monitoring.
-(i) Specifies or approves the use of minor changes in methodology for the specified monitoring requirements and procedures (see &sect; 63.90(a) for definition);
(1) Monitoring shall be conducted as set forth in this section and the relevant standard(s) unless the Administrator -
or (ii) Approves the use of an intermediate or major change or alternative to any monitoring requirements or procedures (see &sect; 63.90(a) for definition).(iii) Owners or operators with flares subject to &sect; 63.11(b) are not subject to the requirements of this section unless otherwise specified in the relevant standard.(2) (i) When the emissions from two or more affected sources are combined before being released to the atmosphere, the owner or operator may install an applicable CMS for each emission stream or for the combined emissions streams, provided the monitoring is sufficient to demonstrate compliance with the relevant standard.(ii) If the relevant standard is a mass emission standard and the emissions from one affected source are released to the atmosphere through more than one point, the owner or operator must install an applicable CMS at each emission point unless the installation of fewer systems is -(A) Approved by the Administrator; or (B) Provided for in a relevant standard (e.g., instead of requiring that a CMS be installed at each emission point before the effluents from those points are channeled to a common control device, the standard specifies that only one CMS is required to be installed at the vent of the control device).(3) When more than one CMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CMS. However, when one CMS is used as Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-25 of 45 APPENDIX NESHAP SUBPART A General Provisions a backup to another CMS, the owner or operator shall report the results from the CMS used to meet the monitoring requirements of this part. If both such CMS are used during a particular reporting period to meet the monitoring requirements of this part, then the owner or operator shall report the results from each CMS for the relevant compliance period.(c) Operation and maintenance of continuous monitoring systems.(1) The owner or operator of an affected source shall maintain and operate each CMS as specified in this section, or in a relevant standard, and in a manner consistent with good air pollution control practices.(i) The owner or operator of an affected source must maintain and operate each CMS as specified in&sect; 63.6(e)(1).(ii) The owner or operator must keep the necessary parts for routine repairs of the affected CMS equipment readily available.(iii) The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan for CMS as specified in &sect; 63.6(e)(3).
(i) Specifies or approves the use of minor changes in methodology for the specified monitoring requirements and procedures (see &sect; 63.90(a) for definition); or                                             (ii) Approves the use of an intermediate or major change or alternative to any monitoring requirements or procedures (see &sect; 63.90(a) for definition).
(2) (i) All CMS must be installed such that representative measures of emissions or process parameters from the affected source are obtained.
(iii) Owners or operators with flares subject to &sect; 63.11(b) are not subject to the requirements of this section unless otherwise specified in the relevant standard.
In addition, CEMS must be located according to procedures contained in the applicable performance specification(s).(ii) Unless the individual subpart states otherwise, the owner or operator must ensure the read out (that portion of the CMS that provides a visual display or record), or other indication of operation, from any CMS required for compliance with the emission standard is readily accessible on site for operational control or inspection by the operator of the equipment.
(2)       (i) When the emissions from two or more affected sources are combined before being released to the atmosphere, the owner or operator may install an applicable CMS for each emission stream or for the combined emissions streams, provided the monitoring is sufficient to demonstrate compliance with the relevant standard.
(3) All CMS shall be installed, operational, and the data verified as specified in the relevant standard either prior to or in conjunction with conducting performance tests under &sect; 63.7. Verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system.(4) Except for system breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level calibration drift adjustments, all CMS, including COMS and CEMS, shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: (i) All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.(ii) All CEMS for measuring emissions other than opacity shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period.(5) Unless otherwise approved by the Administrator, minimum procedures for COMS shall include a method for producing a simulated zero opacity condition and an upscale (high-level) opacity condition using a certified neutral density filter or other related technique to produce a known obscuration of the light beam. Such procedures shall provide a system check of all the analyzer's internal optical surfaces and all electronic circuitry, including the lamp and photodetector assembly normally used in the measurement of opacity.(6) The owner or operator of a CMS that is not a CPMS, which is installed in accordance with the provisions of this part and the applicable CMS performance specification(s), must check the zero (low-level) and high-level calibration drifts at least once daily in accordance with the written procedure specified in the performance evaluation plan developed under paragraphs (e)(3)(i) and (ii) of this section. The zero (low-level) and high-level calibration drifts must be adjusted, at a minimum, whenever the 24-hour zero (low-level) drift exceeds two times the limits of the applicable performance specification(s) specified in the relevant standard.
(ii) If the relevant standard is a mass emission standard and the emissions from one affected source are released to the atmosphere through more than one point, the owner or operator must install an applicable CMS at each emission point unless the installation of fewer systems is -
The system shall allow the amount of excess zero (low-level) and high-level drift measured at the 24-hour interval checks to be recorded and quantified whenever specified.
(A) Approved by the Administrator; or (B) Provided for in a relevant standard (e.g., instead of requiring that a CMS be installed at each emission point before the effluents from those points are channeled to a common control device, the standard specifies that only one CMS is required to be installed at the vent of the control device).
For COMS, all optical and instrumental surfaces exposed to the effluent gases must be cleaned prior to performing the zero (low-level) and high-level drift adjustments; the optical surfaces and instrumental surfaces must be cleaned when the cumulative automatic zero compensation, if applicable, exceeds 4 percent opacity. The CPMS must be calibrated prior to use for the purposes of complying with this section. The CPMS must be checked daily for indication that the system is responding.
(3) When more than one CMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CMS. However, when one CMS is used as Progress Energy Florida, Inc.                                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                                       Title V Permit Renewal Page NESHAPA-25 of 45
If the CPMS system includes an internal system check, results must be recorded and checked daily for proper operation.
 
(7) (i) A CMS is out of control if -(A) The zero (low-level), mid-level (if applicable), or high-level calibration drift (CD) exceeds two times the applicable CD specification in the applicable performance specification or in the relevant standard; or (B) The CMS fails a performance test audit (e.g., cylinder gas audit), relative accuracy audit, relative accuracy test audit, or linearity test audit; or (C) The COMS CD exceeds two times the limit in the applicable performance specification in the relevant standard.(ii) When the CMS is out of control, the owner or operator of the affected source shall take the necessary corrective action and shall repeat all necessary tests which indicate that the system is out of control. The owner or operator Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-26 of 45 APPENDIX NESHAP SUBPART A General Provisions shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out-of-control period is the hour the owner or operator conducts a performance check (e.g., calibration drift)that indicates an exceedance of the performance requirements established under this part. The end of the out-of-control period is the hour following the completion of corrective action and successful demonstration that the system is within the allowable limits. During the period the CMS is out of control, recorded data shall not be used in data averages and calculations, or to meet any data availability requirement established under this part.(8) The owner or operator of a CMS that is out of control as defined in paragraph (c)(7) of this section shall submit all information concerning out-of-control periods, including start and end dates and hours and descriptions of corrective actions taken, in the excess emissions and continuous monitoring system performance report required in &sect; 63.10(e)(3).(d) Quality control program.(1) The results of the quality control program required in this paragraph will be considered by the Administrator when he/she determines the validity of monitoring data.(2) The owner or operator of an affected source that is required to use a CMS and is subject to the monitoring requirements of this section and a relevant standard shall develop and implement a CMS quality control program. As part of the quality control program, the owner or operator shall develop and submit to the Administrator for approval upon request a site-specific performance evaluation test plan for the CMS performance evaluation required in paragraph (e)(3)(i) of this section, according to the procedures specified in paragraph (e). In addition, each quality control program shall include, at a minimum, a written protocol that describes procedures for each of the following operations: (i) Initial and any subsequent calibration of the CMS;(ii) Determination and adjustment of the calibration drift of the CMS;(iii) Preventive maintenance of the CMS, including spare parts inventory;(iv) Data recording, calculations, and reporting;(v) Accuracy audit procedures, including sampling and analysis methods; and (vi) Program of corrective action for a malfunctioning CMS.(3) The owner or operator shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the Administrator.
APPENDIX NESHAP SUBPART A General Provisions a backup to another CMS, the owner or operator shall report the results from the CMS used to meet the monitoring requirements of this part. If both such CMS are used during a particular reporting period to meet the monitoring requirements of this part, then the owner or operator shall report the results from each CMS for the relevant compliance period.
If the performance evaluation plan is revised, the owner or operator shall keep previous (i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. Where relevant, e.g., program of corrective action for a malfunctioning CMS, these written procedures may be incorporated as part of the affected source's startup, shutdown, and malfunction plan to avoid duplication of planning and recordkeeping efforts.(e) Performance evaluation of continuous monitoring systems -(1) General. When required by a relevant standard, and at any other time the Administrator may require under section 114 of the Act, the owner or operator of an affected source being monitored shall conduct a performance evaluation of the CMS. Such performance evaluation shall be conducted according to the applicable specifications and procedures described in this section or in the relevant standard.(2) Notification of performance evaluation.
(c) Operationand maintenance of continuous monitoring systems.
The owner or operator shall notify the Administrator in writing of the date of the performance evaluation simultaneously with the notification of the performance test date required under &sect; 63.7(b)or at least 60 days prior to the date the performance evaluation is scheduled to begin if no performance test is required.(3) (i) Submission of site-specific performance evaluation test plan. Before conducting a required CMS performance evaluation, the owner or operator of an affected source shall develop and submit a site-specific performance evaluation test plan to the Administrator for approval upon request. The performance evaluation test plan shall include the evaluation program objectives, an evaluation program summary, the performance evaluation schedule, data quality objectives, and both an internal and external QA program. Data quality objectives are the pre-evaluation expectations of precision, accuracy, and completeness of data.(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of CMS performance.
(1) The owner or operator of an affected source shall maintain and operate each CMS as specified in this section, or in a relevant standard, and in a manner consistent with good air pollution control practices.
The external QA program shall include, at a minimum, systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities.(iii) The owner or operator of an affected source shall submit the site-specific performance evaluation test plan to the Administrator (if requested) at least 60 days before the performance test or performance evaluation is scheduled to begin, or on a mutually agreed upon date, and review and approval of the performance evaluation test plan by the Administrator will occur with the review and approval of the site-specific test plan (if review of the site-specific test plan is requested).(iv) The Administrator may request additional relevant information after the submittal of a site-specific performance evaluation test plan.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-27 of 45 APPENDIX NESHAP SUBPART A General Provisions (v) In the event that the Administrator fails to approve or disapprove the site-specific performance evaluation test plan within the time period specified in &sect; 63.7(c)(3), the following conditions shall apply: (A) If the owner or operator intends to demonstrate compliance using the monitoring method(s)specified in the relevant standard, the owner or operator shall conduct the performance evaluation within the time specified in this subpart using the specified method(s);(B) If the owner or operator intends to demonstrate compliance by using an alternative to a monitoring method specified in the relevant standard, the owner or operator shall refrain from conducting the performance evaluation until the Administrator approves the use of the alternative method. If the Administrator does not approve the use of the alternative method within 30 days before the performance evaluation is scheduled to begin, the performance evaluation deadlines specified in paragraph (e)(4) of this section may be extended such that the owner or operator shall conduct the performance evaluation within 60 calendar days after the Administrator approves the use of the alternative method.Notwithstanding the requirements in the preceding two sentences, the owner or operator may proceed to conduct the performance evaluation as required in this section (without the Administrator's prior approval of the site-specific performance evaluation test plan) if he/she subsequently chooses to use the specified monitoring method(s) instead of an alternative.(vi) Neither the submission of a site-specific performance evaluation test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator' failure to approve or disapprove a plan in a timely manner shall -(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.(4) Conduct of performance evaluation and performance evaluation dates. The owner or operator of an affected source shall conduct a performance evaluation of a required CMS during any performance test required under &sect; 63.7 in accordance with the applicable performance specification as specified in the relevant standard.
(i) The owner or operator of an affected source must maintain and operate each CMS as specified in
Notwithstanding the requirement in the previous sentence, if the owner or operator of an affected source elects to submit COMS data for compliance with a relevant opacity emission standard as provided under &sect; 63.6(h)(7), he/she shall conduct a performance evaluation of the COMS as specified in the relevant standard, before the performance test required under &sect; 63.7 is conducted in time to submit the results of the performance evaluation as specified in paragraph (e)(5)(ii) of this section. If a performance test is not required, or the requirement for a performance test has been waived under &sect; 63.7(h), the owner or operator of an affected source shall conduct the performance evaluation not later than 180 days after the appropriate compliance date for the affected source, as specified in &sect; 63.7(a), or as otherwise specified in the relevant standard.(5) Reporting performance evaluation results.(i) The owner or operator shall furnish the Administrator a copy of a written report of the results of the performance evaluation simultaneously with the results of the performance test required under &sect; 63.7 or within 60 days of completion of the performance evaluation if no test is required, unless otherwise specified in a relevant standard.
&sect; 63.6(e)(1).
The Administrator may request that the owner or operator submit the raw data from a performance evaluation in the report of the performance evaluation results.(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under &sect; 63.7 and described in &sect; 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation under this paragraph.
(ii) The owner or operator must keep the necessary parts for routine repairs of the affected CMS equipment readily available.
The copies shall be provided at least 15 calendar days before the performance test required under &sect; 63.7 is conducted.(f) Use of an alternative monitoring method -(1) General. Until permission to use an alternative monitoring procedure (minor, intermediate, or major changes; see definition in &sect; 63.90(a))
(iii) The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan for CMS as specified in &sect; 63.6(e)(3).
has been granted by the Administrator under this paragraph (f)(1), the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.(2) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring methods or procedures of this part including, but not limited to, the following: (i) Alternative monitoring requirements when installation of a CMS specified by a relevant standard would not provide accurate measurements due to liquid water or other interferences caused by substances within the effluent gases;(ii) Alternative monitoring requirements when the affected source is infrequently operated;(iii) Alternative monitoring requirements to accommodate CEMS that require additional measurements to correct for stack moisture conditions;(iv) Alternative locations for installing CMS when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements;(v) Alternate methods for converting pollutant concentration measurements to units of the relevant standard;Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-28 of 45 APPENDIX NESHAP SUBPART A General Provisions (vi) Alternate procedures for performing daily checks of zero (low-level) and high-level drift that do not involve use of high-level gases or test cells;(vii) Alternatives to the American Society for Testing and Materials (ASTM) test methods or sampling procedures specified by any relevant standard;(viii) Alternative CMS that do not meet the design or performance requirements in this part, but adequately demonstrate a definite and consistent relationship between their measurements and the measurements of opacity by a system complying with the requirements as specified in' the relevant standard.
(2)       (i) All CMS must be installed such that representative measures of emissions or process parameters from the affected source are obtained. In addition, CEMS must be located according to procedures contained in the applicable performance specification(s).
The Administrator may require that such demonstration be performed for each affected source; or (ix) Alternative monitoring requirements when the effluent from a single affected source or the combined effluent from two or more affected sources is released to the atmosphere through more than one point.(3) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative monitoring method, requirement, or procedure, the Administrator may require the use of a method, requirement, or procedure specified in this section or in the relevant standard.
(ii) Unless the individual subpart states otherwise, the owner or operator must ensure the read out (that portion of the CMS that provides a visual display or record), or other indication of operation, from any CMS required for compliance with the emission standard is readily accessible on site for operational control or inspection by the operator of the equipment.
If the results of the specified and alternative method, requirement, or procedure do not agree, the results obtained by the specified method, requirement, or procedure shall prevail.(4) (i) Request to use alternative monitoring procedure.
(3) All CMS shall be installed, operational, and the data verified as specified in the relevant standard either prior to or in conjunction with conducting performance tests under &sect; 63.7. Verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system.
An owner or operator who wishes to use an alternative monitoring procedure must submit an application to the Administrator as described in paragraph (f)(4)(ii) of this section. The application may be submitted at any time provided that the monitoring procedure is not the performance test method used to demonstrate compliance with a relevant standard or other requirement.
(4) Except for system breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level calibration drift adjustments, all CMS, including COMS and CEMS, shall be in continuous operation and shall meet minimum frequency of operation requirements as follows:
If the alternative monitoring procedure will serve as the performance test method that is to be used to demonstrate compliance with a relevant standard, the application must be submitted at least 60 days before the performance evaluation is scheduled to begin and must meet the requirements for an alternative test method under &sect; 63.7(f).(ii) The application must contain a description of the proposed alternative monitoring system which addresses the four elements contained in the definition of monitoring in &sect; 63.2 and a performance evaluation test plan, if required, as specified in paragraph (e)(3) of this section. In addition, the application must include information justifying the owner or operator's request for an alternative monitoring method, such as the technical or economic infeasibility, or the impracticality, of the affected source using the required method.(iii) The owner or operator may submit the information required in this paragraph well in advance of the submittal dates specified in paragraph (f)(4)(i) above to ensure a timely review by the Administrator in order to meet the compliance demonstration date specified in this section or the relevant standard.(iv) Application for minor changes to monitoring procedures, as specified in paragraph (b)(1) of this section, may be made in the site-specific performance evaluation plan.(5) Approval of request to use alternative monitoring procedure.(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the request to use an alternative monitoring method within 30 calendar days after receipt of the original request and within 30 calendar days after receipt of any supplementary information that is submitted.
(i) All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period.
If a request for a minor change is made in conjunction with site-specific performance evaluation plan, then approval of the plan will constitute approval of the minor change. Before disapproving any request to use an alternative monitoring method, the Administrator will notify the applicant of the Administrator's intention to disapprove the request together with --(A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present additional information to the Administrator before final action on the request. At the time the Administrator notifies the applicant of his or her intention to disapprove the request, the Administrator will specify how much time the owner or operator will have after being notified of the intended disapproval to submit the additional information.(ii) The Administrator may establish general procedures and criteria in a relevant standard to accomplish the requirements of paragraph (f)(5)(i) of this section.(iii) If the Administrator approves the use of an alternative monitoring method for an affected source under paragraph (f)(5)(i) of this section, the owner or operator of such source shall continue to use the alternative monitoring method until he or she receives approval from the Administrator to use another monitoring method as allowed by &sect; 63.8(f).(6) Alternative to the relative accuracy test. An alternative to the relative accuracy test for CEMS specified in a relevant standard may be requested as follows: (i) Criteria for approval of alternative procedures.
(ii) All CEMS for measuring emissions other than opacity shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period.
An alternative to the test method for determining relative accuracy is available for affected sources with emission rates demonstrated to be less than 50 percent of the relevant standard.
(5) Unless otherwise approved by the Administrator, minimum procedures for COMS shall include a method for producing a simulated zero opacity condition and an upscale (high-level) opacity condition using a certified neutral density filter or other related technique to produce a known obscuration of the light beam. Such procedures shall provide a system check of all the analyzer's internal optical surfaces and all electronic circuitry, including the lamp and photodetector assembly normally used in the measurement of opacity.
The owner or operator of an affected source may petition the Administrator under paragraph (f)(6)(ii) of this section to substitute the relative accuracy test in section 7 of Performance Specification 2 with the procedures in section 10 if the results of a performance test conducted according to the requirements in &sect; 63.7, or other tests performed following the criteria in &sect; 63.7, demonstrate that the emission rate of the pollutant of interest in the units of the relevant standard is less than 50 percent of the relevant standard.
(6) The owner or operator of a CMS that is not a CPMS, which is installed in accordance with the provisions of this part and the applicable CMS performance specification(s), must check the zero (low-level) and high-level calibration drifts at least once daily in accordance with the written procedure specified in the performance evaluation plan developed under paragraphs (e)(3)(i) and (ii) of this section. The zero (low-level) and high-level calibration drifts must be adjusted, at a minimum, whenever the 24-hour zero (low-level) drift exceeds two times the limits of the applicable performance specification(s) specified in the relevant standard. The system shall allow the amount of excess zero (low-level) and high-level drift measured at the 24-hour interval checks to be recorded and quantified whenever specified. For COMS, all optical and instrumental surfaces exposed to the effluent gases must be cleaned prior to performing the zero (low-level) and high-level drift adjustments; the optical surfaces and instrumental surfaces must be cleaned when the cumulative automatic zero compensation, if applicable, exceeds 4 percent opacity. The CPMS must be calibrated prior to use for the purposes of complying with this section. The CPMS must be checked daily for indication that the system is responding. If the CPMS system includes an internal system check, results must be recorded and checked daily for proper operation.
For affected sources subject to emission limitations expressed as control efficiency levels, the owner or operator may petition the Administrator to substitute the relative accuracy test with the procedures in section 10 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-29 of 45 APPENDIX NESHAP SUBPART A General Provisions of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement.
(7)       (i) A CMS is out of control if -
The alternative procedures do not apply if the CEMS is used continuously to determine compliance with the relevant standard.(ii) Petition to use alternative to relative accuracy test. The petition to use an alternative to the relative accuracy test shall include a detailed description of the procedures to be applied, the location and the procedure for conducting the alternative, the concentration or response levels of the alternative relative accuracy materials, and the other equipment checks included in the alternative procedure(s).
(A) The zero (low-level), mid-level (if applicable), or high-level calibration drift (CD) exceeds two times the applicable CD specification in the applicable performance specification or in the relevant standard; or (B) The CMS fails a performance test audit (e.g., cylinder gas audit), relative accuracy audit, relative accuracy test audit, or linearity test audit; or (C) The COMS CD exceeds two times the limit in the applicable performance specification in the relevant standard.
The Administrator will review the petition for completeness and applicability.
(ii) When the CMS is out of control, the owner or operator of the affected source shall take the necessary corrective action and shall repeat all necessary tests which indicate that the system is out of control. The owner or operator Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-26 of 45
The Administrator's determination to approve an alternative will depend on the intended use of the CEMS data and may require specifications more stringent than in Performance Specification 2.(iii) Rescission of approval to use alternative to relative accuracy test. The Administrator will review the permission to use an alternative to the CEMS relative accuracy test and may rescind such permission if the CEMS data from a successful completion of the alternative relative accuracy procedure indicate that the affected source's emissions are approaching the level of the relevant standard.
 
The criterion for reviewing the permission is that the collection of CEMS data shows that emissions have exceeded 70 percent of the relevant standard for any averaging period, as specified in the relevant standard.
APPENDIX NESHAP SUBPART A General Provisions shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out-of-control period is the hour the owner or operator conducts a performance check (e.g., calibration drift) that indicates an exceedance of the performance requirements established under this part. The end of the out-of-control period is the hour following the completion of corrective action and successful demonstration that the system is within the allowable limits. During the period the CMS is out of control, recorded data shall not be used in data averages and calculations, or to meet any data availability requirement established under this part.
For affected sources subject to emission limitations expressed as control efficiency levels, the criterion for reviewing the permission is that the collection of CEMS data shows that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for any averaging period, as specified in the relevant standard.
(8) The owner or operator of a CMS that is out of control as defined in paragraph (c)(7) of this section shall submit all information concerning out-of-control periods, including start and end dates and hours and descriptions of corrective actions taken, in the excess emissions and continuous monitoring system performance report required in &sect; 63.10(e)(3).
The owner or operator of the affected source shall maintain records and determine the level of emissions relative to the criterion for permission to use an alternative for relative accuracy testing. If this criterion is exceeded, the owner or operator shall notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increased emissions.
(d) Quality control program.
The Administrator will review the notification and may rescind permission to use an alternative and require the owner or operator to conduct a relative accuracy test of the CEMS as specified in section 7 of Performance Specification 2.(g) Reduction of monitoring data.(1) The owner or operator of each CMS must reduce the monitoring data as specified in paragraphs (g)(1) through (5) of this section.(2) The owner or operator of each COMS shall reduce all data to 6-minute averages calculated from 36 or more data points equally spaced over each 6-minute period. Data from CEMS for measurement other than opacity, unless otherwise specified in the relevant standard, shall be reduced to 1-hour averages computed from four or more data points equally spaced over each 1-hour period, except during periods when calibration, quality assurance, or maintenance activities pursuant to provisions of this part are being performed.
(1) The results of the quality control program required in this paragraph will be considered by the Administrator when he/she determines the validity of monitoring data.
During these periods, a valid hourly average shall consist of at least two data points with each representing a 15-minute period. Alternatively, an arithmetic or integrated 1-hour average of CEMS data may be used. Time periods for averaging are defined in &sect; 63.2.(3) The data may be recorded in reduced or nonreduced form (e.g., ppm pollutant and percent 02 or ng/J of pollutant).
(2) The owner or operator of an affected source that is required to use a CMS and is subject to the monitoring requirements of this section and a relevant standard shall develop and implement a CMS quality control program. As part of the quality control program, the owner or operator shall develop and submit to the Administrator for approval upon request a site-specific performance evaluation test plan for the CMS performance evaluation required in paragraph (e)(3)(i) of this section, according to the procedures specified in paragraph (e). In addition, each quality control program shall include, at a minimum, a written protocol that describes procedures for each of the following operations:
(4) All emission data shall be converted into units of the relevant standard for reporting purposes using the conversion procedures specified in that standard.
(i) Initial and any subsequent calibration of the CMS; (ii) Determination and adjustment of the calibration drift of the CMS; (iii) Preventive maintenance of the CMS, including spare parts inventory; (iv) Data recording, calculations, and reporting; (v) Accuracy audit procedures, including sampling and analysis methods; and (vi) Program of corrective action for a malfunctioning CMS.
After conversion into units of the relevant standard, the data may be rounded to the same number of significant digits as used in that standard to specify the emission limit (e.g., rounded to the nearest 1 percent opacity).(5) Monitoring data recorded during periods of unavoidable CMS breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level adjustments must not be included in any data average computed under this part. For the owner or operator complying with the requirements of &sect; 63. 10(b)(2)(vii)(A) or (B), data averages must include any data recorded during periods of monitor breakdown or malfunction.
(3) The owner or operator shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the Administrator. If the performance evaluation plan is revised, the owner or operator shall keep previous (i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. Where relevant, e.g., program of corrective action for a malfunctioning CMS, these written procedures may be incorporated as part of the affected source's startup, shutdown, and malfunction plan to avoid duplication of planning and recordkeeping efforts.
&sect; 63.9 Notification requirements.(a) Applicability and general information.
(e) Performance evaluation of continuous monitoring systems -
(1) The applicability of this section is set out in &sect; 63. 1(a)(4).(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.
(1) General. When required by a relevant standard, and at any other time the Administrator may require under section 114 of the Act, the owner or operator of an affected source being monitored shall conduct a performance evaluation of the CMS. Such performance evaluation shall be conducted according to the applicable specifications and procedures described in this section or in the relevant standard.
(2) Notification of performance evaluation. The owner or operator shall notify the Administrator in writing of the date of the performance evaluation simultaneously with the notification of the performance test date required under &sect; 63.7(b) or at least 60 days prior to the date the performance evaluation is scheduled to begin if no performance test is required.
(3)       (i) Submission of site-specific performance evaluation test plan. Before conducting a required CMS performance evaluation, the owner or operator of an affected source shall develop and submit a site-specific performance evaluation test plan to the Administrator for approval upon request. The performance evaluation test plan shall include the evaluation program objectives, an evaluation program summary, the performance evaluation schedule, data quality objectives, and both an internal and external QA program. Data quality objectives are the pre-evaluation expectations of precision, accuracy, and completeness of data.
(ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of CMS performance. The external QA program shall include, at a minimum, systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities.
(iii) The owner or operator of an affected source shall submit the site-specific performance evaluation test plan to the Administrator (if requested) at least 60 days before the performance test or performance evaluation is scheduled to begin, or on a mutually agreed upon date, and review and approval of the performance evaluation test plan by the Administrator will occur with the review and approval of the site-specific test plan (if review of the site-specific test plan is requested).
(iv) The Administrator may request additional relevant information after the submittal of a site-specific performance evaluation test plan.
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APPENDIX NESHAP SUBPART A General Provisions (v) In the event that the Administrator fails to approve or disapprove the site-specific performance evaluation test plan within the time period specified in &sect; 63.7(c)(3), the following conditions shall apply:
(A) If the owner or operator intends to demonstrate compliance using the monitoring method(s) specified in the relevant standard, the owner or operator shall conduct the performance evaluation within the time specified in this subpart using the specified method(s);
(B) If the owner or operator intends to demonstrate compliance by using an alternative to a monitoring method specified in the relevant standard, the owner or operator shall refrain from conducting the performance evaluation until the Administrator approves the use of the alternative method. If the Administrator does not approve the use of the alternative method within 30 days before the performance evaluation is scheduled to begin, the performance evaluation deadlines specified in paragraph (e)(4) of this section may be extended such that the owner or operator shall conduct the performance evaluation within 60 calendar days after the Administrator approves the use of the alternative method.
Notwithstanding the requirements in the preceding two sentences, the owner or operator may proceed to conduct the performance evaluation as required in this section (without the Administrator's prior approval of the site-specific performance evaluation test plan) if he/she subsequently chooses to use the specified monitoring method(s) instead of an alternative.
(vi) Neither the submission of a site-specific performance evaluation test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator' failure to approve or disapprove a plan in a timely manner shall -
(A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act.
(4) Conduct of performance evaluation and performance evaluation dates. The owner or operator of an affected source shall conduct a performance evaluation of a required CMS during any performance test required under &sect; 63.7 in accordance with the applicable performance specification as specified in the relevant standard. Notwithstanding the requirement in the previous sentence, if the owner or operator of an affected source elects to submit COMS data for compliance with a relevant opacity emission standard as provided under &sect; 63.6(h)(7), he/she shall conduct a performance evaluation of the COMS as specified in the relevant standard, before the performance test required under &sect; 63.7 is conducted in time to submit the results of the performance evaluation as specified in paragraph (e)(5)(ii) of this section. If a performance test is not required, or the requirement for a performance test has been waived under &sect; 63.7(h), the owner or operator of an affected source shall conduct the performance evaluation not later than 180 days after the appropriate compliance date for the affected source, as specified in &sect; 63.7(a), or as otherwise specified in the relevant standard.
(5) Reporting performance evaluation results.
(i) The owner or operator shall furnish the Administrator a copy of a written report of the results of the performance evaluation simultaneously with the results of the performance test required under &sect; 63.7 or within 60 days of completion of the performance evaluation if no test is required, unless otherwise specified in a relevant standard. The Administrator may request that the owner or operator submit the raw data from a performance evaluation in the report of the performance evaluation results.
(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under &sect; 63.7 and described in &sect; 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation under this paragraph. The copies shall be provided at least 15 calendar days before the performance test required under &sect; 63.7 is conducted.
(f) Use of an alternativemonitoring method -
(1) General. Until permission to use an alternative monitoring procedure (minor, intermediate, or major changes; see definition in &sect; 63.90(a)) has been granted by the Administrator under this paragraph (f)(1), the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard.
(2) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring methods or procedures of this part including, but not limited to, the following:
(i) Alternative monitoring requirements when installation of a CMS specified by a relevant standard would not provide accurate measurements due to liquid water or other interferences caused by substances within the effluent gases; (ii) Alternative monitoring requirements when the affected source is infrequently operated; (iii) Alternative monitoring requirements to accommodate CEMS that require additional measurements to correct for stack moisture conditions; (iv) Alternative locations for installing CMS when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements; (v) Alternate methods for converting pollutant concentration measurements to units of the relevant standard; Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-28 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (vi) Alternate procedures for performing daily checks of zero (low-level) and high-level drift that do not involve use of high-level gases or test cells; (vii) Alternatives to the American Society for Testing and Materials (ASTM) test methods or sampling procedures specified by any relevant standard; (viii) Alternative CMS that do not meet the design or performance requirements in this part, but adequately demonstrate a definite and consistent relationship between their measurements and the measurements of opacity by a system complying with the requirements as specified in' the relevant standard. The Administrator may require that such demonstration be performed for each affected source; or (ix) Alternative monitoring requirements when the effluent from a single affected source or the combined effluent from two or more affected sources is released to the atmosphere through more than one point.
(3) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative monitoring method, requirement, or procedure, the Administrator may require the use of a method, requirement, or procedure specified in this section or in the relevant standard. If the results of the specified and alternative method, requirement, or procedure do not agree, the results obtained by the specified method, requirement, or procedure shall prevail.
(4)       (i) Request to use alternativemonitoring procedure. An owner or operator who wishes to use an alternative monitoring procedure must submit an application to the Administrator as described in paragraph (f)(4)(ii) of this section. The application may be submitted at any time provided that the monitoring procedure is not the performance test method used to demonstrate compliance with a relevant standard or other requirement. If the alternative monitoring procedure will serve as the performance test method that is to be used to demonstrate compliance with a relevant standard, the application must be submitted at least 60 days before the performance evaluation is scheduled to begin and must meet the requirements for an alternative test method under &sect; 63.7(f).
(ii) The application must contain a description of the proposed alternative monitoring system which addresses the four elements contained in the definition of monitoring in &sect; 63.2 and a performance evaluation test plan, if required, as specified in paragraph (e)(3) of this section. In addition, the application must include information justifying the owner or operator's request for an alternative monitoring method, such as the technical or economic infeasibility, or the impracticality, of the affected source using the required method.
(iii) The owner or operator may submit the information required in this paragraph well in advance of the submittal dates specified in paragraph (f)(4)(i) above to ensure a timely review by the Administrator in order to meet the compliance demonstration date specified in this section or the relevant standard.
(iv) Application for minor changes to monitoring procedures, as specified in paragraph (b)(1) of this section, may be made in the site-specific performance evaluation plan.
(5) Approval of request to use alternative monitoringprocedure.
(i) The Administrator will notify the owner or operator of approval or intention to deny approval of the request to use an alternative monitoring method within 30 calendar days after receipt of the original request and within 30 calendar days after receipt of any supplementary information that is submitted. If a request for a minor change is made in conjunction with site-specific performance evaluation plan, then approval of the plan will constitute approval of the minor change. Before disapproving any request to use an alternative monitoring method, the Administrator will notify the applicant of the Administrator's intention to disapprove the request together with --
(A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present additional information to the Administrator before final action on the request. At the time the Administrator notifies the applicant of his or her intention to disapprove the request, the Administrator will specify how much time the owner or operator will have after being notified of the intended disapproval to submit the additional information.
(ii) The Administrator may establish general procedures and criteria in a relevant standard to accomplish the requirements of paragraph (f)(5)(i) of this section.
(iii) If the Administrator approves the use of an alternative monitoring method for an affected source under paragraph (f)(5)(i) of this section, the owner or operator of such source shall continue to use the alternative monitoring method until he or she receives approval from the Administrator to use another monitoring method as allowed by &sect; 63.8(f).
(6) Alternative to the relative accuracy test. An alternative to the relative accuracy test for CEMS specified in a relevant standard may be requested as follows:
(i) Criteriafor approval of alternativeprocedures. An alternative to the test method for determining relative accuracy is available for affected sources with emission rates demonstrated to be less than 50 percent of the relevant standard. The owner or operator of an affected source may petition the Administrator under paragraph (f)(6)(ii) of this section to substitute the relative accuracy test in section 7 of Performance Specification 2 with the procedures in section 10 if the results of a performance test conducted according to the requirements in &sect; 63.7, or other tests performed following the criteria in &sect; 63.7, demonstrate that the emission rate of the pollutant of interest in the units of the relevant standard is less than 50 percent of the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the owner or operator may petition the Administrator to substitute the relative accuracy test with the procedures in section 10 Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-29 of 45
 
APPENDIX NESHAP SUBPART A General Provisions of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement. The alternative procedures do not apply if the CEMS is used continuously to determine compliance with the relevant standard.
(ii) Petition to use alternative to relative accuracy test. The petition to use an alternative to the relative accuracy test shall include a detailed description of the procedures to be applied, the location and the procedure for conducting the alternative, the concentration or response levels of the alternative relative accuracy materials, and the other equipment checks included in the alternative procedure(s). The Administrator will review the petition for completeness and applicability. The Administrator's determination to approve an alternative will depend on the intended use of the CEMS data and may require specifications more stringent than in Performance Specification 2.
(iii) Rescission of approval to use alternative to relative accuracy test. The Administrator will review the permission to use an alternative to the CEMS relative accuracy test and may rescind such permission if the CEMS data from a successful completion of the alternative relative accuracy procedure indicate that the affected source's emissions are approaching the level of the relevant standard. The criterion for reviewing the permission is that the collection of CEMS data shows that emissions have exceeded 70 percent of the relevant standard for any averaging period, as specified in the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the criterion for reviewing the permission is that the collection of CEMS data shows that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for any averaging period, as specified in the relevant standard. The owner or operator of the affected source shall maintain records and determine the level of emissions relative to the criterion for permission to use an alternative for relative accuracy testing. If this criterion is exceeded, the owner or operator shall notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increased emissions. The Administrator will review the notification and may rescind permission to use an alternative and require the owner or operator to conduct a relative accuracy test of the CEMS as specified in section 7 of Performance Specification 2.
(g) Reduction of monitoring data.
(1) The owner or operator of each CMS must reduce the monitoring data as specified in paragraphs (g)(1) through (5) of this section.
(2) The owner or operator of each COMS shall reduce all data to 6-minute averages calculated from 36 or more data points equally spaced over each 6-minute period. Data from CEMS for measurement other than opacity, unless otherwise specified in the relevant standard, shall be reduced to 1-hour averages computed from four or more data points equally spaced over each 1-hour period, except during periods when calibration, quality assurance, or maintenance activities pursuant to provisions of this part are being performed. During these periods, a valid hourly average shall consist of at least two data points with each representing a 15-minute period. Alternatively, an arithmetic or integrated 1-hour average of CEMS data may be used. Time periods for averaging are defined in &sect; 63.2.
(3) The data may be recorded in reduced or nonreduced form (e.g., ppm pollutant and percent 02 or ng/J of pollutant).
(4) All emission data shall be converted into units of the relevant standard for reporting purposes using the conversion procedures specified in that standard. After conversion into units of the relevant standard, the data may be rounded to the same number of significant digits as used in that standard to specify the emission limit (e.g., rounded to the nearest 1 percent opacity).
(5) Monitoring data recorded during periods of unavoidable CMS breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level adjustments must not be included in any data average computed under this part. For the owner or operator complying with the requirements of &sect; 63. 10(b)(2)(vii)(A) or (B), data averages must include any data recorded during periods of monitor breakdown or malfunction.
&sect; 63.9 Notification requirements.
(a) Applicability and general information.
(1) The applicability of this section is set out in &sect; 63. 1(a)(4).
(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.
(3) If any State requires a notice that contains all the information required in a notification listed in this section, the owner or operator may send the Administrator a copy of the notice sent to the State to satisfy the requirements of this section for that notification.
(3) If any State requires a notice that contains all the information required in a notification listed in this section, the owner or operator may send the Administrator a copy of the notice sent to the State to satisfy the requirements of this section for that notification.
(4) (i) Before a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in &sect; 63.13).Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-30 of 45 APPENDIX NESHAP SUBPART A General Provisions (ii) After a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the delegated State authority (which may be the same as the permitting authority).
(4)       (i) Before a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in &sect; 63.13).
In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each notification submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any notifications at its discretion.(b) Initial notifications.
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(1) (i) The requirements of this paragraph apply to the owner or operator of an affected source when such source becomes subject to a relevant standard.(ii) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source shall be subject to the notification requirements of this section.(iii) Affected sources that are required under this paragraph to submit an initial notification may use the application for approval of construction or reconstruction under &sect; 63.5(d) of this subpart, if relevant, to fulfill the initial notification requirements of this paragraph.
 
(2) The owner or operator of an affected source that has an initial startup before the effective date of a relevant standard under this part shall notify the Administrator in writing that the source is subject to the relevant standard.
APPENDIX NESHAP SUBPART A General Provisions (ii) After a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each notification submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any notifications at its discretion.
The notification, which shall be submitted not later than 120 calendar days after the effective date of the relevant standard (or within 120 calendar days after the source becomes subject to the relevant standard), shall provide the following information: (i) The name and address of the owner or operator;(ii) The address (i.e., physical location) of the affected source;(iii) An identification of the relevant standard, or other requirement, that is the basis of the notification and the source's compliance date;(iv) A brief description of the nature, size, design, and method of operation of the source and an identification of the types of emission points within the affected source subject to the relevant standard and types of hazardous air pollutants emitted; and (v) A statement of whether the affected source is a major source or an area source.(3) [Reserved]
(b) Initial notifications.
(4) The owner or operator of a new or reconstructed major affected source for which an application for approval of construction or reconstruction is required under &sect; 63.5(d) must provide the following information in writing to the Administrator: (i) A notification of intention to construct a new major-emitting affected source, reconstruct a major-emitting affected source, or reconstruct a major source such that the source becomes a major-emitting affected source with the application for approval of construction or reconstruction as specified in &sect; 63.5(d)(1)(i);
(1)       (i) The requirements of this paragraph apply to the owner or operator of an affected source when such source becomes subject to a relevant standard.
and (ii) [Reserved](iii) [Reserved](iv) [Reserved];
(ii) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source shall be subject to the notification requirements of this section.
and (v) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.(5) The owner or operator of a new or reconstructed affected source for which an application for approval of construction or reconstruction is not required under &sect; 63.5(d) must provide the following information in writing to the Administrator: (i) A notification of intention to construct a new affected source, reconstruct an affected source, or reconstruct a source such that the source becomes an affected source, and (ii) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.(iii) Unless the owner or operator has requested and received prior permission from the Administrator to submit less than the information in &sect; 63.5(d), the notification must include the information required on the application for approval of construction or reconstruction as specified in &sect; 63.5(d)(1)(i).(c) Request for extension of compliance.
(iii) Affected sources that are required under this paragraph to submit an initial notification may use the application for approval of construction or reconstruction under &sect; 63.5(d) of this subpart, if relevant, to fulfill the initial notification requirements of this paragraph.
If the owner or operator of an affected source cannot comply with a relevant standard by the applicable compliance date for that source, or if the owner or operator has installed BACT or technology to meet LAER consistent with &sect; 63.6(i)(5) of this subpart, he/she may submit to the Administrator (or the State with an approved permit program) a request for an extension of compliance as specified in &sect; 63.6(i)(4) through &sect;63.6(i)(6).
(2) The owner or operator of an affected source that has an initial startup before the effective date of a relevant standard under this part shall notify the Administrator in writing that the source is subject to the relevant standard. The notification, which shall be submitted not later than 120 calendar days after the effective date of the relevant standard (or within 120 calendar days after the source becomes subject to the relevant standard), shall provide the following information:
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-31 of 45 APPENDIX NESHAP SUBPART A General Provisions (d) Notification that source is subject to special compliance requirements.
(i) The name and address of the owner or operator; (ii) The address (i.e., physical location) of the affected source; (iii) An identification of the relevant standard, or other requirement, that is the basis of the notification and the source's compliance date; (iv) A brief description of the nature, size, design, and method of operation of the source and an identification of the types of emission points within the affected source subject to the relevant standard and types of hazardous air pollutants emitted; and (v) A statement of whether the affected source is a major source or an area source.
An owner or operator of a new source that is subject to special compliance requirements as specified in &sect; 63.6(b)(3) and &sect; 63.6(b)(4) shall notify the Administrator of his/her compliance obligations not later than the notification dates established in paragraph (b) of this section for new sources that are not subject to the special provisions.(e) Notification of performance test. The owner or operator of an affected source shall notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin to allow the Administrator to review and approve the site-specific test plan required under &sect; 63.7(c), if requested by the Administrator, and to have an observer present during the test.(f) Notification of opacity and visible emission observations.
(3) [Reserved]
The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting the opacity or visible emission observations specified in &sect;63.6(h)(5), if such observations are required for the source by a relevant standard.
(4) The owner or operator of a new or reconstructed major affected source for which an application for approval of construction or reconstruction is required under &sect; 63.5(d) must provide the following information in writing to the Administrator:
The notification shall be submitted with the notification of the performance test date, as specified in paragraph (e) of this section, or if no performance test is required or visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under &sect; 63.7, the owner or operator shall deliver or postmark the notification not less than 30 days before the opacity or visible emission observations are scheduled to take place.(g) Additional notification requirements for sources with continuous monitoring systems. The owner or operator of an affected source required to use a CMS by a relevant standard shall furnish the Administrator written notification as follows: (1) A notification of the date the CMS performance evaluation under &sect; 63.8(e) is scheduled to begin, submitted simultaneously with the notification of the performance test date required under &sect; 63.7(b). If no performance test is required, or if the requirement to conduct a performance test has been waived for an affected source under &sect; 63.7(h), the owner or operator shall notify the Administrator in writing of the date of the performance evaluation at least 60 calendar days before the evaluation is scheduled to begin;(2) A notification that COMS data results will be used to determine compliance with the applicable opacity emission standard during a performance test required by &sect; 63.7 in lieu of Method 9 or other opacity emissions test method data, as allowed by &sect; 63.6(h)(7)(ii), if compliance with an opacity emission standard is required for the source by a relevant standard.The notification shall be submitted at least 60 calendar days before the performance test is scheduled to begin; and (3) A notification that the criterion necessary to continue use of an alternative to relative accuracy testing, as provided by &sect; 63.8(f)(6), has been exceeded.
(i) A notification of intention to construct a new major-emitting affected source, reconstruct a major-emitting affected source, or reconstruct a major source such that the source becomes a major-emitting affected source with the application for approval of construction or reconstruction as specified in &sect; 63.5(d)(1)(i); and (ii) [Reserved]
The notification shall be delivered or postmarked not later than 10 days after the occurrence of such exceedance, and it shall include a description of the nature and cause of the increased emissions.(h) Notification of compliance status.(1) The requirements of paragraphs (h)(2) through (h)(4)of this section apply when an affected source becomes subject to a relevant standard.(2) (i) Before a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit to the Administrator a notification of compliance status, signed by the responsible official who shall certify its accuracy, attesting to whether the source has complied with the relevant standard.
(iii) [Reserved]
The notification shall list -(A) The methods that were used to determine compliance;(B) The results of any performance tests, opacity or visible emission observations, continuous monitoring system (CMS) performance evaluations, and/or other monitoring procedures or methods that were conducted;(C) The methods that will be used for determining continuing compliance, including a description of monitoring and reporting requirements and test methods;(D) The type and quantity of hazardous air pollutants emitted by the source (or surrogate pollutants if specified in the relevant standard), reported in units and averaging times and in accordance with the test methods specified in the relevant standard;(E) If the relevant standard applies to both major and area sources, an analysis demonstrating whether the affected source is a major source (using the emissions data generated for this notification);(F) A description of the air pollution control equipment (or method) for each emission point, including each control device (or method) for each hazardous air pollutant and the control efficiency (percent) for each control device (or method); and (G) A statement by the owner or operator of the affected existing, new, or reconstructed source as to whether the source has complied with the relevant standard or other requirements.(ii) The notification must be sent before the close of business on the 6 0 th day following the completion of the relevant compliance demonstration activity specified in the relevant standard (unless a different reporting period is Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-32 of 45 APPENDIX NESHAP SUBPART A General Provisions specified in the standard, in which case the letter must be sent before the close of business on the day the report of the relevant testing or monitoring results is required to be delivered or postmarked).
(iv) [Reserved]; and (v) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.
For example, the notification shall be sent before close of business on the 60th (or other required) day following completion of the initial performance test and again before the close of business on the 60th (or other required) day following the completion of any subsequent required performance test. If no performance test is required but opacity or visible emission observations are required to demonstrate compliance with an opacity or visible emission standard under this part, the notification of compliance status shall be sent before close of business on the 30th day following the completion of opacity or visible emission observations.
(5) The owner or operator of a new or reconstructed affected source for which an application for approval of construction or reconstruction is not required under &sect; 63.5(d) must provide the following information in writing to the Administrator:
Notifications may be combined as long as the due date requirement for each notification is met.(3) After a title V permit has been issued to the owner or operator of an affected source, the owner or operator of such source shall comply with all requirements for compliance status reports contained in the source's title V permit, including reports required under this part. After a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit the notification of compliance status to the appropriate permitting authority following completion of the relevant compliance demonstration activity specified in the relevant standard.(4) [Reserved]
(i) A notification of intention to construct a new affected source, reconstruct an affected source, or reconstruct a source such that the source becomes an affected source, and (ii) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date.
(5) If an owner or operator of an affected source submits estimates or preliminary information in the application for approval of construction or reconstruction required in &sect; 63.5(d) in place of the actual emissions data or control efficiencies required in paragraphs (d)(1)(ii)(H) and (d)(2) of &sect; 63.5, the owner or operator shall submit the actual emissions data and other correct information as soon as available but no later than with the initial notification of compliance status required in this section.(6) Advice on a notification of compliance status may be obtained from the Administrator.(i) Adjustment to time periods or postmark deadlines for submittal and review of required communications.
(iii) Unless the owner or operator has requested and received prior permission from the Administrator to submit less than the information in &sect; 63.5(d), the notification must include the information required on the application for approval of construction or reconstruction as specified in &sect; 63.5(d)(1)(i).
(1) (i) Until an adjustment of a time period or postmark deadline has been approved by the Administrator under paragraphs (i)(2) and (i)(3) of this section, the owner or operator of an affected source remains strictly subject to the requirements of this part.(ii) An owner or operator shall request the adjustment provided for in paragraphs (i)(2) and (i)(3) of this section each time he or she wishes to change an applicable time period or postmark deadline specified in this part.(2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator.
(c) Request for extension of compliance. If the owner or operator of an affected source cannot comply with a relevant standard by the applicable compliance date for that source, or if the owner or operator has installed BACT or technology to meet LAER consistent with &sect; 63.6(i)(5) of this subpart, he/she may submit to the Administrator (or the State with an approved permit program) a request for an extension of compliance as specified in &sect; 63.6(i)(4) through &sect; 63.6(i)(6).
An owner or operator who wishes to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The owner or operator shall include in the request whatever information he or she considers useful to convince the Administrator that an adjustment is warranted.
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-31 of 45
(3) If, in the Administrator's judgment, an owner or operator's request for an adjustment to a particular time period or postmark deadline is warranted, the Administrator will approve the adjustment.
 
The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request.(4) If the Administrator is unable to meet a specified deadline, he or she will notify the owner or operator of any significant delay and inform the owner or operator of the amended schedule.(j) Change in information already provided.
APPENDIX NESHAP SUBPART A General Provisions (d) Notification that source is subject to special compliance requirements. An owner or operator of a new source that is subject to special compliance requirements as specified in &sect; 63.6(b)(3) and &sect; 63.6(b)(4) shall notify the Administrator of his/her compliance obligations not later than the notification dates established in paragraph (b) of this section for new sources that are not subject to the special provisions.
Any change in the information already provided under this section shall be provided to the Administrator in writing within 15 calendar days after the change.&sect; 63.10 Recordkeeping and reporting requirements.(a) Applicability and general information.
(e) Notification of performance test. The owner or operator of an affected source shall notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin to allow the Administrator to review and approve the site-specific test plan required under &sect; 63.7(c), if requested by the Administrator, and to have an observer present during the test.
(1) The applicability of this section is set out in &sect; 63. 1(a)(4).(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.
(f) Notification of opacity and visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting the opacity or visible emission observations specified in &sect; 63.6(h)(5), if such observations are required for the source by a relevant standard. The notification shall be submitted with the notification of the performance test date, as specified in paragraph (e) of this section, or if no performance test is required or visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under &sect; 63.7, the owner or operator shall deliver or postmark the notification not less than 30 days before the opacity or visible emission observations are scheduled to take place.
(3) If any State requires a report that contains all the information required in a report listed in this section, an owner or operator may send the Administrator a copy of the report sent to the State to satisfy the requirements of this section for that report.(4) (i) Before a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-33 of 45 APPENDIX NESHAP SUBPART A General Provisions requirements shall submit reports to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in &sect; 63.13).(ii) After a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit reports to the delegated State authority (which may be the same as the permitting authority).
(g) Additional notification requirementsfor sources with continuous monitoring systems. The owner or operator of an affected source required to use a CMS by a relevant standard shall furnish the Administrator written notification as follows:
In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each report submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any reports at its discretion.
(1) A notification of the date the CMS performance evaluation under &sect; 63.8(e) is scheduled to begin, submitted simultaneously with the notification of the performance test date required under &sect; 63.7(b). If no performance test is required, or if the requirement to conduct a performance test has been waived for an affected source under &sect; 63.7(h), the owner or operator shall notify the Administrator in writing of the date of the performance evaluation at least 60 calendar days before the evaluation is scheduled to begin; (2) A notification that COMS data results will be used to determine compliance with the applicable opacity emission standard during a performance test required by &sect; 63.7 in lieu of Method 9 or other opacity emissions test method data, as allowed by &sect; 63.6(h)(7)(ii), if compliance with an opacity emission standard is required for the source by a relevant standard.
(5) If an owner or operator of an affected source in a State with delegated authority is required to submit periodic reports under this part to the State, and if the State has an established timeline for the submission of periodic reports that is consistent with the reporting frequency(ies) specified for such source under this part, the owner or operator may change the dates by which periodic reports under this part shall be submitted (without changing the frequency of reporting) to be consistent with the State's schedule by mutual agreement between the owner or operator and the State. For each relevant standard established pursuant to section 112 of the Act, the allowance in the previous sentence applies in each State beginning 1 year after the affected source's compliance date for that standard.
The notification shall be submitted at least 60 calendar days before the performance test is scheduled to begin; and (3) A notification that the criterion necessary to continue use of an alternative to relative accuracy testing, as provided by &sect; 63.8(f)(6), has been exceeded. The notification shall be delivered or postmarked not later than 10 days after the occurrence of such exceedance, and it shall include a description of the nature and cause of the increased emissions.
Procedures governing the implementation of this provision are specified in &sect; 63.9(i).(6) If an owner or operator supervises one or more stationary sources affected by more than one standard established pursuant to section 112 of the Act, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required for each source shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the latest compliance date for any relevant standard established pursuant to section 112 of the Act for any such affected source(s).
(h) Notification of compliance status.
Procedures governing the implementation of this provision are specified in &sect; 63.9(i).(7) If an owner or operator supervises one or more stationary sources affected by standards established pursuant to section 112 of the Act (as amended November 15, 1990) and standards set under part 60, part 61, or both such parts of this chapter, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required by each relevant (i.e., applicable) standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the stationary source is required to be in compliance with the relevant section 112 standard, or 1 year after the stationary source is required to be in compliance with the applicable part 60 or part 61 standard, whichever is latest. Procedures governing the implementation of this provision are specified in &sect; 63.9(i).(b) General recordkeeping requirements.
(1) The requirements of paragraphs (h)(2) through (h)(4)of this section apply when an affected source becomes subject to a relevant standard.
(2)       (i) Before a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit to the Administrator a notification of compliance status, signed by the responsible official who shall certify its accuracy, attesting to whether the source has complied with the relevant standard. The notification shall list -
(A) The methods that were used to determine compliance; (B) The results of any performance tests, opacity or visible emission observations, continuous monitoring system (CMS) performance evaluations, and/or other monitoring procedures or methods that were conducted; (C) The methods that will be used for determining continuing compliance, including a description of monitoring and reporting requirements and test methods; (D) The type and quantity of hazardous air pollutants emitted by the source (or surrogate pollutants if specified in the relevant standard), reported in units and averaging times and in accordance with the test methods specified in the relevant standard; (E) If the relevant standard applies to both major and area sources, an analysis demonstrating whether the affected source is a major source (using the emissions data generated for this notification);
(F) A description of the air pollution control equipment (or method) for each emission point, including each control device (or method) for each hazardous air pollutant and the control efficiency (percent) for each control device (or method); and (G) A statement by the owner or operator of the affected existing, new, or reconstructed source as to whether the source has complied with the relevant standard or other requirements.
(ii) The notification must be sent before the close of business on the 6 0 th day following the completion of the relevant compliance demonstration activity specified in the relevant standard (unless a different reporting period is Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-32 of 45
 
APPENDIX NESHAP SUBPART A General Provisions specified in the standard, in which case the letter must be sent before the close of business on the day the report of the relevant testing or monitoring results is required to be delivered or postmarked). For example, the notification shall be sent before close of business on the 60th (or other required) day following completion of the initial performance test and again before the close of business on the 60th (or other required) day following the completion of any subsequent required performance test. If no performance test is required but opacity or visible emission observations are required to demonstrate compliance with an opacity or visible emission standard under this part, the notification of compliance status shall be sent before close of business on the 30th day following the completion of opacity or visible emission observations. Notifications may be combined as long as the due date requirement for each notification is met.
(3) After a title V permit has been issued to the owner or operator of an affected source, the owner or operator of such source shall comply with all requirements for compliance status reports contained in the source's title V permit, including reports required under this part. After a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit the notification of compliance status to the appropriate permitting authority following completion of the relevant compliance demonstration activity specified in the relevant standard.
(4) [Reserved]
(5) If an owner or operator of an affected source submits estimates or preliminary information in the application for approval of construction or reconstruction required in &sect; 63.5(d) in place of the actual emissions data or control efficiencies required in paragraphs (d)(1)(ii)(H) and (d)(2) of &sect; 63.5, the owner or operator shall submit the actual emissions data and other correct information as soon as available but no later than with the initial notification of compliance status required in this section.
(6) Advice on a notification of compliance status may be obtained from the Administrator.
(i) Adjustment to time periods orpostmark deadlinesfor submittal and review of required communications.
(1)       (i) Until an adjustment of a time period or postmark deadline has been approved by the Administrator under paragraphs (i)(2) and (i)(3) of this section, the owner or operator of an affected source remains strictly subject to the requirements of this part.
(ii) An owner or operator shall request the adjustment provided for in paragraphs (i)(2) and (i)(3) of this section each time he or she wishes to change an applicable time period or postmark deadline specified in this part.
(2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. An owner or operator who wishes to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The owner or operator shall include in the request whatever information he or she considers useful to convince the Administrator that an adjustment is warranted.
(3) If, in the Administrator's judgment, an owner or operator's request for an adjustment to a particular time period or postmark deadline is warranted, the Administrator will approve the adjustment. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request.
(4) If the Administrator is unable to meet a specified deadline, he or she will notify the owner or operator of any significant delay and inform the owner or operator of the amended schedule.
(j) Change in information alreadyprovided. Any change in the information already provided under this section shall be provided to the Administrator in writing within 15 calendar days after the change.
&sect; 63.10 Recordkeeping and reporting requirements.
(a) Applicability and general information.
(1) The applicability of this section is set out in &sect; 63. 1(a)(4).
(2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions.
(3) If any State requires a report that contains all the information required in a report listed in this section, an owner or operator may send the Administrator a copy of the report sent to the State to satisfy the requirements of this section for that report.
(4)       (i) Before a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-33 of 45
 
APPENDIX NESHAP SUBPART A General Provisions requirements shall submit reports to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in &sect; 63.13).
(ii) After a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit reports to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each report submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any reports at its discretion.
(5) If an owner or operator of an affected source in a State with delegated authority is required to submit periodic reports under this part to the State, and if the State has an established timeline for the submission of periodic reports that is consistent with the reporting frequency(ies) specified for such source under this part, the owner or operator may change the dates by which periodic reports under this part shall be submitted (without changing the frequency of reporting) to be consistent with the State's schedule by mutual agreement between the owner or operator and the State. For each relevant standard established pursuant to section 112 of the Act, the allowance in the previous sentence applies in each State beginning 1 year after the affected source's compliance date for that standard. Procedures governing the implementation of this provision are specified in &sect; 63.9(i).
(6) If an owner or operator supervises one or more stationary sources affected by more than one standard established pursuant to section 112 of the Act, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required for each source shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the latest compliance date for any relevant standard established pursuant to section 112 of the Act for any such affected source(s). Procedures governing the implementation of this provision are specified in &sect; 63.9(i).
(7) If an owner or operator supervises one or more stationary sources affected by standards established pursuant to section 112 of the Act (as amended November 15, 1990) and standards set under part 60, part 61, or both such parts of this chapter, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required by each relevant (i.e., applicable) standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the stationary source is required to be in compliance with the relevant section 112 standard, or 1 year after the stationary source is required to be in compliance with the applicable part 60 or part 61 standard, whichever is latest. Procedures governing the implementation of this provision are specified in &sect; 63.9(i).
(b) General recordkeeping requirements.
(1) The owner or operator of an affected source subject to the provisions of this part shall maintain files of all information (including all reports and notifications) required by this part recorded in a form suitable and readily available for expeditious inspection and review. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. At a minimum, the most recent 2 years of data shall be retained on site. The remaining 3 years of data may be retained off site. Such files may be maintained on microfilm, on a computer, on computer floppy disks, on magnetic tape disks, or on microfiche.
(1) The owner or operator of an affected source subject to the provisions of this part shall maintain files of all information (including all reports and notifications) required by this part recorded in a form suitable and readily available for expeditious inspection and review. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. At a minimum, the most recent 2 years of data shall be retained on site. The remaining 3 years of data may be retained off site. Such files may be maintained on microfilm, on a computer, on computer floppy disks, on magnetic tape disks, or on microfiche.
(2) The owner or operator of an affected source subject to the provisions of this part shall maintain relevant records for such source of -(i) The occurrence and duration of each startup, shutdown, or malfunction of operation (i.e., process equipment);(ii) The occurrence and duration of each malfunction of the required air pollution control and monitoring equipment;(iii) All required maintenance performed on the air pollution control and monitoring equipment;(iv) Actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) when such actions are different from the procedures specified in the affected source's startup, shutdown, and malfunction plan (see &sect; 63.6(e)(3));(v) All information necessary to demonstrate conformance with the affected source's startup, shutdown, and malfunction plan (see &sect; 63.6(e)(3))
(2) The owner or operator of an affected source subject to the provisions of this part shall maintain relevant records for such source of -
when all actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) are consistent with the procedures specified in such plan. (The information needed to demonstrate conformance with the startup, shutdown, and malfunction plan may be recorded using a "checklist," or some other effective form of recordkeeping, in order to minimize the recordkeeping burden for conforming events);(vi) Each period during which a CMS is malfunctioning or inoperative (including out-of-control periods);Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-34 of 45 APPENDIX NESHAP SUBPART A General Provisions (vii) All required measurements needed to demonstrate compliance with a relevant standard (including, but not limited to, 15-minute averages of CMS data, raw performance testing measurements, and raw performance evaluation measurements, that support data that the source is required to report);(A) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction.
(i) The occurrence and duration of each startup, shutdown, or malfunction of operation (i.e., process equipment);
An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard.(B) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction.
(ii) The occurrence and duration of each malfunction of the required air pollution control and monitoring equipment; (iii) All required maintenance performed on the air pollution control and monitoring equipment; (iv) Actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) when such actions are different from the procedures specified in the affected source's startup, shutdown, and malfunction plan (see &sect; 63.6(e)(3));
In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this sections, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator.(C) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (b)(2)(vii), if the administrator or the delegated authority determines these records are required to more accurately assess the compliance status of the affected source.(viii) All results of performance tests, CMS performance evaluations, and opacity and visible emission observations;(ix) All measurements as may be necessary to determine the conditions of performance tests and performance evaluations;(x) All CMS calibration checks;(xi) All adjustments and maintenance performed on CMS;(xii) Any information demonstrating whether a source is meeting the requirements for a waiver of recordkeeping or reporting requirements under this part, if the source has been granted a waiver under paragraph (f) of this section;(xiii) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under&sect; 63.8(f)(6);
(v) All information necessary to demonstrate conformance with the affected source's startup, shutdown, and malfunction plan (see &sect; 63.6(e)(3)) when all actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) are consistent with the procedures specified in such plan. (The information needed to demonstrate conformance with the startup, shutdown, and malfunction plan may be recorded using a "checklist," or some other effective form of recordkeeping, in order to minimize the recordkeeping burden for conforming events);
and (xiv) All documentation supporting initial notifications and notifications of compliance status under &sect; 63.9.(3) Recordkeeping requirement for applicability determinations.
(vi) Each period during which a CMS is malfunctioning or inoperative (including out-of-control periods);
If an owner or operator determines that his or her stationary source that emits (or has the potential to emit, without considering controls) one or more hazardous air pollutants regulated by any standard established pursuant to section 112(d) or (f), and that stationary source is in the source category regulated by the relevant standard, but that source is not subject to the relevant standard (or other requirement established under this part) because of limitations on the source's potential to emit or an exclusion, the owner or operator must keep a record of the applicability determination on site at the source for a period of 5 years after the determination, or until the source changes its operations to become an affected source, whichever comes first. The record of the applicability determination must be signed by the person making the determination and include an analysis (or other information) that demonstrates why the owner or operator believes the source is unaffected (e.g., because the source is an area source). The analysis (or other information) must be sufficiently detailed to allow the Administrator to make a finding about the source's applicability status with regard to the relevant standard or other requirement.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-34 of 45
If relevant, the analysis must be performed in accordance with requirements established in relevant subparts of this part for this purpose for particular categories of stationary sources. If relevant, the analysis should be performed in accordance with EPA guidance materials published to assist sources in making applicability determinations under section 112, if any. The requirements to determine applicability of a standard under &sect; 63.1 (b)(3) and to record the results of that determination under paragraph (b)(3) of this section shall not by themselves create an obligation for the owner or operator to obtain a title V permit.(c) Additional recordkeeping requirements for sources with continuous monitoring systems. In addition to complying with the requirements specified in paragraphs (b)(1) and (b)(2) of this section, the owner or operator of an affected source required to install a CMS by a relevant standard shall maintain records for such source of -(1) All required CMS measurements (including monitoring data recorded during unavoidable CMS breakdowns and out-of-control periods);(2)-(4) [Reserved]
 
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-35 of 45 APPENDIX NESHAP SUBPART A General Provisions (5) The date and time identifying each period during which the CMS was inoperative except for zero (low-level) and high-level checks;(6) The date and time identifying each period during which the CMS was out of control, as defined in &sect; 63.8(c)(7);
APPENDIX NESHAP SUBPART A General Provisions (vii) All required measurements needed to demonstrate compliance with a relevant standard (including, but not limited to, 15-minute averages of CMS data, raw performance testing measurements, and raw performance evaluation measurements, that support data that the source is required to report);
(7) The specific identification (i.e., the date and time of commencement and completion) of each period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during startups, shutdowns, and malfunctions of the affected source;(8) The specific identification (i.e., the date and time of commencement and completion) of each time period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during periods other than startups, shutdowns, and malfunctions of the affected source;(9) [Reserved]
(A) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard.
(10) The nature and cause of any malfunction (if known);(11) The corrective action taken or preventive measures adopted;(12) The nature of the repairs or adjustments to the CMS that was inoperative or out of control;(13) The total process operating time during the reporting period; and (14) All procedures that are part of a quality control program developed and implemented for CMS under &sect; 63.8(d).(15) In order to satisfy the requirements of paragraphs (c)(10) through (c)(12) of this section and to avoid duplicative recordkeeping efforts, the owner or operator may use the affected source's startup, shutdown, and malfunction plan or records kept to satisfy the recordkeeping requirements of the startup, shutdown, and malfunction plan specified in &sect;63.6(e), provided that such plan and records adequately address the requirements of paragraphs (c)(10) through (c)(12).(d) General reporting requirements.
(B) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this sections, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator.
(C) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (b)(2)(vii), if the administrator or the delegated authority determines these records are required to more accurately assess the compliance status of the affected source.
(viii) All results of performance tests, CMS performance evaluations, and opacity and visible emission observations; (ix) All measurements as may be necessary to determine the conditions of performance tests and performance evaluations; (x) All CMS calibration checks; (xi) All adjustments and maintenance performed on CMS; (xii) Any information demonstrating whether a source is meeting the requirements for a waiver of recordkeeping or reporting requirements under this part, if the source has been granted a waiver under paragraph (f) of this section; (xiii) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under
&sect; 63.8(f)(6); and (xiv) All documentation supporting initial notifications and notifications of compliance status under &sect; 63.9.
(3) Recordkeeping requirementfor applicabilitydeterminations.If an owner or operator determines that his or her stationary source that emits (or has the potential to emit, without considering controls) one or more hazardous air pollutants regulated by any standard established pursuant to section 112(d) or (f), and that stationary source is in the source category regulated by the relevant standard, but that source is not subject to the relevant standard (or other requirement established under this part) because of limitations on the source's potential to emit or an exclusion, the owner or operator must keep a record of the applicability determination on site at the source for a period of 5 years after the determination, or until the source changes its operations to become an affected source, whichever comes first. The record of the applicability determination must be signed by the person making the determination and include an analysis (or other information) that demonstrates why the owner or operator believes the source is unaffected (e.g., because the source is an area source). The analysis (or other information) must be sufficiently detailed to allow the Administrator to make a finding about the source's applicability status with regard to the relevant standard or other requirement. If relevant, the analysis must be performed in accordance with requirements established in relevant subparts of this part for this purpose for particular categories of stationary sources. If relevant, the analysis should be performed in accordance with EPA guidance materials published to assist sources in making applicability determinations under section 112, if any. The requirements to determine applicability of a standard under &sect; 63.1 (b)(3) and to record the results of that determination under paragraph (b)(3) of this section shall not by themselves create an obligation for the owner or operator to obtain a title V permit.
(c) Additional recordkeeping requirementsfor sources with continuous monitoring systems. In addition to complying with the requirements specified in paragraphs (b)(1) and (b)(2) of this section, the owner or operator of an affected source required to install a CMS by a relevant standard shall maintain records for such source of -
(1) All required CMS measurements (including monitoring data recorded during unavoidable CMS breakdowns and out-of-control periods);
(2)-(4) [Reserved]
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-35 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (5) The date and time identifying each period during which the CMS was inoperative except for zero (low-level) and high-level checks; (6) The date and time identifying each period during which the CMS was out of control, as defined in &sect; 63.8(c)(7);
(7) The specific identification (i.e., the date and time of commencement and completion) of each period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during startups, shutdowns, and malfunctions of the affected source; (8) The specific identification (i.e., the date and time of commencement and completion) of each time period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during periods other than startups, shutdowns, and malfunctions of the affected source; (9) [Reserved]
(10) The nature and cause of any malfunction (if known);
(11) The corrective action taken or preventive measures adopted; (12) The nature of the repairs or adjustments to the CMS that was inoperative or out of control; (13) The total process operating time during the reporting period; and (14) All procedures that are part of a quality control program developed and implemented for CMS under &sect; 63.8(d).
(15) In order to satisfy the requirements of paragraphs (c)(10) through (c)(12) of this section and to avoid duplicative recordkeeping efforts, the owner or operator may use the affected source's startup, shutdown, and malfunction plan or records kept to satisfy the recordkeeping requirements of the startup, shutdown, and malfunction plan specified in &sect; 63.6(e), provided that such plan and records adequately address the requirements of paragraphs (c)(10) through (c)(12).
(d) General reporting requirements.
(1) Not-withstanding the requirements in this paragraph or paragraph (e) of this section, the owner or operator of an affected source subject to reporting requirements under this part shall submit reports to the Administrator in accordance with the reporting requirements in the relevant standard(s).
(1) Not-withstanding the requirements in this paragraph or paragraph (e) of this section, the owner or operator of an affected source subject to reporting requirements under this part shall submit reports to the Administrator in accordance with the reporting requirements in the relevant standard(s).
(2) Reporting results of performance tests. Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of any performance test under &sect; 63.7 to the Administrator.
(2) Reporting results of performance tests. Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of any performance test under &sect; 63.7 to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of a required performance test to the appropriate permitting authority. The owner or operator of an affected source shall report the results of the performance test to the Administrator (or the State with an approved permit program) before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator. The results of the performance test shall be submitted as part of the notification of compliance status required under &sect; 63.9(h).
After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of a required performance test to the appropriate permitting authority.
(3) Reporting results of opacity or visible emission observations.The owner or operator of an affected source required to conduct opacity or visible emission observations by a relevant standard shall report the opacity or visible emission results (produced using Test Method 9 or Test Method 22, or an alternative to these test methods) along with the results of the performance test required under &sect; 63.7. If no performance test is required, or if visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the performance test required under &sect; 63.7, the owner or operator shall report the opacity or visible emission results before the close of business on the 30th day following the completion of the opacity or visible emission observations.
The owner or operator of an affected source shall report the results of the performance test to the Administrator (or the State with an approved permit program) before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator.
(4) Progressreports. The owner or operator of an affected source who is required to submit progress reports as a condition of receiving an extension of compliance under &sect; 63.6(i) shall submit such reports to the Administrator (or the State with an approved permit program) by the dates specified in the written extension of compliance.
The results of the performance test shall be submitted as part of the notification of compliance status required under &sect; 63.9(h).(3) Reporting results of opacity or visible emission observations.
(5)       (i) Periodic startup, shutdown, and malfunction reports. If actions taken by an owner or operator during a startup, shutdown, or malfunction of an affected source (including actions taken to correct a malfunction) are consistent with the procedures specified in the source's startup, shutdown, and malfunction plan (see Sec. 63.6(e)(3)), the owner or operator shall state such information in a startup, shutdown, and malfunction report. Such a report shall identify any instance where any action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the affected source's startup, shutdown, and malfunction plan, but the source does not exceed any applicable emission limitation in the relevant emission standard. Such a report shall also include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. Reports shall only be required if a startup, shutdown, or malfunction occurred during the reporting period. The startup, shutdown, and malfunction report shall consist of a letter, containing the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, that shall be submitted to the Administrator semiannually (or on a more frequent basis if specified otherwise in a relevant standard or as established otherwise by the permitting authority in the source's title V permit). The startup, shutdown, and malfunction report shall be delivered or postmarked by the 30th day following the end of each calendar half (or other calendar reporting period, as appropriate). If the owner or operator is required to submit excess emissions and continuous monitoring system performance (or other periodic) reports under this part, the startup, shutdown, and malfunction Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-36 of 45
The owner or operator of an affected source required to conduct opacity or visible emission observations by a relevant standard shall report the opacity or visible emission results (produced using Test Method 9 or Test Method 22, or an alternative to these test methods) along with the results of the performance test required under &sect; 63.7. If no performance test is required, or if visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the performance test required under &sect; 63.7, the owner or operator shall report the opacity or visible emission results before the close of business on the 30th day following the completion of the opacity or visible emission observations.
 
(4) Progress reports. The owner or operator of an affected source who is required to submit progress reports as a condition of receiving an extension of compliance under &sect; 63.6(i) shall submit such reports to the Administrator (or the State with an approved permit program) by the dates specified in the written extension of compliance.
APPENDIX NESHAP SUBPART A General Provisions reports required under this paragraph may be submitted simultaneously with the excess emissions and continuous monitoring system performance (or other) reports. If startup, shutdown, and malfunction reports are submitted with excess emissions and continuous monitoring system performance (or other periodic) reports, and the owner or operator receives approval to reduce the frequency of reporting for the latter under paragraph (e) of this section, the frequency of reporting for the startup, shutdown, and malfunction reports also may be reduced if the Administrator does not object to the intended change. The procedures to implement the allowance in the preceding sentence shall be the same as the procedures specified in paragraph (e)(3) of this section.
(5) (i) Periodic startup, shutdown, and malfunction reports. If actions taken by an owner or operator during a startup, shutdown, or malfunction of an affected source (including actions taken to correct a malfunction) are consistent with the procedures specified in the source's startup, shutdown, and malfunction plan (see Sec. 63.6(e)(3)), the owner or operator shall state such information in a startup, shutdown, and malfunction report. Such a report shall identify any instance where any action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the affected source's startup, shutdown, and malfunction plan, but the source does not exceed any applicable emission limitation in the relevant emission standard.
(ii) Immediate startup, shutdown, and malfunction reports. Notwithstanding the allowance to reduce the frequency of reporting for periodic startup, shutdown, and malfunction reports under paragraph (d)(5)(i) of this section, any time an action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, the owner or operator shall report the actions taken for that event within 2 working days after commencing actions inconsistent with the plan followed by a letter within 7 working days after the end of the event. The immediate report required under this paragraph (d)(5)(ii) shall consist of a telephone call (or facsimile (FAX) transmission) to the Administrator within 2 working days after commencing actions inconsistent with the plan, and it shall be followed by a letter, delivered or postmarked within 7 working days after the end of the event, that contains the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, explaining the circumstances of the event, the reasons for not following the startup, shutdown, and malfunction plan, and describing all excess emissions and/or parameter monitoring exceedances which are believed to have occurred. Notwithstanding the requirements of the previous sentence, after the effective date of an approved permit program in the State in which an affected source is located, the owner or operator may make alternative reporting arrangements, in advance, with the permitting authority in that State. Procedures governing the arrangement of alternative reporting requirements under this paragraph (d)(5)(ii) are specified in Sec. 63.9(i).
Such a report shall also include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded.
(e) Additional reporting requirementsfor sources with continuous monitoring systems -
Reports shall only be required if a startup, shutdown, or malfunction occurred during the reporting period. The startup, shutdown, and malfunction report shall consist of a letter, containing the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, that shall be submitted to the Administrator semiannually (or on a more frequent basis if specified otherwise in a relevant standard or as established otherwise by the permitting authority in the source's title V permit). The startup, shutdown, and malfunction report shall be delivered or postmarked by the 30th day following the end of each calendar half (or other calendar reporting period, as appropriate).
(1) General. When more than one CEMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CEMS.
If the owner or operator is required to submit excess emissions and continuous monitoring system performance (or other periodic) reports under this part, the startup, shutdown, and malfunction Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-36 of 45 APPENDIX NESHAP SUBPART A General Provisions reports required under this paragraph may be submitted simultaneously with the excess emissions and continuous monitoring system performance (or other) reports. If startup, shutdown, and malfunction reports are submitted with excess emissions and continuous monitoring system performance (or other periodic) reports, and the owner or operator receives approval to reduce the frequency of reporting for the latter under paragraph (e) of this section, the frequency of reporting for the startup, shutdown, and malfunction reports also may be reduced if the Administrator does not object to the intended change. The procedures to implement the allowance in the preceding sentence shall be the same as the procedures specified in paragraph (e)(3) of this section.(ii) Immediate startup, shutdown, and malfunction reports. Notwithstanding the allowance to reduce the frequency of reporting for periodic startup, shutdown, and malfunction reports under paragraph (d)(5)(i) of this section, any time an action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, the owner or operator shall report the actions taken for that event within 2 working days after commencing actions inconsistent with the plan followed by a letter within 7 working days after the end of the event. The immediate report required under this paragraph (d)(5)(ii) shall consist of a telephone call (or facsimile (FAX) transmission) to the Administrator within 2 working days after commencing actions inconsistent with the plan, and it shall be followed by a letter, delivered or postmarked within 7 working days after the end of the event, that contains the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, explaining the circumstances of the event, the reasons for not following the startup, shutdown, and malfunction plan, and describing all excess emissions and/or parameter monitoring exceedances which are believed to have occurred.
(2) Reporting results of continuous monitoring system performance evaluations.
Notwithstanding the requirements of the previous sentence, after the effective date of an approved permit program in the State in which an affected source is located, the owner or operator may make alternative reporting arrangements, in advance, with the permitting authority in that State. Procedures governing the arrangement of alternative reporting requirements under this paragraph (d)(5)(ii) are specified in Sec. 63.9(i).(e) Additional reporting requirements for sources with continuous monitoring systems -(1) General. When more than one CEMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CEMS.(2) Reporting results of continuous monitoring system performance evaluations.(i) The owner or operator of an affected source required to install a CMS by a relevant standard shall furnish the Administrator a copy of a written report of the results of the CMS performance evaluation, as required under &sect;63.8(e), simultaneously with the results of the performance test required under &sect; 63.7, unless otherwise specified in the relevant standard.(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under &sect; 63.7 and described in &sect; 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation conducted under &sect; 63.8(e). The copies shall be furnished at least 15 calendar days before the performance test required under &sect; 63.7 is conducted.
(i) The owner or operator of an affected source required to install a CMS by a relevant standard shall furnish the Administrator a copy of a written report of the results of the CMS performance evaluation, as required under &sect; 63.8(e), simultaneously with the results of the performance test required under &sect; 63.7, unless otherwise specified in the relevant standard.
(3) Excess emissions and continuous monitoring system performance report and summary report.(i) Excess emissions and parameter monitoring exceedances are defined in relevant standards.
(ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under &sect; 63.7 and described in &sect; 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation conducted under &sect; 63.8(e). The copies shall be furnished at least 15 calendar days before the performance test required under &sect; 63.7 is conducted.
The owner or operator of an affected source required to install a CMS by a relevant standard shall submit an excess emissions and continuous monitoring system performance report and/or a summary report to the Administrator semiannually, except when -(A) More frequent reporting is specifically required by a relevant standard;(B) The Administrator determines on a case-by-case basis that more frequent reporting is necessary to accurately assess the compliance status of the source; or (C) [Reserved].(ii) Request to reduce frequency of excess emissions and continuous monitoring system performance reports. Notwithstanding the frequency of reporting requirements specified in paragraph (e)(3)(i) of this section, an owner or operator who is required by a relevant standard to submit excess emissions and continuous monitoring system performance (and summary) reports on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met: (A) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected source's excess emissions and continuous monitoring system performance reports continually demonstrate that the source is in compliance with the relevant standard;(B) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the relevant standard; and (C) The Administrator does not object to a reduced frequency of reporting for the affected source, as provided in paragraph (e)(3)(iii) of this section.(iii) The frequency of reporting of excess emissions and continuous monitoring system performance (and summary) reports required to comply with a relevant standard may be reduced only after the owner or operator notifies the Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-37 of 45 APPENDIX NESHAP SUBPART A General Provisions Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the 5-year recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements.
(3) Excess emissions and continuous monitoring system performance report and summary report.
Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention.
(i) Excess emissions and parameter monitoring exceedances are defined in relevant standards. The owner or operator of an affected source required to install a CMS by a relevant standard shall submit an excess emissions and continuous monitoring system performance report and/or a summary report to the Administrator semiannually, except when -
The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted.(iv) As soon as CMS data indicate that the source is not in compliance with any emission limitation or operating parameter specified in the relevant standard, the frequency of reporting shall revert to the frequency specified in the relevant standard, and the owner or operator shall submit an excess emissions and continuous monitoring system performance (and summary) report for the noncomplying emission points at the next appropriate reporting period following the noncomplying event. After demonstrating ongoing compliance with the relevant standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard, as provided for in paragraphs (e)(3)(ii) and (e)(3)(iii) of this section.(v) Content and submittal dates for excess emissions and monitoring system performance reports. All excess emissions and monitoring system performance reports and all summary reports, if required, shall be delivered or postmarked by the 30th day following the end of each calendar half or quarter, as appropriate.
(A) More frequent reporting is specifically required by a relevant standard; (B) The Administrator determines on a case-by-case basis that more frequent reporting is necessary to accurately assess the compliance status of the source; or (C) [Reserved].
Written reports of excess emissions or exceedances of process or control system parameters shall include all the information required in paragraphs (c)(5) through (c)(13) of this section, in &sect; 63.8(c)(7) and &sect; 63.8(c)(8), and in the relevant standard, and they shall contain the name, title, and signature of the responsible official who is certifying the accuracy of the report. When no excess emissions or exceedances of a parameter have occurred, or a CMS has not been inoperative, out of control, repaired, or adjusted, such information shall be stated in the report.(vi) Summary report. As required under paragraphs (e)(3)(vii) and (e)(3)(viii) of this section, one summary report shall be submitted for the hazardous air pollutants monitored at each affected source (unless the relevant standard specifies that more than one summary report is required, e.g., one summary report for each hazardous air pollutant monitored).
(ii) Request to reduce frequency of excess emissions and continuous monitoring system performance reports. Notwithstanding the frequency of reporting requirements specified in paragraph (e)(3)(i) of this section, an owner or operator who is required by a relevant standard to submit excess emissions and continuous monitoring system performance (and summary) reports on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met:
The summary report shall be entitled "Summary Report -Gaseous and Opacity Excess Emission and Continuous Monitoring System Performance" and shall contain the following information: (A) The company name and address of the affected source;(B) An identification of each hazardous air pollutant monitored at the affected source;(C) The beginning and ending dates of the reporting period;(D) A brief description of the process units;(E) The emission and operating parameter limitations specified in the relevant standard(s);(F) The monitoring equipment manufacturer(s) and model number(s);(G) The date of the latest CMS certification or audit;(H) The total operating time of the affected source during the reporting period;(I) An emission data summary (or similar summary if the owner or operator monitors control system parameters), including the total duration of excess emissions during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of excess emissions expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total duration of excess emissions during the reporting period into those that are due to startup/shutdown, control equipment problems, process problems, other known causes, and other unknown causes;(J) A CMS performance summary (or similar summary if the owner or operator monitors control system parameters), including the total CMS downtime during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of CMS downtime expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total CMS downtime during the reporting period into periods that are due to monitoring equipment malfunctions, nonmonitoring equipment malfunctions, quality assurance/quality control calibrations, other known causes, and other unknown causes;(K) A description of any changes in CMS, processes, or controls since the last reporting period;(L) The name, title, and signature of the responsible official who is certifying the accuracy of the report; and (M) The date of the report.(vii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is less than 1 percent of the total operating time for the reporting period, and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report shall be Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-38 of 45 APPENDIX NESHAP SUBPART A General Provisions submitted, and the full excess emissions and continuous monitoring system performance report need not be submitted unless required by the Administrator.(viii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is 1 percent or greater of the total operating time for the reporting period, or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, both the summary report and the excess emissions and continuous monitoring system performance report shall be submitted.
(A) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected source's excess emissions and continuous monitoring system performance reports continually demonstrate that the source is in compliance with the relevant standard; (B) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the relevant standard; and (C) The Administrator does not object to a reduced frequency of reporting for the affected source, as provided in paragraph (e)(3)(iii) of this section.
(4) Reporting continuous opacity monitoring system data produced during a performance test. The owner or operator of an affected source required to use a COMS shall record the monitoring data produced during a performance test required under &sect; 63.7 and shall furnish the Administrator a written report of the monitoring results. The report of COMS data shall be submitted simultaneously with the report of the performance test results required in paragraph (d)(2) of this section.(f) Waiver of recordkeeping or reporting requirements.
(iii) The frequency of reporting of excess emissions and continuous monitoring system performance (and summary) reports required to comply with a relevant standard may be reduced only after the owner or operator notifies the Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPA-37 of 45
(1) Until a waiver of a recordkeeping or reporting requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.(2) Recordkeeping or reporting requirements may be waived upon written application to the Administrator if, in the Administrator's judgment, the affected source is achieving the relevant standard(s), or the source is operating under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.(3) If an application for a waiver of record-keeping or reporting is made, the application shall accompany the request for an extension of compliance under &sect; 63.6(i), any required compliance progress report or compliance status report required under this part (such as under&sect; 63.6(i) and &sect; 63.9(h)) or in the source's title V permit, or an excess emissions and continuous monitoring system performance report required under paragraph (e) of this section, whichever is applicable.
 
The application shall include whatever information the owner or operator considers useful to convince the Administrator that a waiver of recordkeeping or reporting is warranted.
APPENDIX NESHAP SUBPART A General Provisions Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the 5-year recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements. Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention. The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted.
(4) The Administrator will approve or deny a request for a waiver of recordkeeping or reporting requirements under this paragraph when he/she -(i) Approves or denies an extension of compliance; or (ii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iii) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.
(iv) As soon as CMS data indicate that the source is not in compliance with any emission limitation or operating parameter specified in the relevant standard, the frequency of reporting shall revert to the frequency specified in the relevant standard, and the owner or operator shall submit an excess emissions and continuous monitoring system performance (and summary) report for the noncomplying emission points at the next appropriate reporting period following the noncomplying event. After demonstrating ongoing compliance with the relevant standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard, as provided for in paragraphs (e)(3)(ii) and (e)(3)(iii) of this section.
(v) Content and submittal datesfor excess emissions and monitoring system performance reports. All excess emissions and monitoring system performance reports and all summary reports, if required, shall be delivered or postmarked by the 30th day following the end of each calendar half or quarter, as appropriate. Written reports of excess emissions or exceedances of process or control system parameters shall include all the information required in paragraphs (c)(5) through (c)(13) of this section, in &sect; 63.8(c)(7) and &sect; 63.8(c)(8), and in the relevant standard, and they shall contain the name, title, and signature of the responsible official who is certifying the accuracy of the report. When no excess emissions or exceedances of a parameter have occurred, or a CMS has not been inoperative, out of control, repaired, or adjusted, such information shall be stated in the report.
(vi) Summary report.As required under paragraphs (e)(3)(vii) and (e)(3)(viii) of this section, one summary report shall be submitted for the hazardous air pollutants monitored at each affected source (unless the relevant standard specifies that more than one summary report is required, e.g., one summary report for each hazardous air pollutant monitored). The summary report shall be entitled "Summary Report - Gaseous and Opacity Excess Emission and Continuous Monitoring System Performance" and shall contain the following information:
(A) The company name and address of the affected source; (B) An identification of each hazardous air pollutant monitored at the affected source; (C) The beginning and ending dates of the reporting period; (D) A brief description of the process units; (E) The emission and operating parameter limitations specified in the relevant standard(s);
(F) The monitoring equipment manufacturer(s) and model number(s);
(G) The date of the latest CMS certification or audit; (H) The total operating time of the affected source during the reporting period; (I) An emission data summary (or similar summary if the owner or operator monitors control system parameters), including the total duration of excess emissions during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of excess emissions expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total duration of excess emissions during the reporting period into those that are due to startup/shutdown, control equipment problems, process problems, other known causes, and other unknown causes; (J) A CMS performance summary (or similar summary if the owner or operator monitors control system parameters), including the total CMS downtime during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of CMS downtime expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total CMS downtime during the reporting period into periods that are due to monitoring equipment malfunctions, nonmonitoring equipment malfunctions, quality assurance/quality control calibrations, other known causes, and other unknown causes; (K) A description of any changes in CMS, processes, or controls since the last reporting period; (L) The name, title, and signature of the responsible official who is certifying the accuracy of the report; and (M) The date of the report.
(vii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is less than 1 percent of the total operating time for the reporting period, and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report shall be Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-38 of 45
 
APPENDIX NESHAP SUBPART A General Provisions submitted, and the full excess emissions and continuous monitoring system performance report need not be submitted unless required by the Administrator.
(viii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is 1 percent or greater of the total operating time for the reporting period, or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, both the summary report and the excess emissions and continuous monitoring system performance report shall be submitted.
(4) Reporting continuous opacity monitoring system data produced during a performance test. The owner or operator of an affected source required to use a COMS shall record the monitoring data produced during a performance test required under &sect; 63.7 and shall furnish the Administrator a written report of the monitoring results. The report of COMS data shall be submitted simultaneously with the report of the performance test results required in paragraph (d)(2) of this section.
(f) Waiver of recordkeeping or reporting requirements.
(1) Until a waiver of a recordkeeping or reporting requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section.
(2) Recordkeeping or reporting requirements may be waived upon written application to the Administrator if, in the Administrator's judgment, the affected source is achieving the relevant standard(s), or the source is operating under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request.
(3) If an application for a waiver of record-keeping or reporting is made, the application shall accompany the request for an extension of compliance under &sect; 63.6(i), any required compliance progress report or compliance status report required under this part (such as under
&sect; 63.6(i) and &sect; 63.9(h)) or in the source's title V permit, or an excess emissions and continuous monitoring system performance report required under paragraph (e) of this section, whichever is applicable. The application shall include whatever information the owner or operator considers useful to convince the Administrator that a waiver of recordkeeping or reporting is warranted.
(4) The Administrator will approve or deny a request for a waiver of recordkeeping or reporting requirements under this paragraph when he/she -
(i) Approves or denies an extension of compliance; or (ii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iii) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable.
(5) A waiver of any recordkeeping or reporting requirement granted under this paragraph may be conditioned on other recordkeeping or reporting requirements deemed necessary by the Administrator.
(5) A waiver of any recordkeeping or reporting requirement granted under this paragraph may be conditioned on other recordkeeping or reporting requirements deemed necessary by the Administrator.
(6) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.&sect; 63.11 Control device requirements.(a) Applicability.
(6) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source.
The applicability of this section is set out in Sec. 63. 1(a)(4).(b) Flares.(1) Owners or operators using flares to comply with the provisions of this part shall monitor these control devices to assure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators using flares shall monitor these control devices.(2) Flares shall be steam-assisted, air-assisted, or non-assisted.
&sect; 63.11 Control device requirements.
(3) Flares shall be operated at all times when emissions may be vented to them.(4) Flares shall be designed for and operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. Test Method 22 in appendix A of part 60 of this chapter shall be used to determine the compliance of flares with the visible emission provisions of this part. The observation period is 2 hours and shall be used according to Method 22.(5) Flares shall be operated with a flame present at all times. The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame.(6) An owner/operator has the choice of adhering to the heat content specifications in paragraph (b)(6)(ii) of this section, and the maximum tip velocity specifications in paragraph (b)(7) or (b)(8) of this section, or adhering to the requirements in paragraph (b)(6)(i) of this section.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-39 of 45 APPENDIX NESHAP SUBPART A General Provisions (i) (A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume) or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity Vmax, as determined by the following equation: Vmax = (XH2 -KI)
(a) Applicability. The applicability of this section is set out in Sec. 63. 1(a)(4).
* K 2 Where: Vmax = Maximum permitted velocity, m/sec.K, = Constant, 6.0 volume-percent hydrogen.K 2 = Constant, 3.9 (m/sec)/volume-percent hydrogen.XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in &sect; 63.14).(B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (b)(7)(i) of this section.(ii) Flares shall be used only with the net heating value of the gas being combusted at 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted at 7.45 MJ/scm (200 Btu/scf) or greater if the flare is non-assisted.
(b) Flares.
The net heating value of the gas being combusted in a flare shall be calculated using the following equation: n HT = K ED CiHi i=l Where: HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 'C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 'C.K = Constant = 1.740 x 10-7 (1/ppmv)(g-mole/scm)(MJ/kcal);
(1) Owners or operators using flares to comply with the provisions of this part shall monitor these control devices to assure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators using flares shall monitor these control devices.
where the standard temperature for (g-mole/scm) is 20 'C.Ci = Concentration of sample component i in ppmv on a wet basis, as measured for organics by Test Method 18 and measured for hydrogen and carbon monoxide by American Society for Testing and Materials (ASTM) D1946-77 or 90 (Reapproved 1994) (incorporated by reference as specified in &sect;63.14).Hi = Net heat of combustion of sample component i, kcal/g-mole at 25 'C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95. (incorporated by reference as specified in &sect; 63.14) if published values are not available or cannot be calculated.
(2) Flares shall be steam-assisted, air-assisted, or non-assisted.
(3) Flares shall be operated at all times when emissions may be vented to them.
(4) Flares shall be designed for and operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. Test Method 22 in appendix A of part 60 of this chapter shall be used to determine the compliance of flares with the visible emission provisions of this part. The observation period is 2 hours and shall be used according to Method 22.
(5) Flares shall be operated with a flame present at all times. The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame.
(6) An owner/operator has the choice of adhering to the heat content specifications in paragraph (b)(6)(ii) of this section, and the maximum tip velocity specifications in paragraph (b)(7) or (b)(8) of this section, or adhering to the requirements in paragraph (b)(6)(i) of this section.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-39 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (i)       (A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume) or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity Vmax, as determined by the following equation:
Vmax = (XH2 - KI)
* K2 Where:
Vmax = Maximum permitted velocity, m/sec.
K, = Constant, 6.0 volume-percent hydrogen.
K2 = Constant, 3.9 (m/sec)/volume-percent hydrogen.
XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in &sect; 63.14).
(B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (b)(7)(i) of this section.
(ii) Flares shall be used only with the net heating value of the gas being combusted at 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted at 7.45 MJ/scm (200 Btu/scf) or greater if the flare is non-assisted. The net heating value of the gas being combusted in a flare shall be calculated using the following equation:
n HT = K EDCiHi i=l Where:
HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 'C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 'C.
K = Constant = 1.740 x 10-7 (1/ppmv)(g-mole/scm)(MJ/kcal); where the standard temperature for (g-mole/scm) is 20 'C.
Ci = Concentration of sample component i in ppmv on a wet basis, as measured for organics by Test Method 18 and measured for hydrogen and carbon monoxide by American Society for Testing and Materials (ASTM) D1946-77 or 90 (Reapproved 1994) (incorporated by reference as specified in &sect; 63.14).
Hi = Net heat of combustion of sample component i, kcal/g-mole at 25 'C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95. (incorporated by reference as specified in &sect; 63.14) if published values are not available or cannot be calculated.
n = Number of sample components.
n = Number of sample components.
(7) (i) Steam-assisted and nonassisted flares shall be designed for and operated with an exit velocity less than 18.3 m/sec (60 ft/sec), except as provided in paragraphs (b)(7)(ii) and (b)(7)(iii) of this section. The actual exit velocity of a flare shall be determined by dividing by the volumetric flow rate of gas being combusted (in units of emission standard temperature and pressure), as determined by Test Method 2, 2A, 2C, or 2D in appendix A to 40 CFR part 60 of this chapter, as appropriate, by the unobstructed (free) cross-sectional area of the flare tip.(ii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, equal to or greater than 18.3 m/sec (60 ft/sec) but less than 122 m/sec (400 ft/sec), are allowed if the net heating value of the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf).(iii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, less than the velocity Vmax, as determined by the method specified in this paragraph, but less than 122 m/sec (400 ft/sec) are allowed. The maximum permitted velocity, Vmax, for flares complying with this paragraph shall be determined by the following equation: Log 1 o(Vmax)=(HT  
(7)       (i) Steam-assisted and nonassisted flares shall be designed for and operated with an exit velocity less than 18.3 m/sec (60 ft/sec), except as provided in paragraphs (b)(7)(ii) and (b)(7)(iii) of this section. The actual exit velocity of a flare shall be determined by dividing by the volumetric flow rate of gas being combusted (in units of emission standard temperature and pressure), as determined by Test Method 2, 2A, 2C, or 2D in appendix A to 40 CFR part 60 of this chapter, as appropriate, by the unobstructed (free) cross-sectional area of the flare tip.
+28.8)/31.7 Where: Vmx = Maximum permitted velocity, m/sec.28.8 = Constant.31.7 = Constant.HT = The net heating value as determined in paragraph (b)(6) of this section.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-40 of 45 APPENDIX NESHAP SUBPART A General Provisions (8) Air-assisted flares shall be designed and operated with an exit velocity less than the velocity Vma,. The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation: Vmx = 8.71 + 0.708(HT)Where: Vmax = Maximum permitted velocity, m/sec.8.71 = Constant.0.708 = Constant.HT = The net heating value as determined in paragraph (b)(6)(ii) of this section.&sect; 63.12 State authority and delegations.(a) The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from (1) Adopting and enforcing any standard, limitation, prohibition, or other regulation applicable to an affected source subject to the requirements of this part, provided that such standard, limitation, prohibition, or regulation is not less stringent than any requirement applicable to such source established under this part;(2) Requiring the owner or operator of an affected source to obtain permits, licenses, or approvals prior to initiating construction, reconstruction, modification, or operation of such source; or (3) Requiring emission reductions in excess of those specified in subpart D of this part as a condition for granting the extension of compliance authorized by section 112(i)(5) of the Act.(b) (1) Section 112(1) of the Act directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards and other requirements pursuant to section 112 for stationary sources located in that State.Because of the unique nature of radioactive material, delegation of authority to implement and enforce standards that control radionuclides may require separate approval.(2) Subpart E of this part establishes procedures consistent with section 112(1) for the approval of State rules or programs to implement and enforce applicable Federal rules promulgated under the authority of section 112. Subpart E also establishes procedures for the review and withdrawal of section 112 implementation and enforcement authorities granted through a section 112(1) approval.(c) All information required to be submitted to the EPA under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act, provided that each specific delegation may exempt sources from a certain Federal or State reporting requirement.
(ii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, equal to or greater than 18.3 m/sec (60 ft/sec) but less than 122 m/sec (400 ft/sec), are allowed if the net heating value of the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf).
The Administrator may permit all or some of the information to be submitted to the appropriate State agency only, instead of to the EPA and the State agency.&sect; 63.13 Addresses of State air pollution control agencies and EPA Regional Offices.(a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted to the appropriate Regional Office of the U.S. Environmental Protection Agency indicated as follows: EPA Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee).
(iii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, less than the velocity Vmax, as determined by the method specified in this paragraph, but less than 122 m/sec (400 ft/sec) are allowed. The maximum permitted velocity, Vmax, for flares complying with this paragraph shall be determined by the following equation:
Director;Air, Pesticides and Toxics Management Division; Atlanta Federal Center, 61 Forsyth Street; Atlanta, GA 30303-3104.(b) All information required to be submitted to the Administrator under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act. The owner or operator of an affected source may contact the appropriate EPA Regional Office for the mailing addresses for those States whose delegation requests have been approved.(c) If any State requires a submittal that contains all the information required in an application, notification, request, report, statement, or other communication required in this part, an owner or operator may send the appropriate Regional Office of the EPA a copy of that submittal to satisfy the requirements of this part for that communication.
Log1o(Vmax)=(HT +28.8)/31.7 Where:
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-41 of 45 APPENDIX NESHAP SUBPART A General Provisions
Vmx = Maximum permitted velocity, m/sec.
&sect; 63.14 Incorporations by reference.(a) The materials listed in this section are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are incorporated as they exist on the date of the approval, and notice of any change in these materials will be published in the Federal Register.
28.8 = Constant.
The materials are available for purchase at the corresponding addresses noted below, and all are available for inspection at the Office of the Federal Register, 800 North Capitol Street, NW., suite 700, Washington, DC, at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC, and at the EPA Library (MD-35), U.S. EPA, Research Triangle Park, North Carolina.(b) The following materials are available for purchase from at least one of the following addresses:
31.7 = Constant.
American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106.(1) ASTM D523-89, Standard Test Method for Specular Gloss, IBR approved for &sect; 63.782.(2) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 306, Sections 7.1.1 and 7.4.2.(3) ASTM D1331-89, Standard Test Methods for Surface and Interfacial Tension of Solutions of Surface Active Agents, IBR approved for Appendix A: Method 306B, Sections 6.2, 11.1, and 12.2.2.(4) ASTM D1475-90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for &sect; 63.788, Appendix A.(5) ASTM D1946-77, 90, 94, Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for &sect; 63.11(b)(6).
HT = The net heating value as determined in paragraph (b)(6) of this section.
(6) ASTM D2369-93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for &sect; 63.788, Appendix A.(7) ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for &sect; 63.11(b)(6).
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-40 of 45
(8) ASTM D2879-83, 96, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for &sect; 63.111 of Subpart G.(9) ASTM D3257-93, Standard Test Methods for Aromatics in Mineral Spirits by Gas Chromatography, IBR approved for &sect; 63.786(b).
 
(10) ASTM 3695-88, Standard Test Method for Volatile Alcohols in Water by Direct Aqueous-Injection Gas Chromatography, IBR approved for &sect; 63.365(e)(1) of Subpart 0.(11) ASTM D3792-91, Standard Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for &sect; 63.788, Appendix A.(12) ASTM D3912-80, Standard Test Method for Chemical Resistance of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.(13) ASTM D4017-90, 96a, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for &sect; 63.788, Appendix A.(14) ASTM D4082-89, Standard Test Method for Effects of Gamma Radiation on Coatings for Use in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.(15) ASTM D4256-89, 94, Standard Test Method for Determination of the Decontaminability of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.(16) ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for &sect; 63.11(b)(6).
APPENDIX NESHAP SUBPART A General Provisions (8) Air-assisted flares shall be designed and operated with an exit velocity less than the velocity Vma,. The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation:
Vmx = 8.71 + 0.708(HT)
Where:
Vmax = Maximum permitted velocity, m/sec.
8.71 = Constant.
0.708 = Constant.
HT = The net heating value as determined in paragraph (b)(6)(ii) of this section.
&sect; 63.12 State authority and delegations.
(a) The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from (1) Adopting and enforcing any standard, limitation, prohibition, or other regulation applicable to an affected source subject to the requirements of this part, provided that such standard, limitation, prohibition, or regulation is not less stringent than any requirement applicable to such source established under this part; (2) Requiring the owner or operator of an affected source to obtain permits, licenses, or approvals prior to initiating construction, reconstruction, modification, or operation of such source; or (3) Requiring emission reductions in excess of those specified in subpart D of this part as a condition for granting the extension of compliance authorized by section 112(i)(5) of the Act.
(b)       (1) Section 112(1) of the Act directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards and other requirements pursuant to section 112 for stationary sources located in that State.
Because of the unique nature of radioactive material, delegation of authority to implement and enforce standards that control radionuclides may require separate approval.
(2) Subpart E of this part establishes procedures consistent with section 112(1) for the approval of State rules or programs to implement and enforce applicable Federal rules promulgated under the authority of section 112. Subpart E also establishes procedures for the review and withdrawal of section 112 implementation and enforcement authorities granted through a section 112(1) approval.
(c) All information required to be submitted to the EPA under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act, provided that each specific delegation may exempt sources from a certain Federal or State reporting requirement. The Administrator may permit all or some of the information to be submitted to the appropriate State agency only, instead of to the EPA and the State agency.
&sect; 63.13 Addresses of State air pollution control agencies and EPA Regional Offices.
(a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted to the appropriate Regional Office of the U.S. Environmental Protection Agency indicated as follows:
EPA Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee). Director; Air, Pesticides and Toxics Management Division; Atlanta Federal Center, 61 Forsyth Street; Atlanta, GA 30303-3104.
(b) All information required to be submitted to the Administrator under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act. The owner or operator of an affected source may contact the appropriate EPA Regional Office for the mailing addresses for those States whose delegation requests have been approved.
(c) If any State requires a submittal that contains all the information required in an application, notification, request, report, statement, or other communication required in this part, an owner or operator may send the appropriate Regional Office of the EPA a copy of that submittal to satisfy the requirements of this part for that communication.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPA-41 of 45
 
APPENDIX NESHAP SUBPART A General Provisions
&sect; 63.14 Incorporations by reference.
(a) The materials listed in this section are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are incorporated as they exist on the date of the approval, and notice of any change in these materials will be published in the Federal Register. The materials are available for purchase at the corresponding addresses noted below, and all are available for inspection at the Office of the Federal Register, 800 North Capitol Street, NW., suite 700, Washington, DC, at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC, and at the EPA Library (MD-35), U.S. EPA, Research Triangle Park, North Carolina.
(b) The following materials are available for purchase from at least one of the following addresses: American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106.
(1) ASTM D523-89, Standard Test Method for Specular Gloss, IBR approved for &sect; 63.782.
(2) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 306, Sections 7.1.1 and 7.4.2.
(3) ASTM D1331-89, Standard Test Methods for Surface and Interfacial Tension of Solutions of Surface Active Agents, IBR approved for Appendix A: Method 306B, Sections 6.2, 11.1, and 12.2.2.
(4) ASTM D1475-90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for &sect; 63.788, Appendix A.
(5) ASTM D1946-77, 90, 94, Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for &sect; 63.11(b)(6).
(6) ASTM D2369-93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for &sect; 63.788, Appendix A.
(7) ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for &sect; 63.11(b)(6).
(8) ASTM D2879-83, 96, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for &sect; 63.111 of Subpart G.
(9) ASTM D3257-93, Standard Test Methods for Aromatics in Mineral Spirits by Gas Chromatography, IBR approved for &sect; 63.786(b).
(10) ASTM 3695-88, Standard Test Method for Volatile Alcohols in Water by Direct Aqueous-Injection Gas Chromatography, IBR approved for &sect; 63.365(e)(1) of Subpart 0.
(11) ASTM D3792-91, Standard Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for &sect; 63.788, Appendix A.
(12) ASTM D3912-80, Standard Test Method for Chemical Resistance of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.
(13) ASTM D4017-90, 96a, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for &sect; 63.788, Appendix A.
(14) ASTM D4082-89, Standard Test Method for Effects of Gamma Radiation on Coatings for Use in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.
(15) ASTM D4256-89, 94, Standard Test Method for Determination of the Decontaminability of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for &sect; 63.782.
(16) ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for &sect; 63.11(b)(6).
(17) ASTM E180-93, Standard Practice for Determining the Precision of ASTM Methods for Analysis and Testing of Industrial Chemicals, IBR approved for &sect; 63.786(b).
(17) ASTM E180-93, Standard Practice for Determining the Precision of ASTM Methods for Analysis and Testing of Industrial Chemicals, IBR approved for &sect; 63.786(b).
(18) ASTM E260-91, 96, General Practice for Packed Column Gas Chromatography, IBR approved for&sect;&sect; 63.750(b)(2) and 63.786(b)(5).
(18) ASTM E260-91, 96, General Practice for Packed Column Gas Chromatography, IBR approved for
(19) Reserved (20) Reserved (21) ASTM D2099-00, Standard Test Method for Dynamic Water Resistance of Shoe Upper Leather by the Maeser Water Penetration Tester, IBR approved for &sect; 63.5350.(24) ASTM D2697-86 (Reapproved 1998), "Standard Test Method for Volume Nonvolatile Matter in Clear or Pigmented Coatings," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1), 63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1), 63.4941(b)(1), and 63.5160(c).
&sect;&sect; 63.750(b)(2) and 63.786(b)(5).
(25) ASTM D6093-97 (Reapproved 2003), "Standard Test Method for Percent Volume Nonvolatile Matter in Clear or Pigmented Coatings Using a Helium Gas Pycnometer," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1), 63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1), 63.4941(b)(1), and 63.5160(c).
(19) Reserved (20) Reserved (21) ASTM D2099-00, Standard Test Method for Dynamic Water Resistance of Shoe Upper Leather by the Maeser Water Penetration Tester, IBR approved for &sect; 63.5350.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-42 of 45 APPENDIX NESHAP SUBPART A General Provisions (26) ASTM D1475-98 (Reapproved 2003), "Standard Test Method for Density of Liquid Coatings, Inks, and Related Products," IBR approved for Sec. Sec. 63.3151(b), 63.3941(b)(4), 63.3941(c), 63.3951(c), 63.4141(b)(3), 63.4141(c), and 63.455 1(c).(27) ASTM D 6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide and Oxygen concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process heaters Using Portable Analyzers, IBR approved for Sec. 63.9307(c)(2).
(24) ASTM D2697-86 (Reapproved 1998), "Standard Test Method for Volume Nonvolatile Matter in Clear or Pigmented Coatings," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1), 63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1),
63.4941(b)(1), and 63.5160(c).
(25) ASTM D6093-97 (Reapproved 2003), "Standard Test Method for Percent Volume Nonvolatile Matter in Clear or Pigmented Coatings Using a Helium Gas Pycnometer," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1),
63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1), 63.4941(b)(1), and 63.5160(c).
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPA-42 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (26) ASTM D1475-98 (Reapproved 2003), "Standard Test Method for Density of Liquid Coatings, Inks, and Related Products," IBR approved for Sec. Sec. 63.3151(b), 63.3941(b)(4), 63.3941(c), 63.3951(c), 63.4141(b)(3),
63.4141(c), and 63.455 1(c).
(27) ASTM D 6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide and Oxygen concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process heaters Using Portable Analyzers, IBR approved for Sec. 63.9307(c)(2).
(28) [Reserved]
(28) [Reserved]
(29) ASTM D6420-99, Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for &sect;&sect; 63.5799 and 63.5850.(30) ASTM E 515-95 (Reapproved 2000), Standard Test Method for Leaks Using Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2).
(29) ASTM D6420-99, Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for &sect;&sect; 63.5799 and 63.5850.
(31) ASTM D5291-02, Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants, IBR approved for Sec. 63.3981, appendix A.(32) ASTM D5965-02, "Standard Test Methods for Specific Gravity of Coating Powders," IBR approved for Sec.Sec. 63.3151(b) and 63.3951(c).
(30) ASTM E 515-95 (Reapproved 2000), Standard Test Method for Leaks Using Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2).
(33) ASTM D6053-00, Standard Test Method for Determination of Volatile Organic Compound (VOC) Content of Electrical Insulating Varnishes, IBR approved for Sec. 63.3981, appendix A.(34) E145-94 (Reapproved 2001), Standard Specification for Gravity-Convection and Forced-Ventilation Ovens, IBR approved for Sec. 63.4581, Appendix A.(35) [Reserved]
(31) ASTM D5291-02, Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants, IBR approved for Sec. 63.3981, appendix A.
(32) ASTM D5965-02, "Standard Test Methods for Specific Gravity of Coating Powders," IBR approved for Sec.
Sec. 63.3151(b) and 63.3951(c).
(33) ASTM D6053-00, Standard Test Method for Determination of Volatile Organic Compound (VOC) Content of Electrical Insulating Varnishes, IBR approved for Sec. 63.3981, appendix A.
(34) E145-94 (Reapproved 2001), Standard Specification for Gravity-Convection and Forced-Ventilation Ovens, IBR approved for Sec. 63.4581, Appendix A.
(35) [Reserved]
(36) ASTM D5066-91 (Reapproved 2001), "Standard Test Method for Determination of the Transfer Efficiency Under Production Conditions for Spray Application of Automotive Paints-Weight Basis," IBR approved for Sec. 63.3161(g).
(36) ASTM D5066-91 (Reapproved 2001), "Standard Test Method for Determination of the Transfer Efficiency Under Production Conditions for Spray Application of Automotive Paints-Weight Basis," IBR approved for Sec. 63.3161(g).
(37) ASTM D5087-02, "Standard Test Method for Determining Amount of Volatile Organic Compound (VOC)Released from Solventborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. Sec. 63.3165(e) and 63.3176, appendix A.(38) ASTM D6266-00a, "Test Method for Determining the Amount of Volatile Organic Compound (VOC)Released from Waterborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. 63.3165(e).(c) The materials listed below are available for purchase from the American Petroleum Institute (API), 1220 L Street, NW., Washington, DC 20005.(1) API Publication 2517, Evaporative Loss from External Floating-Roof Tanks, Third Edition, February 1989, IBR approved for &sect; 63.111 of subpart G of this part.(2) API Publication 2518, Evaporative Loss from Fixed-roof Tanks, Second Edition, October 1991, IBR approved for &sect; 63.150(g)(3)(i)(C) of subpart G of this part.(3) API Manual of Petroleum Measurement Specifications (MPMS) Chapter 19.2, Evaporative Loss From Floating-Roof Tanks (formerly API Publications 2517 and 2519), First Edition, April 1997, IBR approved for &sect; 63.1251 of subpart GGG of this part.(d) State and Local Requirements.
(37) ASTM D5087-02, "Standard Test Method for Determining Amount of Volatile Organic Compound (VOC)
The materials listed below are available at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC.(1) California Regulatory Requirements Applicable to the Air Toxics Program, January 5, 1999, IBR approved for&sect; 63.99(a)(5)(ii) of subpart E of this part.(2) New Jersey's Toxic Catastrophe Prevention Act Program, (July 20, 1998), Incorporation By Reference approved for &sect; 63.99 (a)(30)(i) of subpart E of this part.(3) (i) Letter of June 7, 1999 to the U.S. Environmental Protection Agency Region 3 from the Delaware Department of Natural Resources and Environmental Control requesting formal full delegation to take over primary responsibility for implementation and enforcement of the Chemical Accident Prevention Program under Section 112(r) of the Clean Air Act Amendments of 1990.(ii) Delaware Department of Natural Resources and Environmental Control, Division of Air and Waste Management, Accidental Release Prevention Regulation, sections 1 through 5 and sections 7 through 14, effective January 11, 1999, IBR approved for &sect; 63.99(a)(8)(i) of subpart E of this part.(iii) State of Delaware Regulations Governing the Control of Air Pollution (October 2000), IBR approved for &sect; 63.99(a)(8)(ii)-(v) of subpart E of this part.(e) The materials listed below are available for purchase from the National Institute of Standards and Technology, Springfield, VA 22161, (800) 553-6847.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-43 of 45 APPENDIX NESHAP SUBPART A General Provisions (1) Handbook 44, Specificiations, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices 1998, IBR approved for &sect; 63.1303(e)(3).
Released from Solventborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. Sec. 63.3165(e) and 63.3176, appendix A.
(2) [Reserved](f) The following material is available from the National Council of the Paper Industry for Air and Stream Improvement, Inc.(NCASI), P. 0. Box 133318, Research Triangle Park, NC 27709-3318 or at http://www.ncasi.org:
(38) ASTM D6266-00a, "Test Method for Determining the Amount of Volatile Organic Compound (VOC)
NCASI Method DI/MEOH-94.02, Methanol in Process Liquids GC/FID (Gas Chromatography/Flame Ionization Detection), August 1998, Methods Manual, NCASI, Research Triangle Park, NC, IBR approved for &sect; 63.457(c)(3)(ii) of subpart S of this part.(g) The materials listed below are available for purchase from AOAC International, Customer Services, Suite 400, 2200 Wilson Boulevard, Arlington, Virginia, 22201-3301, Telephone (703) 522-3032, Fax (703) 522-5468.(1) AOAC Official Method 978.01 Phosphorus (Total) in Fertilizers, Automated Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
Released from Waterborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. 63.3165(e).
(c) The materials listed below are available for purchase from the American Petroleum Institute (API), 1220 L Street, NW.,
Washington, DC 20005.
(1) API Publication 2517, Evaporative Loss from External Floating-Roof Tanks, Third Edition, February 1989, IBR approved for &sect; 63.111 of subpart G of this part.
(2) API Publication 2518, Evaporative Loss from Fixed-roof Tanks, Second Edition, October 1991, IBR approved for &sect; 63.150(g)(3)(i)(C) of subpart G of this part.
(3) API Manual of Petroleum Measurement Specifications (MPMS) Chapter 19.2, Evaporative Loss From Floating-Roof Tanks (formerly API Publications 2517 and 2519), First Edition, April 1997, IBR approved for &sect; 63.1251 of subpart GGG of this part.
(d) State and Local Requirements. The materials listed below are available at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC.
(1) California Regulatory Requirements Applicable to the Air Toxics Program,January 5, 1999, IBR approved for
&sect; 63.99(a)(5)(ii) of subpart E of this part.
(2) New Jersey's Toxic CatastrophePrevention Act Program, (July 20, 1998), Incorporation By Reference approved for &sect; 63.99 (a)(30)(i) of subpart E of this part.
(3)       (i) Letter of June 7, 1999 to the U.S. Environmental Protection Agency Region 3 from the Delaware Department of Natural Resources and Environmental Control requesting formal full delegation to take over primary responsibility for implementation and enforcement of the Chemical Accident Prevention Program under Section 112(r) of the Clean Air Act Amendments of 1990.
(ii) Delaware Department of Natural Resources and Environmental Control, Division of Air and Waste Management, Accidental Release Prevention Regulation, sections 1 through 5 and sections 7 through 14, effective January 11, 1999, IBR approved for &sect; 63.99(a)(8)(i) of subpart E of this part.
(iii) State of Delaware Regulations Governing the Control of Air Pollution (October 2000), IBR approved for &sect; 63.99(a)(8)(ii)-(v) of subpart E of this part.
(e) The materials listed below are available for purchase from the National Institute of Standards and Technology, Springfield, VA 22161, (800) 553-6847.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPA-43 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (1) Handbook 44, Specificiations, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices 1998, IBR approved for &sect; 63.1303(e)(3).
(2) [Reserved]
(f) The following material is available from the National Council of the Paper Industry for Air and Stream Improvement, Inc.
(NCASI), P. 0. Box 133318, Research Triangle Park, NC 27709-3318 or at http://www.ncasi.org: NCASI Method DI/MEOH-94.02, Methanol in Process Liquids GC/FID (Gas Chromatography/Flame Ionization Detection), August 1998, Methods Manual, NCASI, Research Triangle Park, NC, IBR approved for &sect; 63.457(c)(3)(ii) of subpart S of this part.
(g) The materials listed below are available for purchase from AOAC International, Customer Services, Suite 400, 2200 Wilson Boulevard, Arlington, Virginia, 22201-3301, Telephone (703) 522-3032, Fax (703) 522-5468.
(1) AOAC Official Method 978.01 Phosphorus (Total) in Fertilizers, Automated Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(2) AOAC Official Method 969.02 Phosphorus (Total) in Fertilizers, Alkalimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(2) AOAC Official Method 969.02 Phosphorus (Total) in Fertilizers, Alkalimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(3) AOAC Official Method 962.02 Phosphorus (Total) in Fertilizers, Gravimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(3) AOAC Official Method 962.02 Phosphorus (Total) in Fertilizers, Gravimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(4) AOAC Official Method 957.02 Phosphorus (Total) in Fertilizers, Preparation of Sample Solution, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(4) AOAC Official Method 957.02 Phosphorus (Total) in Fertilizers, Preparation of Sample Solution, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(5) AOAC Official Method 929.01 Sampling of Solid Fertilizers, Sixteenth edition, 1995, IBR approved for&sect; 63.626(d)(3)(vi).
(5) AOAC Official Method 929.01 Sampling of Solid Fertilizers, Sixteenth edition, 1995, IBR approved for
(6) AOAC Official Method 929.02 Preparation of Fertilizer Sample, Sixteenth edition, 1995, IBR approved for&sect; 63.626(d)(3)(vi).
&sect; 63.626(d)(3)(vi).
(7) AOAC Official Method 958.01 Phosphorus (Total) in Fertilizers, Spectrophotometric Molybdovanadophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).(h) The materials listed below are available for purchase from The Association of Florida Phosphate Chemists, P.O. Box 1645, Bartow, Florida, 33830, Book of Methods Used and Adopted By The Association of Florida Phosphate Chemists, Seventh Edition 1991, IBR.(1) Section IX, Methods of Analysis for Phosphate Rock, No. 1 Preparation of Sample, IBR approved for&sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(6) AOAC Official Method 929.02 Preparation of Fertilizer Sample, Sixteenth edition, 1995, IBR approved for
(2) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus  
&sect; 63.626(d)(3)(vi).
-- P205 or Ca3(PO4)2, Method A-Volumetric Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(7) AOAC Official Method 958.01 Phosphorus (Total) in Fertilizers, Spectrophotometric Molybdovanadophosphate Method, Sixteenth edition, 1995, IBR approved for &sect; 63.626(d)(3)(vi).
(3) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method B --Gravimetric Quimociac Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(h) The materials listed below are available for purchase from The Association of Florida Phosphate Chemists, P.O. Box 1645, Bartow, Florida, 33830, Book of Methods Used and Adopted By The Association of Florida Phosphate Chemists, Seventh Edition 1991, IBR.
(4) Section IX, Methods of Analysis For Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method C --Spectrophotometric Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(1) Section IX, Methods of Analysis for Phosphate Rock, No. 1 Preparation of Sample, IBR approved for
(5) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method A -- Volumetric Method, IBR approved for &sect; 63.606(c)(3)(ii),&sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).
&sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(6) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method B -- Gravimetric Quimociac Method, IBR approved for&sect; 63.606(c)(3)(ii), &sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).
(2) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus -- P205 or Ca3(PO4)2, Method A-Volumetric Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(7) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method C -- Spectrophotometric Method, IBR approved for &sect; 63.606(c)(3)(ii),&sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).(i) The following materials are available for purchase from at least one of the following addresses:
(3) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method B --
ASME International, Orders/Inquiries, P.O. Box 2900, Fairfield, NJ 07007-2900; or Global Engineering Documents, Sales Department, 15 Inverness Way East, Englewood, CO 80112.(1) ASME standard number QHO-1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii).
Gravimetric Quimociac Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
(2) ASME standard number QHO- 1 a- 1996 Addenda to QHO- 1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii).
(4) Section IX, Methods of Analysis For Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method C --
(3) ANSI/ASME PTC 19.10-1981, "Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus]," IBR approved for Sec. Sec. 63.865(b), 63.3166(a)(3), 63.3360(e)(1)(iii), 63.3545(a)(3), 63.3555(a)(3), 63.4166(a)(3), 63.4362(a)(3), 63.4766(a)(3), 63.4965(a)(3), 63.5160(d)(1)(iii), 63.9307(c)(2), and 63.9323(a)(3).
Spectrophotometric Method, IBR approved for &sect; 63.606(c)(3)(ii) and &sect; 63.626(c)(3)(ii).
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-44 of 45 APPENDIX NESHAP SUBPART A General Provisions (j) The following material is available for purchase from: British Standards Institute, 389 Chiswick High Road, London W4 4AL, United Kingdom.(1) BS EN 1593:1999, Non-destructive Testing: Leak Testing--Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2).
(5) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method A -- Volumetric Method, IBR approved for &sect; 63.606(c)(3)(ii),
(2) [Reserved](k) The following material may be obtained from U.S. EPA, Office of Solid Waste (5305W), 1200 Pennsylvania Avenue, NW., Washington, DC 20460: (1) Method 9071B, "n-Hexane Extractable Material(HEM) for Sludge, Sediment, and Solid Samples," (Revision 2, April 1998) as published in EPA Publication SW-846: "Test Methods for Evaluating Solid Waste, Physical/Chemical Methods." The incorporation by reference of Method 9071B is approved for Section 63.7824(e) of Subpart FFFFF of this part.&sect; 63.15 Availability of information and confidentiality.(a) Availability of information.
&sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).
(1) With the exception of information protected through part 2 of this chapter, all reports, records, and other information collected by the Administrator under this part are available to the public. In addition, a copy of each permit application, compliance plan (including the schedule of compliance), notification of compliance status, excess emissions and continuous monitoring systems performance report, and title V permit is available to the public, consistent with protections recognized in section 503(e) of the Act.(2) The availability to the public of information provided to or otherwise obtained by the Administrator under this part shall be governed by part 2 of this chapter.(b) Confidentiality.
(6) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method B -- Gravimetric Quimociac Method, IBR approved for
(1) If an owner or operator is required to submit information entitled to protection from disclosure under section 114(c) of the Act, the owner or operator may submit such information separately.
&sect; 63.606(c)(3)(ii), &sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).
The requirements of section 114(c) shall apply to such information.
(7) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method C -- Spectrophotometric Method, IBR approved for &sect; 63.606(c)(3)(ii),
&sect; 63.626(c)(3)(ii), and &sect; 63.626(d)(3)(v).
(i) The following materials are available for purchase from at least one of the following addresses: ASME International, Orders/Inquiries, P.O. Box 2900, Fairfield, NJ 07007-2900; or Global Engineering Documents, Sales Department, 15 Inverness Way East, Englewood, CO 80112.
(1) ASME standard number QHO-1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii).
(2) ASME standard number QHO- 1a- 1996 Addenda to QHO- 1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii).
(3) ANSI/ASME PTC 19.10-1981, "Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus]," IBR approved for Sec. Sec. 63.865(b), 63.3166(a)(3), 63.3360(e)(1)(iii), 63.3545(a)(3), 63.3555(a)(3), 63.4166(a)(3),
63.4362(a)(3), 63.4766(a)(3), 63.4965(a)(3), 63.5160(d)(1)(iii), 63.9307(c)(2), and 63.9323(a)(3).
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                             Title V Permit Renewal Page NESHAPA-44 of 45
 
APPENDIX NESHAP SUBPART A General Provisions (j) The following material is available for purchase from: British Standards Institute, 389 Chiswick High Road, London W4 4AL, United Kingdom.
(1) BS EN 1593:1999, Non-destructive Testing: Leak Testing--Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2).
(2) [Reserved]
(k) The following material may be obtained from U.S. EPA, Office of Solid Waste (5305W), 1200 Pennsylvania Avenue, NW., Washington, DC 20460:
(1) Method 9071B, "n-Hexane Extractable Material(HEM) for Sludge, Sediment, and Solid Samples," (Revision 2, April 1998) as published in EPA Publication SW-846: "Test Methods for Evaluating Solid Waste, Physical/Chemical Methods." The incorporation by reference of Method 9071B is approved for Section 63.7824(e) of Subpart FFFFF of this part.
&sect; 63.15 Availability of information and confidentiality.
(a) Availability of information.
(1) With the exception of information protected through part 2 of this chapter, all reports, records, and other information collected by the Administrator under this part are available to the public. In addition, a copy of each permit application, compliance plan (including the schedule of compliance), notification of compliance status, excess emissions and continuous monitoring systems performance report, and title V permit is available to the public, consistent with protections recognized in section 503(e) of the Act.
(2) The availability to the public of information provided to or otherwise obtained by the Administrator under this part shall be governed by part 2 of this chapter.
(b) Confidentiality.
(1) If an owner or operator is required to submit information entitled to protection from disclosure under section 114(c) of the Act, the owner or operator may submit such information separately. The requirements of section 114(c) shall apply to such information.
(2) The contents of a title V permit shall not be entitled to protection under section 114(c) of the Act; however, information submitted as part of an application for a title V permit may be entitled to protection from disclosure.
(2) The contents of a title V permit shall not be entitled to protection under section 114(c) of the Act; however, information submitted as part of an application for a title V permit may be entitled to protection from disclosure.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPA-45 of 45 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Subpart ZZZZ-National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Source: 69 FR 33506, June 15, 2004, unless otherwise noted.What This Subpart Covers&sect; 63.6580 What is the purpose of subpart ZZZZ?Subpart ZZZZ establishes national emission limitations and operating limitations for hazardous air pollutants (HAP) emitted from stationary reciprocating internal combustion engines (RICE) located at major and area sources of HAP emissions.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPA-45 of 45
This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and operating limitations.
 
[73 FR 3603, Jan. 18, 2008]&sect; 63.6585 Am I subject to this subpart?You are subject to this subpart if you own or operate a stationary RICE at a major or area source of HAP emissions, except if the stationary RICE is being tested at a stationary RICE test cell/stand.(a) A stationary RICE is any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition.(b) A major source of HAP emissions is a plant site that emits or has the potential to emit any single HAP at a rate of 10 tons (9.07 megagrams) or more per year or any combination of HAP at a rate of 25 tons (22.68 megagrams) or more per year, except that for oil and gas production facilities, a major source of HAP emissions is determined for each surface site.(c) An area source of HAP emissions is a source that is not a major source.(d) If you are an owner or operator of an area source subject to this subpart, your status as an entity subject to a standard or other requirements under this subpart does not subject you to the obligation to obtain a permit under 40 CFR part 70 or 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart as applicable.(e) If you are an owner or operator of a stationary RICE used for national security purposes, you may be eligible to request an exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C.[69 FR 33506, June 15, 2004, as amended at 73 FR 3603, Jan. 18, 2008]&sect; 63.6590 What parts of my plant does this subpart cover?This subpart applies to each affected source.(a) Affected source. An affected source is any existing, new, or reconstructed stationary RICE located at a major or area source of HAP emissions, excluding stationary RICE being tested at a stationary RICE test cell/stand.
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Subpart ZZZZ-National Emissions Standardsfor HazardousAir Pollutantsfor Stationary ReciprocatingInternal Combustion Engines Source: 69 FR 33506, June 15, 2004, unless otherwise noted.
(1) Existing stationary RICE.(i) For stationary RICE with a site rating of more than 500 brake horsepower (HP) located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before December 19, 2002.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-1 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (ii) For stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006.(iii) For stationary RICE located at an area source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006.(iv) A change in ownership of an existing stationary RICE does not make that stationary RICE a new or reconstructed stationary RICE.(2) New stationary RICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after December 19, 2002.(ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006.(iii) A stationary RICE located at an area source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006.(3) Reconstructed stationary RICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after December 19, 2002.(ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after June 12, 2006.(iii) A stationary RICE located at an area source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after June 12, 2006.(b) Stationary RICE subject to limited requirements.  
What This Subpart Covers
(1) An affected source which meets either of the criteria in paragraph (b)(1)(i) through (ii) of this section does not have to meet the requirements of this subpart and of subpart A of this part except for the initial notification requirements of &sect;63.6645(h).(i) The stationary RICE is a new or reconstructed emergency stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions; or (ii) The stationary RICE is a new or reconstructed limited use stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions.
&sect; 63.6580 What is the purpose of subpartZZZZ?
(2) A new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis must meet the initial notification requirements of &sect;63.6645(h) and the requirements of &sect;&sect;63.6625(c), 63.6650(g), and 63.6655(c).
Subpart ZZZZ establishes national emission limitations and operating limitations for hazardous air pollutants (HAP) emitted from stationary reciprocating internal combustion engines (RICE) located at major and area sources of HAP emissions. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and operating limitations.
These stationary RICE do not have to meet the emission limitations and operating limitations of this subpart.(3) A stationary RICE which is an existing spark ignition 4 stroke rich burn (4SRB) stationary RICE located at an area source, an existing spark ignition 4SRB stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source, an existing spark ignition 2 stroke lean burn (2SLB) stationary RICE, an existing spark ignition 4 stroke lean burn (4SLB) stationary RICE, an existing compression ignition (CI) stationary RICE, an existing emergency stationary RICE, an existing limited use stationary RICE, or an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, does not have to meet the requirements of this subpart and of subpart A of this part. No initial notification is necessary.(c) Stationary RICE subject to Regulations under 40 CFR Part 60. An affected source that is a new or reconstructed stationary RICE located at an area source, or is a new or reconstructed stationary RICE located at a major source of HAP emissions and is a spark ignition 2 stroke lean burn (2SLB) stationary RICE with a site rating of less than 500 brake HP, a spark ignition 4 stroke lean burn (4SLB) stationary RICE with a site rating of less than 250 brake HP, or a 4 stroke rich burn (4SRB) stationary RICE with a site rating of less than or equal to 500 brake HP, a stationary RICE with a site rating of less than or equal to 500 brake HP which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-2 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines on an annual basis, an emergency or limited use stationary RICE with a site rating of less than or equal to 500 brake HP, or a compression ignition (CI) stationary RICE with a site rating of less than or equal to 500 brake HP, must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines. No further requirements apply for such engines under this part.[69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008]&sect; 63.6595 When do I have to comply with this subpart?(a) Affected Sources. (1) If you have an existing stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the applicable emission limitations and operating limitations no later than June 15, 2007.(2) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart no later than August 16, 2004.(3) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions after August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.(4) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008.(5) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.(6) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008.(7) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.(b) Area sources that become major sources. If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of HAP, the compliance dates in paragraphs (b)(1) and (2) of this section apply to you.(1) Any stationary RICE for which construction or reconstruction is commenced after the date when your area source becomes a major source of HAP must be in compliance with this subpart upon startup of your affected source.(2) Any stationary RICE for which construction or reconstruction is commenced before your area source becomes a major source of HAP must be in compliance with the provisions of this subpart that are applicable to RICE located at major sources within 3 years after your area source becomes a major source of HAP.(c) If you own or operate an affected source, you must meet the applicable notification requirements in &sect;63.6645 and in 40 CFR part 63, subpart A.[69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008]Emission and Operating Limitations
[73 FR 3603, Jan. 18, 2008]
&sect; 63.6600 What emission limitations and operating limitations must I meet if I own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions?
&sect; 63.6585 Am I subject to this subpart?
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-3 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you own or operate an existing, new, or reconstructed spark ignition 4SRB stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table la to this subpart and the operating limitations in Table lb to this subpart which apply to you.(b) If you own or operate a new or reconstructed 2SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, or a new or reconstructed CI stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you.(c) If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the emission limitations in Tables la and 2a to this subpart or operating limitations in Tables lb and 2b to this subpart: an existing 2SLB stationary RICE, an existing 4SLB stationary RICE, or an existing Cl stationary RICE; a stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis; an emergency stationary RICE; or a limited use stationary RICE.[73 FR 3605, Jan. 18, 2008]&sect; 63.6601 What emission limitations must I meet if I own or operate a 4SLB stationary RICE with a site rating of greater than or equal to 250 brake HP and less than 500 brake HP located at a major source of HAP emissions?
You are subject to this subpart if you own or operate a stationary RICE at a major or area source of HAP emissions, except if the stationary RICE is being tested at a stationary RICE test cell/stand.
If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at major source of HAP emissions manufactured on or after January 1, 2008, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you.[73 FR 3605, Jan. 18, 2008]General Compliance Requirements
(a) A stationary RICE is any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition.
&sect; 63.6605 What are my general requirements for complying with this subpart?(a) You must be in compliance with the emission limitations and operating limitations in this subpart that apply to you at all times, except during periods of startup, shutdown, and malfunction.(b) If you must comply with emission limitations and operating limitations, you must operate and maintain your stationary RICE, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during startup, shutdown, and malfunction.
(b) A major source of HAP emissions is a plant site that emits or has the potential to emit any single HAP at a rate of 10 tons (9.07 megagrams) or more per year or any combination of HAP at a rate of 25 tons (22.68 megagrams) or more per year, except that for oil and gas production facilities, a major source of HAP emissions is determined for each surface site.
(c) An area source of HAP emissions is a source that is not a major source.
(d) If you are an owner or operator of an area source subject to this subpart, your status as an entity subject to a standard or other requirements under this subpart does not subject you to the obligation to obtain a permit under 40 CFR part 70 or 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart as applicable.
(e) If you are an owner or operator of a stationary RICE used for national security purposes, you may be eligible to request an exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C.
[69 FR 33506, June 15, 2004, as amended at 73 FR 3603, Jan. 18, 2008]
&sect; 63.6590     What parts of my plant does this subpartcover?
This subpart applies to each affected source.
(a) Affected source. An affected source is any existing, new, or reconstructed stationary RICE located at a major or area source of HAP emissions, excluding stationary RICE being tested at a stationary RICE test cell/stand.
(1) Existing stationaryRICE.
(i) For stationary RICE with a site rating of more than 500 brake horsepower (HP) located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before December 19, 2002.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPZ-1 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (ii) For stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006.
(iii) For stationary RICE located at an area source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006.
(iv) A change in ownership of an existing stationary RICE does not make that stationary RICE a new or reconstructed stationary RICE.
(2) New stationaryRICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after December 19, 2002.
(ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006.
(iii) A stationary RICE located at an area source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006.
(3) Reconstructed stationaryRICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after December 19, 2002.
(ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after June 12, 2006.
(iii) A stationary RICE located at an area source of HAP emissions is reconstructed if you meet the definition of reconstruction in &sect;63.2 and reconstruction is commenced on or after June 12, 2006.
(b) Stationary RICE subject to limited requirements. (1) An affected source which meets either of the criteria in paragraph (b)(1)(i) through (ii) of this section does not have to meet the requirements of this subpart and of subpart A of this part except for the initial notification requirements of &sect;63.6645(h).
(i) The stationary RICE is a new or reconstructed emergency stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions; or (ii) The stationary RICE is a new or reconstructed limited use stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions.
(2) A new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis must meet the initial notification requirements of &sect;63.6645(h) and the requirements of &sect;&sect;63.6625(c), 63.6650(g), and 63.6655(c). These stationary RICE do not have to meet the emission limitations and operating limitations of this subpart.
(3) A stationary RICE which is an existing spark ignition 4 stroke rich burn (4SRB) stationary RICE located at an area source, an existing spark ignition 4SRB stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source, an existing spark ignition 2 stroke lean burn (2SLB) stationary RICE, an existing spark ignition 4 stroke lean burn (4SLB) stationary RICE, an existing compression ignition (CI) stationary RICE, an existing emergency stationary RICE, an existing limited use stationary RICE, or an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, does not have to meet the requirements of this subpart and of subpart A of this part. No initial notification is necessary.
(c) Stationary RICE subject to Regulations under 40 CFR Part 60. An affected source that is a new or reconstructed stationary RICE located at an area source, or is a new or reconstructed stationary RICE located at a major source of HAP emissions and is a spark ignition 2 stroke lean burn (2SLB) stationary RICE with a site rating of less than 500 brake HP, a spark ignition 4 stroke lean burn (4SLB) stationary RICE with a site rating of less than 250 brake HP, or a 4 stroke rich burn (4SRB) stationary RICE with a site rating of less than or equal to 500 brake HP, a stationary RICE with a site rating of less than or equal to 500 brake HP which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-2 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines on an annual basis, an emergency or limited use stationary RICE with a site rating of less than or equal to 500 brake HP, or a compression ignition (CI) stationary RICE with a site rating of less than or equal to 500 brake HP, must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines. No further requirements apply for such engines under this part.
[69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008]
&sect; 63.6595 When do I have to comply with this subpart?
(a) Affected Sources. (1) If you have an existing stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the applicable emission limitations and operating limitations no later than June 15, 2007.
(2) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart no later than August 16, 2004.
(3) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions after August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.
(4) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008.
(5) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.
(6) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008.
(7) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source.
(b) Area sources that become major sources. If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of HAP, the compliance dates in paragraphs (b)(1) and (2) of this section apply to you.
(1) Any stationary RICE for which construction or reconstruction is commenced after the date when your area source becomes a major source of HAP must be in compliance with this subpart upon startup of your affected source.
(2) Any stationary RICE for which construction or reconstruction is commenced before your area source becomes a major source of HAP must be in compliance with the provisions of this subpart that are applicable to RICE located at major sources within 3 years after your area source becomes a major source of HAP.
(c) If you own or operate an affected source, you must meet the applicable notification requirements in &sect;63.6645 and in 40 CFR part 63, subpart A.
[69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008]
Emission and OperatingLimitations
&sect; 63.6600 What emission limitations and operating limitations must I meet if I own or operate a stationaryRICE with a site rating of more than 500 brake HP located at a major source of HAP emissions?
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-3 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you own or operate an existing, new, or reconstructed spark ignition 4SRB stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table la to this subpart and the operating limitations in Table lb to this subpart which apply to you.
(b) If you own or operate a new or reconstructed 2SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, or a new or reconstructed CI stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you.
(c) If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the emission limitations in Tables la and 2a to this subpart or operating limitations in Tables lb and 2b to this subpart: an existing 2SLB stationary RICE, an existing 4SLB stationary RICE, or an existing Cl stationary RICE; a stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis; an emergency stationary RICE; or a limited use stationary RICE.
[73 FR 3605, Jan. 18, 2008]
&sect; 63.6601 What emission limitations must I meet if I own or operate a 4SLB stationaryRICE with a site ratingof greater than or equal to 250 brake HPand less than 500 brake HP located at a major source of HAP emissions?
If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at major source of HAP emissions manufactured on or after January 1, 2008, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you.
[73 FR 3605, Jan. 18, 2008]
General ComplianceRequirements
&sect; 63.6605   What are my general requirementsfor complying with this subpart?
(a) You must be in compliance with the emission limitations and operating limitations in this subpart that apply to you at all times, except during periods of startup, shutdown, and malfunction.
(b) If you must comply with emission limitations and operating limitations, you must operate and maintain your stationary RICE, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during startup, shutdown, and malfunction.
Testing and Initial Compliance Requirements
Testing and Initial Compliance Requirements
&sect; 63.6610 By what date must I conduct the initial performance tests or other initial compliance demonstrations ifI own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions?
&sect; 63.6610 By what date must I conduct the initialperformancetests or other initialcompliance demonstrations ifI own or operate a stationaryRICE with a site rating of more than 500 brake HP located at a major source of HAP emissions?
If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions you are subject to the requirements of this section.(a) You must conduct the initial performance test or other initial compliance demonstrations in Table 4 to this subpart that apply to you within 180 days after the compliance date that is specified for your stationary RICE in &sect;63.6595 and according to the provisions in &sect;63.7(a)(2).(b) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must demonstrate initial compliance with either the proposed emission limitations or the promulgated emission limitations no later than February 10, 2005 or no later than 180 days after startup of the source, whichever is later, according to &sect;63.7(a)(2)(ix).
If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions you are subject to the requirements of this section.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-4 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, and you chose to comply with the proposed emission limitations when demonstrating initial compliance, you must conduct a second performance test to demonstrate compliance with the promulgated emission limitations by December 13, 2007 or after startup of the source, whichever is later, according to &sect;63.7(a)(2)(ix).(d) An owner or operator is not required to conduct an initial performance test on units for which a performance test has been previously conducted, but the test must meet all of the conditions described in paragraphs (d)(1) through (5) of this section.(1) The test must have been conducted using the same methods specified in this subpart, and these methods must have been followed correctly.
(a) You must conduct the initial performance test or other initial compliance demonstrations in Table 4 to this subpart that apply to you within 180 days after the compliance date that is specified for your stationary RICE in &sect;63.6595 and according to the provisions in &sect;63.7(a)(2).
(2) The test must not be older than 2 years.(3) The test must be reviewed and accepted by the Administrator.
(b) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must demonstrate initial compliance with either the proposed emission limitations or the promulgated emission limitations no later than February 10, 2005 or no later than 180 days after startup of the source, whichever is later, according to &sect;63.7(a)(2)(ix).
(4) Either no process or equipment changes must have been made since the test was performed, or the owner or operator must be able to demonstrate that the results of the performance test, with or without adjustments, reliably demonstrate compliance despite process or equipment changes.(5) The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load.[69 FR 33506, June 15, 2004, as amended at 73 FR 3605, Jan. 18, 2008]&sect; 63.6611 By what date must I conduct the initial performance tests or other initial compliance demonstrations if I own or operate a 4SLB SI stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions?
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-4 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, and you chose to comply with the proposed emission limitations when demonstrating initial compliance, you must conduct a second performance test to demonstrate compliance with the promulgated emission limitations by December 13, 2007 or after startup of the source, whichever is later, according to &sect;63.7(a)(2)(ix).
(d) An owner or operator is not required to conduct an initial performance test on units for which a performance test has been previously conducted, but the test must meet all of the conditions described in paragraphs (d)(1) through (5) of this section.
(1) The test must have been conducted using the same methods specified in this subpart, and these methods must have been followed correctly.
(2) The test must not be older than 2 years.
(3) The test must be reviewed and accepted by the Administrator.
(4) Either no process or equipment changes must have been made since the test was performed, or the owner or operator must be able to demonstrate that the results of the performance test, with or without adjustments, reliably demonstrate compliance despite process or equipment changes.
(5) The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load.
[69 FR 33506, June 15, 2004, as amended at 73 FR 3605, Jan. 18, 2008]
&sect; 63.6611 By what date must I conduct the initialperformance tests or other initialcompliance demonstrationsif I own or operate a 4SLB SI stationaryRICE with a site rating of greaterthan or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions?
If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must conduct an initial performance test within 240 days after the compliance date that is specified for your stationary RICE in &sect;63.6595 and according to the provisions specified in Table 4 to this subpart, as appropriate.
If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must conduct an initial performance test within 240 days after the compliance date that is specified for your stationary RICE in &sect;63.6595 and according to the provisions specified in Table 4 to this subpart, as appropriate.
[73 FR 3605, Jan. 18, 2008]&sect; 63.6615 When must I conduct subsequent performance tests?If you must comply with the emission limitations and operating limitations, you must conduct subsequent performance tests as specified in Table 3 of this subpart.&sect; 63.6620 What performance tests and other procedures must I use?(a) You must conduct each performance test in Tables 3 and 4 of this subpart that applies to you.(b) Each performance test must be conducted according to the requirements in &sect;63.7(e)(1) and under the specific conditions that this subpart specifies in Table 4. The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load.(c) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;63.7(e)(1).(d) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;63.7(e)(3).
[73 FR 3605, Jan. 18, 2008]
Each test run must last at least 1 hour.(e)(1) You must use Equation 1 of this section to determine compliance with the percent reduction requirement:
&sect; 63.6615   When must I conduct subsequentperformance tests?
Ci -C x100=R (Eq. 1)Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-5 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Where: C,= concentration of CO or formaldehyde at the control device inlet, C,,= concentration of CO or formaldehyde at the control device outlet, and R = percent reduction of CO or formaldehyde emissions.
If you must comply with the emission limitations and operating limitations, you must conduct subsequent performance tests as specified in Table 3 of this subpart.
(2) You must normalize the carbon monoxide (CO) or formaldehyde concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen, or an equivalent percent carbon dioxide (C0 2). If pollutant concentrations are to be corrected to 15 percent oxygen and CO 2 concentration is measured in lieu of oxygen concentration measurement, a CO 2 correction factor is needed. Calculate the CO 2 correction factor as described in paragraphs (e)(2)(i) through (iii) of this section.(i) Calculate the fuel-specific F. value for the fuel burned during the test using values obtained from Method 19, section 5.2, and the following equation:= -0.209 Fd (Eq 2)Where: Fo = Fuel factor based on the ratio of oxygen volume to the ultimate CO 2 volume produced by the fuel at zero percent excess air.0.209 = Fraction of air that is oxygen, percent/100.
&sect; 63.6620 What performance tests and otherprocedures must I use?
Fd = Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).F, = Ratio of the volume of CO 2 produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).(ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent oxygen, as follows:-. (Eq. 3)Where: X,, 2= CO 2 correction factor, percent.5.9 = 20.9 percent 02-15 percent 02, the defined O 2 correction value, percent.(iii) Calculate the NOx and SO 2 gas concentrations adjusted to 15 percent O 2 using CO 2 as follows: x C4 = C, % (Eq. 4)%C0 2 Where:%C0 2= Measured CO 2 concentration measured, dry basis, percent.(f) If you comply with the emission limitation to reduce CO and you are not using an oxidation catalyst, if you comply with the emission limitation to reduce formaldehyde and you are not using NSCR, or if you comply with the emission limitation to limit the concentration of formaldehyde in the stationary RICE exhaust and you are not using an oxidation catalyst or NSCR, you must petition the Administrator for operating limitations to be established during the initial performance test and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-6 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines continuously monitored thereafter; or for approval of no operating limitations.
(a) You must conduct each performance test in Tables 3 and 4 of this subpart that applies to you.
You must not conduct the initial performance test until after the petition has been approved by the Administrator.(g) If you petition the Administrator for approval of operating limitations, your petition must include the information described in paragraphs (g)(1) through (5) of this section.(1) Identification of the specific parameters you propose to use as operating limitations; (2) A discussion of the relationship between these parameters and HAP emissions, identifying how HAP emissions change with changes in these parameters, and how limitations on these parameters will serve to limit HAP emissions; (3) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations; (4) A discussion identifying the methods you will use to measure and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (5) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters.(h) If you petition the Administrator for approval of no operating limitations, your petition must include the information described in paragraphs (h)(1) through (7) of this section.(1) Identification of the parameters associated with operation of the stationary RICE and any emission control device which could change intentionally ( e.g., operator adjustment, automatic controller adjustment, etc.) or unintentionally ( e.g., wear and tear, error, etc.) on a routine basis or over time;(2) A discussion of the relationship, if any, between changes in the parameters and changes in HAP emissions; (3) For the parameters which could change in such a way as to increase HAP emissions, a discussion of whether establishing limitations on the parameters would serve to limit HAP emissions; (4) For the parameters which could change in such a way as to increase HAP emissions, a discussion of how you could establish upper and/or lower values for the parameters which would establish limits on the parameters in operating limitations; (5) For the parameters, a discussion identifying the methods you could use to measure them and the instruments you could use to monitor them, as well as the relative accuracy and precision of the methods and instruments; (6) For the parameters, a discussion identifying the frequency and methods for recalibrating the instruments you could use to monitor them; and (7) A discussion of why, from your point of view, it is infeasible or unreasonable to adopt the parameters as operating limitations.(i) The engine percent load during a performance test must be determined by documenting the calculations, assumptions, and measurement devices used to measure or estimate the percent load in a specific application.
(b) Each performance test must be conducted according to the requirements in &sect;63.7(e)(1) and under the specific conditions that this subpart specifies in Table 4. The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load.
A written report of the average percent load determination must be included in the notification of compliance status. The following information must be included in the written report: the engine model number, the engine manufacturer, the year of purchase, the manufacturer's site-rated brake horsepower, the ambient temperature, pressure, and humidity during the performance test, and all assumptions that were made to estimate or calculate percent load during the performance test must be clearly explained.
(c) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in &sect;63.7(e)(1).
If measurement devices such as flow meters, kilowatt meters, beta analyzers, stain gauges, etc. are used, the model number of the measurement device, and an estimate of its accurate in percentage of true value must be provided.&sect; 63.6625 What are my monitoring, installation, operation, and maintenance requirements?
(d) You must conduct three separate test runs for each performance test required in this section, as specified in &sect;63.7(e)(3).
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-7 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you elect to install a CEMS as specified in Table 5 of this subpart, you must install, operate, and maintain a CEMS to monitor CO and either oxygen or CO 2 at both the inlet and the outlet of the control device according to the requirements in paragraphs (a)(1) through (4) of this section.(1) Each CEMS must be installed, operated, and maintained according to the applicable performance specifications of 40 CFR part 60, appendix B.(2) You must conduct an initial performance evaluation and an annual relative accuracy test audit (RATA) of each CEMS according to the requirements in &sect;63.8 and according to the applicable performance specifications of 40 CFR part 60, appendix B as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1.(3) As specified in &sect;63.8(c)(4)(ii), each CEMS must complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. You must have at least two data points, with each representing a different 15-minute period, to have a valid hour of data.(4) The CEMS data must be reduced as specified in &sect;63.8(g)(2) and recorded in parts per million or parts per billion (as appropriate for the applicable limitation) at 15 percent oxygen or the equivalent CO 2 concentration.(b) If you are required to install a continuous parameter monitoring system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and maintain each CPMS according to the requirements in &sect;63.8.(c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must monitor and record your fuel usage daily with separate fuel meters to measure the volumetric flow rate of each fuel. In addition, you must operate your stationary RICE in a manner which reasonably minimizes HAP emissions.(d) If you are operating a new or reconstructed emergency 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must install a non-resettable hour meter prior to the startup of the engine.[69 FR 33506, June 15, 2004, as amended at 73 FR 3606, Jan. 18, 2008]&sect; 63.6630 How do I demonstrate initial compliance with the emission limitations and operating limitations?(a) You must demonstrate initial compliance with each emission and operating limitation that applies to you according to Table 5 of this subpart.(b) During the initial performance test, you must establish each operating limitation in Tables lb and 2b of this subpart that applies to you.(c) You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in &sect;63.6645.Continuous Compliance Requirements
Each test run must last at least 1 hour.
&sect; 63.6635 How do I monitor and collect data to demonstrate continuous compliance?(a) If you must comply with emission and operating limitations, you must monitor and collect data according to this section.(b) Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), you must monitor continuously at all times that the stationary RICE is operating.(c) You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must, however, use all the valid data collected during all other periods.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-8 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines&sect; 63.6640 How do I demonstrate continuous compliance with the emission limitations and operating limitations?(a) You must demonstrate continuous compliance with each emission limitation and operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you according to methods specified in Table 6 of this subpart.(b) You must report each instance in which you did not meet each emission limitation or operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in &sect;63.6650.
(e)(1) You must use Equation 1 of this section to determine compliance with the percent reduction requirement:
If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE.(c) [Reserved](d) Consistent with &sect;&sect;63.6(e) and 63.7(e)(1), deviations from the emission or operating limitations that occur during a period of startup, shutdown, or malfunction are not violations if you demonstrate to the Administrator's satisfaction that you were operating in accordance with &sect;63.6(e)(1).
Ci -C     x100=R           (Eq. 1)
For new, reconstructed, and rebuilt stationary RICE, deviations from the emission or operating limitations that occur during the first 200 hours of operation from engine startup (engine bum-in period) are not violations.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-5 of 29
Rebuilt stationary RICE means a stationary RICE that has been rebuilt as that term is defined in 40 CFR &sect;94.1 l(a).(e) You must also report each instance in which you did not meet the requirements in Table 8 to this subpart that apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart: An existing 2SLB stationary RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing emergency stationary RICE, an existing limited use emergency stationary RICE, or an existing stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart, except for the initial notification requirements:
 
a new or reconstructed stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new or reconstructed emergency stationary RICE, or a new or reconstructed limited use stationary RICE.[69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3606, Jan. 18, 2008]Notifications, Reports, and Records&sect; 63.6645 What notifications must I submit and when?(a) If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions or a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 HP located at a major source of HAP emissions, you must submit all of the notifications in &sect;&sect;63.7(b) and (c), 63.8(e), (0(4) and (f)(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified.(b) As specified in &sect;63.9(b)(2), if you start up your stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart, you must submit an Initial Notification not later than December 13, 2004.(c) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions on or after August 16, 2004, you must submit an Initial Notification not later than 120 days after you become subject to this subpart.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-9 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (d) As specified in &sect;63.9(b)(2), if you start up your stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart and you are required to submit an initial notification, you must submit an Initial Notification not later than July 16, 2008.(e) If you start up your new or reconstructed stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions on or after March 18, 2008 and you are required to submit an initial notification, you must submit an Initial Notification not later than 120 days after you become subject to this subpart.(f) If you are required to submit an Initial Notification but are otherwise not affected by the requirements of this subpart, in accordance with &sect;63.6590(b), your notification should include the information in &sect;63.9(b)(2)(i) through (v), and a statement that your stationary RICE has no additional requirements and explain the basis of the exclusion (for example, that it operates exclusively as an emergency stationary RICE if it has a site rating of more than 500 brake HP located at a major source of HAP emissions).(g) If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in &sect;63.7(b)(1).(h) If you are required to conduct a performance test or other initial compliance demonstration as specified in Tables 4 and 5 to this subpart, you must submit a Notification of Compliance Status according to &sect;63.9(h)(2)(ii).
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Where:
C,= concentration of CO or formaldehyde at the control device inlet, C,,= concentration of CO or formaldehyde at the control device outlet, and R = percent reduction of CO or formaldehyde emissions.
(2) You must normalize the carbon monoxide (CO) or formaldehyde concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen, or an equivalent percent carbon dioxide (C0 2 ). If pollutant concentrations are to be corrected to 15 percent oxygen and CO 2concentration is measured in lieu of oxygen concentration measurement, a CO 2correction factor is needed. Calculate the CO 2 correction factor as described in paragraphs (e)(2)(i) through (iii) of this section.
(i) Calculate the fuel-specific F. value for the fuel burned during the test using values obtained from Method 19, section 5.2, and the following equation:
      - 0.209 Fd
      =                  (Eq 2)
Where:
Fo = Fuel factor based on the ratio of oxygen volume to the ultimate CO 2 volume produced by the fuel at zero percent excess air.
0.209 = Fraction of air that is oxygen, percent/100.
Fd = Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).
F, = Ratio of the volume of CO 2 produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu).
(ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent oxygen, as follows:
        -.         (Eq. 3)
Where:
X,, 2= CO 2 correction factor, percent.
5.9 = 20.9 percent 02-15 percent     02, the defined O 2correction value, percent.
(iii) Calculate the NOx and SO 2 gas concentrations adjusted to 15 percent O 2 using CO 2as follows:
C4     = C, %
x            (Eq. 4)
            %C0 2 Where:
%C0 2= Measured CO 2 concentration measured, dry basis, percent.
(f) If you comply with the emission limitation to reduce CO and you are not using an oxidation catalyst, if you comply with the emission limitation to reduce formaldehyde and you are not using NSCR, or if you comply with the emission limitation to limit the concentration of formaldehyde in the stationary RICE exhaust and you are not using an oxidation catalyst or NSCR, you must petition the Administrator for operating limitations to be established during the initial performance test and Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPZ-6 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines continuously monitored thereafter; or for approval of no operating limitations. You must not conduct the initial performance test until after the petition has been approved by the Administrator.
(g) If you petition the Administrator for approval of operating limitations, your petition must include the information described in paragraphs (g)(1) through (5) of this section.
(1) Identification of the specific parameters you propose to use as operating limitations; (2) A discussion of the relationship between these parameters and HAP emissions, identifying how HAP emissions change with changes in these parameters, and how limitations on these parameters will serve to limit HAP emissions; (3) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations; (4) A discussion identifying the methods you will use to measure and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (5) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters.
(h) If you petition the Administrator for approval of no operating limitations, your petition must include the information described in paragraphs (h)(1) through (7) of this section.
(1) Identification of the parameters associated with operation of the stationary RICE and any emission control device which could change intentionally ( e.g., operator adjustment, automatic controller adjustment, etc.) or unintentionally ( e.g., wear and tear, error, etc.) on a routine basis or over time; (2) A discussion of the relationship, if any, between changes in the parameters and changes in HAP emissions; (3) For the parameters which could change in such a way as to increase HAP emissions, a discussion of whether establishing limitations on the parameters would serve to limit HAP emissions; (4) For the parameters which could change in such a way as to increase HAP emissions, a discussion of how you could establish upper and/or lower values for the parameters which would establish limits on the parameters in operating limitations; (5) For the parameters, a discussion identifying the methods you could use to measure them and the instruments you could use to monitor them, as well as the relative accuracy and precision of the methods and instruments; (6) For the parameters, a discussion identifying the frequency and methods for recalibrating the instruments you could use to monitor them; and (7) A discussion of why, from your point of view, it is infeasible or unreasonable to adopt the parameters as operating limitations.
(i) The engine percent load during a performance test must be determined by documenting the calculations, assumptions, and measurement devices used to measure or estimate the percent load in a specific application. A written report of the average percent load determination must be included in the notification of compliance status. The following information must be included in the written report: the engine model number, the engine manufacturer, the year of purchase, the manufacturer's site-rated brake horsepower, the ambient temperature, pressure, and humidity during the performance test, and all assumptions that were made to estimate or calculate percent load during the performance test must be clearly explained. If measurement devices such as flow meters, kilowatt meters, beta analyzers, stain gauges, etc. are used, the model number of the measurement device, and an estimate of its accurate in percentage of true value must be provided.
&sect; 63.6625 What are my monitoring, installation,operation, and maintenance requirements?
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-7 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you elect to install a CEMS as specified in Table 5 of this subpart, you must install, operate, and maintain a CEMS to monitor CO and either oxygen or CO 2at both the inlet and the outlet of the control device according to the requirements in paragraphs (a)(1) through (4) of this section.
(1) Each CEMS must be installed, operated, and maintained according to the applicable performance specifications of 40 CFR part 60, appendix B.
(2) You must conduct an initial performance evaluation and an annual relative accuracy test audit (RATA) of each CEMS according to the requirements in &sect;63.8 and according to the applicable performance specifications of 40 CFR part 60, appendix B as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1.
(3) As specified in &sect;63.8(c)(4)(ii), each CEMS must complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. You must have at least two data points, with each representing a different 15-minute period, to have a valid hour of data.
(4) The CEMS data must be reduced as specified in &sect;63.8(g)(2) and recorded in parts per million or parts per billion (as appropriate for the applicable limitation) at 15 percent oxygen or the equivalent CO 2 concentration.
(b) If you are required to install a continuous parameter monitoring system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and maintain each CPMS according to the requirements in &sect;63.8.
(c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must monitor and record your fuel usage daily with separate fuel meters to measure the volumetric flow rate of each fuel. In addition, you must operate your stationary RICE in a manner which reasonably minimizes HAP emissions.
(d) If you are operating a new or reconstructed emergency 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must install a non-resettable hour meter prior to the startup of the engine.
[69 FR 33506, June 15, 2004, as amended at 73 FR 3606, Jan. 18, 2008]
&sect; 63.6630   How do I demonstrateinitialcompliance with the emission limitationsand operatinglimitations?
(a) You must demonstrate initial compliance with each emission and operating limitation that applies to you according to Table 5 of this subpart.
(b) During the initial performance test, you must establish each operating limitation in Tables lb and 2b of this subpart that applies to you.
(c) You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in &sect;63.6645.
Continuous Compliance Requirements
&sect; 63.6635   How do I monitor and collect data to demonstrate continuous compliance?
(a) If you must comply with emission and operating limitations, you must monitor and collect data according to this section.
(b) Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), you must monitor continuously at all times that the stationary RICE is operating.
(c) You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must, however, use all the valid data collected during all other periods.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPZ-8 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
&sect; 63.6640 How do I demonstrate continuous compliance with the emission limitations and operatinglimitations?
(a) You must demonstrate continuous compliance with each emission limitation and operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you according to methods specified in Table 6 of this subpart.
(b) You must report each instance in which you did not meet each emission limitation or operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in &sect;63.6650. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE.
(c) [Reserved]
(d) Consistent with &sect;&sect;63.6(e) and 63.7(e)(1), deviations from the emission or operating limitations that occur during a period of startup, shutdown, or malfunction are not violations if you demonstrate to the Administrator's satisfaction that you were operating in accordance with &sect;63.6(e)(1). For new, reconstructed, and rebuilt stationary RICE, deviations from the emission or operating limitations that occur during the first 200 hours of operation from engine startup (engine bum-in period) are not violations.
Rebuilt stationary RICE means a stationary RICE that has been rebuilt as that term is defined in 40 CFR &sect;94.1 l(a).
(e) You must also report each instance in which you did not meet the requirements in Table 8 to this subpart that apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart: An existing 2SLB stationary RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing emergency stationary RICE, an existing limited use emergency stationary RICE, or an existing stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart, except for the initial notification requirements: a new or reconstructed stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new or reconstructed emergency stationary RICE, or a new or reconstructed limited use stationary RICE.
[69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3606, Jan. 18, 2008]
Notifications, Reports, and Records
&sect; 63.6645   What notifications must I submit and when?
(a) If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions or a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 HP located at a major source of HAP emissions, you must submit all of the notifications in &sect;&sect;63.7(b) and (c), 63.8(e), (0(4) and (f)(6),
63.9(b) through (e), and (g) and (h) that apply to you by the dates specified.
(b) As specified in &sect;63.9(b)(2), if you start up your stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart, you must submit an Initial Notification not later than December 13, 2004.
(c) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions on or after August 16, 2004, you must submit an Initial Notification not later than 120 days after you become subject to this subpart.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-9 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (d) As specified in &sect;63.9(b)(2), if you start up your stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart and you are required to submit an initial notification, you must submit an Initial Notification not later than July 16, 2008.
(e) If you start up your new or reconstructed stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions on or after March 18, 2008 and you are required to submit an initial notification, you must submit an Initial Notification not later than 120 days after you become subject to this subpart.
(f) If you are required to submit an Initial Notification but are otherwise not affected by the requirements of this subpart, in accordance with &sect;63.6590(b), your notification should include the information in &sect;63.9(b)(2)(i) through (v), and a statement that your stationary RICE has no additional requirements and explain the basis of the exclusion (for example, that it operates exclusively as an emergency stationary RICE if it has a site rating of more than 500 brake HP located at a major source of HAP emissions).
(g) If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in &sect;63.7(b)(1).
(h) If you are required to conduct a performance test or other initial compliance demonstration as specified in Tables 4 and 5 to this subpart, you must submit a Notification of Compliance Status according to &sect;63.9(h)(2)(ii).
(1) For each initial compliance demonstration required in Table 5 to this subpart that does not include a performance test, you must submit the Notification of Compliance Status before the close of business on the 30th day following the completion of the initial compliance demonstration.
(1) For each initial compliance demonstration required in Table 5 to this subpart that does not include a performance test, you must submit the Notification of Compliance Status before the close of business on the 30th day following the completion of the initial compliance demonstration.
(2) For each initial compliance demonstration required in Table 5 to this subpart that includes a performance test conducted according to the requirements in Table 3 to this subpart, you must submit the Notification of Compliance Status, including the performance test results, before the close of business on the 60th day following the completion of the performance test according to &sect;63.10(d)(2).
(2) For each initial compliance demonstration required in Table 5 to this subpart that includes a performance test conducted according to the requirements in Table 3 to this subpart, you must submit the Notification of Compliance Status, including the performance test results, before the close of business on the 60th day following the completion of the performance test according to &sect;63.10(d)(2).
[73 FR 3606, Jan. 18, 2008]&sect; 63.6650 What reports must I submit and when?(a) You must submit each report in Table 7 of this subpart that applies to you.(b) Unless the Administrator has approved a different schedule for submission of reports under &sect;63.10(a), you must submit each report by the date in Table 7 of this subpart and according to the requirements in paragraphs (b)(1) through (5) of this section.(1) The first Compliance report must cover the period beginning on the compliance date that is specified for your affected source in &sect;63.6595 and ending on June 30 or December 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for your source in &sect;63.6595.(2) The first Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date follows the end of the first calendar half after the compliance date that is specified for your affected source in &sect;63.6595.(3) Each subsequent Compliance report must cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31.(4) Each subsequent Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period.(5) For each stationary RICE that is subject to permitting regulations pursuant to 40 CFR part 70 or 71, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6 (a)(3)(iii)(A), you may submit the first and subsequent Compliance reports according to the dates the permitting authority has established instead of according to the dates in paragraphs (b)(1) through (4) of this section.(c) The Compliance report must contain the information in paragraphs (c)(1) through (6) of this section.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-10 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (1) Company name and address.(2) Statement by a responsible official, with that official's name, title, and signature, certifying the accuracy of the content of the report.(3) Date of report and beginning and ending dates of the reporting period.(4) If you had a startup, shutdown, or malfunction during the reporting period, the compliance report must include the information in &sect;63.10(d)(5)(i).
[73 FR 3606, Jan. 18, 2008]
(5) If there are no deviations from any emission or operating limitations that apply to you, a statement that there were no deviations from the emission or operating limitations during the reporting period.(6) If there were no periods during which the continuous monitoring system (CMS), including CEMS and CPMS, was out-of-control, as specified in &sect;63.8(c)(7), a statement that there were no periods during which the CMS was out-of-control during the reporting period.(d) For each deviation from an emission or operating limitation that occurs for a stationary RICE where you are not using a CMS to comply with the emission or operating limitations in this subpart, the Compliance report must contain the information in paragraphs (c)(1) through (4) of this section and the information in paragraphs (d)(1) and (2) of this section.(1) The total operating time of the stationary RICE at which the deviation occurred during the reporting period.(2) Information on the number, duration, and cause of deviations (including unknown cause, if applicable), as applicable, and the corrective action taken.(e) For each deviation from an emission or operating limitation occurring for a stationary RICE where you are using a CMS to comply with the emission and operating limitations in this subpart, you must include information in paragraphs (c)(1)through (4) and (e)(1) through (12) of this section.(1) The date and time that each malfunction started and stopped.(2) The date, time, and duration that each CMS was inoperative, except for zero (low-level) and high-level checks.(3) The date, time, and duration that each CMS was out-of-control, including the information in &sect;63.8(c)(8).
&sect; 63.6650     What reports must I submit and when?
(4) The date and time that each deviation started and stopped, and whether each deviation occurred during a period of malfunction or during another period.(5) A summary of the total duration of the deviation during the reporting period, and the total duration as a percent of the total source operating time during that reporting period.(6) A breakdown of the total duration of the deviations during the reporting period into those that are due to control equipment problems, process problems, other known causes, and other unknown causes.(7) A summary of the total duration of CMS downtime during the reporting period, and the total duration of CMS downtime as a percent of the total operating time of the stationary RICE at which the CMS downtime occurred during that reporting period.(8) An identification of each parameter and pollutant (CO or formaldehyde) that was monitored at the stationary RICE.(9) A brief description of the stationary RICE.(10) A brief description of the CMS.(11) The date of the latest CMS certification or audit.(12) A description of any changes in CMS, processes, or controls since the last reporting period.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-11 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (f) Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A).
(a) You must submit each report in Table 7 of this subpart that applies to you.
If an affected source submits a Compliance report pursuant to Table 7 of this subpart along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report includes all required information concerning deviations from any emission or operating limitation in this subpart, submission of the Compliance report shall be deemed to satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority.(g) If you are operating as a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must submit an annual report according to Table 7 of this subpart by the date specified unless the Administrator has approved a different schedule, according to the information described in paragraphs (b)(1) through (b)(5) of this section. You must report the data specified in (g)(1) through (g)(3) of this section.(1) Fuel flow rate of each fuel and the heating values that were used in your calculations.
(b) Unless the Administrator has approved a different schedule for submission of reports under &sect;63.10(a), you must submit each report by the date in Table 7 of this subpart and according to the requirements in paragraphs (b)(1) through (5) of this section.
You must also demonstrate that the percentage of heat input provided by landfill gas or digester gas is equivalent to 10 percent or more of the total fuel consumption on an annual basis.(2) The operating limits provided in your federally enforceable permit, and any deviations from these limits.(3) Any problems or errors suspected with the meters.&sect; 63.6655 What records must I keep?(a) If you must comply with the emission and operating limitations, you must keep the records described in paragraphs (a)(1)through (a)(3), (b)(1) through (b)(3) and (c) of this section.(1) A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in&sect;63.10(b)(2)(xiv).
(1) The first Compliance report must cover the period beginning on the compliance date that is specified for your affected source in &sect;63.6595 and ending on June 30 or December 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for your source in &sect;63.6595.
(2) The first Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date follows the end of the first calendar half after the compliance date that is specified for your affected source in &sect;63.6595.
(3) Each subsequent Compliance report must cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31.
(4) Each subsequent Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period.
(5) For each stationary RICE that is subject to permitting regulations pursuant to 40 CFR part 70 or 71, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6 (a)(3)(iii)(A), you may submit the first and subsequent Compliance reports according to the dates the permitting authority has established instead of according to the dates in paragraphs (b)(1) through (4) of this section.
(c) The Compliance report must contain the information in paragraphs (c)(1) through (6) of this section.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPZ-10 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (1) Company name and address.
(2) Statement by a responsible official, with that official's name, title, and signature, certifying the accuracy of the content of the report.
(3) Date of report and beginning and ending dates of the reporting period.
(4) If you had a startup, shutdown, or malfunction during the reporting period, the compliance report must include the information in &sect;63.10(d)(5)(i).
(5) If there are no deviations from any emission or operating limitations that apply to you, a statement that there were no deviations from the emission or operating limitations during the reporting period.
(6) If there were no periods during which the continuous monitoring system (CMS), including CEMS and CPMS, was out-of-control, as specified in &sect;63.8(c)(7), a statement that there were no periods during which the CMS was out-of-control during the reporting period.
(d) For each deviation from an emission or operating limitation that occurs for a stationary RICE where you are not using a CMS to comply with the emission or operating limitations in this subpart, the Compliance report must contain the information in paragraphs (c)(1) through (4) of this section and the information in paragraphs (d)(1) and (2) of this section.
(1) The total operating time of the stationary RICE at which the deviation occurred during the reporting period.
(2) Information on the number, duration, and cause of deviations (including unknown cause, if applicable), as applicable, and the corrective action taken.
(e) For each deviation from an emission or operating limitation occurring for a stationary RICE where you are using a CMS to comply with the emission and operating limitations in this subpart, you must include information in paragraphs (c)(1) through (4) and (e)(1) through (12) of this section.
(1) The date and time that each malfunction started and stopped.
(2) The date, time, and duration that each CMS was inoperative, except for zero (low-level) and high-level checks.
(3) The date, time, and duration that each CMS was out-of-control, including the information in &sect;63.8(c)(8).
(4) The date and time that each deviation started and stopped, and whether each deviation occurred during a period of malfunction or during another period.
(5) A summary of the total duration of the deviation during the reporting period, and the total duration as a percent of the total source operating time during that reporting period.
(6) A breakdown of the total duration of the deviations during the reporting period into those that are due to control equipment problems, process problems, other known causes, and other unknown causes.
(7) A summary of the total duration of CMS downtime during the reporting period, and the total duration of CMS downtime as a percent of the total operating time of the stationary RICE at which the CMS downtime occurred during that reporting period.
(8) An identification of each parameter and pollutant (CO or formaldehyde) that was monitored at the stationary RICE.
(9) A brief description of the stationary RICE.
(10) A brief description of the CMS.
(11) The date of the latest CMS certification or audit.
(12) A description of any changes in CMS, processes, or controls since the last reporting period.
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPZ-11 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (f) Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a Compliance report pursuant to Table 7 of this subpart along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report includes all required information concerning deviations from any emission or operating limitation in this subpart, submission of the Compliance report shall be deemed to satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority.
(g) If you are operating as a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must submit an annual report according to Table 7 of this subpart by the date specified unless the Administrator has approved a different schedule, according to the information described in paragraphs (b)(1) through (b)(5) of this section. You must report the data specified in (g)(1) through (g)(3) of this section.
(1) Fuel flow rate of each fuel and the heating values that were used in your calculations. You must also demonstrate that the percentage of heat input provided by landfill gas or digester gas is equivalent to 10 percent or more of the total fuel consumption on an annual basis.
(2) The operating limits provided in your federally enforceable permit, and any deviations from these limits.
(3) Any problems or errors suspected with the meters.
&sect; 63.6655 What records must I keep?
(a) If you must comply with the emission and operating limitations, you must keep the records described in paragraphs (a)(1) through (a)(3), (b)(1) through (b)(3) and (c) of this section.
(1) A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in
&sect;63.10(b)(2)(xiv).
(2) The records in &sect;63.6(e)(3)(iii) through (v) related to startup, shutdown, and malfunction.
(2) The records in &sect;63.6(e)(3)(iii) through (v) related to startup, shutdown, and malfunction.
(3) Records of performance tests and performance evaluations as required in &sect;63.10(b)(2)(viii).(b) For each CEMS or CPMS, you must keep the records listed in paragraphs (b)(1) through (3) of this section.(1) Records described in &sect;63.10(b)(2)(vi) through (xi).(2) Previous ( i.e., superseded) versions of the performance evaluation plan as required in &sect;63.8(d)(3).
(3) Records of performance tests and performance evaluations as required in &sect;63.10(b)(2)(viii).
(3) Requests for alternatives to the relative accuracy test for CEMS or CPMS as required in &sect;63.8(f)(6)(i), if applicable.(c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must keep the records of your daily fuel usage monitors.(d) You must keep the records required in Table 6 of this subpart to show continuous compliance with each emission or operating limitation that applies to you.&sect; 63.6660 In what form and how long must I keep my records?(a) Your records must be in a form suitable and readily available for expeditious review according to &sect;63.10(b)(1).(b) As specified in &sect;63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-12 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) You must keep each record readily accessible in hard copy or electronic form on-site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to &sect;63.10(b)(1).
(b) For each CEMS or CPMS, you must keep the records listed in paragraphs (b)(1) through (3) of this section.
You can keep the records off-site for the remaining 3 years.Other Requirements and Information
(1) Records described in &sect;63.10(b)(2)(vi) through (xi).
&sect; 63.6665 What parts of the General Provisions apply to me?Table 8 to this subpart shows which parts of the General Provisions in &sect;&sect;63.1 through 63.15 apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with any of the requirements of the General Provisions:
(2) Previous ( i.e., superseded) versions of the performance evaluation plan as required in &sect;63.8(d)(3).
An existing 2SLB RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, an existing emergency stationary RICE, or an existing limited use stationary RICE. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in the General Provisions except for the initial notification requirements:
(3) Requests for alternatives to the relative accuracy test for CEMS or CPMS as required in &sect;63.8(f)(6)(i), if applicable.
A new stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new emergency stationary RICE, or a new limited use stationary RICE.[73 FR 3606, Jan. 18, 2008]&sect; 63.6670 Who implements and enforces this subpart?(a) This subpart is implemented and enforced by the U.S. EPA, or a delegated authority such as your State, local, or tribal agency. If the U.S. EPA Administrator has delegated authority to your State, local, or tribal agency, then that agency (as well as the U.S. EPA) has the authority to implement and enforce this subpart. You should contact your U.S. EPA Regional Office to find out whether this subpart is delegated to your State, local, or tribal agency.(b) In delegating implementation and enforcement authority of this subpart to a State, local, or tribal agency under 40 CFR part 63, subpart E, the authorities contained in paragraph (c) of this section are retained by the Administrator of the U.S. EPA and are not transferred to the State, local, or tribal agency.(c) The authorities that will not be delegated to State, local, or tribal agencies are: (1) Approval of alternatives to the non-opacity emission limitations and operating limitations in &sect;63.6600 under &sect;63.6(g).(2) Approval of major alternatives to test methods under &sect;63.7(e)(2)(ii) and (f) and as defined in &sect;63.90.(3) Approval of major alternatives to monitoring under &sect;63.8(f) and as defined in &sect;63.90.(4) Approval of major alternatives to recordkeeping and reporting under &sect;63.10(f) and as defined in &sect;63.90.(5) Approval of a performance test which was conducted prior to the effective date of the rule, as specified in &sect;63.6610(b).
(c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must keep the records of your daily fuel usage monitors.
&sect; 63.6675 What definitions apply to this subpart?Terms used in this subpart are defined in the Clean Air Act (CAA); in 40 CFR 63.2, the General Provisions of this part; and in this section as follows: Area source means any stationary source of HAP that is not a major source as defined in part 63.Associated equipment as used in this subpart and as referred to in section 112(n)(4) of the CAA, means equipment associated with an oil or natural gas exploration or production well, and includes all equipment from the well bore to the point of custody transfer, except glycol dehydration units, storage vessels with potential for flash emissions, combustion turbines, and stationary RICE.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-13 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines CAA means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Public Law 101-549, 104 Stat. 2399).Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.Custody transfer means the transfer of hydrocarbon liquids or natural gas: After processing and/or treatment in the producing operations, or from storage vessels or automatic transfer facilities or other such equipment, including product loading racks, to pipelines or any other forms of transportation.
(d) You must keep the records required in Table 6 of this subpart to show continuous compliance with each emission or operating limitation that applies to you.
For the purposes of this subpart, the point at which such liquids or natural gas enters a natural gas processing plant is a point of custody transfer.Deviation means any instance in which an affected source subject to this subpart, or an owner or operator of such a source: (1) Fails to meet any requirement or obligation established by this subpart, including but not limited to any emission limitation or operating limitation; (2) Fails to meet any term or condition that is adopted to implement an applicable requirement in this subpart and that is included in the operating permit for any affected source required to obtain such a permit; or (3) Fails to meet any emission limitation or operating limitation in this subpart during malfunction, regardless or whether or not such failure is permitted by this subpart.(4) Fails to satisfy the general duty to minimize emissions established by &sect;63.6(e)(1)(i).
&sect; 63.6660 In what form and how long must I keep my records?
Diesel engine means any stationary RICE in which a high boiling point liquid fuel injected into the combustion chamber ignites when the air charge has been compressed to a temperature sufficiently high for auto-ignition.
(a) Your records must be in a form suitable and readily available for expeditious review according to &sect;63.10(b)(1).
This process is also known as compression ignition.Diesel fuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is fuel oil number 2.Digester gas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and CO 2.Dual-fuel engine means any stationary RICE in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel.Emergency stationary RICE means any stationary RICE whose operation is limited to emergency situations and required testing and maintenance.
(b) As specified in &sect;63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record.
Examples include stationary RICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary RICE used to pump water in the case of fire or flood, etc. Stationary RICE used for peak shaving are not considered emergency stationary RICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by the manufacturer, the vendor, or the insurance company associated with the engine. Required testing of such units should be minimized, but there is no time limit on the use of emergency stationary RICE in emergency situations and for routine testing and maintenance.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-12 of 29
Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may also operate an additional 50 hours per year in non-emergency situations.
 
Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed on or after June 12, 2006, must comply with requirements specified in 40 CFR 60.4243(d).
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) You must keep each record readily accessible in hard copy or electronic form on-site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to &sect;63.10(b)(1). You can keep the records off-site for the remaining 3 years.
Other Requirements and Information
&sect; 63.6665     What parts of the General Provisionsapply to me?
Table 8 to this subpart shows which parts of the General Provisions in &sect;&sect;63.1 through 63.15 apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with any of the requirements of the General Provisions: An existing 2SLB RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, an existing emergency stationary RICE, or an existing limited use stationary RICE. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in the General Provisions except for the initial notification requirements: A new stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new emergency stationary RICE, or a new limited use stationary RICE.
[73 FR 3606, Jan. 18, 2008]
&sect; 63.6670     Who implements and enforces this subpart?
(a) This subpart is implemented and enforced by the U.S. EPA, or a delegated authority such as your State, local, or tribal agency. If the U.S. EPA Administrator has delegated authority to your State, local, or tribal agency, then that agency (as well as the U.S. EPA) has the authority to implement and enforce this subpart. You should contact your U.S. EPA Regional Office to find out whether this subpart is delegated to your State, local, or tribal agency.
(b) In delegating implementation and enforcement authority of this subpart to a State, local, or tribal agency under 40 CFR part 63, subpart E, the authorities contained in paragraph (c) of this section are retained by the Administrator of the U.S. EPA and are not transferred to the State, local, or tribal agency.
(c) The authorities that will not be delegated to State, local, or tribal agencies are:
(1) Approval of alternatives to the non-opacity emission limitations and operating limitations in &sect;63.6600 under &sect;63.6(g).
(2) Approval of major alternatives to test methods under &sect;63.7(e)(2)(ii) and (f) and as defined in &sect;63.90.
(3) Approval of major alternatives to monitoring under &sect;63.8(f) and as defined in &sect;63.90.
(4) Approval of major alternatives to recordkeeping and reporting under &sect;63.10(f) and as defined in &sect;63.90.
(5) Approval of a performance test which was conducted prior to the effective date of the rule, as specified in &sect;63.6610(b).
&sect; 63.6675 What definitions apply to this subpart?
Terms used in this subpart are defined in the Clean Air Act (CAA); in 40 CFR 63.2, the General Provisions of this part; and in this section as follows:
Area source means any stationary source of HAP that is not a major source as defined in part 63.
Associated equipment as used in this subpart and as referred to in section 112(n)(4) of the CAA, means equipment associated with an oil or natural gas exploration or production well, and includes all equipment from the well bore to the point of custody transfer, except glycol dehydration units, storage vessels with potential for flash emissions, combustion turbines, and stationary RICE.
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-13 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines CAA means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Public Law 101-549, 104 Stat. 2399).
Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine.
Custody transfer means the transfer of hydrocarbon liquids or natural gas: After processing and/or treatment in the producing operations, or from storage vessels or automatic transfer facilities or other such equipment, including product loading racks, to pipelines or any other forms of transportation. For the purposes of this subpart, the point at which such liquids or natural gas enters a natural gas processing plant is a point of custody transfer.
Deviation means any instance in which an affected source subject to this subpart, or an owner or operator of such a source:
(1) Fails to meet any requirement or obligation established by this subpart, including but not limited to any emission limitation or operating limitation; (2) Fails to meet any term or condition that is adopted to implement an applicable requirement in this subpart and that is included in the operating permit for any affected source required to obtain such a permit; or (3) Fails to meet any emission limitation or operating limitation in this subpart during malfunction, regardless or whether or not such failure is permitted by this subpart.
(4) Fails to satisfy the general duty to minimize emissions established by &sect;63.6(e)(1)(i).
Diesel engine means any stationary RICE in which a high boiling point liquid fuel injected into the combustion chamber ignites when the air charge has been compressed to a temperature sufficiently high for auto-ignition. This process is also known as compression ignition.
Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is fuel oil number 2.
Digestergas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and CO 2.
Dual-fuel engine means any stationary RICE in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel.
Emergency stationaryRICE means any stationary RICE whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary RICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary RICE used to pump water in the case of fire or flood, etc. Stationary RICE used for peak shaving are not considered emergency stationary RICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by the manufacturer, the vendor, or the insurance company associated with the engine. Required testing of such units should be minimized, but there is no time limit on the use of emergency stationary RICE in emergency situations and for routine testing and maintenance. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may also operate an additional 50 hours per year in non-emergency situations. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed on or after June 12, 2006, must comply with requirements specified in 40 CFR 60.4243(d).
Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution.
Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution.
Gaseous fuel means a material used for combustion which is in the gaseous state at standard atmospheric temperature and pressure conditions.
Gaseousfuel means a material used for combustion which is in the gaseous state at standard atmospheric temperature and pressure conditions.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-14 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline.Glycol dehydration unit means a device in which a liquid glycol (including, but not limited to, ethylene glycol, diethylene glycol, or triethylene glycol) absorbent directly contacts a natural gas stream and absorbs water in a contact tower or absorption column (absorber).
Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page NESHAPZ-14 of 29
The glycol contacts and absorbs water vapor and other gas stream constituents from the natural gas and becomes "rich" glycol. This glycol is then regenerated in the glycol dehydration unit reboiler.
 
The "lean" glycol is then recycled.Hazardous air pollutants (HAP) means any air pollutants listed in or pursuant to section 112(b) of the CAA.ISO standard day conditions means 288 degrees Kelvin (15 degrees Celsius), 60 percent relative humidity and 101.3 kilopascals pressure.Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2.Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich burn engine.Limited use stationary RICE means any stationary RICE that operates less than 100 hours per year.Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production.
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline.
Liquid fuel means any fuel in liquid form at standard temperature and pressure, including but not limited to diesel, residual/crude oil, kerosene/naphtha (jet fuel), and gasoline.Major Source, as used in this subpart, shall have the same meaning as in &sect;63.2, except that: (1) Emissions from any oil or gas exploration or production well (with its associated equipment (as defined in this section))and emissions from any pipeline compressor station or pump station shall not be aggregated with emissions from other similar units, to determine whether such emission points or stations are major sources, even when emission points are in a contiguous area or under common control;(2) For oil and gas production facilities, emissions from processes, operations, or equipment that are not part of the same oil and gas production facility, as defined in &sect;63.1271 of subpart HHH of this part, shall not be aggregated; (3) For production field facilities, only HAP emissions from glycol dehydration units, storage vessel with the potential for flash emissions, combustion turbines and reciprocating internal combustion engines shall be aggregated for a major source determination; and (4) Emissions from processes, operations, and equipment that are not part of the same natural gas transmission and storage facility, as defined in &sect;63.1271 of subpart HHH of this part, shall not be aggregated.
Glycol dehydration unit means a device in which a liquid glycol (including, but not limited to, ethylene glycol, diethylene glycol, or triethylene glycol) absorbent directly contacts a natural gas stream and absorbs water in a contact tower or absorption column (absorber). The glycol contacts and absorbs water vapor and other gas stream constituents from the natural gas and becomes "rich" glycol. This glycol is then regenerated in the glycol dehydration unit reboiler. The "lean" glycol is then recycled.
Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded.
Hazardousairpollutants (HAP) means any air pollutants listed in or pursuant to section 112(b) of the CAA.
Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
ISO standardday conditions means 288 degrees Kelvin (15 degrees Celsius), 60 percent relative humidity and 101.3 kilopascals pressure.
Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality.Non-selective catalytic reduction (NSCR) means an add-on catalytic nitrogen oxides (NOx) control device for rich burn engines that, in a two-step reaction, promotes the conversion of excess oxygen, NOx, CO, and volatile organic compounds (VOC) into C0 2 , nitrogen, and water.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-15 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Oil and gas production facility as used in this subpart means any grouping of equipment where hydrocarbon liquids are processed, upgraded ( i.e., remove impurities or other constituents to meet contract specifications), or stored prior to the point of custody transfer; or where natural gas is processed, upgraded, or stored prior to entering the natural gas transmission and storage source category.
Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2.
For purposes of a major source determination, facility (including a building, structure, or installation) means oil and natural gas production and processing equipment that is located within the boundaries of an individual surface site as defined in this section. Equipment that is part of a facility will typically be located within close proximity to other equipment located at the same facility.
Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich burn engine.
Pieces of production equipment or groupings of equipment located on different oil and gas leases, mineral fee tracts, lease tracts, subsurface or surface unit areas, surface fee tracts, surface lease tracts, or separate surface sites, whether or not connected by a road, waterway, power line or pipeline, shall not be considered part of the same facility.
Limited use stationaryRICE means any stationary RICE that operates less than 100 hours per year.
Examples of facilities in the oil and natural gas production source category include, but are not limited to, well sites, satellite tank batteries, central tank batteries, a compressor station that transports natural gas to a natural gas processing plant, and natural gas processing plants.Oxidation catalyst means an add-on catalytic control device that controls CO and VOC by oxidation.
Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production.
Liquidfuel means any fuel in liquid form at standard temperature and pressure, including but not limited to diesel, residual/crude oil, kerosene/naphtha (jet fuel), and gasoline.
Major Source, as used in this subpart, shall have the same meaning as in &sect;63.2, except that:
(1) Emissions from any oil or gas exploration or production well (with its associated equipment (as defined in this section))
and emissions from any pipeline compressor station or pump station shall not be aggregated with emissions from other similar units, to determine whether such emission points or stations are major sources, even when emission points are in a contiguous area or under common control; (2) For oil and gas production facilities, emissions from processes, operations, or equipment that are not part of the same oil and gas production facility, as defined in &sect;63.1271 of subpart HHH of this part, shall not be aggregated; (3) For production field facilities, only HAP emissions from glycol dehydration units, storage vessel with the potential for flash emissions, combustion turbines and reciprocating internal combustion engines shall be aggregated for a major source determination; and (4) Emissions from processes, operations, and equipment that are not part of the same natural gas transmission and storage facility, as defined in &sect;63.1271 of subpart HHH of this part, shall not be aggregated.
Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded. Failures that are caused in part by poor maintenance or careless operation are not malfunctions.
Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality.
Non-selective catalytic reduction (NSCR) means an add-on catalytic nitrogen oxides (NOx) control device for rich burn engines that, in a two-step reaction, promotes the conversion of excess oxygen, NOx, CO, and volatile organic compounds (VOC) into C0 2 , nitrogen, and water.
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                               Title V Permit Renewal Page NESHAPZ-15 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Oil and gas productionfacility as used in this subpart means any grouping of equipment where hydrocarbon liquids are processed, upgraded ( i.e., remove impurities or other constituents to meet contract specifications), or stored prior to the point of custody transfer; or where natural gas is processed, upgraded, or stored prior to entering the natural gas transmission and storage source category. For purposes of a major source determination, facility (including a building, structure, or installation) means oil and natural gas production and processing equipment that is located within the boundaries of an individual surface site as defined in this section. Equipment that is part of a facility will typically be located within close proximity to other equipment located at the same facility. Pieces of production equipment or groupings of equipment located on different oil and gas leases, mineral fee tracts, lease tracts, subsurface or surface unit areas, surface fee tracts, surface lease tracts, or separate surface sites, whether or not connected by a road, waterway, power line or pipeline, shall not be considered part of the same facility. Examples of facilities in the oil and natural gas production source category include, but are not limited to, well sites, satellite tank batteries, central tank batteries, a compressor station that transports natural gas to a natural gas processing plant, and natural gas processing plants.
Oxidation catalyst means an add-on catalytic control device that controls CO and VOC by oxidation.
Peaking unit or engine means any standby engine intended for use during periods of high demand that are not emergencies.
Peaking unit or engine means any standby engine intended for use during periods of high demand that are not emergencies.
Percent load means the fractional power of an engine compared to its maximum manufacturer's design capacity at engine site conditions.
Percent load means the fractional power of an engine compared to its maximum manufacturer's design capacity at engine site conditions. Percent load may range between 0 percent to above 100 percent.
Percent load may range between 0 percent to above 100 percent.Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable.
Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. For oil and natural gas production facilities subject to subpart HH of this part, the potential to emit provisions in
For oil and natural gas production facilities subject to subpart HH of this part, the potential to emit provisions in&sect;63.760(a) may be used. For natural gas transmission and storage facilities subject to subpart HHH of this part, the maximum annual facility gas throughput for storage facilities may be determined according to &sect;63.1270(a)(1) and the maximum annual throughput for transmission facilities may be determined according to &sect;63.1270(a)(2).
&sect;63.760(a) may be used. For natural gas transmission and storage facilities subject to subpart HHH of this part, the maximum annual facility gas throughput for storage facilities may be determined according to &sect;63.1270(a)(1) and the maximum annual throughput for transmission facilities may be determined according to &sect;63.1270(a)(2).
Production field facility means those oil and gas production facilities located prior to the point of custody transfer.Production well means any hole drilled in the earth from which crude oil, condensate, or field natural gas is extracted.
Productionfield facility means those oil and gas production facilities located prior to the point of custody transfer.
Propane means a colorless gas derived from petroleum and natural gas, with the molecular structure C 3 H 8.Responsible official means responsible official as defined in 40 CFR 70.2.Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to December 19, 2002 with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich burn engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent.Site-rated HP means the maximum manufacturer's design capacity at engine site conditions.
Productionwell means any hole drilled in the earth from which crude oil, condensate, or field natural gas is extracted.
Spark ignition means relating to either: A gasoline-fueled engine; or any other type of engine a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation.
Propanemeans a colorless gas derived from petroleum and natural gas, with the molecular structure C3H 8 .
Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.Stationary reciprocating internal combustion engine (RICE) means any reciprocating internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition.
Responsible official means responsible official as defined in 40 CFR 70.2.
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-16 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Stationary RICE test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that tests stationary RICE.Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion.
Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to December 19, 2002 with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich burn engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent.
Storage vessel with the potential for flash emissions means any storage vessel that contains a hydrocarbon liquid with a stock tank gas-to-oil ratio equal to or greater than 0.31 cubic meters per liter and an American Petroleum Institute gravity equal to or greater than 40 degrees and an actual annual average hydrocarbon liquid throughput equal to or greater than 79,500 liters per day. Flash emissions occur when dissolved hydrocarbons in the fluid evolve from solution when the fluid pressure is reduced.Subpart means 40 CFR part 63, subpart ZZZZ.Surface site means any combination of one or more graded pad sites, gravel pad sites, foundations, platforms, or the immediate physical location upon which equipment is physically affixed.Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric.
Site-ratedHP means the maximum manufacturer's design capacity at engine site conditions.
[69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3607, Jan. 18, 2008]Tablelato Subpart ZZZZ of Part 63-Emission Limitations for Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HP Located at a Major Source of HAP Emissions[As stated in &sect;63.6600, you must comply with the following emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions at 100 percent load plus or minus 10 percent]For each... You must meet the following emission limitations...
Spark ignition means relating to either: A gasoline-fueled engine; or any other type of engine a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines.
: 1. 4SRB a. reduce formaldehyde emissions by 76 percent or more. If you commenced construction or reconstruction stationary RICE between December 19, 2002 and June 15, 2004, you may reduce formaldehyde emissions by 75 percent or more until June 15, 2007;or b. limit the concentration of formaldehyde in the stationary RICE exhaust 350 ppbvd or less at 15 percent 02.[73 FR 3607, Jan. 18, 2008]Tablelbto Subpart ZZZZ of Part 63-Operating Limitations for Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HP Located at a Major Source of HAP Emissions[As stated in &sect;&sect;63.6600, 63.6630 and 63.6640, you must comply with the following operating emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions]
Stationary reciprocatinginternal combustion engine (RICE) means any reciprocating internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition.
__For each... F You must meet the following operating limitation...
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page NESHAPZ-16 of 29
: 1. 4SRB stationary RICE complying with the a. maintain your catalyst so that the pressure drop across the catalyst requirement to reduce formaldehyde emissions by 76 does not change by more than 2 inches of water at 100 percent load percent or more (or by 75 percent or more, if plus or minus 10 percent from the pressure drop across the catalyst applicable) and using NSCR; measured during the initial performance test; and Por 4SRB stationary RICE complying with the b. maintain the temperature of your stationary RICE exhaust so that requirement to limit the concentration of the catalyst inlet temperature is greater than or equal to 750 'F and formaldehyde in the stationary RICE exhaust to 350 less than or equal to 1250 'F.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-17 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines ippbvd or less at 15 percent O 2 and using NSCR.2. 4SRB stationary RICE complying with the Comply with any operating limitations approved by the requirement to reduce formaldehyde emissions by 76 Administrator.
 
percent or more (or by 75 percent or more, if applicable) and not using NSCR;or 4SRB stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust to 350 ppbvd or less at 15 percent O 2 and not using NSCR.[73 FR 3607, Jan. 18, 2008]Table2ato Subpart ZZZZ of Part 63-Emission Limitations for New and Reconstructed 2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB Stationary RICE >_250 HP Located at a Major Source of HAP Emissions[As stated in &sect;&sect;63.6600 and 63.6601, you must comply with the following emission limitations for new and reconstructed lean bum and new and reconstructed compression ignition stationary RICE at 100 percent load plus or minus 10 percent]For each... You must meet the following emission limitation...
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Stationary RICE test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that tests stationary RICE.
: 1. 2SLB a. reduce CO emissions by 58 percent or more;stationary RICE or b. limit concentration of formaldehyde in the stationary RICE exhaust to 12 ppmvd or less at 15 percent 02. If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004, you may limit concentration of formaldehyde to 17 ppmvd or less at 15 percent O 2 until June 15, 2007.2. 4SLB a. reduce CO emissions by 93 percent or more;stationary RICE or b. limit concentration of formaldehyde in the stationary RICE exhaust to 14 ppmvd or less at 15 percent 02.3. CI a. reduce CO emissions by 70 percent or more;stationary RICE or b. limit concentration of formaldehyde in the stationary RICE exhaust to 580 ppbvd or less at 15 percent 02.[73 FR 3608, Jan. 18, 2008]Table2bto Subpart ZZZZ of Part 63-Operating Limitations for New and Reconstructed 2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB Burn Stationary RICE >_250 HP Located at a Major Source of HAP Emissions[As stated in &sect;&sect;63.6600, 63.6601, 63.6630, and 63.6640, you must comply with the following operating limitations for new and reconstructed lean burn and new and reconstructed compression ignition stationary]
Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion.
I For each... You must meet the following operating limitation...
Storage vessel with the potentialfor flash emissions means any storage vessel that contains a hydrocarbon liquid with a stock tank gas-to-oil ratio equal to or greater than 0.31 cubic meters per liter and an American Petroleum Institute gravity equal to or greater than 40 degrees and an actual annual average hydrocarbon liquid throughput equal to or greater than 79,500 liters per day. Flash emissions occur when dissolved hydrocarbons in the fluid evolve from solution when the fluid pressure is reduced.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-18 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 1. 2SLB and 4SLB stationary RICE and CI stationary RICE a. maintain your catalyst so that the pressure drop complying with the requirement to reduce CO emissions and using an across the catalyst does not change by more than 2 oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI inches of water at 100 percent load plus or minus 10 stationary RICE complying with the requirement to limit the percent from the pressure drop across the catalyst that concentration of formaldehyde in the stationary RICE exhaust and was measured during the initial performance test; and using an oxidation catalyst b. maintain the temperature of your stationary RICE exhaust so that the catalyst inlet temperature is greater than or equal to 450 OF and less than or equal to 1350 OF.2. 2SLB and 4SLB stationary RICE and CI stationary RICE Comply with any operating limitations approved by complying with the requirement to reduce CO emissions and not the Administrator.
Subpart means 40 CFR part 63, subpart ZZZZ.
using an oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust and not using an oxidation catalyst[73 FR 3608, Jan. 18, 2008]Table 3 to Subpart ZZZZ of Part 63-Subsequent Performance Tests[As stated in &sect;&sect;63.6615 and 63.6620, you must comply with the following subsequent performance test requirements]
Surface site means any combination of one or more graded pad sites, gravel pad sites, foundations, platforms, or the immediate physical location upon which equipment is physically affixed.
For each... Complying with the requirement to... You must...1. 2SLB and 4SLB stationary RICE and CI Reduce CO emissions and not using a Conduct subsequent performance stationary RICE CEMS tests semiannually.'
Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric.
: 2. 4SRB stationary RICE with a brake Reduce formaldehyde emissions Conduct subsequent performance horsepower  
[69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3607, Jan. 18, 2008]
>5,000 tests semiannually.'
Tablelato SubpartZZZZ of Part63-Emission Limitationsfor Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HP Located at a Major Source of HAP Emissions
: 3. Stationary RICE (all stationary RICE Limit the concentration of formaldehyde Conduct subsequent performance subcategories and all brake horsepower ratings) in the stationary RICE exhaust tests semiannually.'
[As stated in &sect;63.6600, you must comply with the following emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions at 100 percent load plus or minus 10 percent]
'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually.
For each...                                 You must meet the following emission limitations...
If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests.Table 4 to Subpart ZZZZ of Part 63-Requirements for Performance Tests[As stated in &sect;&sect;63.6610, 63.6611, 63.6620, and 63.6640, you must comply with the following requirements for performance tests for stationary RICE]Complying with For each., the requirement According to the following too... You must... Using... requirements...
: 1. 4SRB           a. reduce formaldehyde emissions by 76 percent or more. If you commenced construction or reconstruction stationary RICE between December 19, 2002 and June 15, 2004, you may reduce formaldehyde emissions by 75 percent or more until June 15, 2007; or
: 1. 2SLB, a. Reduce CO i. Measure the O 2 at (1) Portable CO and O 2 analyzer (a) Using ASTM D6522-00 4SLB, and emissions the inlet and outlet of (2005)a(incorporated by reference, CI the control device; see &sect;63.14). Measurements to stationary and determine 02 must be made at the RICE same time as the measurements for CO concentration.
: b. limit the concentration of formaldehyde in the stationary RICE exhaust 350 ppbvd or less at 15 percent 02.
ii. Measure the CO at (1) Portable CO and O 2 analyzer (a) Using ASTM D6522-00 the inlet and the (2005)a(incorporated by reference, Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-19 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines outlet of the control see &sect;63.14) or Method 10 of 40 device CFR, appendix A. The CO concentration must be at 15 percent 02, dry basis.2. 4SRB a. Reduce i. Select the sampling (1) Method 1 or 1A of 40 CFR (a) Sampling sites must be located stationary formaldehyde port location and the part 60, appendix A at the inlet and outlet of the control RICE emissions number of traverse &sect;63.7(d)(1)(i) device.points; and ii. Measure 02 at the (1) Method 3 or 3A or 3B of 40 (a) Measurements to determine 02 inlet and outlet of the CFR part 60, appendix A, or concentration must be made at the control device; and ASTM Method D6522-00 same time as the measurements for (2005). formaldehyde concentration.
[73 FR 3607, Jan. 18, 2008]
iii. Measure moisture (1) Method 4 of 40 CFR part 60, (a) Measurements to determine content at the inlet appendix A, or Test Method 320 moisture content must be made at and outlet of the of 40 CFR part 63, appendix A, the same time and location as the control device; and or ASTM D 6348-03 measurements for formaldehyde concentration.
Tablelbto SubpartZZZZ of Part 63-OperatingLimitationsfor Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HPLocated at a Major Source of HAP Emissions
iv. Measure (1) Method 320 or 323 of 40 (a) Formaldehyde concentration formaldehyde at the CFR part 63, appendix A; or must be at 15 percent 02, dry inlet and the outlet of ASTM D6348-03b, provided in basis. Results of this test consist of the control device ASTM D6348-03 Annex A5 the average of the three 1-hour or (Analyte Spiking Technique), longer runs.the percent R must be greater than or equal to 70 and less than or equal to 130 3. Stationary  
[As stated in &sect;&sect;63.6600, 63.6630 and 63.6640, you must comply with the following operating emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions]
: a. Limit the i. Select the sampling (1) Method 1 or 1A of 40 CFR (a) If using a control device, the RICE concentration of port location and the part 60, appendix A sampling site must be located at formaldehyde in number of traverse &sect;63.7(d)(1)(i) the outlet of the control device.the stationary points; and RICE exhaust ii. Determine the 02 (1) Method 3 or 3A or 3B of 40 (a) Measurements to determine 02 concentration of the CFR part 60, appendix A, or concentration must be made at the stationary RICE ASTM Method D6522-00 same time and location as the exhaust at the (2005) measurements for formaldehyde sampling port concentration.
__For                     each...                     F       You must meet the following operating limitation...
location; and iii. Measure moisture (1) Method 4 of 40 CFR part 60, (a) Measurements to determine content of the appendix A, or Test Method 320 moisture content must be made at stationary RICE of 40 CFR part 63, appendix A, the same time and location as the exhaust at the or ASTM D 6348-03 measurements for formaldehyde sampling port concentration.
: 1. 4SRB stationary RICE complying with the               a. maintain your catalyst so that the pressure drop across the catalyst requirement to reduce formaldehyde emissions by 76       does not change by more than 2 inches of water at 100 percent load percent or more (or by 75 percent or more, if             plus or minus 10 percent from the pressure drop across the catalyst applicable) and using NSCR;                               measured during the initial performance test; and Por 4SRB stationary RICE complying with the                   b. maintain the temperature of your stationary RICE exhaust so that requirement to limit the concentration of                 the catalyst inlet temperature is greater than or equal to 750 'F and formaldehyde in the stationary RICE exhaust to 350       less than or equal to 1250 'F.
location; and iv. Measure (1) Method 320 or 323 of 40 (a) Formaldehyde concentration formaldehyde at the CFR part 63, appendix A; or must be at 15 percent 02, dry exhaust of the ASTM D6348-03b, provided in basis. Results of this test consist of stationary RICE ASTM D6348-03 Annex A5 the average of the three 1-hour or (Analyte Spiking Technique), longer runs.the percent R must be greater than or equal to 70 and less than Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-20 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines..11 ..Lor equal to 130 aYoU may also use Methods 3A and 10 as options to ASTM-D6522-00 (2005). You may obtain a copy of ASTM-D6522-00 (2005) from at least one of the following addresses:
Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPZ-17 of 29
American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106.byou may obtain a copy of ASTM-D6348-03 from at least one of the following addresses:
 
American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106.[73 FR 3609, Jan. 18, 2008]Table 5 to Subpart ZZZZ of Part 63-Initial Compliance With Emission Limitations and Operating Limitations
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines ippbvd or less at 15 percent O 2and using NSCR.
: 2. 4SRB stationary RICE complying with the               Comply with any operating limitations approved by the requirement to reduce formaldehyde emissions by 76       Administrator.
percent or more (or by 75 percent or more, if applicable) and not using NSCR; or 4SRB stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust to 350 ppbvd or less at 15 percent O 2and not using NSCR.
[73 FR 3607, Jan. 18, 2008]
Table2ato Subpart ZZZZ of Part63-Emission Limitationsfor New and Reconstructed2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB StationaryRICE >_250 HP Located at a Major Source of HAP Emissions
[As stated in &sect;&sect;63.6600 and 63.6601, you must comply with the following emission limitations for new and reconstructed lean bum and new and reconstructed compression ignition stationary RICE at 100 percent load plus or minus 10 percent]
For each...                                 You must meet the following emission limitation...
: 1. 2SLB         a. reduce CO emissions by 58 percent or more; stationary RICE or
: b. limit concentration of formaldehyde in the stationary RICE exhaust to 12 ppmvd or less at 15 percent 02. If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004, you may limit concentration of formaldehyde to 17 ppmvd or less at 15 percent O 2 until June 15, 2007.
: 2. 4SLB         a. reduce CO emissions by 93 percent or more; stationary RICE or
: b. limit concentration of formaldehyde in the stationary RICE exhaust to 14 ppmvd or less at 15 percent 02.
: 3. CI           a. reduce CO emissions by 70 percent or more; stationary RICE or
: b. limit concentration of formaldehyde in the stationary RICE exhaust to 580 ppbvd or less at 15 percent 02.
[73 FR 3608, Jan. 18, 2008]
Table2bto Subpart ZZZZ of Part63-OperatingLimitationsfor New and Reconstructed2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB Burn StationaryRICE >_250 HP Located at a Major Source of HAP Emissions
[As stated in &sect;&sect;63.6600, 63.6601, 63.6630, and 63.6640, you must comply with the following operating limitations for new and reconstructed lean burn and new and reconstructed compression ignition stationary]
I                               For each...                               You must meet the following operating limitation...
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                              Title V Permit Renewal Page NESHAPZ-18 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
: 1. 2SLB and 4SLB stationary RICE and CI stationary RICE                   a. maintain your catalyst so that the pressure drop complying with the requirement to reduce CO emissions and using an across the catalyst does not change by more than 2 oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI               inches of water at 100 percent load plus or minus 10 stationary RICE complying with the requirement to limit the               percent from the pressure drop across the catalyst that concentration of formaldehyde in the stationary RICE exhaust and           was measured during the initial performance test; and using an oxidation catalyst                                               b. maintain the temperature of your stationary RICE exhaust so that the catalyst inlet temperature is greater than or equal to 450 OF and less than or equal to 1350 OF.
: 2. 2SLB and 4SLB stationary RICE and CI stationary RICE                   Comply with any operating limitations approved by complying with the requirement to reduce CO emissions and not             the Administrator.
using an oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust and not using an oxidation catalyst
[73 FR 3608, Jan. 18, 2008]
Table 3 to SubpartZZZZ of Part63-Subsequent PerformanceTests
[As stated in &sect;&sect;63.6615 and 63.6620, you must comply with the following subsequent performance test requirements]
For each...                     Complying with the requirement to...                   You must...
: 1. 2SLB and 4SLB stationary RICE and CI             Reduce CO emissions and not using a         Conduct subsequent performance stationary RICE                                     CEMS                                         tests semiannually.'
: 2. 4SRB stationary RICE with a brake               Reduce formaldehyde emissions               Conduct subsequent performance horsepower >5,000                                                                               tests semiannually.'
: 3. Stationary RICE (all stationary RICE             Limit the concentration of formaldehyde Conduct subsequent performance subcategories and all brake horsepower ratings)     in the stationary RICE exhaust               tests semiannually.'
'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests.
Table 4 to SubpartZZZZ of Part 63-Requirementsfor PerformanceTests
[As stated in &sect;&sect;63.6610, 63.6611, 63.6620, and 63.6640, you must comply with the following requirements for performance tests for stationary RICE]
Complying with For each.,     the requirement                                                                   According to the following too...           You must...                       Using...                       requirements...
: 1. 2SLB,       a. Reduce CO       i. Measure the O2 at (1) Portable CO and O 2analyzer        (a) Using ASTM D6522-00 4SLB, and     emissions           the inlet and outlet of                                     (2005)a(incorporated by reference, CI                                 the control device;                                         see &sect;63.14). Measurements to stationary                         and                                                         determine 02 must be made at the RICE                                                                                           same time as the measurements for CO concentration.
ii. Measure the CO at (1) Portable CO and O 2analyzer      (a) Using ASTM D6522-00 the inlet and the                                           (2005)a(incorporated by reference, Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPZ-19 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines outlet of the control                                     see &sect;63.14) or Method 10 of 40 device                                                   CFR, appendix A. The CO concentration must be at 15 percent 02, dry basis.
: 2. 4SRB       a. Reduce         i. Select the sampling (1) Method 1 or 1A of 40 CFR       (a) Sampling sites must be located stationary   formaldehyde     port location and the part 60, appendix A                 at the inlet and outlet of the control RICE         emissions         number of traverse     &sect;63.7(d)(1)(i)                   device.
points; and ii. Measure 02 at the (1) Method 3 or 3A or 3B of 40     (a) Measurements to determine 02 inlet and outlet of the CFR part 60, appendix A, or       concentration must be made at the control device; and     ASTM Method D6522-00             same time as the measurements for (2005).                           formaldehyde concentration.
iii. Measure moisture   (1) Method 4 of 40 CFR part 60,   (a) Measurements to determine content at the inlet   appendix A, or Test Method 320   moisture content must be made at and outlet of the       of 40 CFR part 63, appendix A,   the same time and location as the control device; and     or ASTM D 6348-03                 measurements for formaldehyde concentration.
iv. Measure             (1) Method 320 or 323 of 40       (a) Formaldehyde concentration formaldehyde at the     CFR part 63, appendix A; or       must be at 15 percent 02, dry inlet and the outlet of ASTM D6348-03b, provided in       basis. Results of this test consist of the control device     ASTM D6348-03 Annex A5           the average of the three 1-hour or (Analyte Spiking Technique),     longer runs.
the percent R must be greater than or equal to 70 and less than or equal to 130
: 3. Stationary a. Limit the     i. Select the sampling (1) Method 1 or 1A of 40 CFR       (a) If using a control device, the RICE         concentration of port location and the part 60, appendix A                 sampling site must be located at formaldehyde in   number of traverse     &sect;63.7(d)(1)(i)                   the outlet of the control device.
the stationary   points; and RICE exhaust ii. Determine the 02   (1) Method 3 or 3A or 3B of 40   (a) Measurements to determine 02 concentration of the   CFR part 60, appendix A, or       concentration must be made at the stationary RICE         ASTM Method D6522-00             same time and location as the exhaust at the         (2005)                           measurements for formaldehyde sampling port                                             concentration.
location; and iii. Measure moisture   (1) Method 4 of 40 CFR part 60,   (a) Measurements to determine content of the         appendix A, or Test Method 320   moisture content must be made at stationary RICE         of 40 CFR part 63, appendix A,   the same time and location as the exhaust at the         or ASTM D 6348-03                 measurements for formaldehyde sampling port                                             concentration.
location; and iv. Measure             (1) Method 320 or 323 of 40       (a) Formaldehyde concentration formaldehyde at the     CFR part 63, appendix A; or       must be at 15 percent 02, dry exhaust of the         ASTM D6348-03b, provided in       basis. Results of this test consist of stationary RICE         ASTM D6348-03 Annex A5           the average of the three 1-hour or (Analyte Spiking Technique),     longer runs.
the percent R must be greater than or equal to 70 and less than Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                              Title V Permit Renewal Page NESHAPZ-20 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
                    .       .     11
                                    .   .Lor                 equal to 130 aYoU may also use Methods 3A and 10 as options to ASTM-D6522-00 (2005). You may obtain a copy of ASTM-D6522-00 (2005) from at least one of the following addresses: American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106.
byou may obtain a copy of ASTM-D6348-03 from at least one of the following addresses: American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106.
[73 FR 3609, Jan. 18, 2008]
Table 5 to Subpart ZZZZ of Part 63-InitialCompliance With Emission Limitations and OperatingLimitations
[As stated in &sect;&sect;63.6625 and 63.6630, you must initially comply with the emission and operating limitations as required by the following]
[As stated in &sect;&sect;63.6625 and 63.6630, you must initially comply with the emission and operating limitations as required by the following]
Complying with the For each ... requirement to... You have demonstrated initial compliance if...1. 2SLB and 4SLB a. Reduce CO emissions and i. the average reduction of emissions of CO determined from the stationary RICE using oxidation catalyst, and using initial performance test achieves the required CO percent reduction; and CI stationary a CPMS and RICE ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b);
Complying with the For each ...             requirement to...                     You have demonstrated initial compliance if...
and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.2. 2SLB and 4SLB a. Reduce CO emissions and not i. The average reduction of emissions of CO determined from the stationary RICE using oxidation catalyst initial performance test achieves the required CO percent reduction; and CI stationary and RICE ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b);
: 1. 2SLB and 4SLB a. Reduce CO emissions and               i. the average reduction of emissions of CO determined from the stationary RICE       using oxidation catalyst, and using initial performance test achieves the required CO percent reduction; and CI stationary     a CPMS                             and RICE ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.
and iii. You have recorded the approved operating parameters (if any)during the initial performance test.3. 2SLB and 4SLB a. Reduce CO emissions, and i. You have installed a CEMS to continuously monitor CO and either stationary RICE using a CEMS O 2 or CO 2 at both the inlet and outlet of the oxidation catalyst and CI stationary according to the requirements in &sect;63.6625(a);
: 2. 2SLB and 4SLB a. Reduce CO emissions and not           i. The average reduction of emissions of CO determined from the stationary RICE       using oxidation catalyst           initial performance test achieves the required CO percent reduction; and CI stationary                                         and RICE ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.
and RICE ii. You have conducted a performance evaluation of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B; and iii. The average reduction of CO calculated using &sect;63.6620 equals or exceeds the required percent reduction.
: 3. 2SLB and 4SLB a. Reduce CO emissions, and             i. You have installed a CEMS to continuously monitor CO and either stationary RICE       using a CEMS                       O 2or CO 2 at both the inlet and outlet of the oxidation catalyst and CI stationary                                         according to the requirements in &sect;63.6625(a); and RICE ii. You have conducted a performance evaluation of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B; and iii. The average reduction of CO calculated using &sect;63.6620 equals or exceeds the required percent reduction. The initial test comprises the first 4-hour period after successful validation of the CEMS.
The initial test comprises the first 4-hour period after successful validation of the CEMS.Compliance is based on the average percent reduction achieved during the 4-hour period.4. 4SRB stationary  
Compliance is based on the average percent reduction achieved during the 4-hour period.
: a. Reduce formaldehyde  
: 4. 4SRB stationary a. Reduce formaldehyde                 i. The average reduction of emissions of formaldehyde determined RICE                 emissions and using NSCR           from the initial performance test is equal to or greater than the Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPZ-21 of 29
: i. The average reduction of emissions of formaldehyde determined RICE emissions and using NSCR from the initial performance test is equal to or greater than the Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-21 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b);
 
and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.5. 4SRB stationary  
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.
: a. Reduce formaldehyde  
: 5. 4SRB stationary a. Reduce formaldehyde                 i. The average reduction of emissions of formaldehyde determined RICE                 emissions and not using NSCR       from the initial performance test is equal to or greater than the required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.
: i. The average reduction of emissions of formaldehyde determined RICE emissions and not using NSCR from the initial performance test is equal to or greater than the required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b);
: 5. Stationary RICE a. Limit the concentration of         i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary     02, dry basis, from the three test runs is less than or equal to the RICE exhaust and using oxidation formaldehyde emission limitation; and catalyst or NSCR ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.
and iii. You have recorded the approved operating parameters (if any)during the initial performance test.5. Stationary RICE a. Limit the concentration of i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary 02, dry basis, from the three test runs is less than or equal to the RICE exhaust and using oxidation formaldehyde emission limitation; and catalyst or NSCR ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in &sect;63.6625(b);
: 7. Stationary RICE a. Limit the concentration of         i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary     02, dry basis, from the three test runs is less than or equal to the RICE exhaust and not using         formaldehyde emission limitation; and oxidation catalyst or NSCR ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.
and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.7. Stationary RICE a. Limit the concentration of i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary 02, dry basis, from the three test runs is less than or equal to the RICE exhaust and not using formaldehyde emission limitation; and oxidation catalyst or NSCR ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in &sect;63.6625(b);
Table 6 to SubpartZZZZ of Part63-Continuous Compliance With Emission Limitations and OperatingLimitations
and iii. You have recorded the approved operating parameters (if any)during the initial performance test.Table 6 to Subpart ZZZZ of Part 63-Continuous Compliance With Emission Limitations and Operating Limitations
[As stated in &sect;63.6640, you must continuously comply with the emissions and operating limitations as required by the following]
[As stated in &sect;63.6640, you must continuously comply with the emissions and operating limitations as required by the following]
Complying with the requirement to For each ... o.n .i You must demonstrate continuous compliance by...1. 2SLB and 4SLB a. Reduce CO emissions and using an i. Conducting semiannual performance tests for CO to stationary RICE and oxidation catalyst, and using a CPMS demonstrate that the required CO percent reduction is CI stationary RICE achieved';
Complying with the requirement to For each ...         o.n         i    .                         You must demonstrate continuous compliance by...
and ii. Collecting the catalyst inlet temperature data according to F__ 1&sect;63.6625(b);
: 1. 2SLB and 4SLB         a. Reduce CO emissions and using an i. Conducting semiannual performance tests for CO to stationary RICE and       oxidation catalyst, and using a CPMS demonstrate that the required CO percent reduction is CI stationary RICE                                                 achieved'; and ii. Collecting the catalyst inlet temperature data according to F__                                     1&sect;63.6625(b); and
and_ _iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-22 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 1operating limitations for the catalyst inlet temperature; and v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.2. 2SLB and 4SLB a. Reduce CO emissions and not i. Conducting semiannual performance tests for CO to stationary RICE and using an oxidation catalyst, and using demonstrate that the required CO percent reduction is CI stationary RICE a CPMS achieved 1; and ii. Collecting the approved operating parameter (if any) data__according to &sect;63.6625(b);
_ _iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Permit Renewal Page NESHAPZ-22 of 29
and__iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.3. 2SLB and 4SLB a. Reduce CO emissions and using a i. Collecting the monitoring data according to &sect;63.6625(a), stationary RICE and CEMS reducing the measurements to 1-hour averages, calculating CI stationary RICE the percent reduction of CO emissions according to &sect;63.6620;and ii. Demonstrating that the catalyst achieves the required percent reduction of CO emissions over the 4-hour averaging period; and iii. Conducting an annual RATA of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B, as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1.4. 4SRB stationary  
 
: a. Reduce formaldehyde emissions  
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 1operating limitations for the catalyst inlet temperature; and
[. Collecting the catalyst inlet temperature data according to RICE and using NSCR &sect;63.6625(b);
: v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.
and_ _ii. Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; and iv. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.5. 4SRB stationary  
: 2. 2SLB and 4SLB       a. Reduce CO emissions and not         i. Conducting semiannual performance tests for CO to stationary RICE and     using an oxidation catalyst, and using demonstrate that the required CO percent reduction is CI stationary RICE     a CPMS                                 achieved 1 ; and ii. Collecting the approved operating parameter (if any) data
: a. Reduce formaldehyde emissions  
__according to &sect;63.6625(b); and
: i. Collecting the approved operating parameter (if any) data RICE and not using NSCR according to &sect;63.6625(b);
__iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.
and[ii. reducing these data to 4-hour rolling averages;iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.5. 4SRB stationary Reduce formaldehyde emissions Conducting semiannual performance tests for formaldehyde RICE with a brake to demonstrate that the required formaldehyde percent horsepower  
: 3. 2SLB and 4SLB       a. Reduce CO emissions and using a       i. Collecting the monitoring data according to &sect;63.6625(a),
>5,000 reduction is achieved'.
stationary RICE and   CEMS                                     reducing the measurements to 1-hour averages, calculating CI stationary RICE                                             the percent reduction of CO emissions according to &sect;63.6620; and ii. Demonstrating that the catalyst achieves the required percent reduction of CO emissions over the 4-hour averaging period; and iii. Conducting an annual RATA of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B, as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-23 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 7. Stationary RICE Limit the concentration of i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE to demonstrate that your emissions remain at or below the exhaust and using oxidation catalyst formaldehyde concentration limit'; and or NSCR! ii. Collecting the catalyst inlet temperature data according to&sect;63.6625(b);
: 4. 4SRB stationary     a. Reduce formaldehyde emissions       [.Collecting the catalyst inlet temperature data according to RICE                   and using NSCR                           &sect;63.6625(b); and
and F_ __iii. Reducing these data to 4-hour rolling averages; and ivg.Maintaining the 4-hour rolling averages within the_operating limitations for the catalyst inlet temperature; and v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.8. Stationary RICE Limit the concentration of i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE to demonstrate that your emissions remain at or below the exhaust and not using oxidation formaldehyde concentration limit'; and catalyst or NSCR ii. Collecting the approved operating parameter (if any) data Iaccording to &sect;63.6625(b);
_ _ii. Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; and iv. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.
and__ _ii. Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually.
: 5. 4SRB stationary     a. Reduce formaldehyde emissions         i. Collecting the approved operating parameter (if any) data RICE                   and not using NSCR                       according to &sect;63.6625(b); and
If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests.Table 7 to Subpart ZZZZ of Part 63-Requirements for Reports[As stated in &sect;63.6650, you must comply with the following requirements for reports]You must submit the report..You must submit a(n) The report must contain...
[ii. reducing these data to 4-hour rolling averages; iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.
: 1. Compliance report a. If there are no deviations from any emission limitations  
: 5. 4SRB stationary     Reduce formaldehyde emissions           Conducting semiannual performance tests for formaldehyde RICE with a brake                                             to demonstrate that the required formaldehyde percent horsepower >5,000                                             reduction is achieved'.
: i. Semiannually according to the or operating limitations that apply to you, a statement that requirements in &sect;63.6650(b).
Progress Energy Florida, Inc.                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                                Title V Permit Renewal Page NESHAPZ-23 of 29
there were no deviations from the emission limitations or operating limitations during the reporting period. If there were no periods during which the CMS, including CEMS and CPMS, was out-of-control, as specified in&sect;63.8(c)(7), a statement that there were not periods during which the CMS was out-of-control during the reporting period; or b. If you had a deviation from any emission limitation or i. Semiannually according to the operating limitation during the reporting period, the requirements in &sect;63.6650(b).
 
information in &sect;63.6650(d).
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
If there were periods during which the CMS, including CEMS and CPMS, was out-of-Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-24 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines-ontrol, as specified in &sect;63.8(c)(7), the information in&sect;63.6650(e);
: 7. Stationary RICE       Limit the concentration of               i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE       to demonstrate that your emissions remain at or below the exhaust and using oxidation catalyst     formaldehyde concentration limit ' ; and
or c. If you had a startup, shutdown or malfunction during i. Semiannually according to the the reporting period, the information in &sect;63.10(d)(5)(i) requirements in &sect;63.6650(b).
                                                                  !
: 2. An immediate startup, a. Actions taken for the event; and i. By fax or telephone within 2 shutdown, and malfunction report working days after starting if actions addressing the startup, actions inconsistent with the shutdown, or malfunction were plan.inconsistent with your startup, shutdown, or malfunction plan during the reporting period b. The information in &sect;63.10(d)(5)(ii).  
or NSCR ii. Collecting the catalyst inlet temperature data according to
: i. By letter within 7 working days after the end of the event unless you have made alternative arrangements with the permitting authorities.
                                                                    &sect;63.6625(b); and
__iii.
F_                                              Reducing these data to 4-hour rolling averages; and ivg.Maintaining the 4-hour rolling averages within the
_operating  limitations for the catalyst inlet temperature; and
: v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.
: 8. Stationary RICE       Limit the concentration of               i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE       to demonstrate that your emissions remain at or below the exhaust and not using oxidation           formaldehyde concentration limit'; and Iaccording catalyst or NSCR ii. Collecting the approved operating parameter (if any) data to &sect;63.6625(b); and
___ii.                                         Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.
'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests.
Table 7 to Subpart ZZZZ of Part 63-Requirementsfor Reports
[As stated in &sect;63.6650, you must comply with the following requirements for reports]
You must submit the report..
You must submit a(n)                         The report must contain...
: 1. Compliance report               a. If there are no deviations from any emission limitations i. Semiannually according to the or operating limitations that apply to you, a statement that requirements in &sect;63.6650(b).
there were no deviations from the emission limitations or operating limitations during the reporting period. If there were no periods during which the CMS, including CEMS and CPMS, was out-of-control, as specified in
                                    &sect;63.8(c)(7), a statement that there were not periods during which the CMS was out-of-control during the reporting period; or
: b. If you had a deviation from any emission limitation or i. Semiannually according to the operating limitation during the reporting period, the           requirements in &sect;63.6650(b).
information in &sect;63.6650(d). If there were periods during which the CMS, including CEMS and CPMS, was out-of-Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                    Title V Permit Renewal Page NESHAPZ-24 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
                                        -ontrol, as specified in &sect;63.8(c)(7), the information in
                                        &sect;63.6650(e); or
: c. If you had a startup, shutdown or malfunction during       i. Semiannually according to the the reporting period, the information in &sect;63.10(d)(5)(i)     requirements in &sect;63.6650(b).
: 2. An immediate startup,               a. Actions taken for the event; and                           i. By fax or telephone within 2 shutdown, and malfunction report                                                                     working days after starting if actions addressing the startup,                                                                   actions inconsistent with the shutdown, or malfunction were                                                                       plan.
inconsistent with your startup, shutdown, or malfunction plan during the reporting period
: b. The information in &sect;63.10(d)(5)(ii).                       i. By letter within 7 working days after the end of the event unless you have made alternative arrangements with the permitting authorities.
(&sect;63.10(d)(5)(ii))
(&sect;63.10(d)(5)(ii))
: 3. Report a. The fuel flow rate of each fuel and the heating values i. Annually, according to the that were used in your calculations, and you must requirements in &sect;63.6650.demonstrate that the percentage of heat input provided by landfill gas or digester gas, is equivalent to 10 percent or more of the gross heat input on an annual basis; and b. The operating limits provided in your federally  
: 3. Report                             a. The fuel flow rate of each fuel and the heating values i. Annually, according to the that were used in your calculations, and you must             requirements in &sect;63.6650.
: i. See item 3.a.i.enforceable permit, and any deviations from these limits;and c. Any problems or errors suspected with the meters i. See item 3.a.i.Table 8 to Subpart ZZZZ of Part 63-Applicability of General Provisions to Subpart ZZZZ[As stated in &sect;63.6665, you must comply with the following applicable general provisions]
demonstrate that the percentage of heat input provided by landfill gas or digester gas, is equivalent to 10 percent or more of the gross heat input on an annual basis; and
General provisions Applies to citation Subject of citation subpart Explanation
: b. The operating limits provided in your federally           i. See item 3.a.i.
&sect;63.1General applicability of the General Yes&sect;63.1 -Provisions
enforceable permit, and any deviations from these limits; and
&sect;63.2 [Definitions Yes Additional terms defined in &sect;63.6675.&sect;63.3 Units and abbreviations Yes&sect;63.4 Prohibited activities and circumvention Yes&sect;63.5 Construction and reconstruction Yes_&sect;63.6(a)
: c. Any problems or errors suspected with the meters           i. See item 3.a.i.
_Applicability 1[Yes 11&sect;63.6(b)(1)-(4)
Table 8 to SubpartZZZZ of Part 63-Applicability of GeneralProvisions to Subpart ZZZZ
Compliance dates for new and I _ _ reconstructed sources&sect;63.6(b)(5)
[As stated in &sect;63.6665, you must comply with the following applicable general provisions]
Notification Yes&sect;63.6(b)(6)  
General provisions                                                   Applies to citation                   Subject of citation               subpart                       Explanation
[Reserved]
&sect;63.1General
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-25 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines&sect;63.6(b)(7)
        &sect;63.1     -             applicability of the General Provisions                                 Yes
Compliance dates for new and Yes reconstructed area sources that become major sourcesn&sect;63.6(c)(1)-(2)
&sect;63.2                   [Definitions                                 Yes         Additional terms defined in &sect;63.6675.
Compliance dates for existing sources Yes&sect;63.6(c)(3)-(4)  
&sect;63.3                   Units and abbreviations                     Yes
[Reserved]
&sect;63.4                   Prohibited activities and circumvention     Yes
F&sect;36.6(c)(5)
&sect;63.5                   Construction and reconstruction             Yes
Compliance dates for existing area Yes Isources that become major sources 1&sect;63.6(d)
_&sect;63.6(a)
I[Reserved]
_Applicability                                                   1[Yes         11
F&sect;63.6(e)(1)  
&sect;63.6(b)(1)-(4)         Compliance dates for new and I       _       _       reconstructed sources
]Operation and maintenance Yes&sect;63.6(e)(2)  
&sect;63.6(b)(5)             Notification                                 Yes
][[Reserved]
&sect;63.6(b)(6)             [Reserved]
&sect;63.6(e)(3) 1 Startup, shutdown, and malfunction plan&sect;63.6(f)(1)
Progress Energy Florida, Inc.                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                      Title V Permit Renewal Page NESHAPZ-25 of 29
Applicability of standards except Yes during startup shutdown malfunction (SSM)[&sect;63.6(f)(2)  
 
[Methods for determining compliance Yes[&sect;63.6(f)(3)  
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
]Finding of compliance Yes F[&sect;63.6(g)(1)-(3)  
&sect;63.6(b)(7)           Compliance dates for new and           Yes reconstructed area sources that become major sourcesn
][Use of alternate standard Yes&sect;63.6(h) Opacity and visible emission standards No Subpart ZZZZ does not contain opacity or visible I emission standards.
&sect;63.6(c)(1)-(2)       Compliance dates for existing sources   Yes
&sect;63.6() Compliance extension procedures and Yes&sect;3I) ] criteria I F 1&sect;63.60) ]Presidential compliance exemption Yes&sect;63.7(a)(l)-(2)
&sect;63.6(c)(3)-(4)       [Reserved]                                       F
Performance test dates YeSubpart ZZZZ contains performance test dates at u&sect;&sect;63.6610 and 63.6611.&sect;63.7(a)(3)
&sect;36.6(c)(5)           Compliance dates for existing area     Yes Isources that become major sources 1&sect;63.6(d)             I[Reserved]                                       F
CAA section 114 authority YFs 1&sect;63.7(b)(1) iNotification of performance test&sect;63.7(b)(2)
&sect;63.6(e)(1)         ]Operation   and maintenance             Yes
Notification of rescheduling Fes&sect;63.7(c) Quality assurance/test plan ___&sect;63.7(d) -Testing facilities Yes&sect;63.7(e)(1)
&sect;63.6(e)(2)         ][[Reserved]
Conditions for conducting performance Yes tests&sect;63.7(e)(2)
&sect;63.6(e)(3)         1 Startup, shutdown, and malfunction plan
Conduct of performance tests and Yes lSubpart ZZZZ specifies test methods at &sect;63.6620.reduction of data&sect;63.7(e)(3)
&sect;63.6(f)(1)           Applicability of standards except       Yes during startup shutdown malfunction (SSM)
Test run duration Yes&sect;63.7(e)(4)
[&sect;63.6(f)(2)           [Methods for determining compliance     Yes
Administrator may require other testing Yes Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-26 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines under section 114 of the CAA I&sect;63.7(f) Alternative test method provisions Yes&sect;63.7(g) Performance test data analysis,&#xfd;recordkeeping, and reporting&sect;63.7(h) Waiver of tests Yes&sect;63.8(a)(1) 1Applicability of monitoring Yes Subpart ZZZZ contains specific requirements for requirements monitoring at &sect;63.6625.&sect;63.8(a)(2)
[&sect;63.6(f)(3)         ]Finding of compliance                   Yes       F
Performance specifications Yes&sect;63.8(a)(3)  
[&sect;63.6(g)(1)-(3)     ][Use of alternate standard               Yes
[Reserved]
&sect;63.6(h)               Opacity and visible emission standards No         Subpart ZZZZ does not contain opacity or visible I                                                     emission standards.
&sect;63.8(a)(4)
&sect;63.6()
Monitoring for control devices No_&sect;63.8(b)(1)
  &sect;3I)               ]Compliance extension procedures and criteria                               IYes      F 1&sect;63.60)             ]Presidential compliance exemption       Yes
_Monitoring Yes&sect;63.8(b)(2)-(3)
&sect;63.7(a)(l)-(2)       Performance test dates                   YeSubpart           ZZZZ contains performance test dates at u&sect;&sect;63.6610 and 63.6611.
Multiple effluents and multiple Yes_ _ monitoring systems&sect;63.8(c)(1)
&sect;63.7(a)(3)           CAA section 114 authority               YFs 1&sect;63.7(b)(1)         iNotification of performance test
Monitoring system operation and Yes imaintenance
&sect;63.7(b)(2)           Notification of rescheduling                       Fes
&sect;63.7(c)             Quality assurance/test plan                               ___
&sect;63.7(d)         -   Testing facilities                       Yes
&sect;63.7(e)(1)           Conditions for conducting performance Yes tests
&sect;63.7(e)(2)           Conduct of performance tests and reduction of data Yes     lSubpart ZZZZ specifies test methods at &sect;63.6620.
&sect;63.7(e)(3)           Test run duration                       Yes
&sect;63.7(e)(4)           Administrator may require other testing Yes Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                          Title V Permit Renewal Page NESHAPZ-26 of 29
 
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines under section 114 of the CAA           I
&sect;63.7(f)             Alternative test method provisions       Yes
&sect;63.7(g)             Performance test data analysis,
                    &#xfd;recordkeeping, and reporting
&sect;63.7(h)             Waiver of tests                           Yes
&sect;63.8(a)(1)       1Applicability requirements of monitoring             Yes       Subpart ZZZZ contains specific requirements for monitoring at &sect;63.6625.
&sect;63.8(a)(2)         Performance specifications               Yes
&sect;63.8(a)(3)         [Reserved]
&sect;63.8(a)(4)         Monitoring for control devices           No
_&sect;63.8(b)(1)
_Monitoring                                                   Yes
&sect;63.8(b)(2)-(3)     Multiple effluents and multiple           Yes
_monitoring
_           systems
&sect;63.8(c)(1)         Monitoring system operation and           Yes imaintenance
[&sect;63.8(c)(1)(i)
[&sect;63.8(c)(1)(i)
Routine and predictable SSM Yes&sect;63.8(c)(1)(ii)
&sect;63.8(c)(1)(ii) A Routine and predictable SSM SSM not in Startup Shutdown Yes F
A SSM not in Startup Shutdown F Malfunction Plan&sect;63.8(c)(1)(iii)
Malfunction Plan
Compliance with operation and Yes[maintenance requirements
&sect;63.8(c)(1)(iii)     Compliance with operation and           Yes
[&sect;63.8(c)(2)-(3)
[maintenance requirements
Monitoring system installation Yes&sect;63.8(c)(4)
[&sect;63.8(c)(2)-(3)     Monitoring system installation           Yes
Continuous monitoring system (CMS) Yes Except that subpart ZZZZ does not require&sect;63.8(c)(4)
&sect;63.8(c)(4)
[requirements Continuous Opacity Monitoring System (COMS).[&sect;63.8(c)(5)
&sect;63.8(c)(4)          Continuous monitoring system (CMS)       Yes       Except that subpart ZZZZ does not require
COMS minimum procedures No Subpart ZZZZ does not require COMS.[&sect;63.8(c)(6)-(8)
[requirements                                       Continuous Opacity Monitoring System (COMS).
CMS requirements Yes Except that subpart ZZZZ does not require COMS.[&sect;63.8(d)  
[&sect;63.8(c)(5)         COMS minimum procedures                   No       Subpart ZZZZ does not require COMS.
[CMS quality control Yes&sect;63.8(e) CMS performance evaluation Yes lExcept for &sect;63.8(e)(5)(ii), which applies to_________
[&sect;63.8(c)(6)-(8)     CMS requirements                         Yes     Except that subpart ZZZZ does not require COMS.
________________
[&sect;63.8(d)           [CMS   quality control                     Yes
JCOMS.[&sect;63.8(f)(l)-(5)  
&sect;63.8(e)             CMS performance evaluation               Yes     lExcept for &sect;63.8(e)(5)(ii), which applies to
]Alternative monitoring method Yes[&sect;63.8(f)(6)
_________
IAlternative to relative accuracy test ][Yes __&sect;63.8(g) Data reduction Yes Except that provisions for COMS are not applicable.
________________                                 JCOMS.
Averaging periods for demonstrating compliance are specified at &sect;&sect;63.6635 and 63.6640.&sect;63.9(a) Applicability and State delegation of LYes[notification requirements Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-27 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines&sect;63.9(b)(I)-(5)
[&sect;63.8(f)(l)-(5)   ]Alternative   monitoring method           Yes
Initial notifications Yes Except that &sect;63.9(b)(3) is reserved.&sect;63.9(c) Request for compliance extension Yes&sect;63.9(d) Notification of special compliance Yes_requirements for new sources&sect;63.9(e) ][Notification of performance test Yes&sect;63.9(f) Notification of visible emission No Subpart ZZZZ does not contain opacity or VE I(VE)/opacity test standards.
[&sect;63.8(f)(6)         IAlternative to relative accuracy test ][Yes       __
&sect;63.9(g)(1)
&sect;63.8(g)           Data reduction                             Yes     Except that provisions for COMS are not applicable. Averaging periods for demonstrating compliance are specified at &sect;&sect;63.6635 and 63.6640.
Notification of performance evaluation Yes&sect;63.9(g)(2)
&sect;63.9(a)             Applicability and State delegation of   LYes
Notification of use of COMS data No Subpart ZZZZ does not contain opacity or VE standards.
[notification requirements Progress Energy Florida, Inc.                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                                            Title V Permit Renewal Page NESHAPZ-27 of 29
alternative to RATA is exceeded&sect;63.9(h)(1)-(6)
 
Notification of compliance status Yes Except that notifications for sources using a CEMS are due 30 days after completion of_______________
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
of__ submittal deadlinesperformance evaluations.  
&sect;63.9(b)(I)-(5)           Initial notifications                       Yes     Except that &sect;63.9(b)(3) is reserved.
&sect;63.9(h)(4) is reserved.&sect;63.9(i) Adjustment of submittal deadlines Yes[&sect;63.90) [Change in previous information Yes&sect;63.10(a)
&sect;63.9(c)                 Request for compliance extension             Yes
Administrative provisions for record Yes&sect;keeping/reporting
&sect;63.9(d)                 Notification of special compliance         Yes
&sect;63.10(b)(1)  
_requirements    for new sources
]Record retention Yes&sect;63.10(b)(2)(i)-(v)  
&sect;63.9(e)               ][Notification of performance test             Yes
]Records related to SSM Yes&sect;63.10(b)(2)(vi)-
&sect;63.9(f)                 Notification of visible emission             No     Subpart ZZZZ does not contain opacity or VE I(VE)/opacity test                                     standards.
Records Yes (xi)&sect;63.10(b)(2)(xii)
&sect;63.9(g)(1)               Notification of performance evaluation       Yes
Record when under waiver Yes&sect;63.10(b)(2)(xiii)
&sect;63.9(g)(2)               Notification of use of COMS data           No       Subpart ZZZZ does not contain opacity or VE standards.
Records when using alternative to Yes ]For CO standard if using RATA alternative.
alternative to RATA is exceeded
]RATA&sect;63.10(b)(2)(xiv)
&sect;63.9(h)(1)-(6)           Notification of compliance status           Yes       Except that notifications for sources using a CEMS are due 30 days after completion of
IRecords of supporting documentation Yes&sect;63.10(b)(3)  
_______________        of__submittal deadlinesperformance                   evaluations. &sect;63.9(h)(4) is reserved.
][Records of applicability determination Yes&sect;63.10(c)
&sect;63.9(i)                 Adjustment of submittal deadlines           Yes
Additional records for sources using es Except that &sect;63.10(c)(2)-(4) and (9) are reserved.(CEMS (Y[&sect;63.10(d)(1)  
[&sect;63.90)                 [Change in previous information               Yes
]General reporting requirements Yes&sect;63.10(d)(2)
&sect;63.10(a)                 Administrative provisions for record       Yes
Report of performance test results Yes&sect;63.10(d)(3)
                          &sect;keeping/reporting
Reprting opacity or VE observations No Subpart ZZZZ does not contain opacity or VE stanusdards.
&sect;63.10(b)(1)           ]Record retention                             Yes
&sect;63.10(d)(4)
&sect;63.10(b)(2)(i)-(v) ]Records related to SSM                           Yes
Progress reports _ __&sect;63.10(d)(5)
&sect;63.10(b)(2)(vi)-         Records                                     Yes (xi)
Startup, shutdown, and malfunction Yes Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-28 of 29 APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines IIreports&sect;63.10(e)(1) and Additional CMS reports (2)(i) Z j&sect;63.10(e)(2)(ii)
&sect;63.10(b)(2)(xii)         Record when under waiver                     Yes
ICOMS-related report No Subpart ZZZZ does not require COMS.&sect;63.10(e)(3)
&sect;63.10(b)(2)(xiii)
Excess emission and parameter  
                      ]RATA Records when using alternative to           Yes   ]For CO standard if using RATA alternative.
]1Yes Except that &sect;63.10(e)(3)(i)(C) is reserved.exceedances reports&sect;63.10(e)(4)
&sect;63.10(b)(2)(xiv)       IRecords of supporting documentation           Yes
Reporting COMS data No [Subpart ZZZZ does not require COMS.&sect;63.10(f)
&sect;63.10(b)(3)           ][Records of applicability determination       Yes
Waiver for recordkeeping/reporting Yes&sect;63.11Flares 1No&sect;63.12 State authority and delegations Yes&sect;63.13 Addresses Yes&sect;63.14 Incorporation by reference Yes&sect;63.15 Availability of information Yes[73 FR 3610, Jan. 18, 2008]Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page NESHAPZ-29 of 29 APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
&sect;63.10(c)                 Additional records for sources using         es     Except that &sect;63.10(c)(2)-(4) and (9) are reserved.
RR1. Reporting Schedule.
(CEMS                                       (Y
This table summarizes information for convenience purposes only. It does not supersede any of the terms or conditions of this permit.Report Reporting Deadline(s)
[&sect;63.10(d)(1)           ]General reporting requirements               Yes
Related Condition(s)
&sect;63.10(d)(2)             Report of performance test results           Yes
Plant Problems/Permit Deviations Immediately upon occurrence (See RR2.d.) RR2, RR3 Malfunction Excess Emissions Report Quarterly (if requested)
&sect;63.10(d)(3)             Reprting opacity or VE observations         No       Subpart ZZZZ does not contain opacity or VE stanusdards.
RR3 Semi-Annual Monitoring Report Every 6 months RR4 Annual Operating Report April 1 RR5 Annual Emissions Fee Form and Fee March 1 RR6 Annual Statement of Compliance Within 60 days after the end of each calendar year RR7 (or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement);
&sect;63.10(d)(4)             Progress reports                                             _       __
and Within 60 days after submittal of a written agreement for transfer of responsibility, or Within 60 days after permanent shutdown.Notification of Administrative Permit As needed RR8 Corrections Notification of Startup after Minimum of 60 days prior to the intended startup RR9 Shutdown for More than One Year date or, if emergency startup, as soon as possible after the startup date is ascertained Permit Renewal Application 225 days prior to the expiration date of permit TV17 Test Reports Maximum 45 days following compliance tests TR8 (Permitting Note: See permit Section III. Emissions Units and Specific Conditions, for any additional Emission Unit-specific reporting requirements.]
&sect;63.10(d)(5)             Startup, shutdown, and malfunction         Yes Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                  Title V Permit Renewal Page NESHAPZ-28 of 29
RR2. Reports of Problems.a. Plant Operation-Problems.
 
If the permittee is temporarily unable to comply with any of the conditions of the permit due to breakdown of equipment or destruction by hazard of fire, wind or by other cause, the permittee shall immediately notify the Department.
APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines IIreports
Notification shall include pertinent information as to the cause of the problem, and what steps are being taken to correct the problem and to prevent its recurrence, and where applicable, the owner's intent toward reconstruction of destroyed facilities.
&sect;63.10(e)(1) and     Additional CMS reports (2)(i)                   Z j&sect;63.10(e)(2)(ii)     ICOMS-related report                   No       Subpart ZZZZ does not require COMS.
Such notification does not release the permittee from any liability for failure to comply with Department rules.b. If, for any reason, the permittee does not comply with or will be unable to comply with any condition or limitation specified in this permit, the permittee shall immediately provide the Department with the following information:
&sect;63.10(e)(3)         Excess emission and parameter         ]1Yes       Except that &sect;63.10(e)(3)(i)(C) is reserved.
(1) A description of and cause of noncompliance; and (2) The period of noncompliance, including dates and times; or, if not corrected, the anticipated time the noncompliance is expected to continue, and steps being taken to reduce, eliminate, and prevent recurrence of the noncompliance.
exceedances reports
The permittee shall be responsible for any and all damages which may result and may be subject to enforcement action by the Department for penalties or for revocation of this permit.c. When requested by the Department, the permittee shall within a reasonable time furnish any information required by law which is needed to determine compliance with the permit. If the permittee becomes Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page RR- 1 of 4 APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009) aware the relevant facts were not submitted or were incorrect in the permit application or in any report to the Department, such facts or information shall be corrected promptly.d. "Immediately" shall mean the same day, if during a workday (i.e., 8:00 a.m. -5:00 p.m.), or the first business day after the incident, excluding weekends and holidays; and, for purposes of Rule 62-4.160(15) and 40 CFR 70.6(a)(3)(iii)(B), "promptly" or "prompt" shall have the same meaning as "immediately".
&sect;63.10(e)(4)         Reporting COMS data                     No       [Subpart ZZZZ does not require COMS.
&sect;63.10(f)           Waiver for recordkeeping/reporting     Yes
&sect;63.11Flares                                               1No
&sect;63.12               State authority and delegations         Yes
&sect;63.13               Addresses                               Yes
&sect;63.14               Incorporation by reference             Yes
&sect;63.15               Availability of information             Yes
[73 FR 3610, Jan. 18, 2008]
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                          Title V Permit Renewal Page NESHAPZ-29 of 29
 
APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
RR1. Reporting Schedule.           This table summarizes information for convenience purposes only. It does not supersede any of the terms or conditions of this permit.
Report                                     Reporting Deadline(s)                                 Related Condition(s)
Plant Problems/Permit Deviations           Immediately upon occurrence (See RR2.d.)               RR2, RR3 Malfunction Excess Emissions Report         Quarterly (if requested)                               RR3 Semi-Annual Monitoring Report               Every 6 months                                         RR4 Annual Operating Report                     April 1                                               RR5 Annual Emissions Fee Form and Fee           March 1                                               RR6 Annual Statement of Compliance             Within 60 days after the end of each calendar year     RR7 (or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement); and Within 60 days after submittal of a written agreement for transfer of responsibility, or Within 60 days after permanent shutdown.
Notification of Administrative Permit       As needed                                             RR8 Corrections Notification of Startup after               Minimum of 60 days prior to the intended startup       RR9 Shutdown for More than One Year             date or, if emergency startup, as soon as possible after the startup date is ascertained Permit Renewal Application                 225 days prior to the expiration date of permit       TV17 Test Reports                               Maximum 45 days following compliance tests             TR8 (Permitting Note: See permit Section III. Emissions Units and Specific Conditions,for any additional Emission Unit-specific reporting requirements.]
RR2. Reports of Problems.
: a. Plant Operation-Problems. If the permittee is temporarily unable to comply with any of the conditions of the permit due to breakdown of equipment or destruction by hazard of fire, wind or by other cause, the permittee shall immediately notify the Department. Notification shall include pertinent information as to the cause of the problem, and what steps are being taken to correct the problem and to prevent its recurrence, and where applicable, the owner's intent toward reconstruction of destroyed facilities. Such notification does not release the permittee from any liability for failure to comply with Department rules.
: b. If, for any reason, the permittee does not comply with or will be unable to comply with any condition or limitation specified in this permit, the permittee shall immediately provide the Department with the following information:
(1) A description of and cause of noncompliance; and (2) The period of noncompliance, including dates and times; or, if not corrected, the anticipated time the noncompliance is expected to continue, and steps being taken to reduce, eliminate, and prevent recurrence of the noncompliance. The permittee shall be responsible for any and all damages which may result and may be subject to enforcement action by the Department for penalties or for revocation of this permit.
: c. When requested by the Department, the permittee shall within a reasonable time furnish any information required by law which is needed to determine compliance with the permit. If the permittee becomes Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                        Title V Permit Renewal Page RR- 1 of 4
 
APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009) aware the relevant facts were not submitted or were incorrect in the permit application or in any report to the Department, such facts or information shall be corrected promptly.
: d. "Immediately" shall mean the same day, if during a workday (i.e., 8:00 a.m. - 5:00 p.m.), or the first business day after the incident, excluding weekends and holidays; and, for purposes of Rule 62-4.160(15) and 40 CFR 70.6(a)(3)(iii)(B), "promptly" or "prompt" shall have the same meaning as "immediately".
[Rule 62-4.130, Rule 62-4.160(8), Rule 62-4.160(15), and Rule 62-213.440(1)(b), F.A.C.; 40 CFR 70.6(a)(3)(iii)(B)]
[Rule 62-4.130, Rule 62-4.160(8), Rule 62-4.160(15), and Rule 62-213.440(1)(b), F.A.C.; 40 CFR 70.6(a)(3)(iii)(B)]
RR3. Reports of Deviations from Permit Requirements.
RR3. Reports of Deviations from Permit Requirements. The permittee shall report in accordance with the requirements of Rule 62-210.700(6), F.A.C. (below), and Rule 62-4.130, F.A.C. (condition RR2.), deviations from permit requirements, including those attributable to upset conditions as defined in the permit. Reports shall include the probable cause of such deviations, and any corrective actions or preventive measures taken.
The permittee shall report in accordance with the requirements of Rule 62-210.700(6), F.A.C. (below), and Rule 62-4.130, F.A.C. (condition RR2.), deviations from permit requirements, including those attributable to upset conditions as defined in the permit. Reports shall include the probable cause of such deviations, and any corrective actions or preventive measures taken.Rule 62-210.700(6):
Rule 62-210.700(6): In case of excess emissions resulting from malfunctions, each owner or operator shall notify the Department or the appropriate Local Program in accordance with Rule 62-4.130, F.A.C. (See condition RR2.). A full written report on the malfunctions shall be submitted in a quarterly report, if requested by the Department.
In case of excess emissions resulting from malfunctions, each owner or operator shall notify the Department or the appropriate Local Program in accordance with Rule 62-4.130, F.A.C. (See condition RR2.). A full written report on the malfunctions shall be submitted in a quarterly report, if requested by the Department.
[Rules 62-213.440(1)(b)3.b., and 62-210.700(6)F.A.C.]
[Rules 62-213.440(1)(b)3.b., and 62-210.700(6)F.A.C.]
RR4. Semi-Annual Monitoring Reports. The permittee shall submit reports of any required monitoring at least every six (6) months. All instances of deviations from permit requirements must be clearly identified in such reports. [Rule 62-213.440(1)(b)3.a., F.A.C.]RR5. Annual Operating Report.a. The permittee shall submit to the Compliance Authority, each calendar year, on or before April 1, a completed DEP Form No 62-210.900(5), "Annual Operating Report for Air Pollutant Emitting Facility", for the preceding calendar year.b. Emissions shall be computed in accordance with the provisions of Rule 62-210.370(2), F.A.C.[Rules 62-210.370(2)  
RR4. Semi-Annual Monitoring Reports. The permittee shall submit reports of any required monitoring at least every six (6) months. All instances of deviations from permit requirements must be clearly identified in such reports. [Rule 62-213.440(1)(b)3.a., F.A.C.]
& (3), and 62-213.440(3)(a)2., F.A.C.]RR6. Annual Emissions Fee Form and Fee. Each Title V source permitted to operate in Florida must pay between January 15 and March 1 of each year, an annual emissions fee in an amount determined as set forth in Rule 62-213.205(1), F.A.C.a. If the Department has not received the fee by February 15 of the year following the calendar year for which the fee is calculated, the Department will send the primary responsible official of the Title V source a written warning of the consequences for failing to pay the fee by March 1. If the fee is not postmarked by March 1 of the year due, the Department shall impose, in addition to the fee, a penalty of 50 percent of the amount of the fee unpaid plus interest on such amount computed in accordance with Section 220.807, F.S. If the Department determines that a submitted fee was inaccurately calculated, the Department shall either refund to the permittee any amount overpaid or notify the permittee of any amount underpaid.
RR5. Annual Operating Report.
The Department shall not impose a penalty or interest on any amount underpaid, provided that the permittee has timely remitted payment of at least 90 percent of the amount determined to be due and remits full payment within 60 days after receipt of notice of the amount underpaid.
: a. The permittee shall submit to the Compliance Authority, each calendar year, on or before April 1, a completed DEP Form No 62-210.900(5), "Annual Operating Report for Air Pollutant Emitting Facility",
The Department shall waive the collection of underpayment and shall not refund overpayment of the fee, if the amount is less than 1 percent of the fee due, up to $50.00. The Department shall make every effort to provide a timely assessment of the adequacy of the submitted fee. Failure to pay timely any required annual emissions fee, penalty, or interest constitutes grounds for permit revocation pursuant to Rule 62-4.100, F.A.C.b. Any documentation of actual hours of operation, actual material or heat input, actual production amount, or actual emissions used to calculate the annual emissions fee shall be retained by the owner for a minimum of five (5) years and shall be made available to the Department upon request.c. A completed DEP Form 62-213.900(1), "Major Air Pollution Source Annual Emissions Fee Form", must be submitted by a responsible official with the annual emissions fee.[Rules 62-213.205(1), (1)(g), (1)(i) & (1)(j), F.A.C.]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-2 of 4 APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
for the preceding calendar year.
: b. Emissions shall be computed in accordance with the provisions of Rule 62-210.370(2), F.A.C.
[Rules 62-210.370(2) & (3), and 62-213.440(3)(a)2., F.A.C.]
RR6. Annual Emissions Fee Form and Fee. Each Title V source permitted to operate in Florida must pay between January 15 and March 1 of each year, an annual emissions fee in an amount determined as set forth in Rule 62-213.205(1), F.A.C.
: a. If the Department has not received the fee by February 15 of the year following the calendar year for which the fee is calculated, the Department will send the primary responsible official of the Title V source a written warning of the consequences for failing to pay the fee by March 1. If the fee is not postmarked by March 1 of the year due, the Department shall impose, in addition to the fee, a penalty of 50 percent of the amount of the fee unpaid plus interest on such amount computed in accordance with Section 220.807, F.S. If the Department determines that a submitted fee was inaccurately calculated, the Department shall either refund to the permittee any amount overpaid or notify the permittee of any amount underpaid. The Department shall not impose a penalty or interest on any amount underpaid, provided that the permittee has timely remitted payment of at least 90 percent of the amount determined to be due and remits full payment within 60 days after receipt of notice of the amount underpaid. The Department shall waive the collection of underpayment and shall not refund overpayment of the fee, if the amount is less than 1 percent of the fee due, up to $50.00. The Department shall make every effort to provide a timely assessment of the adequacy of the submitted fee. Failure to pay timely any required annual emissions fee, penalty, or interest constitutes grounds for permit revocation pursuant to Rule 62-4.100, F.A.C.
: b. Any documentation of actual hours of operation, actual material or heat input, actual production amount, or actual emissions used to calculate the annual emissions fee shall be retained by the owner for a minimum of five (5) years and shall be made available to the Department upon request.
: c. A completed DEP Form 62-213.900(1), "Major Air Pollution Source Annual Emissions Fee Form", must be submitted by a responsible official with the annual emissions fee.
[Rules 62-213.205(1), (1)(g), (1)(i) & (1)(j), F.A.C.]
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page RR-2 of 4
 
APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
RR7. Annual Statement of Compliance.
RR7. Annual Statement of Compliance.
: a. The permittee shall submit a Statement of Compliance with all terms and conditions of the permit that includes all the provisions of 40 CFR 70.6(c)(5)(iii), incorporated by reference at Rule 62-204.800, F.A.C., using DEP Form No. 62-213.900(7).
: a. The permittee shall submit a Statement of Compliance with all terms and conditions of the permit that includes all the provisions of 40 CFR 70.6(c)(5)(iii), incorporated by reference at Rule 62-204.800, F.A.C., using DEP Form No. 62-213.900(7). Such statement shall be accompanied by a certification in accordance with Rule 62-213.420(4), F.A.C., for Title V requirements and with Rule 62-214.350, F.A.C.,
Such statement shall be accompanied by a certification in accordance with Rule 62-213.420(4), F.A.C., for Title V requirements and with Rule 62-214.350, F.A.C., for Acid Rain requirements.
for Acid Rain requirements. Such statements shall be submitted (postmarked) to the Department and EPA:
Such statements shall be submitted (postmarked) to the Department and EPA: (1) Annually, within 60 days after the end of each calendar year during which the Title V permit was effective, or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement; and (2) Within 60 days after submittal of a written agreement for transfer of responsibility as required pursuant to 40 CFR 70.7(d)(1)(iv), adopted and incorporated by reference at Rule 62-204.800, F.A.C., or within 60 days after permanent shutdown of a facility permitted under Chapter 62-213, F.A.C.;provided that, in either such case, the reporting period shall be the portion of the calendar year the permit was effective up to the date of transfer of responsibility or permanent facility shutdown, as applicable.
(1) Annually, within 60 days after the end of each calendar year during which the Title V permit was effective, or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement; and (2) Within 60 days after submittal of a written agreement for transfer of responsibility as required pursuant to 40 CFR 70.7(d)(1)(iv), adopted and incorporated by reference at Rule 62-204.800, F.A.C.,
or within 60 days after permanent shutdown of a facility permitted under Chapter 62-213, F.A.C.;
provided that, in either such case, the reporting period shall be the portion of the calendar year the permit was effective up to the date of transfer of responsibility or permanent facility shutdown, as applicable.
: b. In lieu of individually identifying all applicable requirements and specifying times of compliance with, non-compliance with, and deviation from each, the responsible official may use DEP Form No. 62-213.900(7) as such statement of compliance so long as the responsible official identifies all reportable deviations from and all instances of non-compliance with any applicable requirements and includes all information required by the federal regulation relating to each reportable deviation and instance of non-compliance.
: b. In lieu of individually identifying all applicable requirements and specifying times of compliance with, non-compliance with, and deviation from each, the responsible official may use DEP Form No. 62-213.900(7) as such statement of compliance so long as the responsible official identifies all reportable deviations from and all instances of non-compliance with any applicable requirements and includes all information required by the federal regulation relating to each reportable deviation and instance of non-compliance.
: c. The responsible official may treat compliance with all other applicable requirements as a surrogate for compliance with Rule 62-296.320(2), Objectionable Odor Prohibited.
: c. The responsible official may treat compliance with all other applicable requirements as a surrogate for compliance with Rule 62-296.320(2), Objectionable Odor Prohibited.
[Rules 62-213.440(3)(a)2.  
[Rules 62-213.440(3)(a)2. & 3. and (b), F.A.C.]
& 3. and (b), F.A.C.]RR8. Notification of Administrative Permit Corrections.
RR8. Notification of Administrative Permit Corrections.
: a. A facility owner shall notify the Department by letter of minor corrections to information contained in a permit. Such notifications shall include: (1) Typographical errors noted in the permit;(2) Name, address or phone number change from that in the permit;(3) A change requiring more frequent monitoring or reporting by the permittee; (4) A change in ownership or operational control of a facility, subject to the following provisions: (a) The Department determines that no other change in the permit is necessary;(b) The permittee and proposed new permittee have submitted an Application for Transfer of Air Permit, and the Department has approved the transfer pursuant to Rule 62-210.300(7), F.A.C.;and (c) The new permittee has notified the Department of the effective date of sale or legal transfer.(5) Changes listed at 40 CFR 72.83(a)(1), (2), (6), (9) and (10), adopted and incorporated by reference at Rule 62-204.800, F.A.C., and changes made pursuant to Rules 62-214.340(1) and (2), F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-7651o; (6) Changes listed at 40 CFR 72.83(a)(1  
: a. A facility owner shall notify the Department by letter of minor corrections to information contained in a permit. Such notifications shall include:
: 1) and (12), adopted and incorporated by reference at Rule 62-204.800, F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-765 lo, provided the notification is accompanied by a copy of any EPA determination concerning the similarity of the change to those listed at Rule 62-210.360(1)(e), F.A.C.; and (7) Any other similar minor administrative change at the source.b. Upon receipt of any such notification, the Department shall within 60 days correct the permit and provide a corrected copy to the owner.c. After first notifying the owner, the Department shall correct any permit in which it discovers errors of the types listed at Rules 62-210.360(1)(a) and (b), F.A.C., and provide a corrected copy to the owner.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-3 of 4 APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
(1) Typographical errors noted in the permit; (2) Name, address or phone number change from that in the permit; (3) A change requiring more frequent monitoring or reporting by the permittee; (4) A change in ownership or operational control of a facility, subject to the following provisions:
: d. For Title V source permits, other than general permits, a copy of the corrected permit shall be provided to EPA and any approved local air program in the county where the facility or any part of the facility is located.[Rule 62-210.360, F.A.C.]RR9. Notification of Startup. The owners or operator of any emissions unit or facility which has a valid air operation permit which has been shut down more than one year, shall notify the Department in writing of the intent to start up such emissions unit or facility, a minimum of 60 days prior to the intended startup date.a. The notification shall include information as to the startup date, anticipated emission rates or pollutants released, changes to processes or control devices which will result in changes to emission rates, and any other conditions which may differ from the valid outstanding operation permit.b. If, due to an emergency, a startup date is not known 60 days prior thereto, the owner shall notify the Department as soon as possible after the date of such startup is ascertained.
(a) The Department determines that no other change in the permit is necessary; (b) The permittee and proposed new permittee have submitted an Application for Transfer of Air Permit, and the Department has approved the transfer pursuant to Rule 62-210.300(7), F.A.C.;
[Rule 62-210.300(5), F.A.C.]RR1O. Report Submission.
and (c) The new permittee has notified the Department of the effective date of sale or legal transfer.
The permittee shall submit all compliance related notifications and reports required of this permit to the Compliance Authority.  
(5) Changes listed at 40 CFR 72.83(a)(1), (2), (6), (9) and (10), adopted and incorporated by reference at Rule 62-204.800, F.A.C., and changes made pursuant to Rules 62-214.340(1) and (2), F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-7651o; (6) Changes listed at 40 CFR 72.83(a)(1 1) and (12), adopted and incorporated by reference at Rule 62-204.800, F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-765 lo, provided the notification is accompanied by a copy of any EPA determination concerning the similarity of the change to those listed at Rule 62-210.360(1)(e), F.A.C.; and (7) Any other similar minor administrative change at the source.
{See front of permit for address and phone number.)RR11. EPA Report Submission.
: b. Upon receipt of any such notification, the Department shall within 60 days correct the permit and provide a corrected copy to the owner.
Any reports, data, notifications, certifications, and requests required to be sent to the United States Environmental Protection Agency, Region 4, should be sent to: Air, Pesticides  
: c. After first notifying the owner, the Department shall correct any permit in which it discovers errors of the types listed at Rules 62-210.360(1)(a) and (b), F.A.C., and provide a corrected copy to the owner.
& Toxics Management Division, United States Environmental Protection Agency, Region 4, Sam Nunn Atlanta Federal Center, 61 Forsyth Street SW, Atlanta, GA 30303-8960.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                         Title V Permit Renewal Page RR-3 of 4
Phone: 404/562-9077.
 
RR12. Acid Rain Report Submission.
APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)
Acid Rain Program Information shall be submitted, as necessary, to: Department of Environmental Protection, 2600 Blair Stone Road, Mail Station #5510, Tallahassee, Florida 32399-2400.
: d. For Title V source permits, other than general permits, a copy of the corrected permit shall be provided to EPA and any approved local air program in the county where the facility or any part of the facility is located.
Phone: 850/488-6140.
[Rule 62-210.360, F.A.C.]
Fax: 850/922-6979.
RR9. Notification of Startup. The owners or operator of any emissions unit or facility which has a valid air operation permit which has been shut down more than one year, shall notify the Department in writing of the intent to start up such emissions unit or facility, a minimum of 60 days prior to the intended startup date.
RR13. Report Certification.
: a. The notification shall include information as to the startup date, anticipated emission rates or pollutants released, changes to processes or control devices which will result in changes to emission rates, and any other conditions which may differ from the valid outstanding operation permit.
All reports shall be accompanied by a certification by a responsible official, pursuant to Rule 62-213.420(4), F.A.C. [Rule 62-213.440(1)(b)3.c, F.A.C.]RR14. Certification by Responsible Official (RO). In addition to the professional engineering certification required for applications by Rule 62-4.050(3), F.A.C., any application form, report, compliance statement, compliance plan and compliance schedule submitted pursuant to Chapter 62-213, F.A.C., shall contain a certification signed by a responsible official that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete.
: b. If, due to an emergency, a startup date is not known 60 days prior thereto, the owner shall notify the Department as soon as possible after the date of such startup is ascertained.
Any responsible official who fails to submit any required information or who has submitted incorrect information shall, upon becoming aware of such failure or incorrect submittal, promptly submit such supplementary information or correct information.  
[Rule 62-210.300(5), F.A.C.]
[Rule 62-213.420(4), F.A.C.]RR15. Confidential Information.
RR1O. Report Submission. The permittee shall submit all compliance related notifications and reports required of this permit to the Compliance Authority. {See front of permit for address and phone number.)
Whenever an applicant submits information under a claim of confidentiality pursuant to Section 403.111, F.S., the applicant shall also submit a copy of all such information and claim directly to EPA. Any permittee may claim confidentiality of any data or other information by complying with this procedure.  
RR11. EPA Report Submission. Any reports, data, notifications, certifications, and requests required to be sent to the United States Environmental Protection Agency, Region 4, should be sent to: Air, Pesticides & Toxics Management Division, United States Environmental Protection Agency, Region 4, Sam Nunn Atlanta Federal Center, 61 Forsyth Street SW, Atlanta, GA 30303-8960. Phone: 404/562-9077.
[Rules 62-213.420(2), and 62-213.440(1)(d)6., F.A.C.]RR16. Forms and Instructions.
RR12. Acid Rain Report Submission. Acid Rain Program Information shall be submitted, as necessary, to:
The forms used by the Department in the Title V source operation program are adopted and incorporated by reference in Rule 62-213.900, F.A.C. The forms are listed by rule number, which is also the form number, and with the subject, title, and effective date. Copies of forms may be obtained by writing to the Department of Environmental Protection, Division of Air Resource Management, 2600 Blair Stone Road, Tallahassee, Florida 32399-2400, by contacting the appropriate permitting authority or by accessing the Department's web site at: http://www.dep.state.fl.us/air/rules/forms.htm.
Department of Environmental Protection, 2600 Blair Stone Road, Mail Station #5510, Tallahassee, Florida 32399-2400. Phone: 850/488-6140. Fax: 850/922-6979.
RR13. Report Certification. All reports shall be accompanied by a certification by a responsible official, pursuant to Rule 62-213.420(4), F.A.C. [Rule 62-213.440(1)(b)3.c, F.A.C.]
RR14. Certification by Responsible Official (RO). In addition to the professional engineering certification required for applications by Rule 62-4.050(3), F.A.C., any application form, report, compliance statement, compliance plan and compliance schedule submitted pursuant to Chapter 62-213, F.A.C., shall contain a certification signed by a responsible official that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. Any responsible official who fails to submit any required information or who has submitted incorrect information shall, upon becoming aware of such failure or incorrect submittal, promptly submit such supplementary information or correct information. [Rule 62-213.420(4), F.A.C.]
RR15. Confidential Information. Whenever an applicant submits information under a claim of confidentiality pursuant to Section 403.111, F.S., the applicant shall also submit a copy of all such information and claim directly to EPA. Any permittee may claim confidentiality of any data or other information by complying with this procedure. [Rules 62-213.420(2), and 62-213.440(1)(d)6., F.A.C.]
RR16. Forms and Instructions. The forms used by the Department in the Title V source operation program are adopted and incorporated by reference in Rule 62-213.900, F.A.C. The forms are listed by rule number, which is also the form number, and with the subject, title, and effective date. Copies of forms may be obtained by writing to the Department of Environmental Protection, Division of Air Resource Management, 2600 Blair Stone Road, Tallahassee, Florida 32399-2400, by contacting the appropriate permitting authority or by accessing the Department's web site at: http://www.dep.state.fl.us/air/rules/forms.htm.
: a. Major Air Pollution Source Annual Emissions Fee Form (Effective 10/12/2008).
: a. Major Air Pollution Source Annual Emissions Fee Form (Effective 10/12/2008).
: b. Statement of Compliance Form (Effective 06/02/2002).
: b. Statement of Compliance Form (Effective 06/02/2002).
: c. Responsible Official Notification Form (Effective 06/02/2002).
: c. Responsible Official Notification Form (Effective 06/02/2002).
[Rule 62-213.900, F.A.C.: Forms (1), (7) and (8)]Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-4 of 4 APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008
[Rule 62-213.900, F.A.C.: Forms (1), (7) and (8)]
Progress Energy Florida, Inc.                                                              Permit No. 0170004-024-AV Crystal River Power Plant                                                                      Title V Permit Renewal Page RR-4 of 4
 
APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008)
Unless otherwise specified in the permit, the following testing requirements apply to each emissions unit for which testing is required. The terms "stack" and "duct" are used interchangeably in this appendix.
TR1. Required Number of Test Runs. For mass emission limitations, a compliance test shall consist of three complete and separate determinations of the total air pollutant emission rate through the test section of the stack or duct and
: a. Permits shall be effective until suspended, revoked, surrendered, or expired and shall be subject to the provisions of Chapter 403, F.S., and rules of the Department.
: a. Permits shall be effective until suspended, revoked, surrendered, or expired and shall be subject to the provisions of Chapter 403, F.S., and rules of the Department.
: b. Failure to comply with pollution control laws and rules shall be grounds for suspension or revocation.
: b. Failure to comply with pollution control laws and rules shall be grounds for suspension or revocation.
: c. A permit issued pursuant to Chapter 62-4, F.A.C., shall not become a vested property right in the permittee.
: c. A permit issued pursuant to Chapter 62-4, F.A.C., shall not become a vested property right in the permittee. The Department may revoke any permit issued by it if it finds that the permit holder or his agent:
The Department may revoke any permit issued by it if it finds that the permit holder or his agent: (1) Submitted false or inaccurate information in his application or operational reports.(2) Has violated law, Department orders, rules or permit conditions.
(1) Submitted false or inaccurate information in his application or operational reports.
(3) Has failed to submit operational reports or other information required by Department rules.(4) Has refused lawful inspection under Section 403.091, F.S.d. No revocation shall become effective except after notice is served by personal services, certified mail, or newspaper notice pursuant to Section 120.60(7), F.S., upon the person or persons named therein and a hearing held if requested within the time specified in the notice. The notice shall specify the provision of the law, or rule alleged to be violated, or the permit condition or Department order alleged to be violated, and the facts alleged to constitute a violation thereof.[Rule 62-4. 100, F.A.C.]TV22. Not federally enforceable.
(2) Has violated law, Department orders, rules or permit conditions.
Financial Responsibility.
(3) Has failed to submit operational reports or other information required by Department rules.
The Department may require an applicant to submit proof of financial responsibility and may require the applicant to post an appropriate bond to guarantee compliance with the law and Department rules. [Rule 62-4.110, F.A.C.]TV23. Emissions Unit Reclassification.
(4) Has refused lawful inspection under Section 403.091, F.S.
: a. Any emissions unit whose operation permit has been revoked as provided for in Chapter 62-4, F.A.C., shall be deemed permanently shut down for purposes of Rule 62-212.500, F.A.C. Any emissions unit whose permit to operate has expired without timely renewal or transfer may be deemed permanently shut down, provided, however, that no such emissions unit shall be deemed permanently shut down if, within 20 days after receipt of written notice from the Department, the emissions unit owner or operator demonstrates that the permit expiration resulted from inadvertent failure to comply with the requirements of Rule 62-4.090, F.A.C., and that the owner or operator intends to continue the emissions unit in operation, and either submits an application for an air operation permit or complies with permit transfer requirements, if applicable.
: d. No revocation shall become effective except after notice is served by personal services, certified mail, or newspaper notice pursuant to Section 120.60(7), F.S., upon the person or persons named therein and a hearing held if requested within the time specified in the notice. The notice shall specify the provision of the law, or rule alleged to be violated, or the permit condition or Department order alleged to be violated, and the facts alleged to constitute a violation thereof.
: b. If the owner or operator of an emissions unit which is so permanently shut down, applies to the Department for a permit to reactivate or operate such emissions unit, the emissions unit will be reviewed and permitted as a new emissions unit.[Rule 62-210.300(6), F.A.C.]TV24. Transfer of Permits. Per Rule 62-4.160(11), F.A.C., this permit is transferable only upon Department approval in accordance with Rule 62-4.120, F.A.C., as applicable.
[Rule 62-4. 100, F.A.C.]
The permittee shall be liable for any non-compliance of the permitted activity until the transfer is approved by the Department.
TV22. Not federally enforceable. Financial Responsibility. The Department may require an applicant to submit proof of financial responsibility and may require the applicant to post an appropriate bond to guarantee compliance with the law and Department rules. [Rule 62-4.110, F.A.C.]
The permittee transferring the permit shall remain liable for corrective actions that may be required as a result of any Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-3 of 7 APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) violations occurring prior to the sale or legal transfer of the facility.
TV23. Emissions Unit Reclassification.
The permittee shall also comply with the requirements of Rule 62-210.300(7), F.A.C., and use DEP Form No. 62-210.900(7).  
: a. Any emissions unit whose operation permit has been revoked as provided for in Chapter 62-4, F.A.C.,
[Rules 62-4.160(11), 62-4.120, and 62-210.300(7), F.A.C.]Rights. Title, Liability, and Agreements TV25. Rigbhs. As provided in Subsections 403.987(6) and 403.722(5), F.S., the issuance of this permit does not convey any vested rights or any exclusive privileges.
shall be deemed permanently shut down for purposes of Rule 62-212.500, F.A.C. Any emissions unit whose permit to operate has expired without timely renewal or transfer may be deemed permanently shut down, provided, however, that no such emissions unit shall be deemed permanently shut down if, within 20 days after receipt of written notice from the Department, the emissions unit owner or operator demonstrates that the permit expiration resulted from inadvertent failure to comply with the requirements of Rule 62-4.090, F.A.C., and that the owner or operator intends to continue the emissions unit in operation, and either submits an application for an air operation permit or complies with permit transfer requirements, if applicable.
Neither does it authorize any injury to public or private property or any invasion of personal rights, nor any infringement of federal, state, or local laws or regulations.
: b. If the owner or operator of an emissions unit which is so permanently shut down, applies to the Department for a permit to reactivate or operate such emissions unit, the emissions unit will be reviewed and permitted as a new emissions unit.
This permit is not a waiver of or approval of any other Department permit that may be required for other aspects of the total project which are not addressed in this permit. [Rule 62-4.160(3), F.A.C.]TV26. Title. This permit conveys no title to land or water, does not constitute State recognition or acknowledgment of title, and does not constitute authority for the use of submerged lands unless herein provided and the necessary title or leasehold interests have been obtained from the State. Only the Trustees of the Internal Improvement Trust Fund may express State opinion as to title. [Rule 62-4.160(4), (F.A.C.]TV27. Liability.
[Rule 62-210.300(6), F.A.C.]
This permit does not relieve the permittee from liability for harm or injury to human health or welfare, animal, or plant life, or property caused by the construction or operation of this permitted source, or from penalties therefore; nor does it allow the permittee to cause pollution in contravention of F.S. and Department rules, unless specifically authorized by an order from the Department.  
TV24. Transfer of Permits. Per Rule 62-4.160(11), F.A.C., this permit is transferable only upon Department approval in accordance with Rule 62-4.120, F.A.C., as applicable. The permittee shall be liable for any non-compliance of the permitted activity until the transfer is approved by the Department. The permittee transferring the permit shall remain liable for corrective actions that may be required as a result of any Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page TV-3 of 7
[Rule 62-4.160(5), F.A.C.]TV28. Agreements.
 
: a. The permittee, by accepting this permit, specifically agrees to allow authorized Department personnel, upon presentation of credentials or other documents as may be required by law and at reasonable times, access to the premises where the permitted activity is located or conducted to: (1) Have access to and copy any records that must be kept under conditions of the permit;(2) Inspect the facility, equipment, practices, or operations regulated or required under this permit; and, (3) Sample or monitor any substances or parameters at any location reasonably necessary to assure compliance with this permit or Department rules. Reasonable time may depend on the nature of the concern being investigated.
APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) violations occurring prior to the sale or legal transfer of the facility. The permittee shall also comply with the requirements of Rule 62-210.300(7), F.A.C., and use DEP Form No. 62-210.900(7). [Rules 62-4.160(11), 62-4.120, and 62-210.300(7), F.A.C.]
: b. In accepting this permit, the permittee understands and agrees that all records, notes, monitoring data and other information relating to the construction or operation of this permitted source which are submitted to the Department may be used by the Department as evidence in any enforcement case involving the permitted source arising under the Florida Statutes or Department rules, except where such use is prescribed by Sections 403.111 and 403.73, F.S. Such evidence shall only be used to the extent it is consistent with the Florida Rules of Civil Procedure and appropriate evidentiary rules.c. The permittee agrees to comply with changes in Department rules and Florida Statutes after a reasonable time for compliance; provided, however, the permittee does not waive any other rights granted by Florida Statutes or Department rules.[Rules 62-4.160(7), (9), and (10), F.A.C.]Recordkeeping and Emissions Computation TV29. Permit. The permittee shall keep this permit or a copy thereof at the work site of the permitted activity.[Rule 62-4.160(12), F.A.C.]TV30. Recordkeeping.
Rights. Title, Liability, and Agreements TV25. Rigbhs. As provided in Subsections 403.987(6) and 403.722(5), F.S., the issuance of this permit does not convey any vested rights or any exclusive privileges. Neither does it authorize any injury to public or private property or any invasion of personal rights, nor any infringement of federal, state, or local laws or regulations.
This permit is not a waiver of or approval of any other Department permit that may be required for other aspects of the total project which are not addressed in this permit. [Rule 62-4.160(3), F.A.C.]
TV26. Title. This permit conveys no title to land or water, does not constitute State recognition or acknowledgment of title, and does not constitute authority for the use of submerged lands unless herein provided and the necessary title or leasehold interests have been obtained from the State. Only the Trustees of the Internal Improvement Trust Fund may express State opinion as to title. [Rule 62-4.160(4), (F.A.C.]
TV27. Liability. This permit does not relieve the permittee from liability for harm or injury to human health or welfare, animal, or plant life, or property caused by the construction or operation of this permitted source, or from penalties therefore; nor does it allow the permittee to cause pollution in contravention of F.S. and Department rules, unless specifically authorized by an order from the Department. [Rule 62-4.160(5), F.A.C.]
TV28. Agreements.
: a. The permittee, by accepting this permit, specifically agrees to allow authorized Department personnel, upon presentation of credentials or other documents as may be required by law and at reasonable times, access to the premises where the permitted activity is located or conducted to:
(1) Have access to and copy any records that must be kept under conditions of the permit; (2) Inspect the facility, equipment, practices, or operations regulated or required under this permit; and, (3) Sample or monitor any substances or parameters at any location reasonably necessary to assure compliance with this permit or Department rules. Reasonable time may depend on the nature of the concern being investigated.
: b. In accepting this permit, the permittee understands and agrees that all records, notes, monitoring data and other information relating to the construction or operation of this permitted source which are submitted to the Department may be used by the Department as evidence in any enforcement case involving the permitted source arising under the Florida Statutes or Department rules, except where such use is prescribed by Sections 403.111 and 403.73, F.S. Such evidence shall only be used to the extent it is consistent with the Florida Rules of Civil Procedure and appropriate evidentiary rules.
: c. The permittee agrees to comply with changes in Department rules and Florida Statutes after a reasonable time for compliance; provided, however, the permittee does not waive any other rights granted by Florida Statutes or Department rules.
[Rules 62-4.160(7), (9), and (10), F.A.C.]
Recordkeeping and Emissions Computation TV29. Permit. The permittee shall keep this permit or a copy thereof at the work site of the permitted activity.
[Rule 62-4.160(12), F.A.C.]
TV30. Recordkeeping.
: a. Upon request, the permittee shall furnish all records and plans required under Department rules. During enforcement actions, the retention period for all records will be extended automatically unless otherwise stipulated by the Department.
: a. Upon request, the permittee shall furnish all records and plans required under Department rules. During enforcement actions, the retention period for all records will be extended automatically unless otherwise stipulated by the Department.
: b. The permittee shall hold at the facility or other location designated by this permit records of all monitoring information (including all calibration and maintenance records and all original strip chart recordings for continuous monitoring instrumentation) required by the permit, copies of all reports required by this permit, and records of all data used to complete the application for this permit. These Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-4 of 7 APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) materials shall be retained at least five (5) years from the date of the sample, measurement, report, or application unless otherwise specified by Department rule.c. Records of monitoring information shall include: (1) The date, exact place, and time of sampling or measurements, and the operating conditions at the time of sampling or measurement; (2) The person responsible for performing the sampling or measurements; (3) The dates analyses were performed; (4) The person and company that performed the analyses;(5) The analytical techniques or methods used;(6) The results of such analyses.[Rules 62-4.160(14) and 62-213.440(1  
: b. The permittee shall hold at the facility or other location designated by this permit records of all monitoring information (including all calibration and maintenance records and all original strip chart recordings for continuous monitoring instrumentation) required by the permit, copies of all reports required by this permit, and records of all data used to complete the application for this permit. These Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page TV-4 of 7
)(b)2., F.A.C.]TV31. Emissions Computation.
 
Pursuant to Rule 62-210.370, F.A.C., the following required methodologies are to be used by the owner or operator of a facility for computing actual emissions, baseline actual emissions, and net emissions increase, as defined at Rule 62-210.200, F.A.C., and for computing emissions for purposes of the reporting requirements of subsection 62-210.370(3) and paragraph 62-212.300(1)(e), F.A.C., or of any permit condition that requires emissions be computed in accordance with Rule 62-210.370, F.A.C. Rule 62-210.370, F.A.C., is not intended to establish methodologies for determining compliance with the emission limitations of any air permit.For any of the purposes specified above, the owner or operator of a facility shall compute emissions in accordance with the requirements set forth in this subsection.
APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) materials shall be retained at least five (5) years from the date of the sample, measurement, report, or application unless otherwise specified by Department rule.
: a. Basic Approach.
: c. Records of monitoring information shall include:
The owner or operator shall employ, on a pollutant-specific basis, the most accurate of the approaches set forth below to compute the emissions of a pollutant from an emissions unit; provided, however, that nothing in this rule shall be construed to require installation and operation of any continuous emissions monitoring system (CEMS), continuous parameter monitoring system (CPMS), or predictive emissions monitoring system (PEMS) not otherwise required by rule or permit, nor shall anything in this rule be construed to require performance of any stack testing not otherwise required by rule or permit.(1) If the emissions unit is equipped with a CEMS meeting the requirements of paragraph 62-210.370(2)(b), F.A.C., the owner or operator shall use such CEMS to compute the emissions of the pollutant, unless the owner or operator demonstrates to the department that an alternative approach is more accurate because the CEMS represents still-emerging technology.
(1) The date, exact place, and time of sampling or measurements, and the operating conditions at the time of sampling or measurement; (2) The person responsible for performing the sampling or measurements; (3) The dates analyses were performed; (4) The person and company that performed the analyses; (5) The analytical techniques or methods used; (6) The results of such analyses.
(2) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C, but emissions of the pollutant can be computed pursuant to the mass balance methodology of paragraph 62-210.370(2)(c), F.A.C., the owner or operator shall use such methodology, unless the owner or operator demonstrates to the department that an alternative approach is more accurate.(3) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C., and emissions cannot be computed pursuant to the mass balance methodology, the owner or operator shall use an emission factor meeting the requirements of paragraph 62-210.370(2)(d), F.A.C., unless the owner or operator demonstrates to the department that an alternative approach is more accurate.b. Continuous Emissions Monitoring System (CEMS).(1) An owner or operator may use a CEMS to compute emissions of a pollutant for purposes of this rule provided: (a) The CEMS complies with the applicable certification and quality assurance requirements of 40 CFR Part 60, Appendices B and F, or, for an acid rain unit, the certification and quality assurance requirements of 40 CFR Part 75, all adopted by reference at Rule 62-204.800, F.A.C.; or, (b) The owner or operator demonstrates that the CEMS otherwise represents the most accurate means of computing emissions for purposes of this rule.(2) Stack gas volumetric flow rates used with the CEMS to compute emissions shall be obtained by the most accurate of the following methods as demonstrated by the owner or operator: (a) A calibrated flowmeter that records data on a continuous basis, if available; or Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-5 of 7 APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009)(b) The average flow rate of all valid stack tests conducted during a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit.(3) The owner or operator may use CEMS data in combination with an appropriate f-factor, heat input data, and any other necessary parameters to compute emissions if such method is demonstrated by the owner or operator to be more accurate than using a stack gas volumetric flow rate as set forth at subparagraph 62-210.370(2)(b)2., F.A.C., above.c. Mass Balance Calculations.
[Rules 62-4.160(14) and 62-213.440(1 )(b)2., F.A.C.]
(1) An owner or operator may use mass balance calculations to compute emissions of a pollutant for purposes of this rule provided the owner or operator: (a) Demonstrates a means of validating the content of the pollutant that is contained in or created by all materials or fuels used in or at the emissions unit; and, (b) Assumes that the emissions unit emits all of the pollutant that is contained in or created by any material or fuel used in or at the emissions unit if it cannot otherwise be accounted for in the process or in the capture and destruction of the pollutant by the unit's air pollution control equipment.
TV31. Emissions Computation. Pursuant to Rule 62-210.370, F.A.C., the following required methodologies are to be used by the owner or operator of a facility for computing actual emissions, baseline actual emissions, and net emissions increase, as defined at Rule 62-210.200, F.A.C., and for computing emissions for purposes of the reporting requirements of subsection 62-210.370(3) and paragraph 62-212.300(1)(e), F.A.C., or of any permit condition that requires emissions be computed in accordance with Rule 62-210.370, F.A.C. Rule 62-210.370, F.A.C., is not intended to establish methodologies for determining compliance with the emission limitations of any air permit.
(2) Where the vendor of a raw material or fuel which is used in or at the emissions unit publishes a range of pollutant content from such material or fuel, the owner or operator shall use the highest value of the range to compute the emissions, unless the owner or operator demonstrates using site-specific data that another content within the range is more accurate.(3) In the case of an emissions unit using coatings or solvents, the owner or operator shall document, through purchase receipts, records and sales receipts, the beginning and ending VOC inventories, the amount of VOC purchased during the computational period, and the amount of VOC disposed of in the liquid phase during such period.d. Emission Factors.(1) An owner or operator may use an emission factor to compute emissions of a pollutant for purposes of this rule provided the emission factor is based on site-specific data such as stack test data, where available, unless the owner or operator demonstrates to the department that an alternative emission factor is more accurate.
For any of the purposes specified above, the owner or operator of a facility shall compute emissions in accordance with the requirements set forth in this subsection.
An owner or operator using site-specific data to derive an emission factor, or set of factors, shall meet the following requirements.(a) If stack test data are used, the emission factor shall be based on the average emissions per unit of input, output, or gas volume, whichever is appropriate, of all valid stack tests conducted during at least a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit.(b) Multiple emission factors shall be used as necessary to account for variations in emission rate associated with variations in the emissions unit's operating rate or operating conditions during the period over which emissions are computed.(c) The owner or operator shall compute emissions by multiplying the appropriate emission factor by the appropriate input, output or gas volume value for the period over which the emissions are computed.
: a. Basic Approach. The owner or operator shall employ, on a pollutant-specific basis, the most accurate of the approaches set forth below to compute the emissions of a pollutant from an emissions unit; provided, however, that nothing in this rule shall be construed to require installation and operation of any continuous emissions monitoring system (CEMS), continuous parameter monitoring system (CPMS), or predictive emissions monitoring system (PEMS) not otherwise required by rule or permit, nor shall anything in this rule be construed to require performance of any stack testing not otherwise required by rule or permit.
The owner or operator shall not compute emissions by converting an emission factor to pounds per hour and then multiplying by hours of operation, unless the owner or operator demonstrates that such computation is the most accurate method available.
(1) If the emissions unit is equipped with a CEMS meeting the requirements of paragraph 62-210.370(2)(b), F.A.C., the owner or operator shall use such CEMS to compute the emissions of the pollutant, unless the owner or operator demonstrates to the department that an alternative approach is more accurate because the CEMS represents still-emerging technology.
(2) If site-specific data are not available to derive an emission factor, the owner or operator may use a published emission factor directly applicable to the process for which emissions are computed.
(2) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C, but emissions of the pollutant can be computed pursuant to the mass balance methodology of paragraph 62-210.370(2)(c), F.A.C., the owner or operator shall use such methodology, unless the owner or operator demonstrates to the department that an alternative approach is more accurate.
If no directly-applicable emission factor is available, the owner or operator may use a factor based on a similar, but different, process.e. Accounting for Emissions During Periods of Missing Data from CEMS, PEMS, or CPMS. In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of missing data from CEMS, PEMS, or CPMS using other site-specific data to generate a reasonable estimate of such emissions.
(3) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C.,
Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Pennit Renewal Page TV-6 of 7 APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009)
and emissions cannot be computed pursuant to the mass balance methodology, the owner or operator shall use an emission factor meeting the requirements of paragraph 62-210.370(2)(d), F.A.C., unless the owner or operator demonstrates to the department that an alternative approach is more accurate.
: f. Accounting for Emissions During Periods of Startup and Shutdown.
: b. Continuous Emissions Monitoring System (CEMS).
In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of startup andshutdown of the emissions unit.g. Fugitive Emissions.
(1) An owner or operator may use a CEMS to compute emissions of a pollutant for purposes of this rule provided:
In computing the emissions of a pollutant from a facility or emissions unit, the owner or operator shall account for the fugitive emissions of the pollutant, to the extent quantifiable, associated with such facility or emissions unit.h. Recordkeeping.
(a) The CEMS complies with the applicable certification and quality assurance requirements of 40 CFR Part 60, Appendices B and F, or, for an acid rain unit, the certification and quality assurance requirements of 40 CFR Part 75, all adopted by reference at Rule 62-204.800, F.A.C.; or, (b) The owner or operator demonstrates that the CEMS otherwise represents the most accurate means of computing emissions for purposes of this rule.
The owner or operator shall retain a copy of all records used to compute emissions pursuant to this rule for a period of five years from the date on which such emissions information is submitted to the department for any regulatory purpose.[Rule 62-210.370(1)  
(2) Stack gas volumetric flow rates used with the CEMS to compute emissions shall be obtained by the most accurate of the following methods as demonstrated by the owner or operator:
& (2), F.A.C.]Responsible Official TV32. Designation and Update. The permittee shall designate and update a responsible official as required by Rule 62-213.202, F.A.C.TV33. Asbestos.
(a) A calibrated flowmeter that records data on a continuous basis, if available; or Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page TV-5 of 7
This permit does not authorize any demolition or renovation of the facility or its parts or components which involves asbestos removal. This permit does not constitute a waiver of any of the requirements of Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, National Emission Standard for Asbestos, adopted and incorporated by reference in Rule 62-204.800, F.A.C. Compliance with Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, Section 61.145, is required for any asbestos demolition or renovation at the source. [40 CFR 61; Rule 62-204.800, F.A.C.; and, Chapter 62-257, F.A.C.]TV34. Refrigerant Requirements.
 
Any facility having refrigeration equipment, including air conditioning equipment, which uses a Class I or II substance (listed at 40 CFR 82, Subpart A, Appendices A and B), and any facility which maintains, services, or repairs motor vehicles using a Class I or Class II substance as refrigerant must comply with all requirements of 40 CFR 82, Subparts B and F, and with Chapter 62-281, F.A.C.TV35. Open Burning Prohibited.
APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009)
Unless otherwise authorized by Rule 62-296.320(3) or Chapter 62-256, F.A.C., open burning is prohibited.
(b) The average flow rate of all valid stack tests conducted during a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit.
Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page TV-7 of 7 APPENDIX U LIST OF UNREGULATED EMISSIONS UNITS AND/OR ACTIVITIES.
(3) The owner or operator may use CEMS data in combination with an appropriate f-factor, heat input data, and any other necessary parameters to compute emissions if such method is demonstrated by the owner or operator to be more accurate than using a stack gas volumetric flow rate as set forth at subparagraph 62-210.370(2)(b)2., F.A.C., above.
Unregulated Emissions Units and/or Activities.
: c. Mass Balance Calculations.
An emissions unit which emits no "emissions-limited pollutant" and which is subject to no unit-specific work practice standard, though it may be subject to regulations applied on a facility-wide basis (e.g., unconfined emissions, odor, general opacity) or to regulations that require only that it be able to prove exemption from unit-specific emissions or work practice standards.
(1) An owner or operator may use mass balance calculations to compute emissions of a pollutant for purposes of this rule provided the owner or operator:
The below listed emissions units and/or activities are neither 'regulated emissions units' nor 'insignificant emissions units'.E.U. ID No. Brief Description of Emissions Units and/or Activity 017 Fuel and lube oil tanks and vents 1 018 Sewage treatment, water treatment, lime storage 2 019 Two 3500 kW diesel generators associated with Unit 3-Notes: 1. This unregulated emissions unit consists of the following facilities:
(a) Demonstrates a means of validating the content of the pollutant that is contained in or created by all materials or fuels used in or at the emissions unit; and, (b) Assumes that the emissions unit emits all of the pollutant that is contained in or created by any material or fuel used in or at the emissions unit if it cannot otherwise be accounted for in the process or in the capture and destruction of the pollutant by the unit's air pollution control equipment.
Associated with Units 1 and 2: Number 2 fuel oil, 210,000 gal capacity, tank # 10.Lube oil vents, one each at Unit 1 and 2.Rotoclone with air filter at Unit 1.Oil vent at Unit 1.Associated with Unit 3: Equipment diesel tanks, tanks 2 through 8, 15, 16, 22 and 23, capacities from 30 gallons to 30,118 gallons.Lube oil tank, 25,000 gallon capacity, tank #9.Two small cooling towers west of Main Building.Two lube oil vents.Associated with Units 4 and 5: Number 2 fuel oil, 256,200 gal capacity, tank # 1, and 255,318 gal capacity, tank # 2.Equipment diesel tanks, tanks 3 and 4, capacity of 250 gallons, each.Lube oil tank, 30,000 gallon capacity, tank #16.Lube oil vents.Associated with the Crystal River Site: Equipment diesel tanks, E.O.F. #01, capacity of 2,000 gallons and E.O.F. # 02, capacity of 25 gallons.Waste oil tank, Garage # 01, 150 gallon capacity.Mineral spirits tanks, O.C. # 01, 80 gallon capacity, N. Sub. # 04, 1,100 gallon capacity.Transmission oil tanks, N. Sub. # 01 through 03, capacity of 1,100 gallons each.UST for diesel-2 @ 10,000 gallons each and one @ 20,000 gal UST for gasoline -1 @ 10,000 gallons 2. This unregulated emissions unit consists of the following facilities:
(2) Where the vendor of a raw material or fuel which is used in or at the emissions unit publishes a range of pollutant content from such material or fuel, the owner or operator shall use the highest value of the range to compute the emissions, unless the owner or operator demonstrates using site-specific data that another content within the range is more accurate.
Associated with Units 1, 2, 4 and 5: Water treatment systems for all EUSGUs.Sewage treatment plant.Lime storage.3. These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page U-1 of 1 ATTACHMENTS (INCLUDED FOR CONVENIENCE)
(3) In the case of an emissions unit using coatings or solvents, the owner or operator shall document, through purchase receipts, records and sales receipts, the beginning and ending VOC inventories, the amount of VOC purchased during the computational period, and the amount of VOC disposed of in the liquid phase during such period.
: d. Emission Factors.
(1) An owner or operator may use an emission factor to compute emissions of a pollutant for purposes of this rule provided the emission factor is based on site-specific data such as stack test data, where available, unless the owner or operator demonstrates to the department that an alternative emission factor is more accurate. An owner or operator using site-specific data to derive an emission factor, or set of factors, shall meet the following requirements.
(a) If stack test data are used, the emission factor shall be based on the average emissions per unit of input, output, or gas volume, whichever is appropriate, of all valid stack tests conducted during at least a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit.
(b) Multiple emission factors shall be used as necessary to account for variations in emission rate associated with variations in the emissions unit's operating rate or operating conditions during the period over which emissions are computed.
(c) The owner or operator shall compute emissions by multiplying the appropriate emission factor by the appropriate input, output or gas volume value for the period over which the emissions are computed. The owner or operator shall not compute emissions by converting an emission factor to pounds per hour and then multiplying by hours of operation, unless the owner or operator demonstrates that such computation is the most accurate method available.
(2) If site-specific data are not available to derive an emission factor, the owner or operator may use a published emission factor directly applicable to the process for which emissions are computed. If no directly-applicable emission factor is available, the owner or operator may use a factor based on a similar, but different, process.
: e. Accounting for Emissions During Periodsof Missing Datafrom CEMS, PEMS, or CPMS. In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of missing data from CEMS, PEMS, or CPMS using other site-specific data to generate a reasonable estimate of such emissions.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                       Title V Pennit Renewal Page TV-6 of 7
 
APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009)
: f. Accounting for Emissions During Periods of Startup and Shutdown. In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of startup andshutdown of the emissions unit.
: g. Fugitive Emissions. In computing the emissions of a pollutant from a facility or emissions unit, the owner or operator shall account for the fugitive emissions of the pollutant, to the extent quantifiable, associated with such facility or emissions unit.
: h. Recordkeeping. The owner or operator shall retain a copy of all records used to compute emissions pursuant to this rule for a period of five years from the date on which such emissions information is submitted to the department for any regulatory purpose.
[Rule 62-210.370(1) & (2), F.A.C.]
Responsible Official TV32. Designation and Update. The permittee shall designate and update a responsible official as required by Rule 62-213.202, F.A.C.
TV33. Asbestos. This permit does not authorize any demolition or renovation of the facility or its parts or components which involves asbestos removal. This permit does not constitute a waiver of any of the requirements of Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, National Emission Standard for Asbestos, adopted and incorporated by reference in Rule 62-204.800, F.A.C. Compliance with Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, Section 61.145, is required for any asbestos demolition or renovation at the source. [40 CFR 61; Rule 62-204.800, F.A.C.; and, Chapter 62-257, F.A.C.]
TV34. Refrigerant Requirements. Any facility having refrigeration equipment, including air conditioning equipment, which uses a Class I or II substance (listed at 40 CFR 82, Subpart A, Appendices A and B), and any facility which maintains, services, or repairs motor vehicles using a Class I or Class II substance as refrigerant must comply with all requirements of 40 CFR 82, Subparts B and F, and with Chapter 62-281, F.A.C.
TV35. Open Burning Prohibited. Unless otherwise authorized by Rule 62-296.320(3) or Chapter 62-256, F.A.C., open burning is prohibited.
Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                      Title V Permit Renewal Page TV-7 of 7
 
APPENDIX U LIST OF UNREGULATED EMISSIONS UNITS AND/OR ACTIVITIES.
Unregulated Emissions Units and/or Activities. An emissions unit which emits no "emissions-limited pollutant" and which is subject to no unit-specific work practice standard, though it may be subject to regulations applied on a facility-wide basis (e.g., unconfined emissions, odor, general opacity) or to regulations that require only that it be able to prove exemption from unit-specific emissions or work practice standards.
The below listed emissions units and/or activities are neither 'regulated emissions units' nor 'insignificant emissions units'.
E.U. ID No.                       Brief Description of Emissions Units and/or Activity 017       Fuel and lube oil tanks and vents1              2 018       Sewage treatment, water treatment, lime storage 019       Two 3500 kW diesel generators associated with Unit 3-Notes:
: 1. This unregulated emissions unit consists of the following facilities:
Associated with Units 1 and 2:
Number 2 fuel oil, 210,000 gal capacity, tank # 10.
Lube oil vents, one each at Unit 1 and 2.
Rotoclone with air filter at Unit 1.
Oil vent at Unit 1.
Associated with Unit 3:
Equipment diesel tanks, tanks 2 through 8, 15, 16, 22 and 23, capacities from 30 gallons to 30,118 gallons.
Lube oil tank, 25,000 gallon capacity, tank #9.
Two small cooling towers west of Main Building.
Two lube oil vents.
Associated with Units 4 and 5:
Number 2 fuel oil, 256,200 gal capacity, tank # 1, and 255,318 gal capacity, tank # 2.
Equipment diesel tanks, tanks 3 and 4, capacity of 250 gallons, each.
Lube oil tank, 30,000 gallon capacity, tank #16.
Lube oil vents.
Associated with the Crystal River Site:
Equipment diesel tanks, E.O.F. #01, capacity of 2,000 gallons and E.O.F. # 02, capacity of 25 gallons.
Waste oil tank, Garage # 01, 150 gallon capacity.
Mineral spirits tanks, O.C. # 01, 80 gallon capacity, N. Sub. # 04, 1,100 gallon capacity.
Transmission oil tanks, N. Sub. # 01 through 03, capacity of 1,100 gallons each.
UST for diesel-2 @ 10,000 gallons each and one @ 20,000 gal UST for gasoline - 1 @ 10,000 gallons
: 2. This unregulated emissions unit consists of the following facilities:
Associated with Units 1, 2, 4 and 5:
Water treatment systems for all EUSGUs.
Sewage treatment plant.
Lime storage.
: 3. These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.
Progress Energy Florida, Inc.                                                             Permit No. 0170004-024-AV Crystal River Power Plant                                                                     Title V Permit Renewal Page U-1 of 1
 
ATTACHMENTS (INCLUDED FOR CONVENIENCE)
The following attachments are included for convenient reference:
The following attachments are included for convenient reference:
Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996).Table H, Permit Summary.Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal FIGURE 1--
Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996).
Table H, Permit Summary.
Progress Energy Florida, Inc.                                   Permit No. 0170004-024-AV Crystal River Power Plant                                          Title V Permit Renewal
 
FIGURE 1--


==SUMMARY==
==SUMMARY==
REPORT--GASEOUS AND OPACITY EXCESS EMISSION AND MONITORING SYSTEM PERFORMANCE (INCLUDED FOR CONVENIENCE)
REPORT--GASEOUS AND OPACITY EXCESS EMISSION AND MONITORING SYSTEM PERFORMANCE (INCLUDED FOR CONVENIENCE)
[Note: This form is referenced in 40 CFR 60.7, Subpart A-General Provisions]
[Note: This form is referenced in 40 CFR 60.7, Subpart A-General Provisions]
Pollutant (Circle One): SO 2 NO, TRS Reporting period dates: From H 2 S CO Opacity to Company: Emission Limitation:
Pollutant (Circle One):         SO 2           NO,             TRS           H2 S    CO          Opacity Reporting period dates:       From                                                       to Company:
Address: Monitor Manufacturer:
Emission Limitation:
Model No.: Date of Latest CMS Certification or Audit: Process Unit(s)
Address:
Monitor Manufacturer:
Model No.:
Date of Latest CMS Certification or Audit:
Process Unit(s)


== Description:==
== Description:==


Total source operating time in reporting period 1: Emission data summary 1 CMS performance summary1 1. Duration of excess emissions in reporting period due to: a. Startup/shutdow n .................................................
Total source operating time in reporting period 1:
: b. Control equipment problems ...............................
Emission data summary 1                                                                 CMS performance summary1
: c. Process problem s .................................................
: 1. Duration of excess emissions in reporting period due to:                              1. CMS downtime in reporting period due to:
: d. O ther know n causes ............................................
: a. Startup/shutdow n .................................................                 a. Monitor equipment malfunctions .........................             .
: e. U nknow n causes ..................................................
: b. Control equipment problems ...............................                           b. Non-Monitor equipment malfunctions ................
: 2. Total duration of excess emissions
: c. Process problem s .................................................                 c. Quality assurance calibration ...............................         .
.......................
: d. O ther know n causes ............................................                   d. O ther know n causes .............................................
: 3. Total duration of excess emissions x (100) / [Total source operating time] ...........................................  
: e. U nknow n causes ..................................................                 e. U nknow n causes ..................................................
%2 1. CMS downtime in reporting period due to: a. Monitor equipment malfunctions
: 2. Total duration of excess emissions .......................                           2. Total CM S D owntim e ..........................................
.........................  
: 3. Total duration of excess emissions x (100) / [Total                                  3. [Total CMS Downtime] x (100) / [Total source source operating time] ...........................................             %    operating tim e] ................................................   . ..... %2 2
.b. Non-Monitor equipment malfunctions
I 2
................
For For opacity, recordperiod:
: c. Quality assurance calibration
the reporting    all timesIf the in total minutes. durationFor gases,     record of excess      all timesis in emissions          hours. or greater of the total operating time or 1 percent the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in 40 CFR 60.7(c) shall be submitted.
...............................  
Note: On a separatepage, describe any changes since last quarter in CMS, process or controls.
.d. O ther know n causes .............................................
I certify that the information contained in this report is true, accurate, and complete.
: e. U nknow n causes ..................................................
Name:
: 2. Total CM S D owntim e ..........................................
Signature:                                                                                                       Date:
: 3. [Total CMS Downtime]
Title:
x (100) / [Total source operating tim e] ................................................  
Progress Energy Florida, Inc.                                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                                    Title V Permit Renewal
...... % 2 I For opacity, record all times in minutes. For gases, record all times in hours.2 For the reporting period: If the total duration of excess emissions is 1 percent or greater of the total operating time or the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in 40 CFR 60.7(c) shall be submitted.
 
Note: On a separate page, describe any changes since last quarter in CMS, process or controls.I certify that the information contained in this report is true, accurate, and complete.Name: Signature:
TABLE H PERMIT HISTORY E.U.                                                                                               Issue     Expiration Extended   Revised ID No.                               Description                               Permit No.           Date         Date       Date   Date(s) 001       Unit 1                                                     AO 09-169341               12/20/89   12/18/94           2/11/94 2/6/97 6/30/99 002       Unit 2                                                     AO 09-191820               5/21/91     5/21/96             6/24/91 2/11/94 2/6/97 6/30/99 001 &       Units I and 2                                             0170004-002-AO             9/16/96 002       Used Oil Firing                                           (Mod. of above permits) 004, 003,     Units 4 & 5, & Cooling Towers for 4 & 5                   PSD Permit                 3/30/78                         11/30/88 015                                                                   PSD-FL-007                 2/27/80 004,       Power Plant Siting Certification, Units 4 & 5             PA 77-09                   11/21/78                         2/22/80 003       (Incl. Limits on Sulfur for Units 1 & 2)                                                                               5/22/80 5/6/82 2/2/84 7/3/84 9/12/97 6/30/99 006, 008, 009,   Units 1 & 2 Flyash Handling System (Sources 1, 4 &5)       AC 09-184438               11/9/90     10/31/91 010                                                                   AC 09-256791               11/17/94   01/15/96 (Replaced AC 09-184438) 008       Units 1 & 2 Flyash Transfer Silo (Source 3)               AO 09-193593               3/26/91     10/31/91 006,008,009,     Units 1 & 2 Flyash Handling System (Sources 1, 3, 4 & 5)   AO 09-202440               11/8/91     10/31/96 010 014       Units 1 & 2 Bottom/Economizer Ash Handling System         AC 09-235915               10/4/93     6/1/94 014       Units 1 & 2 Bottom Ash Handling                           AO 09-248541               7/21/94     7/15/99 012       Diesel Generators                                         AO 09-205952               4/27/92     3/31/97 013       Four Helper Cooling Towers                                 AC 09-162037 & PSD-       8/29/90     10/1/93   12/1/93 FL-139 013       Four Helper Cooling Towers                                 AO 09-236827               10/20/93     10/1/98 All       Initial Title V Permit                                     0170004-004-AV             01/01/00     12/31/04           3/29/01 All       Title V Renewal                                           0170004-009-AV             01/01/04     12/31/09 020       New Cooling Tower                                         0170004-010-AC             04/03/06   04/30/07 Title V Revision to Include Cooling Tower                 0170004-011-AV             06/09/06     12/31/09 Trial Burn of PRB Coal                                     0170004-012-AC             04/26/06   05/01/07 003,004       SCR project on Units 4 and 5                               0170004-013-AC             03/02/07   03/02/10 016       Coal Yard Modification                                     0170004-014-AC             12/15/06   06/30/08 016       Title V Revision to Include Coal Yard Modification         0170004-015-AV             02/22/07     12/31/09 Progress Energy Florida, Inc.                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                        Title V Permit Renewal Page H- I of 2
Date: Title: Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal TABLE H PERMIT HISTORY E.U. Issue Expiration Extended Revised ID No. Description Permit No. Date Date Date Date(s)001 Unit 1 AO 09-169341 12/20/89 12/18/94 2/11/94 2/6/97 6/30/99 002 Unit 2 AO 09-191820 5/21/91 5/21/96 6/24/91 2/11/94 2/6/97 6/30/99 001 & Units I and 2 0170004-002-AO 9/16/96 002 Used Oil Firing (Mod. of above permits)004, 003, Units 4 & 5, & Cooling Towers for 4 & 5 PSD Permit 3/30/78 11/30/88 015 PSD-FL-007 2/27/80 004, Power Plant Siting Certification, Units 4 & 5 PA 77-09 11/21/78 2/22/80 003 (Incl. Limits on Sulfur for Units 1 & 2) 5/22/80 5/6/82 2/2/84 7/3/84 9/12/97 6/30/99 006, 008, 009, Units 1 & 2 Flyash Handling System (Sources 1, 4 &5) AC 09-184438 11/9/90 10/31/91 010 AC 09-256791 11/17/94 01/15/96 (Replaced AC 09-184438)008 Units 1 & 2 Flyash Transfer Silo (Source 3) AO 09-193593 3/26/91 10/31/91 006,008,009, Units 1 & 2 Flyash Handling System (Sources 1, 3, 4 & 5) AO 09-202440 11/8/91 10/31/96 010 014 Units 1 & 2 Bottom/Economizer Ash Handling System AC 09-235915 10/4/93 6/1/94 014 Units 1 & 2 Bottom Ash Handling AO 09-248541 7/21/94 7/15/99 012 Diesel Generators AO 09-205952 4/27/92 3/31/97 013 Four Helper Cooling Towers AC 09-162037  
 
& PSD- 8/29/90 10/1/93 12/1/93 FL-139 013 Four Helper Cooling Towers AO 09-236827 10/20/93 10/1/98 All Initial Title V Permit 0170004-004-AV 01/01/00 12/31/04 3/29/01 All Title V Renewal 0170004-009-AV 01/01/04 12/31/09 020 New Cooling Tower 0170004-010-AC 04/03/06 04/30/07 Title V Revision to Include Cooling Tower 0170004-011-AV 06/09/06 12/31/09 Trial Burn of PRB Coal 0170004-012-AC 04/26/06 05/01/07 003,004 SCR project on Units 4 and 5 0170004-013-AC 03/02/07 03/02/10 016 Coal Yard Modification 0170004-014-AC 12/15/06 06/30/08 016 Title V Revision to Include Coal Yard Modification 0170004-015-AV 02/22/07 12/31/09 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page H- I of 2 TABLE H PERMIT HISTORY E.U. Issue Expiration Extended Revised ID No. Description Permit No. Date Date Date Date(s)003, 004 FGD Project Units 4 and 5 0170004-016-AC 05/18/07 11/01/11 001 -004 BART Project 0170004-017-AC 02/26/09 07/01/14 013,027 Unit 3 Uprate Cooling Tower 0170004-018-AC 10/12/07 10/12/12 003, 004 Units 4 and 5 Control Project 0170004-019-AC 02/26/09 11/01/11 001-004 Title V CAIR Revision 0170004-020-AC 01/30/09 12/31/09 003, 004 Units 4 and 5 Upgrades 0170004-022-AC 05/11/09 11/01/11 003,004 Revisions for Alkali Injection on Units 4 and 5 0170004-023-AC All Title V Renewal 0170004-024-AV 01/01/10 12/31/14 ID Number Changes (for tracking purposes):
TABLE H PERMIT HISTORY E.U.                                                                                           Issue   Expiration Extended Revised ID No.                               Description                           Permit No.           Date       Date     Date   Date(s) 003, 004     FGD Project Units 4 and 5                             0170004-016-AC           05/18/07   11/01/11 001 -004       BART Project                                           0170004-017-AC           02/26/09   07/01/14 013,027       Unit 3 Uprate Cooling Tower                           0170004-018-AC           10/12/07   10/12/12 003, 004     Units 4 and 5 Control Project                         0170004-019-AC           02/26/09   11/01/11 001-004       Title V CAIR Revision                                 0170004-020-AC           01/30/09   12/31/09 003, 004     Units 4 and 5 Upgrades                                 0170004-022-AC           05/11/09   11/01/11 003,004       Revisions for Alkali Injection on Units 4 and 5       0170004-023-AC All       Title V Renewal                                       0170004-024-AV           01/01/10   12/31/14 ID Number Changes (for tracking purposes):
From: Facility ID No.: 09TPA0004 To: Facility ID No.: 0170004 Progress Energy Florida, Inc.Crystal River Power Plant Permit No. 0170004-024-AV Title V Permit Renewal Page H-2 of 2 U. S. Nuclear Regulatory Commission 3F0410-04 Response to Request for Documents RAI 3-1 Crystal River Mariculture Center Juvenile Releases PROGRESS ENERGY CRYSTAL RIVER MARICULTURE CENTER FINGERLING/JUVENILE RELEASE  
From: Facility ID No.: 09TPA0004 To: Facility ID No.: 0170004 Progress Energy Florida, Inc.                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                  Title V Permit Renewal Page H-2 of 2
 
U. S. Nuclear Regulatory Commission                             Response to 3F0410-04                                           Request for Documents RAI 3-1 Crystal River Mariculture Center Juvenile Releases
 
PROGRESS ENERGY CRYSTAL RIVER MARICULTURE CENTER FINGERLING/JUVENILE RELEASE  


==SUMMARY==
==SUMMARY==
RED RED DRUM SPOTTED SPO EDSTRIPED YEAR SEATROUT PINK SHRIMP PIGFISH SILVER PERCH STONE CRAB BLUE CRAB D R U M _ _ L A R V A E _ L A VAEA T R O U T_ _ _ _ _ _ _ _ _ _ _ _ _ _ M U L L E T _ _ _ _ _ _ _ _ _LARVAE 1992 17,519 0 0 0 0 0 0 0 0 0 1993 169,165 0 6,908 0 0 0 0 0 0 0 1994 12,204 0 55,304 0 0 0 0 0 0 0 1995 26,900 0 60,189 0 12,000 0 0 0 0 0 1996 50,795 0 32,994 0 7,750 0 0 0 0 0 1997 0 0 0 0 0 pond trials 0 0 0 0 1998 157,833 800,000 171,350 425,000 0 pond trials 0 0 0 0 1999 67,227 575,500 40,536 290,000 34,541 25,000 first feeding 0 0 0 0 larvae controlled spawning/I  
 
,300,000 2000 285,366 0 11,000 0 9,839 0 first feeding 0 0 0 larvae/pond trial (none released)2001 16,251 0 130 0 91,079 indoor culture 0 0 0 0 controlled 2002 4,070 0 250,054 0 36,934 indoor culture 0 spawning/pond trial 0 0 1 _(none released)2003 125,064 0 163,200 0 49755 500,000 first 0 39,942 first feeding 692,000 zoea stage I controlled spawning and feeding larvae larvae pond trial (none released)2004 15,000 0 16,500 0 0 0 0 0 4,000,000 Zoea I 35,000,000 Zoea I 2005 0 0 4,768 0 87,374 0 0 0 8,767,055 Zoea I 31,447,656 Zoea I 2006 0 0 81,700 0 42,830 0 0 0 14,851,847 Zoea 1 15,475,245 Zoea 1 2007 0 0 70,000 0 43,000 0 0 0 4,729,060 Zoea 1 11,823,380 Zoea 1 2008 0 0 75,180 0 0 0 0 0 0 0 2009 0 0 92,000 0 0 0 0 0 0 0'Totals 947,394 1,375.500 1,131,813 715,00 415,02 525,000 first 39,942 first feeding 32,347,962 zoea 93,746,281 Z1 t feeding larvae 0 larvae stage I U. S. Nuclear Regulatory Commission 3F0410-04 Response to Request for Documents RAI 3-2 & RAI 5-1 Env Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida}}
RED     RED DRUM             SPOTTED         SPO   EDSTRIPED YEAR                                                     SEATROUT DR U M_ _   L A R V A E_            T R O UT_  LA VAEA PINK SHRIMP LARVAE                          _M U
_ L
_ LE_ T_ _     __
PIGFISH
_   __  __
SILVER PERCH          STONE CRAB
_ __
BLUE CRAB
_ _ _ _   __
1992     17,519         0                   0             0               0               0                       0                 0                     0                     0 1993     169,165         0                 6,908           0               0               0                       0                 0                     0                     0 1994       12,204         0               55,304           0               0               0                       0                 0                     0                     0 1995     26,900           0               60,189           0             12,000             0                       0                 0                     0                     0 1996     50,795           0               32,994           0             7,750             0                       0                 0                     0                     0 1997         0           0                   0           0               0           pond trials                 0                   0                   0                       0 1998     157,833     800,000             171,350       425,000             0           pond trials                 0                   0                   0                       0 1999     67,227       575,500             40,536       290,000         34,541   25,000 first feeding             0                   0                   0                       0 larvae controlled spawning/I ,300,000 2000     285,366           0               11,000           0             9,839             0               first feeding             0                   0                       0 larvae/pond trial (none released) 2001       16,251         0                 130           0             91,079       indoor culture               0                   0                   0                       0 controlled 2002       4,070           0               250,054           0             36,934       indoor culture               0         spawning/pond trial           0                       0 1             _(none                                                                                               released) 2003     125,064           0               163,200           0             49755         500,000 first               0         39,942 first feeding 692,000 zoea stage I controlled spawning and feeding larvae                                 larvae                             pond trial (none released) 2004     15,000           0               16,500           0               0               0                     0                   0           4,000,000 Zoea I       35,000,000 Zoea I 2005         0             0                 4,768           0             87,374             0                     0                   0           8,767,055 Zoea I       31,447,656 Zoea I 2006       0             0               81,700           0             42,830             0                     0                 0           14,851,847 Zoea 1       15,475,245 Zoea 1 2007         0             0             70,000             0           43,000               0                     0                 0           4,729,060 Zoea 1       11,823,380 Zoea 1 2008         0             0             75,180             0               0               0                     0                 0                     0                       0 2009         0             0             92,000             0               0               0                     0                 0                     0                       0
'Totals   947,394     1,375.500           1,131,813       715,00         415,02         525,000 first                         39,942 first feeding   32,347,962 zoea         93,746,281 Z1 t                                                                               feeding larvae               0               larvae               stage I
 
U. S. Nuclear Regulatory Commission                           Response to 3F0410-04                                         Request for Documents RAI 3-2 & RAI 5-1 Env Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida}}

Latest revision as of 19:23, 13 November 2019

Response to Request for Additional Information for the Review of the License Renewal Application - Environmental Document Request
ML101320400
Person / Time
Site: Crystal River Duke Energy icon.png
Issue date: 04/01/2010
From: Franke J
Florida Power Corp, Progress Energy Florida
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
3F0410-04, TAC ME0278
Download: ML101320400 (275)
v • d • e


Text

{{#Wiki_filter:0Progress Energy Crystal River Nuclear Plant Docket No. 50-302 Operating License No. DPR-72 Ref: 10 CFR 54 April 1, 2010 3F0410-04 50 0ý U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001

Subject:

Crystal River Unit 3 - Response to Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278) - Environmental Document Request

References:

(1) CR-3 to NRC letter, dated December 16, 2008, "Crystal River Unit 3 - Application for Renewal of Operating License" (2) NRC to CR-3, letter dated March 5, 2010, "Request for Additional Information for the Review of the Crystal River Unit 3 Nuclear Generating Plant, License Renewal Application (TAC NO. ME0278)"

Dear Sir:

On December 16, 2008, Florida Power Corporation (FPC), doing business as Progress Energy Florida, Inc. (PEF), requested renewal of the operating license for Crystal River Unit 3 (CR-3) to extend the term of its operating license an additional 20 years beyond the current expiration date (Reference 1). Subsequently, the Nuclear Regulatory Commission (NRC), by letter dated March 5, 2010, provided a request for additional information (RAI) concerning the CR-3 License Renewal Application (LRA) and a request for documents (Reference 2). The Enclosure to this letter provides the response to the request for documents. A response to the RAI is being provided in a separate letter (CR-3 letter 3F0410-03 dated April 1, 2010). No new regulatory commitments are contained in this submittal. If you have any questions regarding this submittal, please contact Mr. Mike Heath, Supervisor, License Renewal, at (910) 457-3487, e-mail at mike.heath@pgnmail.com. ce President Crystal River Unit 3 JAF/dwh

Enclosure:

Response to Request for Documents xc: NRC CR-3 Project Manager NRC License Renewal Project Manager NRC Regional Administrator, Region II Senior Resident Inspector Progress Energy Florida, Inc. Crystal River Nuclear Plant 15760 W. Power Line Street Crystal River, FL 34428

PROGRESS ENERGY FLORIDA, INC. CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50 - 302 / LICENSE NUMBER DPR - 72 ENCLOSURE RESPONSE TO REQUEST FOR DOCUMENTS

U. S. Nuclear Regulatory Commission Enclosure 3F0410-04 Page 1 of 5 RESPONSE TO REQUEST FOR DOCUMENTS The following requests for additional information are needed by the U.S. Nuclear Regulatory Commission (NRC) staff to complete its review of the Crystal River Nuclear Generating Plant, Unit 3 (CR-3) application for license renewal and prepare the draft supplemental environmental impact statement. To support the staff's continued review of the CR-3 environmental report (ER), please provide the information and documents described below. Those items marked with letter and number (i.e., AQ-1, H-2, etc.) refer to corresponding items in the Revised Environmental Site Audit Needs List dated October 6, 2009. RAI 1 - Cumulative Impacts NRC staff must evaluate the cumulative impacts of extended operation of all reasonably foreseeable activities. The following information is needed to complete the cumulative impact evaluation.

1. Provide information on the status of the refurbishment activities discussed in Section 3.2 of the ER. Also, provide information on when the power uprate amendment is expected to be submitted.

Response

The response to this request is being submitted in a separateletter.

2. Provide information on the resources that would be affected by the construction of the proposed Levy County nuclear plants' cooling tower discharge line to the CR-3 discharge canal. Also provide a summary of impacts the potentially chemically-treated cooling water from the Levy County plants may have on the CR-3 discharge canal.

Response

The response to this request is being submitted in a separateletter. RAI 2 - Air Quality and Meteorology

1. Provide documentation demonstrating that Progress Energy submitted an application to renew its Title V permit to the Florida Department of Environmental Protection (FL DEP) on or before the renewal application due date of July 5, 2009, specified in the permit and that the renewal application was accepted by FL DEP, allowing the Title V Permit to remain in effect past its expiration date during FL DEP's processing of the renewal application.

Response

Refer to the enclosed document "RAI 2-1 Title V Permit."

U. S. Nuclear Regulatory Commission Enclosure 3F0410-04 Page 2 of 5 RAI 3 - Aquatic Ecology

1. Provide a summary of releases from the Progress Energy Mariculture Center 1992-2008.

Response

Refer to the enclosed document "RAI 3-1 CrystalRiver MaricultureCenter Juvenile Releases."

2. Progress Energy 2009 - Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida;

Response

Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida."

3. Ager et al. 2008 - Crystal River Power Plant Fish Impingement Study Report. Please provide the entire report, if possible. Otherwise provide the following:
  • Executive Summary
  • Chapter 2 (including the figures and tables)
  • Tables 4 through 11, 13 through 20, and 34 through 40
  • Figures 3 through 4, 6 through 19
  • Appendices 1 through 32

Response

Refer to the enclosed document "RAI 3-3 Crystal River Impingement Report March 3, 2008."

4. Copies of the 1993-1995 Seagrass Monitoring Reports, November 2001 Seagrass Recovery Report, the 2008 Seagrass Quantification Report, and the final report of the Seagrass Technical Advisory Committee.

Response

Refer to the enclosed documents: 

           *   "RAI 3-4  CR Seagrass TechnicalAdvisory Committee Final Report,"
           *   "RAI 3-4  CrystalRiver 1993 SeagrassStudy,"
           *   "RAI 3-4  CrystalRiver 1994 SeagrassStudy,"
           *   "RAI 3-4  CrystalRiver 1995 SeagrassStudy,"
           *   "RAI 3-4  CrystalRiver November 2001 SeagrassSurvey, " and
           *   "RAI 3-4  Seagrass QuantificationReport_4-24-08."
5. TP-042 Marine Turtle Permit (the current annual permit).

Response

Refer to the enclosed document "RAI 3-5 Marine Turtle Permit."

U. S. Nuclear Regulatory Commission Enclosure 3F0410-04 Page 3 of 5

6. AQ-1 (Also T-20) - The response letters from National Marine Fisheries Service (NMFS) and Florida Wildlife Commission regarding listed species and sensitive habitats were not provided (only the Fish and Wildlife Service (FWS) response letter was provided).

Correspondence from NMFS and Florida or a statement that none exists should be provided.

Response

Refer to the enclosed document "RAI 3-6 National Marine Fisheries Service Letter." In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.

7. Provide copies of the reports prepared by Applied Biology, Inc (1983), Florida Power Corporation (FPC) (1978b), FPC (1 982b). Complete citations for these reports are listed on page 4-2 of the 316 Study.

Response

Refer to the enclosed document "RAI 3-7 Crystal River 3 Impingement Study (1978b)." A statement that the other two requested documents could not be located is provided in a separate letter. RAI 4- Hydrology

1. H-9 (also H-5) - Quarterly National Pollutant Discharge Elimination System, Industrial Waste Water, Domestic Waste Water monitoring reports (for past 5 years) with cover letters to the FL DEP. Provide the full reports and cover letters. Spreadsheets of sampling data were previously submitted, however the reports provide more comprehensive information on what was sampled, standards measured against, exceedances, explanations for exceedances, and corrective actions as well as maps and other useful information.

If the quarterly data is summarized in annual reports, then therannual reports may be submitted instead of the quarterly reports. Because these documents can be large, electronic files can be submitted in lieu of hardcopies.

Response

Refer to the enclosed National Pollutant Discharge Elimination System (NPDES), Industrial Waste Water (IWW), and Domestic Waste Water (DWW) documents: 

           *   "RAI 4  2005 NPDES Reports,"
           *   "RAI 4  2006 NPDES Reports,"

o "RAI 4 2007 NPDES Reports," 

           *   "RAI 4  2008 NPDES Reports,"
           *   "RAI 4  2009 NPDES Reports,"
           *   "RAI 4  2005 IWW Reports,"

U. S. Nuclear Regulatory Commission Enclosure 3F0410-04 Page 4 of 5 

           *   "RAI 4  2006 IWW Reports,"
           *   "RAI 4  2007 IVWV Reports,"
           *   "RAI 4  2008 IWVV Reports,"
           *   "RAI 4  2009 IWVVW Reports,"
           *   "RAI 4  2005 DWW Reports,"
           *   "RAI 4  2006 DWW Reports,"
           *   "RAI 4  2007 DWW Reports,"
           *   "RAI 4  2008 DWW Reports," and
           *   "RAI 4  2009 DWW Reports."

RAI 5 - Terrestrial Ecology

1. T Provide the tables, figures, and appendices from the report "Environmental Support Document, Crystal River Unit 3, South Cooling Tower Laydown Area, Citrus County Florida."

Response

Refer to the enclosed document "RAI 3-2 & RAI 5-1 Environmental Support Document CrystalRiver Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida."

2. T The November 5, 2009, request for additional information response provided a map of the percolation ponds and an FWS wood stork colonies core foraging areas map, but there is no explanatory text provided.

Provide a brief description of wood stork use of the site along with an explanation of how the two figures relate to that use. Provide the source for the FWS wood stock map so it can be properly cited.

Response

The response to this request is being submitted in a separate letter.

3. T No information was provided on measures to protect threatened or endangered species during transmission line ROW maintenance. The letter from the FWS to Progress Energy (October 28, 2008) regarding impacts to the listed eastern indigo snake provides recommendations for mitigation for this species when carrying out transmission line maintenance, including the submission of a protection/education plan that, if implemented, would result in a "may affect, not likely to adversely affect" determination.

Provide a transmission line ROW maintenance plan per the recommendations of the FWS to protect the eastern indigo snake and its habitat that includes the protection/education plan referenced above.

Response

The response to this request is being submitted in a separate letter.

U. S. Nuclear Regulatory Commission Enclosure 3F0410-04 Page 5 of 5

4. T Provide information on the potential effects of cooling tower drift on terrestrial vegetation of the CR-3 site. Has deposition of particulates (salt drift) from cooling towers plumes resulted in any damage to vegetation or increased salinity of soils? Provide salt drift study reports for the years when helper towers were added. If no reports exist, then a statement that no such information exists should be provided.

Response

Refer to the enclosed documents: 

            *   "RAI 5-4 Crystal River Salt Drift Correspondence,"
            *   "RAI 5-4 Crystal River Salt Drift FDEPResponse, " and
            *   "RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report."

In addition, a statement regarding the impact of salt drift from cooling towers is provided in a separate letter.

5. T-20 (Also AQ-1) - Provide all responses from correspondence with the State of Florida regarding threatened and endangered species. If no responses were received from the State, provide a statement to that effect.

Response

Refer to the enclosed Florida NaturalAreas Inventory (FNAI) documents: 

            "   "RAI 5-5 FNAI Central Florida Report," and
            "   "RAI 5-5 FNAI Lake Tarpon Report."

In addition, a statement that no response from the State of Florida could be found is provided in a separate letter.

U. S. Nuclear Regulatory 3F0410-04 rwaoo*ý Response to Request for Documents Documents Enclose N 4 2009 NPDES Reports

1. RAI 2-1 Title V Permit
2. RAI 3-1 Crystal River Mariculture Center Juvenile 19. RAI 4 2005 Industrial Waste Water Reports Releases.
3. RAI 3-2 & RAI 5-1 Environmental Support Document Crystal River Unit 3 South Cooling 20. RAI 4 2006 Industrial Waste Water Reports Tower Laydown Area, Citrus County, Florida.
4. RAI 3-3 Crystal River Impingement Report Mar 3 21. RAI 4 2007 Industrial Waste Water Reports 2008
5. RAI 3-4 CR Seagrass Technical Advisory 22. RAI 4 2008 Industrial Waste Water Reports Committee Final Report
6. RAI 3-4 Crystal River 1993 Seagrass Study 23. RAI 4 2009 Industrial Waste Water Reports
7. RAI 3-4 Crystal River 1994 Seagrass Study 24. RAI 4 2005 Domestic Waste Water Reports
8. RAI 3-4 Crystal River 1995 Seagrass Study 25. RAI 4 2006 Domestic Waste Water Reports
9. RAI 3-4 Crystal River November 2001 Seagrass 26. RAI 4 2007 Domestic Waste Water Reports Survey
10. RAI 3-4 Seagrass Quantification Report_4-24-08 27. RAI 4 2008 Domestic Waste Water Reports
11. RAI 3-5 Marine Turtle Permit 28. RAI 4 2009 Domestic Waste Water Reports
12. RAI 3-6 National Marine Fisheries Service Letter 29. RAI 5-4 Crystal River Salt Drift Correspondence
13. RAI 3-7 Crystal River 3 Impingement Study 30. RAI 5-4 Crystal River Salt Drift FDEP Response (1978b)
14. RAI 42005 NPDES Reports 31. RAI 5-4 Crystal River Salt Drift Study 93-94 Annual Report
15. RAI 4 2006 NPDES Reports 32. RAI 5-5 FNAI Central Florida Report
16. RAI 4 2007 NPDES Reports 33. RAI 5-5 FNAI Lake Tarpon Report
17. RAI 4 2008 NPDES Reports

Progress Energy PROGRESS ENERGY FLORIDA, INC. CRYSTAL RIVER ENERGY COMPLEX LICENSING & REGULATORY PROGRAMS (NAIB) 15760 W. POWER LINE STREET CRYSTAL RIVER, FL 34428-6708 U.S. Nuclear Regulatory Commission Attention: Document ControlDesk 11555 Rockville Pike Rockville, Maryland 20852 RETURN AND FORWARDING POSTAGE.GUARANTEED

U. S. Nuclear Regulatory Commission Response to 3F0410-04 Request for Documents RAI 2-1 Title V Permit

NOTICE OF FINAL PERMIT In the Matter of an Applicationfor Permit by: Florida Power Corporation Permit No. 01 70004-024-AV dba Progress Energy Florida, Inc. Crystal River Power Plant 299 First Avenue North Title V Air Operation Permit Renewal Mail Code CN77 Citrus County St. Petersburg, Florida 33701 Responsible Official: Mr. Larry Hatcher, Plant Manager Enclosed is the final permit package to renew the Title V air operation permit for Crystal River Power Plant. The existing facility is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. This permit is issued pursuant to Chapter 403, Florida Statutes. Any party to this order has the right to seek judicial review of it under Section 120.68 of the Florida Statutes by filing a notice of appeal under Rule 9.110 of the Florida Rules of Appellate Procedure with the clerk of the Department of Environmental Protection in the Office of General Counsel (Mail Station #35, 3900 Commonwealth Boulevard, Tallahassee, Florida, 32399-3000) and by filing a copy of the notice of appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The notice must be filed within 30 days after this order is filed with the clerk of the Department. Executed in Tallahassee, Florida. Trina Vielhauer, Chief Bureau of Air Regulation TLV/jh/sm CERTIFICATE OF SERVICE The undersigned duly designated deputy agency clerk hereby certifies that this Notice of Final Permit (including the Final Permit and Final Determination), or a link to these documents available electronically on a publicly accessible server, was sent by electronic mail with. received receipt requested to the persons listed below: Mr. Larry Hatcher, Progress Energy Florida, Inc.: larry.hatclier@pgnmail.com Mr. Dave Meyer, P.E., Progress Energy Florida, Inc.: dave.mever@pgnmail.com Mr. Scott Osbourn, P.E., Golder Associates, Inc.: sosboum@golder.com Ms. Cyndy Wilkinson, Progress Energy Florida,, Inc.: cyndy.wilkinson@pgnmail.com Ms. Danielle Henry, DEP - SWD: danielle.d.henry dep.state.fl.us Ms. Susan Machinski, DEP - SD: susan.machinski@,dep.state.fl.us Ms. Katy Forney, U.S. EPA Region 4: forney.kathleen@epamail.epa.gov Ms. Ana Oquendo, EPA Region 4: oquendo.ana(aepamail.epa.gov Ms. Barbara Friday, DEP - BAR: barbara.friday~dep.state.fl.us (for posting with U.S. EPA, Region 4) Ms. Victoria Gibson, DEP - BAR: victoria.gibson@dep.state.fl.us (for reading file) Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to Section 120.52(7), Florida Statutes, with the designated agep4\clerk, receipt of which is hereby

Florida Department of Environmental Protection Bob Martinez Center 2600 Blair Stone Road I. V(IC~IJA Tallahassee. Florida 32399-2400 PERMITTEE: Permit No. 01 70004-024-AV Florida Power Corporation Crystal River Power Plant dba Progress Energy Florida, Inc. Facility ID No. 0170004 299 First Avenue North Title V Air Operation Permit Renewal Mail Code CN77 St. Petersburg, Florida 33701 The purpose of this permit is to renew the Title V air operation permit for the above referenced facility. The existing Crystal River Power Plant is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. UTM Coordinates are: Zone 17, 334.3 km East and 3204.5 km North. Latitude is: 280 57' 34" North and Longitude is: 820 42' 1" West. The Title V air operation permit is issued under the provisions of Chapter 403, Florida Statutes (F.S.), and Florida Administrative Code (F.A.C.) Chapters 62-4, 62-210, 62-213 and 62-214. The above named permittee is hereby authorized to operate the facility in accordance with the terms and conditions of this permit. Effective Date: January 1, 2010 Renewal Application Due Date: May 20, 2014 Expiration Date: December 31, 2014 

                                                                            . \     !;

Joseph Kahn< Director Division of Air Resource Management JK/tlv/jkh/sm

FINAL DETERMINATION qPERMITTEE Florida Power Corporation dba Progress Energy Florida, Inc. (PEF) 299 First Avenue, North Mail Code CN77 St. Petersburg, Florida 33701 PERMITTING AUTHORITY Florida Department of Environmental Protection (Department) Division of Air Resource Management Bureau of Air Regulation, Title V Section 2600 Blair Stone Road, MS #5505 Tallahassee, Florida 32399-2400 PROJECT Permit No. 0170004-024-AV Crystal River Power Plant The purpose of this project is to renew the Title V air operation permit for Crystal River Power Plant. NOTICE AND PUBLICATION The Department distributed a draft/proposed Intent to Issue a Title V Air Operation Permit Renewal package on October 27, 2009. The applicant published the Public Notice of Intent to Issue a Title V Air Operation Permit Renewal in the Citrus County Chronicle on November 2, 2009. The I. Department received the proof of publication on November 5, 2009. A proposed permit was issued for EPA review on October 27, 2009. COMMENTS No comments were received from either the Public during the 30-day public comment period or from EPA during their 45-day review period; however, comments were received from the Permittee. The comments are minor administrative corrections to the permit. The comments were not considered significant enough to reissue the draft Title V air operation permit and require another Public Notice, therefore, the draft/proposed Title V air operation permit was changed. Those comments are addressed below. Additions to the permit are indicated by a double underline. Deletions from the permit are indicated by a st~ke thr mtgh. Email from Dave Meyer dated November 19, 2009 COMMENT 1. It is requested to add the following language to the end of Specific Condition A.L.: "Heat input shall be determined by coal analysis and the coal feeder scales, 24 hour average. The CEMs heat input value shall not be used." RESPONSE 1. A review in response to this comment resulted in the discovery that the following permitting note, which was contained in permit No. 0170004-003-AC, was inadvertently omitted in the draft/proposed permit. It has been reinserted following Specific Condition A.1. (PermittingNote: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operation to 110 percent of the test load), to establish appropriateemission limits and to aid in determiningfuture rule applicability.] COMMENT 2. Delete specific condition A.2.b. Bartow Unit 1 has been taken out of service. RESPONSE 2. Specific condition A.2. has been changed as follows: A.2. Methods of Operation.

a. Fuels. The fuels that are allowed to be burned in these units are:

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 1 of 6

FINAL DETERMINATION (1) Bituminous coal, (2) Bituminous coal and bituminous coal briquette mixture, (3) Distillate fuel oil for startup, and (4) Used oil in accordance with the specific conditions in Subsection J.7 (5) flyash in aadridance with Spcifi Oilyn.nditiens o A.2.b. and A.26.

b. OilyA7yash. These beenssins units may burn ily flyash (reuyahb) fredm Bar-tow Unit 1 int aMENTrdante with the fuellewing h ificc d Flyash. Only flyash freom Baeigw e Unit 1 may be burned in these emssions units.

Onie the achufulated batklugef Bantew Unit 1 flyash (cstimnatb d at approfxiately 13,000 tuns)is burned, 3 nTly the additional flyash grneratcd At Baflec Unit 1 shall be bund in thesercnsttsion urits. (2) Blend Rate Limeit. The aximum flyash blend rate shall not exaeed 2%of the total bcileri feed en a 'weight basis. [Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AG; and, 0170004-006-AC] In addition specific condition A.26. has been deleted as follows: A.26. Oilybeusdash 0- eorfdkeein. a Thelowoerd fr opersatar shall mfuake and maintain the fmllwinbg ruedrds srt eaah day that flyash is burned in the boiler:

a. Date and Unit numtiberm,
b. Timfe period of flyash burning and start and end timfes-,
e. Total quantity of flyash burned in tons per day, and
d. Maximiumoflyash blend fate during perliodof fyash burn (percent flyash in total em ssiens unit fuel feed en a weight basis).

[Rule 62 213.4110, F.A.C.; and Permfit No. 0170004 005 AO] Specific conditions A.27. and A.28. have been renumbered as A.26. and A.27., respectively. COMMENT 3. Quantifying the fuel density is appropriate for fuel oil, it is typically not measured for fuels such as coal. Change specific condition A.22.b. to read "Recordkeeping. Record daily the amount of coal fired, the density opacityof each fuel, the Btu value, and the percent sulfur content by weight of each fuel." RESPONSE 3. The language in specific condition A.22.b. reflects the language in the air construction permit. The requested language was not found to be in an air construction permit for these units. Therefore, no change will be made. COMMENT 4. The wording in the current permit is not clear regarding flame stabilization. We want to clarify that fuel oil is used as an ignitor fuel and for low load flame stabilization. It is requested to change specific condition B.2.a.(2) to read "Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and low load flame stabilization fuel. Natural gas may be used as a startup and low load flame stabilization fuel. RESPONSE 4: Air construction permit 0170004-006-AC authorized No. 2 fuel oil to be used as an ignitor fuel and natural gas as a startup and low load flame stabilization fuel. The air construction permit did not authorize No. 2 fuel oil to be used as a low load flame stabilization fuel. Therefore, no change will be made. COMMENT 5: One purpose of the Title V permit is to summarize the operating requirements. We felt that it was appropriate to outline the opacity allowance in specific condition B.11. in the Title V permit to clarify when the opacity standard used is in effect. It is requested to add the following language at the end of specific condition B.11.: "The opacity standards set forth in 40 CFR 60.11 shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard. [40 CFR 60. 11 ]" RESPONSE 5: The requested language is in Attachment NSPS A. The requested language from 40 CFR 60.11 is not applicable to excess emissions. Condition B.11. is from Rule 62.210.700, F.A.C. Please note that Rule 62-2 10.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. This is stated in the permit under the heading Excess Emissions. No change will be made. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 2 of 6

FINAL DETERMINATION COMMENT 6: Quantifying the fuel density is appropriate for fuel oil. It is typically not measured for fuels such as coal. Change specific condition B.25.b. to read "Recordkeeping. Record daily the amount of coal fired, the density (f of each fuel, the Btu value, and the percent sulfur content by weight of each fuel." RESPONSE 6: The requested language was not found to be in an air construction permit for these units. Therefore, no change will be made. COMMENT 7: We have historically submitted our excess emissions report on a quarterly basis. Our intent is for the Title V permit to accurately reflect when we submit our excess emissions report. Change specific condition B.28 to read: B.28. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority: Report Reporting Deadline Related Condition(s) Notice of Excess Emissions Postmarked by the 3 0 th day following the B.13. and B.29 end of each g RESPONSE 7: Specific conditions B.13., B.28. and B.29. are conditions stating applicable requirements of 40 CFR 60 Subpart D relating to excess emissions and reporting. It is the intention of these conditions to bring to awareness federal requirements for excess emissions which the facility is subject. Subpart D requires excess emissions reporting every six months. The Department is not able to rewrite the federal regulations. However, the facility may submit these reports more frequently if they choose to do so. No change will be made. COMMENT 8: Delete specific condition C.16. This is not required in our current TV permit. The above record-keeping is required in sections III.A. & B. We feel it is redundani to require this information in this section of the permit. RESPONSE 8: Condition C.16 has been deleted. Condition C.17. has been renumbered to C.16. COMMENT 9: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity Change specific condition D.14 as follows: D.14. The visible emissions test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statemfent of the approximfate ash transfer rate during the test shall be submfitted with each test report. Failure to submit the process tr-ansfier- rate, -Andor operationf unider conditionis that are not representative of normal operations may invalidate the test and fail to provide reas.nable assurance of eemp.la.nee. Unit load will be utilized to assure 90 to 100% capacity during testing. [Permit No. AC09-235915] RESPONSE 9: The language in Condition D.14. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee. The language may only be changed through an air construction permit. No change will be made to condition. COMMENT 10: The stricken language is not in our current TV permit. There is no system to measure the ash flow rate. The plant staff currently use unit load to assure they are operating at 90 to 100% capacity. Change specific condition D.15. as follows: D.15. Reporting Ash Transfer Rate. A statem.ent f the appr-oximate ash transfer rate during the test shall be submitte'd wiit~h feaeh. compliance test report. Failure to submit the process tr-ansfer rate and o prto under conditions that afe not representative of normfal operations mfay invalidate the test and fail to provid-e reasonable assurance of comfipliance. Unit load will be utilized to assure 90 to 100% capacity during testing. Unit load shall be submitted with each compliance test report. [Permit No. AC09-235915] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 3 of 6

FINAL DETERMINATION RESPONSE 10. The language in Condition D.15. is from the facility's federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee. The condition may only be changed through an air construction permit. No change will be made to condition. COMMENT 11: The current TV permit utilizes the below wording. We prefer this wording as it allows more flexibility in determining the test operating rate (fuel flow may difficult to measure). Electrical output may be a better indicator. E.17. Operating Rate During Testing. Testing of emissions shall be conducted with the generator(s) operating at 90 to 100 percent of the maximum fuel firing rate for each generator. If it is impracticable to test at permitted capacity, an emissions unit may be tested at less than the minimum permitted capacity (i.e., at less than 90 percent of the maximum operation rate allowed by the permit); in this case, subsequent emissions unit operations may be limited to 110 percent of the test load until a new test is conducted, provided however, operations do not exceed 100 percent of the maximum operation rate allowed by the permit. Once the emissions unit is so limited, operation at higher capacities is allowed for no more than 15 consecutive days for the purpose of additional compliance testing to regain the authority to operate at the permitted capacity. Failure to submit the actual operating rate may invalidate the test. [Rule 62-297.310(2), F.A.C.; and, AC 09-202080] RESPONSE 11: The requested language is in Appendix TR, Condition TR2. The language in Condition E.17. is from the federally enforceable air construction permit No. AC09-235915 which was accepted by the permittee. The condition may only be changed through an air construction permit. No change will be made to condition. COMMENT 12: Replace the word "nine" with the word "all" in the last sentence of the first paragraph of the emission unit description in Subsection F. RESPONSE 12: The Department believes that the description is clear as written. No change will be made. COMMENT 13: In accordance with an alternate procedure dated June 7, 2000, the wording for condition F.4. is not in the current TV permit. The current TV permit requires the following preferred wording: F.4. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate): (a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps). (b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem. (c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered. [Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7, 2000] RESPONSE 13: The provisions of the approved alternate procedure, ASP No. 00-E-01 dated June 7, 2000, which were reflected in Condition F.4. of the previous Title V permit, were inadvertently omitted during this renewal process. Condition F.9. of the renewal permit has been corrected as follows to replace the omitted ASP provisions: 1P 0 

    ' D.J O 0--      1-ýOp T-ýý                                                                   ýý11           +ý 1-              t,     +t-Depar.tm ent,.. shall be c.nducted fer ea.h e..ling tower-while it is                                   90 100% capacity. Suche at gperated tests shall"be conduceted int accordanceewith 40 CER 60 Appendixi A, using EPA Method 5, oray T  AjuI  f1 ul,~,*- *F .. .  .; v*A 1.... t-, . 1; .... a ,a    *tl ..,l l 1i., A**  'kk     fl    L'"    .....  **'.U
                                                                                                                                    . L 'J
                                                                                                                                         ... te equivlent mnethod approeved by the Depar-tment. Specifically, when using EPA Method 5, -A                                   distilled eater r-inse shall be used in place of aeetonle, and the impinge catch shall be eyxcluded from emission calculations, The salt water flew rate dur-ing the compliance tests shall be determinifed using the manufactturer's ceenified Progress Energy Florida, Inc.                                                                                           Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Air Operation Permit Renewal Page 4 of 6

FINAL DETERMINATION pump cur-vos, or any other equivalent mnethod approeved by the Depaftmfent. If compliatnce test resut indicate that the pafticulate eision arfgeater-than 90% but less than 100% of its allowable limiit et 11.89 lbs~ir-per- eeil! (stack), the failt .illb. rquir-ed to conduct anoether- stack test withint thirty mnonths. Whereas, a partfieulate stack test will be roquir-ed onee evefy five y'ear~s if the compliance test results show that the partficulate emissions are below 80% of the 11.89 lbs/bf allowed limit. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate): (a) Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans (b) Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up ispections and correction of uroblems when the daily visual inspection of the cells indicates a problem. (c) Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered. [Rule 62-213*440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7. 2000] COMMENT 14: The below dates reflect the current testing schedule: G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012). [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] RESPONSE 14: Specific Condition G.10. has been corrected as follows: G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012). [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] COMMENT 15: We believe the reference to Specific Condition 1.6. in Specific Condition 1.8. is a typo RESPONSE 15: Condition 1.8. has been corrected as follows: 1.8. Inspection Log. Any problems detected during the work practice inspections identified in Specific Condition 1.610t. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000] COMMENT 16: My understanding was that a trailer mounted engine is not considered a stationary source, and thus not subject to the new NSPS & HAPS regulations. I now understand that the DEP considers it a stationary source when in operation, and therefore request that it be added to Appendix ICE - Requirements For Internal Combustion Engines: E.U. No. Brief description of engine 031? Crystal River Unit 3 trailer mounted fire pump Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 5 of 6

FINAL DETERMINATION RESPONSE 16: The table in Appendix ICE has been changed as follows: In- Displacement Rule E.U. No. Brief Description of Engine Service Applicability Date 028 3500 kW diesel generator associated with Unit 3 03/2006 12,443 in3 ZZZZ 029 Diesel fire pump, south yard 08/2009 14.5 L zzZZ, IIII 030 Emergency generator (meteorological weather station) 09/2009 992 CC ZZZZ, JJJJ 031 Fire Pump, Trailer Mounted, Unit 3 02/2008 8700 CC ZZZZ, IIII As a result of this change the second to last paragraph of the Facility Description in the Statement of Basis has also been changed as follows: The facility has th-ee four new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1111, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 afid-*EU030 and EU031) were created for these units. CONCLUSION The final action of the Department is to issue the permit with the minor corrections noted above. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 6 of 6

STATEMENT OF BASIS Title V Air Operation Permit Renewal Florida Power Corporation dba Progress Energy Florida, Inc. Crystal River Power Plant Permit No. 0170004-024-AV APPLICANT The applicant for this project is Florida Power Corporation dba Progress Energy Florida, Inc. The applicant's responsible official and mailing address are: Mr. Larry Hatcher, Plant Manager, Florida Power Corporation dba Progress Energy Florida, Inc., 299 First Avenue, North, Mail Code CN77, St. Petersburg, Florida, 33701. FACILITY DESCRIPTION The applicant operates the existing Crystal River Power Plant, which is located in Citrus County at 15760 West Power Line Street, Crystal River, Florida. This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and Nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generator(s). The nuclear unit (Unit 3) is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit. The facility has the potential to emit particulate matter, sulfur dioxide, nitrogen oxides, and carbon monoxides. This facility is subject to regulation under Acid Rain, Phase II, 40 CFR 75, Clean Air Interstate Rule, Rule 62-296.470, F.A.C., 40 CFR 60 Subparts A, D, Y, 1111 and JJJJ, General Provisions, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction Is Commenced After August 17, 1971, Standards of Performance for Coal Preparation Plants, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines, and Standards of Performance for Stationary Spark Ignition Internal Combustion Engines, respectively. The facility is subject to the regulations of 30 CFR 63 Subparts A and ZZZZ, General Provisions and National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines, respectively. The facility operates stationary reciprocating internal combustion engines (EU019), therefore, it is subject to regulation under 40 CFR 63, Subpart ZZZZ - National Emissions Standards For Hazardous Air Pollutants For Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time. The facility has three new reciprocating internal combustion engines that are subject to regulation under 40 CFR 63, Subpart ZZZZ, and 40 CFR 60 Subpart 1III, and 40 CFR 60 Subpart JJJJ. New regulated emission units (EU028, EU029 and EU030) were created for these units. Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities. PROJECT DESCRIPTION The purpose of this permitting project is to renew the existing Title V permit for the above referenced facility. PROCESSING SCHEDULE AND RELATED DOCUMENTS Application for a Title V Air Operation Permit Renewal received May 21, 2009 Additional Information Request dated July 10, 2009 Additional Information Response received October 8, 2009 PRIMARY REGULATORY REQUIREMENTS Title III: The facility is identified as a major source of hazardous air pollutants (HAP). Title IV: The facility operates units subject to the acid rain provisions of the Clean Air Act. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 1 of 2

STATEMENT OF BASIS Title V: The facility is a Title V major source of air pollution in accordance with Chapter 62-213, Florida Administrative Code (F.A.C.). PSD: The facility is a Prevention of Significant Deterioration (PSD)-major source of air pollution in accordance with Rule 62-212.400, F.A.C. NSPS: The facility operates units subject to the New Source Performance Standards (NSPS) of 40 Code of Federal Regulations (CFR) 60. NESHAP: The facility operates units subject to the National Emissions Standards for Hazardous Air Pollutants (NESHAP) of 40 CFR 63. CAIR: The facility is subject to the Clean Air Interstate Rule (CAIR) set forth in Rule 62-296.470, F.A.C. Siting: Emissions units EU001, EU002, EU003 and EU004 were originally certified pursuant to the power plant siting provisions of Chapter 62-17, F.A.C. CAM: Compliance Assurance Monitoring (CAM) applies to emissions units EU001, EU002, EU003 and EU004 at the facility. CAM applies because these units have control equipment used to meet federally enforceable limits or standards. PROJECT REVIEW Changes made as part of this renewal were reformatting, replacement of TV-6 with new Appendix TV, streamlining of EU sections by moving common conditions to the new appendices.). New regulated emission units were created due to applicability to 40 CFR 60 1III, 40 CFR 60 JJJJ and 40 CFR 63 ZZZZ. Minor changes were requested by the applicant. Changes requested by the applicant include adding concrete batch plants and grout batch plants to Appendix I, and adding a 20,000 gallon underground storage tank for diesel to EU017 in Appendix U. Additionally, a change was made to the ambient air monitoring specific condition for EU003 and EU004 (FFSG units 5 and 4, respectively) to make it consistent with the change made to Conditions of Certification, PA 77-09, in the Post-certification Amendment, dated June 19, 2008. In this amendment, the Department determined that Progress Energy Florida could cease to operate and remove Site No. 4 monitoring station (SO 2 only). CONCLUSION This project renews Title V air operation permit No. 0170004-009-AV, which was issued on January 1, 2005. This Title V air operation permit renewal is issued under the provisions of Chapter 403, Florida Statues (F.S.), and Chapters 62-4, 62-210, 62-213 and 62-214, F.A.C. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 2 of 2

Florida Power Corporation dba Progress Energy Florida, Inc. (PEF) Crystal River Power Plant Facility ID No. 0170004 Citrus County Title V Air Operation Permit Renewal Permit No. 0170004-024-AV (Renewal of Title V Air Operation Permit No. 0170004-009-AV) JETItON F/LORI A Permitting Authority: State of Florida Department of Environmental Protection Division of Air Resource Management Bureau of Air Regulation Title V Section 2600 Blair Stone Road Mail Station #5505 Tallahassee, Florida 32399-2400 Telephone: (850) 488-0114 Fax: (850) 921-9533 Compliance Authority: State of Florida Department of Environmental Protection Southwest District Office 13051 North Telecom Parkway Temple Terrace, FL 33637-0926 Telephone: 813/632-7600 Fax: 813/632-7668

Florida Power Corporation dba Progress Energy Florida, Inc. Crystal River Power Plant Title V Air Operation Permit Renewal Permit No. 0170004-024-AV Table of Contents Section Pa2e Number I. Facility Information. A . F acility D escrip tio n . .................................................................................................................................... 2 B . Sum m ary of Emissions U nits . ..................................................................................................................... 2 C . Applicable R egulations . .............................................................................................................................. 2 II. F acility-w ide C ond ition s. ................................................................................................................................... 4 III. Emissions Units and Conditions. A. Fossil Fuel Steam Generator (FFSG), Units land 2 ................................................................................ 6 B. FFSG Units 4 and 5......................................................... 11 C. Fly A sh Transfer & Storage, Units 1 and 2 .......................................................................................... 17 D . Bottom Ash Storage Silo for U nits 1 and 2 ........................................................................................... 20 E . R elocatable D iesel Generators . ................................................................................................................. 23 F . C ooling T owers for U nits 1, 2 and 3 . ........................................................................................................ 26 G. C ooling Tow ers for U nits 4 and 5 ........................................................................................................ 28 H. Material Handling Activities for Coal-Fired Steam Units ..................................................................... 30 I. Portable Cooling Towers for U nits 1 and 2 ........................................................................................... 32 J. U sed O il C omm on C ondition . ................................................................................................................... 34 IV . A cid R ain P art ................................................................................................................................................... 36 Phase II Acid Rain Application/Compliance Plan. Phase II Acid Rain NOx Compliance Plan. Phase II Acid Rain NOx Averaging Plan. V . C lean A ir Interstate R ule P art . ......................................................................................................................... 48 V I. A ppen dice s. ...................................................................................................................................................... 54 Appendix A, Glossary. Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997). Appendix CAM, Compliance Assurance Monitoring Plan. Appendix I, List of Insignificant Emissions Units and/or Activities. Appendix NSPS, Subpart A - General Provisions. Appendix NSPS, Subpart D - Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971. Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines. Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines. Appendix NSPS, Subpart Y - Standards of Performance for Coal Preparation Plants. Appendix NESHAP, Subpart A - General Provisions. Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. Appendix RR, Facility-wide Reporting Requirements. Appendix TR, Facility-wide Testing Requirements. Appendix TV, Title V General Conditions. Appendix U, List of Unregulated Emissions Units and/or Activities. R eferenced Attachm ents ................................................................................................................................. At End Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996). Table H, Permit History. Pagei

SECTION I. FACILITY INFORMATION. Subsection A. Facility Description. This facility consists of: four coal-fired fossil fuel steam generating (FFSG) units with electrostatic precipitators; two natural draft cooling towers for FFSG Units 4 and 5; helper mechanical cooling towers for FFSG Units 1, 2 and nuclear Unit 3; coal, fly ash, and bottom ash handling facilities; and, relocatable diesel fired generators. Nuclear Unit 3 is not considered part of this permit, although certain emissions units associated with Unit 3 are included in this permit. Also included in this permit are miscellaneous unregulated/insignificant emissions units and/or activities. Subsection B. Summary of Emissions Units. E.U. No. I Brief Description Regulated Emission Units 001 FFSG, Unit 1 002 FFSG, Unit 2 004 FFSG, Unit 4 003 FFSG, Unit 5 006 Fly ash transfer (Source 1) from FFSG Unit 1 008 Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009 Fly ash transfer (Source 4) from FFSG Unit 2 010 Fly ash transfer (Source 5) from FFSG Unit 2 014 Bottom ash storage silo for FFSG Units 1 and 2 012 Relocatable diesel generators 013 Cooling towers for FFSG Units 1, 2, and 3 015 Cooling towers for FFSG Units 4 and 5 016 Material handling activities for coal-fired steam units 020 Portable Cooling Towers for FFSG Units 1 and 2 028 3500 kW diesel generator associated with Unit 3 029 Diesel fire pump, south yard 030 Emergency generator (meteorological weather station) UnregulatedEmissions Units and/orActivities 017 Fuel and lube oil tanks and vents 018 Sewage treatment, water treatment, lime storage 019 Two 3500 kW diesel generators associated with Unit 3 Subsection C. Applicable Re2ulations. Based on the Title V air operation renewal application received May 21, 2009, this facility is a major source of hazardous air pollutants (HAP). Because this facility operates stationary reciprocating internal combustion engines (EU019), it is subject to regulation under 40 CFR 63, Subpart ZZZZ - National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. However, since the engines being operated meet the Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time. The existing facility is a PSD major source of air pollutants in accordance with Rule 62-212.400, F.A.C. A summary of applicable regulations is shown in the following table. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 2 of 54

SECTION I. FACILITY INFORMATION. Regulation EU Nos. 40 CFR 60, Subpart A, NSPS General Provisions 003, 004, 016 40 CFR 60, Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction 003,004 is Commenced After August 17, 1971 40 CFR 60, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion 029 Engines 40 CFR 60, Subpart JJJJ, Standards of Performance for 030 Stationary Spark Ignition Internal Combustion Engines 40 CFR 63, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating 028,029,030 Internal Combustion Engines 40 CFR 63, Subpart Y, Standards of Performance for Coal 016 Preparation Plants. 40 CFR 75 Acid Rain Monitoring Provisions 001,002, 003,004 Rule 62-296.405, F.A.C. 001,002 Rule 62-210.370, F.A.C. 001,002, 003,004, 006, 008,009,010, 013,014, 015,016, 020 Rule 62-210.700, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.410, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-213.440, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, 015,016, 020 Rule 62-297.310, F.A.C. 001, 002, 003, 004, 006, 008, 009, 010, 013, 014, Rule_62-297.3_10,________ 1015,016, 020 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 3 of 54

SECTION II. FACILITY-WIDE CONDITIONS. The following conditions apply facility-wide to all emission units and activities: FW1. Appendices. The permittee shall comply with all documents identified in Section VI, Appendices, listed in the Table of Contents. Each document is an enforceable part of this permit unless otherwise indicated. [Rule 62-213.440, F.A.C.] Emissions and Controls FW2. Not federally Enforceable. Objectionable Odor Prohibited. No person shall cause, suffer, allow or permit the discharge of air pollutants, which cause or contribute to an objectionable odor. An "objectionable odor" means any odor present in the outdoor atmosphere which by itself or in combination with other odors, is or may be harmful or injurious to human health or welfare, which unreasonably interferes with the comfortable use and enjoyment of life or property, or which creates a nuisance. [Rule 62-296.320(2) and 62-210.200(Definitions), F.A.C.] FW3. General Volatile Organic Compounds (VOC) Emissions or Organic Solvents (OS) Emissions. The permittee shall allow no person to store, pump, handle, process, load, unload or use in any process or installation, volatile organic compounds or organic solvents without applying known and existing vapor emission control devices or systems deemed-necessary and ordered by the Department. The owner or operator shall:

a. Tightly cover or close all VOC or OS containers when they are not in use.
b. Tightly cover all open tanks which contain VOC or OS when they are not in use.
c. Maintain all pipes, valves, fittings, etc., which handle VOC or OS in good operating condition.
d. Immediately confine and clean up VOC or OS spills and make sure wastes are placed in closed containers for reuse, recycling or proper disposal.

[Rule 62-296.320(1), F.A.C.; Permit No. 0170004-024-AC] FW4. General Visible Emissions. No person shall cause, let, permit, suffer or allow to be discharged into the atmosphere the emissions of air pollutants from any activity equal to or greater than 20% opacity. EPA Method 9 is the method of compliance pursuant to Chapter 62-297, F.A.C. This regulation does not impose a specific testing requirement. [Rule 62-296.320(4)(b), F.A.C.] FW5. Unconfined Particulate Matter. No person shall cause, let, permit, suffer or allow the emissions of unconfined particulate matter from any activity, including vehicular movement; transportation of materials; construction; alteration; demolition or wrecking; or industrially related activities such as loading, unloading, storing or handling; without taking reasonable precautions to prevent such emissions. Reasonable precautions to prevent emissions of unconfined particulate matter at this facility include:

a. Maintenance of paved areas as needed.
b. Regular mowing of grass and care of vegetation.
c. Limiting access to plant property by unnecessary vehicles.

[Rule 62-296.320(4)(c), F.A.C.; and, proposed by applicant in Title V air operation permit renewal application received May 21, 2009.] Annual Reports and Fees See Appendix RR, Facility-wide Reporting Requirements for additional details. FW6. Annual Operating Report. The permittee shall submit an annual report that summarizes the actual operating rates and emissions from this facility. Annual operating reports shall be submitted to the Compliance Authority by April 1st of each year. [Rule 62-210.370(3), F.A.C.] FW7. Annual Emissions Fee Form and Fee. The annual Title V emissions fees are due (postmarked) by March 0 of each year. The completed form and calculated fee shall be submitted to: Major Air Pollution Source Annual Emissions Fee, P.O. Box 3070, Tallahassee, Florida 32315-3070. The forms are available for download by accessing the Title V Annual Emissions Fee On-line Information Center at the following Internet web site: http://www.dep.state.fl.us/air/emission/tvfee.ht-n. [Rule 62-213.205, F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 4 of 54

SECTION II. FACILITY-WIDE CONDITIONS. FW8. Annual Statement of Compliance. The permittee shall submit an annual statement of compliance to the compliance authority at the address shown on the cover of this permit within 60 days after the end of each calendar year during which the Title V permit was effective. [Rules 62-213.440(3)(a)2. & 3. and (b), F.A.C.] FW9. Prevention of Accidental Releases (Section 112(r) of CAA).

a. As required by Section 112(r)(7)(B)(iii) of the CAA and 40 CFR 68, the owner or operator shall submit an updated Risk Management Plan (RMP) to the Chemical Emergency Preparedness and Prevention Office (CEPPO) RMP Reporting Center.
b. As required under Section 252.941(1)(c), F.S., the owner or operator shall report to the appropriate representative of the Department of Community Affairs (DCA), as established by department rule, within one working day of discovery of an accidental release of a regulated substance from the stationary source, if the owner or operator is required to report the release to the United States Environmental Protection Agency under Section 112(r)(6) of the CAA.
c. The owner or operator shall submit the required annual registration fee to the DCA on or before April 1, in accordance with Part IV, Chapter 252, F.S., and Rule 9G-21, F.A.C.
d. Any required written reports, notifications, certifications, and data required to be sent to the DCA, should be sent to: Department of Community Affairs, Division of Emergency Management, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2100, Telephone: (850) 413-9921, Fax: (850) 488-1739.
e. Any Risk Management Plans, original submittals, revisions, or updates to submittals, should be sent to:

RMP Reporting Center, Post Office Box 10162, Fairfax, VA 22038, Telephone: (703) 227-7650. Any required reports to be sent to the National Response Center, should be sent to: National Response Center, EPA Office of Solid Waste and Emergency Response, USEPA (5305 W), 401 M Street SW, Washington, D.C. 20460, Telephone: (800) 424-8802. Send the required annual registration fee using approved forms made payable to: Cashier, Department of Community Affairs, State Emergency Response Commission, 2555 Shumard Oak Boulevard, Tallahassee, FL 32399-2149 [Part IV, Chapter 252, F.S.; and, Rule 9G-21, F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 5 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection A. Emissions Units 001, 002 The specific conditions in this section apply to the following emissions units: EU No. Brief Description 001 FFSG, Unit 1 002 FFSG, Unit 2 Emissions unit 001 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler, It is rated at 440.5 megawatt (MW). Emissions are exhausted through a 499 feet stack with a 15 feet exit diameter, 2910 F exit temperature and 1,407,923 acfm actual volumetric flow rate. Emissions unit 002 (EU001) is a pulverized coal, dry bottom, tangentially-fired boiler. It is rated at 523.8 MW. Emissions are exhausted through a 502 feet stack with a 16 feet exit diameter, 3000 F exit temperature and 1,931,324 acfm actual volumetric flow rate. Emissions from both EUOO1 and EU002 are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Buell Manufacturing Company, Inc. [PermittingNotes: These emissions units are regulated under Acid Rain, Phase I and II and Rule 62-296.405, F.A.C., Fossil Fuel Steam Generatorswith More than 250 million Btu per Hour Heat Input, and Power Plant Siting CertificationPA 77-09 conditions. The pollutants' emissions limits in Rule 62-296.405, F.A. C. have been changed through Permit Nos. 0170004-003-AC, 0170004-006-AC, PSD-FL-007,and PA 77-09. Fossilfuelfired steam generator Unit 1 began commercial operation in 1966. Fossilfuelfired steam generator Unit 2 began commercial operationin 1969.] Essential Potential to Emit (PTE) Parameters A.1. Permitted Capacity. The maximum allowable heat input rate is as follows: EU No. MMBtu/hr Heat Input Fuel Type Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture Bituminous Coal; or Bituminous Coal and Bituminous Coal Briquette Mixture [Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330 & 62-296.405, F.A.C.; and, Permit Nos. 0170004-003-AC and 0170004-006-AC] [PermittingNote: The heat input limitations have been placed in each permit to identify the capacity of each unit for the purposes of confirming that emissions testing is conducted within 90 to 100 percent of the unit's rated capacity (or to limit future operationto 110 percent of the test load), to establish appropriateemission limits and to aid in determiningfuture rule applicability.] A.2. Methods of Operation.

a. Fuels. The fuels that are allowed to be burned in these units are:

(1) Bituminous coal, (2) Bituminous coal and bituminous coal briquette mixture, (3) Distillate fuel oil for startup, and (4) Used oil in accordance with the specific conditions in Subsection J. [Rule 62-213.410, F.A.C.; Permit Nos. 0170004-002-AO; 0170004-005-AO; and, 0170004-006-AC] A.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] A.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 6 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection A. Emissions Units 001, 002 Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions A.5.-A.9. are based on the specified averaging time of the applicable test method. A.5. Visible Emissions (VE).

a. EUO01. The VE from FFSG Unit 1 shall not exceed 40 percent opacity, six minute average. [Rule 62-296.405(1)(a), F.A.C.; OGC Case No. 86-1576, Order dated December 11, 1986; Permit No. 0170004-003-AC]
b. EUO02. The VE from FFSG Unit 2 shall not exceed 20 percent opacity, six minute average, except for one two-minute period per hour during which opacity shall not exceed 40 percent. [Rule 62-296.405(1)(a), F.A.C.; Permit No. 0170004-003-AC]

[PermittingNote: QuarterlyPM testing not requiredper Rule 62-296.405(1)(a), F.A.C. per OGC Case No. 86-1576] A.6. VE - Soot Blowing and Load Change. Excess emissions resulting from boiler cleaning (soot blowing) and load change shall be permitted provided the duration of such excess emissions shall not exceed 3-hours in any 24 hour period and visible emissions shall not exceed Number 3 of the Ringelmann Chart (60 percent opacity), six minute average, and providing (1) best operational practices to minimize emissions are adhered to and (2) the duration of the excess emissions shall be minimized.

a. Load Change. A load change occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more.
b. VE > 60%. VE above 60 percent opacity shall be allowed for not more than 4, six (6)-minute periods, during the 3-hour period of excess emissions allowed by this condition, for boiler cleaning and load changes, at units which have installed and are operating continuous opacity monitors.

[Rule 62-210.700(3), F.A.C. and Permit No. 0170004-003-AC] [PermittingNote: These units have operationalcontinuous opacity monitors.] A.7. Particulate Matter (PM) Emissions. PM emissions shall not exceed 0.1 pound per million Btu heat input. [Rule 62-296.405(1)(b), F.A.C.; Permit No. 0170004-003-AC] [Permitting note: The averaging time for the particulatematter standardcorrespondsto the cumulative sampling time of the specified test method.] A.8. PM - Soot Blowing and Load Change. PM emissions shall not exceed an average of 0.3 pounds per million Btu heat input during the 3-hours in any 24-hour period of excess emissions allowed for boiler cleaning (soot blowing) and load change. [Rule 62-210.700(3), F.A.C.; Permit No. 0170004-003-AC] A.9. Sulfur Dioxide (SOZ).

a. Coal Burning. When burning coal, SO 2 emissions shall not exceed 2.1 pounds per million Btu heat input, 24-hour average.
b. Coal/BriquetteMixture. The maximum percent sulfur content of the coal/briquette mixture shipment shall not exceed 1.05%, by weight, averaged on an annual basis.

[Rule 62-213.440, F.A.C.; PPSC PA 77-09; Permit Nos. PSD-FL-007, 0170004-003-AC; and, 0170004-006-AC] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 7 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection A. Emissions Units 001, 002 A.10. Excess Emissions Allowed.

a. Excess emissions resulting from startup, shutdown, or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.]
b. Excess emissions resulting from startup or shutdown shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized.

[Rule 62-210.700(2), F.A.C.] A.11. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Monitoring of Operations A.12. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM) requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64; Rules 62-204.800 and 62-213.440(1)(b)1.a., F.A.C.] Continuous Monitoring Requirements A.13. Continuous Monitoring System. Each owner or operator shall install, calibrate, operate and maintain a continuous monitoring system for continuously monitoring opacity. Performance specifications, location of monitor, data requirements, data reduction and reporting requirements shall conform with the requirements of 40 C.F.R. Part 51, Appendix P, adopted and incorporated by reference in subsection 62-204.800(2), F.A.C., and 40 C.F.R. Part 60, Appendix B, adopted by reference in subsection 62-204.800(7), F.A.C. [Rule 62-296.405(f), F.A.C.] (PermittingNote: The Acid Rain CEMs, requiredby 40 CFR 75, satisfies Specific Condition A.13.} Test Methods and Procedures A.14. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 3 Gas Analysis for Carbon Dioxide, Oxygen, Excess Air, and Dry Molecular Weight Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources 5 Determination of Particulate Emissions from Stationary Sources 5B Determination of Nonsulfuric Acid Particulate Matter from Stationary Sources 5F Determination of Nonsulfate Particulate Matter from Stationary Sources 6 Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6C Determination of Sulfur Dioxide Emissions from Stationary Sources Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 8 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection A. Emissions Units 001, 002 Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Particulate Emissions from Stationary Sources (In-Stack Filtration Method) Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, 19 Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.) ASTM D2013-72, Standard Methods by the American Society of Testing and Materials for Fuel ASTM D3177-75, Analysis ASTM D4239-85, or latest ASTM edition methods The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rules 62-297.401, and 62-204.800, F.A.C., Permit No. 0170004-003-AC] A.15. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.3 10, F.A.C.] A.16. Annual Compliance Tests Required. Except as provided in Specific Condition A.23., during each federal fiscal year (October 1st to September 30th), each EUOO1 and EU002 shall be tested to demonstrate compliance with the emissions standards for PM and VE. [Rule 62-297.310(7), F.A.C.; OGC Case No. 86-1576; and Permit No. 0170004-003-AC] A.17. Compliance Tests Prior To Renewal. Except as provided in Specific Condition A.23., compliance tests shall be performed for PM and VE once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions A.5. - A.9. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.] A.18. PM Emissions. The test methods for PM emissions shall be EPA Methods 17, 5, 5B, or 5F, incorporated by reference in Chapter 62-297, F.A.C. The minimum sample volume shall be 30 dry standard cubic feet. EPA Method 5 may be used with filter temperature no more than 320 degrees Fahrenheit. For EPA Method 17, stack temperature shall be less than 375 degrees Fahrenheit. The owner or operator may use EPA Method 5 to demonstrate compliance. EPA Method 3 or 3A with Orsat analysis shall be used when the oxygen based F-factor, computed according to EPA Method 19, is used in lieu of heat input. Acetone wash shall be used with EPA Method 5 or 17. [Rules 62-213.440, 62-296.405(1)(e)2., and 62-297.401, F.A.C.; Permit No. 0170004-003-AC] A.19. VE. The test method for VE shall be EPA Method 9, incorporated in Chapter 62-297, F.A.C. In lieu of Method 9 testing, a transmissometer utilizing a 6-minute block average for opacity measurement may be used, provided such transmissometer is installed, certified, calibrated, operated and maintained in accordance with the provisions of 40 CFR 75. [Rules 62-296.405(1)(e)1. and 62-297.401, F.A.C.; Permit No. 0170004-003-AC] A.20. SO2. The test methods for SO 2 emissions shall be EPA Methods 6, 6A, 6B, or 6C, incorporated by reference in Chapter 62-297, F.A.C. Fuel sampling and analysis may be used as an alternate sampling procedure. The Department will retain the authority to require EPA Method 6 or 6C if it has reason to believe that exceedences of the sulfur dioxide emissions limiting standard are occurring. Results of an approved fuel Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 9 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection A. Emissions Units 001, 002 sampling and analysis program shall have the same effect as EPA Method 6 test results for purposes of demonstrating compliance or noncompliance with sulfur dioxide standards. The permittee may use the EPA test methods, referenced above, to demonstrate compliance; however, as an alternate sampling procedure authorized by permit, the permittee may demonstrate compliance using fuel sampling and analysis. If the permittee elects to discontinue fuel sampling and analysis, it shall perform a stack test for sulfur dioxide at the time of the next particulate matter test, and annually thereafter until fuel sampling and analysis is resumed. [Rules 62-213.440, 62-296.405(1)(e)3. and 62-297.401, F.A.C.; Permit No. 0170004-003-AC; PA 77-09] A.21. SO? - Fuel Analysis. The owner or operator may demonstrate compliance with the SO 2 limitation using fuel sampling and analysis. This protocol is allowed because the emissions unit does not have an operating flue gas desulfurization device. See specific conditions A.20. and A.22. [Rule 62-296.405(1)(f)1.b., F.A.C.; Permit Nos. 0170004-003-AC and 0170004-006-AC] A.22. SO? - Alternate Fuel Sampling. The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the SO2 standard:

a. Method. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.
b. Recordkeeping. Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.
c. Calculations. Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.

[Rules 62-213.440, 62-296.405(1)(e)3., 62-296.405(1)(f) 1.b. and 62-297.440, F.A.C.; Permit Nos. 0170004-003-AC and 0170004-006-AC] A.23. When PM Tests Not Required. Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning:

a. only gaseous fuel(s); or
b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or
c. only liquid fuel(s) for less than 400 hours per year.

[Rules 62-297.310(7)(a)3. & 5., F.A.C.; and, ASP Number 97-B-01.] Recordkeeping and Reporting Requirements A.24. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority: Report Reporting Deadline Related Condition(s) Notice of Excess Emissions Quarterly A.25. A.25. Quarterly Reporting. The owners or operators shall submit to the Department a written report of emissions in excess of the emission limiting standards, for each calendar quarter. The nature and cause of the excessive emissions shall be explained. This report does not relieve the owner or operator of the legal liability for violations. All recorded data shall be maintained on file by the facility for a period of five years. [Rules 62-213.440 and 62-296.405(g), F.A.C.] A.26. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Other Requirements A.27. These emissions units are also subject to conditions contained in Subsection J. Used Oil Common Condition. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 10 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004 The specific conditions in this section apply to the following emissions units: EU No. Brief Description 003 FFSG, Unit 5 004 FFSG, Unit 4 Emissions units 003 and 004 (EU003 and EU004) are pulverized coal, dry bottom, wall-fired boilers. Both are rated at 760 MW. Emissions are exhausted through their own stacks. Each stack is 600 feet stack with a 25.5 feet exit diameter, 253 'F exit temperature and 2,979 acfm actual volumetric flow rate. Emissions are controlled from each unit with a high efficiency electrostatic precipitator, manufactured by Combustion Engineering. [PermittingNotes: These emissions units are regulated underAcid Rain, Phase I and H and Rule 62-210.300, F.A.C., Permits Required; 40 CFR 60 Subpart D, Standardsof Performancefor Fossil-Fuel-FiredSteam Generatorsfor Which ConstructionIs Commenced After August 17, 1971; PSD-FL-007 issued by EPA in February 1978 and, Power Plant Siting CertificationPA 77-09 conditions. Fossilfuelfired steam generator Unit 4 began commercial operation in 1982. Fossilfuelfired steam generatorUnit 5 began commercial operationin 1984.] Essential Potential to Emit (PTE) Parameters B.1. Permitted Capacity. The maximum allowable heat input rate is as follows: Unit No. MMBtu/hr Heat Input Fuel Type Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture Bituminous Coal and Bituminous Coal /Bituminous Coal Briquette Mixture [Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), 62-214.330, F.A.C.] B.2. Methods of Operation - Fuels. The fuels that are allowed to be burned in these units are:

a. Bituminous coal,
b. Bituminous coal and bituminous coal briquette mixture with the exception that No. 2 Fuel oil may be used as an ignitor fuel and natural gas may be used as a startup and low load flame stabilization fuel.
c. Used oil in accordance with the specific conditions of this permit (See Subsection J.).

[Rule 62-213.410, F.A.C.; Permit No. 0170004-006-AC; PPSC PA-77-09 and modified conditions] B.3. Flue Gas Desulfurization (FGD) Equipment. Prior to the installation of any FGD equipment, plans and specifications for such equipment shall be submitted to the Department for review and approval. [PPSC PA 77-09] B.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] B.5. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions B.6. - B.10. are based on the specified averaging time of the applicable test method. B.6. PM Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which:

a. Contain PM in excess of 43 nanograms per joule heat input (0.10 lb per million Btu) derived from fossil fuel.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 11 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004

b. Exhibit greater than 20 percent opacity, six minute average, except for one six-minute period per hour of not more than 27 percent opacity.

[40 CFR 60.42(a)(1) & (2)] B.7. SO1 Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain SO 2 in excess of:

a. 340 nanograms per joule heat input (0.80 lb per million Btu), 24-hour average, derived from liquid fossil fuel.
b. 520 nanograms per joule heat input (1.2 lb per million Btu), 24-hour average, derived from solid fossil fuel.
c. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) shall be determined by proration using the following formula:

PSS 0 2 = [y(340) +z(520)]/(y+z) where: PSS0 2 is the prorated standard for sulfur dioxide when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired, y is the percentage of total heat input derived from liquid fossil fuel, and z is the percentage of total heat input derived from solid fossil fuel.

d. Compliance shall be based on the total heat input from all fossil fuels burned, including gaseous fuels.

[40 CFR 60.43(a), (b) and (c); and, PPSC PA 77-09] B.8. SO, - Sulfur Content.

a. The maximum percent sulfur content of the coal/briquette mixture shall not exceed 0.68%, by weight, averaged on an annual basis. [Rule 62-213.440, F.A.C.; and, Permit No. 0170004-006-AC]
b. Fuel oil shall not contain more than 0.73% sulfur by weight. (See Specific Condition B.2.) [Rule 62-213.410, F.A.C.; PPSC PA-77-09 and modified conditions]

B.9. Nitrogen Oxides (NOx) Emissions. No owner or operator shall cause to be discharged into the atmosphere from any affected facility any gases which contain nitrogen oxides, expressed as NO 2 , in excess of:

a. 86 nanograms per joule heat input (0.20 lb per million Btu), 30-day rolling average, derived from gaseous fossil fuel.
b. 129 nanograms per joule heat input (0.30 lb per million Btu), 30-day rolling average, derived from liquid fossil fuel.
c. 300 nanograms per joule heat input (0.70 lb per million Btu), 30-day rolling average, derived from solid fossil fuel.
d. When different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) is determined by proration using the following formula:

PSNOx = x(86)+y(130)+z(300) x+y+z where: PSNOx = is the prorated standard for nitrogen oxides when burning different fuels simultaneously, in nanograms per joule heat input derived from all fossil fuels fired or from all fossil fuels fired; x = is the percentage of total heat input derived from gaseous fossil fuel; y = is the percentage of total heat input derived from liquid fossil fuel; and, z = is the percentage of total heat input derived from solid fossil fuel. [40 CFR 60.44(a)(2) and (3), and (b); and, PPSC PA 77-09] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 12 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004 B.10. Unit Specific State Only Limit For NOx. A unit specific, state-only average annual NOx emission limit of 0.50 lb/MMBtu applies. Compliance shall be demonstrated within the Annual Operating Report (AOR). [Rule 62-4.070(3), F.A.C.] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. B.11. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] B.12. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] B.13. NSPS Excess Emissions. Excess emissions shall be as defined in 40 CFR 60.45(g), Subpart D, Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced After August 17, 1971. [40 CFR 60.45(g)] Monitorine of Operations B.14. CAM Plan. These emissions units are subject to the Compliance Assurance Monitoring (CAM) requirements contained in the attached Appendix CAM. Failure to adhere to the monitoring requirements specified does not necessarily indicate an exceedance of a specific emissions limitation; however, it may constitute good reason to require compliance testing pursuant to Rule 62-297.310(7)(b), F.A.C. [40 CFR 64; Rules 62-204.800 and 62-213.440(1)(b)l.a., F.A.C.] B.15. Ambient Air Monitoring. An ambient monitoring station located on site (Site No. 2) includes monitors for particulate matter less than 10 micrometers in diameter (PM 10), particulate matter 2.5 micrometers in diameter and smaller (PM 2 5), and SO 2 . All monitors located at Site No. 2 will continue to be operated by Progress Energy Florida (PEF) and PEF will continue reporting data from these monitors as required by Special Condition 1.A.2 of the Conditions of Certification. New or existing monitoring devices shall be located as designated by the Department. The monitoring devices for sulfur dioxide shall meet the requirements of 40 CFR 53. [PPSC PA 77-09, and order modifying conditions of certification, OGC Case No. 83-0818, dated February 2, 1984, and Rules 62-213.440 and 62-296.405(1)(c)3., F.A.C.; Department letter dated July 23, 2008] Continuous Monitoring Requirements B.16. Required Continuous Monitoring Systems (CMS). Continuous monitoring systems are required for SO 2, NOx, CO 2 and opacity. CMS shall be in accordance with the requirements of 40 CFR 60.45. [40 CFR 60.45; and PPSC PA 77-09] B.17. COMS for Periodic Monitoring: Periodic monitoring for opacity shall be COMS, which are maintained and operated in conformance with 40 CFR Part 75. [Rule 62-213.440, F.A.C.] Test Methods and Procedures B.18. Test Methods. Required tests shall be performed in accordance with the following reference methods: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 13 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004 Method Description of Method and Comments Determination of Oxygen and Carbon Dioxide Concentrations in Emissions from Stationary Sources Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 5 Determination of Particulate Emissions from Stationary Sources 5B Determination of Sulfur Dioxide Emissions from Stationary Sources Determination of Sulfur Dioxide Daily Average Emissions from Fossil Fuel Combustion Sources Determination of Sulfur Dioxide and Carbon Dioxide Daily Average Emissions From Fossil Fuel Combustion Sources 6B Determination of Sulfur Dioxide Emissions from Stationary Sources 6C Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Nitrogen Oxide Emissions from Stationary Sources - Ion Chromatographic Method Determination of Nitrogen Oxide Emissions from Stationary Sources - Alkaline-Permanganate/Colormetric Method Determination of Nitrogen Oxide Emissions from Stationary Sources (Instrument Analyzer Procedure) Gas Analysis for The Determination of Emission Rate Correction Factor or Excess Air 7E Determination of Nitrogen Oxide Emissions from Stationary Sources Determination of Sulfuric Acid Mist and Sulfur Dioxide Emission from Stationary Sources 9 Visual Determination of the Opacity of Emissions from Stationary Sources Determination of Sulfur Dioxide Removal Efficiency and Particulate Matter, Sulfur Dioxide, and Nitrogen Oxides Emission Rates (Optional F-factor method may be used to determine flow rate and gas analysis to calculate mass emissions in lieu of Methods 1-4.) ASTM Method D2015- Standard Methods by the American Society of Testing and Materials for fuel 77, D240-76, D1826-77, analysis ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C.; 40 CFR 60 Subpart D] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 14 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004 B.19. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] B.20. Annual Compliance Tests Required. Except as provided in Specific Condition B.27., during each federal fiscal year (October 1st to September 3 0 th), each EU003 and EU004 shall be tested to demonstrate compliance with the emissions standards for PM, VE, SO 2 and NOx. [Rule 62-297.310(7), F.A.C.] B.21. Compliance Tests Prior To Renewal. Except as provided in Specific Condition B.27., compliance tests shall be performed for PM, VE, SO 2 and NOx once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions B.6. - B.10. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.] B.22. Compliance Testing Required. The owner or operator shall conduct emission testing in accordance with the requirements of 40 CFR 60.46. [40 CFR 60.46] B.23. Annual RATA Tests May Substitute for Annual NOx and SO) Tests. Annual RATA tests performed for NOx and SO 2 may be substituted for the annual compliance tests for these pollutants. To substitute for the annual compliance tests, the owner or operator must notify the Department of the RATA tests at least 15 days prior to the date on which each formal compliance test is to begin and the results must be submitted as the compliance tests no later than 45 days after the last sampling run of each test is completed. The test runs shall be consecutively completed in a manner that fulfills the test length requirements of the EPA test methods. [40 CFR 75; Request of applicant, February 11, 1998] B.24. SO, - Fuel Analysis. The permittee shall demonstrate compliance with the SO 2 limit in specific condition B.8.a. by means of a fuel analysis provided by the vendor or the permittee upon each fuel delivery. See specific condition B.25. [Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC] B.25. SO - Alternate Fuel Sampling. The following fuel sampling and analysis program shall be used as an alternate sampling procedure authorized by permit to demonstrate compliance with the fuel sulfur standard:

a. Methods. Determine and record the as-fired fuel sulfur content, percent by weight, for coal using appropriate ASTM methods such as, ASTM D2013-72, ASTM D3177-75, and ASTM D4239-85, or latest ASTM edition methods, to analyze a representative sample of coal following each fuel delivery.
b. Recordkeeping. Record daily the amount of coal fired, the density of each fuel, the Btu value, and the percent sulfur content by weight of each fuel.
c. Calculations. Utilize the information in a. and b., above, to calculate the SO 2 emission rate to ensure compliance at all times.

[Rule 62-213.440, F.A.C.; Permit No. 0170004-006-AC] B.26. VE. The test method for VE shall be EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Chapter 62-297, F.A.C. [Rules 62-296.405(1)(e)1. and 62-297.401, F.A.C.] B.27. When PM Tests Not Required. Annual and permit renewal compliance testing for particulate matter emissions is not required for these emissions units while burning:

a. only gaseous fuel(s); or
b. gaseous fuel(s) in combination with any amount of liquid fuel(s) for less than 400 hours per year; or
c. only liquid fuel(s) for less than 400 hours per year.

[Rules 62-297.310(7)(a)3. & 5., F.A.C.; and, ASP Number 97-B-01.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 15 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection B. Emissions Units 003, 004 Recordkeeping and Reporting Requirements B.28. Reporting Schedule. The following reports and notifications shall be submitted to the Compliance Authority: Report Reporting Deadline Related Condition(s) Notice of Excess Emissions Postmarked by the 3 0 th day following the B.13. and B.29 end of each six-month period B.29. Excess Emission Reports. Excess emissions, as defined in 40 CFR 60.45(g), shall be reported in accordance with the requirements of 40 CFR 60.45(g). [40 CFR 60.45(g)] B.30. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Other Requirements B.31. These emissions units are also subject to condition J.1. contained in Subsection J. Used Oil Common Condition. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 16 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection C. Emissions Units 006, 008, 009, 010 The specific conditions in this section apply to the following emissions units:. EU No. Brief Description 006 Fly ash transfer (Source 1) from FFSG Unit 1 008 Fly ash storage silo (Source 3) for FFSG Units 1 and 2 009 Fly ash transfer (Source 4) from FFSG Unit 2 010 Fly ash transfer (Source 5) from FFSG Unit 2 Emissions unit 006 (EU006) is a fly ash transfer (Source 1) from FFSG Unit 1. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 1 electrostatic precipitator (ESP) to the fly ash storage silo (Source 3) at a design transfer rate of 44 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 1,820 acfm. Emissions unit 008 (EU008) is a fly ash storage silo (Source 3) for FFSG Units 1 and 2. This emissions unit consists of the fly ash storage silo used to store fly ash from the ESP of FFSG Units 1 and 2. Fly ash is pneumatically conveyed from the FFSG Units 1 and 2 ESPs at a combined transfer rate of 174 tons per hour. PM emissions are controlled by a Pulse King Model M 100 S baghouse at a design air flow of 2,546 acfm. Fly ash from the storage silo is disposed of either in a dry form by loading into enclosed tanker trucks or in a wet form by loading wet ash into open trucks. Emissions unit 009 (EU009) is a fly ash transfer (Source 4) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2C to the fly ash storage silo (Source 3) at a design transfer rate of 60 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,200 acfm. Emissions unit 010 (EU010) is a fly ash transfer (Source 5) from FFSG Unit 2. This emissions unit consists of the fly ash conveying line, dense phase transfer vessel and separator used to transfer fly ash from the FFSG Unit 2 ESP number 2A and 2B to the fly ash storage silo (Source 3) at a maximum design transfer rate of 70 tons per hour. PM emissions are controlled by a Monex Resources, Inc. Model MD80 baghouse at a design air flow of 2,800 acfm. (Permittingnote(s): These emissions units are regulated under Best Available Control Technology (BACT) Determinationsordered2/5/79 (proposed1/26/79) and 8/16/79.] Essential Potential to Emit (PTE) Parameters C.1. Permitted Capacity. The transfer rates shall not exceed: EU No. Transfer Rate (tons per hour) 006 44 008 174 009 60 010 70 [Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.] C.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] C.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 17 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection C. Emissions Units 006, 008, 009, 010 C.4. Additional Reasonable Precautions for Control of PM Emissions. The owner or operator shall take the following reasonable precautions to control emissions of PM from transport of ash from EU008 for disposal or use:

a. Ash for transport shall be wetted before loading into open trucks,
b. Dry ash shall be transferred to enclosed tanker trucks.

[Permit No. AC09-256791] Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions C.5. - C.6.. are based on the specified averaging time of the applicable test method. C.5. PM Emission Limitations. Emissions of particulate matter from the following emissions units shall not exceed: EU No. Emission Limit Emission Limit (pounds per hour) (tons per year) 006 3.5 15.4 008 0.6 2.6 009 2.2 9.6 010 2.2 9.6 [Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79] C.6. VE. VE from each of the Units 1 and 2 flyash handling system baghouse exhaust stacks shall not exceed 5% opacity. See Specific Condition C.13. [Permit No. AC09-256791; BACT Determinations dated 2/5/79 and 8/16/79] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. C.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] C.8. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Test Methods and Procedures C.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources Visual Determination of Fugitive Emissions from material Sources and Smoke Emissions 2from Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [62-297.401, F.A.C., Permit No. AC09-256791] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 18 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection C. Emissions Units 006, 008, 009, 010 C.10. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] C.11. Annual Compliance Tests Required. During each federal fiscal year (October 1 sI to September 3 0 th), each EU006, EU008, EU009 and EU010 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7), F.A.C. and Permit No. AC09-256791] C.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions C.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.] C.13. VE in Lieu of Stack Test. Due to the expense and complexity of conducting a stack test on minor sources of PM and because the ash handling system emissions units are controlled with baghouses, the Department, pursuant to Rule 62-297.620(4), F.A.C. will consider compliance with 5% VE limitation (See Specific Condition C.6.) as reasonable assurance of compliance with the PM emission limitations in Specific Condition C.5. in lieu of particulate stack tests. If the Department has reason to believe that the particulate emission standard applicable to each emissions unit (006, 008, 009 and 010) is not being met, it may require that compliance be demonstrated by stack testing in accordance with Chapter 62-297, F.A.C. [Permit No. AC09-256791; BACT Determination dated 2/5/79] C.14. VE. Compliance for VE shall be demonstrated using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C. and referenced in Rule 62-297, F.A.C. C.15. Specific VE Test Requirements. Each test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each of the baghouse filter/separate exhausts (total of four emission points to be tested). VE testing shall be conducted while transferring fly ash from both FFSG Units 1 and 2 to the silo (EU008) at the same time. The tests shall be conducted during a period when both FFSG Units 1 and 2 are operating at 90 to 100% of full load while sootblowing. A statement of the FFSG unit loads, verifying the tests were conducted during sootblowing, shall be submitted with the test reports. [Permit No. AC09-256791] [Permitting note: Forthose emissions points containing a baghouse, the permittee shall perform and record the results of weekly qualitative observations of VE checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormal VE.] Recordkeeping and Reporting Reqiuirements C.16. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 19 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection D. Emissions Unit 014 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 014 Bottom Ash Storage Silo for FFSG Units 1 and 2 Emissions unit 014 (EU014) is a bottom ash storage silo for FFSG Units 1 and 2, with associated vacuum blower exhausts and bin vent filter (total of three emission points). This emissions unit consists of the system to collect and store bottom ash and economizer ash from both FFSG Units 1 and 2 at a total rate of 16 tons per hour (8 tons per hour from each FFSG unit) at an airflow rate of 2,200 standard cubic feet per minute (scfm) from each unit. Ash is conveyed by vacuum from each FFSG unit by a separate vacuum blower, with air and ash passing through a baghouse (filter/separator) where ash is deposited in the silo and air is exhausted through the vacuum blower. Air displaced in the silo is vented through an additional bag filter (the bin vent filter) at an airflow rate of 2,400 scfm. Ash stored in the silo is unloaded into trucks for sale, use or disposal at the on-site ash disposal facility. Ash will be wet via a pug mill before loading into open trucks, or dry ash will be transferred to enclosed tanker trucks. [Permittingnote(s): This emissions unit is regulatedunder Rule 62-296.320, F.A. C., and by applicable requirements of AC09-235915.} Essential Potential to Emit (PTE) Parameters D.A. Permitted Capacity. The maximum rate of transfer of ash from Units 1 and 2 to the ash storage silo shall not exceed 16 tons per hour (8 tons per hour from each FFSG unit). [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C.; Permit No. AC09-235915] D.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] D.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] D.4. Additional Reasonable Precautions for Control of PM Emissions. The owner or operator shall take the following reasonable precautions to control emissions of particulate matter from transport of ash from EU014 for disposal or use:

a. Ash for transport shall be wet via a pug mill before loading into open trucks,
b. Dry ash shall be transferred to enclosed tanker trucks.

[Permit No. AC09-235915] Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions D.5. - D.6. are based on the specified averaging time of the applicable test method. D.5. PM Emissions. The maximum allowable emission rate of PM from the bottom/economizer ash handling system for a maximum process transfer rate of 8 tons per hour per unit is 13.03 pounds per hour as set by the Process Weight Table contained within Rule 62-296.320(4), F.A.C. At lesser process rates the allowable emission rates can be determined front the appropriate equation. This limitation represents total combined PM emissions from the two filter/separator exhausts and the bin vent filter exhaust. [Permit No. AC09-235915] D.6. VE Limitation. Due to the expense and complexity of conducting a stack test on minor sources of PM, and because this ash handling system is equipped with baghouse control devices, the Department, pursuant to Rule 62-297.620(4), F.A.C., establishes a VE limitation not to exceed an opacity of 5% in lieu of a PM stack test. This limitation applies to emissions from the two filter/separator exhausts and to the bin vent filter exhaust. [Permit No. AC09-235915] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 20 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection D. Emissions Unit 014 Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. D.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] D.8. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Test Methods and Procedures D.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C.; Permit No. AC09-235915] D.10. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] DA.L Annual Compliance Tests Required. During each federal fiscal year (October 1s to September 3 0 th), EU014 shall be tested to demonstrate compliance with the emissions standards for VE. [Rule 62-297.310(7), F.A.C.; Permit No. AC09-235915] D.12. Compliance Tests Prior To Renewal. Compliance tests shall be performed for VE once every 5 years. The tests shall occur prior to obtaining a renewed operating permit to demonstrate compliance with the emission limits in Specific Conditions D.6. [Rules 62-210.300(2)(a) and 62-297.310(7)(a), F.A.C.; Permit No. AC09-235915] D.13. VE. Each emission point of EU014 shall demonstrate compliance using EPA Method 9, adopted and incorporated by reference in Rule 62-204.800, F.A.C., and referenced in Chapter 62-297, F.A.C. The minimum requirements for stationary point source emission test procedures shall be in accordance with Rule 62-297, F.A.C. and 40 CFR 60 Appendix A. [Permit No. AC09-235915] D.14. Specific VE Test Requirements. The visible emissions test shall be a minimum of thirty minutes in duration. Separate VE tests shall be conducted on each the filter/separator exhausts and the bin vent filter exhaust (total of three emission points to the tested). Tests shall be conducted with both Units 1 and 2 transferring ash to the storage silo at the same time. A statement of the approximate ash transfer rate during the test shall be submitted with each test report. Failure to submit the process transfer rate and or operation under conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance. [Permit No. AC09-235915] Recordkeepin2 and Reporting Requirements D.15. Reporting Ash Transfer Rate. A statement of the approximate ash transfer rate during the test shall be submitted with each compliance test report. Failure to submit the process transfer rate and or operation under Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 21 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection D. Emissions Unit 014 conditions that are not representative of normal operations may invalidate the test and fail to provide reasonable assurance of compliance. [Permit No. AC09-235915] D.16. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 22 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection E. Emissions Unit 012 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 012 Three relocatable diesel generator(s) Emissions unit 012 (EU012) consists of three relocatable Caterpillar Model 3508-DITA 820 kilowatt (kW) diesel generators. Each relocatable diesel generator has a maximum heat input of 8.58 MMBtu/hr. Each generator is fueled by new No. 2 fuel oil per hour with a maximum rating of 820 kilowatts. Each generator has its own stack. Emissions from the generators are uncontrolled, and therefore, are not subject to CAM. (Permittingnotes: These emissions units are regulated under Rule 62-210.300, F.A.C., PermitsRequired. This section of the permit is only applicablewhen the generatorsare located at the Crystal River Power Plant. These relocatablegeneratorswere permitted in 1991 under permit No. AC09-202080.] Essential Potential to Emit (PTE) Parameters E.1. Permitted Capacity. The maximum (combined) allowable heat input rate and fuel firing rate is as follows: EU No. MMHetuIhr Gallons/hour Fuel Type Heat Input 012 8.58 (each 62.1 New No. 2 Fuel Oil generator) [Rules 62-4.160(2), 62-204.800, 62-210.200(PTE), F.A.C.; and, Permit No. AC09-202080.] E.2. Methods of Operation - Fuels. Only new No. 2 fuel oil with a maximum sulfur content of 0.5%, by weight, shall be burned in this unit. [Permit No. AC09-202080] E.3. Hours of Operation. The hours of operation expressed as "engine-hours" shall not exceed 2,970 hours in any consecutive 12 month period. The total hours of operation expressed as "engine-hours" shall be the summation of the individual hours of operation of each generator. [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C.; Permit No. AC09-202080.] E.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition E.5. is based on the specified averaging time of the applicable test method. E.5. VE. VE shall not be equal to or greater than 20 percent opacity. [Rule 62-296.320(4)(b)1, F.A.C.; Permit No. AC09-202080] E.6. S02 - Sulfur Content. The new No. 2 fuel oil sulfur content shall not exceed 0.5%, by weight. [Permit No. AC09-202080] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. E.7. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 23 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection E. Emissions Unit 012 E.8. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Test Methods and Procedures E.9. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources ASTM D1552-90 or later Standard Test Methods for Sulfur in Petroleum Products editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rules 62-204.800, 62-297.401 and 62-297.440, F.A.C.] E.10. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] E.11. Annual Compliance Tests. During each federal fiscal year (October 1st to September 3 0 th), EU012 shall be tested to demonstrate compliance with the emissions standards for VE. Annual emissions compliance testing for visible emissions is not required for these emissions units while burning liquid fuels for less than 400 hours per year. [Rules 62-297.310(7), and 62-297.310(7)(a)4. & 8., F.A.C.] E.12. Compliance Tests Prior to Renewal. Except as provided for in condition TR7. of Appendix TR, Testing Requirements, EU012 shall be tested for the following pollutant prior to obtaining a renewed operation permit: VE. [Rule 62-297.310(7)(a)3., F.A.C.] E.13. VE. The test method for VE shall be EPA Method 9, incorporated and adopted by reference in Rule 62-204.800. F.A.C., and referenced in Chapter 62-297, F.A.C. [Rule 62-297.310(4), F.A.C.; Permit No. AC09-202080] E.14. SO - Sulfur Content Testing. The fuel sulfur content, percent by weight, for liquid fuels shall be evaluated using either ASTM D1552-90 or later editions, ASTM D2622-94, ASTM D4294-90, or both ASTM D4057-88 and ASTM D129-91, or later editions. In addition, any ASTM method (or later editions) referenced in Rule 62-297-440(1) F.A.C., or in 40 CFR 60.335 (b)(10) is acceptable, [Rules 62-213.440 and 62-297.440, F.A.C.] E.15. Fuel Sulfur Analysis. The permittee shall demonstrate compliance with the liquid fuel sulfur limit by means of a fuel analysis provided by the vendor or permittee upon each fuel delivery. [Rule 62-213.440, F.A.C.] E.16. Testing after Relocation. After each relocation, each generator shall be tested within 30 days of startup for opacity and the fuel shall be analyzed for the sulfur content to demonstrate compliance with the permit limits in this section. [Rules 62-4.070(3) and 62-297.310(7)(b),F.A.C.; Permit No. AC09-202080] E.17. Testing Operating Rate. Testing of each diesel generator emissions must be accomplished while operating the diesel generator within + 10% of the maximum fuel firing rate of 62.1 gallons per hour. Failure to submit the actual operating rate may invalidate the test. [Permit No. AC09-202080] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 24 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection E. Emissions Unit 012 Recordkeeping and Reporting Requirements E.18. Recordkeeping. The owner or operator shall maintain the following records:

a. the daily hours of operation for each of the generators,
b. the daily hours of operation expressed as "engine- hours",
c. the cumulative total hours of operation expressed as "engine-hours" for each month, and
d. the sulfur content, in percent by weight, of all the fuel burned shall be kept based on either vendor provided as-delivered or as-received fuel sample analysis.

[Rules 62-213.440 and 62-297.310(8), F.A.C.; Permit No. AC09-202080] E.19. Relocation Notification. The permittee shall notify the compliance authority, in writing, at least 15 days prior to the date on which any diesel generator is to be relocated. The notification shall specify the following;

a. which generator, by serial number, is being relocated,
b. which location the generator is being relocated from and which location it is being relocated to, and
c. the approximate startup date at the new location.

[Permit No. AC09-202080] E.20. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Other Requirements E.21. PSD Avoidance. Specific conditions in construction permit AC09-202080, limiting the "engine hours", were accepted by the applicant to escape Prevention of Significant Deterioration review. If Progress Energy Florida, Inc. requests a relaxation of any of the federally enforceable emission limits in this permit, the relaxation of limits may be subject to the preconstruction review requirements of Rule 62-212.400(4) - (12), F.A.C., as though construction had not yet begun. [Rule 62-212.400(12), F.A.C.; Permit No. AC09-202080]. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 25 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection F. Emissions Unit 013 The specific conditions in this section apply to the following emissions unit: EU No.1 Brief Description 013 Cooling Towers for FFSG Units 1, 2 and Nuclear Unit 3 Emissions unit 013 (EU013) is cooling towers for FFSG units 1, 2 and nuclear unit 3, used to reduce plant discharge water temperature. (This emissions unit may be referred to as "helper cooling towers.") This emissions unit consists of four towers with nine cells per tower, with high efficiency (99.8%) drift eliminators, operating at a maximum seawater flow rate of 735,000 gallons per minute for all nine cells combined, with a design airflow rate of 1.46 x 106 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by high efficiency drift eliminators. [Permittingnote(s): This emissions unit is regulated under Prevention of Significant Deterioration(PSD)(PSD permit ACO9-162037/PSD-FL-139 issued 8/29/90) and Best Available Control Technology (BACT), Determinationdated 8/29/90, which set a drift emission rate of 0.004%.) Essential Potential to Emit (PTE) Parameters F.1. Hours of Operation. The operating hours for each cooling tower pump shall not exceed 4,320 hours per year (12-month rolling total). [Rule 62-210.200(PTE), F.A.C.; and, Permit No. AC09-162037/PSD-FL-139] F.2. Drift Eliminators. Drift eliminators shall be installed and maintained so that minimum bypass occurs. Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators. [Rule 62-213.440, F.A.C.; and, Permit No. AC09-162037/PSD-FL-139)] [PermittingNote: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets so visible emissions testing is not possible.] F.3. Pump Run Time Meters Required. Each cooling tower seawater pump shall be equipped each with a run-hour meters. [Rule 62-213.440, F.A.C.; and, AC09-162037/PSD-FL-139] F.4. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Conditions F.5. is based on the specified averaging time of the applicable test method. F.5. Cooling Tower Emission Limit. The maximum allowable emissions of particulate matter form each cell (stack) is 11.89 lb/hr. This is based on a 0.004% drift rate (ratio of drift to the circulate rate) and the following table: Flow Rate (gpm) Total PM (from all 36 cells) PM 10 lbs/hr TPY lbs/hr TPY 735,000 428 925 214 462 (PM 10 is approximately 50% of total PM) [Permit No. AC09-162037/PSD-FL-139, BACT] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 26 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection F. Emissions Unit 013 F.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] F.7. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Test Methods and Procedures F.8. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.3 10, F.A.C.] F.9. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During the warm months when the helper cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.004% drift rate):

a. Daily "walk down" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).
b. Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.
c. Weekly visual inspection of the inlet water screens and prompt correction when broken sections or pluggage is discovered.

[Rule 62-213.440, F.A.C.; and, AC 09-162037 (PSD-FL-139); and, ASP No. 00-E-01 dated June 7, 2000] Recordkeeping and Reporting Requirements F.10. Pump Run Logs. A log shall be maintained of the hours of operation of each pump supplying salt water to the helper cooling towers. Pump flow rates shall be determined from the manufacturer's certified pump curves, or any other equivalent method approved by the Department. [Rule 62-213.440, F.A.C.; Permit No. AC09-162037/PSD-FL- 139] F.11. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 27 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection G. Emissions Unit 015 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 015 Cooling Towers for FFSG Units 4 and 5 Emissions unit 015 (EU015) is cooling towers for FFSG Units 4 and 5 used to reduce plant discharge water temperature. (These towers are hyperbolic cooling towers.) Seawater is sprayed through the towers where induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions controlled by high efficiency drift eliminators. Seawater flow rate is 331,000 gallons per minute. [Permittingnote(s): This emissions unit is regulatedunder Prevention of Significant Deterioration(PSD) (PSD permit PSD-FL-007 issued by EPA as modified by EPA on 11/30/88.)) Essential Potential to Emit (PTE) Parameters G.1. Permitted Capacity. The maximum seawater flow rate shall not exceed 331,000 gallons per minute per cooling tower. [Rules 62-4.160(2) and 62-210.200(PTE), F.A.C., 62-204.800, F.A.C.] G.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] G.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition(s) G.4. is based on the specified averaging time of the applicable test method. G.4. PM Emissions - Cooling Tower Emission Limit. PM emissions shall not exceed 175 lb/hr from each cooling tower. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] [PermittingNote: The emission limit is based on a BACT Determinationrequiring control of drift emissions with drift eliminators. The modified PSD permit removed a limitation on drift rate, substituting an emissions limit in pounds per hour. PM emissions are assumed to be all PM1 0.] [PermittingNote: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets so visible emissions testing is not possible.] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. G.5. Excess Emissions. Should either tower emission rate exceed 175 lb/hr, the permittee shall:

a. Notify EPA and the Department within 10 days of becoming aware of the exceedance.
b. Provide an assessment of necessary corrective actions and a proposed schedule of implementation within an additional 20 days.
c. Expeditiously complete corrective actions.
d. Retest the tower within three months after the correction is completed.
e. Submit the testing report within 45 days after completion of said tests.

[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] G.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 28 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection G. Emissions Unit 015 G.7. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Monitoring of Operations G.8. Inspection. The drift eliminators of both towers shall be inspected from the concrete walkways not less than every three months by Progress Energy Florida staff or representatives to assure that the drift eliminators are clean and in good working order. Not less than annually, a complete inspection of the towers shall be conducted by a qualified inspector with recognized expertise in the field. Certification that the drift eliminators are properly installed and in good working order shall be provided in the record keeping and reporting requirements noted below. [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88]. Test Methods and Procedures G.9. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] G.10. Test Every Five Years. The FFSG Unit 4 cooling tower shall be tested every five years from 1988 (the next required year from the effective date of this permit is 2013). The FFSG Unit 5 cooling tower shall be tested every five years from 1992 (the next required year from the effective date of this permit is 2012). [Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] G.11. PM Emission Test Method. Testing shall be in accordance with following requirements:

a. PM emissions shall be measured by the sensitive paper method.
b. Testing shall be conducted either at the drift eliminator level within the tower or at the tower exit plane.

(The sampling locations at the drift eliminator level and apparatus are shown in diagrams attached as Appendix P.)

c. No less than three test runs shall be conducted for each test and all valid data from each of these test runs shall be averaged to demonstrate compliance. No individual test run result shall determine compliance or noncompliance. The emission rate reported as a percent of the circulating water, as well as lb/hr., and total dissolved solids in the cooling tower basin and intake water, shall be reported for each test run.

[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] Recordkeepin2 and Reporting Requirements G.12. Reporting. Reports on tower testing and inspection shall be handled as follows:

a. Maintained within onsite files within 30 days after all visual inspections of the drift eliminators.
b. Agency Submittal within 45 days after the compliance testing of either tower.

[Rule 62-213.440, F.A.C.; and, Modified PSD permit, PSD-FL-007, issued by EPA 11/30/88] G.13. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 29 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection H. Emissions Unit 016 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 016 Material handling activities for coal-fired steam units. Emissions unit 016 (EU016) is material handling activities for coal-fired steam units. This emissions unit consists of a crane-operated clam-shell bucket mounted on a traveling gantry, enclosed conveyor belts, coal crushers and storage bunkers used for the storage and transport of coal, for FFSG Units 1, 2, 4 and 5. The barge unloading capabilities are 2,500 tons per hour and 32,000 tons per day. The speed of the conveyors and the crusher associated with boilers 1 and 2 is 900 tons per hour. This unit also encompasses fly ash and bottom ash handling equipment associated with Units 4 and 5 which are not addressed by other emissions units. (Permittingnotes: This emissions unit is regulatedpartially under Power Plant Siting CertificationPA 77-09 (Units 4 and 5 only) and, is subject to NSPS 40 CFR 60 Subpart Y. This emissions unit is also regulated under permit number 0170004-014-AC (issued concurrently with this revised permit number 0170004-015-AV), which authorized the replacementof the barge unloading equipment to decrease the time requiredto unload coal barges, and the increase in conveying and crushing speeds of the equipmentfeeding coal to units I and 2.] Essential Potential to Emit (PTE) Parameters H.1. Containment of Fugitive Emissions. To the extent possible, the equipment that comprises the coal processing equipment at this facility (crushers, conveyors, drop points, and storage bunkers) shall be covered or enclosed at all times when the equipment is in operation. Except for the barge load-out and the stacker re-claimer sections of the conveying system that are required by design to be open, and which are not specifically subject to regulation under 40 CFR 60 Subpart Y, any other open section of the coal processing equipment shall be required to have any annual emission test conducted upon it. [Permit No. 0170004-014-AC] H.2. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] H.3. Hours of Operation. The emissions units may operate continuously, i.e., 8,760 hours/year. [Rule 62-210.200(PTE), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging time for Specific Condition H.4 is based on the specified averaging time of the applicable test method. H.4. VE. The owner or operator shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater, six minute average. [PPSC PA 77-09 (coal facilities associated with Units 1, 2, 4 and 5); and, Permit No. 0170004-014-AC] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. H.5. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 30 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection H. Emissions Unit 016 H.6. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Test Methods and Procedures H.7. Test Methods. Required tests shall be performed in accordance with the following reference methods: Method Description of Method and Comments 9 Visual Determination of the Opacity of Emissions from Stationary Sources 22 Visual Determination of Fugitive Emissions from Material Sources and Smoke Emissions form Flares The above methods are described in 40 CFR 60, Appendix A, and adopted by reference in Rule 62-204.800, F.A.C. No other methods may be used unless prior written approval is received from the Department. [Rule 62-297.401, F.A.C., Permit No. 0170004-014-AC] H.8. Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] H.9. VE. (This condition applies to coal facilities associated with emissions units 001, 002, 004 and 003 -- FFSG Units 1, 2, 4 and 5.) When required by the Department, or annually as specified in Specific Condition H.1., EPA Method 9 and the procedures in 40 CFR 60.11 shall be used to determine opacity. [40 CFR 60.254; and, Permit No. 0170004-014-AC] (Permitting Note: Except as specified in Specific Condition H.9., annual testing is not being required because the regulated emissions points are either enclosed or confined within a building.] (Permittingnote: For those emissions points containing a baghouse (ash silos), the permittee shall perform and record the results of weekly qualitative observations of visible emissions checks (e.g., Method 22) with follow-up Method 9 tests within 24 hours of any abnormalvisible emissions.] Recordkeeping and Reporting Requirements H.10. Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 31 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection I. Emission Unit 020 The specific conditions in this section apply to the following emissions unit: EU No. Brief Description 020 Cooling towers for FFSG Units 1 and 2 used to reduce plant discharge water temperature. Emissions unit 020 (EU020) is cooling towers for FFSG Units 1 and 2, used to reduce plant discharge water temperature. (This emission unit may be referred to as "portable cooling towers.") This emissions unit consists of 71 or 72 cells (dependent upon manufacturer), is 12' wide and 11' high, includes drift eliminators, operates at a maximum circulating seawater flow rate of 180,000 gallons per minute for all cells combined, and a design airflow rate of 25,000 acfm from each cell. Seawater is sprayed through the towers where fan induced air flow causes evaporative cooling. Water vapor, saltwater droplets (drift) and salt particles are emitted. Drift emissions are controlled by drift eliminators. (Permittingnote(s): This emissions unit is regulatedunder Prevention of Significant Deterioration(PSD) (permit 0170004-010-AC) and includes a Best Available Control Technology (BACT) Determination,which allows for a drift emission rate of 0.0015% with limited usage.] Essential Potential to Emit (PTE) Parameters 1.1. Hours of Operation. The operating hours for the portable cooling towers shall not exceed an equivalent of 2,920 hours per year of operation (12-month rolling total). This condition shall be complied with by limiting the circulating water flow usage through the portable cooling towers to 31.5 x 109 gallons per calendar year. [Rule 62-210.200(PTE), F.A.C.; Permit No. 0170004-010-AC)] 1.2. Drift Eliminators. Drift eliminators shall be installed and maintained as per the manufacturer's specifications. Regular maintenance shall be scheduled to ensure proper operation of the drift eliminators. [Rule 62-213.440, F.A.C.; Permit No. 0170004-010-AC)] (Permitting Note: This emissions unit is not subject to a visible emissions limitation. Emissionsfrom this emissions unit include water droplets, so visible emission testing is not possible.] 1.3. Emissions Unit Operating Rate Limitation After Testing. See the related testing provisions in Appendix TR, Facility-wide Testing Requirements. [Rule 62-297.310(2), F.A.C.] Emission Limitations and Standards Unless otherwise specified, the averaging times for Specific Conditions 1.4. - 1.5.. are based on the specified averaging time of the applicable test method. 1.4. Drift Rate. The portable cooling towers shall be designed, operated and maintained to achieve a drift rate of no more than 0.0015% of the circulating water flow. [Permit No. 0170004-010-AC] 1.5. PM Emissions. The drift rate standard in Specific Condition 1.4. equates to an estimated emission rate of particulate matter (PM) from the cooling tower at 35.1 pounds per hour. [Permit No. 0170004-010-AC] (Permitting Note: The emission limit is based on a BACT Determinationsetting the maximum drift emissions at 0.0015%. PM1O emissions are estimated to be approximately 6% of the particulatematter emission rate.] Excess Emissions Rule 62-210.700 (Excess Emissions), F.A.C. cannot vary any requirement of an NSPS, NESHAP or Acid Rain program provision. 1.6. Excess Emissions Allowed. Excess emissions resulting from startup, shutdown or malfunction shall be permitted provided that best operational practices to minimize emissions are adhered to and the duration of excess emissions shall be minimized but in no case exceed two hours in any 24 hour period unless specifically authorized by the Department for longer duration. [Rule 62-210.700(1), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 32 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection I. Emission Unit 020 1.7. Excess Emissions Prohibited. Excess emissions which are caused entirely or in part by poor maintenance, poor operation, or any other equipment or process failure which may reasonably be prevented during startup, shutdown or malfunction shall be prohibited. [Rule 62-210.700(4), F.A.C.] Monitoring of Operations 1.8. Inspection Log. Any problems detected during the work practice inspections identified in Specific Condition 1.10. shall be documented in a log identifying the cell (or water screen), the inspector, the time (when discovered and the hours operated before the problem was corrected), and a description of the problem and the corrective actions taken. This log shall be maintained onsite and shall be made available to DEP upon request. The log shall be maintained so as to provide an indication as to whether routine inspections have been conducted as required even when there are no problems to record. [Rules 62-213.440 and 62-297.310(7), F.A.C., Permit No. 0170004-010-AC and ASP No. 00-E-01 dated June 7, 2000] Test Methods and Procedures 1.9. Common Testing Requirements. Unless otherwise specified, tests shall be conducted in accordance with the requirements and procedures specified in Appendix TR, Facility-Wide Testing Requirements, of this permit. [Rule 62-297.310, F.A.C.] 1.10. Emission Test Method. The drift elimination system on the helper cooling towers shall be maintained so as to minimize pluggage and to insure timely repair of broken sections of the drift eliminators. During those calendar days when the portable cooling towers are used, the following work practice shall be implemented, in lieu of EPA Method 5, to demonstrate compliance with the originally designed removal efficiency (no more than 0.0015% drift rate):

a. Walkdown Inspections. Daily "walkdown" inspection of each operational cell visually checking for problems with the drift eliminators such as pluggage, algae build-up, and mechanical components (fans and pumps).
b. Visual Inspections. Daily visual inspection of the cells which are in operation to ascertain the presence of higher than expected visible emissions when atmospheric conditions allow, and follow-up inspections and correction of problems when the daily visual inspection of the cells indicates a problem.
c. Weekly Inspections. Weekly visual inspections of the inlet water screens and prompt correction when broken sections or pluggage is discovered.

[Rule 62-213.440, F.A.C., Permit No. 0170004-010-AC; and ASP No. 00-E-01 dated June 7, 2000] Recordkeeping and Reportin2 Requirements 1.11. Circulating Water Flow-Meters Required. Circulating water flow will be measured by monitoring the hours of each circulating water pump. For each hour of operation, each north pump will flow 15 thousand gallons per minute (kgpm) (900 thousand gallons per hour (kgph)) and each south pump will flow 4 kgpm (240 khph). The fans in bank C1 through C15 will be monitored for operation. If any of the fans are operating in those cells, the circulating water flow will be 39 kgpm (2,340 kgph). Partial hours of operation shall be prorated. Records of circulating water flow shall be maintained for each calendar month. [Rule 62-213.440, F.A.C.; Permit No. 0170004-10-AC] 1.12 Other Reporting Requirements. See Appendix RR, Facility-Wide Reporting Requirements, for additional reporting requirements. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 33 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection J. Common Conditions The specific conditions in this section apply to the following emissions units: EU No. Brief Description 001 Fossil Fuel Steam Generator, Unit 1 002 Fossil Fuel Steam Generator, Unit 2 004 Fossil Fuel Steam Generator, Unit 4 003 Fossil Fuel Steam Generator, Unit 5 {Permitting Notes: The emissions units above are subject to the following condition which allows the burning of on-specification used oil pursuant to the requirements of this permit and this subsection.) J.1. Used Oil. Burning of on-specification used oil is allowed in emissions units 001, 002, 004 and 003 in accordance with all other conditions of this permit and the following conditions:

a. On-specification Used Oil Allowed as Fuel. This permit allows the burning of used oil fuel meeting EPA "on-specification" used oil specifications, with a PCB concentration of less than 50 ppm. Used oil that does not meet the specifications for on-specification used oil shall not be burned at this facility. On-specification used oil shall meet the following specifications: [40 CFR 279, Subpart B.]

(1) Arsenic shall not exceed 5.0 ppm, (2) Cadmium shall not exceed 2.0 ppm, (3) Chromium shall not exceed 10.0 ppm, (4) Lead shall not exceed 100.0 ppm, (5) Total halogens shall not exceed 1000 ppm, (6) Flash point shall not be less than 100 degrees F.

b. Quantity Limited. The maximum quantity of on-specification used oil that may be burned in all four emissions units combined is 10 million gallons in any consecutive 12-month period.
c. Used Oil ContainingPCBs Not Allowed. Used oil containing a PCB concentration of 50 or more ppm shall not be burned at this facility. Used oil shall not be blended to meet this requirement.
d. PCB Concentrationof 2 to less than 50 ppm. On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall be burned only at normal source operating temperatures. On-specification used oil with a PCB concentration of 2 to less than 50 ppm shall not be burned during periods of startup or shutdown.

Before accepting from each marketer the first shipment of on-specification used oil with a PCB concentration of 2 to 49 ppm, the owner or operator shall provide each marketer with a one-time written and signed notice certifying that the owner or operator will burn the used oil in a qualified combustion device and must identify the class of combustion device. The notice must state that EPA or a RCRA-delegated state agency has been given a description of the used oil management activities at the facility and that an industrial boiler or furnace will be used to burn the used oil with a PCB concentration of 2 to 49 ppm. The description of the used oil management activities shall be submitted to the EPA or may be submitted to the Administrator, Hazardous Waste Regulation Section, Florida Department of Environmental Protection, 2600 Blair Stone Road, Tallahassee, FL 32399-2400. A copy of the notice provided to each marketer shall be maintained at the facility. [40 CFR 279.61 and 761.20(e)]

e. CertificationRequired. The owner or operator shall receive from the marketer, for each load of used oil received, a certification that the used oil meets the specifications for on-specification used oil and contains a PCB concentration of less than 50 ppm. This certification shall also describe the basis for the certification, such as analytical results.

Used oil to be burned for energy recovery is presumed to contain quantifiable levels (2 ppm) of PCB unless the marketer obtains analyses (testing) or other information that the used oil fuel does not contain quantifiable levels of PCBs. Note that a claim that used oil does not contain quantifiable levels of PCBs (that is, that the used oil contains less than 2 ppm of PCBs) must be documented by analysis or other Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 34 of 54

SECTION III. EMISSIONS UNITS AND SPECIFIC CONDITIONS. Subsection J. Common Conditions information. The first person making the claim that the used oil does not contain PCBs is responsible for furnishing the documentation. The documentation can be tests, personal or special knowledge of the source and composition of the used oil, or a certification from the person generating the used oil claiming that the used oil contains no detectable PCBs.

f. Testing Required. The owner or operator shall sample and analyze each batch of used oil to be burned for the following parameters:

(1) Arsenic, cadmium, chromium, lead, total halogens, flash point, PCBs*, and specific gravity. (2) Testing (sampling, extraction and analysis) shall be performed using approved methods specified in EPA Publication SW-846 (Test Methods for Evaluating Solid Waste, Physical/Chemical Methods), latest edition.

  • Analysis for PCBs is not required if a claim is made that the used oil does not contain quantifiable levels of PCBs.
g. Record Keeping Required. The owner or operator shall obtain, make, and keep the following records related to the use of used oil in a form suitable for inspection at the facility by the Department: [40 CFR 279.61 and 761.20(e)]

(1) The gallons of on-specification used oil accepted and burned each month in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.) (2)The total gallons of on-specification used oil burned in the preceding consecutive 12-month period in each unit. (This record shall be completed no later than the fifteenth day of the succeeding month.) (3) Results of the analyses required above, including documentation if a claim is made that the used oil does not contain quantifiable levels of PCBs. (4) The source and quantity of each batch of used oil received each month, including the name, address and EPA identification number (if applicable) of all marketers that delivered used oil to the facility, and the quantity delivered. (5) Records of the operating rate of each unit while burning used oil and the dates and time periods each unit burns used oil.

h. Reporting Required The owner or operator shall submit to the Department's Southwest District office, with the Annual Operation Report form, an attachment showing the total amount of on-specification used oil burned during the previous calendar year. The quantity of used oil shall be individually reported and shall not be combined with other fuels.

[Rule 62-213.440, F.A.C.; 40 CFR 279 and 40 CFR 761; and Permit No. 0170004-002-AO] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 35 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Operated by: Florida Power Corporation dba Progress Energy Florida ORIS Code: 0628 The emissions units listed below are regulated under Acid Rain, Phase I. E.U. No. EPA ID# Brief Description 001 1 FFSG, Unit 1. 002 2 FFSG, Unit 2 003 5 FFSG, Unit 5, 004 4 FFSG, Unit 4, A.1. The Phase II Acid Rain Part application submitted for this facility, as approved by the Department, is a part of this permit. The owners and operators of these Phase II acid rain units must comply with the standard requirements and special provisions set forth in the applications listed below:

a. DEP Form No. 62-210.900(1)(a), dated 08/25/09, received 10/08/2009.
b. DEP Form No. 62-210.900(1)(a)1, dated 08/25/09, received 10/08/2009.
c. EPA Form 7610-28 (12-03), dated 08/25/09, received 10/08/2009.

[Chapter 62-213, F.A.C. and Rule 62-214.320, F.A.C.] A.2. Nitrogen oxide (NOx) requirements for each Acid Rain Phase 1I unit are as follows: E.U. ID # EPA ID NOx Limit 001 1 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014. Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 37,112,400 MMBtu. Also, see Additional Requirements a., b. and c., below. 002 2 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014. Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.57 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 42,602,400 MMBtu. Also, see Additional Requirements a., b. and c., below. 003 5 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014. Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 74,334,600 MMBtu. Also, see Additional Requirements a., b. and c., below. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 36 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions E.U. ID # EPA ID NOx Limit 004 4 Pursuant to 40 CFR 76.11, the Florida Department of Environmental Protection approves five (5) NOx emissions averaging plans for this unit. Each plan is effective for one calendar year for the years 2010, 2011, 2012, 2013 and 2014. Under each plan, this unit's NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.59 lb/MMBtu. In addition, this unit shall not have an annual heat input greater than 79,385,400 MMBtu. Also, see Additional Requirements a., b. and c., below. Additional Requirements

a. Under the plan (NOx Phase 1I averaging plan), the actual Btu-weighted annual average NOx emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NOx emission rate for the same units had they each been operated, during the same period of time, in compliance with the applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 76.1 l(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in compliance for that year with its alternative contemporaneous annual emission limitation and annual heat input limit.
b. In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only after the North Carolina Department of Environmental and Natural Resources - Bureau of Air Quality, the Western North Carolina Regional Air Pollution Control Agency, and the South Carolina Department of Health and Environmental Control, have also approved this averaging plan.
c. In addition to the described NOx compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOx compliance plan and requirements covering excess emissions.

A.3. Sulfur dioxide (SO,) Emission Allowances. SO 2 emissions from sources subject to the Federal Acid Rain Program (Title IV) shall not exceed any allowances that the source lawfully holds under the Federal Acid Rain Program. Allowances shall not be used to demonstrate compliance with a non-Title IV applicable requirement of the Act.

a. No permit revision shall be required for increases in emissions that are authorized by allowances acquired pursuant to the Federal Acid Rain Program, provided that such increases do not require a permit revision pursuant to Rule 62-213.400(3), F.A.C.
b. No limit shall be placed on the number of allowances held by the source under the Federal Acid Rain Program.
c. Allowances shall be accounted for under the Federal Acid Rain Program.

[Rule 62-213.440(1)(c)1., 2. & 3., F.A.C.] A.4. Comments, notes, and justifications: None. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 37 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Acid Rain Part Application For more intormation. see instructions and refer to 40 CFR 72.30, 72.31, and 74: and Chapter 02-214, F.A.G. This submission is: 10 New 0 Revised 1A Renewal STEP I Crystal River Fl. 628 Identify the source Plant name State ORIS/Plant Code by plant name, state, and ORIS or plant code. STEP 2 a b c d a Enter the unit ID# for every Acid Rain Unit ID' .50 Opt-In Unit will New or 502 Opt-In New or 302 Opt-tn unit at the Acid Rain Unit? hold Units Units source In column allowances 

       .a.,                                        (Yes or No)     in accordance          Commence                    Monitor with 40 CFR         Operation Date             Certification If unit a SO2 Opt-in                                           72.9(c)(1)                                     Deadline unit, enter "yea" In     I                      No                            N/A                     N/A column "b".                                                       Yes 2                      NO                            N/A                     NIA For new units or                                                  Yes SOz Opt-In units,        4                      No                            N/A                     NIA enter the requested                                               Yes information in           5                      No                            IN/A                    N/A Yes columns "d" and "e."                                                              Yes Yes Yes Yes Yes Yes                                __________

__________ Yes ___________________ _________ ________ Yes _________________ DEP Forn No. 62-210.900Dl )(a) - Form Effective: 3/1/08 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 38 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1) STEP 3 Acid Rain Part Reauirements. (1) The desirgated representative of each Acid Rain source and each AcidRain unit at the source shal"t Read the (i) Submit a complete Acd Rain Part appnclion (including a compliance plan) under 40 CFR Part 72 and RUate02-214.320 and 330. standard F.A.C..Inaccordance with the deadlines specified in Rule 62-214.320, FAC.; and (i) Submi in a timely manner any supplemental information that the DEP determines Is necessary in order to review an Acid Rain Part requirements. application and Issue or deny an AcidRain Part; (2) The owners end operators of each Acid Rain source andeacth Acid Rain unit at the source sthag: (i) Oporate the unit in compr*iancwith a complete Acid Rain Part application or a auperseding Acid Rain Part isaued by the DEP; and (it) Have an Acid Rain Part. Monitoring Requirements. (1) The owners and operators and, to the extent app*cable, designated representative of-h Ac]dRain aource and each Acid Rein unit at the source shall comply with the monitoring requirements as provided in 40 CFR Part 75. andRule 02-214.420, FA.C. (2) The emissions measurements recorded and reportedInaccordance with 40 CFR Part 75 shall be used to deterrntine compliance byithe unit with the Acid Rain emlssions limitations and emissions reduction requirements forsulfur dioxide and nilrogen oxides under the Acid Rain Program. (3) The requirements of 40 CFR Part 75 shall not affect the responsibility of the owners and operators to monitax emissions of other pollJtanits or other emissions characleristcs at the unit under other applicable requirements of the Ad and other provisions ot the operating permit for the source. (4) For applicationa including a SOýOpt-er unit, a monitoring plan tfo each SOZOpt-in unit must be submitted with this application pursuant to40 CFR 74.14(a). For renewal applicetions for SO0 Opt-in units incude arnupdated monitoring plan Ifapplicable under 40 CFR 75.53(b). Sulfur Dioxide Requirements. (1) The owners and operators of each source and each Acid Rain unit at the source shall: (I) Hold allowances. as of the allowance transfer deadline, in the unit's compliance subaccount (after deductions under 40 CFR 73.34(c)). or Inthe compsi subaaccunt uce af another Acid Rain ulit at the are sou-.e i the -stent provided in 40 CFR 73.35(b)3)3.not tess than the total annual emissions of sulfur dioxide ftr the previouscalendar year from the unit; and (ii) Comply with the applcable Acid Rain emissions limilations for sulftr dioxide. (7) Eaci ton of sultur dioxide emned in excess of theAcid Rain emissions timitatlons tfr sulfur dioxide snall constitute a separate violation of theAct. (3) AnAcid Rain cri1 shalt be sece tlothe requirementn under Paragraph (1) ofthe rciaut dioxide requorementsiasfellows: (i) Starting January 1. 2000. an AcidRain unit under 40 CFR 72.6(a}(2); or (i) Starting on the later of January 1, 2000, or the deasine for monitor cedfication under 40 CFR Pan 75, an Acid Rain unit under 40 CFR 72.6(aX2). (4) Altowances shell be held in. deducted from, or transferred amtong Allowance Trcking System accounts in accordance with the Acid Rain Program. (5) An aliowance shau not be deducted in order to comply with the requimrernts under paragraph (1) of the sugtur dioxide requirements prior to the calendar year for which the allowance was altocated. (6) An aliowence ellocated by the Aclsinisthraor under the AdidRain Program is a limited authorization to eint sulfur dioxide in ocoordance with the Acid Rain Program. No provision of the AcidRain Program, ge Acid Rain Part application. the Acid Rain Part or an exemption under 40 CFR 7W7or 72.8 and no provision of law shall be construed to limitthe authority of 01h United States to terninate or limitsuch authorization. (7) An aliowance atlocated by the Administrator under the Acid Rain Program does not constitute a property ight Nitrogen Oxides Reouirelment.* The owners endoperators ot the source and each Add Rain unit at the sotrce shalt comply with the applicable Acid Rain amissions limitation for nitrogen oxides. Excess Emissions Requirements. (t) The deigtated tepresentalive of an Acid Rain writ that has excess emrisons in any calendar year shag submft a proposed offset plan, as required under 40 CFR Pat 77. (2) The owners arndoperators ctan Acid Rain unit that has exciess emissions in any calendar year shalt (I) Pay without demand the penalty required. and pay upon demand the interest on tgat penalty, as rertuired by40 CFR Part 77: and (ii) Comply with the terms of an approved offset plan, as required by 40 CFR Parl 77. Recordkeeoing and Reporting Requirements. (1) Unless otherwise provided, the owners and operators of thi scurce and eaichAcd Rain unit at thesource shallt eep on site at the source each of the following documents fo e period of 5 years fromthe date the document is created. This period may be extended forcause. at any timepior to the end of p years, Inwritig by the EPA or trwDEP: (i} The certificale of representation forthe designated reprensentative for the source and each Add Rain ursl at the source and all documents that demonstrate the truth ofthe stetements in the certificate of representatior.In accordance with Rule 62-214.350. F.A.C.: Provided that the certificate and documents shetl be retained on site at the sourcebeyond such 5-year period until such documents are superseded because of the submiltsion ofa new ceritficate ofrepresentation changing the designated representative; (1) All enissions monitoring information, in acc*rdance with 40 CFR Part 75, provided that to the "rent thait40 CFR Pait 75 provides fr a 3-year period for recordheoping. the 3-year period shall apply;, (Si)Copies of allreports, conmpliance certifcationes. and other sutsmissionis and all records made or required under the Acid Rain Program; and. DEP Form No. 62-210.900(1Xa)- Form Effective: 3/161/08 2 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 39 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1) STEP 3, Recordkeepina and Reporting Requirements (contj Conitnued. (iv) Copies of alt documents used to complete an Acid Rain Part application and any other submnissln under the Acid Rain Program or to Oemonstrate omplirace with therequirements of Me Acid Rain Program. (2) The deslgnated representative of an Acid Rain source and each Acid Rain unit at the source shait submit the reports and compiance certillcatiorna required under the Acid Rain Program, inrluding those under 40 CFR Part 72, Subpart I, and 40 CFR Part 75. Liability. (1) Any person wntoknoweigly violates any requirement or Orothition of the Acid Rain"Prooram. a complete Acid Rain Part appication. an Acid Rain Part. or an exemption under 40 CFR 72. or 72.8, including any requirement for the payment of any penalty owed to the Uniled States, shall be subjectto enforcement pursuant to section 113(c) of theAct. (2) Any person who knowingly makes a talse. material statement in artyrecord, subrmdnslvn, orreport under the Acid Rain Program shall be subjet to criminal enforcement purthirruttO section `113(c0) of the Act and18 U.S.C. 1001. (3) No oemnit revision shal easuse any violation of the requirements of the Acid Rain Program that occurs prior to the date that the revision takes effact. (4) Each Acid Rain source and each Acid Rain unit shall meet the requirements of the Acid Rain Program. (5) Any provisionrof the AcidRain Program that applies to an Acid Rain sJurce (inokdtna a provlslon appliahiloa to the designated representative of an Add Rain source) shall also apply to the owners and operators of such source andof the Acid Rain units at the source. (6) Any provision of the AcidRain Program that applies to an Acid Rain unit (including a provision epplicable to tre designated representative of an Acid Rain unit) shat also apply to the owners and operators of such urit. Except as provided under 40 CFR 72.44 (Phase I repowering extension plans) and 40 CFR 76.11 (NOx averaging plans), and except with regard to the requirements applicabte to units with a common stack under 40 CFR Part 75 (including 40 CFR 75.16, 75.17, and 75.18), the owners and operators exn the designated reproeuntative of one AiddRain unit shah not be liable for any violation by any other Acid Rain unit o( which they are not owners or operators or the designaled representative and that is located at a source ofwhich they are not owners or operators or the designated representative. (7) Each violatlo of a provision of 40 CFR Podrs72.73, 74, 75,76. 77. and 78 by an Acd Rain source or Acid Rain unit. or by an owner or operator or designated representative of such source or unit shell be a separate violation of the Act. Effect on Other Authorities. No provision of the AcidRain Program, an Acti Rain Part application. an Acid Rain Part, or an exemption under 40 CFR 72.7or 72.8 shall be constnred as: (1) Except as epmesry provided in ttle IV of"lheAct. exampling or ex'ring the sownerend operaton; and, to the extent applicabl. the designated representative of an Acid Rain source or Acid Rain unit from conrliance with any other provision of the Act, including the provisions of dine Iof the Act relating to app*ceble Nations] Ambient AirQuality Standards or State Implemrentalion Plans; (2) Uriting the number of allowances a urit can hold; provided, that the number of allowances held by the urit shal not aftect the sources obligation to comply with any other provisions of the Act; (3) Requiring a change of any kind In any state law regulating electric utilityrates and charges, affecting any state towregarding such state regulation.or limiting such stlte reguteiton, inrcudieg any prudence review requirements urnder such slate law; (4) Modifying the Federal Power Act or affecting the aut0ority of the Federal Energy Regulatory Commission under the Federal Power Act; or. (5) Interfering with or Irnpaldrsg any program torcompetitive bidding for power supply In a stale In whicf such program in eslablilsted. STEP 4 For SOz Opt-in f g h (not required for units only. renewal application) In column -'" enter Number of hours unit the unit IDa for operated In the six every SO0 Opt-In Unit ID# Description of the combustion unit months preceding initial unit Identified In applicatior columul "a" of STEP 2. For column "g" describe the combustion unit and attach Information and diagrams on the combustion unit's configuration. In column "h" enter the hours. DEP Form No. 62-210.900( )(a)- Form Effective: 3116/08 3 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 40 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Crystal River Plant Name (from STEP 1i STEP 5 j k I m n For SO Opt-In units only. Voo required for Current Current -- 10ptin renewall Actual SO0 Allowable 1985 Allowable SO, Promulgated applications.) Baseline or Alternative Emissions Rate SO2 Emissions Emissions Rate SO 2 Emissions. Unit ID# Baseline under under Rate under under Rate under In column "i" enter 40 CFR 74.20 40 CFR 74.22 40 CFR 74.23 40 CFR 74.24 40 CFR 74.25 the unit ID# for (mmBtu) (Ibs/mmBtu) (Ibs/mmBtlu) (lbslmmfBtu) (lba/mmBtu) every SO 2 Opt-in unit Identified In column "a" (and In column. "f"). 2 For columns "j" 4 through "n," enter the information 5 required under 40 CFR 74.20-74-25 and attach all supporting documentation required by 40 CFR 74.20-74.25. STEP 6 A. It the combustion source seeks to qualify for a transfer of allowances from the replacement of thermal energy, a thermal energy plan as provided in 40 CFR 74.47 for combustion sources must be attached. B. A statement whether the combustion unit was previouzly an affected unit under 40 CFR 74. For SO 2 Opt-n C. A statement that the combustion unit is not an affected unit under 40 CFR 72.6 and does not have an units only. exemption under 40 CFR 72.7, 72.8, or 72.14. D. Attach a complete compliance plan for SO0 under 40CFR 72.40. Attach additional E. The designated representative of the combustion unit shall submit a monitoring plan in accordance with 40 requirements, CFR 74.61. For renewal application, submit an updated monitoring plan if applicable under 40 CFR 75.53(b). certify and sign. F. The following statement must be signed by the designated representative or altemate designated representative of the combustion source: 'I certify that the data submitted under 40 CFR Part 74, Subpart C, reflects actual operations of the combustion source and has not been adjusted In any way." Signature I Date STEP 7 Certification (for designated representative or alternate designated representative only) Iam authorized tomake this sub*nssion on behan of tie owners and operators of the Add Rain source or Acid Rain units or which the rubmnission Read the Is made. Icertify under penalty OtIaw Sat I have personallyeaMined, and am faretiar wia, the statements end Intmation submitted in this certification document and en itSasachmenta. eased ornmy inquiry os Item individuals with primaryrespnalit~ity for obaining thu ifonknaon. Icrtify that the statement; provide statements and informatlon are to the best of my knowledge and belieftrue. accurate, and complete. I am aware that thereare significant penalties name, title, owner for subititting false statements and Infonrmaton or omitting mqubied statemerts and information, including the possbility of fine or imprisonment. company name, phone, and e-mall address; sign, and date. Name Brenda E. Brickhouse I Title Director - Environmental Health and Safety Owner Company Name Florida Power Corporation dba Progress Energy Florida, Inc. Phone 727 820 5153 IE-mail address Brenda.brickhousetOpnmail.com Signature .Date*A /---2C DEP Form No. 62-210.900(1)(a)- Form Effective: 3/16108 4, Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 41 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions United States Environmental Protection Agency OMB No. 2060-0258 Acid Rain Program Phase I! NOx Compliance Plan For more information, see instructions and refer to 40 CFR 76.11 NO. Compliance - Page 1 This submission Is: [] New [E] Revised Page [] of STEP 1 Indicate plant name, State, Crystal River F1 628 and ORIS code from NADB. if applicable Plant Name State ORIS Code STEP 2 Identify each affected Group I and Group 2 boiler using the boiler to# from NADB,If applicable, Indicate bolter type: "CiB" for cell burner. "C" forwcyclone. "0DW" for dry bottom wall-fired, "r, for tangentially fired. "V"for vertically fired, 

                                           =d-"W- for w"t bottom. Ind*sate the com lien. ution selected for .o-h unit.

I yp/ TyeT ITpeDW I /Typ DBW Typ Type__ El~ (a) Standard annual average emission Imitallon of 0.50 LI[][ W][][ IflhmBtu (for Phae I dry bottom wall-firod boilars) (b) Standard annual average emission lImitation ot o.45 tbImmetu (for PhAse(j tangentially F- LI. fired boilersl (c) EPA-approved early eletion plan under 40 CFR 7 A through 12,31107 (also Indicate above D- Ml F-1 emission limit specified In plan) d) Standard annual average emission limI.ttton of1.40 LI lbmmBtu (Ifor Phasg dry bottom wall-fired bolters) (a) Standard annual average emission limitation of 0G4 IIbmmatu Ifor Pelit tangentially LI E-1 fired boilers) 1I)Standard annual average emission Ihbtation of 0.88 tbimrnmtu (Forcell burner boIlers) LI (g) Standard annual average emission limitation of 0.86 lblmmBtu (for cyclone boilers) LI LI MI (h) Standard annual average emission limitation of 0.81 EI LI Ib/mmBtul(for vertically fired boilers) (I) Standard annual average emission limitation of 0.84 El LI Ib/mmntu (for wet bottom boilers) (J)NO. Averaging Plan (include NO% Averaging form) (k) Common stack pursuant to 40 CFR 75.17(a)(2X1)(A) (check the standard emission C1 LI limitation box above for most stringent lImitation appIlcable to any unit utilizing stack) (I) Common stack pursuant to 40 CFR 76.17(a)(2)(i)(B) with NO. AversgLng (check the NO. LI Averaging Plan box and include NO, Averaging form) EPA Form 7610-28 (12-03) Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 42 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions NO, Compliance - Page 2 Crystal River Page n2 of R2 Plant Name (from step "11 STEP 2, cont'd lD# IEl m) EPA-approved common stack apportionment me(hod pursuant to 40 CFR 7&.17 (t)()pIIXC), (a)(2X111t)(1) or (b)(2) (n) AFL include Phase ItAEL Demonstrallon Period. Final AEL F7 Ei Li1 MI Petilton. or AEL Renewal ferm as approprlats) (o) Petition for AEL demonstrlaton period or final AEL under revieowby U.S. EPA ar Li demonstration perlod ongoing (p) Repowering extension plan Li El Li Li approved or under review STEP 3 Standard Requirements Read the standard requirements and Genera. This source is subject to the standard requirements in 40 CFR 72.9 (consistent with 40 CFR 76.8(e)(1)(i)). certificatton, enter the These requirements are listed in this source's Acid Rain Permit. name of the designated representative, sign & date. Special Provisions for Early Election Units Nitrooen Oxides. A unit that Is governed by an approved early election plan shall be subject to an emissions limItation for NO. as provided under 40 CFR 76.8(a)(2) except as provided under 40 CFR T6.8(e)(lil). Liabili . The owners and operators of a unit governed by an approved early election plan shall be liable for any violation of the plan or 40 CFR 76.8 at that unit. The owners and operators shall be liable, beginning January 1, 2000, for fulfilling the obligations specified in 40 CFR Part 77. Teirnination. An approved ealdy election plan shall be In effect only until the earlier of January 1, 2008 of January A of the calendar year for which a termination of the plan takes effect. If the designated representative of the unit under an approved early election plan fails to dernonsitrte complianic with the applicable emissions limitation under 40 CFR 76.5 for any year during the period beginning January 1 of the first year the early election takes effect and ending December 31. 2007. the permitting authority will terminate the plan. The termination will take effect beginning January I of the year after the year for which there is a failure to demonstrate compliance, and the designated representative may not submit a new early election plan. The designated representative of the unit under an approved early election plan may terminate the plan any year prior to 2008 but may not submit a new early election plan. In order Io terminate the plan, the designated representative must submit a notice under 40 CFR 72.40(d) by January 1 of the year for which the termination is to take affect, If an early election plan is terminated any year prior to 2000, the unit shall meet, beginning January 1. 2000, the applicable emissions limitation for NO, for Phase II units with Group I boilers under 40 CFR 76.7, If an early election plan Is terminaled on or after 2000, the unit shall meet, beginning on the effective dale of the termination, the applicable emissions limitation for NO, for Phase II units with Group 1 boilers under 40 CFR 76.7. CerMfIcation I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission Is made. I certify under penalty of law that I have personally examined, and am familiar with, the statements and information submitted in this document and all Its attachments. Based on my Inquiry of those Individuals with primary responsibility for obtaining the Information. I certify that the statements and information are to the best of my knowledge and belief true, accurate. and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and Information. including the possibility of fine or Imprisonment. EPA Form 7610-28 (12-03) Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 43 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Florida Department of Environmental Protection Phase II NOx Averaging Plan For more Information, refer to 40 CFR 76.11 This submission is: Ii New x Revised (a) (b) (ci STEP 1 Plant Name Ait. Contemp. Identity the units participating in this averaging plan by Emission Emission Annual Heat Input plant name, state, State ID# Limitation Limitation Limit Asheville N,4 6 U.53 1I0,i, , ( and boiler ID# from MADS. In column (a), fill in each units Asheville NL; z 0.4b I.bzt51j U.10 applicable emission limitation from 40 CFR 76.5, 76.6, or 76.7. In column (b), assign an 6,185,400 altemative contemporaneous Cape I-ear NU b U.40 6.1U5,4 annual emissions limitation In lb/mmBtu 7,612,800 to each unit. In column H. I-. Lee (c), assign an annual -T- -U7 U.60U, tou78,U9 eat input limitaUon In mmBtu to each unit H. F. Lee NU; - OU.45 U0 5,4J epU Continua to page 3 if necessary. H. F. Lee rNU 3 U U.7/ 1J.411 .=U Btu-welghted annual emission rate Btu-weighted annual average STEP 2 averaged over the units if they are emission rate for same units Use the formula to enter the operated In accordance with the operated in compliance with 40 Btu.weighted annual proposed averaging plan CFR 76.5, 76.6 or 76.7 emission rate averaged over the units If they are operated in accordance with the proposed averaging plan and the Btu-weighted annual average emission rate 0.44 0.44 for the same units If they are operated in compliance with 40 CFR 76.5, 76.6, or 76.7. The former must. be less thanor equal to the latter. < [R[R, xHI,] ynj=l Hji er, =, Hx Where, Ru Alternative contemporaneous annual emissions limitation for unit i. in 16lmmBtu, as specified in column (b) of Step 1; RHI Applicable emission limitation for unit I, in Ib/mmBtu, as specified In column (a) of Step 1: HIj Annual heat input for unit i, in mmBtu, as specified in column (c) of Step 1; Number of units In the averaging plan DEP F'orrn No. 62-210.900(i)(a)1. Effective: 31-16010 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 44 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Crystal River Power Plant Piant Name (from Step 1) 1 0 X This plan is effective for calendar year 2010 through calendar year STEP 3 2014 unless notification to terminate the plan is given. Mark one of the two options Q Treat this plan as 0) identical planseach effective for one calendar year for the following and enter dates. calendar years: .. .. .. . and __ unless notification to terminate one or more of these plans is given. STEP 4 Special Provisions Read the special Emission Limitations provisions and certification, enter the name of the Each affected unit in an approved averag in plan. is in compliance with the Acid Rain emission designated representative. and limitation for NO, under the plan only if the following requirements are met: sign and date. For each unit, the unit's actual -annualaverage emission rate for the calendar year, in rnmBtu is less than or equal to its alternative contemporaneous annual emission limitation in the averaging plan, and (a) For each unit with an alternative contemporaneous emission limitation less stringent than the applicable emission limitation in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year does not exceed the annual heat Input (b) limit For each in the aveunigtwt plan, in an eitemailve contemporaneous emission limitation more stringent than the applicable emission limittion in 40 CFR 76.5, 76.6, or 76.7, the actual annual heat input for the calendar year is not less than the annual heat input limit If one averaging (ii) in mte or more of°the plan,units or does not meet the requirements of (i), the designated representative that shall demonstrate, the actual Btu-weighted annualin average accordance with 40 emission CFR rate for 76.11(d)(1 the units in)(ii)(A) andis(B) the plen oless than or equal 1o the Btu-weighted annual average rate for the same units had they each been operated, duri ng the same period of timein compliance with the applicable emission limitations in 40l CFR 75.5, 75.5, or 76.7. (iii) If there is a successful grou'p showing of compliance under 40 CFR 76,11(d)(1)(ii)(A) and (B) for a calendar year then all unitesn the averaging plan shall be deemed to be in compliance for thai year with their alternative contemporaneous emission limitations and annual heat Input limits under (i). The owners and operators of a unit governed by an approved averaging plan shall be liable for any violation of the plan or this section at that unit or any other unit in the plan, including liability forfulfilling the obligations specified in part 77 of this chapter and sections 113 and 41 -of the Act. Termination The designated representative may submit a notification to terminate an approved averaging plan, in accordance with 40 CFR 72.40(d). no later than October I of the calendar year for which the plan is to be terminated. Certification I am authorized to make this submission on behalf of the owners and operators of the affected source or affected units for which the submission is ma de. I certify under penalty of law that F have personally examined and am familiar with, the statements and information submitted in this document and all Its altachments. Based on my Inquiry of those individuals with primary responsibility for obtaining the information, I certify that the statements and Information are to the best of mf knowledge and belief true, accurate, and complete. I am aware that there are significant penalties for submitting false statements and information or omitting required statements and information, including the possibility oftfine or imprisonment. Name Brenda E. Brickhouse Signature f--' f -, -Date . g,5 ]c.. DEP Form No. 62-210.900(1Xa)i. Effective: 3161/08 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 45 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions Crystal River Power Plant Plant Name (from Step 1) (a) (b) (c) STEP 1 Alt. Continue the Contemp. Identlflcation of Eislsion Emission Annual Heat Input units from Stop 1, Plant Name State ID# Umitation Limitation Limit page 1, here. Mayo NC IA 0.46 0.15 16,685,025 Mayo NC IB 0.46 0.1.5 16,685,025 H.B. Robinson SC 1 0.40 0.525 12,879,540 Roxboro NC 1 0.46 0.145 16,254,975 Roxboro NC .2 0.40 0.145 32,789,S49 Roxboro NC 3A 0.46 0.235 17,651,860 Roxboro NC 3B 0.46 0.235 17,651,860 Roxboro NC 4A 0.46 0.225 17,928,281 Roxboro NC 4B 0.46 0.225 17,928,281 L.V. Sutton NC 1 0.40 0.605 6,536,531 L.V. Sutton NC 2 0.46 0.605 6,725,250 L.V. Sutton NC 3 0.46 0.50 28,232,325 Weatherspoon NC 1 0.46 1.00 3,746,925 Weatherspoon. NC 2 0.46 1.00 3,798,165 Weatherspoon NC 3 0.40 0.65 6,141,480 Crystal River FL 1 0.40 0.57 37,112,400 Crystal River FL 2 0.40 0.57 42,602,400 Crystal River FL 4 0.46 0.59 79,385,400 Crystal River FL 5 0.46 0.59 74,334,600 DEP Form No. 62-210.900(i)(a)1. Effective: 3/16/08 3 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 46 of 54

SECTION IV. ACID RAIN PART. Federal Acid Rain Provisions rysta v-er Power Ilant Plant Name (from Step 1) STEP I (a) (b) (c) All. Continue the Contemp. Annual Heat Input Identification of Emission Emission Limit units from Stop 1, Plant Name State ID# Limitation Limitation page 1, here. 4 .4- 4 .4. 4 .4- 4 + I 4- + DEP Foffn Na. 62-210.900(l)(a)l. Effective: 3/16108 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 47 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions Operated by: Florida Power Corporation dba Progress Energy Florida Plant: Crystal River Power Plant ORIS Code: 628 The emissions units below are regulated under the Clean Air Interstate Rule. EU No. EPA Unit ID# Brief Description 001 1 Fossil Fuel Steam Generator (FFSG) Unit 1 002 2 FFSG Unit 2 003 5 FFSG Unit 3 004 4 FFSG Unit 4

1. Clean Air Interstate Rule Application. The Clean Air Interstate Rule Part Form submitted for this facility is a part of this permit. The owners and operators of these CAIR units as identified in this form must comply with the standard requirements and special provisions set forth in the CAIR Part Form (DEP Form No. 62-210.900(1)(b)) dated March 16, 2008, which is attached at the end of this section. [Chapter 62-213, F.A.C.

and Rule 62-210.200, F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 48 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions

  • Clean Air Interstate Rule (CAIR) Part For more Infonrnaton. see n0tNuSc&ons and refer l 40 CFR 96.121,98.122,96.221, 96.222, 96.321 and 96.322; and Rule 62-296.470, F.A.C.

This vuxisaloon is: 03 New fffRviaed 13"Renewal STEP 1 Plant Name: CRYSTAL RIVER POWER PLANT State: Florid ORIS or EtA Plant Code Ideiffy the source by -2 plant name and ORI8 or EIA plant code STEP 2 a b c d e f Unit Will Unit will Unit will In column "a" enter the hold nitWgen hold sulfur hold NOx Ozone New Units New Units unit I10 for every CAIR adds (NOx) dioxide (SO2) Season aalwlowe aewances afwinoes Expected F unit at the CAIR source. In accordance In accordance In aordance Commence Monitor with 40 CFR wtih 40 CFR with 40 CFR Comnunen*al Ceruication In columns "b," "c," Unit ID# 96.106(c1) g96.206(cXl) 96.306(cXl) Operation Daft Oeadline and "d," Indicate to x x which CAIR program(s) I or E.U.-01 x each unit Is subject by 2 or E.U.-002 placing an "X" in the column(s). 5 or E.U.-003 X X X

  • For new units, enter the 4 or E.U.-004 requested informntlon in columns "e" and "f.

0 DEP Form No. 62-210.900(i)(b) - Formi m Effectve: 3/16M8 I Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 49 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions 0 CRYSTAL RIVER POWER PLANT I plaruNormn (USTEP1) STEP 3 CAIR NOx ANNUAL TRADING PROGRAM Rad ihe stwx d CAmR Padt Reaimmmt. requirements. (1) Thi CAIR dod represnlebe of each CAIR NORscums sld each CAIR NOx rai at ft aawrn sl W)Subn* hI M OEPsa and celied CAIR Part form under 40 CFR 96.122 and Rule 62-296.470. FAC., in pnlelte ith Om dede specidied in Rue 62-213.42D, FAC.; and (2) The oners and operaln' t eich CAIR NO. souc and auch CAIR NO. unt am the scure9Who aCAR Part d Mu Te V qaIhqpg p*eni issued by #* DEP uwder 40 CFR Padl 96. SiupM CC, and opena M souc and the un i i wth such CAIR Monitonf . Recorft . and Reoordkeeolna Reautmnienta. (1) The owners midoperatml. end Mt CAIR des- nale repesernll of each CAIR NO sucue aind each CAIR NOr at ft auew diai Coon lsyw modnaitlrg. repornMiand -ec*-eeplgrequumnt of 40 CFR Pat 906. Subpat Ward Rule 02.29.470. F.AC. (2)The ensmsoms n uasmmrnns recorded and repored Inaccordance wh 40 CFR Po 96, Subpa*tH.HK ld be used to delemee oenimi- by ch CAR NOx nul- *ithte I CAR NOx rnsn RPettnen. N*x Emisslon Reaukements. (1) As of ft -Innce rimu er deene tra condol peeod, the ownam and *atm a edi CARNO mideaAAIRN ORW at Mtsuscwedaldhold infu acuree ceplanoacousnut,CAIR NO4 dloomies avelable fo cnnyence dedualona fortMu hioperlod uider 40CM 95.154(a) h nanewait fbIlsdunmuhinaihibNORiamwslor'Mu nib pearldfrornalCAJR NORmlatatfteu506w. dean6ld I accordance wmi40 CFR Pall o. S n HK

2) ACAIR NOx wrllid beoeathd theMumquksmsnl tide.psz-waph d (I) toh NO%Requiremens atnn fMber of Jumy 1.20M.

or f d 1ehifor enesof Muftsniesmnilot ,rtd1a8- requiremif uider 40 CFA 96.170(bX1) or (2) and foreach - - , pertod asftim . (3) A CAIR NOA m*ance slidl not be deduded. bo mIpIlm i Mufrequu*eieuts under par-a ;ph(1) d tie NORRAqunmitw, fo a 

                              ..i . parid ia imii yest eorihe          ndwe     bwhich i CAIR NO xab           i     ie ioccale (4) CAIR NOx adlman            OWil be heldin.deduCld from. or tranele      io or Mmaoi CAIR NO Aowaim Ttadh                ymm         t hi acrdance vmh 40 CFR Pt 96. Subart FF and GG (5) A CAIR NOAdoeaicelis aUnied *Aiortioion to ant one ton aoNO in aci a ne with ftMu               CAIR NOx Arniui Trafi Ptuin. No proaleo*nl haM      CAR NORAnnual Traing Progamn,Mu CAIR P*, oran *mopkn ide 40 CR95.10w mnopo a                                  law
  • be
                                 *uead to Ibat Mu *ii*lty of MfuOf or VMu        UnbEd Steels io amni* or birt sch sulhoezllon (6) A CAIR NO allomance does no corslbde a propety ofth (7) Upon rcordati*n byfte Adrntabo under 40 CFR P*t 95, Subpart EE. FF. r GGO,                u ams    acaon, b      lsr.. or dedtcdo of aCAR NOx cna       hioor frtm aCAIR NORunt's compliance accnt Is'               aulhd Ficorp     matonoy Inany CAIR Pamt    of OMu  same. Sel hdde Me CAIR NORmEt E e          Emissions ReoieMenIs.

I a CAR NOR so-ce ernis NOx uding any oonh parod in m olto CAu R NOh. b l (1) The Oreers and operaor, ao fMurce and easch CAJR NORunita Muf sme s*ld aunmrdered. CAIR NOR 4 slowanboss rufo f dedubion unde 40 CFR 96.154(d(1) and pay any fne. penay, ora nmmaor md any u r a. b sam videllona, under It Clean AirAct or appktafrle sate low. and M2Each lon of such excess aridsalon arid each day of such car" period dial consitulsa separate violation of 40 CFR Pert 96.Subpart AA ft Clean Air Act. sand OPicste SIRe 10W.. Be n and Reoftnm Reirements. (1) Unless otuwise provided. Mheowwrs and operatorsdofe CAR NORscums and each CAR NO. unk at El scum slMWkeep on sOtea Mhesuroe eacho. eiM Ioung doceunla brorapwaod of S)*mmtornMt d Mu docum l os crauld. Trl pearod may be foed r causm,*a anne beore Mu f ed c 5 m n, ,melng IbyMu DEP o*rf AdMtn .

0) The, -erh1wofapreawwJ unide40 CAR 96.113 f UwCAIR daeignso represenwive r ft scums end each CAR NORuit at ft source aid all donmincels at dnnsab Mu
                                                                            "'utdV       ofto I -m-dshinu    One,10,1c alrepeuentaticnprode o                Wv           atMu csth
                                                                                                                                                               , e 11ad  s mi doceaunle slibe                   n siebaltie soure. beyoid such Syserpemod till such dooorenhi ar superseded bernie is Muettinbaesion of
                                                             'abhe a new ,e1c         a11 epeof 1        under 40 CFR 96 113 dhhngi Mu CAIR deielnabd teprosenbtdWo Ol) AM m          a notog It nemti, in raccodance w1i40 CFR Pawt99, Sutpml H.K afkpMtpu.              prodded          hM e            ! 40* R Per 06Suapet  14,prvide. forea 3-V-rperiod fo socriueephirg Mu3-yw-perldhelWly.

(11)Copies ofall reports. ooniqtabn-ce welldreidubsaoeend 

                                                                                             ~sulier   s          al              or required uider die CAIR NOR meodsnde                                Annua Treft Proponi v) Copis at1 dolacnte uaednlieo nlot e CAIR Pm iorm and any olier mlesibsio underie CAIR NO, Annual Trafi Provanonto dmondie    -, -           nce wl M rw  eem nw atCAIR e           NOx Ania Trsin ProemL (2) The CAIR dasignaod represento's. of a CAR NOx soure. nd each CAIR NO. atrat Mu w-. sclu subtn* f %                                   under Mu CAR NO
  • Trang Prog.
                                                  *ual                *r*d*emee w der4o CFR Pt 6 SeAd9           p H DEP Form No. 02-210.900(1 Xb) - Form Eflac*v: 311600                                                                     2 Progress Energy Florida, Inc.                                                                                                          Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                  Title V Air Operation Permit Renewal Page 50 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions 10 CRYSTAL RIVER POWER PLANT Plant Momni Mfom STEP 1) STEP 3. ConUnued UaI. (1) EuIi CAR NOx Wju=e and each CAIR NOx unit sha meet t dime CAIR NO8 Annual Troun Piopam of thqulnm'ml (2) Any provion o Ie CAIR NOx Annual Tradn Piroganiemt i0 a CAIR NOx a xmie*we CAIR de* *rapreartn feCa CR NO, soucea*l alo appylaf towns and operas o such source ad ofi CAR NOA al *te ourc. (3) Any provision o it CAR NO, Annarl Tr*dino Phroarn Pu appies toa CAR NOHwx w or to CAR 

                                                                                                                                     *e                  prsenmive da CAIR NOx urt &Waboapply to the owners ard opera; s of such uit.

Efctd on O00e Authodfies No prvision ofdie CAR NO, Annual Tradng Progrm a CAR P*t oran empdon wider 40 CFR .O1 " beoh o daa me or eaarogudt fhsowne and opemrto and ie CAIR designated presamadve, of a CAIR NO, swim or CAR NOx unit frm compliance vantarmy om Is u apcl d Stlae Ilnmrton Pan. a lederally mnforable permi or do Ciem AIr Ac. CAIR SO TRADING PROGRAM CNR Part Roursments. (1) The CAIR desiged reprevendsae of each CAIR S(h aource and each CAIR S01 unit atth source sIi:

0) Subnt bI DOEP a npleme aindc'lled CAJR Part forn under 40 CFR 96.222 and Rule 82-M.4 dumIll specillied InRule 62-213.4M0. FAC.: arid FAC.. Ina c mP (i) *tnrvedm; (2) Th owners ad operatoe d eac CNR SO* soume and each CAR SO unat the so se al a CAIR P**d in*t Me V operalng permt Ismed by fthDEP under 40 CFR Part 96. Subp*rt CCC. for t soue and operat so ad each CAR rad In I'- idilli si CAR Pat Monftorimn. Reoortino. and Recordkeedona ReaWrements.

(1) Rhe oners ard operatorl, and Pue CAIR designled repreeenalve, of each CAIR S0 souce and each SOh CAIR unit at me aource 09 wmplyiti Punh*r*torg, reporft. and racordkeepift reqirements of 40 CFR Part 0,Subpart HH. and Rule 62-298.470. FAC. (2) The emIsna meneement recorded and up otdi naccordance whlh 40 CFR Part 96. Subpart IFl sll be ued to deernui* corpllaice by each CAIR SO8 source withmhe oUowfg CAR SOQ Ensalon Raqukernents. SO, Emission Reoutrements. (1) Asmo faoac IInsfadealcbra conrmpei me iowsm and operators d each CAR SO2 *,nit source arid each CAR SO at fe source shel hoK, In ft sourcesacoplierc accunt a orage equivalar inCAIR SO, alowanns available for compliance deductiona fr feort period, as delswiftm Inacoordance with 40 CFR 96.254(s) arid ft notraless Pun ft tonaodi latl slA~r dbodde ermissions for ft ceni period kom al CAIR SO3,units at Pu souce. asdl* ned In cI ii 40 CFA Part 96. *5Subpm tH. (2) ACAR SOh shall be lorbjtlame muremepntw underpa*raaph (1) ime Suiw Diode Emilon Reirementerits gon ft low of Jsriwhy 1.2010 or to d1edl1ne for meetig t units-morito cartiication requirements under 40 CFR 96.270(bX) or (2) a-rid1 each control (3) ACAURSO, alowainc shal not bededticted. fot r-gilance 

                                                                                               ",ii       Pu requirenmes under peragraph (1) Pu   t SO, Emilalort Raquirkennts.

frma crn period ins dasride year be* ahePuw otr m ti CPRu R SO, allowance vas allocaled. (4) CAR SOa -oI lbe hld i*. dad- fon, ort ambard intoMoreamo CAJR SO, AMmnc Tracug System acon In accordance an i 40 CFR Per 96. &ulertFFF aid GGG. (5) ACAIR S i,lowerie Isa lnmied aulhi0taiontlo enit auifudorcke h accodance wilhf CAR SOz TradT ProWgram o provision dito CAIR SOl Tradng PRogram, Ph CAIR Part, or an arranllon under 40 CFR 96.205 arnd no provision odtow WW be conatrued to nt Pu sihafaty of fit stm or lie ULnitd Stewa to minat or biit msch aufulzatlon. (6) ACAIR SO, dowanice does nol omoatble aproperty rghlt (7) Upon recmrdude by fte Adni*ihtiu under 40 CFR Pnt 95. Subpart FFF or GGG. every a .nvansl. or deUcondo a CAR SO, d~nm m Irotn* a CAIR SOa utilte compitonce acoumt inororated r autor cally hisny CAIR Part d th souce Oa incldo to CAIR SO, uit ExOes EmLssions Pmreowmns. eraCAR SOsource anftS$08 durNWin nycni period inaon iuCA O rimos iito.Prc (1) TIhowners and operators ofme som ard each CAJR SO, unit at tm source shml smursnde the CAR SO, allowances reqired fo dedction under 40 CFR 9N.254(dXt) and pey any In. penmlty, or asseamaent or comply with any othe remedy imposed. for the sne v~idaiona. underme Cleanr Air Act orapplicable sumlatow. arid (2) Each ton d such excess amnis asrd each day of such oontbol period miW ronsimemapvriolation 0140 CPaPr, Subpart AAA PueClem Air Act and applicable sae loa. DEP Form No. 82-210.900(l Xb) - FormI Efectve: 3/168 3 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 51 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions CRYSTAL RIVER POWER PLANT 6 Plat Mem (Im STEP 1 STEP 3. DM&NUMMEN WND MNL Mmn M Uw!IMLS CoQltnuWo (1) unte* oIeIe proviOdd, do mmeI aid opoalr of ft CAR SO, s arcmedeich CAM SO, uni at dwo aumc aW keepoof at0**w umsme catholiOokeing domaneiu *ra perodd of S.mu from w dale th docment IS ThN* rodaybe fdrcaudse. at any tirm bter 1 ie and @15yens Inwili by Depm; 'or li Adinistror. M) The cmowte of u under 40 CFR 213 0r le CAR dWsnlted spsetied fr iourmed esch CAIR SOrumta soi- mid edonw0um ldo li Wilto ti e-ea 

                                                                                   -, the                           IIn ft       10 1e of , p -- - -, piraMdsid              1* x111, a id doaainift doll be oned on sift at lio sums beyon Such 51morperiod utwil ach doagfrismweu* Sperseded becauseof 1w Submission of a Noe 't11 osr,'ea      f              -, under 40 CFR 98.213 dwn               lie CAR desigled                           .epresmielue.

(i) ANl e msing ineielni hin amrmie wbio40 CytR Pe 6 OSubpa*-t b 1.0.. tte pofiitw pL Med dlisot i t -W40 CFA Pet W, Subpart HH1. providee foa 3" w period for recordleeping. tor3-jr perad ll aply. (i) Capin of at repote compiance oml~waonl andaha eujrrdsiar. andaN r mde bouda o requied unde the CJR S0 T P age-Ov) Copieo as docmime umed to amCAJR Pint tern and ohler subiseso under ihoCAR SOQ,Treeing pgMmig or to dm11nem m maom i 1wh mruqusamimf de CAR SO, Trading Prioui. (2) 11T CAIR deosigated .uprmiecim s, a CAIR SO, scums and each CAIR SO undi at to scums shag eubrd lie roem II 'udder th CAIR SO, Traing Prowas indig oe under40 CFR Pet 96. Subpart HHH. (1) Each CAIR SO, ecu mid each CAR SO nditsdil meot On requimeoits e @ft CAIR SO, Trdlng Pragmo. M2)Any rouslmOn 1wCAR ho SO, TredMg Prrm h plagmetoa CAR SO, emc nr th1 CAIR dedIV -agmemane d a CAIR SO, ecum eoll soo apply mh; g otnn and operator@ o muc earch m d od@oCAR SO, units ot eums S (3) Any praomi of fth CAR SO0 TrtiMg Pro e aVolin to a CAIR SO unit or e CAIR desad repeeerallm ofa CAIR SO, uit etl ioap aply te ie ame aid aper, olo hdi udl Effect on Ofher Authorfte. No prowslon of 1o CANR O, Trading Progam. a CAMRPart, or annenplia under 40 CFR 91.05 shag be awabud a rn or excludig lieoiersmnd aper I andri CA*R desi c ropmoeetata, Va CAIR SO, Sm or CA R SO, unit *oni  ;- with ay allow pravli oato alppicale, awroved Stle krolmwimllao Plan. a Iedraly IV - m. or le CleamAir AcL CAIR NO. OZONE SEASON TRADING PROGRAM CAIR Part ReMAirements. (1) Thi CAIR doesinalad repmerdatim ofeach CAIR NO. Ozone Seamoan mcane wed each CAIR NOx Ozone Smonc umna at So scums shea

0) Sub"it lo 1 DEP a .ipIwmandcamled CAIR Paodte under 40 CFR 96.322 and Rule 62-M.470. FAC., In Ae f dmiineas apeled in Rue 62-213.420. FAC.; and (at)(RawvedJ (2) The ioners aid a frra CAR NO. Oza Sa*son ums aq each oedhwae a Tile V opeag pari or air ctrui pan, aid each CAR NOxCree eamoanuma u*qi fo ham a TOl V oareang iperi or sir masalnon perivit at go source Shae a CAIR Paot khidedd I le Ttoe V operating peartal or on parim*isaued by lie DEP under 40 CFR Pad 90. Subpart CCCC. fo li and o aI do Sms mid w unatin In. wth such CAORPat.

Monttblko. Repudft. and Recoidkeeplma Reouiefmmeits. (1) The omers mnd operetand OnCAIR degnated repremie. of each CAR NO. Ozone Season ecm@ and each CAIR NO. Ozone Seaeaimt a 1mer a c y i 1 rrrg. ropontth and rkei urm rr 1o40 CFR Padr . Subpwt HN Rul 62-2M.470. *AC. (2) TI er ismici mneaarti recoded mid spod In to 40 CFR Put 91. Subpart 1*M dol be ueed to doain0 Widm 

                              .mqr eu by each CAIR NO. Omze Seamana*=u                             1w the ftual CAR NO. Owm SeaeonEii                              Requ*en.tent.

N06 Ozone 66880 Eateo Reaulmments. (1) As 0ofOnm 1we 0 I - loreao-enrs peiod. So m midd opman 1eao CAIR NO, Ozone Season eurc mid - 1 CAR NO, 0 0n Seemanunl at tho so siae,hold. InSo cntgnce socunrt CAJR NO. ona Samoan aeawmoes waedble tr amums's ooIenmoa daductons fort coobel prmod under 40 CFR 11.364(a) in an mooued not bas tmo te Iwna told NO, anhiatons tor t coanmb peod ftn CAIR NO, Ozm Seacsn ums It ato smore.as domeied 0 ina, - l, 40 CFR Part 96. Subpart 501*. M A C-R NO, Owe S1en w s b eubjedt 1w reqsn-enl wide peagraph (I) o0f NO. O=wo Seoon I n Re**anb 

                               .        o 1w l@1       oa      1. 1. or 1w deen farimia ywleon                         meaig aie mioe unors                           req-             ider 40 CFR 96.370*bX                    )or(S) end ioreedi              , p1led 1w'esem.

(3) A CAIR NO. Ozone Seeman alaomna Stell noi be deducted. fa*twc imoean 1wirheqiprnm*t under paupeph (1) d* hNOA Ow Semman Erson Raquir e toronida period ina Ca yaw beforeto yew fo uhdi On CAR NO, Ozne Seemon macewa (4) CAIR NO, Owe Smoa n be hmiin.o umed n ortanaero d or aweg CAIR NO, Ozor oSemenA nc Tradd"g SaoM mm In amdarmlih 40 CFR Palt 9. Subpeft FFFF mid GGG-. (5) A CAR NO. Ooie Season ItsnItid atM -l'aaao oitson *nn t NO, in aoda toar mi CARt NO n Season Traing Prapsor NH roAiami@1f1w CAJ R INO Ozone Seem Tradkg ProIartr. 1w CAIR Paot r an a g'pl unde 40 CFR 9. onmd twuedi @loo almws be amelued hfiMaiw uauliorly@11w ort* 1w UntdSistee hterminat or Winilcmiitarizaio~n. (6) A CAIR NO, Ozon Sean - dams nrt consomme a poperty r* (7) UP- .9m' toyto Aiinrnr uidoe 40 CFR Pot 91. Subart EEEE. FFF or GGGG. evey almio. bwt. n n r. deducion on a CAN O, Oz on Season toaw fom a CAIR NO. Ow*e Samoa n amplce 

                                                                                                                                -            eccil incoportd snay                      in y CR Pint of11w scums li Includes to CAIR NO, OwoneSeamson                     mnit 00P Fonn No. 82-210.g00(1Xb) - Pnii E&0cnivo: 31606                                                                            4 Progress Energy Florida, Inc.                                                                                                                                     Permit No. 0170004-024-AV Crystal River Power Plant                                                                                                                         Title V Air Operation Permit Renewal Page 52 of 54

SECTION V. CAIR PART. Clean Air Interstate Rule Provisions I CRYSTAL RIVER POWER PLANT IPart Name (MraM Sr1 1) 1 IExces Emissions Rmeaurments. ST1EP 3 If a CAR NO. Oane See sm&mu enits ft NO, diwwg Wnyosnfrl putod in mum of UheCAIR NOOn.Samenmsabiftan livnr: Continued (1)1e omer a opera; s oftIhe source d each CAR NOx Ozo Season unita the source sal sumaredwlte CAIR NO. Ozo. Season mqhd 

                                              -l*'anmmtor dmdu&a.on unde40 CFR 95.364(dX*l) and pay any           , penalty. or assssment or comply ih " cow amedy Imposed. for I. same vidalon*. under the Clean Air Act or applicable state law &nd (2)Each ton ofsuch excess emissaions and each day of such conbif period          stai cobutla a aeparate violation of40 CFR Part 96. Subpart d Clean Air Act. and applicable SUNa the,                                      low Recordkeecpin          and Reportlna Reauimmets.

(I) Urnea ohamdise promded, h ,werisw1d operAtr-m of te CAIR NO Ozne Seamansurce ard each CAIR NO,, Ow Season unit at t arnwltSatg~ eeponsoaw achof 3 ollek~ doanmiefor a period of 5 yeam from to date Ins docuners Is ratd Tt~apeitod may be a tcr caee ornded use at any o b.1m Vihandof S !uaInsing by te DEP or ftAdrninlator. (I) The wrialt of -a .' under 40 CFR 96.313 for the CAIR deagnt ruprea itatas thormsoe arid each CAR N Oustne Season unit the source and Oallonn tat docmmna tOle ruistdht of e mtama iin Ihe enthecata of rlepfulliauoont ai l da 3 

                                - k, I and documents dog be                     on at at netalnad          mumsor-beyond such 5"ar period unti such docuaenta                superseded because af the submiloi of a new           "allflc, of s.prmeno und,d40CFR 96.113 chagngng di CAIR desinted representativ

(,) All -a1alw o1m Ifritnallm In ,ao 1- with 40 CFR Part U, Subpart HHHW. of Vlf pat. p Mvid t to th m a* 40 CFR PonE9.Suiar Meffi, provier;lsaa 31me period for rcordkeping der 3,ye eripaod"*3 apply. (0i) Copis of ONd rept. ompanca c-Ist- and owh" subtlssiosi and all ramoudl n.e or raqiulired wnder ev CAM NO. OzR Seaaon Tradft P ogiani (Qv)Copies of all docaras used to omliea a CAIR Par in anw ay ow submission under ieoCAJR NO Ozons Samoan Traai Program o to denorasata womprian we Uthdr arquiVers of Ift CAJR NO, Ozan Season Tradin Pmagna. (2) The CAIR designated representative ofa CAR NOx Ozone Samson source and each CAIR NO%One Seaaonit at the sowos OW eubdf I3he reports required uwder the CAR NO%Ozone Seasm Tmdeln Program. inckldng hose under 40 CFR Pwt 9, Subpert HHWL Uawbltr. (1) Each CAARNO. Ozone Season asume and each CAR NO%Ozone Seaso unit slil timetth of the CAIR NO, OWne Seeson nertesm Trading PRogram. (2) Any prIs-on at to CAIR NO%ozone Semon Tradf0 PmrWam Oit applies 0oa CAIR NOx Ozone Seaaon aource orB CAIR d g a rspreseue ofa CAMRNO,, COons Season mo s also apply to the asm and olper~wo of a*h sumse id of heCAR NO. Ozone SeA unftaof source. (3) Any pmviaon of sh CAJR NOx Ozone Season Tradig Progrum tal applies to a CAIR NOx Ozone Season undtor ft CAR gea 

                              .upanmwtv ofa CAJR NO, Oaie Seaon unit " als                  eo apply to to owners and opeal          o such unwL Effect on 00we Aufthoties No provialon of lit CAR NO. Ozone Season Trading Pmoginis,            a CAIR Part, or an exemption under 40 CAR 96306 shall be coeudas
                                  - FIn or    ~mod        1 owner endg     opras aid "i CAJRdesiprieted represenfabve. ofa CAIR NOx Ourie Season source or CAR~                   NO,,

Ozone Seao wlt from copino1 with any ows provision of e applicable, appmoved State Implemenation Plan afederally uderosabla permi.or th Clean Air Ac. STEP 4 Certification (for designated representative or altemat. designated represanatalve only) Read 01w I amadhotaed to mnakn fti submission on behalf of th owner aid operators of te CAR mums or CAIR units for ~t thresubnsion is 

                            ,ne".I                      Nobwiof lawie I32   lieu. personoyamairond, aid an butmler w^it, staemenlets and informullon submitted InOft cmti3tir                                                   Based an my lqusyof              viduaswtlU~ rmrreaponutial for Inose                                                   1W nfmeOWi.
                                                                                                                                                           #0*l              I Muytat stat~~~mef                          aniin         f arlto 1 beat f my knowledge aid bellel'ir.

sden anmd oit.Ia w,02Oeaea~cn ststmanntt provide ioo, e kiue*n roilldngiftfad aiadkirni, kdid ,, the posiltyo company name, Manager, Env mentl S i o phone, and @.-mall Name: Patricia Q. West Florida address; sign, and data. Company Owner Name FLORIDA POWER CORPORATION DBA PROGRESS ENERGY FLORIDA, INC. Phone: 727.820.5739 E-mailAdrs:p icaw t pgm lco Addressurebc Datwes pg aico DEP Form No. 62-210.9000(Xb)- Form Effecilve: 3/10M 5 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 53 of 54

SECTION VI. APPENDICES. The Following Appendices Are Enforceable Parts of This Permit: Appendix A, Glossary. Appendix ASP, ASP Number 97-B-01 (With Scrivener's Order Dated July 9, 1997). Appendix CAM, Compliance Assurance Monitoring Plan. Appendix I, List of Insignificant Emissions Units and/or Activities. Appendix NSPS, Subpart A - General Provisions. Appendix NSPS, Subpart D - Standards of Performance for Fossil Fuel Fired Steam Generators for which Construction is Commenced After August 17, 1971. Appendix NSPS, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines. Appendix NSPS, Subpart JJJJ, Standards of Performance for Stationary Spark Ignition Internal Combustion Engines. Appendix NSPS, Subpart Y - Standards of Performance for Coal Preparation Plants. Appendix NESHAP, Subpart A - General Provisions. Appendix NESHAP, Subpart ZZZZ, National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. Appendix RR, Facility-wide Reporting Requirements. Appendix TR, Facility-wide Testing Requirements. Appendix TV, Title V General Conditions. Appendix U, List of Unregulated Emissions Units and/or Activities. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Air Operation Permit Renewal Page 54 of 54

APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Abbreviations and Acronyms: o F: degrees Fahrenheit lbs/hr: pounds per hour acfm: actual cubic feet per minute LONG: Longitude AOR: Annual Operating Report MACT: maximum achievable technology ARMS: Air Resource Management System mm: millimeter (Department's database) MMBtu: million British thermal units BACT: best available control technology MSDS: material safety data sheets Btu: British thermal units MW: megawatt CAM: compliance assurance monitoring NESHAP: National Emissions Standards for CEMS: continuous emissions monitoring system Hazardous Air Pollutants cfm: cubic feet per minute NOx: nitrogen oxides CFR: Code of Federal Regulations NSPS: New Source Performance Standards CO: carbon monoxide O&M: operation and maintenance COMS: continuous opacity monitoring system 02: oxygen DARM: Division of Air Resources Management ORIS: Office of Regulatory Information Systems DCA: Department of Community Affairs OS: Organic Solvent DEP: Department of Environmental Protection Pb: lead Department: Department of Environmental PM: particulate matter Protection PM10 : particulate matter with a mean aerodynamic dscfm: dry standard cubic feet per minute diameter of 10 microns or less EPA: Environmental Protection Agency PSD: prevention of significant deterioration ESP: electrostatic precipitator (control system for psi: pounds per square inch reducing particulate matter) PTE: potential to emit EU: emissions unit RACT: reasonably available control technology F.A.C.: Florida Administrative Code RATA: relative accuracy test audit F.D.: forced draft RMP: Risk Management Plan F.S.: Florida Statutes RO: Responsible Official FGR: flue gas recirculation SAM: sulfuric acid mist FI: fluoride scf: standard cubic feet ft 2: square feet scfm: standard cubic feet per minute ft3: cubic feet SIC: standard industrial classification code gpm: gallons per minute SNCR: selective non-catalytic reduction (control gr: grains system used for reducing emissions of nitrogen HAP: hazardous air pollutant oxides) Hg: mercury SOA: Specific Operating Agreement I.D.: induced draft SO 2: sulfur dioxide ID: identification TPH: tons per hour ISO: International Standards Organization (refers to TPY: tons per year those conditions at 288 Kelvin, 60% relative UTM: Universal Transverse Mercator coordinate humidity and 101.3 kilopascals pressure.) system kPa: kilopascals VE: visible emissions LAT: Latitude VOC: volatile organic compounds Ib: pound x: By or times Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A - 1 of 2

APPENDIX A ABBREVIATIONS, ACRONYMS, CITATIONS AND IDENTIFICATION NUMBERS Citations: The following examples illustrate the methods used in this permit to abbreviate and cite the references of rules, regulations,guidance memorandums, permit numbers and ID numbers. Code of Federal Regulations: Example: [40 CFR 60.334] Where: 40 refers to Title 40 CFR refers to Code of Federal Regulations 60 refers to Part 60 60.334 refers to Regulation 60.334 Florida Administrative Code (F.A.C.) Rules: Example: [Rule 62-213.205, F.A.C.] Where: 62 refers to Title 62 62-213 refers to Chapter 62-213 62-213.205 refers to Rule 62-213.205, F.A.C. Identification Numbers: Facility Identification (ID) Number: Example: Facility ID No.: 1050221 Where: 105 = 3-digit number code identifying the facility is located in Polk County 0221 = 4-digit number assigned by state database. Permit Numbers: Example: 1050221-002-AV, or 1050221-001-AC Where: AC = Air Construction Permit AV = Air Operation Permit (Title V Source) 105 = 3-digit number code identifying the facility is located in Polk County 0221= 4-digit number assigned by permit tracking database 001 or 002= 3-digit sequential project number assigned by permit tracking database Example: PSD-FL-185 PA95-01 AC53-208321 Where: PSD = Prevention of Significant Deterioration Permit PA = Power Plant Siting Act Permit AC53 = old Air Construction Permit numbering identifying the facility is located in Polk County Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A - 2 of 2

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of ) 

                                                                     )

Florida Electric Power Coordinating Group, Inc., ) ASP No. 97-13-01 Petitioner. )) ORDER ON REOQUE51 ALTENATE PROCEDURES AND REOUrREM-_QLi Pursuant to Rule 62-297.620, Florida Administrative Code (F.AC.), the Florida Electric Coordinating Group, Incorporated, (FCG) petitioned for approval to: (1) Exempt fossil fuel steam generators which burn liquid and/or solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter complianee test; and, (2) Exempt fossil fuel steam generators which burn liquid andlor solid fuel for less than 400 hours during the federal fiscal year from the requirement to conduct an annual particulate matter compliance test during the year prior to renewal of an operation permit. This Order is intended to clarify particulate testing requirements for those fossil fuel steam generators which primarily burn gaseous fuels including but not necessarily limited to natural gas. Having considered the provisions ofRule 62-296.40S(Il), F.A.C., Rule 62-297.310(7), F.A.C., and all supporting documentation, the following Findings of Fact, Conclusions of Law, and Order are entered: FINDINGS OF FACT

1. The Florida Electric Power Coordinating Grqoý; Incorporated, petitioned the Department to exempt those fossil fuel steam generatord'which have a heat input of more than 250 million Btu per hour and burn solid and/or liquid fuel less than 400 hours during the year from the requirement to conduct an annual particulate matter compliance test [Exhibit 1)
2. Rule 62-296.405(l)(a), F.A.C., applies to those fossil fuel steam generators that are not subject to the federal standards of performance for new stationary sources (NSPS) in 40 CFR 60 and which have a heat input of more than 250 million Btu per hour.
3. Rule 62-296.405(I)(a), F.A.C., limits visible emissions from affected fossil fuel steam generators to, "20 percent opacity except for either one six-miaute period per hour during which Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-1 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) not exceed 40 percent. The option selected shall be specified in the emissions unt's construction and operation permits. Emissions units governed by this visible emission limit shall test for particulate emission compliance annually and as otherwise required by Rule 62-297, F.A.C."

4. Rule 6 2-296.405(1)(a), F.A.C, further states, "Emissions units electing to test for particulate matter emission compliance quarterly shall be allowed visible emissions of 40 percent opacity. The results of such tests shall be submitted to the Department. Upon demonstration that the particulate standard has been regularly complied with, the Secretary, upon petition by the applicant, shall reduce the frequency of particulate testing to no less than once annually.
5. Rule 297.310(7)(a)l., F.A.C., states, "The owner or operator of a new or modified.

emissions unit that is subject to an emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission linilting standard prior to obtaining an operation permit for such emissions unit."

6. Rule 297,310(7)(a)3., F.A.C., states, "The owner or operator of an emissions unit that is subject to any emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission limiting standard prior to obtaining a renewed operation permit. Emissions units that are required to conduct an annual compliance test may submit the most recent annual compliance test to satisfy the requirements of this provision.
7. Rule 297.310(7)(a)3., F.A.C., further states, "In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or d., F.A.C., the Department shall not require submission of emission compliance test results for any emissions unit that, during the year prior to renewal: a. Did not operate; or, b. In the case of a fuel burning emissions unit, burned liquid and/or solid fuel for a total of no more than 400 hours,"
8. Rule 297.3 10(7)(a)4., F.AC., states, "During each federal fiscal year (October 1 -

September 30), unless otherwise specified by rule, order, or permit, the owner or operator of each emissions unit shall have a formal compliance test conducted for: a. Visible emissions, if there is an applicable standard; b. Each of the following pollutants, if there is an applicable standard, aid if the emissions unit emits or has the potential to emit: 5 tons per year or more of lead or lead compounds measured as elemental lead; 30 tons per year,6r.more of acrylonitrile; or 100 tons per year or more of any other regulated air pollutant..."

9. Rule 297.310(7)(a)5., F.A.C., states, "An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unit that, in a federal fiscal year, does not bum liquid and/or solid fuel, other than during startup, for a total oFmore than 400 hours."
10. Rule 297.3 10(7)(a)6., F.A.C., states, "For fossil fuel steam generators on a semi-annual particulate matter emission compliance testing schedule, a compliance test shall not be
                                                           -Pa*e 2 of'-

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-2 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup." 1I. Rule 297.310(7)(a)7., F.A.C., states, "For emissions units electing to conduct particulate matter emission compliance testing quarterly pursuant to Rule 6 2 -2 96. 40 5(2)(a), F.KC., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than duing startup." [Note: The reference should be to Rule 62-296,405(l)(a), F.A.C., rather than Rule 62-29 6 .405(2)(a), F.A.C.]

12. The fifth edition of the U. S. Environmental Protection Agency's q9_mJigtign ofAkr Pollutant Emission Factors, AP-42, that ernmissions ofilterable particulate from Sas-fired fossil fuel steam generators with a heat input of more than about 10 million Btu per hour may be expected to range from 0.001 to 0.006 pound per million Btu. [Exhibit 21
13. Rule 62-296.405(f)(b), F.A.C. and the federal standards of performance for new stationary sources in 40 CFR 60.42) Subpart D, limit particulate emissions from uncontrolled fossil fuel fired steam generators with a heat input of more than 250 million Btu to 0.1 pound per million Btu.

CONCLUSIONS OF LAW

1. The Department hasjurisdiction to consider the matter pursuant to Section 403.061, Florida Statutes (F.S.), and Rule 62-297.620, F.A.C.
2. Pursuant to Rule 62-297.310(7), F.A.C., the Department may require Petitioner to conduct compliance tests that identify the nature and quantity ofpollutant emissions, ig after investigation, it is believed that any applicable emission standard or condition of the applicable permits is being violated.
3. There is reason to believe that a fossil fuel steam generator which does not burn liquid and/or solid fuel (other than during starmup) for a total ofmore than 400 hours in a federal fiscal year and complies with all other applicable limits and permit conditions is in compliance with the applicable particulate mass emission limiting standard.

ORDER Having considered the requirements of Rule 62-296.405, F.AG.C, Rule 62-297.310, F.A-C., and supporting documentation, it is hereby ordered that-

1. An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unitthat, in a federal fiscal year, does not burn liquid and/or solid fuel, other than during startup, for a total of more than 400 hours;
                                                              -- Page 3 of 8--

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-3 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997)

2. For Fossil fitel steam generators on a serri-annual particulate matter emisLion compliance testing schedule, a compliance test shall not be required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup;
3. For emissions units electing to conduct paxtuculate matter emission compliance testing quarterly pursuant to Rule 62-296405(l)(a), F.A.C., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than during startup;
4. In renewing an air operation permit pursuant to Rule 62-210.300(2)(a)3.b., c., or di.,

F.A.C., the Department shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal.

5. Pursuant to Rule 62-297.310(7), F.A.C., owners of affected fossil fuel steam generators may be required to conduct compliance tests that identify the nature and quantity of pollutant emissions, if, after investigation, it is believed that any applicable emission standard or enndition of the applicable permits is being violated.
6. Pursuant to Rule 62-297.310(8). F.A.C., owners of affected fossil fuel steam generators shall subunit the compliance test report to the District Director of the Department district office having jurisdiction over the emissions unit and, where applicable, the Air Program Administrator of the appropriate Department-approved local air program wAtbin 45 days of completion of the test.

PETITMON FOR ADMINMSTRATfVE REVIEW The Department will take the action described in this Order unless a timely petition for an administrative hearing is filed pursuant to sections 120.569 and 120.57 of the Florida Statutes, or a party requests mediation as an alternative remedy under section 120.573 before the deadline for filing a petition. Choosing mediation will not adversely affect the right to a hearing if mediation does not result in a settlement- The procedures for petitioning for a hearing are set forth below, followed by the procedures for requesting medialion. A.person whose substantial interests are affet.ed by the Department's proposed decision may petition for an administrative hearing in accordance with sections 120.569 and 120.57 of the Florida Statutes. The petition must contain the information set forth below and must be filed (received) in the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000. Petitions must be filed within 21 days of receipt of this Order. A petitioner must mail a copy of the petition to the applicant at the address indicated above, at the time of filing. The falure of any person to file a petition (or a request for mediation, as discussed below) within the appropriate time period shall constitute a waiver of that person's right to request an administrative determination (hearing) under sectionas 120.569 and 120.57 of 

                                                               -- Page 4 tf 8--

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APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) the Florida Statutes, or to intervene in this proceeding and participate as a party to it. Any subsequent intervention will be only at the approval of the presiding officer upon the filing of a motion in compliance with Rule 28-5.207 of the Florida Administrative Code. A petition must contain the following information: (a) The name, address, and telephone number of each petitioner, the applicant's name and address, the Department File Number, and the county in which the project is proposed; (b) A statement of how and when each petitioner received notice of the Department's action or proposed action; (c) A statement of how each petitioner's substantial interests are affected by the Department's action or proposed action; (d) A statement of the material facts disputed by each petitioner, if any; (e) A statement of facts that the petitioner contends warrant reversal or modification of the Department's action or proposed action; (f) A statement identifying the rules or statutes each petitioner contends require reversal or modification of the Department's action or proposed action; and, (g) A statement of the relief sought by each petitioner, stating precisely the action each petitioner wants the Department to take with respect to the Department's action or proposed action in the notice of intent. Because the administrative hearing process is designed to formulate final agency action, the filing of a petition means that the Department's final action may be different from the position taken by it in this Order. Persons whose substantial interests will be affected by any such final decision of the Department on the application have the right to petition to become a party to the proeeding, in accordance with the requirements set forth above. A person whose substantial interests are affected by the Department's proposed decision, may elect to pursue mediation by asking all parties to the proceeding to agree to such mediation and by filing with the Department a request for mediation and the written agreement of all such parties to mediate the dispute. The request and agreement must be filed in (received by) the Office of General Counsel of the Department at 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000, by the same deadline as set forth above for the filing of a petition. A request for mediation must contain the following information: 

                                                             -- Page 5 of 8-Progress Energy Florida, Inc.                                                                                 Permit No. 0170004-024-AV Crystal River Power Plant                                                                                          Title V Permit Renewal Page ASP-5 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) (a) The namre address, and telephone number of the person requesting mediation a~nd that person's representative, if any, (b) A statement of the preliminary agency action; (c) A statement of the relief sought; and (d) Either an explanation of how the requester's substantial interests will be affected by the action or proposed action addressed in this notice of intent or a statement clearly identifying the petition for hearing that the requester has already filed, and incorporating it by reference. The agreement to mediate must include the following: (a) The names, addresses, and telephone numbers of any persons who may attend the mediation; (b) The name, address, and telephone number of the mediator selected by the parties, or a provision for selecting a mediator within a specified time; (c) The agreed allocation of the costs and fees associated with the mediation; (d) The agreement of the parties on the confidentiality of discussions and documents introduced during mediation; (c) The date, time, and place of the first mediation session, or a deadline for holding the first session, if no mediator has yet been chosen; (f) The name of each party's representative who shall have authority to settle or recommend settlement; and (g) The siignatures of all parties or their authorized representatives. As provided in section 120.573 of the Florida StV'tes, the timely agreement of all parties to mediate will toll the tima lirmitations imposed by sectiorti 120.569 and 120.57 for requesting and holding an administrative hearing Unless otherwis'agreed by the parties, the mediation must be concluded within sixty days of the execution of the agreement. If mediation results in settlement of the administrative dispute, the Department must enter a final order incorporating the agreement of the parties. Persons whose substantial interests will be affected by such a modified final decision of the Department have a right to petition for a hearing only in accordance with the requirements for such petitions set forth above, If mediation terminates without settlement of the dispute, the Department shall notify all parties in writing that the administrative hearing processes under sections 120.569 and 120,57 remain available for disposition of the dispute, and the notice will 

                                                            --. ge 6 of e-Progress Energy Florida, Inc.                                                                               Permit No. 0170004-024-AV Crystal River Power Plant                                                                                         Title V Permit Renewal Page ASP-6 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) specify the deadlines that then will apply for challenging the agency action and electing remedies under those two statutes. In addition to the above, a person subject to regulation has a right to apply for a variance from or waiver of the requirements of particular rules, on certain conditions, under section 120.542 of the Florida Statutes. The relief provided by this state statute applies only to state rules, not statutes, and not to any federal regulatory requirements. Applying for a variance or waiver does not substitute or extend the time for filing a petition for an administrative hearing or exercising any other right that a person may have in relation to the action proposed in this notice of intent. The application for a variance or waiver is made by filing a petition with the Office of General Counsel of the Department, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000. The petition must specify tie following inlormation; (a) The nami, address, and telephone number of the petitioner; (h) The name, address, and telephone number of the attorney or qualified representative of the petitioner, if any, (c) Each rule or portion of a rule from which a variance or waiver is requested; (d) The citation to the statute underlying (implemented by) the rule identilied in (c) above; (c) The type of action requested; (f) The specific facts that would justify a variance or waiver for the petitioner; (g) The reason why the variance or waiver would serve the purposes of'the underlying statute (implemented by the rule); and (h) A statement whether the variance or waiver'isjermanent or temporary and, if temporary, a statement of the dates showing the duration of the variance or waiver requested. The Department will grant a variance or waiver, when the petition demonstrates both that the application of the rule would create a substantial hardship or violate principles of fairness, as each of those terms is defined in section 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner. Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or waivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully 

                                                             -Page  7 of S-Progress Energy Florida, Inc.                                                                                Permit No. 0170004-024-AV Crystal River Power Plant                                                                                           Title V Permit Renewal Page ASP-7 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) each of those terms is defined insection 120.542(2) of the Florida Statutes, and that the purpose of the underlying statute will be or has been achieved by other means by the petitioner. Persons subject to regulation pursuant to any federally delegated or approved air program should be aware that Florida is specifically not authorized to issue variances or w'aivers from any requirements of any such federally delegated or approved program. The requirements of the program remain fully enforceable by the Administrator of the EPA and by any person under the Clian Air Act unless and until the Administrator separately approves any variance or waiver in accordance with the procedures of the federal program. This Order constitutes final agency action unless a petition is filed in accordance with the above paragraphs. Upon timely filing of a petition, this Order will not be effective until further Order of the Department. RIGHT TO APPEAL Any party to this Order has the right to seek judicial review of the Order pursuant to Section 120.68, F.S., by the filing of a Notice of Appeal pursuant to Rule 9.110, Florida Rules of Appellate Procedure, with the Clerk of the Department in the Office of General Counsel, 3900 Commonwealth Boulevard, Mail Station 35, Tallahassee, Florida 32399-3000; and, by filing a copy of the Notice of Appeal accompanied by the applicable filing fees with the appropriate District Court of Appeal. The Notice of Appeal must be filed within 30 days from the date the Notice of Agency Action is filed with the Clerk of the Department. DONE AND ORDERED this Jýj day of -W -- 1997 in Tallahassee, Florida. STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION HOWARDI P J HODES, Director Division of Ar Re-sources Management Twin To'*ers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114 

                                                           -Page 8 of .-

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-8 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) CERTIMCATF OF SERVICE The undersigned duly designated deputy clerk hereby certifies that a copy of the foregoing was mailed to Rich Piper, Chair, Florida Power Coordinatin, Group, Inc., 405 Reo Street, Suite 100, Tampa, Florida 33609-1004, 'on this

  • day of March 1997.

Clerk Stamp FILING AND ACKNOWLEDGMENT FILED, on this date, pursuant to 

                                                               §120.52C7), Florida Statutes, with the designated Department Clerk, receipt of which is hereby acknowledged.

Cl6k Date Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-9 of 10

APPENDIX ASP ASP NUMBER 97-B-01 (With Scrivener's Order Dated July 9, 1997) STATE OF FLORIDA DEPARTMENT OF ENVIRONMENTAL PROTECTION In the matter of: ) Florida Electric Power Coordinating Group, Inc., 

                                                            ))

ASP No. 97-B-01 

                                                            )

Petitioner. ) ORDER CORRECTING SCRIVENER'S ERROR 

            \ The Order which authorizes owners of natural gas fired fossil fuel steam generators to forgo particulate matter compliance testing on an annual basis and prior to renewal of an operation permit entered on the 17th day of March, 1997, is hereby corrected on page 4, paragraph number 4, by deleting the words "pursuant to Rule 62-210.300(2)(a)3.b., c., or d.,

F,.A. C,":

4. In renewing an air operation permit pUSant--t-Rulc 62 210.3 00(24(*c, -.b,,

iA*-k. the Department, shall not require submission of particulate matter emission compliance test results for any fossil fuel steam generator emissions unit that burned liquid and/or solid fuel for a total of no more than 400 hours during the year prior to renewal. DONE AND ORDERED this c I day of (j (7 1997 in Tallahassee, Florida. STATE OFFLORIDA DEPARTMENT OF ENVIRONWMENTAL PROTECTION HOWARD L. RHODES, Director Division of Air Resources Management Twin Towers Office Building 2600 Blair Stone Road Tallahassee, Florida 32399-2400 (904) 488-0114 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ASP-10 of 10

APPENDIX CAM Compliance Assurance Monitoring Plan Pursuant to Rule 62-213.440(1)(b)l.a., F.A.C., the CAM plans that are included in this appendix contain the monitoring requirements necessary to satisfy 40 CFR 64. Conditions 1. - 17. are generic conditions applicable to all emissions units that are subject to the CAM requirements. Specific requirements related to each emissions unit are contained in the attached tables, as submitted by the applicant and approved by the Department. 40 CFR 64.6 Approval of Monitoring.

1. The attached CAM plan(s), as submitted by the applicant, is/are approved for the purposes of satisfying the requirements of 40 CFR 64.3. [40 CFR 64.6(a)]
2. The attached CAM plan(s) include the following information:
a. The indicator(s) to be monitored (such as temperature, pressure drop, emissions, or similar parameter);
b. The means or device to be used to measure the indicator(s) (such as temperature measurement device, visual observation, or CEMS); and
c. The performance requirements established to satisfy 40 CFR 64.3(b) or (d), as applicable.

[40 CFR 64.6(c)(1)]

3. The attached CAM plan(s) describe the means by which the owner or operator will define an exceedance of the permitted limits or an excursion from the stated indicator ranges and averaging periods for purposes of responding to (see CAM Conditions 5. - 9.) and reporting exceedances or excursions (see CAM Conditions
10. - 14.). [40 CFR 64.6(c)(2)]
4. The permittee is required to conduct the monitoring specified in the attached CAM plan(s) and shall fulfill the obligations specified in the conditions below (see CAM Conditions 5. - 17.). [40 CFR 64.6(c)(3)]

40 CFR 64.7 Operation of Approved Monitorin2.

5. Commencement of Operation. The owner or operator shall conduct the monitoring required under this appendix upon the effective date of this Title V permit. [40 CFR 64.7(a)]
6. Proper Maintenance. At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment. [40 CFR 64.7(b)]
7. Continued Operation. Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of this part, including data averages and calculations, or fulfilling a minimum data availability requirement, if applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions. [40 CFR 64.7(c)]
8. Response To Excursions or Exceedances.
a. Upon detecting an excursion or exceedance, the owner or operator shall restore operation of the pollutant-specific emissions unit (including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions. The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance (other than those caused by excused startup or shutdown conditions, if allowed by this permit). Such actions may include initial inspection and evaluation, recording that operations returned to normal without operator action (such as through response by a computerized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the applicable emission limitation or standard, as applicable.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-1 of 4

APPENDIX CAM Compliance Assurance Monitoring Plan

b. Determination of whether the owner or operator has used acceptable procedures in response to an excursion or exceedance will be based on information available, which may include but is not limited to, monitoring results, review of operation and maintenance procedures and records, and inspection of the control device, associated capture system, and the process.

[40 CFR 64.7(d)(1) & (2)]

9. Documentation of Need for Improved Monitoring. If the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the permitting authority and, if necessary, submit a proposed modification to the Title V permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions, modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters. [40 CFR 64.7(e)]

40 CFR 64.8 Quality Improvement Plan (QIP) Requirements.

10. Based on the results of a determination made under CAM Condition 8.a., above, the permitting authority may require the owner or operator to develop and implement a QIP. Consistent with CAM Condition 4., an accumulation of exceedances or excursions exceeding 5 percent duration of a pollutant-specific emissions unit's operating time for a reporting period, may require the implementation of a QIP. The threshold may be set at a higher or lower percent or may rely on other criteria for purposes of indicating whether a pollutant-specific emissions unit is being maintained and operated in a manner consistent with good air pollution control practices. [40 CFR 64.8(a)]
11. Elements of a QIP:
a. The owner or operator shall maintain a written QIP, if required, and have it available for inspection.
b. The plan initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate:

(1) Improved preventive maintenance practices. (2) Process operation changes. (3) Appropriate improvements to control methods. (4) Other steps appropriate to correct control performance. (5) More frequent or improved monitoring (only in conjunction with one or more steps under CAM Condition 11.b(i) through (iv), above). [40 CFR 64.8(b)]

12. If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the permitting authority if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined. [40 CFR 64.8(c)]
13. Following implementation of a QIP, upon any subsequent determination pursuant to CAM Condition 8.b.,

the permitting authority may require that an owner or operator make reasonable changes to the QIP if the QIP is found to have:

a. Failed to address the cause of the control device performance problems; or
b. Failed to provide adequate procedures for correcting control device performance problems as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions.

[40 CFR 64.8(d)]

14. Implementation of a QIP shall not excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. [40 CFR 64.8(e)]

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APPENDIX CAM Compliance Assurance Monitoring Plan 40 CFR 64.9 Reporting And Recordkeeping Requirements.

15. General reporting requirements.
a. On and after the date specified in CAM Condition 5. by which the owner or operator must use monitoring that meets the requirements of this appendix, the owner or operator shall submit monitoring reports semi-annually to the permitting authority in accordance with Rule 62-213.440(1)(b)3.a., F.A.C.
b. A report for monitoring under this part shall include, at a minimum, the information required under Rule 62-213.440(1)(b)3.a., F.A.C., and the following information, as applicable:

(1) Summary information on the number, duration and cause (including unknown cause, if applicable) of excursions or exceedances, as applicable, and the corrective actions taken; (2) Summary information on the number, duration and cause (including unknown cause, if applicable) for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable); and (3) A description of the actions taken to implement a QIP during the reporting period as specified in CAM Conditions 10. through 14. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring. [40 CFR 64.9(a)]

16. General recordkeeping requirements.
a. The owner or operator shall comply with the recordkeeping requirements specified in Rule 62-213.440(1)(b)2., F.A.C. The owner or operator shall maintain records of monitoring data, monitor performance data, corrective actions taken, any written quality improvement plan required pursuant to CAM Conditions 10. through 14., and any activities undertaken to implement a quality improvement plan, and other supporting information required to be maintained under this part (such as data used to document the adequacy of monitoring, or records of monitoring maintenance or corrective actions).
b. Instead of paper records, the owner or operator may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements.

[40 CFR 64.9(b)] 40 CFR 64.10 Savings Provisions.

17. It should be noted that nothing in this appendix shall:
a. Excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the Act. The requirements of this appendix shall not be used to justify the approval of monitoring less stringent than the monitoring which is required under separate legal authority and are not intended to establish minimum requirements for the purpose of determining the monitoring to be imposed under separate authority under the Act, including monitoring in permits issued pursuant to Title I of the Act. The purpose of this part is to require, as part of the issuance of a permit under Title V of the Act, improved or new monitoring at those emissions units where monitoring requirements do not exist or are inadequate to meet the requirements of this part.
b. Restrict or abrogate the authority of the Administrator or the permitting authority to impose additional or more stringent monitoring, recordkeeping, testing, or reporting requirements on any owner or operator of a source under any provision of the Act, including but not limited to sections 1 14(a)(1) and 504(b), or state law, as applicable.
c. Restrict or abrogate the authority of the Administrator or permitting authority to take any enforcement action under the Act for any violation of an applicable requirement or of any person to take action under section 304 of the Act.

[40 CFR 64.10] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-3 of 4

APPENDIX CAM Compliance Assurance Monitoring Plan Emissions Units 001, 002, 003 & 004 Two tangentially fired coal units and two dry bottom wall-fired units; Particulate Matter emissions controlled by Electrostatic Precipitators Monitoring Approach Indicator

1. Indicator Opacity.

Measurement Approach Continuous opacity monitoring system (COMS). II. Indicator Range For Units 2, 4 and 5, an excursion is defined as any 1 hour of opacity greater than 15% (other than startup, shutdown, "load-changing" and sootblowing periods). For Unit 1, an excursion is defined as any 1 hour of opacity greater than 22% (other than startup, shutdown, "load-changing" and sootblowing periods). Load-changing occurs when the operational capacity of a unit is in the 10 percent to 100 percent capacity range, other than startup or shutdown, which exceeds 10 percent of the unit's rated capacity and which occurs at a rate of 0.5 percent per minute or more. An excursion will trigger an evaluation of operation of the boiler(s) and ESP(s). Corrective action will be taken as necessary. Any excursion will trigger recordkeeping and reporting requirements. III. Performance Criteria A. Data Based on available opacity data while stack testing, the representative stack Representativeness opacity of units 2, 4 and 5 is in the range of 2 to 12%. Based upon available opacity data while stack testing, the representative stack opacity of Unit 1 is in the range of 5 to 20%. B. Verification of Annual testing during normal operation is used to verify particulate mass Operational Status loading. The COM system is audited quarterly. C. QA/QC Practices and Operate COMS according to 40 CFR Part 60 Appendix B, Performance Criteria Specification 1 and general provisions 60.13. The COMS is automatically calibrated every 24 hours. Calibration information is recorded through a data acquisition system (DAS). A neutral density filter test is performed quarterly as well as preventive maintenance items; replace filters, clean optics, etc., as prescribed by the manufacturer. D. Monitoring Frequency Opacity is monitored continuously. E. Data Collection The COMS collects data that are reduced to 6-minute averages. Consecutive Procedures 6-minute averages are tracked through the Distributed Control System (DAS) and CEM software. Daily reports with all six-minute averages are generated. F. Averaging Period Ten consecutive 6-minute averages. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page CAM-4 of 4

APPENDIX I LIST OF INSIGNIFICANT EMISSIONS UNITS AND/OR ACTIVITIES The facilities, emissions units, or pollutant-emitting activities listed in Rule 62-210.300(3)(a), F.A.C., Categorical Exemptions, or that meet the criteria specified in Rule 62-210.300(3)(b)1., F.A.C., Generic Emissions Unit Exemption, are exempt from the permitting requirements of Chapters 62-210, 62-212 and 62-4, F.A.C.; provided, however, that exempt emissions units shall be subject to any applicable emission limiting standards and the emissions from exempt emissions units or activities shall be considered in determining the potential emissions of the facility containing such emissions units. Emissions units and pollutant-emitting activities exempt from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., shall not be exempt from the permitting requirements of Chapter 62-213, F.A.C., if they are contained within a Title V source; however, such emissions units and activities shall be considered insignificant for Title V purposes provided they also meet the criteria of Rule 62-213.430(6)(b), F.A.C. No emissions unit shall be entitled to an exemption from permitting under Rules 62-210.300(3)(a) and (b)1., F.A.C., if its emissions, in combination with the emissions of other units and activities at the facility, would cause the facility to emit or have the potential to emit any pollutant in such amount as to make the facility a Title V source. The below listed emissions units and/or activities are considered insignificant pursuant to Rule 62-213.430(6), F.A.C. Brief Description of Emissions Units and/or Activities

1. Vehicle diesel and gasoline tanks.
2.
  • Diesel fire pump and tank at Unit 3 (FWP-7).
3.
  • Diesel pump driver for emergency feedwater (1,670 BHP).
4.
  • Diesel generator for security bldg and system (backup).
5.
  • 260 kW emergency diesel generator at Unit 3 technical support center.
6.
  • Unit 3 diesel generator air compressors.
7. Unit 3 halon fire protection system.
8.
  • Fire pump house emergency diesel generator units and electric generator units.
9. Laboratory facilities.
10. CEM equipment and calibration gas storage and venting.
11. Surface coating of less than 6.0 gallons per day.
12. Brazing, soldering and welding.
13. Grounds maintenance.
14.
  • Miscellaneous gas and diesel engines (under 500 hp).
15. Miscellaneous material handling activities.
16. Part waster.
17. Miscellaneous material cleaning equipment (e.g., self contained sand blasting).
18.
  • 175 kW emergency diesel generator for the Site Administration building.
19. Sand Blasting.
20. One concrete batch plant.
21. Two grout batch plants.
  • These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page I-1 of 1

APPENDIX ICE REQUIREMENTS FOR INTERNAL COMBUSTION ENGINES This Title V facility contains stationary internal combustion engines that have been exempted from the requirement to obtain an air construction permit because they qualify for one of the categorical exemptions listed in Rule 62-210.300(3)(a), Florida Administrative Code (F.A.C.). However, they are included in this permit as regulated emissions units because they are subject to one or more of the following federal rules:

  • 40 CFR 60, Subpart IIII-Standards of Performance for Stationary Compression Ignition Internal Combustion Engines.
  • 40 CFR 60, Subpart JJJJ-Standards of Performance for Stationary Spark Ignition Internal Combustion Engines.
  • 40 CFR 63, Subpart ZZZZ-National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines.

The below listed engines are subject to the specified federal rules. In- Displacement Rule E.U. No. Brief Description of Engine Service Applicability Date 028 3500 kW diesel generator associated with Unit 3 03/2006 12,443 in3 ZZZZ 029 Diesel fire pump, south yard 08/2009 14.5 L ZZZZ, 1III 030 Emergency generator (meteorological weather 09/2009 992 CC ZZZZ, JJJJ station) 1 031 Fire Pump, Trailer Mounted, Unit 3 02/2008 8700 CC ZZZZ, IIII The engines listed above are currently demonstrating compliance with the emissions limitations of the applicable federal rule through the retention of a manufacturer's certification statement. So long as that certification is able to be retained, no additional compliance demonstration is required. At such time that the manufacturer's certification is no longer valid (i.e. due to operation or maintenance practices that are inconsistent with the manufacturer's recommendations), the permittee shall begin demonstrating compliance with the standards listed in the applicable federal rule (included in the appendices as an enforceable part of this permit) in a manner that is prescribed by that rule. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page ICE-1 of 1

APPENDIX NSPS SUBPART A General Conditions Title 40: Protectionof Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES FederalRegulations Adopted by Reference In accordance with Rule 62-204.800, F.A.C., the following federal regulation in Title 40 of the Code of FederalRegulations (CFR) was adopted by reference. The originalfederal rule numbering has been retained. Federal Revision Date: June 13, 2007 Rule Effective Date: October 1, 2007 Standardized Conditions Revision Date: October 9, 2008 40 CFR Part 60, Subpart A - GeneralProvisions § 60.1 Applicability. (a) Except as provided in subparts B and C, the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. (b) Any new or revised standard of performance promulgated pursuant to section 11 1(b) of the Act shall apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of such new or revised standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility. (c) In addition to complying with the provisions of this part, the owner or operator of an affected facility may be required to obtain an operating permit issued to stationary sources by an authorized State air pollution control agency or by the Administrator of the U.S. Environmental Protection Agency (EPA) pursuant to Title V of the Clean Air Act (Act) as amended November 15, 1990 (42 U.S.C. 7661). For more information about obtaining an operating permit see part 70 of this chapter. (d) Site-specific standardfor Merck & Co., Inc. 's Stonewall Plant in Elkton, Virginia. (Not Applicable] § 60.2 Definitions. The terms used in this part are defined in the Act or in this section as follows: Act means the Clean Air Act (42 U.S.C. 7401 et seq. ) Administratormeans the Administrator of the Environmental Protection Agency or his authorized representative. Affected facility means, with reference to a stationary source, any apparatus to which a standard is applicable. Alternative method means any method of sampling and analyzing for an air pollutant which is not a reference or equivalent method but which has been demonstrated to the Administrator's satisfaction to, in specific cases, produce results adequate for his determination of compliance. Approved permit program means a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to Title V of the Act (42 U.S.C. 7661). Capital expenditure means an expenditure for a physical or operational change to an existing facility which exceeds the product of the applicable "annual asset guideline repair allowance percentage" specified in the latest edition of Internal Revenue Service (IRS) Publication 534 and the existing facility's basis, as defined by section 1012 of the Internal Revenue Code. However, the total expenditure for a physical or operational change to an existing facility must not be reduced by any "excluded additions" as defined in IRS Publication 534, as would be done for tax purposes. Clean coal technology demonstrationproject means a project using funds appropriated under the heading 'Department of Energy-Clean Coal Technology', up to a total amount of $2,500,000,000 for commercial demonstrations of clean coal technology, or similar projects funded through appropriations for the Environmental Protection Agency. Commenced means, with respect to the definition of new source in section 111(a)(2) of the Act, that an owner or operator has undertaken a continuous program of construction or modification or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or modification. Construction means fabrication, erection, or installation of an affected facility. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-1 of 29

APPENDIX NSPS SUBPART A General Conditions Continuous monitoring system means the total equipment, required under the emission monitoring sections in applicable subparts, used to sample and condition (if applicable), to analyze, and to provide a permanent record of emissions or process parameters. Electric utility steam generating unit means any steam electric generating unit that is constructed for the purpose of supplying more than one-third of its potential electric output capacity and more than 25 MW electrical output to any utility power distribution system for sale. Any steam supplied to a steam distribution system for the purpose of providing steam to a steam-electric generator that would produce electrical energy for sale is also considered in determining the electrical energy output capacity of the affected facility. Equivalent method means any method of sampling and analyzing for an air pollutant which has been demonstrated to the Administrator's satisfaction to have a consistent and quantitatively known relationship to the reference method, under specified conditions. Excess Emissions and Monitoring Systems PerformanceReport is a report that must be submitted periodically by a source in order to provide data on its compliance with stated emission limits and operating parameters, and on the performance of its monitoring systems. Existing facility means, with reference to a stationary source, any apparatus of the type for which a standard is promulgated in this part, and the construction or modification of which was commenced before the date of proposal of that standard; or any apparatus which could be altered in such a way as to be of that type. Force majeure means, for purposes of §60.8, an event that will be or has been caused by circumstances beyond the control of the affected facility, its contractors, or any entity controlled by the affected facility that prevents the owner or operator from complying with the regulatory requirement to conduct performance tests within the specified timeframe despite the affected facility's best efforts to fulfill the obligation. Examples of such events are acts of nature, acts of war or terrorism, or equipment failure or safety hazard beyond the control of the affected facility. Isokinetic sampling means sampling in which the linear velocity of the gas entering the sampling nozzle is equal to that of the undisturbed gas stream at the sample point. Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a Title V permit occurs immediately after the EPA takes final action on the final permit. Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Modification means any physical change in, or change in the method of operation of, an existing facility which increases the amount of any air pollutant (to which a standard applies) emitted into the atmosphere by that facility or which results in the emission of any air pollutant (to which a standard applies) into the atmosphere not previously emitted. Monitoring device means the total equipment, required under the monitoring of operations sections in applicable subparts, used to measure and record (if applicable) process parameters. Nitrogen oxides means all oxides of nitrogen except nitrous oxide, as measured by test methods set forth in this part. One-hour period means any 60-minute period commencing on the hour. Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background. Owner or operatormeans any person who owns, leases, operates, controls, or supervises an affected facility or a stationary source of which an affected facility is a part. Part 70 permit means any permit issued, renewed, or revised pursuant to part 70 of this chapter. Particulatematter means any finely divided solid or liquid material, other than uncombined water, as measured by the reference methods specified under each applicable subpart, or an equivalent or alternative method. Permitprogram means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C. 7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter. Permittingauthority means: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-2 of 29

APPENDIX NSPS SUBPART A General Conditions (1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661). Proportionalsampling means sampling at a rate that produces a constant ratio of sampling rate to stack gas flow rate. Reactivation of a very clean coal-fired electric utility steam generatingunit means any physical change or change in the method of operation associated with the commencement of Commercial operations by a coal-fired utility unit after a period of discontinued operation where the unit: (1) Has not been in operation for the two-year period prior to the enactment of the Clean Air Act Amendments of 1990, and the emissions from such unit continue to be carried in the permitting authority's emissions inventory at the time of enactment; (2) Was equipped prior to shut-down with a continuous system of emissions control that achieves a removal efficiency for sulfur dioxide of no less than 85 percent and a removal efficiency for particulates of no less than 98 percent; (3) Is equipped with low-NOx burners prior to the time of commencement of operations following reactivation; and (4) Is otherwise in compliance with the requirements of the Clean Air Act. Reference method means any method of sampling and analyzing for an air pollutant as specified in the applicable subpart. Repowering means replacement of an existing coal-fired boiler with one of the following clean coal technologies: atmospheric or pressurized fluidized bed combustion, integrated gasification combined cycle, magnetohydrodynamics, direct and indirect coal-fired turbines, integrated gasification fuel cells, or as determined by the Administrator, in consultation with the Secretary of Energy, a derivative of one or more of these technologies, and any other technology capable of controlling multiple combustion emissions simultaneously with improved boiler or generation efficiency and with significantly greater waste reduction relative to the performance of technology in widespread commercial use as of November 15, 1990. Repowering shall also include any oil and/or gas-fired unit which has been awarded clean coal technology demonstration funding as of January 1, 1991, by the Department of Energy. Run means the net period of time during which an emission sample is collected. Unless otherwise specified, a run may be either intermittent or continuous within the limits of good engineering practice. Shutdown means the cessation of operation of an affected facility for any purpose. Six-minute period means any one of the 10 equal parts of a one-hour period. Standard means a standard of performance proposed or promulgated under this part. Standardconditions means a temperature of 293 K (68F) and a pressure of 101.3 kilopascals (29.92 in Hg). Startup means the setting in operation of an affected facility for any purpose. State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement: (1) The provisions of this part; and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context. Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant. Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part. Volatile Organic Compound means any organic compound which participates in atmospheric photochemical reactions; or which is measured by a reference method, an equivalent method, an alternative method, or which is determined by procedures specified under any subpart. [44 FR 55173, Sept. 25, 1979, as amended at 45 FR 5617, Jan. 23, 1980; 45 FR 85415, Dec. 24, 1980; 54 FR 6662, Feb. 14, 1989; 55 FR 51382, Dec. 13, 1990; 57 FR 32338, July 21, 1992; 59 FR 12427, Mar. 16, 1994; 72 FR 27442, May 16, 2007] § 60.3 Units and abbreviations. Used in this part are abbreviations and symbols of units of measure. These are defined as follows: (a) System International (SI) units of measure: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-3 of 29

APPENDIX NSPS SUBPART A General Conditions A-ampere g-gram Hz-hertz J-joule K-degree Kelvin kg-kilogram mi-meter m3 -- cubic meter mg-milligram-i 0-3gram mm-millimeter 3 meter Mg-megagram--10 6 gram mol-mole N-newton ng-nanogram- 10- 9gram nm-nanometer- 10-9meter Pa-pascal s-second V-volt W-watt n-ohm pg-microgram-1 0-6gram (b) Other units of measure: Btu-British thermal unit 

   'C-degree Celsius (centigrade) cal-calorie cfm---cubic feet per minute cu ft--cubic feet dcf-dry cubic feet dcm--dry cubic meter dscf-dry cubic feet at standard conditions dscm-dry cubic meter at standard conditions eq-equivalent
   'F--degree Fahrenheit ft-feet gal-gallon gr-grain g-eq-gram equivalent hr-hour Progress Energy Florida, Inc.                                       Permit No. 0170004-024-AV Crystal River Power Plant                                               Title V Permit Renewal Page A-4 of 29

APPENDIX NSPS SUBPART A General Conditions in-inch k-1,000 I-liter lpm-liter per minute lb-pound meq-milliequivalent min-minute ml-milliliter mol. wt.-molecular weight ppb-parts per billion ppm-parts per million psia-pounds per square inch absolute psig-pounds per square inch gage 

    °R--degree Rankine scf--cubic feet at standard conditions scfh-cubic feet per hour at standard conditions scm-cubic meter at standard conditions sec-second sq ft-square feet std-at standard conditions (c)      Chemical nomenclature:

CdS-cadmium sulfide CO-carbon monoxide CO 2-- carbon dioxide HCl-hydrochloric acid Hg-mercury H2 0-water H2 S-hydrogen sulfide H2 SO 4-- sulfuric acid N 2-nitrogen NO-nitric oxide N0 2-nitrogen dioxide NOx-nitrogen oxides O 2-oxygen SO 2-sulfur dioxide S0 3-sulfur trioxide SOx-sulfur oxides (d) Miscellaneous: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-5 of 29

APPENDIX NSPS SUBPART A General Conditions A.S.T.M.-American Society for Testing and Materials [42 FR 37000, July 19, 1977; 42 FR 38178, July 27, 1977] § 60.4 Address. All addresses that pertainto Floridahave been incorporated. To see the complete list of addressesplease go to http://ecfr.jzpoaccess.gov/cgzilt/textltext-idx?c=ecfr&r_-n=div6&view=text&node=40:6.0. 1.1. 1.1 &idno=40. Link to an amendment published at 73 FR 18164, Apr. 3, 2008. (a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted in duplicate to the appropriate Regional Office of the U.S. Environmental Protection Agency to the attention of the Director of the Division indicated in the following list of EPA Regional Offices. Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee), Director, Air and Waste Management Division, U.S. Environmental Protection Agency, 345 Courtland Street, NE., Atlanta, GA 30365. (b) Section I 11(c) directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards of performance for new stationary sources located in such State. All information required to be submitted to EPA under paragraph (a) of this section, must also be submitted to the appropriate State Agency of any State to which this authority has been delegated (provided, that each specific delegation may except sources from a certain Federal or State reporting requirement). The appropriate mailing address for those States whose delegation request has been approved is as follows: (K) Bureau of Air Quality Management, Department of Environmental Regulation, Twin Towers Office Building, 2600 Blair Stone Road, Tallahassee, FL 32301. [40 FR 18169, Apr. 25, 1975] Editorial Note: For Federal Register citations affecting §60.4 see the List of CFR Sections Affected which appears in the Finding Aids section of the printed volume and on GPO Access. § 60.5 Determination of construction or modification. (a) When requested to do so by an owner or operator, the Administrator will make a determination of whether action taken or intended to be taken by such owner or operator constitutes construction (including reconstruction) or modification or the commencement thereof within the meaning of this part. (b) The Administrator will respond to any request for a determination under paragraph (a) of this section within 30 days of receipt of such request. [40 FR 58418, Dec. 16, 1975] § 60.6 Review ofplans. (a) When requested to do so by an owner or operator, the Administrator will review plans for construction or modification for the purpose of providing technical advice to the owner or operator. (b) (1) A separate request shall be submitted for each construction or modification project. (2) Each request shall identify the location of such project, and be accompanied by technical information describing the proposed nature, size, design, and method of operation of each affected facility involved in such project, including information on any equipment to be used for measurement or control of emissions. (c) Neither a request for plans review nor advice furnished by the Administrator in response to such request shall (1) relieve an owner or operator of legal responsibility for compliance with any provision of this part or of any applicable State or local requirement, or (2) prevent the Administrator from implementing or enforcing any provision of this part or taking any other action authorized by the Act. [36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974] § 60.7 Notification and recordkeeping. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-6 of 29

APPENDIX NSPS SUBPART A General Conditions (a) Any owner or operator subject to the provisions of this part shall furnish the Administrator written notification or, if acceptable to both the Administrator and the owner or operator of a source, electronic notification, as follows: (1) A notification of the date construction (or reconstruction as defined under §60.15) of an affected facility is commenced postmarked no later than 30 days after such date. This requirement shall not apply in the case of mass-produced facilities which are purchased in completed form. (2) [Reserved] (3) A notification of the actual date of initial startup of an affected facility postmarked within 15 days after such date. (4) A notification of any physical or operational change to an existing facility which may increase the emission rate of any air pollutant to which a standard applies, unless that change is specifically exempted under an applicable subpart or in §60.14(e). This notice shall be postmarked 60 days or as soon as practicable before the change is commenced and shall include information describing the precise nature of the change, present and proposed emission control systems, productive capacity of the facility before and after the change, and the expected completion date of the change. The Administrator may request additional relevant information subsequent to this notice. (5) A notification of the date upon which demonstration of the continuous monitoring system performance commences in accordance with §60.13(c). Notification shall be postmarked not less than 30 days prior to such date. (6) A notification of the anticipated date for conducting the opacity observations required by §60.11(e)(1) of this part. The notification shall also include, if appropriate, a request for the Administrator to provide a visible emissions reader during a performance test. The notification shall be postmarked not less than 30 days prior to such date. (7) A notification that continuous opacity monitoring system data results will be used to determine compliance with the applicable opacity standard during a performance test required by §60.8 in lieu of Method 9 observation data as allowed by §60.11(e)(5) of this part. This notification shall be postmarked not less than 30 days prior to the date of the performance test. (b) Any owner or operator subject to the provisions of this part shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. (c) Each owner or operator required to install a continuous monitoring device shall submit excess emissions and monitoring systems performance report (excess emissions are defined in applicable subparts) and-or summary report form (see paragraph (d) of this section) to the Administrator semiannually, except when: more frequent reporting is specifically required by an applicable subpart; or the Administrator, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. All reports shall be postmarked by the 30th day following the end of each six-month period. Written reports of excess emissions shall include the following information: (1) The magnitude of excess emissions computed in accordance with §60.13(h), any conversion factor(s) used, and the date and time of commencement and completion of each time period of excess emissions. The process operating time during the reporting period. (2) Specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the affected facility. The nature and cause of any malfunction (if known), the corrective action taken or preventative measures adopted. (3) The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and span checks and the nature of the system repairs or adjustments. (4) When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or adjusted, such information shall be stated in the report. (d) The summary report form shall contain the information and be in the format shown in figure 1 unless otherwise specified by the Administrator. One summary report form shall be submitted for each pollutant monitored at each affected facility. (1) If the total duration of excess emissions for the reporting period is less than 1 percent of the total operating time for the reporting period and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report form shall be submitted and the excess emission report described in 

        §60.7(c) need not be submitted unless requested by the Administrator.

(2) If the total duration of excess emissions for the reporting period is 1 percent or greater of the total operating time for the reporting period or the total CMS downtime for the reporting period is 5 percent or greater of the total operating Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-7 of 29

APPENDIX NSPS SUBPART A General Conditions time for the reporting period, the summary report form and the excess emission report described in §60.7(c) shall both be submitted. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-8 of 29

APPENDIX NSPS SUBPART A General Conditions Figure 1-Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance Pollutant (Circle One-SO2/NOx/TRS/H 2S/CO/Opacity) Reporting period dates: From to Company: Emission Limitation Address: Monitor Manufacturer and Model No. Date of Latest CMS Certification or Audit Process Unit(s)

Description:

Total source operating time in reporting period' 1 Emission data summary' CMS performance summary

1. Duration of excess emissions in reporting period due to: 1. CMS downtime in reporting period due to:
a. Startup/shutdown a. Monitor equipment malfunctions
b. Control equipment problems b. Non-Monitor equipment malfunctions
c. Process problems c. Quality assurance calibration
d. Other known causes d. Other known causes
e. Unknown causes e. Unknown causes
2. Total duration of excess emission 2. Total CMS Downtime
3. Total duration of excess emissions x (100) [Total source %2 3. [Total CMS Downtime] x (100) [Total source %2 operating time] operating time]

'For opacity, record all times in minutes. For gases, record all times in hours. 2For the reporting period: If the total duration of excess emissions is 1 percent or greater of the total operating time or the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in §60.7(c) shall be submitted. On a separate page, describe any changes since last quarter in CMS, process or controls. I certify that the information contained in this report is true, accurate, and complete. Name Signature Title Date Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-9 of 29

APPENDIX NSPS SUBPART A General Conditions (e) (1) Notwithstanding the frequency of reporting requirements specified in paragraph (c) of this section, an owner or operator who is required by an applicable subpart to submit excess emissions and monitoring systems performance reports (and summary reports) on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met: (i) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected facility's excess emissions and monitoring systems reports submitted to comply with a standard under this part continually demonstrate that the facility is in compliance with the applicable standard; (ii) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the applicable standard; and (iii) The Administrator does not object to a reduced frequency of reporting for the affected facility, as provided in paragraph (e)(2) of this section. (2) The frequency of reporting of excess emissions and monitoring systems performance (and summary) reports may be reduced only after the owner or operator notifies the Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the required recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements. Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention. The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted. (3) As soon as monitoring data indicate that the affected facility is not in compliance with any emission limitation or operating parameter specified in the applicable standard, the frequency of reporting shall revert to the frequency specified in the applicable standard, and the owner or operator shall submit an excess emissions and monitoring systems performance report (and summary report, if required) at the next appropriate reporting period following the noncomplying event. After demonstrating compliance with the applicable standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard as provided for in paragraphs (e)(1) and (e)(2) of this section. (f) Any owner or operator subject to the provisions of this part shall maintain a file of all measurements, including continuous monitoring system, monitoring device, and performance testing measurements; all continuous monitoring system performance evaluations; all continuous monitoring system or monitoring device calibration checks; adjustments and maintenance performed on these systems or devices; and all other information required by this part recorded in a permanent form suitable for inspection. The file shall be retained for at least two years following the date of such measurements, maintenance, reports, and records, except as follows: (1) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard. (2) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (f) of this section, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator. (3) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (f) of this section, if the Administrator or the delegated Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-10 of 29

APPENDIX NSPS SUBPART A General Conditions authority determines these records are required to more accurately assess the compliance status of the affected source. (g) If notification substantially similar to that in paragraph (a) of this section is required by any other State or local agency, sending the Administrator a copy of that notification will satisfy the requirements of paragraph (a) of this section. (h) Individual subparts of this part may include specific provisions which clarify or make inapplicable the provisions set forth in this section. [36 FR 24877, Dec. 28, 1971, as amended at 40 FR 46254, Oct. 6, 1975; 40 FR 58418, Dec. 16, 1975; 45 FR 5617, Jan. 23, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 52 FR 9781, Mar. 26, 1987; 55 FR 51382, Dec. 13, 1990; 59 FR 12428, Mar. 16, 1994; 59 FR 47265, Sep. 15, 1994; 64 FR 7463, Feb. 12, 1999] § 60.8 Performancetests. (a) Except as specified in paragraphs (a)(1),(a)(2), (a)(3), and (a)(4) of this section, within 60 days after achieving the maximum production rate at which the affected facility will be operated, but not later than 180 days after initial startup of such facility, or at such other times specified by this part, and at such other times as may be required by the Administrator under section 114 of the Act, the owner or operator of such facility shall conduct performance test(s) and furnish the Administrator a written report of the results of such performance test(s). (1) If a force majeure is about to occur, occurs, or has occurred for which the affected owner or operator intends to assert a claim of force majeure, the owner or operator shall notify the Administrator, in writing as soon as practicable following the date the owner or operator first knew, or through due diligence should have known that the event may cause or caused a delay in testing beyond the regulatory deadline, but the notification must occur before the performance test deadline unless the initial force majeure or a subsequent force majeure event delays the notice, and in such cases, the notification shall occur as soon as practicable. (2) The owner or operator shall provide to the Administrator a written description of the force majeure event and a rationale for attributing the delay in testing beyond the regulatory deadline to the force majeure; describe the measures taken or to be taken to minimize the delay; and identify a date by which the owner or operator proposes to conduct the performance test. The performance test shall be conducted as soon as practicable after the force majeure occurs. (3) The decision as to whether or not to grant an extension to the performance test deadline is solely within the discretion of the Administrator. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an extension as soon as practicable. (4) Until an extension of the performance test deadline has been approved by the Administrator under paragraphs (a)(1), (2), and (3) of this section, the owner or operator of the affected facility remains strictly subject to the requirements of this part. (b) Performance tests shall be conducted and data reduced in accordance with the test methods and procedures contained in each applicable subpart unless the Administrator (1) specifies or approves, in specific cases, the use of a reference method with minor changes in methodology, (2) approves the use of an equivalent method, (3) approves the use of an alternative method the results of which he has determined to be adequate for indicating whether a specific source is in compliance, (4) waives the requirement for performance tests because the owner or operator of a source has demonstrated by other means to the Administrator's satisfaction that the affected facility is in compliance with the standard, or (5) approves shorter sampling times and smaller sample volumes when necessitated by process variables or other factors. Nothing in this paragraph shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act. (c) Performance tests shall be conducted under such conditions as the Administrator shall specify to the plant operator based on representative performance of the affected facility. The owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of the performance tests. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test nor shall emissions in excess of the level of the applicable emission limit during periods of startup, shutdown, and malfunction be considered a violation of the applicable emission limit unless otherwise specified in the applicable standard. (d) The owner or operator of an affected facility shall provide the Administrator at least 30 days prior notice of any performance test, except as specified under other subparts, to afford the Administrator the opportunity to have an observer present. If after 30 days notice for an initially scheduled performance test, there is a delay (due to operational Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-1I of 29

APPENDIX NSPS SUBPART A General Conditions problems, etc.) in conducting the scheduled performance test, the owner or operator of an affected facility shall notify the Administrator (or delegated State or local agency) as soon as possible of any delay in the original test date, either by providing at least 7 days prior notice of the rescheduled date of the performance test, or by arranging a rescheduled date with the Administrator (or delegated State or local agency) by mutual agreement. (e) The owner or operator of an affected facility shall provide, or cause to be provided, performance testing facilities as follows: (1) Sampling ports adequate for test methods applicable to such facility. This includes (i) constructing the air pollution control system such that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures and (ii) providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures. (2) Safe sampling platform(s). (3) Safe access to sampling platform(s). (4) Utilities for sampling and testing equipment. (f) Unless otherwise specified in the applicable subpart, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the applicable standard. For the purpose of determining compliance with an applicable standard, the arithmetic means of results of the three runs shall apply. In the event that a sample is accidentally lost or conditions occur in which one of the three runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances, beyond the owner or operator's control, compliance may, upon the Administrator's approval, be determined using the arithmetic mean of the results of the two other runs. [36 FR 24877, Dec. 23, 1971, as amended at 39 FR 9314, Mar. 8, 1974; 42 FR 57126, Nov. 1, 1977; 44 FR 33612, June 11, 1979; 54 FR 6662, Feb. 14, 1989; 54 FR 21344, May 17, 1989; 64 FR 7463, Feb. 12, 1999; 72 FR 27442, May 16, 2007] § 60.9 Availability of information. The availability to the public of information provided to, or otherwise obtained by, the Administrator under this part shall be governed by part 2 of this chapter. (Information submitted voluntarily to the Administrator for the purposes of §§60.5 and 60.6 is governed by §§2.201 through 2.213 of this chapter and not by §2.301 of this chapter.) § 60.10 State authority. The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from: (a) Adopting and enforcing any emission standard or limitation applicable to an affected facility, provided that such emission standard or limitation is not less stringent than the standard applicable to such facility. (b) Requiring the owner or operator of an affected facility to obtain permits, licenses, or approvals prior to initiating construction, modification, or operation of such facility. § 60.11 Compliance with standards and maintenance requirements. (a) Compliance with standards in this part, other than opacity standards, shall be determined in accordance with performance tests established by §60.8, unless otherwise specified in the applicable standard. (b) Compliance with opacity standards in this part shall be determined by conducting observations in accordance with Method 9 in appendix A of this part, any alternative method that is approved by the Administrator, or as provided in paragraph (e)(5) of this section. For purposes of determining initial compliance, the minimum total time of observations shall be 3 hours (30 6-minute averages) for the performance test or other set of observations (meaning those fugitive-type emission sources subject only to an opacity standard). (c) The opacity standards set forth in this part shall apply at all times except during periods of startup, shutdown, malfunction, and as otherwise provided in the applicable standard. (d) At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-12 of 29

APPENDIX NSPS SUBPART A General Conditions (e) (1) For the purpose of demonstrating initial compliance, opacity observations shall be conducted concurrently with the initial performance test required in §60.8 unless one of the following conditions apply. If no performance test under 

         §60.8 is required, then opacity observations shall be conducted within 60 days after achieving the maximum production rate at which the affected facility will be operated but no later than 180 days after initial startup of the facility. If visibility or other conditions prevent the opacity observations from being conducted concurrently with the initial performance test required under §60.8, the source owner or operator shall reschedule the opacity observations as soon after the initial performance test as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. In these cases, the 30-day prior notification to the Administrator required in
        §60.7(a)(6) shall be waived. The rescheduled opacity observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under §60.8. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity observations from being made concurrently with the initial performance test in accordance with procedures contained in Method 9 of appendix B of this part. Opacity readings of portions of plumes which contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity standards. The owner or operator of an affected facility shall make available, upon request by the Administrator, such records as may be necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification. Except as provided in paragraph (e)(5) of this section, the results of continuous monitoring by transmissometer which indicate that the opacity at the time visual observations were made was not in excess of the standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the source shall meet the burden of proving that the instrument used meets (at the time of the alleged violation) Performance Specification 1 in appendix B of this part, has been properly maintained and (at the time of the alleged violation) that the resulting data have not been altered in any way.

(2) Except as provided in paragraph (e)(3) of this section, the owner or operator of an affected facility to which an opacity standard in this part applies shall conduct opacity observations in accordance with paragraph (b) of this section, shall record the opacity of emissions, and shall report to the Administrator the opacity results along with the results of the initial performance test required under §60.8. The inability of an owner or operator to secure a visible emissions observer shall not be considered a reason for not conducting the opacity observations concurrent with the initial performance test. (3) The owner or operator of an affected facility to which an opacity standard in this part applies may request the Administrator to determine and to record the opacity of emissions from the affected facility during the initial performance test and at such times as may be required. The owner or operator of the affected facility shall report the opacity results. Any request to the Administrator to determine and to record the opacity of emissions from an affected facility shall be included in the notification required in §60.7(a)(6). If, for some reason, the Administrator cannot determine and record the opacity of emissions from the affected facility during the performance test, then the provisions of paragraph (e)(1) of this section shall apply. (4) An owner or operator of an affected facility using a continuous opacity monitor (transmissometer) shall record the monitoring data produced during the initial performance test required by §60.8 and shall furnish the Administrator a written report of the monitoring results along with Method 9 and §60.8 performance test results. (5) An owner or operator of an affected facility subject to an opacity standard may submit, for compliance purposes, continuous opacity monitoring system (COMS) data results produced during any performance test required under 

        §60.8 in lieu of Method 9 observation data. If an owner or operator elects to submit COMS data for compliance with the opacity standard, he shall notify the Administrator of that decision, in writing, at least 30 days before any performance test required under §60.8 is conducted. Once the owner or operator of an affected facility has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent tests required under §60.8 until the owner or operator notifies the Administrator, in writing, to the contrary. For the purpose of determining compliance with the opacity standard during a performance test required under §60.8 using COMS data, the minimum total time of COMS data collection shall be averages of all 6-minute continuous periods within the duration of the mass emission performance test. Results of the COMS opacity determinations shall be submitted along with the results of the performance test required under §60.8. The owner or operator of an affected facility using a COMS for compliance purposes is responsible for demonstrating that the COMS meets the requirements specified in §60.13(c) of this part, that the COMS has been properly maintained and operated, and that the resulting data have not been altered in any way. If COMS data results are submitted for compliance with the opacity standard for a period of time during which Method 9 data indicates noncompliance, the Method 9 data will be used to determine compliance with the opacity standard.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A- 13 of 29

APPENDIX NSPS SUBPART A General Conditions (6) Upon receipt from an owner or operator of the written reports of the results of the performance tests required by 

         §60.8, the opacity observation results and observer certification required by §60.11(e)(1), and the COMS results, if applicable, the Administrator will make a finding concerning compliance with opacity and other applicable standards. If COMS data results are used to comply with an opacity standard, only those results are required to be submitted along with the performance test results required by §60.8. If the Administrator finds that an affected facility is in compliance with all applicable standards for which performance tests are conducted in accordance with
         §60.8 of this part but during the time such performance tests are being conducted fails to meet any applicable opacity standard, he shall notify the owner or operator and advise him that he may petition the Administrator within 10 days of receipt of notification to make appropriate adjustment to the opacity standard for the affected facility.

(7) The Administrator will grant such a petition upon a demonstration by the owner or operator that the affected facility and associated air pollution control equipment was operated and maintained in a manner to minimize the opacity of emissions during the performance tests; that the performance tests were performed under the conditions established by the Administrator; and that the affected facility and associated air pollution control equipment were incapable of being adjusted or operated to meet the applicable opacity standard. (8) The Administrator will establish an opacity standard for the affected facility meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity standard at all times during which the source is meeting the mass or concentration emission standard. The Administrator will promulgate the new opacity standard in the Federal Register. (f) Special provisions set forth under an applicable subpart shall supersede any conflicting provisions in paragraphs (a) through (e) of this section. (g) For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in this part, nothing in this part shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. [38 FR 28565, Oct. 15, 1973, as amended at 39 FR 39873, Nov. 12, 1974; 43 FR 8800, Mar. 3, 1978; 45 FR 23379, Apr. 4, 1980; 48 FR 48335, Oct. 18, 1983; 50 FR 53113, Dec. 27, 1985; 51 FR 1790, Jan. 15, 1986; 52 FR 9781, Mar. 26, 1987; 62 FR 8328, Feb. 24, 1997; 65 FR 61749, Oct. 17, 2000] § 60.12 Circumvention. No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. [39 FR 9314, Mar. 8, 1974] § 60.13 Monitoringrequirements. (a) For the purposes of this section, all continuous monitoring systems required under applicable subparts shall be subject to the provisions of this section upon promulgation of performance specifications for continuous monitoring systems under appendix B to this part and, if the continuous monitoring system is used to demonstrate compliance with emission limits on a continuous basis, appendix F to this part, unless otherwise specified in an applicable subpart or by the Administrator. Appendix F is applicable December 4, 1987. (b) All continuous monitoring systems and monitoring devices shall be installed and operational prior to conducting performance tests under §60.8. Verification of operational status shall, as a minimum, include completion of the manufacturer's written requirements or recommendations for installation, operation, and calibration of the device. (c) If the owner or operator of an affected facility elects to submit continuous opacity monitoring system (COMS) data for compliance with the opacity standard as provided under §60.11(e)(5), he shall conduct a performance evaluation of the COMS as specified in Performance Specification 1, appendix B, of this part before the performance test required under 

    §60.8 is conducted. Otherwise, the owner or operator of an affected facility shall conduct a performance evaluation of the COMS or continuous emission monitoring system (CEMS) during any performance test required under §60.8 or within 30 days thereafter in accordance with the applicable performance specification in appendix B of this part, The owner or operator of an affected facility shall conduct COMS or CEMS performance evaluations at such other times as may be required by the Administrator under section 114 of the Act.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-14 of 29

APPENDIX NSPS SUBPART A General Conditions (1) The owner or operator of an affected facility using a COMS to determine opacity compliance during any performance test required under §60.8 and as described in §60.11(e)(5) shall furnish the Administrator two or, upon request, more copies of a written report of the results of the COMS performance evaluation described in paragraph (c) of this section at least 10 days before the performance test required under §60.8 is conducted. (2) Except as provided in paragraph (c)(1) of this section, the owner or operator of an affected facility shall furnish the Administrator within 60 days of completion two or, upon request, more copies of a written report of the results of the performance evaluation. (d) (1) Owners and operators of a CEMS installed in accordance with the provisions of this part, must check the zero (or low level value between 0 and 20 percent of span value) and span (50 to 100 percent of span value) calibration drifts at least once daily in accordance with a written procedure. The zero and span must, as a minimum, be adjusted whenever either the 24-hour zero drift or the 24-hour span drift exceeds two times the limit of the applicable performance specification in appendix B of this part. The system must allow the amount of the excess zero and span drift to be recorded and quantified whenever specified. Owners and operators of a COMS installed in accordance with the provisions of this part, must automatically, intrinsic to the opacity monitor, check the zero and upscale (span) calibration drifts at least once daily. For a particular COMS, the acceptable range of zero and upscale calibration materials is as defined in the applicable version of PS-1 in appendix B of this part. For a COMS, the optical surfaces, exposed to the effluent gases, must be cleaned before performing the zero and upscale drift adjustments, except for systems using automatic zero adjustments. The optical surfaces must be cleaned when the cumulative automatic zero compensation exceeds 4 percent opacity. (2) Unless otherwise approved by the Administrator, the following procedures must be followed for a COMS. Minimum procedures must include an automated method for producing a simulated zero opacity condition and an upscale opacity condition using a certified neutral density filter or other related technique to produce a known obstruction of the light beam. Such procedures must provide a system check of all active analyzer internal optics with power or curvature, all active electronic circuitry including the light source and photodetector assembly, and electronic or electro-mechanical systems and hardware and or software used during normal measurement operation. (e) Except for system breakdowns, repairs, calibration checks, and zero and span adjustments required under paragraph (d) of this section, all continuous monitoring systems shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: (1) All continuous monitoring systems referenced by paragraph (c) of this section for measuring opacity of emissions shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period. (2) All continuous monitoring systems referenced by paragraph (c) of this section for measuring emissions, except opacity, shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. (f) All continuous monitoring systems or monitoring devices shall be installed such that representative measurements of emissions or process parameters from the affected facility are obtained. Additional procedures for location of continuous monitoring systems contained in the applicable Performance Specifications of appendix B of this part shall be used. (g) When the effluents from a single affected facility or two or more affected facilities subject to the same emission standards are combined before being released to the atmosphere, the owner or operator may install applicable continuous monitoring systems on each effluent or on the combined effluent. When the affected facilities are not subject to the same emission standards, separate continuous monitoring systems shall be installed on each effluent. When the effluent from one affected facility is released to the atmosphere through more than one point, the owner or operator shall install an applicable continuous monitoring system on each separate effluent unless the installation of fewer systems is approved by the Administrator. When more than one continuous monitoring system is used to measure the emissions from one affected facility (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required from each continuous monitoring system. (h) (1) Owners or operators of all continuous monitoring systems for measurement of opacity shall reduce all data to 6-minute averages and for continuous monitoring systems other than opacity to 1-hour averages for time periods as defined in §60.2. Six-minute opacity averages shall be calculated from 36 or more data points equally spaced over each 6-minute period. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-15 of 29

APPENDIX NSPS SUBPART A General Conditions (2) For continuous monitoring systems other than opacity, 1-hour averages shall be computed as follows, except that the provisions pertaining to the validation of partial operating hours are only applicable for affected facilities that are required by the applicable subpart to include partial hours in the emission calculations: (i) Except as provided under paragraph (h)(2)(iii) of this section, for a full operating hour (any clock hour with 60 minutes of unit operation), at least four valid data points are required to calculate the hourly average, i.e. , one data point in each of the 15-minute quadrants of the hour. (ii) Except as provided under paragraph (h)(2)(iii) of this section, for a partial operating hour (any clock hour with less than 60 minutes of unit operation), at least one valid data point in each 15-minute quadrant of the hour in which the unit operates is required to calculate the hourly average. (iii) For any operating hour in which required maintenance or quality-assurance activities are performed: (A) If the unit operates in two or more quadrants of the hour, a minimum of two valid data points, separated by at least 15 minutes, is required to calculate the hourly average; or (B) If the unit operates in only one quadrant of the hour, at least one valid data point is required to calculate the hourly average. (iv) If a daily calibration error check is failed during any operating hour, all data for that hour shall be invalidated, unless a subsequent calibration error test is passed in the same hour and the requirements of paragraph (h)(2)(iii) of this section are met, based solely on valid data recorded after the successful calibration. (v) For each full or partial operating hour, all valid data points shall be used to calculate the hourly average. (vi) Except as provided under paragraph (h)(2)(vii) of this section, data recorded during periods of continuous monitoring system breakdown, repair, calibration checks, and zero and span adjustments shall not be included in the data averages computed under this paragraph. (vii)Owners and operators complying with the requirements of §60.7(f)(1) or (2) must include any data recorded during periods of monitor breakdown or malfunction in the data averages. (viii) When specified in an applicable subpart, hourly averages for certain partial operating hours shall not be computed or included in the emission averages ( e.g. hours with < 30 minutes of unit operation under 

               §60.47b(d)).

(ix) Either arithmetic or integrated averaging of all data may be used to calculate the hourly averages. The data may be recorded in reduced or nonreduced form ( e.g. , ppm pollutant and percent O 2or ng/J of pollutant). (3) All excess emissions shall be converted into units of the standard using the applicable conversion procedures specified in the applicable subpart. After conversion into units of the standard, the data may be rounded to the same number of significant digits used in the applicable subpart to specify the emission limit. (i) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring procedures or requirements of this part including, but not limited to the following: (1) Alternative monitoring requirements when installation of a continuous monitoring system or monitoring device specified by this part would not provide accurate measurements due to liquid water or other interferences caused by substances in the effluent gases. (2) Alternative monitoring requirements when the affected facility is infrequently operated. (3) Alternative monitoring requirements to accommodate continuous monitoring systems that require additional measurements to correct for stack moisture conditions. (4) Alternative locations for installing continuous monitoring systems or monitoring devices when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements. (5) Alternative methods of converting pollutant concentration measurements to units of the standards. (6) Alternative procedures for performing daily checks of zero and span drift that do not involve use of span gases or test cells. (7) Alternatives to the A.S.T.M. test methods or sampling procedures specified by any subpart. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A- 16 of 29

APPENDIX NSPS SUBPART A General Conditions (8) Alternative continuous monitoring systems that do not meet the design or performance requirements in Performance Specification 1, appendix B, but adequately demonstrate a definite and consistent relationship between its measurements and the measurements of opacity by a system complying with the requirements in Performance Specification 1. The Administrator may require that such demonstration be performed for each affected facility. (9) Alternative monitoring requirements when the effluent from a single affected facility or the combined effluent from two or more affected facilities is released to the atmosphere through more than one point. (j) An alternative to the relative accuracy (RA) test specified in Performance Specification 2 of appendix B may be requested as follows: (1) An alternative to the reference method tests for determining RA is available for sources with emission rates demonstrated to be less than 50 percent of the applicable standard. A source owner or operator may petition the Administrator to waive the RA test in Section 8.4 of Performance Specification 2 and substitute the procedures in Section 16.0 if the results of a performance test conducted according to the requirements in §60.8 of this subpart or other tests performed following the criteria in §60.8 demonstrate that the emission rate of the pollutant of interest in the units of the applicable standard is less than 50 percent of the applicable standard. For sources subject to standards expressed as control efficiency levels, a source owner or operator may petition the Administrator to waive the RA test and substitute the procedures in Section 16.0 of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement. The alternative procedures do not apply if the continuous emission monitoring system is used to determine compliance continuously with the applicable standard. The petition to waive the RA test shall include a detailed description of the procedures to be applied. Included shall be location and procedure for conducting the alternative, the concentration or response levels of the alternative RA materials, and the other equipment checks included in the alternative procedure. The Administrator will review the petition for completeness and applicability. The determination to grant a waiver will depend on the intended use of the CEMS data (e.g., data collection purposes other than NSPS) and may require specifications more stringent than in Performance Specification 2 (e.g., the applicable emission limit is more stringent than NSPS). (2) The waiver of a CEMS RA test will be reviewed and may be rescinded at such time, following successful completion of the alternative RA procedure, that the CEMS data indicate that the source emissions are approaching the level. The criterion for reviewing the waiver is the collection of CEMS data showing that emissions have exceeded 70 percent of the applicable standard for seven, consecutive, averaging periods as specified by the applicable regulation(s). For sources subject to standards expressed as control efficiency levels, the criterion for reviewing the waiver is the collection of CEMS data showing that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for seven, consecutive, averaging periods as specified by the applicable regulation(s) [e.g., §60.45(g) (2) and (3), §60.73(e), and §60.84(e)]. It is the responsibility of the source operator to maintain records and determine the level of emissions relative to the criterion on the waiver of RA testing. If this criterion is exceeded, the owner or operator must notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increasing emissions. The Administrator will review the notification and may rescind the waiver and require the owner or operator to conduct a RA test of the CEMS as specified in Section 8.4 of Performance Specification 2. [40 FR 46255, Oct. 6, 1975; 40 FR 59205, Dec. 22, 1975, as amended at 41 FR 35185, Aug. 20, 1976; 48 FR 13326, Mar. 30, 1983; 48 FR 23610, May 25, 1983; 48 FR 32986, July 20, 1983; 52 FR 9782, Mar. 26, 1987; 52 FR 17555, May 11, 1987; 52 FR 21007, June 4, 1987; 64 FR 7463, Feb. 12, 1999; 65 FR 48920, Aug. 10, 2000; 65 FR 61749, Oct. 17, 2000; 66 FR 44980, Aug. 27, 2001; 71 FR 31102, June 1, 2006; 72 FR 32714, June 13, 2007] Editorial Note: At 65 FR 61749, Oct. 17, 2000, §60.13 was amended by revising the words "ng/J of pollutant" to read "ng of pollutant per J of heat input" in the sixth sentence of paragraph (h). However, the amendment could not be incorporated because the words "ng/J of pollutant" do not exist in the sixth sentence of paragraph (h). § 60.14 Modification. (a) Except as provided under paragraphs (e) and (f) of this section, any physical or operational change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which a standard applies shall be considered a modification within the meaning of section 111 of the Act. Upon modification, an existing facility shall become an affected facility for each pollutant to which a standard applies and for which there is an increase in the emission rate to the atmosphere. (b) Emission rate shall be expressed as kg/hr of any pollutant discharged into the atmosphere for which a standard is applicable. The Administrator shall use the following to determine emission rate: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-17 of 29

APPENDIX NSPS SUBPART A General Conditions (1) Emission factors as specified in the latest issue of "Compilation of Air Pollutant Emission Factors," EPA Publication No. AP-42, or other emission factors determined by the Administrator to be superior to AP-42 emission factors, in cases where utilization of emission factors demonstrates that the emission level resulting from the physical or operational change will either clearly increase or clearly not increase. (2) Material balances, continuous monitor data, or manual emission tests in cases where utilization of emission factors as referenced in paragraph (b)(1) of this section does not demonstrate to the Administrator's satisfaction whether the emission level resulting from the physical or operational change will either clearly increase or clearly not increase, or where an owner or operator demonstrates to the Administrator's satisfaction that there are reasonable grounds to dispute the result obtained by the Administrator utilizing emission factors as referenced in paragraph (b)(1) of this section. When the emission rate is based on results from manual emission tests or continuous monitoring systems, the procedures specified in appendix C of this part shall be used to determine whether an increase in emission rate has occurred. Tests shall be conducted under such conditions as the Administrator shall specify to the owner or operator based on representative performance of the facility. At least three valid test runs must be conducted before and at least three after the physical or operational change. All operating parameters which may affect emissions must be held constant to the maximum feasible degree for all test runs. (c) The addition of an affected facility to a stationary source as an expansion to that source or as a replacement for an existing facility shall not by itself bring within the applicability of this part any other facility within that source. (d) [Reserved] (e) The following shall not, by themselves, be considered modifications under this part: (1) Maintenance, repair, and replacement which the Administrator determines to be routine for a source category, subject to the provisions of paragraph (c) of this section and §60.15. (2) An increase in production rate of an existing facility, if that increase can be accomplished without a capital expenditure on that facility. (3) An increase in the hours of operation. (4) Use of an alternative fuel or raw material if, prior to the date any standard under this part becomes applicable to that source type, as provided by §60.1, the existing facility was designed to accommodate that alternative use. A facility shall be considered to be designed to accommodate an alternative fuel or raw material if that use could be accomplished under the facility's construction specifications as amended prior to the change. Conversion to coal required for energy considerations, as specified in section 111(a)(8) of the Act, shall not be considered a modification. (5) The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial. (6) The relocation or change in ownership of an existing facility. (f) Special provisions set forth under an applicable subpart of this part shall supersede any conflicting provisions of this section. (g) Within 180 days of the completion of any physical or operational change subject to the control measures specified in paragraph (a) of this section, compliance with all applicable standards must be achieved. (h) No physical change, or change in the method of operation, at an existing electric utility steam generating unit shall be treated as a modification for the purposes of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the 5 years prior to the change. (i) Repowering projects that are awarded funding from the Department of Energy as permanent clean coal technology demonstration projects (or similar projects funded by EPA) are exempt from the requirements of this section provided that such change does not increase the maximum hourly emissions of any pollutant regulated under this section above the maximum hourly emissions achievable at that unit during the five years prior to the change. (j) (1) Repowering projects that qualify for an extension under section 409(b) of the Clean Air Act are exempt from the requirements of this section, provided that such change does not increase the actual hourly emissions of any Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-18 of 29

APPENDIX NSPS SUBPART A General Conditions pollutant regulated under this section above the actual hourly emissions achievable at that unit during the 5 years prior to the change. (2) This exemption shall not apply to any new unit that: (i) Is designated as a replacement for an existing unit; (ii) Qualifies under section 409(b) of the Clean Air Act for an extension of an emission limitation compliance date under section 405 of the Clean Air Act; and (iii) Is located at a different site than the existing unit. (k) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project is exempt from the requirements of this section. A temporary clean coal control technology demonstrationproject, for the purposes of this section is a clean coal technology demonstration project that is operated for a period of 5 years or less, and which complies with the State implementation plan for the State in which the project is located and other requirements necessary to attain and maintain the national ambient air quality standards during the project and after it is terminated. (1) The reactivation of a very clean coal-fired electric utility steam generating unit is exempt from the requirements of this section. [40 FR 58419, Dec. 16, 1975, as amended at 43 FR 34347, Aug. 3, 1978; 45 FR 5617, Jan. 23, 1980; 57 FR 32339, July 21, 1992; 65 FR 61750, Oct. 17, 2000] § 60.15 Reconstruction. (a) An existing facility, upon reconstruction, becomes an affected facility, irrespective of any change in emission rate. (b) "Reconstruction" means the replacement of components of an existing facility to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part. (c) "Fixed capital cost" means the capital needed to provide all the depreciable components. (d) If an owner or operator of an existing facility proposes to replace components, and the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, he shall notify the Administrator of the proposed replacements. The notice must be postmarked 60 days (or as soon as practicable) before construction of the replacements is commenced and must include the following information: (1) Name and address of the owner or operator. (2) The location of the existing facility. (3) A brief description of the existing facility and the components which are to be replaced. (4) A description of the existing air pollution control equipment and the proposed air pollution control equipment. (5) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new facility. (6) The estimated life of the existing facility after the replacements. (7) A discussion of any economic or technical limitations the facility may have in complying with the applicable standards of performance after the proposed replacements. (e) The Administrator will determine, within 30 days of the receipt of the notice required by paragraph (d) of this section and any additional information he may reasonably require, whether the proposed replacement constitutes reconstruction. (f) The Administrator's determination under paragraph (e) shall be based on: (1) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new facility; (2) The estimated life of the facility after the replacements compared to the life of a comparable entirely new facility; (3) The extent to which the components being replaced cause or contribute to the emissions from the facility; and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-19 of 29

APPENDIX NSPS SUBPART A General Conditions (4) Any economic or technical limitations on compliance with applicable standards of performance which are inherent in the proposed replacements. (g) Individual subparts of this part may include specific provisions which refine and delimit the concept of reconstruction set forth in this section. [40 FR 58420, Dec. 16, 1975] § 60.16 Priority list. A list ofprioritizedmajor source categoriesmay be found at the following EPA web site: http://ecfr.gjpoaccess.gov/cgi/tltext/text-idx?c=ecfr&rn-n=div6&view=text&node=40:6.0.1.1.1.1&idno=40 § 60.17 Incorporationsby reference. The materials listed below are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register on the date listed. These materials are incorporated as they exist on the date of the approval, and a notice of any change in these materials will be published in the Federal Register. The materials are available for purchase at the corresponding address noted below, and all are available for inspection at the Library (C267-01), U.S. EPA, Research Triangle Park, NC or at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202-741-6030, or go to: http://Www.archives.gov/federal register/code-ofjederal regulations/ibrlocations, html. (a) The following materials are available for purchase from at least one of the following addresses: American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106. (1) ASTM A99-76, 82 (Reapproved 1987), Standard Specification for Ferromanganese, incorporation by reference (IBR) approved for §60.261. (2) ASTM A100-69, 74, 93, Standard Specification for Ferrosilicon, IBR approved for §60.261. (3) ASTM A101-73, 93, Standard Specification for Ferrochromium, IBR approved for §60.261. (4) ASTM A482-76, 93, Standard Specification for Ferrochromesilicon, IBR approved for §60.261. (5) ASTM A483-64, 74 (Reapproved 1988), Standard Specification for Silicomanganese, IBR approved for §60.261. (6) ASTM A495-76, 94, Standard Specification for Calcium-Silicon and Calcium Manganese-Silicon, IBR approved for §60.261. (7) ASTM D86-78, 82, 90, 93, 95, 96, Distillation of Petroleum Products, IBR approved for §§60.562-2(d), 60.593(d), 60.593a(d), and 60.633(h). (8) ASTM D129-64, 78, 95, 00, Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for §§60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, 12.5.2.2.3. (9) ASTM D129-00 (Reapproved 2005), Standard Test Method for Sulfur in Petroleum Products (General Bomb Method), IBR approved for §60.4415(a)(1)(i). (10) ASTM D240-76, 92, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter, IBR approved for §§60.46(c), 60.296(b), and Appendix A: Method 19, Section 12.5.2.2.3. (11) ASTM D270-65, 75, Standard Method of Sampling Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.1. (12) ASTM D323-82, 94, Test Method for Vapor Pressure of Petroleum Products (Reid Method), IBR approved for 

         §§60.111(1), 60.11 la(g), 60.11 lb(g), and 60.116b(f)(2)(ii).

(13)ASTM D388-77, 90, 91, 95, 98a, 99 (Reapproved 2004)E' , Standard Specification for Classification of Coals by Rank, IBR approved for §§60.24(h)(8), 60.41 of subpart D of this part, 60.45(f)(4)(i), 60.45(f)(4)(ii), 60.45(f)(4)(vi), 60.41Da of subpart Da of this part, 60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, and 60.4102. (14)ASTM D388-77, 90, 91, 95, 98a, Standard Specification for Classification of Coals by Rank, IBR approved for 

         §§60.251(b) and (c) of subpart Y of this part.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-20 of 29

APPENDIX NSPS SUBPART A General Conditions (15)ASTM D396-78, 89, 90, 92, 96, 98, Standard Specification for Fuel Oils, IBR approved for §§60.41b of subpart Db of this part, 60.41c of subpart Dc of this part, 60.11 l(b) of subpart K of this part, and 60.111 a(b) of subpart Ka of this part. (16)ASTM D975-78, 96, 98a, Standard Specification for Diesel Fuel Oils, IBR approved for §§60.11 l(b) of subpart K of this part and 60.111 a(b) of subpart Ka of this part. (17) ASTM D1072-80, 90 (Reapproved 1994), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for 

        §60.335(b)(10)(ii).

(18) ASTM D1072-90 (Reapproved 1999), Standard Test Method for Total Sulfur in Fuel Gases, IBR approved for 

        §60.4415(a)(1)(ii).

(19) ASTM D1137-53, 75, Standard Method for Analysis of Natural Gases and Related Types of Gaseous Mixtures by the Mass Spectrometer, IBR approved for §60.45(O(5)(i). (20) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 5, Section 7.1.3; Method 5E, Section 7.2.1; Method 5F, Section 7.2.1; Method 6, Section 7.1.1; Method 7, Section 7.1.1; Method 7C, Section 7.1.1; Method 7D, Section 7.1.1; Method 10A, Section 7.1.1; Method 11, Section 7.1.3; Method 12, Section 7.1.3; Method 13A, Section 7.1.2; Method 26, Section 7.1.2; Method 26A, Section 7.1.2; and Method 29, Section 7.2.2. (21)ASTM D1266-87, 91, 98, Standard Test Method for Sulfur in Petroleum Products (Lamp Method), IBR approved for §§60.1060)(2) and 60.335(b)(10)(i). (22) ASTM D1266-98 (Reapproved 2003)el, Standard Test Method for Sulfur in Petroleum Products (Lamp Method), IBR approved for §60.4415(a)(1)(i). (23)ASTM D1475-60 (Reapproved 1980), 90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for §60.435(d)(1), Appendix A: Method 24, Section 6.1; and Method 24A, Sections 6.5 and 7.1. (24)ASTM D1552-83, 95, 01, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method), IBR approved for §§60.106(j)(2), 60.335(b)(10)(i), and Appendix A: Method 19, Section 12.5.2.2.3. (25)ASTM D1552-03, Standard Test Method for Sulfur in Petroleum Products (High-Temperature Method), IBR approved for §60.4415(a)(1)(i). (26)ASTM D1826-77, 94, Standard Test Method for Calorific Value of Gases in Natural Gas Range by Continuous Recording Calorimeter, IBR approved for §§60.45(f)(5)(ii), 60.46(c)(2), 60.296(b)(3), and Appendix A: Method 19, Section 12.3.2.4. (27)ASTM D1835-87, 91, 97, 03a, Standard Specification for Liquefied Petroleum (LP) Gases, IBR approved for 

        §§60.4lDa of subpart Da of this part, 60.41b of subpart Db of this part, and 60.41c of subpart Dc of this part.

(28)ASTM D1945-64, 76, 91, 96, Standard Method for Analysis of Natural Gas by Gas Chromatography, IBR approved for §60.45(f)(5)(i). (29) ASTM D1946-77, 90 (Reapproved 1994), Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for §§60.18(f)(3), 60.45(f)(5)(i), 60.564(f)(1), 60.614(e)(2)(ii), 60.614(e)(4), 60.664(e)(2)(ii), 60.664(e)(4), 60.704(d)(2)(ii), and 60.704(d)(4). (30) ASTM D2013-72, 86, Standard Method of Preparing Coal Samples for Analysis, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3. (31)ASTM D2015-77 (Reapproved 1978), 96, Standard Test Method for Gross Calorific Value of Solid Fuel by the Adiabatic Bomb Calorimeter, IBR approved for §60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3. (32) ASTM D2016-74, 83, Standard Test Methods for Moisture Content of Wood, IBR approved for Appendix A: Method 28, Section 16.1.1. (33)ASTM D2234-76, 96, 97b, 98, Standard Methods for Collection of a Gross Sample of Coal, IBR approved for Appendix A: Method 19, Section 12.5.2.1.1. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-21 of 29

APPENDIX NSPS SUBPART A General Conditions (34) ASTM D2369-81, 87, 90, 92, 93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for Appendix A: Method 24, Section 6.2. (35)ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for §§60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3), 60.614(e)(4), 60.664(e)(4), and 60.704(d)(4). (36)ASTM D2504-67, 77, 88 (Reapproved 1993), Noncondensable Gases in C3 and Lighter Hydrocarbon Products by Gas Chromatography, IBR approved for §§60.485(g)(5) and 60.485a(g)(5). (37) ASTM D2584-68 (Reapproved 1985), 94, Standard Test Method for Ignition Loss of Cured Reinforced Resins, IBR approved for §60.685(c)(3)(i). (38) ASTM D2597-94 (Reapproved 1999), Standard Test Method for Analysis of Demethanized Hydrocarbon Liquid Mixtures Containing Nitrogen and Carbon Dioxide by Gas Chromatography, IBR approved for §60.335(b)(9)(i). (39) ASTM D2622-87, 94, 98, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for §§60.1060)(2) and 60.335(b)(10)(i). (40) ASTM D2622-05, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-Ray Fluorescence Spectrometry, IBR approved for §60.4415(a)(1)(i). (41)ASTM D2879-83, 96, 97, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for §§60.11 lb(f)(3), 60.116b(e)(3)(ii), 60.116b(f)(2)(i), 60.485(e)(1), and 60.485a(e)(1). (42) ASTM D2880-78, 96, Standard Specification for Gas Turbine Fuel Oils, IBR approved for §§60.11 l(b), 60.11 la(b), and 60.335(d). (43)ASTM D2908-74, 91, Standard Practice for Measuring Volatile Organic Matter in Water by Aqueous-Injection Gas Chromatography, IBR approved for §60.564(j). (44)ASTM D2986-71, 78, 95a, Standard Method for Evaluation of Air, Assay Media by the Monodisperse DOP (Dioctyl Phthalate) Smoke Test, IBR approved for Appendix A: Method 5, Section 7.1.1; Method 12, Section 7.1.1; and Method 13A, Section 7.1.1.2. (45)ASTM D3173-73, 87, Standard Test Method for Moisture in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3. (46) ASTM D3176-74, 89, Standard Method for Ultimate Analysis of Coal and Coke, IBR approved for §60.45(f)(5)(i) and Appendix A: Method 19, Section 12.3.2.3. (47) ASTM D3177-75, 89, Standard Test Method for Total Sulfur in the Analysis Sample of Coal and Coke, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3. (48) ASTM D3178-73 (Reapproved 1979), 89, Standard Test Methods for Carbon and Hydrogen in the Analysis Sample of Coal and Coke, IBR approved for §60.45(f)(5)(i). (49)ASTM D3246-81, 92, 96, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for §60.335(b)(10)(ii). (50)ASTM D3246-05, Standard Test Method for Sulfur in Petroleum Gas by Oxidative Microcoulometry, IBR approved for §60.4415(a)(1)(ii). (51) ASTM D3270-73T, 80, 91, 95, Standard Test Methods for Analysis for Fluoride Content of the Atmosphere and Plant Tissues (Semiautomated Method), IBR approved for Appendix A: Method 13A, Section 16.1. (52)ASTM D3286-85, 96, Standard Test Method for Gross Calorific Value of Coal and Coke by the Isoperibol Bomb Calorimeter, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3. (53) ASTM D3370-76, 95a, Standard Practices for Sampling Water, IBR approved for §60.564(j). (54) ASTM D3792-79, 91, Standard Test Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.3. (55) ASTM D4017-81, 90, 96a, Siandard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for Appendix A: Method 24, Section 6.4. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-22 of 29

APPENDIX NSPS SUBPART A General Conditions (56)ASTM D4057-81, 95, Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.3. (57) ASTM D4057-95 (Reapproved 2000), Standard Practice for Manual Sampling of Petroleum and Petroleum Products, IBR approved for §60.4415(a)(1). (58)ASTM D4084-82, 94, Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR approved for §60.334(h)(1). (59) ASTM D4084-05, Standard Test Method for Analysis of Hydrogen Sulfide in Gaseous Fuels (Lead Acetate Reaction Rate Method), IBR approved for §§60.4360 and 60.4415(a)(1)(ii). (60)ASTM D4177-95, Standard Practice for Automatic Sampling of Petroleum and Petroleum Products, IBR approved for Appendix A: Method 19, Section 12.5.2.2.1. (61)ASTM D4177-95 (Reapproved 2000), Standard Practice for Automatic Sampling of Petroleum and Petroleum Products, IBR approved for §60.4415(a)(1). (62) ASTM D4239-85, 94, 97, Standard Test Methods for Sulfur in the Analysis Sample of Coal and Coke Using High Temperature Tube Furnace Combustion Methods, IBR approved for Appendix A: Method 19, Section 12.5.2.1.3. (63)ASTM D4294-02, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for §60.335(b)(10)(i). (64) ASTM D4294-03, Standard Test Method for Sulfur in Petroleum and Petroleum Products by Energy-Dispersive X-Ray Fluorescence Spectrometry, IBR approved for §60.4415(a)(1)(i). (65) ASTM D4442-84, 92, Standard Test Methods for Direct Moisture Content Measurement in Wood and Wood-base Materials, IBR approved for Appendix A: Method 28, Section 16.1.1. (66) ASTM D4444-92, Standard Test Methods for Use and Calibration of Hand-Held Moisture Meters, IBR approved for Appendix A: Method 28, Section 16.1.1. (67) ASTM D4457-85 (Reapproved 1991), Test Method for Determination of Dichloromethane and 1, 1, 1-Trichloroethane in Paints and Coatings by Direct Injection into a Gas Chromatograph, IBR approved for Appendix A: Method 24, Section 6.5. (68)ASTM D4468-85 (Reapproved 2000), Standard Test Method for Total Sulfur in Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry, IBR approved for §§60.335(b)(10)(ii) and 60.4415(a)(1)(ii). (69) ASTM D4629-02, Standard Test Method for Trace Nitrogen in Liquid Petroleum Hydrocarbons by Syringe/Inlet Oxidative Combustion and Chemiluminescence Detection, IBR approved for §§60.49b(e) and 60.335(b)(9)(i). (70)ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for §§60.18(f)(3), 60.485(g)(6), 60.485a(g)(6), 60.564(f)(3), 60.614(d)(4), 60.664(e)(4), and 60.704(d)(4). (71)ASTM D4810-88 (Reapproved 1999), Standard Test Method for Hydrogen Sulfide in Natural Gas Using Length of Stain Detector Tubes, IBR approved for §§60.4360 and 60.4415(a)(1)(ii). (72)ASTM D5287-97 (Reapproved 2002), Standard Practice for Automatic Sampling of Gaseous Fuels, IBR approved for §60.4415(a)(1). (73) ASTM D5403-93, Standard Test Methods for Volatile Content of Radiation Curable Materials, IBR approved for Appendix A: Method 24, Section 6.6. (74) ASTM D5453-00, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for §60.335(b)(10)(i). (75) ASTM D5453-05, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Motor Fuels and Oils by Ultraviolet Fluorescence, IBR approved for §60.4415(a)(1)(i). (76) ASTM D5504-01, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Chemiluminescence, IBR approved for §§60.334(h)(1) and 60.4360. (77)ASTM D5762-02, Standard Test Method for Nitrogen in Petroleum and Petroleum Products by Boat-Inlet Chemiluminescence, IBR approved for §60.335(b)(9)(i). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-23 of 29

APPENDIX NSPS SUBPART A General Conditions (78) ASTM D5865-98, Standard Test Method for Gross Calorific Value of Coal and Coke, IBR approved for 

        §60.45(f)(5)(ii), 60.46(c)(2), and Appendix A: Method 19, Section 12.5.2.1.3.

(79) ASTM D6216-98, Standard Practice for Opacity Monitor Manufacturers to Certify Conformance with Design and Performance Specifications, IBR approved for Appendix B, Performance Specification 1. (80)ASTM D6228-98, Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for §60.334(h)(1). (81) ASTM D6228-98 (Reapproved 2003), Standard Test Method for Determination of Sulfur Compounds in Natural Gas and Gaseous Fuels by Gas Chromatography and Flame Photometric Detection, IBR approved for §§60.4360 and 60.4415. (82) ASTM D6348-03, Standard Test Method for Determination of Gaseous Compounds by Extractive Direct Interface Fourier Transform Infrared (FTIR) Spectroscopy, IBR approved for table 7 of Subpart IIII of this part and table 2 of subpart JJJJ of this part. (83) ASTM D6366-99, Standard Test Method for Total Trace Nitrogen and Its Derivatives in Liquid Aromatic Hydrocarbons by Oxidative Combustion and Electrochemical Detection, IBR approved for §60.335(b)(9)(i). (84) ASTM D6420-99 (Reapproved 2004) Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for table 2 of subpart JJJJ of this part. (85) ASTM D6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for §60.335(a). (86)ASTM D6522-00 (Reapproved 2005), Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide, and Oxygen Concentrations in Emissions from Natural Gas-Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process Heaters Using Portable Analyzers, IBR approved for table 2 of subpart JJJJ of this part. (87)ASTM D6667-01, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for §60.335(b)(10)(ii). (88) ASTM D6667-04, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, IBR approved for §60.4415(a)(1)(ii). (89)ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound and Tbtal Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro Method), IBR approved for Appendix B to part 60, Performance Specification 12A, Section 8.6.2. (90)ASTM E168-67, 77, 92, General Techniques of Infrared Quantitative Analysis, IBR approved for §§60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f). (91) ASTM E169-63, 77, 93, General Techniques of Ultraviolet Quantitative Analysis, IBR approved for 

        §§60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f).

(92) ASTM E260-73, 91, 96, General Gas Chromatography Procedures, IBR approved for §§60.485a(d)(1), 60.593(b)(2), 60.593a(b)(2), and 60.632(f). (b) The following material is available for purchase from the Association of Official Analytical Chemists, 1111 North 19th Street, Suite 210, Arlington, VA 22209. (1) AOAC Method 9, Official Methods of Analysis of the Association of Official Analytical Chemists, 11th edition, 1970, pp. 11-12, IBR approved January 27, 1983 for §§60.204(b)(3), 60.214(b)(3), 60.224(b)(3), 60.234(b)(3). (c) The following material is available for purchase from the American Petroleum Institute, 1220 L Street NW., Washington, DC 20005. (1) API Publication 2517, Evaporation Loss from External Floating Roof Tanks, Second Edition, February 1980, IBR approved January 27, 1983, for §§60.111(i), 60.11 la(f), 60.11 la(f)(1) and 60.116b(e)(2)(i). (d) The following material is available for purchase from the Technical Association of the Pulp and Paper Industry (TAPPI), Dunwoody Park, Atlanta, GA 30341. (1) TAPPI Method T624 os-68, IBR approved January 27, 1983 for §60.285(d)(3). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-24 of 29

APPENDIX NSPS SUBPART A General Conditions (e) The following material is available for purchase from the Water Pollution Control Federation (WPCF), 2626 Pennsylvania Avenue NW., Washington, DC 20037. (1) Method 209A, Total Residue Dried at 103-105 'C, in Standard Methods for the Examination of Water and Wastewater, 15th Edition, 1980, IBR approved February 25, 1985 for §60.683(b). (f) The following material is available for purchase from the following address: Underwriter's Laboratories, Inc. (UL), 333 Pfingsten Road, Northbrook, IL 60062. (1) UL 103, Sixth Edition revised as of September 3, 1986, Standard for Chimneys, Factory-built, Residential Type and Building Heating Appliance. (g) The following material is available for purchase from the following address: West Coast Lumber Inspection Bureau, 6980 SW. Barnes Road, Portland, OR 97223. (1) West Coast Lumber Standard Grading Rules No. 16, pages 5-21 and 90 and 91, September 3, 1970, revised 1984. (h) The following material is available for purchase from the American Society of Mechanical Engineers (ASME), Three Park Avenue, New York, NY 10016-5990. (1) ASME QRO-1-1994, Standard for the Qualification and Certification of Resource Recovery Facility Operators, IBR approved for §§60.56a, 60.54b(a), 60.54b(b), 60.1185(a), 60.1185(c)(2), 60.1675(a), and 60.1675(c)(2). (2) ASME PTC 4.1-1964 (Reaffirmed 1991), Power Test Codes: Test Code for Steam Generating Units (with 1968 and 1969 Addenda), IBR approved for §§60.46b of subpart Db of this part, 60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)(3) and 60.1810(a)(3). (3) ASME Interim Supplement 19.5 on Instruments.and Apparatus: Application, Part II of Fluid Meters, 6th Edition (1971), EBR approved for §§60.58a(h)(6)(ii), 60.58b(i)(6)(ii), 60.1320(a)4), and 60.1810(a)(4). (4) ANSI/ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus], IBR approved for Tables 1 and 3 of subpart EEEE, Tables 2 and 4 of subpart FFFF, Table 2 of subpart JJJJ, and 

        §§60.4415(a)(2) and 60.4415(a)(3) of subpart KKKK of this part.

(i) Test Methods for Evaluating Solid Waste, Physical/Chemical Methods," EPA Publication SW-846 Third Edition (November 1986), as amended by Updates I (July 1992), II (September 1994), IIA (August, 1993), JIB (January 1995), and III (December 1996). This document may be obtained from the U.S. EPA, Office of Solid Waste and Emergency Response, Waste Characterization Branch, Washington, DC 20460, and is incorporated by reference for appendix A to part 60, Method 29, Sections 7.5.34; 9.2.1; 9.2.3; 10.2; 10.3; 11.1.1; 11.1.3; 13.2.1; 13.2.2; 13.3.1; and Table 29-3. (j) "Standard Methods for the Examination of Water and Wastewater," 16th edition, 1985. Method 303F: "Determination of Mercury by the Cold Vapor Technique." This document may be obtained from the American Public Health Association, 1015 18th Street, NW., Washington, DC 20036, and is incorporated by reference for appendix A to part 60, Method 29, Sections 9.2.3; 10.3; and 11.1.3. (k) This material is available for purchase from the American Hospital Association (AHA) Service, Inc., Post Office Box 92683, Chicago, Illinois 60675-2683. You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-124), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC. (1) An Ounce of Prevention: Waste Reduction Strategies for Health Care Facilities. American Society for Health Care Environmental Services of the American Hospital Association. Chicago, Illinois. 1993. AHA Catalog No. 057007. ISBN 0-87258-673-5. IBR approved for §60.35e and §60.55c. (1) This material is available for purchase from the National Technical Information Services, 5285 Port Royal Road, Springfield, Virginia 22161. You may inspect a copy at EPA's Air and Radiation Docket and Information Center (Docket A-91-61, Item IV-J-125), Room M-1500, 1200 Pennsylvania Ave., NW., Washington, DC. (1) OMB Bulletin No. 93-17: Revised Statistical Definitions for Metropolitan Areas. Office of Management and Budget, June 30, 1993. NTIS No. PB 93-192-664. IBR approved for §60.31e. (m) This material is available for purchase from at least one of the following addresses: The Gas Processors Association, 6526 East 60th Street, Tulsa, OK, 74145; or Information Handling Services, 15 Inverness Way East, PO Box 1154, Englewood, CO 80150-1154. You may inspect a copy at EPA's Air and Radiation Docket and Information Center, Room B 108, 1301 Constitution Ave., NW., Washington, DC 20460. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-25 of 29

APPENDIX NSPS SUBPART A General Conditions (1) Gas Processors Association Method 2377-86, Test for Hydrogen Sulfide and Carbon Dioxide in Natural Gas Using Length of Stain Tubes, IBR approved for §§60.334(h)(1), 60.4360, and 60.4415(a)(1)(ii). (2) [Reserved] (n) This material is available for purchase from IHS Inc., 15 Inverness Way East, Englewood, CO 80112. (1) International Organization for Standards 8178-4: 1996(E), Reciprocating Internal Combustion Engines-Exhaust Emission Measurement-Part 4: Test Cycles for Different Engine Applications, IBR approved for §60.4241(b). (2) [Reserved] [48 FR 3735, Jan. 27, 1983] Editorial Note: For Federal Register citations affecting §60.17, see the List of CFR Sections Affected, which appears in the Finding Aids section of the printed volume and on GPO Access. § 60.18 Generalcontrol device requirements. (a) Introduction.This section contains requirements for control devices used to comply with applicable subparts of parts 60 and 61. The requirements are placed here for administrative convenience and only apply to facilities covered by subparts referring to this section. (b) Flares.Paragraphs (c) through (f) apply to flares. (c) (1) Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. (2) Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f). (3) An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4) of this section, or adhering to the requirements in paragraph (c)(3)(i) of this section. (i) (A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume), or greater, and are designed for and operated with an exit velocity less than 37.2 mi/sec (122 ft/sec) and less than the velocity, Vmax. as determined by the following equation: Vmax=(XH2-Kj)* K 2 Where: Vmax = Maximum permitted velocity, m/sec. K, = Constant, 6.0 volume-percent hydrogen. K2 = Constant, 3.9(m/sec)/volume-percent hydrogen. XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in §60.17). (B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (f)(4) of this section. (ii) Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value of the gas being combusted shall be determined by the methods specified in paragraph (f)(3) of this section. (4) (i) Steam-assisted and nonassisted flares shall be designed for and operated with an exit velocity, as determined by the methods specified in paragraph (0(4) of this section, less than 18.3 in/sec (60 ft/sec), except as provided in paragraphs (c)(4) (ii) and (iii) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-26 of 29

APPENDIX NSPS SUBPART A General Conditions (ii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the methods specified in paragraph (f)(4), equal to or greater than 18.3 m/sec (60 ft/sec) but less than 122 m/sec (400 ft/sec) are allowed if the net heating value of the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf). (iii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the methods specified in paragraph (f)(4), less than the velocity, Vmax, as determined by the method specified in paragraph (f)(5), and less than 122 m/sec (400 ft/sec) are allowed. (5) Air-assisted flares shall be designed and operated with an exit velocity less than the velocity, Vmax, as determined by the method specified in paragraph (f)(6). (6) Flares used to comply with this section shall be steam-assisted, air-assisted, or nonassisted. (d) Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control devices. (e) Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them. (f) (1) Method 22 of appendix A to this part shall be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22. (2) The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. (3) The net heating value of the gas being combusted in a flare shall be calculated using the following equation: n 

                                                            . K t CiH$
                                                            *T View or download PDF where:

HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of off gas is based on combustion at 25 

        'C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 'C; K = Constant.                  I    rg
                                                                     *le}      MJ 1.740 x 10"         p-       scio I"C) 1' where the standard temperature for           ile og    is 20'C; scm View or download PDF Ci = Concentration of sample component i in ppm on a wet basis, as measured for organics by Reference Method 18 and measured for hydrogen and carbon monoxide by ASTM D1946-77 or 90 (Reapproved 1994) (Incorporated by reference as specified in §60.17); and Hi = Net heat of combustion of sample component i, kcal/g mole at 25 'C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95 (incorporated by reference as specified in §60.17) if published values are not available or cannot be calculated.

(4) The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross sectional area of the flare tip. (5) The maximum permitted velocity, Vm.x, for flares complying with paragraph (c)(4)(iii) shall be determined by the following equation. Log10(Vmax=(HT+28.8)/31.7 Vmax = Maximum permitted velocity, M/sec 28.8 = Constant Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-27 of 29

APPENDIX NSPS SUBPART A General Conditions 31.7 = Constant HT = The net heating value as determined in paragraph (0(3). (6) The maximum permitted velocity, V ,,,, for air-assisted flares shall be determined by the following equation. Vmjx = 8.706+0.7084 (HT) Vmax = Maximum permitted velocity, m/sec 8.706 = Constant 0.7084 = Constant HT = The net heating value as determined in paragraph (0(3). [51 FR 2701, Jan. 21, 1986, as amended at 63 FR 24444, May 4, 1998; 65 FR 61752, Oct. 17, 2000] § 60.19 Generalnotification and reportingrequirements. (a) For the purposes of this part, time periods specified in days shall be measured in calendar days, even if the word "calendar" is absent, unless otherwise specified in an applicable requirement. (b) For the purposes of this part, if an explicit postmark deadline is not specified in an applicable requirement for the submittal of a notification, application, report, or other written communication to the Administrator, the owner or operator shall postmark the submittal on or before the number of days specified in the applicable requirement. For example, if a notification must be submitted 15 days before a particular event is scheduled to take place, the notification shall be postmarked on or before 15 days preceding the event; likewise, if a notification must be submitted 15 days after a particular event takes place, the notification shall be delivered or postmarked on or before 15 days following the end of the event. The use of reliable non-Government mail carriers that provide indications of verifiable delivery of information required to be submitted to the Administrator, similar to the postmark provided by the U.S. Postal Service, or alternative means of delivery, including the use of electronic media, agreed to by the permitting authority, is acceptable. (c) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. Procedures governing the implementation of this provision are specified in paragraph (f) of this section. (d) If an owner or operator of an affected facility in a State with delegated authority is required to submit periodic reports under this part to the State, and if the State has an established timeline for the submission of periodic reports that is consistent with the reporting frequency(ies) specified for such facility under this part, the owner or operator may change the dates by which periodic reports under this part shall be submitted (without changing the frequency of reporting) to be consistent with the State's schedule by mutual agreement between the owner or operator and the State. The allowance in the previous sentence applies in each State beginning 1 year after the affected facility is required to be in compliance with the applicable subpart in this part. Procedures governing the implementation of this provision are specified in paragraph (f) of this section. (e) If an owner or operator supervises one or more stationary sources affected by standards set under this part and standards set under part 61, part 63, or both such parts of this chapter, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State with an approved permit program) a common schedule on which periodic reports required by each applicable standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the stationary source is required to be in compliance with the applicable subpart in this part, or 1 year after the stationary source is required to be in compliance with the applicable 40 CFR part 61 or part 63 of this chapter standard, whichever is latest. Procedures governing the implementation of this provision are specified in paragraph (f) of this section. (f) (1) (i) Until an adjustment of a time period or postmark deadline has been approved by the Administrator under paragraphs (0(2) and (0(3) of this section, the owner or operator of an affected facility remains strictly subject to the requirements of this part. (ii) An owner or operator shall request the adjustment provided for in paragraphs (f)(2) and (f)(3) of this section each time he or she wishes to change an applicable time period or postmark deadline specified in this part. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-28 of 29

APPENDIX NSPS SUBPART A General Conditions (2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. An owner or operator who wishes to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The owner or operator shall include in the request whatever information he or she considers useful to convince the Administrator that an adjustment is warranted. (3) If, in the Administrator's judgment, an owner or operator's request for an adjustment to a particular time period or postmark deadline is warranted, the Administrator will approve the adjustment. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request. (4) If the Administrator is unable to meet a specified deadline, he or she will notify the owner or operator of any significant delay and inform the owner or operator of the amended schedule. [59 FR 12428, Mar. 16, 1994, as amended at 64 FR 7463, Feb. 12, 1998] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page A-29 of 29

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 Title 40: Protection of Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES Subpart D-Standardsof Performancefor Fossil-Fuel-FiredSteam Generatorsfor Which ConstructionIs Commenced After August 17, 1971 Source: 72 FR 32717, June 13, 2007, unless otherwise noted. § 60.40 Applicability and designation of affected facility. (a) The affected facilities to which the provisions of this subpart apply are: (1) Each fossil-fuel-fired steam generating unit of more than 73 megawatts (MW) heat input rate (250 million British thermal units per hour (MMBtu/hr)). (2) Each fossil-fuel and wood-residue-fired steam generating unit capable of firing fossil fuel at a heat input rate of more than 73 MW (250 MMBtu/hr). (b) Any change to an existing fossil-fuel-fired steam generating unit to accommodate the use of combustible materials, other than fossil fuels as defined in this subpart, shall not bring that unit under the applicability of this subpart. (c) Except as provided in paragraph (d) of this section, any facility under paragraph (a) of this section that commenced construction or modification after August 17, 1971, is subject to the requirements of this subpart. (d) The requirements of §§60.44 (a)(4), (a)(5), (b) and (d), and 60.45(f)(4)(vi) are applicable to lignite-fired steam generating units that commenced construction or modification after December 22, 1976. (e) Any facility covered under subpart Da is not covered under this subpart. § 60.41 Definitions. As used in this subpart, all terms not defined herein shall have the meaning given them in the Act, and in subpart A of this part. Boiler operatingday means a 24-hour period between 12 midnight and the following midnight during which any fuel is combusted at any time in the steam-generating unit. It is not necessary for fuel to be combusted the entire 24-hour period. Coal means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite by ASTM D388 (incorporated by reference, see §60.17). Coal refuse means waste-products of coal mining, cleaning, and coal preparation operations (e.g. culm, gob, etc.) containing coal, matrix material, clay, and other organic and inorganic material. Fossilfuel means natural gas, petroleum, coal, and any form of solid, liquid, or gaseous fuel derived from such materials for the purpose of creating useful heat. Fossilfuel and wood residue-firedsteam generatingunit means a furnace or boiler used in the process of burning fossil fuel and wood residue for the purpose of producing steam by heat transfer. Fossil-fuel-fired steam generating unit means a furnace or boiler used in the process of burning fossil fuel for the purpose of producing steam by heat transfer. Wood residue means bark, sawdust, slabs, chips, shavings, mill trim, and other wood products derived from wood processing and forest management operations. § 60.42 Standardforparticulatematter (PM). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-1 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (a) On and after the date on which the performance test required to be conducted by §60.8 is completed, no owner or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from any affected facility any gases that: (1) Contain PM in excess of 43 nanograms per joule (ng/J) heat input (0.10 lb/MMBtu) derived from fossil fuel or fossil fuel and wood residue. (2) Exhibit greater than 20 percent opacity except for one six-minute period per hour of not more than 27 percent opacity. (b)(1) On or after December 28, 1979, no owner or operator shall cause to be discharged into the atmosphere from the Southwestern Public Service Company's Harrington Station #1, in Amarillo, TX, any gases which exhibit greater than 35 percent opacity, except that a maximum or 42 percent opacity shall be permitted for not more than 6 minutes in any hour. (2) Interstate Power Company shall not cause to be discharged into the atmosphere from its Lansing Station Unit No. 4 in Lansing, IA, any gases which exhibit greater than 32 percent opacity, except that a maximum of 39 percent opacity shall be permitted for not more than six minutes in any hour. (c) As an alternate to meeting the requirements of paragraph (a) of this section, an owner or operator that elects to install, calibrate, maintain, and operate a continuous emissions monitoring systems (CEMS) for measuring PM emissions can petition the Administrator (in writing) to comply with §60.42Da(a) of subpart Da of this part. If the Administrator grants the petition, the source will from then on (unless the unit is modified or reconstructed in the future) have to comply with the requirements in §60.43Da(a) of subpart Da of this part. [60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5077, Jan. 28, 2009] § 60.43 Standardfor sulfur dioxide (S02). (a) Except as provided under paragraph (d) of this section, on and after the date on which the performance test required to be conducted by §60.8 is completed, no owner or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from any affected facility any gases that contain SO 2in excess of: (1) 340 ng/J heat input (0.80 lb/MMBtu) derived from liquid fossil fuel or liquid fossil fuel and wood residue. (2) 520 ng/J heat input (1.2 lb/MMBtu) derived from solid fossil fuel or solid fossil fuel and wood residue, except as provided in paragraph (e) of this section. (b) Except as provided under paragraph (d) of this section, when different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) shall be determined by proration using the following formula: PS y (340) + z (5 20') Where: PSs 0 2= Prorated standard for S02 when burning different fuels simultaneously, in ng/J heat input derived from all fossil fuels or from all fossil fuels and wood residue fired; y = Percentage of total heat input derived from liquid fossil fuel; and z = Percentage of total heat input derived from solid fossil fuel. (c) Compliance shall be based on the total heat input from all fossil fuels burned, including gaseous fuels. (d) As an alternate to meeting the requirements of paragraphs (a) and (b) of this section, an owner or operator can petition the Administrator (in writing) to comply with §60.43Da(i)(3) of subpart Da of this part or comply with §60.42b(k)(4) of subpart Db of this part, as applicable to the affected source. If the Administrator grants the petition, the source will from then on Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-2 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (unless the unit is modified or reconstructed in the future) have to comply with the requirements in §60.43Da(i)(3) of subpart Da of this part or §60.42b(k)(4) of subpart Db of this part, as applicable to the affected source. (e) Units 1 and 2 (as defined in appendix G of this part) at the Newton Power Station owned or operated by the Central Illinois Public Service Company will be in compliance with paragraph (a)(2) of this section if Unit 1 and Unit 2 individually comply with paragraph (a)(2) of this section or if the combined emission rate from Units 1 and 2 does not exceed 470 ng/J (1.1 lb/MMBtu) combined heat input to Units 1 and 2. [60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5077, Jan. 28, 2009] § 60.44 Standardfor nitrogen oxides (NOX). (a) Except as provided under paragraph (e) of this section, on and after the date on which the performance test required to be conducted by §60.8 is completed, no owner or operator subject to the provisions of this subpart shall cause to be discharged into the atmosphere from any affected facility any gases that contain NOx, expressed as NO 2 in excess of: (1) 86 ng/J heat input (0.20 lb/MMBtu) derived from gaseous fossil fuel. (2) 129 ng/J heat input (0.30 lb/MMBtu) derived from liquid fossil fuel, liquid fossil fuel and wood residue, or gaseous fossil fuel and wood residue. (3) 300 ng/J heat input (0.70 lb/MMBtu) derived from solid fossil fuel or solid fossil fuel and wood residue (except lignite or a solid fossil fuel containing 25 percent, by weight, or more of coal refuse). (4) 260 ng/J heat input (0.60 lb MMBtu) derived from lignite or lignite and wood residue (except as provided under paragraph (a)(5) of this section). (5) 340 ng/J heat input (0.80 lb MMBtu) derived from lignite which is mined in North Dakota, South Dakota, or Montana and which is burned in a cyclone-fired unit. (b) Except as provided under paragraphs (c), (d), and (e) of this section, when different fossil fuels are burned simultaneously in any combination, the applicable standard (in ng/J) is determined by proration using the following formula: w (260) + x (86) + y 0 30) + z (300) S(w + x + y + z) Where: PSNOx= Prorated standard for NOx when burning different fuels simultaneously, in ng/J heat input derived from all fossil fuels fired or from all fossil fuels and wood residue fired; w = Percentage of total heat input derived from lignite; x = Percentage of total heat input derived from gaseous fossil fuel; y = Percentage of total heat input derived from liquid fossil fuel; and z = Percentage of total heat input derived from solid fossil fuel (except lignite). (c) When a fossil fuel containing at least 25 percent, by weight, of coal refuse is burned in combination with gaseous, liquid, or other solid fossil fuel or wood residue, the standard for NOx does not apply. (d) Except as provided under paragraph (e) of this section, cyclone-fired units which burn fuels containing at least 25 percent of lignite that is mined in North Dakota, South Dakota, or Montana remain subject to paragraph (a)(5) of this section regardless of the types of fuel combusted in combination with that lignite. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-3 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (e) As an alternate to meeting the requirements of paragraphs (a), (b), and (d) of this section, an owner or operator can petition the Administrator (in writing) to comply with §60.44Da(e)(3) of subpart Da of this part. If the Administrator grants the petition, the source will from then on (unless the unit is modified or reconstructed in the future) have to comply with the requirements in §60.44Da(e)(3) of subpart Da of this part. § 60.45 Emissions andfuel monitoring. (a) Each owner or operator shall install, calibrate, maintain, and operate continuous opacity monitoring system (COMS) for measuring opacity and a CEMS for measuring SO2emissions, NOx emissions, and either oxygen (02) or carbon dioxide (C02) except as provided in paragraph (b) of this section. (b) Certain of the CEMS requirements under paragraph (a) of this section do not apply to owners or operators under the following conditions: (1) For a fossil-fuel-fired steam generator that burns only gaseous or liquid fossil fuel (excluding residual oil) with potential SO2emissions rates of 26 ng/J (0.060 lb/MMBtu) or less and that does not use post-combustion technology to reduce emissions of SO2or PM, CEMS for measuring the opacity of emissions and S02 emissions are not required if the owner or operator monitors SO2emissions by fuel sampling and analysis or fuel receipts. (2) For a fossil-fuel-fired steam generator that does not use a flue gas desulfurization device, a CEMS for measuring SO 2emissions is not required if the owner or operator monitors SO 2 emissions by fuel sampling and analysis. (3) Notwithstanding §60.13(b), installation of a CEMS for NOx may be delayed until after the initial performance tests under §60.8 have been conducted. If the owner or operator demonstrates during the performance test that emissions of NOx are less than 70 percent of the applicable standards in §60.44, a CEMS for measuring NOx emissions is not required. If the initial performance test results show that NOx emissions are greater than 70 percent of the applicable standard, the owner or operator shall install a CEMS for NOx within one year after the date of the initial performance tests under §60.8 and comply with all other applicable monitoring requirements under this part. (4) If an owner or operator does not install any CEMS for sulfur oxides and NOx, as provided under paragraphs (b)(1) and (b)(3) or paragraphs (b)(2) and (b)(3) of this section a CEMS for measuring either O 2or CO 2is not required. (5) An owner or operator may petition the Administrator (in writing) to install a PM CEMS as an alternative to the CEMS for monitoring opacity emissions. (6) A CEMS for measuring the opacity of emissions is not required for a fossil fuel-fired steam generator that does not use post-combustion technology (except a wet scrubber) for reducing PM, SO 2 , or carbon monoxide (CO) emissions, burns only gaseous fuels or fuel oils that contain less than or equal to 0.30 weight percent sulfur, and is operated such that emissions of CO to the atmosphere from the affected source are maintained at levels less than or equal to 0.15 lb/MMBtu on a boiler operating day average basis. Owners and operators of affected sources electing to comply with this paragraph must demonstrate compliance according to the procedures specified in paragraphs (b)(6)(i) through (iv) of this section. (i) You must monitor CO emissions using a CEMS according to the procedures specified in paragraphs (b)(6)(i)(A) through (D) of this section. (A) The CO CEMS must be installed, certified, maintained, and operated according to the provisions in §60.58b(i)(3) of subpart Eb of this part. (B) Each 1-hour CO emissions average is calculated using the data points generated by the CO CEMS expressed in parts per million by volume corrected to 3 percent oxygen (dry basis). (C) At a minimum, valid 1-hour CO emissions averages must be obtained for at least 90 percent of the operating hours on a 30-day rolling average basis. The 1-hour averages are calculated using the data points required in §60.13(h)(2). (D) Quarterly accuracy determinations and daily calibration drift tests for the CO CEMS must be performed in accordance with procedure 1 in appendix F of this part. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-4 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (ii) You must calculate the 1-hour average CO emissions levels for each boiler operating day by multiplying the average hourly CO output concentration measured by the CO CEMS times the corresponding average hourly flue gas flow rate and divided by the corresponding average hourly heat input to the affected source. The 24-hour average CO emission level is determined by calculating the arithmetic average of the hourly CO emission levels computed for each boiler operating day. (iii) You must evaluate the preceding 24-hour average CO emission level each boiler operating day excluding periods of affected source startup, shutdown, or malfunction. If the 24-hour average CO emission level is greater than 0.15 lb/MMBtu, you must initiate investigation of the relevant equipment and control systems within 24 hours of the first discovery of the high emission incident and, take the appropriate corrective action as soon as practicable to adjust control settings or repair equipment to reduce the 24-hour average CO emission level to 0.15 lb/MMBtu or less. (iv) You must record the CO measurements and calculations performed according to paragraph (b)(6) of this section and any corrective actions taken. The record of corrective action taken must include the date and time during which the 24-hour average CO emission level was greater than 0.15 lb/MMBtu, and the date, time, and description of the corrective action. (7) The owner or operator of an affected facility subject to an opacity standard under §60.42 and that elects to not install a COMS because the affected facility burns only fuels as specified under paragraph (b)(1) of this section, monitors PM emissions as specified under paragraph (b)(5) of this section, or monitors CO emissions as specified under paragraph (b)(6) of this section shall conduct a performance test using Method 9 of appendix A-4 of this part and the procedures in §60.11 to demonstrate compliance with the applicable limit in §60.42 and shall comply with either paragraphs (b)(7)(i), (b)(7)(ii), or (b)(7)(iii) of this section. If during the initial 60 minutes of observation all 6-minute averages are less than 10 percent and all individual 15-second observations are less than or equal to 20 percent, the observation period may be reduced from 3 hours to 60 minutes. (i) Except as provided in paragraph (b)(7)(ii) or (b)(7)(iii) of this section, the owner or operator shall conduct subsequent Method 9 of appendix A-4 of this part performance tests using the procedures in paragraph (b)(7) of this section according to the applicable schedule in paragraphs (b)(7)(i)(A) through (b)(7)(i)(D) of this section, as determined by the most recent Method 9 of appendix A-4 of this part performance test results. (A) If no visible emissions are observed, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 12 calendar months from the date that the most recent performance test was conducted; (B) If visible emissions are observed but the maximum 6-minute average opacity is less than or equal to 5 percent, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 6 calendar months from the date that the most recent performance test was conducted; (C) If the maximum 6-minute average opacity is greater than 5 percent but less than or equal to 10 percent, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 3 calendar months from the date that the most recent performance test was conducted; or (D) If the maximum 6-minute average opacity is greater than 10 percent, a subsequent Method 9 of appendix A-4 of this part performance test must be completed within 30 calendar days from the date that the most recent performance test was conducted. (ii) If the maximum 6-minute opacity is less than 10 percent during the most recent Method 9 of appendix A-4 of this part performance test, the owner or operator may, as an alternative to performing subsequent Method 9 of appendix A-4 of this part performance test, elect to perform subsequent monitoring using Method 22 of appendix A-7 of this part according to the procedures specified in paragraphs (b)(7)(ii)(A) and (B) of this section. (A) The owner or operator shall conduct 10 minute observations (during normal operation) each operating day the affected facility fires fuel for which an opacity standard is applicable using Method 22 of appendix A-7 of this part and demonstrate that the sum of the occurrences of any visible emissions is not in excess of 5 percent of the observation period ( i.e. , 30 seconds per 10 minute period). If the sum of the occurrence of any visible emissions is greater than 30 seconds during the initial 10 minute observation, immediately conduct a 30 minute observation. If the sum of the occurrence of visible emissions is greater than 5 percent of the observation period ( i.e. , 90 seconds per 30 minute period) the owner or operator shall either document and adjust the operation of the facility and demonstrate within 24 hours that the sum of the occurrence of visible emissions is equal to or less than 5 percent during a 30 minute observation ( i.e. , 90 seconds) or conduct a new Method 9 of Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-5 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 appendix A-4 of this part performance test using the procedures in paragraph (b)(7) of this section within 30 calendar days according to the requirements in §60.46(b)(3). (B) If no visible emissions are observed for 30 operating days during which an opacity standard is applicable, observations can be reduced to once every 7 operating days during which an opacity standard is applicable. If any visible emissions are observed, daily observations shall be resumed. (iii) If the maximum 6-minute opacity is less than 10 percent during the most recent Method 9 of appendix A-4 of this part performance test, the owner or operator may, as an alternative to performing subsequent Method 9 of appendix A-4 performance tests, elect to perform subsequent monitoring using a digital opacity compliance system according to a site-specific monitoring plan approved by the Administrator. The observations shall be similar, but not necessarily identical, to the requirements in paragraph (b)(7)(ii) of this section. For reference purposes in preparing the monitoring plan, see OAQPS "Determination of Visible Emission Opacity from Stationary Sources Using Computer-Based Photographic Analysis Systems." This document is available from the U.S. Environmental Protection Agency (U.S. EPA); Office of Air Quality and Planning Standards; Sector Policies and Programs Division; Measurement Policy Group (D243-02), Research Triangle Park, NC 27711. This document is also available on the Technology Transfer Network (TTN) under Emission Measurement Center Preliminary Methods. (c) For performance evaluations under §60.13(c) and calibration checks under §60.13(d), the following procedures shall be used: (1) Methods 6, 7, and 3B of appendix A of this part, as applicable, shall be used for the performance evaluations of SO 2and NOx continuous monitoring systems. Acceptable alternative methods for Methods 6, 7, and 3B of appendix A of this part are given in §60.46(d). (2) Sulfur dioxide or nitric oxide, as applicable, shall be used for preparing calibration gas mixtures under Performance Specification 2 of appendix B to this part. (3) For affected facilities burning fossil fuel(s), the span value for a continuous monitoring system measuring the opacity of emissions shall be 80, 90, or 100 percent. For a continuous monitoring system measuring sulfur oxides or NOx the span value shall be determined using one of the following procedures: (i) Except as provided under paragraph (c)(3)(ii) of this section, SO 2 and NOx span values shall be determined as follows: In parts per million Fossil fuel Span value for SO 2 Span value for NOx Gas CI) 500. Liquid 1,000 500. Solid 1,500 1,000. Combinations 1,000y + 1,500z 500 (x + y) + 1,000z. 'Not applicable. Where: x = Fraction of total heat input derived from gaseous fossil fuel; y = Fraction of total heat input derived from liquid fossil fuel; and z = Fraction of total heat input derived from solid fossil fuel. (ii) As an alternative to meeting the requirements of paragraph (c)(3)(i) of this section, the owner or operator of an affected facility may elect to use the SO 2and NOx span values determined according to sections 2.1.1 and 2.1.2 in appendix A to part 75 of this chapter. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-6 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (4) All span values computed under paragraph (c)(3)(i) of this section for burning combinations of fossil fuels shall be rounded to the nearest 500 ppm. Span values that are computed under paragraph (c)(3)(ii) of this section shall be rounded off according to the applicable procedures in section 2 of appendix A to part 75 of this chapter. (5) For a fossil-fuel-fired steam generator that simultaneously burns fossil fuel and nonfossil fuel, the span value of all CEMS shall be subject to the Administrator's approval. (d) [Reserved] (e) For any CEMS installed under paragraph (a) of this section, the following conversion procedures shall be used to convert the continuous monitoring data into units of the applicable standards (ng/J, lb/MMBtu): (1) When a CEMS for measuring O 2 is selected, the measurement of the pollutant concentration and O 2concentration shall each be on a consistent basis (wet or dry). Alternative procedures approved by the Administrator shall be used when measurements are on a wet basis. When measurements are on a dry basis, the following conversion procedure shall be used: E =ECF(IF "" 20.9 (20.9-%02) Where E, C, F, and %O 2are determined under paragraph (f) of this section. (2) When a CEMS for measuring CO 2is selected, the measurement of the pollutant concentration and CO 2 concentration shall each be on a consistent basis (wet or dry) and the following conversion procedure shall be used: ECF ( 100) 

            %C0 2 )

Where E, C, F. and %CO 2are determined under paragraph (f) of this section. (f) The values used in the equations under paragraphs (e)(1) and (2) of this section are derived as follows: (1) E = pollutant emissions, ng/J (lb/MMBtu). (2) C = pollutant concentration, ng/dscm (lb/dscf), determined by multiplying the average concentration (ppm) for each one-hour period by 4.15 x 104 M ng/dscm per ppm (2.59 x 10- 9M lb/dscf per ppm)'where M = pollutant molecular weight, gig-mole (lb/lb-mole). M = 64.07 for SO 2and 46.01 for NOx. (3) %02, %CO2 = O 2or CO 2 volume (expressed as percent), determined with equipment specified under paragraph (a) of this section. (4) F, Fc= a factor representing a ratio of the volume of dry flue gases generated to the calorific value of the fuel combusted (F), and a factor representing a ratio of the volume of CO 2generated to the calorific value of the fuel combusted (FJ), respectively. Values of F and F, are given as follows: (i) For anthracite coal as classified according to ASTM D388 (incorporated by reference, see §60.17), F = 2,723 x 10-i 7dscm/J (10,140 dscf/MMBtu) and Fc= 0.532 x 10-17SCM COJJ (1,980 scf CO 2/MMBtu). (ii) For subbituminous and bituminous coal as classified according to ASTM D388 (incorporated by reference, see §60.17), F = 2.637 x 10-7dscm/J (9,820 dscf/MMBtu) and F,= 0.486 x 10- 7scm CO2/J (1,810 scf CO 2/MMBtu). (iii) For liquid fossil fuels including crude, residual, and distillate oils, F = 2.476 x 10-7dscm/J (9,220 dscf/MMBtu) and Fo= 0.384 x 10- 7scm CO 2/J (1,430 scf CO 2/IMMBtu). (iv) For gaseous fossil fuels, F = 2.347 x 10-7dscm/J (8,740 dscf/MMBtu). For natural gas, propane, and butane fuels, Fc= 0.279 x 10- 7scm C0 2/J (1,040 scf C0 2 /MMBtu) for natural gas, 0.322 x 10- 7scm CO2J (1,200 scf CO 2/MMBtu) for propane, and 0.338 x 10- 7 scm C0 2/J (1,260 scf CO 2/MMBtu) for butane. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-7 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (v) For bark F = 2.589 x 10-Tdscm/J (9,640 dscf/MMBtu) and F,= 0.500 x 10- 7scm C0 2/J (1,840 scf CO 2/MMBtu). For wood residue other than bark F = 2.492 x 10- 7dscm/J (9,280 dscf/MMBtu) and F,= 0.494 x 10- 7scm C0 2/J (1,860 scf CO 2/MMBtu). (vi) For lignite coal as classified accordiný to ASTM D388 (incorporated by reference, see §60.17), F = 2.659 x 10-7dscm/J (9,900 dscf/MMBtu) and F,= 0.516 x 10- scm CO2/J (1,920 scf CO2/MMBtu). (5) The owner or operator may use the following equation to determine an F factor (dscm/J or dscf/MMBtu) on a dry basis (if it is desired to calculate F on a wet basis, consult the Administrator) or F, factor (scm C0 2/J, or scf CO 2/MMBtu) on either basis in lieu of the F or F, factors specified in paragraph (f)(4) of this section: F 10-'[227.2 (%/.H) + 95.5 (%C) + 35.6 (%AS) +8.7 (%N) - 28.7 (/0)] GCV 2.0 x-10-(%C) GCV (SI units) F =10-' [3.64 (%H) +1.53 (%/.C)+ 0.57 (%oS) +0.14 (%N) - 0.46 (%O)] GCV (English uiits) F. =20.0 (%C) GCV (S Iunits) 

                               ,    321x10' (%C)

GCV (Engishiunits) (i) %H, %C, %S, %N, and %0 are content by weight of hydrogen, carbon, sulfur, nitrogen, and 0 2 (expressed as percent), respectively, as determined on the same basis as GCV by ultimate analysis of the fuel fired, using ASTM D3178 or D3176 (solid fuels), or computed from results using ASTM D1 137, D1945, or D1946 (gaseous fuels) as applicable. (These five methods are incorporated by reference, see §60.17.) (ii) GVC is the gross calorific value (kJ/kg, Btu/lb) of the fuel combusted determined by the ASTM test methods D2015 or D5865 for solid fuels and D1826 for gaseous fuels as applicable. (These three methods are incorporated by reference, see §60.17.) (iii) For affected facilities which fire both fossil fuels and nonfossil fuels, the F or F, value shall be subject to the Administrator's approval. (6) For affected facilities firing combinations of fossil fuels or fossil fuels and wood residue, the F or F, factors determined by paragraphs (f)(4) or (f)(5) of this section shall be prorated in accordance with the applicable formula as follows: F =ZX1 F. or Fý = EXi(Fý), W, i-1 Where: Xi= Fraction of total heat input derived from each type of fuel (e.g. natural gas, bituminous coal, wood residue, etc.); Fi or (Fc)i= Applicable F or Fc factor for each fuel type determined in accordance with paragraphs (f)(4) and (0(5) of this section; and n = Number of fuels being burned in combination. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-8 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (g) Excess emission and monitoring system performance reports shall be submitted to the Administrator semiannually for each six-month period in the calendar year. All semiannual reports shall be postmarked by the 30th day following the end of each six-month period. Each excess emission and MSP report shall include the information required in §60.7(c). Periods of excess emissions and monitoring systems (MS) downtime that shall be reported are defined as follows: (1) Opacity. Excess emissions are defined as any six-minute period during which the average opacity of emissions exceeds 20 percent opacity, except that one six-minute average per hour of up to 27 percent opacity need not be reported. (i) For sources subject to the opacity standard of §60.42(b)(1), excess emissions are defined as any six-minute period during which the average opacity of emissions exceeds 35 percent opacity, except that one six-minute average per hour of up to 42 percent opacity need not be reported. (ii) For sources subject to the opacity standard of §60.42(b)(2), excess emissions are defined as any six-minute period during which the average opacity of emissions exceeds 32 percent opacity, except that one six-minute average per hour of up to 39 percent opacity need not be reported. (2) Sulfur dioxide. Excess emissions for affected facilities are defined as: (i) For affected facilities electing not to comply with §60.43(d), any three-hour period during which the average emissions (arithmetic average of three contiguous one-hour periods) of SO 2as measured by a CEMS exceed the applicable standard in §60.43; or (ii) For affected facilities electing to comply with §60.43(d), any 30 operating day period during which the average emissions (arithmetic average of all one-hour periods during the 30 operating days) of SO 2as measured by a CEMS exceed the applicable standard in §60.43. Facilities complying with the 30-day SO 2standard shall use the most current associated SO 2 compliance and monitoring requirements in §§60.48Da and 60.49Da of subpart Da of this part or §§60.45b and 60.47b of subpart Db of this part, as applicable. (3) Nitrogen oxides. Excess emissions for affected facilities using a CEMS for measuring NOx are defined as: (i) For affected facilities electing not to comply with §60.44(e), any three-hour period during which the average emissions (arithmetic average of three contiguous one-hour periods) exceed the applicable standards in §60.44; or (ii) For affected facilities electing to comply with §60.44(e), any 30 operating day period during which the average emissions (arithmetic average of all one-hour periods during the 30 operating days) of NOx as measured by a CEMS exceed the applicable standard in §60.44. Facilities complying with the 30-day NOx standard shall use the most current associated NOx compliance and monitoring requirements in §§60.48Da and 60.49Da of subpart Da of this part. (4) Particulatematter. Excess emissions for affected facilities using a CEMS for measuring PM are defined as any boiler operating day period during which the average emissions (arithmetic average of all operating one-hour periods) exceed the applicable standards in §60.42. Affected facilities using PM CEMS must follow the most current applicable compliance and monitoring provisions in §§60.48Da and 60.49Da of subpart Da of this part. (h) The owner or operator of an affected facility subject to the opacity limits in §60.42 that elects to monitor emissions according to the requirements in §60.45(b)(7) shall maintain records according to the requirements specified in paragraphs (h)(1) through (3) of this section, as applicable to the visible emissions monitoring method used. (1) For each performance test conducted using Method 9 of appendix A-4 of this part, the owner or operator shall keep the records including the information specified in paragraphs (h)(1)(i) through (iii) of this section. (i) Dates and time intervals of all opacity observation periods; (ii) Name, affiliation, and copy of current visible emission reading certification for each visible emission observer participating in the performance test; and (iii) Copies of all visible emission observer opacity field data sheets; Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-9 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (2) For each performance test conducted using Method 22 of appendix A-4 of this part, the owner or operator shall keep the records including the information specified in paragraphs (h)(2)(i) through (iv) of this section. (i) Dates and time intervals of all visible emissions observation periods; (ii) Name and affiliation for each visible emission observer participating in the performance test; (iii) Copies of all visible emission observer opacity field data sheets; and (iv) Documentation of any adjustments made and the time the adjustments were completed to the affected facility operation by the owner or operator to demonstrate compliance with the applicable monitoring requirements. (3) For each digital opacity compliance system, the owner or operator shall maintain records and submit reports according to the requirements specified in the site-specific monitoring plan approved by the Administrator. [60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5077, Jan. 28, 2009] § 60.46 Test methods and procedures. (a) In conducting the performance tests required in §60.8, and subsequent performance tests as requested by the EPA Administrator, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in §60.8(b). Acceptable alternative methods and procedures are given in paragraph (d) of this section. (b) The owner or operator shall determine compliance with the PM, SO 2, and NOx standards in §§60.42, 60.43, and 60.44 as follows: (1) The emission rate (E) of PM, SO 2 , or NOx shall be computed for each run using the following equation: E = CF,: ((20920.9-%0,) Where: E = Emission rate of pollutant, ng/J (lb/million Btu); C = Concentration of pollutant, ng/dscm (lb/dscf); %02= O 2concentration, percent dry basis; and Fd= Factor as determined from Method 19 of appendix A of this part. (2) Method 5 of appendix A of this part shall be used to determine the PM concentration (C) at affected facilities without wet flue-gas-desulfurization (FGD) systems and Method 5B of appendix A of this part shall be used to determine the PM concentration (C) after FGD systems. (i) The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). The probe and filter holder heating systems in the sampling train shall be set to provide an average gas temperature of 160+/-14 °C (320+/-25 OF). (ii) The emission rate correction factor, integrated or grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration (%02). The O 2sample shall be obtained simultaneously with, and at the same traverse points as, the particulate sample. If the grab sampling procedure is used, the O 2 concentration for the run shall be the arithmetic mean of the sample O 2 concentrations at all traverse points. (iii) If the particulate run has more than 12 traverse points, the O 2traverse points may be reduced to 12 provided that Method 1 of appendix A of this part is used to locate the 12 O2traverse points. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-10 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 (3) Method 9 of appendix A of this part and the procedures in §60.11 shall be used to determine opacity. (4) Method 6 of appendix A of this part shall be used to determine the SO 2concentration. (i) The sampling site shall be the same as that selected for the particulate sample. The sampling location in the duct shall be at the centroid of the cross section or at a point no closer to the walls than 1 m (3.28 ft). The sampling time and sample volume for each sample run shall be at least 20 minutes and 0.020 dscm (0.71 dscf). Two samples shall be taken during a 1-hour period, with each sample taken within a 30-minute interval. (ii) The emission rate correction factor, integrated sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O 2 concentration (%02). The O 2sample shall be taken simultaneously with, and at the same point as, the SO 2 sample. The SO 2emission rate shall be computed for each pair of SO 2and O 2samples. The SO 2emission rate (E) for each run shall be the arithmetic mean of the results of the two pairs of samples. (5) Method 7 of appendix A of this part shall be used to determine the NOx concentration. (i) The sampling site and location shall be the same as for the SO 2sample. Each run shall consist of four grab samples, with each sample taken at about 15-minute intervals. (ii) For each NOx sample, the emission rate correction factor, grab sampling and analysis procedure of Method 3B of appendix A of this part shall be used to determine the O2 concentration (%02). The sample shall be taken simultaneously with, and at the same point as, the NOx sample. (iii) The NOx emission rate shall be computed for each pair of NOx and O2 samples. The NOx emission rate (E) for each run shall be the arithmetic mean of the results of the four pairs of samples. (c) When combinations of fossil fuels or fossil fuel and wood residue are fired, the owner or operator (in order to compute the prorated standard as shown in §§60.43(b) and 60.44(b)) shall determine the percentage (w, x, y, or z) of the total heat input derived from each type of fuel as follows: (1) The heat input rate of each fuel shall be determined by multiplying the gross calorific value of each fuel fired by the rate of each fuel burned. (2) ASTM Methods D2015, or D5865 (solid fuels), D240 (liquid fuels), or D1826 (gaseous fuels) (all of these methods are incorporated by reference, see §60.17) shall be used to determine the gross calorific values of the fuels. The method used to determine the calorific value of wood residue must be approved by the Administrator. (3) Suitable methods shall be used to determine the rate of each fuel burned during each test period, and a material balance over the steam generating system shall be used to confirm the rate. (d) The owner or operator may use the following as alternatives to the reference methods and procedures in this section or in other sections as specified: (1) The emission rate (E) of PM, SO 2 and NOx may be determined by using the F, factor, provided that the following procedure is used: (i) The emission rate (E) shall be computed using the following equation: E =CFý 0 

           %C0 2 )

Where: E = Emission rate of pollutant, ng/J (lb/MMBtu); C = Concentration of pollutant, ng/dscm (lb/dscf); Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-I1 of 12

APPENDIX NSPS SUBPART D Standards of Performance for Fossil-Fuel-Fired Steam Generators for Which Construction is Commenced after August 17, 1971 %C0 2= CO 2concentration, percent dry basis; and Fc= Factor as determined in appropriate sections of Method 19 of appendix A of this part. (ii) If and only if the average F, factor in Method 19 of appendix A of this part is used to calculate E and either E is from 0.97 to 1.00 of the emission standard or the relative accuracy of a continuous emission monitoring system is from 17 to 20 percent, then three runs of Method 3B of appendix A of this part shall be used to determine the O 2and CO 2concentration according to the procedures in paragraph (b)(2)(ii), (4)(ii), or (5)(ii) of this section. Then if F, (average of three runs), as calculated from the equation in Method 3B of appendix A of this part, is more than +/-3 percent than the average Fo value, as determined from the average values of Fd and F, in Method 19 of appendix A of this part, i.e. , Fo.a = 0.209 (Fda/Faa), then the following procedure shall be followed: (A) When Fo is less than 0.97 Fo,, then E shall be increased by that proportion under 0.97 Faa, e.g. , if Fo is 0.95 Foa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the emission standard. (B) When F0 is less than 0.97 F., and when the average difference (d) between the continuous monitor minus the reference methods is negative, then E shall be increased by that proportion under 0.97 Fma, e.g. , if F. is 0.95 Fwa, E shall be increased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification. (C) When F. is greater than 1.03 Foa and when the average difference d is positive, then E shall be decreased by that proportion over 1.03 F.., e.g., if F. is 1.05 Faa, E shall be decreased by 2 percent. This recalculated value shall be used to determine compliance with the relative accuracy specification. (2) For Method 5 or 5B of appendix A-3 of this part, Method 17 of appendix A-6 of this part may be used at facilities with or without wet FGD systems if the stack gas temperature at the sampling location does not exceed an average temperature of 160 'C (320 'F). The procedures of sections 8.1 and 11.1 of Method 5B of appendix A-3 of this part may be used with Method 17 of appendix A-6 of this part only if it is used after wet FGD systems. Method 17 of appendix A-6 of this part shall not be used after wet FGD systems if the effluent gas is saturated or laden with water droplets. (3) Particulate matter and SO 2 may be determined simultaneously with the Method 5 of appendix A of this part train provided that the following changes are made: (i) The filter and impinger apparatus in sections 2.1.5 and 2.1.6 of Method 8 of appendix A of this part is used in place of the condenser (section 2.1.7) of Method 5 of appendix A of this part. (ii) All applicable procedures in Method 8 of appendix A of this part for the determination of S0 2(including moisture) are used: (4) For Method 6 of appendix A of this part, Method 6C of appendix A of this part may be used. Method 6A of appendix A of this part may also be used whenever Methods 6 and 3B of appendix A of this part data are specified to determine the' SO 2emission rate, under the conditions in paragraph (d)(1) of this section. (5) For Method 7 of appendix A of this part, Method 7A, 7C, 7D, or 7E of appendix A of this part may be used. If Method 7C, 7D, or 7E of appendix A of this part is used, the sampling time for each run shall be at least 1 hour and the integrated sampling approach shall be used to determine the O 2 concentration (%02) for the emission rate correction factor. (6) For Method 3 of appendix A of this part, Method 3A or 3B of appendix A of this part may be used. (7) For Method 3B of appendix A of this part, Method 3A of appendix A of this part may be used. [60 FR 65415, Dec. 19, 1995, as amended at 74 FR 5078, Jan. 28, 2009] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page D-12 of 12

APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants Title 40: Protectionof Environment PART 60-STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES Subpart Y-Standards of Performancefor CoalPreparationPlants § 60.250 Applicability and designation of affectedfacility. (a) The provisions of this subpart are applicable to any of the following affected facilities in coal preparation plants which process more than 181 Mg (200 tons) per day: Thermal dryers, pneumatic coal-cleaning equipment (air tables), coal processing and conveying equipment (including breakers and crushers), coal storage systems, and coal transfer and loading systems. (b) Any facility under paragraph (a) of this section that commences construction or modification after October 24, 1974, is subject to the requirements of this subpart. [42 FR 37938, July 25, 1977; 42 FR 44812, Sept. 7, 1977, as amended at 65 FR 61757, Oct. 17, 2000] § 60.251 Definitions. As used in this subpart, all terms not defined herein have the meaning given them in the Act and in subpart A of this part. (a) Coal preparationplant means any facility (excluding underground mining operations) which prepares coal by one or more of the following processes: breaking, crushing, screening, wet or dry cleaning, and thermal drying. (b) Bituminous coal means solid fossil fuel classified as bituminous coal by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see §60.17). (c) Coal means all solid fossil fuels classified as anthracite, bituminous, subbituminous, or lignite by ASTM Designation D388-77, 90, 91, 95, or 98a (incorporated by reference-see §60.17). (d) Cyclonic flow means a spiraling movement of exhaust gases within a duct or stack. (e) Thermal dryer means any facility in which the moisture content of bituminous coal is reduced by contact with a heated gas stream which is exhausted to the atmosphere. (f) Pneumatic coal-cleaning equipment means any facility which classifies bituminous coal by size or separates bituminous coal from refuse by application of air stream(s). (g) Coal processingand conveying equipment means any machinery used to reduce the size of coal or to separate coal from refuse, and the equipment used to convey coal to or remove coal and refuse from the machinery. This includes, but is not limited to, breakers, crushers, screens, and conveyor belts. (h) Coal storage system means any facility used to store coal except for open storage piles. (i) Transferand loading system means any facility used to transfer and load coal for shipment. [41 FR 2234, Jan. 15, 1976, as amended at 48 FR 3738, Jan. 27, 1983; 65 FR 61757, Oct. 17, 2000] § 60.252 Standardsfor particulatematter. (a) On and after the date on which the performance test required to be conducted by §60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any thermal dryer gases which: (1) Contain particulate matter in excess of 0.070 g/dscm (0.031 gr/dscf). (2) Exhibit 20 percent opacity or greater. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page Y-1 of 2

APPENDIX NSPS SUBPART Y Standards of Performance for Coal Preparation Plants (b) On and after the date on which the performance test required to be conducted by §60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any pneumatic coal cleaning equipment, gases which: (1) Contain particulate matter in excess of 0.040 g/dscm (0.017 gr/dscf). (2) Exhibit 10 percent opacity or greater. (c) On and after the date on which the performance test required to be conducted by §60.8 is completed, an owner or operator subject to the provisions of this subpart shall not cause to be discharged into the atmosphere from any coal processing and conveying equipment, coal storage system, or coal transfer and loading system processing coal, gases which exhibit 20 percent opacity or greater. [41 FR 2234, Jan. 15, 1976, as amended at 65 FR 61757, Oct. 17, 2000] § 60.253 Monitoringof operations. (a) The owner or operator of any thermal dryer shall install, calibrate, maintain, and continuously operate monitoring devices as follows: (1) A monitoring device for the measurement of the temperature of the gas stream at the exit of the thermal dryer on a continuous basis. The monitoring device is to be certified by the manufacturer to be accurate within +/-1.7 'C (+/-3 °F). (2) For affected facilities that use venturi scrubber emission control equipment: (i) A monitoring device for the continuous measurement of the pressure loss through the venturi constriction of the control equipment. The monitoring device is to be certified by the manufacturer to be accurate within +/-1 inch water gauge. (ii) A monitoring device for the continuous measurement of the water supply pressure to the control equipment. The monitoring device is to be certified by the manufacturer to be accurate within +/-5 percent of design water supply pressure. The pressure sensor or tap must be located close to the water discharge point. The Administrator may be consulted for approval of alternative locations. (b) All monitoring devices under paragraph (a) of this section are to be recalibrated annually in accordance with procedures under §60.13(b). [41 FR 2234, Jan. 15, 1976, as amended at 54 FR 6671, Feb. 14, 1989; 65 FR 61757, Oct. 17, 2000] § 60.254 Test methods and procedures. (a) In conducting the performance tests required in §60.8, the owner or operator shall use as reference methods and procedures the test methods in appendix A of this part or other methods and procedures as specified in this section, except as provided in §60.8(b). (b) The owner or operator shall determine compliance with the particular matter standards in §60.252 as follows: (1) Method 5 shall be used to determine the particulate matter concentration. The sampling time and sample volume for each run shall be at least 60 minutes and 0.85 dscm (30 dscf). Sampling shall begin no less than 30 minutes after startup and shall terminate before shutdown procedures begin. (2) Method 9 and the procedures in §60.11 shall be used to determine opacity. [54 FR 6671, Feb. 14, 1989] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page Y-2 of 2

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart IIIl-Standardsof Performancefor Stationary CompressionIgnition Internal Combustion Engines Source: 71 FR 39172, July 11, 2006, unless otherwise noted. What This Subpart Covers § 60.4200 Am I subject to this subpart? (a) The provisions of this subpart are applicable to manufacturers, owners, and operators of stationary compression ignition (CI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (3) of this section. For the purposes of this subpart, the date that construction commences is the date the engine is ordered by the owner or operator. (1) Manufacturers of stationary CI ICE with a displacement of less than 30 liters per cylinder where the model year is: (i) 2007 or later, for engines that are not fire pump engines, (ii) The model year listed in table 3 to this subpart or later model year, for fire pump engines. (2) Owners and operators of stationary CI ICE that commence construction after July 11, 2005 where the stationary CI ICE are: (i) Manufactured after April 1, 2006 and are not fire pump engines, or (ii) Manufactured as a certified National Fire Protection Association (NFPA) fire pump engine after July 1, 2006. (3) Owners and operators of stationary CI ICE that modify or reconstruct their stationary CI ICE after July 11, 2005. (b) The provisions of this subpart are not applicable to stationary CI ICE being tested at a stationary CI ICE test cell/stand. (c) If you are an owner or operator of an area source subject to this subpart, you are exempt from the obligation to obtain a permit under 40 CFR part 70 or 40 CFR part 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart applicable to area sources. (d) Stationary CI ICE may be eligible for exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C (or the exemptions described in 40 CFR part 89, subpart J and 40 CFR part 94, subpart J, for engines that would need to be certified to standards in those parts), except that owners and operators, as well as manufacturers, may be eligible to request an exemption for national security. Emission Standardsfor Manufacturers § 60.4201 What emission standards must I meet for non-emergency engines if I am a stationary CI internalcombustion engine manufacturer? (a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 kilowatt (KW) (3,000 horsepower (HP)) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 89.112, 40 CFR 89.113, 40 CFR 1039.101, 40 CFR 1039.102, 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same model year and maximum engine power. (b) Stationary CI internal combustion engine manufacturers must certify their 2007 through 2010 model year non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power. (c) Stationary CI internal combustion engine manufacturers must certify their 2011 model year and later non-emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder to the certification emission standards for new nonroad CI engines in 40 CFR 1039.101, 40 CFR 1039.102, 40 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-1 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, and 40 CFR 1039.115, as applicable, for all pollutants, for the same maximum engine power. (d) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power. § 60.4202 What emission standardsmust I meet for emergency engines if I am a stationaryCI internalcombustion engine manufacturer? (a) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power less than or equal to 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (a)(1) through (2) of this section. (1) For engines with a maximum engine power less than 37 KW (50 HP): (i) The certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants for model year 2007 engines, and (ii) The certification emission standards for new nonroad CI engines in 40 CFR 1039.104, 40 CFR 1039.105, 40 CFR 1039.107, 40 CFR 1039.115, and table 2 to this subpart, for 2008 model year and later engines. (2) For engines with a maximum engine power greater than or equal to 37 KW (50 HP), the certification emission standards for new nonroad CI engines for the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants beginning in model year 2007. (b) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a maximum engine power greater than 2,237 KW (3,000 HP) and a displacement of less than 10 liters per cylinder that are not fire pump engines to the emission standards specified in paragraphs (b)(1) through (2) of this section. (1) For 2007 through 2010 model years, the emission standards in table 1 to this subpart, for all pollutants, for the same maximum engine power. (2) For 2011 model year and later, the certification emission standards for new nonroad CI engines for engines of the same model year and maximum engine power in 40 CFR 89.112 and 40 CFR 89.113 for all pollutants. (c) Stationary CI internal combustion engine manufacturers must certify their 2007 model year and later emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines to the certification emission standards for new marine CI engines in 40 CFR 94.8, as applicable, for all pollutants, for the same displacement and maximum engine power. (d) Beginning with the model years in table 3 to this subpart, stationary CI internal combustion engine manufacturers must certify their fire pump stationary CI ICE to the emission standards in table 4 to this subpart, for all pollutants, for the same model year and NFPA nameplate power. § 60.4203 How long must my engines meet the emission standardsif I am a stationary CI internalcombustion engine manufacturer? Engines manufactured by stationary CI internal combustion engine manufacturers must meet the emission standards as required in §§60.4201 and 60.4202 during the useful life of the engines. Emission Standardsfor Owners and Operators § 60.4204 What emission standardsmust I meetfor non-emergency engines if I am an owner or operatorof a stationary CI internalcombustion engine? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-2 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of less than 10 liters per cylinder must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder must comply with the emission standards in 40 CFR 94.8(a)(1). (b) Owners and operators of 2007 model year and later non-emergency stationary CI ICE with a displacement of less than 30 liters per cylinder must comply with the emission standards for new CI engines in §60.4201 for their 2007 model year and later stationary CI ICE, as applicable. (c) Owners and operators of non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (c)(1) and (2) of this section. (1) Reduce nitrogen oxides (NOx) emissions by 90 percent or more, or limit the emissions of NOxin the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (g/KW-hr) (1.2 grams per HP-hour (g/HP-hr)). (2) Reduce particulate matter (PM) emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr). § 60.4205 What emission standardsmust I meet for emergency engines if I am an owner or operatorof a stationaryCI internalcombustion engine? (a) Owners and operators of pre-2007 model year emergency stationary CI ICE with a displacement of less than 10 liters per cylinder that are not fire pump engines must comply with the emission standards in table 1 to this subpart. Owners and operators of pre-2007 model year non-emergency stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards in 40 CFR 94.8(a)(1). (b) Owners and operators of 2007 model year and later emergency stationary CI ICE with a displacement of less than 30 liters per cylinder that are not fire pump engines must comply with the emission standards for new nonroad CI engines in §60.4202, for all pollutants, for the same model year and maximum engine power for their 2007 model year and later emergency stationary CI ICE. (c) Owners and operators of fire pump engines with a displacement of less than 30 liters per cylinder must comply with the emission standards in table 4 to this subpart, for all pollutants. (d) Owners and operators of emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must meet the requirements in paragraphs (d)(1) and (2) of this section. (1) Reduce NOx emissions by 90 percent or more, or limit the emissions of NOx in the stationary CI internal combustion engine exhaust to 1.6 grams per KW-hour (1.2 grams per HP-hour). (2) Reduce PM emissions by 60 percent or more, or limit the emissions of PM in the stationary CI internal combustion engine exhaust to 0.15 g/KW-hr (0.11 g/HP-hr). § 60.4206 How long must I meet the emission standardsif I am an owner or operatorof a stationary CI internal combustion engine? Owners and operators of stationary CI ICE must operate and maintain stationary CI ICE that achieve the emission standards as required in §§60.4204 and 60.4205 according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer, over the entire life of the engine. Fuel Requirements for Owners and Operators § 60.4207 Whatfuel requirements must I meet if I am an owner or operatorof a stationaryCI internal combustion engine subject to this subpart? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-3 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) Beginning October 1, 2007, owners and operators of stationary CI ICE subject to this subpart that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.5 10(a). (b) Beginning October 1, 2010, owners and operators of stationary CI ICE subject to this subpart with a displacement of less than 30 liters per cylinder that use diesel fuel must use diesel fuel that meets the requirements of 40 CFR 80.510(b) for nonroad diesel fuel. (c) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart may petition the Administrator for approval to use remaining non-compliant fuel that does not meet the fuel requirements of paragraphs (a) and (b) of this section beyond the dates required for the purpose of using up existing fuel inventories. If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator. (d) Owners and operators of pre-2011 model year stationary CI ICE subject to this subpart that are located in areas of Alaska not accessible by the Federal Aid Highway System may petition the Administrator for approval to use any fuels mixed with used lubricating oil that do not meet the fuel requirements of paragraphs (a) and (b) of this section. Owners and operators must demonstrate in their petition to the Administrator that there is no other place to use the lubricating oil. If approved, the petition will be valid for a period of up to 6 months. If additional time is needed, the owner or operator is required to submit a new petition to the Administrator. (e) Stationary CI ICE that have a national security exemption under §60.4200(d) are also exempt from the fuel requirements in this section. Other Requirements for Owners and Operators § 60.4208 What is the deadlinefor importingor installing stationary CI ICE produced in the previous model year? (a) After December 31, 2008, owners and operators may not install stationary CI ICE (excluding fire pump engines) that do not meet the applicable requirements for 2007 model year engines. (b) After December 31, 2009, owners and operators may not install stationary CI ICE with a maximum engine power of less than 19 KW (25 HP) (excluding fire pump engines) that do not meet the applicable requirements for 2008 model year engines. (c) After December 31, 2014, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 19 KW (25 HP) and less than 56 KW (75 HP) that do not meet the applicable requirements for 2013 model year non-emergency engines. (d) After December 31, 2013, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 56 KW (75 HP) and less than 130 KW (175 HP) that do not meet the applicable requirements for 2012 model year non-emergency engines. (e) After December 31, 2012, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 130 KW (175 HP), including those above 560 KW (750 HP), that do not meet the applicable requirements for 2011 model year non-emergency engines. (f) After December 31, 2016, owners and operators may not install non-emergency stationary CI ICE with a maximum engine power of greater than or equal to 560 KW (750 HP) that do not meet the applicable requirements for 2015 model year non-emergency engines. (g) In addition to the requirements specified in §§60.4201, 60.4202, 60.4204, and 60.4205, it is prohibited to import stationary CI ICE with a displacement of less than 30 liters per cylinder that do not meet the applicable requirements specified in paragraphs (a) through (f) of this section after the dates specified in paragraphs (a) through (f) of this section. (h) The requirements of this section do not apply to owners or operators of stationary CI ICE that have been modified, reconstructed, and do not apply to engines that were removed from one existing location and reinstalled at a new location. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-4 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines § 60.4209 What are the monitoring requirements if I am an owner or operatorof a stationary CI internalcombustion engine? If you are an owner or operator, you must meet the monitoring requirements of this section. In addition, you must also meet the monitoring requirements specified in §60.4211. (a) If you are an owner or operator of an emergency stationary CI internal combustion engine, you must install a non-resettable hour meter prior to startup of the engine. (b) If you are an owner or operator of a stationary CI internal combustion engine equipped with a diesel particulate filter to comply with the emission standards in §60.4204, the diesel particulate filter must be installed with a backpressure monitor that notifies the owner or operator when the high backpressure limit of the engine is approached. Compliance Requirements § 60.4210 What are my compliance requirementsif I am a stationary CI internalcombustion engine manufacturer? (a) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of less than 10 liters per cylinder to the emission standards specified in §60.4201(a) through (c) and §60.4202(a), (b) and (d) using the certification procedures required in 40 CFR part 89, subpart B, or 40 CFR part 1039, subpart C, as applicable, and must test their engines as specified in those parts. For the purposes of this subpart, engines certified to the standards in table I to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89. For the purposes of this subpart, engines certified to the standards in table 4 to this subpart shall be subject to the same requirements as engines certified to the standards in 40 CFR part 89, except that engines with NFPA nameplate power of less than 37 KW (50 HP) certified to model year 2011 or later standards shall be subject to the same requirements as engines certified to the standards in 40 CFR part 1039. (b) Stationary CI internal combustion engine manufacturers must certify their stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder to the emission standards specified in §60.4201(d) and §60.4202(c) using the certification procedures required in 40 CFR part 94 subpart C, and must test their engines as specified in 40 CFR part 94. (c) Stationary CI internal combustion engine manufacturers must meet the requirements of 40 CFR 1039.120, 40 CFR 1039.125, 40 CFR 1039.130, 40 CFR 1039.135, and 40 CFR part 1068 for engines that are certified to the emission standards in 40 CFR part 1039. Stationary CI internal combustion engine manufacturers must meet the corresponding provisions of 40 CFR part 89 or 40 CFR part 94 for engines that would be covered by that part if they were nonroad (including marine) engines. Labels on such engines must refer to stationary engines, rather than or in addition to nonroad or marine engines, as appropriate. Stationary CI internal combustion engine manufacturers must label their engines according to paragraphs (c)(1) through (3) of this section. (1) Stationary CI internal combustion engines manufactured from January 1, 2006 to March 31, 2006 (January 1, 2006 to June 30, 2006 for fire pump engines), other than those that are part of certified engine families under the nonroad CI engine regulations, must be labeled according to 40 CFR 1039.20. (2) Stationary CI internal combustion engines manufactured from April 1, 2006 to December 31, 2006 (or, for fire pump engines, July 1, 2006 to December 31 of the year preceding the year listed in table 3 to this subpart) must be labeled according to paragraphs (c)(2)(i) through (iii) of this section: (i) Stationary CI internal combustion engines that are part of certified engine families under the nonroad regulations must meet the labeling requirements for nonroad CI engines, but do not have to meet the labeling requirements in 40 CFR 1039.20. (ii) Stationary CI internal combustion engines that meet Tier 1 requirements (or requirements for fire pumps) under this subpart, but do not meet the requirements applicable to nonroad CI engines must be labeled according to 40 CFR 1039.20. The engine manufacturer may add language to the label clarifying that the engine meets Tier 1 requirements (or requirements for fire pumps) of this subpart. (iii) Stationary CI internal combustion engines manufactured after April 1, 2006 that do not meet Tier 1 requirements of this subpart, or fire pumps engines manufactured after July 1, 2006 that do not meet the requirements for fire pumps under this Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-5 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines subpart, may not be used in the U.S. If any such engines are manufactured in the U.S. after April 1, 2006 (July 1, 2006 for fire pump engines), they must be exported or must be brought into compliance with the appropriate standards prior to initial operation. The export provisions of 40 CFR 1068.230 would apply to engines for export and the manufacturers must label such engines according to 40 CFR 1068.230. (3) Stationary CI internal combustion engines manufactured after January 1, 2007 (for fire pump engines, after January 1 of the year listed in table 3 to this subpart, as applicable) must be labeled according to paragraphs (c)(3)(i) through (iii) of this section. (i) Stationary CI internal combustion engines that meet the requirements of this subpart and the corresponding requirements for nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate. (ii) Stationary CI internal combustion engines that meet the requirements of this subpart, but are not certified to the standards applicable to nonroad (including marine) engines of the same model year and HP must be labeled according to the provisions in part 89, 94 or 1039, as appropriate, but the words "stationary" must be included instead of "nonroad" or "marine" on the label. In addition, such engines must be labeled according to 40 CFR 1039.20. (iii) Stationary CI internal combustion engines that do not meet the requirements of this subpart must be labeled according to 40 CFR 1068.230 and must be exported under the provisions of 40 CFR 1068.230. (d) An engine manufacturer certifying an engine family or families to standards under this subpart that are identical to standards applicable under parts 89, 94, or 1039 for that model year may certify any such family that contains both nonroad (including marine) and stationary engines as a single engine family and/or may include any such family containing stationary engines in the averaging, banking and trading provisions applicable for such engines under those parts. (e) Manufacturers of engine families discussed in paragraph (d) of this section may meet the labeling requirements referred to in paragraph (c) of this section for stationary CI ICE by either adding a separate label containing the information required in paragraph (c) of this section or by adding the words "and stationary" after the word "nonroad" or "marine," as appropriate, to the label. (f) Starting with the model years shown in table 5 to this subpart, stationary CI internal combustion engine manufacturers must add a permanent label stating that the engine is for stationary emergency use only to each new emergency stationary CI internal combustion engine greater than or equal to 19 KW (25 HP) that meets all the emission standards for emergency engines in §60.4202 but does not meet all the emission standards for non-emergency engines in §60.4201. The label must be added according to the labeling requirements specified in 40 CFR 1039.135(b). Engine manufacturers must specify in the owner's manual that operation of emergency engines is limited to emergency operations and required maintenance and testing. (g) Manufacturers of fire pump engines may use the test cycle in table 6 to this subpart for testing fire pump engines and may test at the NFPA certified nameplate HP, provided that the engine is labeled as "Fire Pump Applications Only". (h) Engine manufacturers, including importers, may introduce into commerce uncertified engines or engines certified to earlier standards that were manufactured before the new or changed standards took effect until inventories are depleted, as long as such engines are part of normal inventory. For example, if the engine manufacturers' normal industry practice is to keep on hand a one-month supply of engines based on its projected sales, and a new tier of standards starts to apply for the 2009 model year, the engine manufacturer may manufacture engines based on the normal inventory requirements late in the 2008 model year, and sell those engines for installation. The engine manufacturer may not circumvent the provisions of §§60.4201 or 60.4202 by stockpiling engines that are built before new or changed standards take effect. Stockpiling of such engines beyond normal industry practice is a violation of this subpart. (i) The replacement engine provisions of 40 CFR 89.1003(b)(7), 40 CFR 94.1103(b)(3), 40 CFR 94.1103(b)(4) and 40 CFRý 1068.240 are applicable to stationary CI engines replacing existing equipment that is less than 15 years old. § 60.4211 What are my compliance requirements if I am an owner or operatorof a stationaryCI internalcombustion engine? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-6 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (a) If you are an owner or operator and must comply with the emission standards specified in this subpart, you must operate and maintain the stationary CI internal combustion engine and control device according to the manufacturer's written instructions or procedures developed by the owner or operator that are approved by the engine manufacturer. In addition, owners and operators may only change those settings that are permitted by the manufacturer. You must also meet the requirements of 40 CFR parts 89, 94 and/or 1068, as they apply to you. (b) If you are an owner or operator of a pre-2007 model year stationary CI internal combustion engine and must comply with the emission standards specified in §§60.4204(a) or 60.4205(a), or if you are an owner or operator of a CI fire pump engine that is manufactured prior to the model years in table 3 to this subpart and must comply with the emission standards specified in §60.4205(c), you must demonstrate compliance according to one of the methods specified in paragraphs (b)(1) through (5) of this section. (1) Purchasing an engine certified according to 40 CFR part 89 or 40 CFR part 94, as applicable, for the same model year and maximum engine power. The engine must be installed and configured according to the manufacturer's specifications. (2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly. (3) Keeping records of engine manufacturer data indicating compliance with the standards. (4) Keeping records of control device vendor data indicating compliance with the standards. (5) Conducting an initial performance test to demonstrate compliance with the emission standards according to the requirements specified in §60.4212, as applicable. (c) If you are an owner or operator of a 2007 model year and later stationary CI internal combustion engine and must comply with the emission standards specified in §60.4204(b) or §60.4205(b), or if you are an owner or operator of a CI fire pump engine that is manufactured during or after the model year that applies to your fire pump engine power rating in table 3 to this subpart and must comply with the emission standards specified in §60.4205(c), you must comply by purchasing an engine certified to the emission standards in §60.4204(b), or §60.4205(b) or (c), as applicable, for the same model year and maximum (or in the case of fire pumps, NFPA nameplate) engine power. The engine must be installed and configured according to the manufacturer's specifications. (d) If you are an owner or operator and must comply with the emission standards specified in §60.4204(c) or §60.4205(d), you must demonstrate compliance according to the requirements specified in paragraphs (d)(1) through (3) of this section. (1) Conducting an initial performance test to demonstrate initial compliance with the emission standards as specified in §60.4213. (2) Establishing operating parameters to be monitored continuously to ensure the stationary internal combustion engine continues to meet the emission standards. The owner or operator must petition the Administrator for approval of operating parameters to be monitored continuously. The petition must include the information described in paragraphs (d)(2)(i) through (v) of this section. (i) Identification of the specific parameters you propose to monitor continuously; (ii) A discussion of the relationship between these parameters and NOxand PM emissions, identifying how the emissions of these pollutants change with changes in these parameters, and how limitations on these parameters will serve to limit NOxand PM emissions; (iii) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations; (iv) A discussion identifying the methods and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (v) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-7 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (3) For non-emergency engines with a displacement of greater than or equal to 30 liters per cylinder, conducting annual performance tests to demonstrate continuous compliance with the emission standards as specified in §60.4213. (e) Emergency stationary ICE may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State, or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. There is no time limit on the use of emergency stationary ICE in emergency situations. Anyone may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency ICE beyond 100 hours per year. For owners and operators of emergency engines meeting standards under 

§60.4205 but not §60.4204, any operation other than emergency operation, and maintenance and testing as permitted in this section, is prohibited.

Testing Requirementsfor Owners and Operators § 60.4212 What test methods and otherprocedures must I use if I am an owner or operatorof a stationary CI internal combustion engine with a displacementof less than 30 liters per cylinder? Owners and operators of stationary CI ICE with a displacement of less than 30 liters per cylinder who conduct performance tests pursuant to this subpart must do so according to paragraphs (a) through (d) of this section. (a) The performance test must be conducted according to the in-use testing procedures in 40 CFR part 1039, subpart F. (b) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR part 1039 must not exceed the not-to-exceed (NTE) standards for the same model year and maximum engine power as required in 40 CFR 1039.101(e) and 40 CFR 1039.102(g)(1), except as specified in 40 CFR 1039.104(d). This requirement starts when NTE requirements take effect for nonroad diesel engines under 40 CFR part 1039. (c) Exhaust emissions from stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8, as applicable, must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in 40 CFR 89.112 or 40 CFR 94.8, as applicable, determined from the following equation: NTE requirem eit for each pollutant = (1 .25) x (STD) (Ecq. 1) Where: STD = The standard specified for that pollutant in 40 CFR 89.112 or 40 CFR 94.8, as applicable. Alternatively, stationary CI ICE that are complying with the emission standards for new CI engines in 40 CFR 89.112 or 40 CFR 94.8 may follow the testing procedures specified in §60.4213 of this subpart, as appropriate. (d) Exhaust emissions from stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in §60.4204(a), §60.4205(a), or §60.4205(c) must not exceed the NTE numerical requirements, rounded to the same number of decimal places as the applicable standard in §60.4204(a), §60.4205(a), or §60.4205(c), determined from the equation in paragraph (c) of this section. Where: STD = The standard specified for that pollutant in §60.4204(a), §60.4205(a), or §60.4205(c). Alternatively, stationary CI ICE that are complying with the emission standards for pre-2007 model year engines in §60.4204(a), §60.4205(a), or §60.4205(c) may follow the testing procedures specified in §60.4213, as appropriate. § 60.4213 What test methods and otherproceduresmust I use if I am an owner or operatorof a stationaryCI internal combustion engine with a displacementof greaterthan or equal to 30 liters per cylinder? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-8 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Owners and operators of stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder must conduct performance tests according to paragraphs (a) through (d) of this section. (a) Each performance test must be conducted according to the requirements in §60.8 and under the specific conditions that this subpart specifies in table 7. The test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load. (b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in §60.8(c). (c) You must conduct three separate test runs for each performance test required in this section, as specified in §60.8(f). Each test run must last at least 1 hour. (d) To determine compliance with the percent reduction requirement, you must follow the requirements as specified in paragraphs (d)(1) through (3) of this section. (1) You must use Equation 2 of this section to determine compliance with the percent reduction requirement: C-C* x 100=R (Eq. 2) Ci Where: C1 = concentration of NOx or PM at the control device inlet, Co = concentration of NOx or PM at the control device outlet, and R = percent reduction of NOx or PM emissions. (2) You must normalize the NOx or PM concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen (02) using Equation 3 of this section, or an equivalent percent carbon dioxide (C0 2) using the procedures described in paragraph (d)(3) of this section. 5.9 Caj = C' 20.9 5.9(Eq. 

                - %0O2             3)

Where: Cadj = Calculated NOx or PM concentration adjusted to 15 percent 02. Cd = Measured concentration of NOx or PM, uncorrected. 5.9 = 20.9 percent 02-15 percent 02, the defined O 2correction value, percent. %02= Measured O2 concentration, dry basis, percent. (3) If pollutant concentrations are to be corrected to 15 percent O 2and CO 2 concentration is measured in lieu of O2concentration measurement, a CO 2 correction factor is needed. Calculate the CO 2correction factor as described in paragraphs (d)(3)(i) through (iii) of this section. (i) Calculate the fuel-specific F0 value for the fuel burned during the test using values obtained from Method 19, Section 5.2, and the following equation: 0.209* F. - ý (Eq. 4) Where: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-9 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Fo= Fuel factor based on the ratio of O 2 volume to the ultimate C0 2volume produced by the fuel at zero percent excess air. 0.209 = Fraction of air that is 02, percent/100. Fd= Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu). F,= Ratio of the volume of C0 2produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu). (ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent 02, as follows: 5.9 

           -        (Eq. 5 Where:

Xco2= C0 2correction factor, percent. 5.9 = 20.9 percent 02-15 percent 02, the defined O 2correction value, percent. (iii) Calculate the NOx and PM gas concentrations adjusted to 15 percent O2 using CO 2as follows: 

      = C.     --        (Eq. 6)
             %C0  2 Where:

Cadj = Calculated NOx or PM concentration adjusted to 15 percent 02. Cd = Measured concentration of NOx or PM, uncorrected. %C0 2= Measured C0 2concentration, dry basis, percent. (e) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 7 of this section: ER = C.x 1.912 x 10-3 x Q x T (Eq- 7) KW-hoi( Where: ER = Emission rate in grams per KW-hour. Cd = Measured NOx concentration in ppm. 1.912x10- 3= Conversion constant for ppm NOx to grams per standard cubic meter at 25 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meter per hour. T = Time of test run, in hours. KW-hour = Brake work of the engine, in KW-hour. (f) To determine compliance with the PM mass per unit output emission limitation, convert the concentration of PM in the engine exhaust using Equation 8 of this section: ER = 4x Q x T KW-hour Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-10 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Where: ER = Emission rate in grams per KW-hour. C~dj = Calculated PM concentration in grams per standard cubic meter. Q = Stack gas volumetric flow rate, in standard cubic meter per hour. T = Time of test run, in hours. KW-hour = Energy output of the engine, in KW. Notification, Reports, and Recordsfor Owners and Operators § 60.4214 What are my notification, reporting,and recordkeepingrequirements if I am an owner or operatorof a stationary CI internalcombustion engine? (a) Owners and operators of non-emergency stationary CI ICE that are greater than 2,237 KW (3,000 HP), or have a displacement of greater than or equal to 10 liters per cylinder, or are pre-2007 model year engines that are greater than 130 KW (175 HP) and not certified, must meet the requirements of paragraphs (a)(1) and (2) of this section. (1) Submit an initial notification as required in §60.7(a)(1). The notification must include the information in paragraphs (a)(1)(i) through (v) of this section. (i) Name and address of the owner or operator; (ii) The address of the affected source; (iii) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (iv) Emission control equipment; and (v) Fuel used. (2) Keep records of the information in paragraphs (a)(2)(i) through (iv) of this section. (i) All notifications submitted to comply with this subpart and all documentation supporting any notification. (ii) Maintenance conducted on the engine. (iii) If the stationary CI internal combustion is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards. (iv) If the stationary CI internal combustion is not a certified engine, documentation that the engine meets the emission standards. (b) If the stationary CI internal combustion engine is an emergency stationary internal combustion engine, the owner or operator is not required to submit an initial notification. Starting with the model years in table 5 to this subpart, if the emergency engine does not meet the standards applicable to non-emergency engines in the applicable model year, the owner or operator must keep records of the operation of the engine in emergency and non-emergency service that are recorded through the non-resettable hour meter. The owner must record the time of operation of the engine and the reason the engine was in operation during that time. (c) If the stationary CI internal combustion engine is equipped with a diesel particulate filter, the owner or operator must keep records of any corrective action taken after the backpressure monitor has notified the owner or operator that the high backpressure limit of the engine is approached. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-11 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines SpecialRequirements 

§ 60.4215 What requirements must I meetfor engines used in Guam, American Samoa, or the Commonwealth of the Northern MarianaIslands?

(a) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are required to meet the applicable emission standards in §60.4205. Non-emergency stationary CI ICE with a displacement of greater than or equal to 30 liters per cylinder, must meet the applicable emission standards in §60.4204(c). (b) Stationary CI ICE that are used in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands are not required to meet the fuel requirements in §60.4207. 

§ 60.4216 What requirements must I meet for engines used in Alaska?

(a) Prior to December 1, 2010, owners and operators of stationary CI engines located in areas of Alaska not accessible by the Federal Aid Highway System should refer to 40 CFR part 69 to determine the diesel fuel requirements applicable to such engines. (b) The Governor of Alaska may submit for EPA approval, by no later than January 11, 2008, an alternative plan for implementing the requirements of 40 CFR part 60, subpart IIII, for public-sector electrical utilities located in rural areas of Alaska not accessible by the Federal Aid Highway System. This alternative plan must be based on the requirements of section 111 of the Clean Air Act including any increased risks to human health and the environment and must also be based on the unique circumstances related to remote power generation, climatic conditions, and serious economic impacts resulting from implementation of 40 CFR part 60, subpart II. If EPA approves by rulemaking process an alternative plan, the provisions as approved by EPA under that plan shall apply to the diesel engines used in new stationary internal combustion engines subject to this paragraph. § 60.4217 What emission standardsmust I meet ifI am an owner or operatorof a stationaryinternalcombustion engine using specialfuels? (a) Owners and operators of stationary CI ICE that do not use diesel fuel, or who have been given authority by the Administrator under §60.4207(d) of this subpart to use fuels that do not meet the fuel requirements of paragraphs (a) and (b) of §60.4207, may petition the Administrator for approval of alternative emission standards, if they can demonstrate that they use a fuel that is not the fuel on which the manufacturer of the engine certified the engine and that the engine cannot meet the applicable standards required in §60.4202 or §60.4203 using such fuels. (b) [Reserved] GeneralProvisions § 60.4218 What parts of the General Provisionsapply to me? Table 8 to this subpart shows which parts of the General Provisions in §§60.1 through 60.19 apply to you. Definitions § 60.4219 What definitions apply to this subpart? As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part. Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page IIII-12 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine. Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil. Diesel particulatefilter means an emission control technology that reduces PM emissions by trapping the particles in a flow filter substrate and periodically removes the collected particles by either physical action or by oxidizing (burning off) the particles in a process called regeneration. Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary CI ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines. Engine manufacturermeans the manufacturer of the engine. See the definition of "manufacturer" in this section. Firepump engine means an emergency stationary internal combustion engine certified to NFPA requirements that is used to provide power to pump water for fire suppression or protection. Manufacturerhas the meaning given in section 216(1) of the Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for sale or resale. Maximum engine power means maximum engine power as defined in 40 CFR 1039.801. Model year means either: (1) The calendar year in which the engine was originally produced, or (2) The annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced. Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine. Reciprocatinginternal combustion engine means any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work. Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work. Spark ignition means relating to a gasoline, natural gas, or liquefied petroleum gas fueled engine or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines. Stationary internalcombustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition. Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-13 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart IIII. Useful life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for useful life for stationary CI ICE with a displacement of less than 10 liters per cylinder are given in 40 CFR 1039.101(g). The values for useful life for stationary CI ICE with a displacement of greater than or equal to 10 liters per cylinder and less than 30 liters per cylinder are given in 40 CFR 94.9(a). Table 1 to SubpartIIII of Part60-Emission Standardsfor StationaryPre-2007Model Year Engines With a Displacementof <10 Liters per Cylinder and 2007-2010 Model Year Engines >2,237 KW (3,000 HP)and With a Displacement of <10 Liters per Cylinder [As stated in §§60.4201(b), 60.4202(b), 60.4204(a), and 60.4205(a), you must comply with the following emission standards] Emission standards for stationary pre-2007 model year engines with a displacement of <10 liters per cylinder and 2007-2010 model year engines >2,237 KW (3,000 HP) and with a displacement of Maximum engine <10 liters per cylinder in g/KW-hr (g/HP-hr) power NMHC + NOx HC NOx CO PM KW<8 (HP<11) 10.5 (7.8) 8.0 (6.0) 1.0 (0.75) 8_<KW<19 9.5 (7.1) 6.6 (4.9) 0.80 (0.60) (1 1<HP<25) 19_<KW<37 9.5 (7.1) 5.5 (4.1) 0.80 (0.60) (25<HP<50) 37<KW<56 9.2 (6.9) (50<HP<75) 56<KW<75 9.2 (6.9) (75<HP<100) 75<KW<130 9.2 (6.9) (100<HP<175) 130<KW<225 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54 (0.40) (175<HP<300) 225<KW<450 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54(0.40) (300<HP<600) 450<KW<560 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54(0.40) (600<HP<750) KW>560 (HP>750) 1.3 (1.0) 9.2 (6.9) 11.4 (8.5) 0.54 (0.40) Table 2 to SubpartIIII of Part60-Emission Standardsfor 2008 Model Year and LaterEmergency Stationary CI ICE <37 KW (50 HP) With a Displacement of <10 Liters per Cylinder [As stated in §60.4202(a)(1), you must comply with the following emission standards] Emission standards for 2008 model year and later emergency stationary CI ICE <37 KW (50 HP) with a displacement of <10 liters per cylinder in g/KW-hr (g/HP-hr) Engine power Model year(s) NOx+ NMHC CO PM KW<8 (HP<1 1) 2008+][ 7.5 (5.6)1 8.0 (6.0) 0.40 (0.30) _8<_KW<19 2008+11 7.5 (5.6) 6.6 (419) 0.4. (0.3 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page IIII-14 of 19

APPENDIX NSPS SUBPART 1III Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (11_HP<25) 19<KW<37 2008+ 7.5 (5.6) 5.5 (4.1) 0.30 (0.22) (25_IHP<50) 1E_ Table 3 to Subpart IIII of Part60-CertificationRequirementsfor StationaryFire Pump Engines [As stated in §60.4202(d), you must certify new stationary fire pump engines beginning with the following model years:] Starting model year engine manufacturers must certify new stationary fire pump engines Engine power according to §60.4202(d) KW<75 (HP<100) 2011 75<KW<130 2010 (100<_HP<175) 130<KW<560 2009 (175<HP<750) KW>560 (HP>750) 2008 Table 4 to Subpart IIII of Part60-Emission Standardsfor StationaryFire Pump Engines [As stated in §§60.4202(d) and 60.4205(c), you must comply with the following emission standards for stationary fire pump engines] Maximum engine power Model year(s) 1F NMHC + NOx CO PM [KW<8 (HP<I 1) 2010 and earlier 10.5 (7.8) 8.0(6.0)] 1.0 (0.75) 2011+ 7.5 (5.6) [ 0.40 (0.30) [8<KW<19 (11*HP<25) [2010 and earlier I9.5(7.1)1 6 0.80 (0.60) 2011+ 7.5 (5.6) 0.40 (0.30) 19<KW<37 (25<HP<50) 2010 and earlier r-l 9.5 (7.1) = [ 0.80 (0.60) [2011+ 7.5 (5.6])- 0.30 (0.22) 137<KW<56 (50<HP<75) F2010 and earlier 10.5(7.8) 5 0.80 (0.60) 2011+ 4.7(3.5) 1 0.40 (0.30)1 [56<KW<75 (75<HP<100) F2010 and earlier 110.5 (7.8) 5 0.80 (0.60) 2011+l 4.7](3.5) 0.40 (0.30)1 f75_<KW<130 (100<HP<175) 2009 and earlier I 10.5 (7.8) 5.013J[ 0.80 (0.60)1 

                                              ]2010+                                     4.0(3.0)                   1   0.30 (0.22)]

130<KW<225 (175<HP<300) [2008 and earlier 10.5 (7.8) 3.5 2.[ 0.54 (0.40) 12009+7 4.0(3.0) 0.20 (0.15) 225_<KW<450 (300<HP<600) 2008 and earlier 110.5(7.8)1 1 0.54 (0.40) 3 0 .0 0.20(0.15 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-15 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines 450_KW_560 (600_<HP_<750) 2008 and earlier [ 10.5(7.) F 3.5(2.6) 0.54 (0.40) [2009+ 4.0_(3.0) ] 0.20 (0.15) KW>560 (HP>750) 2007 and earlier 10.5[(7. 8 ) 3. 6 0.54 (0.40) 

                                  =[2008+                                             6.4 (4.8)1      =                0.20 (0.15)

'For model years 2011-2013, manufacturers, owners and operators of fire pump stationary CI ICE in this engine power category with a rated speed of greater than 2,650 revolutions per minute (rpm) may comply with the emission limitations for 2010 model year engines. 2For model years 2010-2012, manufacturers, owners and operators of fire pump stationary CI ICE in this engine power category with a rated speed of greater than 2,650 rpm may comply with the emission limitations for 2009 model year engines. 3 In model years 2009-2011, manufacturers of fire pump stationary CI ICE in this engine power category with a rated speed of greater than 2,650 rpm may comply with the emission limitations for 2008 model year engines. Table 5 to SubpartIII1 of Part 60-Labeling and Recordkeeping Requirementsfor New StationaryEmergency Engines [You must comply with the labeling requirements in §60.4210(f) and the recordkeeping requirements in §60.4214(b) for new emergency stationary CI ICE beginning in the following model years:] Engine power Starting model year 19<_KW<56 (25_<HP<75) 2013 56_KW<130 (75:<HP<175) 2012 KW_130 (HP>175) 2011 Table 6 to SubpartIIII of Part60-Optional3-Mode Test Cycle for Stationary FirePump Engines [As stated in §60.4210(g), manufacturers of fire pump engines may use the following test cycle for testing fire pump engines:] Torque Weighting Mode No. Engine speed 1 (percent) 2 factors 1 [Rated 100 0.30 r2 Rated 75 0.501 3 Rated 50 0.20 'Engine speed: +/-2 percent of point. 2Torque: NFPA certified nameplate HP for 100 percent point. All points should be +/-2 percent of engine percent load value. Table 7 to Subpart IIII of Part60-Requirementsfor Performance Tests for Stationary CI ICE With a Displacementof >30 Liters per Cylinder [As stated in §60.4213, you must comply with the following requirements for performance tests for stationary CI ICE with a displacement of ?30 liters per cylinder:] Complying with the According to the For each requirement to You must Using following requirements

1. Stationary CI a. Reduce NOx i. Select the sampling port (1) Method 1 or IA of 40 (a) Sampling sites must be Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-16 of 19

APPENDIX NSPS SUBPART IIII Standards of Performance for Stationary Compression Ignition Internal Combustion Engines internal combustion emissions by 90 location and the number of CFR part 60, appendix A located at the inlet and engine with a percent or more traverse points; outlet of the control device. displacement of >30 liters per cylinder ii. Measure 02 at the inlet (2) Method 3, 3A, or 3B of (b) Measurements to and outlet of the control 40 CFR part 60, appendix determine O 2 concentration device; A must be made at the same time as the measurements for NOx concentration. iii. If necessary, measure (3) Method 4 of 40 CFR (c) Measurements to moisture content at the part 60, appendix A, determine moisture content inlet and outlet of the Method 320 of 40 CFR must be made at the same control device; and, part 63, appendix A, or time as the measurements ASTM D 6348-03 for NOx concentration. (incorporated by reference, see §60.17) iv. Measure NOx at the (4) Method 7E of 40 CFR (d) NOx concentration inlet and outlet of the part 60, appendix A, must be at 15 percent 02, control device Method 320 of 40 CFR dry basis. Results of this part 63, appendix A, or test consist of the average ASTM D 6348-03 of the three 1-hour or (incorporated by reference, longer runs. see §60.17)

b. Limit the i. Select the sampling port (1) Method 1 or IA of 40 (a) If using a control concentration of location and the number of CFR part 60, appendix A device, the sampling site NOx in the traverse points; must be located at the stationary CI outlet of the control device.

internal combustion engine exhaust. ii. Determine the (2) Method 3, 3A, or 3B of (b) Measurements to O 2concentration of the 40 CFR part 60, appendix determine O 2concentration stationary internal A must be made at the same combustion engine exhaust time as the measurement at the sampling port for NOx concentration. location; and, iii. If necessary, measure (3) Method 4 of 40 CFR (c) Measurements to moisture content of the part 60, appendix A, determine moisture content stationary internal Method 320 of 40 CFR must be made at the same combustion engine exhaust part 63, appendix A, or time as the measurement at the sampling port ASTM D 6348-03 for NOx concentration. location; and, (incorporated by reference, see §60.17) iv. Measure NOx at the (4) Method 7E of 40 CFR (d) NOx concentration exhaust of the stationary part 60, appendix A, must be at 15 percent 02, internal combustion engine Method 320 of 40 CFR dry basis. Results of this part 63, appendix A, or test consist of the average ASTM D 6348-03 of the three 1-hour or (incorporated by reference, longer runs. see §60.17)

c. Reduce PM i. Select the sampling port (1) Method 1 or IA of 40 (a) Sampling sites must be emissions by 60 location and the number of CFR part 60, appendix A located at the inlet and percent or more traverse points; outlet of the control device.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-17 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines ii. Measure O 2at the inlet (2) Method 3, 3A, or 3B of (b) Measurements to and outlet of the control 40 CFR part 60, appendix determine O 2concentration device; A must be made at the same time as the measurements for PM concentration. iii. If necessary, measure (3) Method 4 of 40 CFR (c) Measurements to moisture content at the part 60, appendix A determine and moisture inlet and outlet of the content must be made at control device; and the same time as the measurements for PM concentration. iv. Measure PM at the inlet (4) Method 5 of 40 CFR (d) PM concentration must and outlet of the control part 60, appendix A be at 15 percent 02, dry device basis. Results of this test consist of the average of the three 1-hour or longer runs.

d. Limit the i. Select the sampling port (1) Method 1 or 1A of 40 (a) If using a control concentration of PM location and the number of CFR part 60, appendix A device, the sampling site in the stationary CI traverse points; must be located at the internal combustion outlet of the control device.

engine exhaust ii. Determine the (2) Method 3, 3A, or 3B of (b) Measurements to O2 concentration of the 40 CFR part 60, appendix determine O 2concentration stationary internal A must be made at the same combustion engine exhaust time as the measurements at the sampling port for PM concentration. location; and iii. If necessary, measure (3) Method 4 of 40 CFR (c) Measurements to moisture content of the part 60, appendix A determine moisture content stationary internal must be made at the same combustion engine exhaust time as the measurements at the sampling port for PM concentration. location; and iv. Measure PM at the (4) Method 5 of 40 CFR (d) PM concentration must exhaust of the stationary part 60, appendix A be at 15 percent 02, dry internal combustion engine basis. Results of this test consist of the average of the three 1-hour or longer runs. Table 8 to SubpartIIII of Part60-Applicability of GeneralProvisionsto Subpart II1I [As stated in §60.4218, you must comply with the following applicable General Provisions:] General Applies Provisions to citation Subject of citation subpart Explanation §60.1 General applicability of the DfGeneral Provisions 1§60.2 IDefinitions I Yes jAdditional terms defined in §60.4219. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page 1111-18 of 19

APPENDIX NSPS SUBPART 1111 Standards of Performance for Stationary Compression Ignition Internal Combustion Engines 

               §Units and abbreviations                  Y         [         _     _       _      _      _       _      _       _
§60.4      ddress                                        Yes
§60.5m          Determination of construction or         Yes

[§60.5 [odification_______________________________ [§60.6 [Review of plans IYes [§60.7 [Notification and Recordkeeping Yes Except that §60.7 only applies as specified in §60.4214(a). 

§60.8           Performance tests                        Yes      Except that §60.8 only applies to stationary CI ICE with a displacement of (>_30 liters per cylinder and engines that are not certified.

[§60.9 ]rAvailability of informationes [§60.10 ][State Authority Yes 

§60.11          maiteneCompliance with standards and     No       Requirements are specified in subpart 1111.

[§60.12 ]Circumvention Yes 

§60.13          Monitoring requirements                  Yes      Except that §60.13 only applies to stationary CI ICE with a IL                                        J         displacement of (>30 liters per cylinder.

i§60.14 &Modification Yes 

§60.15          Reconstruction                           Yes
§       Z60.16  Priority list                                        __Yes__

_§60.17 Incorporations by reference Yes 

§60.18          General control device                   No requirements
§60.19          General notification and reporting Yes requirements Progress Energy Florida, Inc.                                                                            Permit No. 0170004-024-AV Crystal River Power Plant                                                                                     Title V Permit Renewal Page 1111-19 of 19

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Subpart JJJJ-Standardsof Performancefor StationarySpark Ignition Internal Combustion Engines Source: 73 FR 3591, Jan. 18, 2008, unless otherwise noted. What This Subpart Covers § 60.4230 Am I subject to this subpart? (a) The provisions of this subpart are applicable to manufacturers, owners, and operators of stationary spark ignition (SI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (5) of this section. For the purposes of this subpart, the date that construction commences is the date the engine is ordered by the owner or operator. (1) Manufacturers of stationary SI ICE with a maximum engine power less than or equal to 19 kilowatt (KW) (25 horsepower (HP)) that are manufactured on or after July 1, 2008. (2) Manufacturers of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) that are gasoline fueled or that are rich burn engines fueled by liquefied petroleum gas (LPG), where the date of manufacture is: (i) On or after July 1, 2008; or (ii) On or after January 1, 2009, for emergency engines. (3) Manufacturers of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) that are not gasoline fueled and are not rich bum engines fueled by LPG, where the manufacturer participates in the voluntary manufacturer certification program described in this subpart and where the date of manufacture is: (i) On or after July 1, 2007, for engines with a maximum engine power greater than or equal to 500 HP (except lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP); (ii) On or after January 1, 2008, for lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP; (iii) On or after July 1, 2008, for engines with a maximum engine power less than 500 HP; or (iv) On or after January 1, 2009, for emergency engines. (4) Owners and operators of stationary SI ICE that commence construction after June 12, 2006, where the stationary SI ICE are manufactured: (i) On or after July 1, 2007, for engines with a maximum engine power greater than or equal to 500 HP (except lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP); (ii) on or after January 1, 2008, for lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP; (iii) on or after July 1, 2008, for engines with a maximum engine power less than 500 HP; or (iv) on or after January 1, 2009, for emergency engines with a maximum engine power greater than 19 KW (25 HP). (5) Owners and operators of stationary SI ICE that commence modification or reconstruction after June 12, 2006. (b) The provisions of this subpart are not applicable to stationary SI ICE being tested at an engine test cell/stand. (c) If you are an owner or operator of an area source subject to this subpart, you are exempt from the obligation to obtain a permit under 40 CFR part 70 or 40 CFR part 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart as applicable. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-1 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (d) For the purposes of this subpart, stationary SI ICE using alcohol-based fuels are considered gasoline engines. (e) Stationary SI ICE may be eligible for exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C (or the exemptions described in 40 CFR parts 90 and 1048, for engines that would need to be certified to standards in those parts), except that owners and operators, as well as manufacturers, may be eligible to request an exemption for national security. (f) Owners and operators of facilities with internal combustion engines that are acting as temporary replacement units and that are located at a stationary source for less than 1 year and that have been properly certified as meeting the standards that would be applicable to such engine under the appropriate nonroad engine provisions, are not required to meet any other provisions under this subpart with regard to such engines. Emission Standardsfor Manufacturers § 60.4231 What emission standards must I meet if I am a manufacturerof stationarySI internalcombustion engines or equipment containingsuch engines? (a) Stationary SI internal combustion engine manufacturers must certify their stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP) manufactured on or after July 1, 2008 to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 1054, as follows: the engine must meet emission standards and related requirements for nonhandheld engines If engine replacement is ... and manufacturing dates are.., under... (1) below 225 cc July 1, 2008 to December 31, 2011 40 CFR part 90. (2) below 225 cc January 1, 2012 or later 40 CFR part 1054. (3) at or above 225 cc July 1, 2008 to December 31, 2010 40 CFR part 90. (4) at or above 225 cc January 1, 2011 or later 40 CFR part 1054. (b) Stationary SI internal combustion engine manufacturers must certify their stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) (except emergency stationary ICE with a maximum engine power greater than 25 HP and less than 130 HP) that use gasoline and that are manufactured on or after the applicable date in §60.4230(a)(2), or manufactured on or after the applicable date in §60.4230(a)(4) for emergency stationary ICE with a maximum engine power greater than or equal to 130 HP, to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 1048. Stationary SI internal combustion engine manufacturers must certify their emergency stationary SI ICE with a maximum engine power greater than 25 HP and less than 130 HP that are manufactured on or after the applicable date in §60.4230(a)(4) to the Phase 1 emission standards in 40 CFR 90.103, applicable to class II engines, and other requirements for new nonroad SI engines in 40 CFR part 90. Stationary SI internal combustion engine manufacturers may certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cubic centimeters (cc) to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 1054, as appropriate. (c) Stationary SI internal combustion engine manufacturers must certify their stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) (except emergency stationary ICE with a maximum engine power greater than 25 HP and less than 130 HP) that are rich burn engines that use LPG and that are manufactured on or after the applicable date in §60.4230(a)(2), or manufactured on or after the applicable date in §60.4230(a)(4) for emergency stationary ICE with a maximum engine power greater than or equal to 130 HP, to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 1048. Stationary SI internal combustion engine manufacturers must certify their emergency stationary SI ICE with a maximum engine power greater than 25 HP and less than 130 HP that are manufactured on or after the applicable date in §60.4230(a)(4) to the Phase 1 emission standards in 40 CFR 90.103, applicable to class II engines, and other requirements for new nonroad SI engines in 40 CFR part 90. Stationary SI internal combustion engine manufacturers may certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cc to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 1054, as appropriate. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-2 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (d) Stationary SI internal combustion engine manufacturers who choose to certify their stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) and less than 75 KW (100 HP) (except gasoline and rich burn engines that use LPG and emergency stationary ICE with a maximum engine power greater than 25 HP and less than 130 HP) under the voluntary manufacturer certification program described in this subpart must certify those engines to the certification emission standards for new nonroad SI engines in 40 CFR part 1048. Stationary SI internal combustion engine manufacturers who choose to certify their emergency stationary SI ICE greater than 25 HP and less than 130 HP, must certify those engines to the Phase 1 emission standards in 40 CFR 90.103, applicable to class II engines, for new nonroad SI engines in 40 CFR part

90. Stationary SI internal combustion engine manufacturers may certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cc to the certification emission standards for new nonroad SI engines in 40 CFR part 90 or 1054, as appropriate. For stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) and less than 75 KW (100 HP) (except gasoline and rich burn engines that use LPG and emergency stationary ICE with a maximum engine power greater than 25 HP and less than 130 HP) manufactured prior to January 1, 2011, manufacturers may choose to certify these engines to the standards in Table I to this subpart applicable to engines with a maximum engine power greater than or equal to 100 HP and less than 500 HP.

(e) Stationary SI internal combustion engine manufacturers who choose to certify their stationary SI ICE with a maximum engine power greater than or equal to 75 KW (100 HP) (except gasoline and rich burn engines that use LPG) under the voluntary manufacturer certification program described in this subpart must certify those engines to the emission standards in Table 1 to this subpart. Stationary SI internal combustion engine manufacturers may certify their stationary SI ICE with a maximum engine power greater than or equal to 75 KW (100 HP) that are lean burn engines that use LPG to the certification emission standards for new nonroad SI engines in 40 CFR part 1048. For stationary SI ICE with a maximum engine power greater than or equal to 100 HP (75 KW) and less than 500 HP (373 KW) manufactured prior to January 1, 2011, and for stationary SI ICE with a maximum engine power greater than or equal to 500 HP (373 KW) manufactured prior to July 1, 2010, manufacturers may choose to certify these engines to the certification emission standards for new nonroad SI engines in 40 CFR part 1048 applicable to engines that are not severe duty engines. (f) Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, to the extent they apply to equipment manufacturers. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59175, Oct. 8, 2008] § 60.4232 How long must my engines meet the emission standardsif I am a manufacturerof stationarySI internal combustion engines? Engines manufactured by stationary SI internal combustion engine manufacturers must meet the emission standards as required in §60,4231 during the certified emissions life of the engines. Emission Standardsfor Owners and Operators § 60.4233 What emission standardsmust I meet if I am an owner or operatorof a stationarySI internalcombustion engine? (a) Owners and operators of stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP) manufactured on or after July 1, 2008, must comply with the emission standards in §60.4231(a) for their stationary SI ICE. (b) Owners and operators of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) manufactured on or after the applicable date in §60.4230(a)(4) that use gasoline must comply with the emission standards in §60.4231(b) for their stationary SI ICE. (c) Owners and operators of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) manufactured on or after the applicable date in §60.4230(a)(4) that are rich burn engines that use LPG must comply with the emission standards in §60.4231(c) for their stationary SI ICE. (d) Owners and operators of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) and less than 75 KW (100 HP) (except gasoline and rich burn engines that use LPG) must comply with the emission standards for field testing in 40 CFR 1048.101(c) for their non-emergency stationary SI ICE and with the emission standards in Table I to this subpart for their emergency stationary SI ICE. Owners and operators of stationary SI ICE with a maximum engine power greater than Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-3 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 19 KW (25 HP) and less than 75 KW (100 HP) manufactured prior to January 1, 2011, that were certified to the standards in Table 1 to this subpart applicable to engines with a maximum engine power greater than or equal to 100 HP and less than 500 HP, may optionally choose to meet those standards. (e) Owners and operators of stationary SI ICE with a maximum engine power greater than or equal to 75 KW (100 HP) (except gasoline and rich burn engines that use LPG) must comply with the emission standards in Table I to this subpart for their stationary SI ICE. For owners and operators of stationary SI ICE with a maximum engine power greater than or equal to 100 HP (except gasoline and rich bum engines that use LPG) manufactured prior to January 1, 2011 that were certified to the certification emission standards in 40 CFR part 1048 applicable to engines that are not severe duty engines, if such stationary SI ICE was certified to a carbon monoxide (CO) standard above the standard in Table 1 to this subpart, then the owners and operators may meet the CO certification (not field testing) standard for which the engine was certified. (f) Owners and operators of any modified or reconstructed stationary SI ICE subject to this subpart must meet the requirements as specified in paragraphs (f)(1) through (5) of this section. (1) Owners and operators of stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP), that are modified or reconstructed after June 12, 2006, must comply with the same emission standards as those specified in paragraph (a) of this section. (2) Owners and operators of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) that use gasoline engines, that are modified or reconstructed after June 12, 2006, must comply with the same emission standards as those specified in paragraph (b) of this section. (3) Owners and operators of stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) that are rich bum engines that use LPG, that are modified or reconstructed after June 12, 2006, must comply with the same emission standards as those specified in paragraph (c) of this section. (4) Owners and operators of stationary SI natural gas and lean burn LPG engines with a maximum engine power greater than 19 KW (25 HP), that are modified or reconstructed after June 12, 2006, must comply with the same emission standards as those specified in paragraph (d) or (e) of this section, except that such owners and operators of non-emergency engines and emergency engines greater than or equal to 130 HP must meet a nitrogen oxides (NOx) emission standard of 3.0 grams per HP-hour (g/HP-hr), a CO emission standard of 4.0 g/HP-hr (5.0 g/HP-hr for non-emergency engines less than 100 HP), and a volatile organic compounds (VOC) emission standard of 1.0 g/HP-hr, or a NOx emission standard of 250 ppmvd at 15 percent oxygen (02), a CO emission standard 540 ppmvd at 15 percent 02(675 ppmvd at 15 percent O 2for non-emergency engines less than 100 HP), and a VOC emission standard of 86 ppmvd at 15 percent 02, where the date of manufacture of the engine is: (i) Prior to July 1, 2007, for non-emergency engines with a maximum engine power greater than or equal to 500 HP; (ii) Prior to July 1, 2008, for non-emergency engines with a maximum engine power less than 500 HP; (iii) Prior to January 1, 2009, for emergency engines. (5) Owners and operators of stationary SI landfill/digester gas ICE engines with a maximum engine power greater than 19 KW (25 HP), that are modified or reconstructed after June 12, 2006, must comply with the same emission standards as those specified in paragraph (e) of this section for stationary landfill/digester gas engines. (g) Owners and operators of stationary SI wellhead gas ICE engines may petition the Administrator for approval on a case-by-case basis to meet emission standards no less stringent than the emission standards that apply to stationary emergency SI engines greater than 25 HP and less than 130 HP due to the presence of high sulfur levels in the fuel, as specified in Table 1 to this subpart. The request must, at a minimum, demonstrate that the fuel has high sulfur levels that prevent the use of aftertreatment controls and also that the owner has reasonably made all attempts possible to obtain an engine that will meet the standards without the use of aftertreatment controls. The petition must request the most stringent standards reasonably applicable to the engine using the fuel. (h) Owners and operators of stationary SI ICE that are required to meet standards that reference 40 CFR 1048.101 must, if testing their engines in use, meet the standards in that section applicable to field testing, except as indicated in paragraph (e) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-4 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 

§ 60.4234 How long must I meet the emission standardsif I am an owner or operatorof a stationarySI internal combustion engine?

Owners and operators of stationary SI ICE must operate and maintain stationary SI ICE that achieve the emission standards as required in §60.4233 over the entire life of the engine. Other Requirementsfor Owners and Operators 

§ 60.4235 What fuel requirements must I meet if I am an owner or operatorof a stationarySI gasolinefired internal combustion engine subject to this subpart?

Owners and operators of stationary SI ICE subject to this subpart that use gasoline must use gasoline that meets the per gallon sulfur limit in 40 CFR 80.195. 

§ 60.4236 What is the deadlinefor importingor installingstationary SI ICE produced in the previous model year?

(a) After July 1, 2010, owners and operators may not install stationary SI ICE with a maximum engine power of less than 500 HP that do not meet the applicable requirements in §60.4233. (b) After July 1, 2009, owners and operators may not install stationary SI ICE with a maximum engine power of greater than or equal to 500 HP that do not meet the applicable requirements in §60.4233, except that lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP that do not meet the applicable requirements in 

§60.4233 may not be installed after January 1, 2010.

(c) For emergency stationary SI ICE with a maximum engine power of greater than 19 KW (25 HP), owners and operators may not install engines that do not meet the applicable requirements in §60.4233 after January 1, 2011. (d) In addition to the requirements specified in §§60.4231 and 60.4233, it is prohibited to import stationary SI ICE less than or equal to 19 KW (25 HP), stationary rich burn LPG SI ICE, and stationary gasoline SI ICE that do not meet the applicable requirements specified in paragraphs (a), (b), and (c) of this section, after the date specified in paragraph (a), (b), and (c) of this section. (e) The requirements of this section do not apply to owners and operators of stationary SI ICE that have been modified or reconstructed, and they do not apply to engines that were removed from one existing location and reinstalled at a new location. § 60.4237 What are the monitoring requirements if I am an owner or operatorof an emergency stationarySI internal combustion engine? (a) Starting on July 1, 2010, if the emergency stationary SI internal combustion engine that is greater than or equal to 500 HP that was built on or after July 1, 2010, does not meet the standards applicable to non-emergency engines, the owner or operator must install a non-resettable hour meter. (b) Starting on January 1, 2011, if the emergency stationary SI internal combustion engine that is greater than or equal to 130 HP and less than 500 HP that was built on or after January 1, 2011, does not meet the standards applicable to non-emergency engines, the owner or operator must install a non-resettable hour meter. (c) If you are an owner or operator of an emergency stationary SI internal combustion engine that is less than 130 HP, was built on or after July 1, 2008, and does not meet the standards applicable to non-emergency engines, you must install a non-resettable hour meter upon startup of your emergency engine. Compliance Requirementsfor Manufacturers § 60.4238 What are my compliance requirements if I am a manufacturerof stationarySI internalcombustion engines

  • 19 KW (25 HP)or a manufacturer of equipment containing such engines?

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-5 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Stationary SI internal combustion engine manufacturers who are subject to the emission standards specified in §60.423 1(a) must certify their stationary SI ICE using the certification procedures required in 40 CFR part 90, subpart B, or 40 CFR part 1054, subpart C, as applicable, and must test their engines as specified in those parts. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, subpart C, to the extent they apply to equipment manufacturers. [73 FR 59176, Oct. 8, 2008] § 60.4239 What are my compliance requirementsif I am a manufacturer of stationarySI internalcombustion engines >19 KW (25 HP) that use gasoline or a manufacturerof equipment containingsuch engines? Stationary SI internal combustion engine manufacturers who are subject to the emission standards specified in §60.4231(b) must certify their stationary SI ICE using the certification procedures required in 40 CFR part 1048, subpart C, and must test their engines as specified in that part. Stationary SI internal combustion engine manufacturers who certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cc to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 40 CFR part 1054, and manufacturers of stationary SI emergency engines that are greater than 25 HP and less than 130 HP who meet the Phase 1 emission standards in 40 CFR 90.103, applicable to class II engines, must certify their stationary SI ICE using the certification procedures required in 40 CFR part 90, subpart B, or 40 CFR part 1054, subpart C, as applicable, and must test their engines as specified in those parts. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, subpart C, to the extent they apply to equipment manufacturers. [73 FR 59176, Oct. 8, 2008] § 60.4240 What are my compliance requirementsif I am a manufacturer of stationarySI internalcombustion engines >19 KW (25 HP) that are rich burn engines that use LPG or a manufacturerof equipment containingsuch engines? Stationary SI internal combustion engine manufacturers who are subject to the emission standards specified in §60.4231(c) must certify their stationary SI ICE using the certification procedures required in 40 CFR part 1048, subpart C, and must test their engines as specified in that part. Stationary SI internal combustion engine manufacturers who certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cc to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 40 CFR part 1054, and manufacturers of stationary SI emergency engines that are greater than 25 HP and less than 130 HP who meet the Phase 1 emission standards in 40 CFR 90.103, applicable to class II engines, must certify their stationary SI ICE using the certification procedures required in 40 CFR part 90, subpart B, or 40 CFR part 1054, subpart C, as applicable, and must test their engines as specified in those parts. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, subpart C, to the extent they apply to equipment manufacturers. [73 FR 59176, Oct. 8, 2008] § 60.4241 What are my compliance requirementsif I am a manufacturerof stationarySI internalcombustion engines participatingin the voluntary certificationprogram or a manufacturerof equipment containingsuch engines? (a) Manufacturers of stationary SI internal combustion engines with a maximum engine power greater than 19 KW (25 HP) that do not use gasoline and are not rich burn engines that use LPG can choose to certify their engines to the emission standards in §60.4231(d) or (e), as applicable, under the voluntary certification program described in this subpart. Manufacturers who certify their engines under the voluntary certification program must meet the requirements as specified in paragraphs (b) through (g) of this section. In addition, manufacturers of stationary SI internal combustion engines who choose to certify their engines under the voluntary certification program, must also meet the requirements as specified in §60.4247. (b) Manufacturers of engines other than those certified to standards in 40 CFR part 90 or 40 CFR part 1054 must certify their stationary SI ICE using the certification procedures required in 40 CFR part 1048, subpart C, and must follow the same test procedures that apply to large SI nonroad engines under 40 CFR part 1048, but must use the D-1 cycle of International Organization of Standardization 8178-4: 1996(E) (incorporated by reference, see 40 CFR 60.17) or the test cycle Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-6 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines requirements specified in Table 5 to 40 CFR 1048.505, except that Table 5 of 40 CFR 1048.505 applies to high load engines only. Stationary SI internal combustion engine manufacturers who certify their stationary SI ICE with a maximum engine power less than or equal to 30 KW (40 HP) with a total displacement less than or equal to 1,000 cc to the certification emission standards and other requirements for new nonroad SI engines in 40 CFR part 90 or 40 CFR part 1054, and manufacturers of emergency engines that are greater than 25 HP and less than 130 HP who meet the Phase 1 standards in 40 CFR 90.103, applicable to class II engines, must certify their stationary SI ICE using the certification procedures required in 40 CFR part 90, subpart B, or 40 CFR part 1054, subpart C, as applicable, and must test their engines as specified in those parts. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, subpart C, to the extent they apply to equipment manufacturers. (c) Certification of stationary S1 ICE to the emission standards specified in §60.423 1(d) or (e), as applicable, is voluntary, but manufacturers who decide to certify are subject to all of the requirements indicated in this subpart with regard to the engines included in their certification. Manufacturers must clearly label their stationary SI engines as certified or non-certified engines. (d) Manufacturers of natural gas fired stationary SI ICE who conduct voluntary certification of stationary SI ICE to the emission standards specified in §60.4231(d) or (e), as applicable, must certify their engines for operation using fuel that meets the definition of pipeline-quality natural gas. The fuel used for certifying stationary SI natural gas engines must meet the definition of pipeline-quality natural gas as described in §60.4248. In addition, the manufacturer must provide information to the owner and operator of the certified stationary SI engine including the specifications of the pipeline-quality natural gas to which the engine is certified and what adjustments the owner or operator must make to the engine when installed in the field to ensure compliance with the emission standards. (e) Manufacturers of stationary SI ICE that are lean burn engines fueled by LPG who conduct voluntary certification of stationary SI ICE to the emission standards specified in §60.4231(d) or (e), as applicable, must certify their engines for operation using fuel that meets the specifications in 40 CFR 1065.720. (f) Manufacturers may certify their engines for operation using gaseous fuels in addition to pipeline-quality natural gas; however, the manufacturer must specify the properties of that fuel and provide testing information showing that the engine will meet the emission standards specified in §60.423 1(d) or (e), as applicable, when operating on that fuel. The manufacturer must also provide instructions for configuring the stationary engine to meet the emission standards on fuels that do not meet the pipeline-quality natural gas definition. The manufacturer must also provide information to the owner and operator of the certified stationary SI engine regarding the configuration that is most conducive to reduced emissions where the engine will be operated on gaseous fuels with different quality than the fuel that it was certified to. (g) A stationary SI engine manufacturer may certify an engine family solely to the standards applicable to landfill/digester gas engines as specified in §60.4231(d) or (e), as applicable, but must certify their engines for operation using landfill/digester gas and must add a permanent label stating that the engine is for use only in landfill/digester gas applications. The label must be added according to the labeling requirements specified in 40 CFR 1048.135(b). (h) For purposes of this subpart, when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included. (i) For engines being certified to the voluntary certification standards in Table 1 of this subpart, the VOC measurement shall be made by following the procedures in 40 CFR 1065.260 and 1065.265 in order to determine the total NMHC emissions by using a flame-ionization detector and non-methane cutter. As an alternative to the nonmethane cutter, manufacturers may use a gas chromatograph as allowed under 40 CFR 1065.267 and may measure ethane, as well as methane, for excluding such levels from the total VOC measurement. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59176, Oct. 8, 2008] § 60.4242 What other requirements must I meet if I am a manufacturerof stationarySI internalcombustion engines or equipment containing stationarySI internalcombustion engines or a manufacturerof equipment containing such engines? (a) Stationary SI internal combustion engine manufacturers must meet the provisions of 40 CFR part 90, 40 CFR part 1048, or 40 CFR part 1054, as applicable, as well as 40 CFR part 1068 for engines that are certified to the emission standards in 40 CFR part 1048 or 1054, except that engines certified pursuant to the voluntary certification procedures in §60.4241 are Progress Energy Florida, Inc. 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APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines subject only to the provisions indicated in §60.4247 and are permitted to provide instructions to owners and operators allowing for deviations from certified configurations, if such deviations are consistent with the provisions of paragraphs §60.4241(c) through (f). Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060, as applicable. Labels on engines certified to 40 CFR part 1048 must refer to stationary engines, rather than or in addition to nonroad engines, as appropriate. (b) An engine manufacturer certifying an engine family or families to standards under this subpart that are identical to standards applicable under 40 CFR part 90, 40 CFR part 1048, or 40 CFR part 1054 for that model year may certify any such family that contains both nonroad and stationary engines as a single engine family and/or may include any such family containing stationary engines in the averaging, banking and trading provisions applicable for such engines under those parts. This provision also applies to equipment or component manufacturers certifying to standards under 40 CFR part 1060. (c) Manufacturers of engine families certified to 40 CFR part 1048 may meet the labeling requirements referred to in paragraph (a) of this section for stationary SI ICE by either adding a separate label containing the information required in paragraph (a) of this section or by adding the words "and stationary" after the word "nonroad" to the label. (d) For all engines manufactured on or after January 1, 2011, and for all engines with a maximum engine power greater than 25 HP and less than 130 HP manufactured on or after July 1, 2008, a stationary SI engine manufacturer that certifies an engine family solely to the standards applicable to emergency engines must add a permanent label stating that the engines in that family are for emergency use only. The label must be added according to the labeling requirements specified in 40 CFR 1048.135(b). (e) All stationary SI engines subject to mandatory certification that do not meet the requirements of this subpart must be labeled according to 40 CFR 1068.230 and must be exported under the provisions of 40 CFR 1068.230. Stationary SI engines subject to standards in 40 CFR part 90 may use the provisions in 40 CFR 90.909. Manufacturers of stationary engines with a maximum engine power greater than 25 HP that are not certified to standards and other requirements under 40 CFR part 1048 are subject to the labeling provisions of 40 CFR 1048.20 pertaining to excluded stationary engines. (f) For manufacturers of gaseous-fueled stationary engines required to meet the warranty provisions in 40 CFR 90.1103 or 1054.120, we may establish an hour-based warranty period equal to at least the certified emissions life of the engines (in engine operating hours) if we determine that these engines are likely to operate for a number of hours greater than the applicable useful life within 24 months. We will not approve an alternate warranty under this paragraph (f) for nonroad engines. An alternate warranty period approved under this paragraph (f) will be the specified number of engine operating hours or two years, whichever comes first. The engine manufacturer shall request this alternate warranty period in its application for certification or in an earlier submission. We may approve an alternate warranty period for an engine family subject to the following conditions: (1) The engines must be equipped with non-resettable hour meters. (2) The engines must be designed to operate for a number of hours substantially greater than the applicable certified emissions life. (3) The emission-related warranty for the engines may not be shorter than any published warranty offered by the manufacturer without charge for the engines. Similarly, the emission-related warranty for any component shall not be shorter than any published warranty offered by the manufacturer without charge for that component. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008] Compliance Requirementsfor Owners and Operators § 60.4243 What are my compliance requirementsif I am an owner or operatorof a stationarySI internalcombustion engine? (a) If you are an owner or operator of a stationary SI internal combustion engine that is manufactured after July 1, 2008, and must comply with the emission standards specified in §60.4233(a) through (c), you must comply by purchasing an engine certified to the emission standards in §60.4231(a) through (c), as applicable, for the same engine class and maximum engine power. You must also meet the requirements as specified in 40 CFR part 1068, subparts A through D, as they apply to you. If you adjust engine settings according to and consistent with the manufacturer's instructions, your stationary SI internal Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-8 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines combustion engine will not be considered out of compliance. In addition, you must meet one of the requirements specified in (a)(1) and (2) of this section. (1) If you operate and maintain the certified stationary SI internal combustion engine and control device according to the manufacturer's emission-related written instructions, you must keep records of conducted maintenance to demonstrate compliance, but no performance testing is required if you are an owner or operator. (2) If you do not operate and maintain the certified stationary SI internal combustion engine and control device according to the manufacturer's emission-related written instructions, your engine will be considered a non-certified engine, and you must demonstrate compliance according to (a)(2)(i) through (iii) of this section, as appropriate. (i) If you are an owner or operator of a stationary SI internal combustion engine less than 100 HP, you must keep a maintenance plan and records of conducted maintenance to demonstrate compliance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions, but no performance testing is required if you are an owner or operator. (ii) If you are an owner or operator of a stationary SI internal combustion engine greater than or equal to 100 HP and less than or equal to 500 HP, you must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, you must conduct an initial performance test within 1 year of engine startup to demonstrate compliance. (iii) If you are an owner or operator of a stationary SI internal combustion engine greater than 500 HP, you must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, you must conduct an initial performance test within 1 year of engine startup and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance. (b) If you are an owner or operator of a stationary SI internal combustion engine and must comply with the emission standards specified in §60.4233(d) or (e), you must demonstrate compliance according to one of the methods specified in paragraphs (b)(1) and (2) of this section. (1) Purchasing an engine certified according to procedures specified in this subpart, for the same model year and demonstrating compliance according to one of the methods specified in paragraph (a) of this section. (2) Purchasing a non-certified engine and demonstrating compliance with the emission standards specified in §60.4233(d) or (e) and according to the requirements specified in §60.4244, as applicable, and according to paragraphs (b)(2)(i) and (ii) of this section. (i) If you are an owner or operator of a stationary SI internal combustion engine greater than 25 HP and less than or equal to 500 HP, you must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, you must conduct an initial performance test to demonstrate compliance. (ii) If you are an owner or operator of a stationary SI internal combustion engine greater than 500 HP, you must keep a maintenance plan and records of conducted maintenance and must, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, you must conduct an initial performance test and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance. (c) If you are an owner or operator of a stationary SI internal combustion engine that must comply with the emission standards specified in §60.4233(f), you must demonstrate compliance according paragraph (b)(2)(i) or (ii) of this section, except that if you comply according to paragraph (b)(2)(i) of this section, you demonstrate that your non-certified engine complies with the emission standards specified in §60.4233(f). (d) Emergency stationary ICE may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by Federal, State or local government, the manufacturer, the vendor, or the insurance company associated with the engine. Maintenance checks and readiness testing of such units is limited to 100 hours per year. There is no time limit on the use of emergency stationary ICE in emergency situations. The owner or operator may petition the Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-9 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency ICE beyond 100 hours per year. Emergency stationary ICE may operate up to 50 hours per year in non-emergency situations, but those 50 hours are counted towards the 100 hours per year provided for maintenance and testing. The 50 hours per year for non-emergency situations cannot be used for peak shaving or to generate income for a facility to supply power to an electric grid or otherwise supply power as part of a financial arrangement with another entity. For owners and operators of emergency engines, any operation other than emergency operation, maintenance and testing, and operation in non-emergency situations for 50 hours per year, as permitted in this section, is prohibited. (e) Owners and operators of stationary SI natural gas fired engines may operate their engines using propane for a maximum of 100 hours per year as an alternative fuel solely during emergency operations, but must keep records of such use. If propane is used for more than 100 hours per year in an engine that is not certified to the emission standards when using propane, the owners and operators are required to conduct a performance test to demonstrate compliance with the emission standards of §60.4233. (f) If you are an owner or operator of a stationary SI internal combustion engine that is less than or equal to 500 HP and you purchase a non-certified engine or you do not operate and maintain your certified stationary SI internal combustion engine and control device according to the manufacturer's written emission-related instructions, you are required to perform initial performance testing as indicated in this section, but you are not required to conduct subsequent performance testing unless the stationary engine is rebuilt or undergoes major repair or maintenance. A rebuilt stationary SI ICE means an engine that has been rebuilt as that term is defined in 40 CFR 94.1 1(a). (g) It is expected that air-to-fuel ratio controllers will be used with the operation of three-way catalysts/non-selective catalytic reduction. The AFR controller must be maintained and operated appropriately in order to ensure proper operation of the engine and control device to minimize emissions at all times. (h) If you are an owner/operator of an stationary SI internal combustion engine with maximum engine power greater than or equal to 500 HP that is manufactured after July 1, 2007 and before July 1, 2008, and must comply with the emission standards specified in sections 60.4233(b) or (c), you must comply by one of the methods specified in paragraphs (h)(1) through (h)(4) of this section. (1) Purchasing an engine certified according to 40 CFR part 1048. The engine must be installed and configured according to the manufacturer's specifications. (2) Keeping records of performance test results for each pollutant for a test conducted on a similar engine. The test must have been conducted using the same methods specified in this subpart and these methods must have been followed correctly. (3) Keeping records of engine manufacturer data indicating compliance with the standards. (4) Keeping records of control device vendor data indicating compliance with the standards. Testing Requirementsfor Owners and Operators § 60.4244 What test methods and otherprocedures must I use if I am an owner or operatorof a stationarySI internal combustion engine? Owners and operators of stationary SI ICE who conduct performance tests must follow the procedures in paragraphs (a) through (f) of this section. (a) Each performance test must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and according to the requirements in §60.8 and under the specific conditions that are specified by Table 2 to this subpart. (b) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in §60.8(c). If your stationary SI internal combustion engine is non-operational, you do not need to startup the engine solely to conduct a performance test; however, you must conduct the performance test immediately upon startup of the engine. (c) You must conduct three separate test runs for each performance test required in this section, as specified in §60.8(f). Each test run must be conducted within 10 percent of 100 percent peak (or the highest achievable) load and last at least 1 hour. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-10 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (d) To determine compliance with the NOx mass per unit output emission limitation, convert the concentration of NOx in the engine exhaust using Equation 1 of this section: ER-Cax 1.912 x 10-3x Q x T HP -hr Where: ER = Emission rate of NOx in g/HP-hr. Cd = Measured NOx concentration in parts per million by volume (ppmv). 1.912x10- 3 = Conversion constant for ppm NOx to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meter per hour, dry basis. T = Time of test run, in hours. HP-hr = Brake work of the engine, horsepower-hour (HP-hr). (e) To determine compliance with the CO mass per unit output emission limitation, convert the concentration of CO in the engine exhaust using Equation 2 of this section: ER = Ca x 1.164 x 10-3 x Q x T HP -hr Where: ER = Emission rate of CO in g/HP-hr. Cd = Measured CO concentration in ppmv. 1.164x10- 3 = Conversion constant for ppm CO to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis. T = Time of test run, in hours. HP-hr = Brake work of the engine, in HP-hr. (f) For purposes of this subpart, when calculating emissions of VOC, emissions of formaldehyde should not be included. To determine compliance with the VOC mass per unit output emission limitation, convert the concentration of VOC in the engine exhaust using Equation 3 of this section: ER= Ca x 1.833HPx 3xHP-hr(Eq. hr Q xT 3) Where: ER = Emission rate of VOC in g/HP-hr. Cd = VOC concentration measured as propane in ppmv. 1.833x 10- 3 = Conversion constant for ppm VOC measured as propane, to grams per standard cubic meter at 20 degrees Celsius. Q = Stack gas volumetric flow rate, in standard cubic meters per hour, dry basis. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-1 1 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines T = Time of test run, in hours. HP-hr = Brake work of the engine, in HP-hr. (g) If the owner/operator chooses to measure VOC emissions using either Method 18 of 40 CFR part 60, appendix A, or Method 320 of 40 CFR part 63, appendix A, then it has the option of correcting the measured VOC emissions to account for the potential differences in measured values between these methods and Method 25A. The results from Method 18 and Method 320 can be corrected for response factor differences using Equations 4 and 5 of this section. The corrected VOC concentration can then be placed on a propane basis using Equation 6 of this section. RFý - C Eq-4) CkM Where: RFi = Response factor of compound i when measured with EPA Method 25A. CMi = Measured concentration of compound i in ppmv as carbon. CAi = True concentration of compound i in ppmv as carbon. C,_ RFCixC (Eq. 5) Where: Cicorr = Concentration of compound i corrected to the value that would have been measured by EPA Method 25A, ppmv as carbon. Cimeas = Concentration of compound i measured by EPA Method 320, ppmv as carbon. Cr,: 0.6098 xCi. (Eq. 6) Where: CPeq = Concentration of compound i in mg of propane equivalent per DSCM. Notification, Reports, and Records for Owners and Operators § 60.4245 What are my notification, reporting,and recordkeeping requirements if Iam an owner or operatorof a stationarySI internalcombustion engine? Owners or operators of stationary SI ICE must meet the following notification, reporting and recordkeeping requirements. (a) Owners and operators of all stationary SI ICE must keep records of the information in paragraphs (a)(1) through (4) of this section. (1) All notifications submitted to comply with this subpart and all documentation supporting any notification. (2) Maintenance conducted on the engine. (3) If the stationary SI internal combustion engine is a certified engine, documentation from the manufacturer that the engine is certified to meet the emission standards and information as required in 40 CFR parts 90, 1048, 1054, and 1060, as applicable. (4) If the stationary SI internal combustion engine is not a certified engine or is a certified engine operating in a non-certified manner and subject to §60.4243(a)(2), documentation that the engine meets the emission standards. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-12 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (b) For all stationary SI emergency ICE greater than or equal to 500 HP manufactured on or after July 1, 2010, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than or equal to 130 HP and less than 500 HP manufactured on or after July 1, 2011 that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. For all stationary SI emergency ICE greater than 25 HP and less than 130 HP manufactured on or after July 1, 2008, that do not meet the standards applicable to non-emergency engines, the owner or operator of must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter. The owner or operator must document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non-emergency operation. (c) Owners and operators of stationary SI ICE greater than or equal to 500 HP that have not been certified by an engine manufacturer to meet the emission standards in §60.4231 must submit an initial notification as required in §60.7(a)(1). The notification must include the information in paragraphs (c)(1) through (5) of this section. (1) Name and address of the owner or operator; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used. (d) Owners and operators of stationary SI ICE that are subject to performance testing must submit a copy of each performance test as conducted in §60.4244 within 60 days after the test has been completed. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008] GeneralProvisions § 60.4246 What parts of the General Provisionsapply to me? Table 3 to this subpart shows which parts of the General Provisions in §§60.1 through 60.19 apply to you. Mobile Source Provisions § 60.4247 What parts of the mobile source provisions apply to me if I am a manufacturerof stationarySI internal combustion engines or a manufacturer of equipment containingsuch engines? (a) Manufacturers certifying to emission standards in 40 CFR part 90, including manufacturers certifying emergency engines below 130 HP, must meet the provisions of 40 CFR part 90. Manufacturers certifying to emission standards in 40 CFR part 1054 must meet the provisions of 40 CFR part 1054. Manufacturers of equipment containing stationary SI internal combustion engines meeting the provisions of 40 CFR part 1054 must meet the provisions of 40 CFR part 1060 to the extent they apply to equipment manufacturers. (b) Manufacturers required to certify to emission standards in 40 CFR part 1048 must meet the provisions of 40 CFR part 1048. Manufacturers certifying to emission standards in 40 CFR part 1048 pursuant to the voluntary certification program must meet the requirements in Table 4 to this subpart as well as the standards in 40 CFR 1048.101. (c) For manufacturers of stationary SI internal combustion engines participating in the voluntary certification program and certifying engines to Table I to this subpart, Table 4 to this subpart shows which parts of the mobile source provisions in 40 CFR parts 1048, 1065, and 1068 apply to you. Compliance with the deterioration factor provisions under 40 CFR 1048.205(n) and 1048.240 will be required for engines built new on and after January 1, 2010. Prior to January 1, 2010, Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ- 13 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines manufacturers of stationary internal combustion engines participating in the voluntary certification program have the option to develop their own deterioration factors based on an engineering analysis. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008] Definitions § 60.4248 What definitions apply to this subpart? As used in this subpart, all terms not defined herein shall have the meaning given them in the CAA and in subpart A of this part. Certified emissions life means the period during which the engine is designed to properly function in terms of reliability and fuel consumption, without being remanufactured, specified as a number of hours of operation or calendar years, whichever comes first. The values for certified emissions life for stationary SI ICE with a maximum engine power less than or equal to 19 KW (25 HP) are given in 40 CFR 90.105, 40 CFR 1054.107, and 40 CFR 1060.101, as appropriate. The values for certified emissions life for stationary SI ICE with a maximum engine power greater than 19 KW (25 HP) certified to 40 CFR part 1048 are given in 40 CFR 1048.101(g). The certified emissions life for stationary SI ICE with a maximum engine power greater than 75 KW (100 HP) certified under the voluntary manufacturer certification program of this subpart is 5,000 hours or 7 years, whichever comes first. Certified stationaryinternal combustion engine means an engine that belongs to an engine family that has a certificate of conformity that complies with the emission standards and requirements in this part, or of 40 CFR part 90, 40 CFR part 1048, or 40 CFR part 1054, as appropriate. Combustion turbine means all equipment, including but not limited to the turbine, the fuel, air, lubrication and exhaust gas systems, control systems (except emissions control equipment), and any ancillary components and sub-components comprising any simple cycle combustion turbine, any regenerative/recuperative cycle combustion turbine, the combustion turbine portion of any cogeneration cycle combustion system, or the combustion turbine portion of any combined cycle steam/electric generating system. Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine. Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is number 2 distillate oil. Digestergas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and carbon dioxide (C02). Emergency stationary internal combustion engine means any stationary internal combustion engine whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary ICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary ICE used to pump water in the case of fire or flood, etc. Stationary SI ICE used for peak shaving are not considered emergency stationary ICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines. Engine manufacturermeans the manufacturer of the engine. See the definition of "manufacturer" in this section. Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution. Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline. Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-14 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich bum engine. Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production. Manufacturer has the meaning given in section 216(1) of the Clean Air Act. In general, this term includes any person who manufactures a stationary engine for sale in the United States or otherwise introduces a new stationary engine into commerce in the United States. This includes importers who import stationary engines for resale. Maximum engine power means maximum engine power as defined in 40 CFR 1048.801. Model year means either: The calendar year in which the engine was originally produced, or the annual new model production period of the engine manufacturer if it is different than the calendar year. This must include January 1 of the calendar year for which the model year is named. It may not begin before January 2 of the previous calendar year, and it must end by December 31 of the named calendar year. For an engine that is converted to a stationary engine after being placed into service as a nonroad or other non-stationary engine, model year means the calendar year or new model production period in which the engine was originally produced. Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality. Other internal combustion engine means any internal combustion engine, except combustion turbines, which is not a reciprocating internal combustion engine or rotary internal combustion engine. Pipeline-qualitynaturalgas means a naturally occurring fluid mixture of hydrocarbons (e.g., methane, ethane, or propane) produced in geological formations beneath the Earth's surface that maintains a gaseous state at standard atmospheric temperature and pressure under ordinary conditions, and which is provided by a supplier through a pipeline. Pipeline-quality natural gas must either be composed of at least 70 percent methane by volume or have a gross calorific value between 950 and 1,100 British thermal units per standard cubic foot. Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to June 12, 2006, with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich bum engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent. Rotary internal combustion engine means any internal combustion engine which uses rotary motion to convert heat energy into mechanical work. Spark ignition means relating to either: a gasoline-fueled engine; or any other type of engine with a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines. Stationary internal combustion engine means any internal combustion engine, except combustion turbines, that converts heat energy into mechanical work and is not mobile. Stationary ICE differ from mobile ICE in that a stationary internal combustion engine is not a nonroad engine as defined at 40 CFR 1068.30 (excluding paragraph (2)(ii) of that definition), and is not used to propel a motor vehicle or a vehicle used solely for competition. Stationary ICE include reciprocating ICE, rotary ICE, and other ICE, except combustion turbines. Stationary internal combustion engine test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that test stationary ICE. Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-15 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Subpart means 40 CFR part 60, subpart JJJJ. Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric. Volatile organic compounds means volatile organic compounds as defined in 40 CFR 5 1.100(s). Voluntary certificationprogram means an optional engine certification program that manufacturers of stationary SI internal combustion engines with a maximum engine power greater than 19 KW (25 HP) that do not use gasoline and are not rich burn engines that use LPG can choose to participate in to certify their engines to the emission standards in §60.4231(d) or (e), as applicable. [73 FR 3591, Jan. 18, 2008, as amended by 73 FR 59177, Oct. 8, 2008] Table I to Subpart JJJJof Part 60-NOx, CO, and VOC Emission Standardsfor StationaryNon-Emergency SI Engines >100 HP (Except Gasoline and Rich Burn LPG), StationarySI Landfill/DigesterGas Engines, and Stationary Emergency Engines >25 HP Emission Standards' Maximum engine Manufacture irnr g/HP-hr ]ppmvd at 15% 02 02 Engine type and fuel power date N cCO FVO NOx O Non-Emergency SI Natural Gasb and Non- 100<HP<500 7/1/2008 2.0 4.0 1.0 160 540 86 Emergency SI Lean Burn LPG b 1/1/2011[ 1.0 120 [ 0.7 82 270 60] Non-Emergency SI Lean Burn Natural Gas and 500>HP<1,350 1/1/20081 2.0 4. 0 1.0 1601 540 86 LPG 7/1/2010 1 1.0 1 3i 0.7 82 270] 60 Non-Emergency SI Natural Gas and Non- HP>500 7/1/2007 2.0 4.1 1.0 161 540 86 Emergency SI Lean Burn LPG (except lean burn HP2500 7/1/201007 82 270 60 500=>-HP<1,350) Landfill/Digester Gas (except lean burn HP<500 7/1/20081 3.0 5.00 1.0 220 610 80 500>HP<1,350) 1/1/2011 2.0 [5.0 1.0] 150] 610 80 HP>s500 7/1/2007 3.0 5.0] 1.0 220] 610 80 7/1/2010 2.0 5.0] 1.0 150] 610 80 Landfill/Digester Gas Lean Burn 500>HP<1,350 1/1/20081 3]0[5.1 1.0 220] 610 80 7/1/201 0 5.0]1 1.01150] 610 80 Emergency 25>HP<130 1/1/2009 1J2.0[4. Cl 387 N/A N/A N/A 1.0 160] 540 N/A 86 HP> 130 1L aOwners and operators of stationary non-certified SI engines may choose to comply with the emission standards in units of either g/HP-hr or ppmvd at 15 percent 02. bOwners and operators of new or reconstructed non-emergency lean burn SI stationary engines with a site rating of greater than or equal to 250 brake HP located at a major source that are meeting the requirements of 40 CFR part 63, subpart ZZZZ, Table 2A do not have to comply with the CO emission standards of Table 1 of this subpart. cThe emission standards applicable to emergency engines between 25 HP and 130 HP are in terms of NOx+HC. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-16 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines dFor purposes of this subpart, when calculating emissions of volatile organic compounds, emissions of formaldehyde should not be included. Table 2 to SubpartJJJJof Part60-Requirementsfor Performance Tests [As stated in §60.4244, you must comply with the following requirements for performance tests within 10 percent of 100 percent peak (or the highest achievable) load] According to the Complying with the following For each requirement to You must Using requirements

1. Stationary SI a. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a internal combustion concentration of NOxin location and the number of 40 CFR part 60, control device, the engine the stationary SI internal traverse points; appendix A or ASTM sampling site must demonstrating combustion engine Method D6522- be located at the compliance exhaust. 00(2005)a. outlet of the control according to device.

§60.4244. ii. Determine the (2) Method 3, 3A, or 3Bbof 40 (b) Measurements to 

                    %2concentration of the      CFR part 60, appendix A or         determine stationary internal         ASTM Method D6522-                 O 2concentration must combustion engine           00(2005)'.                         be made at the same exhaust at the sampling                                        time as the port location;                                                 measurements for NOx concentration.

iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60. stationary internal combustion engine exhaust; iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see §60.17). measurement for NOx sampling port location; concentration. and

v. Measure NOx at the (5) Method 7E of 40 CFR part 60, (d) Results of this test exhaust of the stationary appendix A, Method D6522- consist of the average of internal combustion 00(2005)', Method 320 of 40 the three 1-hour or engine. CFR part 63, appendix A, or longer runs.

ASTM D6348-03 (incorporated by reference, see §60.17).

b. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a concentration of CO in location and the number of 40 CFR part 60, control device, the the stationary SI internal traverse points; appendix A. sampling site must combustion engine be located at the exhaust. outlet of the control device.

ii. Determine the (2) Method 3, 3A, or 3Bb of 40 (b) Measurements to O2 concentration of the CFR part 60, appendix A or determine stationary internal ASTM Method D6522- O 2concentration must Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-17 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines combustion engine 00(2005)a. be made at the same exhaust at the sampling time as the port location; measurements for CO concentration. iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60. stationary internal combustion engine exhaust; iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see §60.17). measurement for CO sampling port location; concentration. and

v. Measure CO at the (5) Method 10 of 40 CFR part 60, (d) Results of this test exhaust of the stationary appendix A, ASTM Method consist of the average of internal combustion D6522-00(2005)a, Method 320 of the three 1-hour or engine. 40 CFR part 63, appendix A, or longer runs.

ASTM D 6348-03 (incorporated by reference, see §60.17).

c. limit the i. Select the sampling port (1) Method 1 or 1A of (a) If using a concentration of VOC location and the number of 40 CFR part 60, control device, the in the stationary SI traverse points; appendix A. sampling site must internal combustion be located at the engine exhaust. outlet of the control device.

ii. Determine the (2) Method 3, 3A, or 3Bbof 40 (b) Measurements to O 2concentration of the CFR part 60, appendix A or determine stationary internal ASTM Method D6522- O 2 concentration must combustion engine 00(2005)'. be made at the same exhaust at the sampling time as the port location; measurements for VOC concentration. iii. Determine the (3) Method 2 or 19 of 40 CFR exhaust flowrate of the part 60. stationary internal combustion engine exhaust; iv. If necessary, (4) Method 4 of 40 CFR part 60, (c) Measurements to measure moisture appendix A, Method 320 of 40 determine moisture content of the stationary CFR part 63, appendix A, or must be made at the internal combustion ASTM D6348-03 (incorporated same time as the engine exhaust at the by reference, see §60.17). measurement for VOC sampling port location; concentration. and

v. Measure VOC at the (5) Methods 25A and 18 of 40 (d) Results of this test exhaust of the stationary CFR part 60, appendix A, Method consist of the average of internal combustion 25A with the use of a methane the three 1-hour or engine, cutter as described in 40 CFR longer runs.

1065.265, Method 18 or 40 CFR Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-18 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines part 60, appendix A,cd Method 320 of 40 CFR part 63, appendix A, or ASTM D6348-03 (incorporated by reference, see 

                                                   §60.17).
  'ASTM D6522-00 is incorporated by reference; see 40 CFR 60.17. Also, you may petition the Administrator for approval to use alternative methods for portable analyzer.

byou may use ASME PTC 19.10-1981, Flue and Exhaust Gas Analyses, for measuring the O 2content of the exhaust gas as an alternative to EPA Method 3B. cYou may use EPA Method 18 of 40 CFR part 60, appendix A, provided that you conduct an adequate presurvey test prior to the emissions test, such as the one described in OTM 11 on EPA's Web site ( http://www.epa.gov/ttn/emc/prelim/otmll.pdf). dYou may use ASTM D6420-99 (2004), Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography/Mass Spectrometry as an alternative to EPA Method 18 for measuring total nonmethane organic. Table 3 to Subpart JJJJof Part 60-Applicabilityof GeneralProvisions to SubpartJJJJ [As stated in §60.4246, you must comply with the following applicable General Provisions] General provisions Applies to citation Subject of citation subpart Explanation 

  §60.1                 General applicability of the         Yes General Provisions
  §60.2                [Definitions                           Yes          Additional terms defined in §60.4248.
  §60.3                Units and abbreviations               Yes
  §60.4                [Address                             ][Yes
  §60.5                 Determination of construction or     Yes

_modification _ _ [§60.6 [Review of plans Yes [§60.7 [Notification and Recordkeeping Yes Except that §60.7 only applies as specified in §60.4245. 

  §60.8
  §60.8                 Performance tests Performance_   tests 1Yes            Except that §60.8 only applies to owners and operators
                                                                       -]who are subject to performance testing in subpart JJJJ.

I [§60.9 [Availability of information Yes [§60.10 State Authority Yes 

  §60.11               Compliance with standards and         Yes          [Requirements are specified in subpart JJJJ.

_maintenance requirements 

  §60.12               [Circumvention                      ]IYes          IF
  §60.13               Monitoring requirements               No
  §60.14               Modification                           Yes
  §60.15               Reconstruction                         Yes Progress Energy Florida, Inc.                                                                       Permit No. 0170004-024-AV Crystal River Power Plant                                                                                 Title V Permit Renewal Page JJJJ-19 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines §60.16 Priority list Yes §60.17 Incorporations by reference Yes §60.18 General control device No requirements §60.19 

                 ]requirements General notification and reporting Yes

___ _ Table 4 to SubpartJJJJof Part 60-Applicability of Mobile Source Provisionsfor ManufacturersParticipatingin the Voluntary CertificationProgramand Certifying Stationary SI ICE to Emission Standards in Table I of SubpartJJJJ [As stated in §60.4247, you must comply with the following applicable mobile source provisions if you are a manufacturer participating in the voluntary certification program and certifying stationary SI ICE to emission standards in Table 1 of subpart JJJJ] Mobile source provisions Applies to citation Subject of citation subpart Explanation 1048 subpart A Overview and Applicability Yes 1048 subpart B Emission Standards and Related Requirements Yes Except for the specific sections below. 1048.101 Exhaust Emission Standards No 1048.105 Evaporative Emission Standards No 1048.110 Diagnosing Malfunctions No 1048.140 Certifying Blue Sky Series Engines No 1048.145 Interim Provisions No 1048 subpart C Certifying Engine Families Yes Except for the specific sections below. 1048.205(b) AECD reporting Yes 1048.205(c) OBD Requirements No 1048.205(n) Deterioration Factors Yes Except as indicated in 60.4247(c). 1048.205(p)(1) Deterioration Factor Discussion Yes 1048.205(p)(2) Liquid Fuels as they require No 1048.240(b)(c)(d) Deterioration Factors Yes 1048 subpart D Testing Production-Line Engines Yes 1048 subpart E Testing In-Use Engines No 1048 subpart F Test Procedures Yes 1065.5(a)(4) Raw sampling (refers reader back to the specific Yes emissions regulation for guidance) 1048 subpart G Compliance Provisions Yes 1048 subpart H Reserved Progress Energy Florida, Inc. Permit No. 01 70004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-20 of 21

APPENDIX NSPS SUBPART JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 1048 subpart I Definitions and Other Reference Information Yes 1048 appendix I and II Yes 1065 (all subparts) Engine Testing Procedures Yes Except for the specific section below. 1065.715 Test Fuel Specifications for Natural Gas No 1068 (all subparts) General Compliance Provisions for Nonroad Programs Yes Except for the specific sections below. 1068.245 Hardship Provisions for Unusual Circumstances No 1068.250 Hardship Provisions for Small-Volume Manufacturers No 1068.255 Hardship Provisions for Equipment Manufacturers and Secondary Engine Manufacturers Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page JJJJ-21 of 21

APPENDIX NESHAP SUBPART A General Provisions 40 CFR 63 Subpart A - General Provisions § 63.1 Applicability. (a) General. (1) Terms used throughout this part are defined in § 63.2 or in the Clean Air Act (Act) as amended in 1990, except that individual subparts of this part may include specific definitions in addition to or that supersede definitions in § 63.2. (2) This part contains national emission standards for hazardous air pollutants (NESHAP) established pursuant to section 112 of the Act as amended November 15, 1990. These standards regulate specific categories of stationary sources that emit (or have the potential to emit) one or more hazardous air pollutants listed in this part pursuant to section 112(b) of the Act. This section explains the applicability of such standards to sources affected by them. The standards in this part are independent of NESHAP contained in 40 CFR part 61. The NESHAP in part 61 promulgated by signature of the Administrator before November 15, 1990 (i.e., the date of enactment of the Clean Air Act Amendments of 1990) remain in effect until they are amended, if appropriate, and added to this part. (3) No emission standard or other requirement established under this part shall be interpreted, construed, or applied to diminish or replace the requirements of a more stringent emission limitation or other applicable requirement established by the Administrator pursuant to other authority of the Act (section 111, part C or D or any other authority of this Act), or a standard issued under State authority. The Administrator may specify in a specific standard under this part that facilities subject to other provisions under the Act need only comply with the provisions of that standard. (4) (i) Each relevant standard in this part 63 must identify explicitly whether each provision in this subpart A is or is not included in such relevant standard. (ii) If a relevant part 63 standard incorporates the requirements of 40 CFR part 60, part 61, or other part 63 standards, the relevant part 63 standard must identify explicitly the applicability of each corresponding part 60,part 61, or other part 63 subpart A (General) Provision. (iii) The General Provisions in this Subpart A do not apply to regulations developed pursuant to section 112(r) of the amended Act., unless otherwise specified in those regulations. (5) [Reserved] (6) To obtain the most current list of categories of sources to be regulated under section 112 of the Act, or to obtain the most recent regulation promulgation schedule established pursuant to section 112(e) of the Act, contact the Office of the Director, Emission Standards Division, Office of Air Quality Planning and Standards, U.S. EPA (MD-13), Research Triangle Park, North Carolina 27711. (7) [Reserved] (8) [Reserved] (9) [Reserved] (10) For the purposes of this part, time periods specified in days shall be measured in calendar days, even if the word "calendar" is absent, unless otherwise specified in an applicable requirement. (11) For the purposes of this part, if an explicit postmark deadline is not specified in an applicable requirement for the submittal of a notification, application, test plan, report, or other written communication to the Administrator, the owner or operator shall postmark the submittal on or before the number of days specified in the applicable requirement. For example, if a notification must be submitted 15 days before a particular event is scheduled to take place, the notification shall be postmarked on or before 15 days preceding the event; likewise, if a notification must be submitted 15 days after a particular event takes place, the notification shall be postmarked on or before 15 days following the end of the event. The use of reliable non-Government mail carriers that provide indications of verifiable delivery of information required to be submitted to the Administrator, similar to the postmark provided by the U.S. Postal Service, or alternative means of delivery agreed to by the permitting authority, is acceptable. (12) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. Procedures governing the implementation of this provision are specified in § 63.9(i). (13) [Reserved] (14) [Reserved] (b) Initial applicabilitydeterminationfor this part. (1) The provisions of this part apply to the owner or operator of any stationary source that - (i) Emits or has the potential to emit any hazardous air pollutant listed in or pursuant to section 112(b) of the Act; and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-1 of 45

APPENDIX NESHAP SUBPART A General Provisions (ii) Is subject to any standard, limitation, prohibition, or other federally enforceable requirement established pursuant to this part. (2) [Reserved] (3) An owner or operator of a stationary source who is in the relevant source category and who determines that the source is not subject to a relevant standard or other requirement established under this part, must keep a record as specified in 

§ 63.10(b)(3).

(c) Applicability of this part after a relevant standardhas been set under this part. (1) If a relevant standard has been established under this part, the owner or operator of an affected source must comply with the provisions of that standard and of this subpart as provided in paragraph (a)(4) of this section. (2) Except as provided in § 63.10(b)(3), if a relevant standard has been established under this part, the owner or operator of an affected source may be required to obtain a title V permit from a permitting authority in the State in which the source is located. Emission standards promulgated in this part for area sources pursuant to section 112(c)(3) of the Act will specify whether - (i) States will have the option to exclude area sources affected by that standard from the requirement to obtain a title V permit (i.e., the standard will exempt the category of area sources altogether from the permitting requirement); (ii) States will have the option to defer permitting of area sources in that category until the Administrator takes rulemaking action to determine applicability of the permitting requirements; or (iii) If a standard fails to specify what the permitting requirements will be for area sources affected by such a standard, then area sources that are subject to the standard will be subject to the requirement to obtain a title V permit without any deferral. (3) [Reserved] (4) [Reserved] (5) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source also shall be subject to the notification requirements of this subpart. (d) [Reserved] (e) If the Administrator promulgates an emission standard under section 112(d) or (h) of the Act that is applicable to a source subject to an emission limitation by permit established under section 112(j) of the Act, and the requirements under the section 1120) emission limitation are substantially as effective as the promulgated emission standard, the owner or operator may request the permitting authority to revise the source's title V permit to reflect that the emission limitation in the permit satisfies the requirements of the promulgated emission standard. The process by which the permitting authority determines whether the section 112(j) emission limitation is substantially as effective as the promulgated emission standard must include, consistent with part 70 or 71 of this chapter, the opportunity for full public, EPA, and affected State review (including the opportunity for EPA's objection) prior to the permit revision being finalized. A negative determination by the permitting authority constitutes final action for purposes of review and appeal under the applicable title V operating permit program. § 63.2 Definitions. The terms used in this part are defined in the Act or in this section as follows: Act means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Pub. L. 101-549, 104 Stat. 2399). Actual emissions is defined in subpart D of this part for the purpose of granting a compliance extension for an early reduction of hazardous air pollutants. Administratormeans the Administrator of the United States Environmental Protection Agency or his or her authorized representative (e.g., a State that has been delegated the authority to implement the provisions of this part). Affected source, for the purposes of this part, means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory for which a section 112(d) standard or other relevant standard is established pursuant to section 112 of the Act. Each relevant standard will define the "affected source," as defined in this paragraph unless a different definition is warranted based on a published justification as to why this definition would result in significant administrative, practical, or implementation problems and why the different definition would resolve those problems. The term "affected source," as used in this part, is separate and distinct from any other use of that term in EPA regulations such as those implementing title IV of the Act. Affected source Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-2 of 45

APPENDIX NESHAP SUBPART A General Provisions may be defined differently for part 63 than affected facility and stationary source in parts 60 and 61, respectively. This definition of "affected source," and the procedures for adopting an alternative definition of "affected source," shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002. Alternative emission limitation means conditions established pursuant to sections 112(i)(5) or 112(i)(6) of the Act by the Administrator or by a State with an approved permit program. Alternative emission standardmeans an alternative means of emission limitation that, after notice and opportunity for public comment, has been demonstrated by an owner or operator to the Administrator's satisfaction to achieve a reduction in emissions of any air pollutant at least equivalent to the reduction in emissions of such pollutant achieved under a relevant design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act. Alternative test method means any method of sampling and analyzing for an air pollutant that is not a test method in this chapter and that has been demonstrated to the Administrator's satisfaction, using Method 301 in Appendix A of this part, to produce results adequate for the Administrator's determination that it may be used in place of a test method specified in this part. Approved permit programmeans a State permit program approved by the Administrator as meeting the requirements of part 70 of this chapter or a Federal permit program established in this chapter pursuant to title V of the Act (42 U.S.C. 7661). Area source means any stationary source of hazardous air pollutants that is not a major source as defined in this part. Commenced means, with respect to construction or reconstruction of an affected source, that an owner or operator has undertaken a continuous program of construction or reconstruction or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of construction or reconstruction. Compliance date means the date by which an affected source is required to be in compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established by the Administrator (or a State with an approved permit program) pursuant to section 112 of the Act. Compliance schedule means: (1) In the case of an affected source that is in compliance with all applicable requirements established under this part, a statement that the source will continue to comply with such requirements; or (2) In the case of an affected source that is required to comply with applicable requirements by a future date, a statement that the source will meet such requirements on a timely basis and, if required by an applicable requirement, a detailed schedule of the dates by which each step toward compliance will be reached; or (3) In the case of an affected source not in compliance with all applicable requirements established under this part, a schedule of remedial measures, including an enforceable sequence of actions or operations with milestones and a schedule for the submission of certified progress reports, where applicable, leading to compliance with a relevant standard, limitation, prohibition, or any federally enforceable requirement established pursuant to section 112 of the Act for which the affected source is not in compliance. This compliance schedule shall resemble and be at least as stringent as that contained in any judicial consent decree or administrative order to which the source is subject. Any such schedule of compliance shall be supplemental to, and shall not sanction non-compliance with, the applicable requirements on which it is based. Construction means the on-site fabrication, erection, or installation of an affected source. Construction does not include the removal of all equipment comprising an affected source from an existing location and reinstallation of such equipment at a new location. The owner or operator of an existing affected source that is relocated may elect not to reinstall minor ancillary equipment including, but not limited to, piping, ductwork, and valves. However, removal and reinstallation of an affected source will be construed as reconstruction if it satisfies the criteria for reconstruction as defined in this section. The costs of replacing minor ancillary equipment must be considered in determining whether the existing affected source is reconstructed. Continuous emission monitoring system (CEMS) means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of emissions. Continuous monitoring system (CMS) is a comprehensive term that may include, but is not limited to, continuous emission monitoring systems, continuous opacity monitoring systems, continuous parameter monitoring systems, or other manual or automatic monitoring that is used for demonstrating compliance with an applicable regulation on a continuous basis as defined by the regulation. Continuous opacity monitoring system (COMS) means a continuous monitoring system that measures the opacity of emissions. Continuous parametermonitoring system means the total equipment that may be required to meet the data acquisition and availability requirements of this part, used to sample, condition (if applicable), analyze, and provide a record of process or control system parameters. Effective date means: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-3 of 45

APPENDIX NESHAP SUBPART A General Provisions (1) With regard to an emission standard established under this part, the date of promulgation in the FEDERAL REGISTER of such standard; or (2) With regard to an alternative emission limitation or equivalent emission limitation determined by the Administrator (or a State with an approved permit program), the date that the alternative emission limitation or equivalent emission limitation becomes effective according to the provisions of this part. Emission standardmeans a national standard, limitation, prohibition, or other regulation promulgated in a subpart of this part pursuant to sections 112(d), 112(h), or 112(f) of the Act. Emissions averaging is a way to comply with the emission limitations specified in a relevant standard, whereby an affected source, if allowed under a subpart of this part, may create emission credits by reducing emissions from specific points to a level below that required by the relevant standard, and those credits are used to offset emissions from points that are not controlled to the level required by the relevant standard. EPA means the United States Environmental Protection Agency. Equivalent emission limitation means any maximum achievable control technology emission limitation or requirements which are applicable to a major source of hazardous air pollutants and are adopted by the Administrator (or a State with an approved permit program) on a case-by-case basis, pursuant to section 112(g) or (j) of the Act. Excess emissions and continuous monitoring system performance report is a report that must be submitted periodically by an affected source in order to provide data on its compliance with relevant emission limits, operating parameters, and the performance of its continuous parameter monitoring systems. Existing source means any affected source that is not a new source. Federally enforceable means all limitations and conditions that are enforceable by the Administrator and citizens under the Act or that are enforceable under other statutes administered by the Administrator. Examples of federally enforceable limitations and conditions include, but are not limited to: (1) Emission standards, alternative emission standards, alternative emission limitations, and equivalent emission limitations established pursuant to section 112 of the Act as amended in 1990; (2) New source performance standards established pursuant to section 111 of the Act, and emission standards established pursuant to section 112 of the Act before it was amended in 1990; (3) All terms and conditions in a title V permit, including any provisions that limit a source's potential to emit, unless expressly designated as not federally enforceable; (4) Limitations and conditions that are part of an approved State Implementation Plan (SIP) or a Federal Implementation Plan (FIP); (5) Limitations and conditions that are part of a Federal construction permit issued under 40 CFR 52.21 or any construction permit issued under regulations approved by the EPA in accordance with 40 CFR part 51; (6) Limitations and conditions that are part of an operating permit where the permit and the permitting program pursuant to which it was issued meet all of the following criteria: (i) The operating permit program has been submitted to and approved by EPA into a State implementation plan (SIP) under section 110 of the CAA; (ii) The SIP imposes a legal obligation that operating permit holders adhere to the terms and limitations of such permits and provides that permits which do not conform to the operating permit program requirements and the requirements of EPA's underlying regulations may be deemed not "federally enforceable" by EPA; (iii) The operating permit program requires that all emission limitations, controls, and other requirements imposed by such permits will be at least as stringent as any other applicable limitations and requirements contained in the SIP or enforceable under the SIP, and that the program may not issue permits that waive, or make less stringent, any limitations or requirements contained in or issued pursuant to the SIP, or that are otherwise "federally enforceable"; (iv) The limitations, controls, and requirements in the permit in question are permanent, quantifiable, and otherwise enforceable as a practical matter; and (v) The permit in question was issued only after adequate and timely notice and opportunity for comment for EPA and the public. (7) Limitations and conditions in a State rule or program that has been approved by the EPA under subpart E of this part for the purposes of implementing and enforcing section 112; and (8) Individual consent agreements that the EPA has legal authority to create. Fixed capital cost means the capital needed to provide all the depreciable components of an existing source. Fugitive emissions means those emissions from a stationary source that could not reasonably pass through a stack, chimney, vent, or other functionally equivalent opening. Under section 112 of the Act, all fugitive emissions are to be considered in determining whether a stationary source is a major source. Hazardousairpollutant means any air pollutant listed in or pursuant to section 112(b) of the Act. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-4 of 45

APPENDIX NESHAP SUBPART A General Provisions Issuance of a part 70 permit will occur, if the State is the permitting authority, in accordance with the requirements of part 70 of this chapter and the applicable, approved State permit program. When the EPA is the permitting authority, issuance of a title V permit occurs immediately after the EPA takes final action on the final permit. Major source means any stationary source or group of stationary sources located within a contiguous area and under common control that emits or has the potential to emit considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants, unless the Administrator establishes a lesser quantity, or in the case of radionuclides, different criteria from those specified in this sentence. Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control and monitoring equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Monitoring means the collection and use of measurement data or other information to control the operation of a process or pollution control device or to verify a work practice standard relative to assuring compliance with applicable requirements. Monitoring is composed of four elements: (1) Indicator(s) of performance -- the parameter or parameters you measure or observe for demonstrating proper operation of the pollution control measures or compliance with the applicable emissions limitation or standard. Indicators of performance may include direct or predicted emissions measurements (including opacity), operational parametric values that correspond to process or control device (and capture system) efficiencies or emissions rates, and recorded findings of inspection of work practice activities, materials tracking, or design characteristics. Indicators may be expressed as a single maximum or minimum value, a function of process variables (for example, within a range of pressure drops), a particular operational or work practice status (for example, a damper position, completion of a waste recovery task, materials tracking), or an interdependency between two or among more than two variables. (2) Measurement techniques -- the means by which you gather and record information of or about the indicators of performance. The components of the measurement technique include the detector type, location and installation specifications, inspection procedures, and quality assurance and quality control measures. Examples of measurement techniques include continuous emission monitoring systems, continuous opacity monitoring systems, continuous parametric monitoring systems, and manual inspections that include making records of process conditions or work practices. (3) Monitoring frequency -- the number of times you obtain and record monitoring data over a specified time interval. Examples of monitoring frequencies include at least four points equally spaced for each hour for continuous emissions or parametric monitoring systems, at least every 10 seconds for continuous opacity monitoring systems, and at least once per operating day (or week, month, etc.) for work practice or design inspections. (4) Averaging time -- the period over which you average and use data to verify proper operation of the pollution control approach or compliance with the emissions limitation or standard. Examples of averaging time include a 3-hour average in units of the emissions limitation, a 30-day rolling average emissions value, a daily average of a control device operational parametric range, and an instantaneous alarm. New affected source means the collection of equipment, activities, or both within a single contiguous area and under common control that is included in a section 112(c) source category or subcategory that is subject to a section 112(d) or other relevant standard for new sources. This definition of "new affected source," and the criteria to be utilized in implementing it, shall apply to each section 112(d) standard for which the initial proposed rule is signed by the Administrator after June 30, 2002. Each relevant standard will define the term "new affected source," which will be the same as the "affected source" unless a different collection is warranted based on consideration of factors including: (1) Emission reduction impacts of controlling individual sources versus groups of sources; (2) Cost effectiveness of controlling individual equipment; (3) Flexibility to accommodate common control strategies; (4) Cost/benefits of emissions averaging; (5) Incentives for pollution prevention; (6) Feasibility and cost of controlling processes that share common equipment (e.g., product recovery devices); (7) Feasibility and cost of monitoring; and (8) Other relevant factors. New source means any affected source the construction or reconstruction of which is commenced after the Administrator first proposes a relevant emission standard under this part establishing an emission standard applicable to such source. Opacity means the degree to which emissions reduce the transmission of light and obscure the view of an object in the background. For continuous opacity monitoring systems, opacity means the fraction of incident light that is attenuated by an optical medium. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-5 of 45

APPENDIX NESHAP SUBPART A General Provisions Owner or operatormeans any person who owns, leases, operates, controls, or supervises a stationary source.. Performance audit means a procedure to analyze blind samples, the content of which is known by the Administrator, simultaneously with the analysis of performance test samples in order to provide a measure of test data quality. Performance evaluation means the conduct of relative accuracy testing, calibration error testing, and other measurements used in validating the continuous monitoring system data. Performancetest means the collection of data resulting from the execution of a test method (usually three emission test runs) used to demonstrate compliance with a relevant emission standard as specified in the performance test section of the relevant standard. Permit modification means a change to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661). Permitprogram means a comprehensive State operating permit system established pursuant to title V of the Act (42 U.S.C. 7661) and regulations codified in part 70 of this chapter and applicable State regulations, or a comprehensive Federal operating permit system established pursuant to title V of the Act and regulations codified in this chapter. Permit revision means any permit modification or administrative permit amendment to a title V permit as defined in regulations codified in this chapter to implement title V of the Act (42 U.S.C. 7661). Permittingauthority means: (1) The State air pollution control agency, local agency, other State agency, or other agency authorized by the Administrator to carry out a permit program under part 70 of this chapter; or (2) The Administrator, in the case of EPA-implemented permit programs under title V of the Act (42 U.S.C. 7661). Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. Reconstruction means the replacement of components of an affected or a previously unaffected stationary source to such an extent that: (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable new source; and (2) It is technologically and economically feasible for the reconstructed source to meet the relevant standard(s) established by the Administrator (or a State) pursuant to section 112 of the Act. Upon reconstruction, an affected source, or a stationary source that becomes an affected source, is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source. Regulation promulgationschedule means the schedule for the promulgation of emission standards under this part, established by the Administrator pursuant to section 112(e) of the Act and published in the FEDERAL REGISTER. Relevant standardmeans: (1) An emission standard; (2) An alternative emission standard; (3) An alternative emission limitation; or (4) An equivalent emission limitation established pursuant to section 112 of the Act that applies to the collection of equipment, activities, or both regulated by such standard or limitation. A relevant standard may include or consist of a design, equipment, work practice, or operational requirement, or other measure, process, method, system, or technique (including prohibition of emissions) that the Administrator (or a State) establishes for new or existing sources to which such standard or limitation applies. Every relevant standard established pursuant to section 112 of the Act includes subpart A of this part, as provided by § 63.1(a)(4), and all applicable appendices of this part or of other parts of this chapter that are referenced in that standard. Responsible official means one of the following: (1) For a corporation: A president, secretary, treasurer, or vice president of the corporation in charge of a principal business function, or any other person who performs similar policy or decision-making functions for the corporation, or a duly authorized representative of such person if the representative is responsible for the overall operation of one or more manufacturing, production, or operating facilities and either: (i) The facilities employ more than 250 persons or have gross annual sales or expenditures exceeding $25 million (in second quarter 1980 dollars); or (ii) The delegation of authority to such representative is approved in advance by the Administrator. (2) For a partnership or sole proprietorship: a general partner or the proprietor, respectively. (3) For a municipality, State, Federal, or other public agency: either a principal executive officer or ranking elected official. For the purposes of this part, a principal executive officer of a Federal agency includes the chief executive officer having responsibility for the overall operations of a principal geographic unit of the agency (e.g., a Regional Administrator of the EPA). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-6 of 45

APPENDIX NESHAP SUBPART A General Provisions (4) For affected sources (as defined in this part) applying for or subject to a title V permit: "responsible official" shall have the same meaning as defined in part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever is applicable. Run means one of a series of emission or other measurements needed to determine emissions for a representative operating period or cycle as specified in this part. Shutdown means the cessation of operation of an affected source or portion of an affected source for any purpose. Six-minute period means, with respect to opacity determinations, any one of the 10 equal parts of a 1-hour period. Standardconditions means a temperature of 293 'K (680 F) and a pressure of 101.3 kilopascals (29.92 in. Hg). Startup means the setting in operation of an affected source for any purpose. State means all non-Federal authorities, including local agencies, interstate associations, and State-wide programs, that have delegated authority to implement: (1) The provisions of this part and/or (2) the permit program established under part 70 of this chapter. The term State shall have its conventional meaning where clear from the context. Stationary source means any building, structure, facility, or installation which emits or may emit any air pollutant. Test method means the validated procedure for sampling, preparing, and analyzing for an air pollutant specified in a relevant standard as the performance test procedure. The test method may include methods described in an appendix of this chapter, test methods incorporated by reference in this part, or methods validated for an application through procedures in Method 301 of appendix A of this part. Title Vpermit means any permit issued, renewed, or revised pursuant to Federal or State regulations established to implement title V of the Act (42 U.S.C. 7661). A title V permit issued by a State permitting authority is called a part 70 permit in this part. Visible emission means the observation of an emission of opacity or optical density above the threshold of vision. Working day means any day on which Federal Government offices (or State government offices for a State that has obtained delegation under section 112(1)) are open for normal business. Saturdays, Sundays, and official Federal (or where delegated, State) holidays are not working days. § 63.3 Units and abbreviations. Used in this part are abbreviations and symbols of units of measure. These are defined as follows: (a) System International (SI) units of measure: A = ampere g = gram Hz = hertz J =joule K= degree Kelvin kg = kilogram I = liter m = meter m3= cubic meter mg= milligram = 10 -3 gram ml = milliliter = 10 -3 liter mm = millimeter = 10 -3 meter Mg = megagram = 106 gram = metric ton MJ = megajoule mol = mole N = newton ng = nanogram = 10 -9_gram nm = nanometer = 10 - meter Pa = pascal s = second V = volt W = watt 

            = ohm g= microgram = 10-6 gram tl= microliter = 10 -6 liter Progress Energy Florida, Inc.                                                                         Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPA-7 of 45

APPENDIX NESHAP SUBPART A General Provisions (b) Other units of measure: Btu = British thermal unit 

         'C = degree Celsius (centigrade) cal = calorie cfm = cubic feet per minute cc = cubic centimeter cu ft = cubic feet d = day dcf = dry cubic feet dcm = dry cubic meter dscf = dry cubic feet at standard conditions dscm = dry cubic meter at standard conditions eq = equivalent
         'F = degree Fahrenheit ft = feet ft 2 = square feet ft 3 = cubic feet gal = gallon gr = grain g-eq = gram equivalent g-mole = gram mole hr = hour in. = inch in. H 20 = inches of water K = 1,000 kcal = kilocalorie lb = pound 1pm = liter per minute meq = milliequivalent min = minute MW = molecular weight oz = ounces ppb = parts per billion ppbw = parts per billion by weight ppbv = parts per billion by volume ppm = parts per million ppmw = parts per million by weight ppmv = parts per million by volume psia = pounds per square inch absolute psig = pounds per square inch gage
        'R = degree Rankine scf = cubic feet at standard conditions scfh = cubic feet at standard conditions per hour scm = cubic meter at standard conditions scmm= cubic meter at standard conditions per minute sec = second sq ft = square feet std = at standard conditions v/v = volume per volume yd 2 = square yards yr = year (c) Miscellaneous:

act = actual avg = average I.D. = inside diameter M = molar N = normal Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-8 of 45

APPENDIX NESHAP SUBPART A General Provisions O.D. = outside diameter 

          % = percent

§ 63.4 Prohibited activities and circumvention. (a) Prohibitedactivities. (1) No owner or operator subject to the provisions of this part must operate any affected source in violation of the requirements of this part. Affected sources subject to and in compliance with either an extension of compliance or an exemption from compliance are not in violation of the requirements of this part. An extension of compliance can be granted by the Administrator under this part; by a State with an approved permit program; or by the President under section 112(i)(4) of the Act. (2) No owner or operator subject to the provisions of this part shall fail to keep records, notify, report, or revise reports as required under this part. (3) [Reserved] (4) [Reserved] (5) [Reserved] (b) Circumvention. No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment, or process to conceal an emission that would otherwise constitute noncompliance with a relevant standard. Such concealment includes, but is not limited to (1) The use of diluents to achieve compliance with a relevant standard based on the concentration of a pollutant in the effluent discharged to the atmosphere; (2) The use of gaseous diluents to achieve compliance with a relevant standard for visible emissions; and (3) [Reserved] (c) Severability. Notwithstanding any requirement incorporated into a title V permit obtained by an owner or operator subject to the provisions of this part, the provisions of this part are federally enforceable. § 63.5 Preconstruction review and notification requirements. (a) Applicability. (1) This section implements the preconstruction review requirements of section 112(i)(1) for sources subject to a relevant emission standard that has been promulgated in this part. In addition, this section includes other requirements for constructed and reconstructed stationary sources that are or become subject to a relevant promulgated emission standard. (2) After the effective date of a relevant standard promulgated under this part, the requirements in this section apply to owners or operators who construct a new source or reconstruct a source after the proposal date of that standard. New or reconstructed sources that start up before the standard's effective date are not subject to the preconstruction review requirements specified in paragraphs (b)(3), (d), and (e) of this section. (b) Requirementsfor existing, newly constructed, and reconstructedsources. (1) A new affected source for which construction commences after proposal of a relevant standard is subject to relevant standards for new affected sources, including compliance dates. An affected source for which reconstruction commences after proposal of a relevant standard is subject to relevant standards for new sources, including compliance dates, irrespective of any change in emissions of hazardous air pollutants from that source. (2) [Reserved] (3) After the effective date of any relevant standard promulgated by the Administrator under this part, no person may, without obtaining written approval in advance from the Administrator in accordance with the procedures specified in paragraphs (d) and (e) of this section, do any of the following: (i) Construct a new affected source that is major-emitting and subject to such standard; (ii) Reconstruct an affected source that is major-emitting and subject to such standard; or (iii) Reconstruct a major source such that the source becomes an affected source that is major-emitting and subject to the standard. (4) After the effective date of any relevant standard promulgated by the Administrator under this part, an owner or operator who constructs a new affected source that is not major-emitting or reconstructs an affected source that is not major-emitting that is subject to such standard, or reconstructs a source such that the source becomes an affected source subject to Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-9 of 45

APPENDIX NESHAP SUBPART A General Provisions the standard, must notify the Administrator of the intended construction or reconstruction. The notification must be submitted in accordance with the procedures in § 63.9(b). (5) [Reserved] (6) After the effective date of any relevant standard promulgated by the Administrator under this part, equipment added (or a process change) to an affected source that is within the scope of the definition of affected source under the relevant standard must be considered part of the affected source and subject to all provisions of the relevant standard established for that affected source. (c) [Reserved] (d) Applicationfor approval of construction or reconstruction.The provisions of this paragraph implement section 1 12(i)(1) of the Act. (1) General application requirements. (i) An owner or operator who is subject to the requirements of paragraph (b)(3) of this section must submit to the Administrator an application for approval of the construction or reconstruction. The application must be submitted as soon as practicable before actual construction or reconstruction begins. The application for approval of construction or reconstruction may be used to fulfill the initial notification requirements of § 63.9(b)(5). The owner or operator may submit the application for approval well in advance of the date actual construction or reconstruction begins in order to ensure a timely review by the Administrator and that the planned date to begin will not be delayed. (ii) A separate application shall be submitted for each construction or reconstruction. Each application for approval of construction or reconstruction shall include at a minimum: (A) The applicant's name and address; (B) A notification of intention to construct a new major affected source or make any physical or operational change to a major affected source that may meet or has been determined to meet the criteria for a reconstruction, as defined in § 63.2 or in the relevant standard; (C) The address (i.e., physical location) or proposed address of the source; (D) An identification of the relevant standard that is the basis of the application; (E) The expected date of the beginning of actual construction or reconstruction; (F) The expected completion date of the construction or reconstruction; (G) [Reserved] (H) The type and quantity of hazardous air pollutants emitted by the source, reported in units and averaging times and in accordance with the test methods specified in the relevant standard, or if actual emissions data are not yet available, an estimate of the type and quantity of hazardous air pollutants expected to be emitted by the source reported in units and averaging times specified in the relevant standard. The owner or operator may submit percent reduction information if a relevant standard is established in terms of percent reduction. However, operating parameters, such as flow rate, shall be included in the submission to the extent that they demonstrate performance and compliance; and (I) [Reserved] (J) Other information as specified in paragraphs (d)(2) and (d)(3) of this section. (iii) An owner or operator who submits estimates or preliminary information in place of the actual emissions data and analysis required in paragraphs (d)(1)(ii)(H) and (d)(2) of this section shall submit the actual, measured emissions data and other correct information as soon as available but no later than with the notification of compliance status required in § 63.9(h) (see § 63.9(h)(5)). (2) Applicationfor approval of construction. Each application for approval of construction must include, in addition to the information required in paragraph (d)(1)(ii) of this section, technical information describing the proposed nature, size, design, operating design capacity, and method of operation of the source, including an identification of each type of emission point for each type of hazardous air pollutant that is emitted (or could reasonably be anticipated to be emitted) and a description of the planned air pollution control system (equipment or method) for each emission point. The description of the equipment to be used for the control of emissions must include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions must include an estimated control efficiency (percent) for that method. Such technical information must include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-10 of 45

APPENDIX NESHAP SUBPART A General Provisions (3) Applicationfor approval of reconstruction.Each application for approval of reconstruction shall include, in addition to the information required in paragraph (d)(1)(ii) of this section - (i) A brief description of the affected source and the components that are to be replaced; (ii) A description of present and proposed emission control systems (i.e., equipment or methods). The description of the equipment to be used for the control of emissions shall include each control device for each hazardous air pollutant and the estimated control efficiency (percent) for each control device. The description of the method to be used for the control of emissions shall include an estimated control efficiency (percent) for that method. Such technical information shall include calculations of emission estimates in sufficient detail to permit assessment of the validity of the calculations; (iii) An estimate of the fixed capital cost of the replacements and of constructing a comparable entirely new source; (iv) The estimated life of the affected source after the replacements; and (v) A discussion of any economic or technical limitations the source may have in complying with relevant standards or other requirements after the proposed replacements. The discussion shall be sufficiently detailed to demonstrate to the Administrator's satisfaction that the technical or economic limitations affect the source's ability to comply with the relevant standard and how they do so. (vi) If in the application for approval of reconstruction the owner or operator designates the affected source as a reconstructed source and declares that there are no economic or technical limitations to prevent the source from complying with all relevant standards or other requirements, the owner or operator need not submit the information required in paragraphs (d)(3)(iii) through (d)(3)(v) of this section. (4) Additional information. The Administrator may request additional relevant information after the submittal of an application for approval of construction or reconstruction. (e) Approval of construction or reconstruction. (1) (i) If the Administrator determines that, if properly constructed, or reconstructed, and operated, a new or existing source for which an application under paragraph (d) of this section was submitted will not cause emissions in violation of the relevant standard(s) and any other federally enforceable requirements, the Administrator will approve the construction or reconstruction. (ii) In addition, in the case of reconstruction, the Administrator's determination under this paragraph will be based on: (A) The fixed capital cost of the replacements in comparison to the fixed capital cost that would be required to construct a comparable entirely new source; (B) The estimated life of the source after the re-placements compared to the life of a comparable entirely new source; (C) The extent to which the components being replaced cause or contribute to the emissions from the source; and (D) Any economic or technical limitations on compliance with relevant standards that are inherent in the proposed replacements. (2) (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of construction or reconstruction within 60 calendar days after receipt of sufficient information to evaluate an application submitted under paragraph (d) of this section. The 60-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted. (ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application. (3) Before denying any application for approval of construction or reconstruction, the Administrator will notify the applicant of the Administrator's intention to issue the denial together with - (i) Notice of the information and findings on which the intended denial is based; and (ii) Notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator to enable further action on the application. (4) A final determination to deny any application for approval will be in writing and will specify the grounds on which the denial is based. The final determination will be made within 60 calendar days of presentation of additional information or arguments (if the application is complete), or within 60 calendar days after the final date specified for presentation if no presentation is made. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-11 of 45

APPENDIX NESHAP SUBPART A General Provisions (5) Neither the submission of an application for approval nor the Administrator's approval of construction or reconstruction shall - (i) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (ii) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act. (f) Approval of construction or reconstructionbased on prior State preconstructionreview. (1) Preconstruction review procedures that a State utilizes for other purposes may also be utilized for purposes of this section if the procedures are substantially equivalent to those specified in this section. The Administrator will approve an application for construction or reconstruction specified in paragraphs (b)(3) and (d) of this section if the owner or operator of a new affected source or reconstructed affected source, who is subject to such requirement meets the following conditions: (i) The owner or operator of the new affected source or reconstructed affected source has undergone a preconstruction review and approval process in the State in which the source is (or would be) located and has received a federally enforceable construction permit that contains a finding that the source will meet the relevant promulgated emission standard, if the source is properly built and operated. (ii) Provide a statement from the State or other evidence (such as State regulations) that it considered the factors specified in paragraph (e)(1) of this section. (2) The owner or operator must submit to the Administrator the request for approval of construction or reconstruction under this paragraph (f)(2) no later than the application deadline specified in paragraph (d)(1) of this section (see also § 63.9(b)(2)). The owner or operator must include in the request information sufficient for the Administrator's determination. The Administrator will evaluate the owner or operator's request in accordance with the procedures specified in paragraph (e) of this section. The Administrator may request additional relevant information after the submittal of a request for approval of construction or reconstruction under this paragraph (f)(2). § 63.6 Compliance with standards and maintenance requirements. (a) Applicability. (1) The requirements in this section apply to the owner or operator of affected sources for which any relevant standard has been established pursuant to section 112 of the Act and the applicability of such requirements is set out in accordance with § 63.1(a)(4) unless -- (i) The Administrator (or a State with an approved permit program) has granted an extension of compliance consistent with paragraph (i) of this section; or (ii) The President has granted an exemption from compliance with any relevant standard in accordance with section 112(i)(4) of the Act. (2) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source, such source shall be subject to the relevant emission standard or other requirement. (b) Compliance datesfor new and reconstructed sources. (1) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source for which construction or reconstruction commences after proposal of a relevant standard that has an initial startup before the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard not later than the standard's effective date. (2) Except as specified in paragraphs (b)(3) and (4) of this section, the owner or operator of a new or reconstructed affected source that has an initial startup after the effective date of a relevant standard established under this part pursuant to section 112(d), (f), or (h) of the Act must comply with such standard upon startup of the source' (3) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established under this part pursuant to section 112(d), 112(f), or 112(h) of the Act but before the effective date (that is, promulgation) of such standard shall comply with the relevant emission standard not later than the date 3 years after the effective date if: (i) The promulgated standard (that is, the relevant standard) is more stringent than the proposed standard; for purposes of this paragraph, a finding that controls or compliance methods are "more stringent" must include control technologies or performance criteria and compliance or compliance assurance methods that are different but are substantially equivalent to those required by the promulgated rule, as determined by the Administrator (or his or her authorized representative); and (ii) The owner or operator complies with the standard as proposed during the 3-year period immediately after the effective date. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-12 of 45

APPENDIX NESHAP SUBPART A General Provisions (4) The owner or operator of an affected source for which construction or reconstruction is commenced after the proposal date of a relevant standard established pursuant to section 112(d) of the Act but before the proposal date of a relevant standard established pursuant to section 112(f) shall not be required to comply with the section 112(f) emission standard until the date 10 years after the date construction or reconstruction is commenced, except that, if the section 112(f) standard is promulgated more than 10 years after construction or reconstruction is commenced, the owner or operator must comply with the standard as provided in paragraphs (b)(1) and (2) of this section. (5) The owner or operator of a new source that is subject to the compliance requirements of paragraph (b)(3) or (4) of this section must notify the Administrator in accordance with § 63.9(d). (6) [Reserved] (7) When an area source becomes a major source by the addition of equipment or operations that meet the definition of new affected source in the relevant standard, the portion of the existing facility that is a new affected source must comply with all requirements of that standard applicable to new sources. The source owner or operator must comply with the relevant standard upon startup. (c) Compliance datesfor existing sources. (1) After the effective date of a relevant standard established under this part pursuant to section 112(d) or 112(h) of the Act, the owner or operator of an existing source shall comply with such standard by the compliance date established by the Administrator in the applicable subpart(s) of this part. Except as otherwise provided for in section 112 of the Act, in no case will the compliance date established for an existing source in an applicable subpart of this part exceed 3 years after the effective date of such standard. (2) If an existing source is subject to a standard established under this part pursuant to section 112(f) of the Act, the owner or operator must comply with the standard by the date 90 days after the standard's effective date, or by the date specified in an extension granted to the source by the Administrator under paragraph (i)(4)(ii) of this section, whichever is later. (3)-(4) [Reserved] (5) Except as provided in paragraph (b)(7) of this section, the owner or operator of an area source that increases its emissions of (or its potential to emit) hazardous air pollutants such that the source becomes a major source shall be subject to relevant standards for existing sources. Such sources must comply by the date specified in the standards for existing area sources that become major sources. If no such compliance date is specified in the standards, the source shall have a period of time to comply with the relevant emission standard that is equivalent to the compliance period specified in the relevant standard for existing sources in existence at the time the standard becomes effective. (d) [Reserved] (e) Operation and maintenance requirements. (1) (i) At all times, including periods of startup, shutdown, and malfunction, the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. During a period of startup, shutdown, or malfunction, this general duty to minimize emissions requires that the owner or operator reduce emissions from the affected source to the greatest extent which is consistent with safety and good air pollution control practices. The general duty to minimize emissions during a period of startup, shutdown, or malfunction does not require the owner or operator to achieve emission levels that would be required by the applicable standard at other times if this is not consistent with safety and good air pollution control practices, nor does it require the owner or operator to make any further efforts to reduce emissions if levels required by the applicable standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures (including the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section), review of operation and maintenance records, and inspection of the source. (ii) Malfunctions must be corrected as soon as practicable after their occurrence in accordance with the startup, shutdown, and malfunction plan required in paragraph (e)(3) of this section. To the extent that an unexpected event arises during a startup, shutdown, or malfunction, an owner or operator must comply by minimizing emissions during such a startup, shutdown, and malfunction event consistent with safety and good air pollution control practices. (iii) Operation and maintenance requirements established pursuant to section 112 of the Act are enforceable independent of emissions limitations or other requirements in relevant standards. (2) [Reserved] (3) Startup, shutdown, and malfunction plan. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-13 of 45

APPENDIX NESHAP SUBPART A General Provisions (i)The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan that describes, in detail, procedures for operating and maintaining the source during periods of startup, shutdown, and malfunction, and a program of corrective action for malfunctioning process and air pollution control and monitoring equipment used to comply with the relevant standard. (A) Ensure that, at all times, the owner or operator operates and maintains each affected source, including associated air pollution control and monitoring equipment, in a manner which satisfies the general duty to minimize emissions established by paragraph (e)(1)(i) of this section; (B) Ensure that owners or operators are prepared to correct malfunctions as soon as practicable after their occurrence in order to minimize excess emissions of hazardous air pollutants; and (C) Reduce the reporting burden associated with periods of startup, shutdown, and malfunction (including corrective action taken to restore malfunctioning process and air pollution control equipment to its normal or usual manner of operation). (ii) During periods of startup, shutdown, and malfunction, the owner or operator of an affected source must operate and maintain such source (including associated air pollution control and monitoring equipment) in accordance with the procedures specified in the startup, shutdown, and malfunction plan developed under paragraph (e)(3)(i) of this section. (iii) When actions taken by the owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) are consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, the owner or operator must keep records for that event which demonstrate that the procedures specified in the plan were followed. These records may take the form of a "checklist," or other effective form of recordkeeping that confirms conformance with the startup, shutdown, and malfunction plan for that event. In addition, the owner or operator must keep records of these events as specified in § 63.10(b), including records of the occurrence and duration of each startup, shutdown, or malfunction of operation and each malfunction of the air pollution control and monitoring equipment. Furthermore, the owner or operator shall confirm that actions taken during the relevant reporting period during periods of startup, shutdown, and malfunction were consistent with the affected source's startup, shutdown and malfunction plan in the semiannual (or more frequent) startup, shutdown, and malfunction report required in § 63.10(d)(5). (iv) If an action taken by the owner or operator during a startup, shutdown, or malfunction (including an action taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, then the owner or operator must record the actions taken for that event and must report such actions within 2 working days after commencing actions inconsistent with the plan, followed by a letter within 7 working days after the end of the event, in accordance with Sec. 63.10(d)(5) (unless the owner or operator makes alternative reporting arrangements, in advance, with the Administrator). (v) The owner or operator must maintain at the affected source a current startup, shutdown, and malfunction plan and must make the plan available upon request for inspection and copying by the Administrator. In addition, if the startup, shutdown, and malfunction plan is subsequently revised as provided in paragraph (e)(3)(viii) of this section, the owner or operator must maintain at the affected source each previous (i.e., superseded) version of the startup, shutdown, and malfunction plan, and must make each such previous version available for inspection and copying by the Administrator for a period of 5 years after revision of the plan. If at any time after adoption of a startup, shutdown, and malfunction plan the affected source ceases operation or is otherwise no longer subject to the provisions of this part, the owner or operator must retain a copy of the most recent plan for 5 years from the date the source ceases operation or is no longer subject to this part and must make the plan available upon request for inspection and copying by the Administrator. The Administrator may at any time request in writing that the owner or operator submit a copy of any startup, shutdown, and malfunction plan (or a portion thereof) which is maintained at the affected source or in the possession of the owner or operator. Upon receipt of such a request, the owner or operator must promptly submit a copy of the requested plan (or a portion thereof) to the Administrator. The Administrator must request that the owner or operator submit a particular startup, shutdown, or malfunction plan (or a portion thereof) whenever a member of the public submits a specific and reasonable request to examine or to receive a copy of that plan or portion of a plan. The owner or operator may elect to submit the required copy of any startup, shutdown, and malfunction plan to the Administrator in an electronic format. If the owner or operator claims that any portion of such a startup, shutdown, and malfunction plan is confidential business information entitled to protection from disclosure under section 114(c) of the Act or 40 CFR 2.30 1, the material which is claimed as confidential must be clearly designated in the submission. (vi) To satisfy the requirements of this section to develop a startup, shutdown, and malfunction plan, the owner or operator may use the affected source's standard operating procedures (SOP) manual, or an Occupational Safety and Health Administration (OSHA) or other plan, provided the alternative plans meet all the requirements of this section and are made available for inspection or submitted when requested by the Administrator. (vii) Based on the results of a determination made under paragraph (e)(1)(i) of this section, the Administrator may require that an owner or operator of an affected source make changes to the startup, shutdown, and Progress Energy Florida, Inc. 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APPENDIX NESHAP SUBPART A General Provisions malfunction plan for that source. The Administrator must require appropriate revisions to a startup, shutdown, and malfunction plan, if the Administrator finds that the plan: (A) Does not address a startup, shutdown, or malfunction event that has occurred; (B) Fails to provide for the operation of the source (including associated air pollution control and monitoring equipment) during a startup, shutdown, or malfunction event in a manner consistent with the general duty to minimize emissions established by paragraph (e)(1)(i) of this section; (C) Does not provide adequate procedures for correcting malfunctioning process and/or air pollution control and monitoring equipment as quickly as practicable; or (D) Includes an event that does not meet the definition of startup, shutdown, or malfunction listed in 

     § 63.2.

(viii) The owner or operator may periodically revise the startup, shutdown, and malfunction plan for the affected source as necessary to satisfy the requirements of this part or to reflect changes in equipment or procedures at the affected source. Unless the permitting authority provides otherwise, the owner or operator may make such revisions to the startup, shutdown, and malfunction plan without prior approval by the Administrator or the permitting authority. However, each such revision to a startup, shutdown, and malfunction plan must be reported in the semiannual report required by § 63.10(d)(5). If the startup, shutdown, and malfunction plan fails to address or inadequately addresses an event that meets the characteristics of a malfunction but was not included in the startup, shutdown, and malfunction plan at the time the owner or operator developed the plan, the owner or operator must revise the startup, shutdown, and malfunction plan within 45 days after the event to include detailed procedures for operating and maintaining the source during similar malfunction events and a program of corrective action for similar malfunctions of process or air pollution control and monitoring equipment. In the event that the owner or operator makes any revision to the startup, shutdown, and malfunction plan which alters the scope of the activities at the source which are deemed to be a startup, shutdown, or malfunction, or otherwise modifies the applicability of any emission limit, work practice requirement, or other requirement in a standard established under this part, the revised plan shall not take effect until after the owner or operator has provided a written notice describing the revision to the permitting authority. (ix) The title V permit for an affected source must require that the owner or operator adopt a startup, shutdown, and malfunction plan which conforms to the provisions of this part, and that the owner or operator operate and maintain the source in accordance with the procedures specified in the current startup, shutdown, and malfunction plan. However, any revisions made to the startup, shutdown, and malfunction plan in accordance with the procedures established by this part shall not be deemed to constitute permit revisions under part 70 or part 71 of this chapter. Moreover, none of the procedures specified by the startup, shutdown, and malfunction plan for an affected source shall be deemed to fall within the permit shield provision in section 504(f) of the Act. (f) Compliance with nonopacity emission standards-(1) Applicability. The non-opacity emission standards set forth in this part shall apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the non-opacity emission standards set forth in this part, then that emission point must still be required to comply with the non-opacity emission standards and other applicable requirements. (2) Methods for determining compliance. (i) The Administrator will determine compliance with nonopacity emission standards in this part based on the results of performance tests conducted according to the procedures in § 63.7, unless otherwise specified in an applicable subpart of this part. (ii) The Administrator will determine compliance with nonopacity emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, including the evaluation of monitoring data, as specified in § 63.6(e) and applicable subparts of this part. (iii) If an affected source conducts performance testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if - (A) The performance test was conducted within a reasonable amount of time before an initial performance test is required to be conducted under the relevant standard; (B) The performance test was conducted under representative operating conditions for the source; (C) The performance test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in § 63.7(e) of this subpart; and (D) The performance test was appropriately quality-assured, as specified in § 63.7(c). (iv) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by review of records, inspection of the source, and other procedures specified in applicable subparts of this part. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-15 of 45

APPENDIX NESHAP SUBPART A General Provisions (v) The Administrator will determine compliance with design, equipment, work practice, or operational emission standards in this part by evaluation of an owner or operator's conformance with operation and maintenance requirements, as specified in paragraph (e) of this section and applicable subparts of this part. (3) Finding of compliance. The Administrator will make a finding concerning an affected source's compliance with a non-opacity emission standard, as specified in paragraphs (f)(1) and (2) of this section, upon obtaining all the compliance information required by the relevant standard (including the written reports of performance test results, monitoring results, and other information, if applicable), and information available to the Administrator pursuant to paragraph (e)(1)(i) of this section. (g) Use of an alternative nonopacity emission standard. (1) If, in the Administrator's judgment, an owner or operator of an affected source has established that an alternative means of emission limitation will achieve a reduction in emissions of a hazardous air pollutant from an affected source at least equivalent to the reduction in emissions of that pollutant from that source achieved under any design, equipment, work practice, or operational emission standard, or combination thereof, established under this part pursuant to section 112(h) of the Act, the Administrator will publish in the FEDERAL REGISTER a notice permitting the use of the alternative emission standard for purposes of compliance with the promulgated standard. Any FEDERAL REGISTER notice under this paragraph shall be published only after the public is notified and given the opportunity to comment. Such notice will restrict the permission to the stationary source(s) or category(ies) of sources from which the alternative emission standard will achieve equivalent emission reductions. The Administrator will condition permission in such notice on requirements to assure the proper operation and maintenance of equipment and practices required for compliance with the alternative emission standard and other requirements, including appropriate quality assurance and quality control requirements, that are deemed necessary. (2) An owner or operator requesting permission under this paragraph shall, unless otherwise specified in an applicable subpart, submit a proposed test plan or the results of testing and monitoring in accordance with § 63.7 and § 63.8, a description of the procedures followed in testing or monitoring, and a description of pertinent conditions during testing or monitoring. Any testing or monitoring conducted to request permission to use an alternative nonopacity emission standard shall be appropriately quality assured and quality controlled, as specified in § 63.7 and § 63.8. (3) The Administrator may establish general procedures in an applicable subpart that accomplish the requirements of paragraphs (g)(1) and (g)(2) of this section. (h) Compliance with opacity and visible emission standards - (1) Applicability. The opacity and visible emission standards set forth in this part must apply at all times except during periods of startup, shutdown, and malfunction, and as otherwise specified in an applicable subpart. If a startup, shutdown, or malfunction of one portion of an affected source does not affect the ability of particular emission points within other portions of the affected source to comply with the opacity and visible emission standards set forth in this part, then that emission point shall still be required to comply with the opacity and visible emission standards and other applicable requirements. (2) Methods for determining compliance. (i) The Administrator will determine compliance with opacity and visible emission standards in this part based on the results of the test method specified in an applicable subpart. Whenever a continuous opacity monitoring system (COMS) is required to be installed to determine compliance with numerical opacity emission standards in this part, compliance with opacity emission standards in this part shall be determined by using the results from the COMS. Whenever an opacity emission test method is not specified, compliance with opacity emission standards in this part shall be determined by conducting observations in accordance with Test Method 9 in appendix A of part 60 of this chapter or the method specified in paragraph (h)(7)(ii) of this section. Whenever a visible emission test method is not specified, compliance with visible emission standards in this part shall be determined by conducting observations in accordance with Test Method 22 in appendix A of part 60 of this chapter. (ii) [Reserved] (iii) If an affected source undergoes opacity or visible emission testing at startup to obtain an operating permit in the State in which the source is located, the results of such testing may be used to demonstrate compliance with a relevant standard if - (A) The opacity or visible emission test was conducted within a reasonable amount of time before a performance test is required to be conducted under the relevant standard; (B) The opacity or visible emission test was conducted under representative operating conditions for the source; (C) The opacity or visible emission test was conducted and the resulting data were reduced using EPA-approved test methods and procedures, as specified in § 63.7(e); and (D) The opacity or visible emission test was appropriately quality-assured, as specified in § 63.7(c) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-16 of 45

APPENDIX NESHAP SUBPART A General Provisions (3) [Reserved] (4) Notification of opacity or visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting opacity or visible emission observations in accordance with § 63.9(f), if such observations are required for the source by a relevant standard. (5) Conduct of opacity or visible emission observations.When a relevant standard under this part includes an opacity or visible emission standard, the owner or operator of an affected source shall comply with the following: (i) For the purpose of demonstrating initial compliance, opacity or visible emission observations shall be conducted concurrently with the initial performance test required in § 63.7 unless one of the following conditions applies: (A) If no performance test under § 63.7 is required, opacity or visible emission observations shall be conducted within 60 days after achieving the maximum production rate at which a new or reconstructed source will be operated, but not later than 120 days after initial startup of the source, or within 120 days after the effective date of the relevant standard in the case of new sources that start up before the standard's effective date. If no performance test under § 63.7 is required, opacity or visible emission observations shall be conducted within 120 days after the compliance date for an existing or modified source; or (B) If visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under § 63.7, or within the time period specified in paragraph (h)(5)(i)(A) of this section, the source's owner or operator shall reschedule the opacity or visible emission observations as soon after the initial performance test, or time period, as possible, but not later than 30 days thereafter, and shall advise the Administrator of the rescheduled date. The rescheduled opacity or visible emission observations shall be conducted (to the extent possible) under the same operating conditions that existed during the initial performance test conducted under § 63.7. The visible emissions observer shall determine whether visibility or other conditions prevent the opacity or visible emission observations from being made concurrently with the initial performance test in accordance with procedures contained in Test Method 9 or Test Method 22 in appendix A of part 60 of this chapter. (ii) For the purpose of demonstrating initial compliance, the minimum total time of opacity observations shall be 3 hours (30 6-minute averages) for the performance test or other required set of observations (e.g., for fugitive-type emission sources subject only to an opacity emission standard). (iii) The owner or operator of an affected source to which an opacity or visible emission standard in this part applies shall conduct opacity or visible emission observations in accordance with the provisions of this section, record the results of the evaluation of emissions, and report to the Administrator the opacity or visible emission results in accordance with the provisions of § 63.10(d). (iv) [Reserved] (v) Opacity readings of portions of plumes that contain condensed, uncombined water vapor shall not be used for purposes of determining compliance with opacity emission standards. (6) Availability of records. The owner or operator of an affected source shall make available, upon request by the Administrator, such records that the Administrator deems necessary to determine the conditions under which the visual observations were made and shall provide evidence indicating proof of current visible observer emission certification. (7) Use of a continuous opacity monitoring system. (i) The owner or operator of an affected source required to use a continuous opacity monitoring system (COMS) shall record the monitoring data produced during a performance test required under § 63.7 and shall furnish the Administrator a written report of the monitoring results in accordance with the provisions of § 63.10(e)(4). (ii) Whenever an opacity emission test method has not been specified in an applicable subpart, or an owner or operator of an affected source is required to conduct Test Method 9 observations (see appendix A of part 60 of this chapter), the owner or operator may submit, for compliance purposes, COMS data results produced during any performance test required under § 63.7 in lieu of Method 9 data. If the owner or operator elects to submit COMS data for compliance with the opacity emission standard, he or she shall notify the Administrator of that decision, in writing, simultaneously with the notification under § 63.7(b) of the date the performance test is scheduled to begin. Once the owner or operator of an affected source has notified the Administrator to that effect, the COMS data results will be used to determine opacity compliance during subsequent performance tests required under § 63.7, unless the owner or operator notifies the Administrator in writing to the contrary not later than with the notification under § 63.7(b) of the date the subsequent performance test is scheduled to begin. (iii) For the purposes of determining compliance with the opacity emission standard during a performance test required under § 63.7 using COMS data, the COMS data shall be reduced to 6-minute averages over the duration of the mass emission performance test. (iv) The owner or operator of an affected source using a COMS for compliance purposes is responsible for demonstrating that he/she has complied with the performance evaluation requirements of § 63.8(e), that the COMS has been properly maintained, operated, and data quality-assured, as specified in § 63.8(c) and § 63.8(d), and that the resulting data have not been altered in any way. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-17 of 45

APPENDIX NESHAP SUBPART A General Provisions (v) Except as provided in paragraph (h)(7)(ii) of this section, the results of continuous monitoring by a COMS that indicate that the opacity at the time visual observations were made was not in excess of the emission standard are probative but not conclusive evidence of the actual opacity of an emission, provided that the affected source proves that, at the time of the alleged violation, the instrument used was properly maintained, as specified in § 63.8(c), and met Performance Specification 1 in appendix B of part 60 of this chapter, and that the resulting data have not been altered in any way. (8) Findingof compliance. The Administrator will make a finding concerning an affected source's compliance with an opacity or visible emission standard upon obtaining all the compliance information required by the relevant standard (including the written reports of the results of the performance tests required by § 63.7, the results of Test Method 9 or another required opacity or visible emission test method, the observer certification required by paragraph (h)(6) of this section, and the continuous opacity monitoring system results, whichever is/are applicable) and any information available to the Administrator needed to determine whether proper operation and maintenance practices are being used. (9) Adjustment to an opacity emission standard. (i) If the Administrator finds under paragraph (h)(8) of this section that an affected source is in compliance with all relevant standards for which initial performance tests were conducted under § 63.7, but during the time such performance tests were conducted fails to meet any relevant opacity emission standard, the owner or operator of such source may petition the Administrator~to make appropriate adjustment to the opacity emission standard for the affected source. Until the Administrator notifies the owner or operator of the appropriate adjustment, the relevant opacity emission standard remains applicable. (ii) The Administrator may grant such a petition upon a demonstration by the owner or operator that - (A) The affected source and its associated air pollution control equipment were operated and maintained in a manner to minimize the opacity of emissions during the performance tests; (B) The performance tests were performed under the conditions established by the Administrator; and (C) The affected source and its associated air pollution control equipment were incapable of being adjusted or operated to meet the relevant opacity emission standard. (iii) The Administrator will establish an adjusted opacity emission standard for the affected source meeting the above requirements at a level at which the source will be able, as indicated by the performance and opacity tests, to meet the opacity emission standard at all times during which the source is meeting the mass or concentration emission standard. The Administrator will promulgate the new opacity emission standard in the FEDERAL REGISTER. (iv) After the Administrator promulgates an adjusted opacity emission standard for an affected source, the owner or operator of such source shall be subject to the new opacity emission standard, and the new opacity emission standard shall apply to such source during any subsequent performance tests. (i) Extension of compliance with emission standards. (1) Until an extension of compliance has been granted by the Administrator (or a State with an approved permit program) under this paragraph, the owner or operator of an affected source subject to the requirements of this section shall comply with all applicable requirements of this part. (2) Extension of compliance for early reductions and other reductions (i) Early reductions. Pursuant to section 112(i)(5) of the Act, if the owner or operator of an existing source demonstrates that the source has achieved a reduction in emissions of hazardous air pollutants in accordance with the provisions of subpart D of this part, the Administrator (or the State with an approved permit program) will grant the owner or operator an extension of compliance with specific requirements of this part, as specified in subpart D. (ii) Other reductions. Pursuant to section 112(i)(6) of the Act, if the owner or operator of an existing source has installed best available control technology (BACT) (as defined in section 169(3) of the Act) or technology required to meet a lowest achievable emission rate (LAER) (as defined in section 171 of the Act) prior to the promulgation of an emission standard in this part applicable to such source and the same pollutant (or stream of pollutants) controlled pursuant to the BACT or LAER installation, the Administrator will grant the owner or operator an extension of compliance with such emission standard that will apply until the date 5 years after the date on which such installation was achieved, as determined by the Administrator. (3) Request for extension of compliance. Paragraphs (i)(4) through (i)(7) of this section concern requests for an extension of compliance with a relevant standard under this part (except requests for an extension of compliance under paragraph (i)(2)(i) of this section will be handled through procedures specified in subpart D of this part). (4) (i) (A) The owner or operator of an existing source who is unable to comply with a relevant standard established under this part pursuant to section 112(d) of the Act may request that the Administrator (or a State, when the State has an approved part 70 permit program and the source is required to obtain a part 70 permit under that program, or a State, when the State has been delegated the authority to implement and enforce the emission standard for that source) grant an extension allowing the source up to 1 additional year to comply with the standard, if such additional period is necessary for Progress Energy Florida, Inc. 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APPENDIX NESHAP SUBPART A General Provisions the installation of controls. An additional extension of up to 3 years may be added for mining waste operations, if the 1-year extension of compliance is insufficient to dry and cover mining waste in order to reduce emissions of any hazardous air pollutant. The owner or operator of an affected source who has requested an extension of compliance under this paragraph and who is otherwise required to obtain a title V permit shall apply for such permit or apply to have the source's title V permit revised to incorporate the conditions of the extension of compliance. The conditions of an extension of compliance granted under this paragraph will be incorporated into the affected source's title V permit according to the provisions of part 70 or Federal title V regulations in this chapter (42 U.S.C. 7661), whichever are applicable. (B) Any request under this paragraph for an extension of compliance with a relevant standard must be submitted in writing to the appropriate authority no later than 120 days prior to the affected source's compliance date (as specified in paragraphs (b) and (c) of this section), except as provided for in paragraph (i)(4)(i)(C) of this section. Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the date of denial. Emission standards established under this part may specify alternative dates for the submittal of requests for an extension of compliance if alternatives are appropriate for the source categories affected by those standards. (C) An owner or operator may submit a compliance extension request after the date specified in paragraph (i)(4)(i)(B) of this section provided the need for the compliance extension arose after that date, and before the otherwise applicable compliance date and the need arose due to circumstances beyond reasonable control of the owner or operator. This request must include, in addition to the information required in paragraph (i)(6)(i) of this section, a statement of the reasons additional time is needed and the date when the owner or operator first learned of the problems. Nonfrivolous requests submitted under this paragraph will stay the applicability of the rule as to the emission points in question until such time as the request is granted or denied. A denial will be effective as of the original compliance date. (ii) The owner or operator of an existing source unable to comply with a relevant standard established under this part pursuant to section 112(f) of the Act may request that the Administrator grant an extension allowing the source up to 2 years after the standard's effective date to comply with the standard. The Administrator may grant such an extension if he/she finds that such additional period is necessary for the installation of controls and that steps will be taken during the period of the extension to assure that the health of persons will be protected from imminent endangerment. Any request for an extension of compliance with a relevant standard under this paragraph must be submitted in writing to the Administrator not later than 90 calendar days after the effective date of the relevant standard. (5) The owner or operator of an existing source that has installed BACT or technology required to meet LAER [as specified in paragraph (i)(2)(ii) of this section] prior to the promulgation of a relevant emission standard in this part may request that the Administrator grant an extension allowing the source 5 years from the date on which such installation was achieved, as determined by the Administrator, to comply with the standard. Any request for an extension of compliance with a relevant standard under this paragraph shall be submitted in writing to the Administrator not later than 120 days after the promulgation date of the standard. The Administrator may grant such an extension if he or she finds that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard. (6) (i) The request for a compliance extension under paragraph (i)(4) of this section shall include the following information: (A) A description of the controls to be installed to comply with the standard; (B) A compliance schedule, including the date by which each step toward compliance will be reached. At a minimum, the list of dates shall include: (1) The date by which on-site construction, installation of emission control equipment, or a process change is planned to be initiated; and (2) The date by which final compliance is to be achieved; (C) [Reserved] (D) [Reserved] (ii) The request for a compliance extension under paragraph (i)(5) of this section shall include all information needed to demonstrate to the Administrator's satisfaction that the installation of BACT or technology to meet LAER controls the same pollutant (or stream of pollutants) that would be controlled at that source by the relevant emission standard. (7) Advice on requesting an extension of compliance may be obtained from the Administrator (or the State with an approved permit program). (8) Approval of requestfor extension of compliance. Paragraphs (i)(9) through (i)(14) of this section concern approval of an extension of compliance requested under paragraphs (i)(4) through (i)(6) of this section. (9) Based on the information provided in any request made under paragraphs (i)(4) through (i)(6) of this section, or other information, the Administrator (or the State with an approved permit program) may grant an extension of compliance with an emission standard, as specified in paragraphs (i)(4) and (i)(5) of this section. (10) The extension will be in writing and will - Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-19 of 45

APPENDIX NESHAP SUBPART A General Provisions (i) Identify each affected source covered by the extension; (ii) Specify the termination date of the extension; (iii) Specify the dates by which steps toward compliance are to be taken, if appropriate; (iv) Specify other applicable requirements to which the compliance extension applies (e.g., performance tests); and (v) (A) Under paragraph (i)(4), specify any additional conditions that the Administrator (or the State) deems necessary to assure installation of the necessary controls and protection of the health of persons during the extension period; or (B) Under paragraph (i)(5), specify any additional conditions that the Administrator deems necessary to assure the proper operation and maintenance of the installed controls during the extension period. (11) The owner or operator of an existing source that has been granted an extension of compliance under paragraph (i)(10) of this section may be required to submit to the Administrator (or the State with an approved permit program) progress reports indicating whether the steps toward compliance outlined in the compliance schedule have been reached. The contents of the progress reports and the dates by which they shall be submitted will be specified in the written extension of compliance granted under paragraph (i)(10) of this section. (12) (i) The Administrator (or the State with an approved permit program) will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(i) or (i)(5) of this section. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 30 calendar days after receipt of the original application and within 30 calendar days after receipt of any supplementary information that is submitted. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. (ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 30 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application. (iii) Before denying any request for an extension of compliance, the Administrator (or the State with an approved permit program) will notify the owner or operator in writing of the Administrator's (or the State's) intention to issue the denial, together with - (A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator (or the State) before further action on the request. (iv) The Administrator's final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made. (13) (i) The Administrator will notify the owner or operator in writing of approval or intention to deny approval of a request for an extension of compliance within 30 calendar days after receipt of sufficient information to evaluate a request submitted under paragraph (i)(4)(ii) of this section. The 30-day approval or denial period will begin after the owner or operator has been notified in writing that his/her application is complete. The Administrator (or the State) will notify the owner or operator in writing of the status of his/her application, that is, whether the application contains sufficient information to make a determination, within 15 calendar days after receipt of the original application and within 15 calendar days after receipt of any supplementary information that is submitted. (ii) When notifying the owner or operator that his/her application is not complete, the Administrator will specify the information needed to complete the application and provide notice of opportunity for the applicant to present, in writing, within 15 calendar days after he/she is notified of the incomplete application, additional information or arguments to the Administrator to enable further action on the application. (iii) Before denying any request for an extension of compliance, the Administrator will notify the owner or operator in writing of the Administrator's intention to issue the denial, together with - (A) Notice of the information and findings on which the intended denial is based; and (B) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the intended denial, additional information or arguments to the Administrator before further action on the request. (iv) A final determination to deny any request for an extension will be in writing and will set forth the specific grounds on which the denial is based. The final determination will be made within 30 calendar days after Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-20 of 45

APPENDIX NESHAP SUBPART A General Provisions presentation of additional information or argument (if the application is complete), or within 30 calendar days after the final date specified for the presentation if no presentation is made. (14) The Administrator (or the State with an approved permit program) may terminate an extension of compliance at an earlier date than specified if any specification under paragraph (i)(10)(iii) or (iv) of this section is not met. Upon a determination to terminate, the Administrator will notify, in writing, the owner or operator of the Administrator's determination to terminate, together with: (i) Notice of the reason for termination; and (ii) Notice of opportunity for the owner or operator to present in writing, within 15 calendar days after he/she is notified of the determination to terminate, additional information or arguments to the Administrator before further action on the termination. (iii) A final determination to terminate an extension of compliance will be in writing and will set forth the specific grounds on which the termination is based. The final determination will be made within 30 calendar days after presentation of additional information or arguments, or within 30 calendar days after the final date specified for the presentation if no presentation is made. (15) [Reserved] (16) The granting of an extension under this section shall not abrogate the Administrator's authority under section 114 of the Act. (j) Exemption from compliance with emission standards.The President may exempt any stationary source from compliance with any relevant standard established pursuant to section 112 of the Act for a period of not more than 2 years if the President determines that the technology to implement such standard is not available and that it is in the national security interests of the United States to do so. An exemption under this paragraph may be extended for 1 or more additional periods, each period not to exceed 2 years. § 63.7 Performance testing requirements. (a) Applicability andperformance test dates. (1) The applicability of this section is set out in § 63.1(a)(4). (2) If required to do performance testing by a relevant standard, and unless a waiver of performance testing is obtained under this section or the conditions of paragraph (c)(3)(ii)(B) of this section apply, the owner or operator of the affected source must perform such tests within 180 days of the compliance date for such source. (i)- (viii) [Reserved] (ix) When an emission standard promulgated under this part is more stringent than the standard proposed (see § 63.6(b)(3)), the owner or operator of a new or reconstructed source subject to that standard for which construction or reconstruction is commenced between the proposal and promulgation dates of the standard shall comply with performance testing requirements within 180 days after the standard's effective date, or within 180 days after startup of the source, whichever is later. If the promulgated standard is more stringent than the proposed standard, the owner or operator may choose to demonstrate compliance with either the proposed or the promulgated standard. If the owner or operator chooses to comply with the proposed standard initially, the owner or operator shall conduct a second performance test within 3 years and 180 days after the effective date of the standard, or after startup of the source, whichever is later, to demonstrate compliance with the promulgated standard. (3) The Administrator may require an owner or operator to conduct performance tests at the affected source at any other time when the action is authorized by section 114 of the Act. (b) Notification of performance test. (1) The owner or operator of an affected source must notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is initially scheduled to begin to allow the Administrator, upon request, to review an approve the site-specific test plan required under paragraph (c) of this section and to have an observer present during the test. (2) In the event the owner or operator is unable to conduct the performance test on the date specified in the notification requirement specified in paragraph (b)(1) of this section due to unforeseeable circumstances beyond his or her control, the owner or operator must notify the Administrator as soon as practicable and without delay prior to the scheduled performance test date and specify the date when the performance test is rescheduled. This notification of delay in conducting the performance test shall not relieve the owner or operator of legal responsibility for compliance with any other applicable provisions of this part or with any other applicable Federal, State, or local requirement, nor will it prevent the Administrator from implementing or enforcing this part or taking any other action under the Act. (c) Quality assuranceprogram. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-21 of 45

APPENDIX NESHAP SUBPART A General Provisions (1) The results of the quality assurance program required in this paragraph will be considered by the Administrator when he/she determines the validity of a performance test. (2) (i) Submission of site-specific test plan. Before conducting a required performance test, the owner or operator of an affected source shall develop and, if requested by the Administrator, shall submit a site-specific test plan to the Administrator for approval. The test plan shall include a test program summary, the test schedule, data quality objectives, and both an internal and external quality assurance (QA) program. Data quality objectives are the pretest expectations of precision, accuracy, and completeness of data. (ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of test data precision; an example of internal QA is the sampling and analysis of replicate samples. (iii) The external QA program shall include, at a minimum, application of plans for a test method performance audit (PA) during the performance test. The PA's consist of blind audit samples provided by the Administrator and analyzed during the performance test in order to provide a measure of test data bias. The external QA program may also include systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities. (iv) The owner or operator of an affected source shall submit the site-specific test plan to the Administrator upon the Administrator's request at least 60 calendar days before the performance test is scheduled to take place, that is, simultaneously with the notification of intention to conduct a performance test required under paragraph (b) of this section, or on a mutually agreed upon date. (v) The Administrator may request additional relevant information after the submittal of a site-specific test plan. (3) Approval of site-specific test plan. (i) The Administrator will notify the owner or operator of approval or intention to deny approval of the site-specific test plan (if review of the site-specific test plan is requested) within 30 calendar days after receipt of the original plan and within 30 calendar days after receipt of any supplementary information that is submitted under paragraph (c)(3)(i)(B) of this section. Before disapproving any site-specific test plan, the Administrator will notify the applicant of the Administrator's intention to disapprove the plan together with - (A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present, within 30 calendar days after he/she is notified of the intended disapproval, additional information to the Administrator before final action on the plan. (ii) In the event that the Administrator fails to approve or disapprove the site-specific test plan within the time period specified in paragraph (c)(3)(i) of this section, the following conditions shall apply: (A) If the owner or operator intends to demonstrate compliance using the test method(s) specified in the relevant standard or with only minor changes to those tests methods (see paragraph (e)(2)(i) of this section), the owner or operator must conduct the performance test within the time specified in this section using the specified method(s); (B) If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method when the Administrator approves the site-specific test plan (if review of the site-specific test plan is requested) or after the alternative method is approved (see paragraph (f) of this section). However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval 45 days after submission of the site-specific test plan or request to use an alternative method. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative. (iii) Neither the submission of a site-specific test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator's failure to approve or disapprove a plan in a timely manner shall - (A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act. (4) (i) Performance test method auditprogram. The owner or operator must analyze performance audit (PA) samples during each performance test. The owner or operator must request performance audit materials 30 days prior to the test date. Audit materials including cylinder audit gases may be obtained by contacting the appropriate EPA Regional Office or the responsible enforcement authority. (ii) The Administrator will have sole discretion to require any subsequent remedial actions of the owner or operator based on the PA results. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-22 of 45

APPENDIX NESHAP SUBPART A General Provisions (iii) If the Administrator fails to provide required PA materials to an owner or operator of an affected source in time to analyze the PA samples during a performance test, the requirement to conduct a PA under this paragraph shall be waived for such source for that performance test. Waiver under this paragraph of the requirement to conduct a PA for a particular performance test does not constitute a waiver of the requirement to conduct a PA for future required performance tests. (d) Performance testingfacilities. If required to do performance testing, the owner or operator of each new source and, at the request of the Administrator, the owner or operator of each existing source, shall provide performance testing facilities as follows: (1) Sampling ports adequate for test methods applicable to such source. This includes: (i) Constructing the air pollution control system such-that volumetric flow rates and pollutant emission rates can be accurately determined by applicable test methods and procedures; and (ii) Providing a stack or duct free of cyclonic flow during performance tests, as demonstrated by applicable test methods and procedures; (2) Safe sampling platform(s); (3) Safe access to sampling platform(s); (4) Utilities for sampling and testing equipment; and (5) Any other facilities that the Administrator deems necessary for safe and adequate testing of a source. (e) Conduct of performance tests. (1) Performance tests shall be conducted under such conditions as the Administrator specifies to the owner or operator based on representative performance (i.e., performance based on normal operating conditions) of the affected source. Operations during periods of startup, shutdown, and malfunction shall not constitute representative conditions for the purpose of a performance test, nor shall emissions in excess of the level of the relevant standard during periods of startup, shutdown, and malfunction be considered a violation of the relevant standard unless otherwise specified in the relevant standard or a determination of noncompliance is made under § 63.6(e). Upon request, the owner or operator shall make available to the Administrator such records as may be necessary to determine the conditions of performance tests. (2) Performance tests shall be conducted and data shall be reduced in accordance with the test methods and procedures set forth in this section, in each relevant standard, and, if required, in applicable appendices of parts 51, 60, 61, and 63 of this chapter unless the Administrator - (i) Specifies or approves, in specific cases, the use of a test method with minor changes in methodology (see definition in § 63.90(a)). Such changes may be approved in conjunction with approval of the site-specific test plan (see paragraph (c) of this section); or (ii) Approves the use of an intermediate or major change or alternative to a test method (see definitions in § 63.90(a)), the results of which the Administrator has determined to be adequate for indicating whether a specific affected source is in compliance; or (iii) Approves shorter sampling times or smaller sample volumes when necessitated by process variables or other factors; or (iv) Waives the requirement for performance tests because the owner or operator of an affected source has demonstrated by other means to the Administrator's satisfaction that the affected source is in compliance with the relevant standard. (3) Unless otherwise specified in a relevant standard or test method, each performance test shall consist of three separate runs using the applicable test method. Each run shall be conducted for the time and under the conditions specified in the relevant standard. For the purpose of determining compliance with a relevant standard, the arithmetic mean of the results of the three runs shall apply. Upon receiving approval from the Administrator, results of a test run may be replaced with results of an additional test run in the event that (i) A sample is accidentally lost after the testing team leaves the site; or (ii) Conditions occur in which one of the three runs must be discontinued because of forced shutdown; or (iii) Extreme meteorological conditions occur; or (iv) Other circumstances occur that are beyond the owner or operator's control. (4) Nothing in paragraphs (e)(1) through (e)(3) of this section shall be construed to abrogate the Administrator's authority to require testing under section 114 of the Act. (f) Use of an alternative test method - (1) General. Until authorized to use an intermediate or major change or alternative to a test method, the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-23 of 45

APPENDIX NESHAP SUBPART A General Provisions (2) The owner or operator of an affected source required to do performance testing by a relevant standard may use an alternative test method from that specified in the standard provided that the owner or operator - (i) Notifies the Administrator of his or her intention to use an alternative test method at least 60 days before the performance test is scheduled to begin; (ii) Uses Method 301 in appendix A of this part to validate the alternative test method. This may include the use of specific procedures of Method 301 if use of such procedures are sufficient to validate the alternative test method; and (iii) Submits the results of the Method 301 validation process along with the notification of intention and the justification for not using the specified test method. The owner or operator may submit the information required in this paragraph well in advance of the deadline specified in paragraph (f)(2)(i) of this section to ensure a timely review by the Administrator in order to meet the performance test date specified in this section or the relevant standard. (3) The Administrator will determine whether the owner or operator's validation of the proposed alternative test method is adequate and issue an approval or disapproval of the alternative test method. If the owner or operator intends to demonstrate compliance by using an alternative to any test method specified in the relevant standard, the owner or operator is authorized to conduct the performance test using an alternative test method after the Administrator approves the use of the alternative method. However, the owner or operator is authorized to conduct the performance test using an alternative method in the absence of notification of approval/disapproval 45 days after submission of the request to use an alternative method and the request satisfies the requirements in paragraph (f)(2) of this section. The owner or operator is authorized to conduct the performance test within 60 calendar days after he/she is authorized to demonstrate compliance using an alternative test method. Notwithstanding the requirements in the preceding three sentences, the owner or operator may proceed to conduct the performance test as required in this section (without the Administrator's prior approval of the site-specific test plan) if he/she subsequently chooses to use the specified testing and monitoring methods instead of an alternative. (4) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative test method for the purposes of demonstrating compliance with a relevant standard, the Administrator may require the use of a test method specified in a relevant standard. (5) If the owner or operator uses an alternative test method for an affected source during a required performance test, the owner or operator of such source shall continue to use the alternative test method for subsequent performance tests at that affected source until he or she receives approval from the Administrator to use another test method as allowed under § 63.7(f). (6) Neither the validation and approval process nor the failure to validate an alternative test method shall abrogate the owner or operator's responsibility to comply with the requirements of this part. (g) Data analysis, recordkeeping, and reporting. (1) Unless otherwise specified in a relevant standard or test method, or as otherwise approved by the Administrator in writing, results of a performance test shall include the analysis of samples, determination of emissions, and raw data. A performance test is "completed" when field sample collection is terminated. The owner or operator of an affected source shall report the results of the performance test to the Administrator before the, close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator (see § 63.9(i)). The results of the performance test shall be submitted as part of the notification of compliance status required under § 63.9(h). Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall send the results of the performance test to the appropriate permitting authority. (2) [Reserved] (3) For a minimum of 5 years after a performance test is conducted, the owner or operator shall retain and make available, upon request, for inspection by the Administrator the records or results of such performance test and other data needed to determine emissions from an affected source. (h) Waiver of performance tests. (1) Until a waiver of a performance testing requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section. (2) Individual performance tests may be waived upon written application to the Administrator if, in the Administrator's judgment, the source is meeting the relevant standard(s) on a continuous basis, or the source is being operated under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request. (3) Request to waive a performance test. (i) If a request is made for an extension of compliance under § 63.6(i), the application for a waiver of an initial performance test shall accompany the information Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-24 of 45

APPENDIX NESHAP SUBPART A General Provisions required for the request for an extension of compliance. If no extension of compliance is requested or if the owner or operator has requested an extension of compliance and the Administrator is still considering that request, the application for a waiver of an initial performance test shall be submitted at least 60 days before the performance test if the site-specific test plan under paragraph (c) of this section is not submitted. (ii) If an application for a waiver of a subsequent performance test is made, the application may accompany any required compliance progress report, compliance status report, or excess emissions and continuous monitoring system performance report [such as those required under § 63.6(I), § 63.9(h), and § 63.10(e) or specified in a relevant standard or in the source's title V permit], but it shall be submitted at least 60 days before the performance test if the site-specific test plan required under paragraph (c) of this section is not submitted. (iii) Any application for a waiver of a performance test shall include information justifying the owner or operator's request for a waiver, such as the technical or economic infeasibility, or the impracticality, of the affected source performing the required test. (4) Approval of request to waive performance test. The Administrator will approve or deny a request for a waiver of a performance test made under paragraph (h)(3) of this section when he/she - (i) Approves or denies an extension of compliance under § 63.6(i)(8); or (ii) Approves or disapproves a site-specific test plan under § 63.7(c)(3); or (iii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iv) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable. (5) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source. § 63.8 Monitoring requirements. (a) Applicability. (1) The applicability of this section is set out in § 63.1(a)(4). (2) For the purposes of this part, all CMS required under relevant standards shall be subject to the provisions of this section upon promulgation of performance specifications for CMS as specified in the relevant standard or otherwise by the Administrator. (3) [Reserved] (4) Additional monitoring requirements for control devices used to comply with provisions in relevant standards of this part are specified in § 63.11. (b) Conduct of monitoring. (1) Monitoring shall be conducted as set forth in this section and the relevant standard(s) unless the Administrator - (i) Specifies or approves the use of minor changes in methodology for the specified monitoring requirements and procedures (see § 63.90(a) for definition); or (ii) Approves the use of an intermediate or major change or alternative to any monitoring requirements or procedures (see § 63.90(a) for definition). (iii) Owners or operators with flares subject to § 63.11(b) are not subject to the requirements of this section unless otherwise specified in the relevant standard. (2) (i) When the emissions from two or more affected sources are combined before being released to the atmosphere, the owner or operator may install an applicable CMS for each emission stream or for the combined emissions streams, provided the monitoring is sufficient to demonstrate compliance with the relevant standard. (ii) If the relevant standard is a mass emission standard and the emissions from one affected source are released to the atmosphere through more than one point, the owner or operator must install an applicable CMS at each emission point unless the installation of fewer systems is - (A) Approved by the Administrator; or (B) Provided for in a relevant standard (e.g., instead of requiring that a CMS be installed at each emission point before the effluents from those points are channeled to a common control device, the standard specifies that only one CMS is required to be installed at the vent of the control device). (3) When more than one CMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CMS. However, when one CMS is used as Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-25 of 45

APPENDIX NESHAP SUBPART A General Provisions a backup to another CMS, the owner or operator shall report the results from the CMS used to meet the monitoring requirements of this part. If both such CMS are used during a particular reporting period to meet the monitoring requirements of this part, then the owner or operator shall report the results from each CMS for the relevant compliance period. (c) Operationand maintenance of continuous monitoring systems. (1) The owner or operator of an affected source shall maintain and operate each CMS as specified in this section, or in a relevant standard, and in a manner consistent with good air pollution control practices. (i) The owner or operator of an affected source must maintain and operate each CMS as specified in § 63.6(e)(1). (ii) The owner or operator must keep the necessary parts for routine repairs of the affected CMS equipment readily available. (iii) The owner or operator of an affected source must develop and implement a written startup, shutdown, and malfunction plan for CMS as specified in § 63.6(e)(3). (2) (i) All CMS must be installed such that representative measures of emissions or process parameters from the affected source are obtained. In addition, CEMS must be located according to procedures contained in the applicable performance specification(s). (ii) Unless the individual subpart states otherwise, the owner or operator must ensure the read out (that portion of the CMS that provides a visual display or record), or other indication of operation, from any CMS required for compliance with the emission standard is readily accessible on site for operational control or inspection by the operator of the equipment. (3) All CMS shall be installed, operational, and the data verified as specified in the relevant standard either prior to or in conjunction with conducting performance tests under § 63.7. Verification of operational status shall, at a minimum, include completion of the manufacturer's written specifications or recommendations for installation, operation, and calibration of the system. (4) Except for system breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level calibration drift adjustments, all CMS, including COMS and CEMS, shall be in continuous operation and shall meet minimum frequency of operation requirements as follows: (i) All COMS shall complete a minimum of one cycle of sampling and analyzing for each successive 10-second period and one cycle of data recording for each successive 6-minute period. (ii) All CEMS for measuring emissions other than opacity shall complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. (5) Unless otherwise approved by the Administrator, minimum procedures for COMS shall include a method for producing a simulated zero opacity condition and an upscale (high-level) opacity condition using a certified neutral density filter or other related technique to produce a known obscuration of the light beam. Such procedures shall provide a system check of all the analyzer's internal optical surfaces and all electronic circuitry, including the lamp and photodetector assembly normally used in the measurement of opacity. (6) The owner or operator of a CMS that is not a CPMS, which is installed in accordance with the provisions of this part and the applicable CMS performance specification(s), must check the zero (low-level) and high-level calibration drifts at least once daily in accordance with the written procedure specified in the performance evaluation plan developed under paragraphs (e)(3)(i) and (ii) of this section. The zero (low-level) and high-level calibration drifts must be adjusted, at a minimum, whenever the 24-hour zero (low-level) drift exceeds two times the limits of the applicable performance specification(s) specified in the relevant standard. The system shall allow the amount of excess zero (low-level) and high-level drift measured at the 24-hour interval checks to be recorded and quantified whenever specified. For COMS, all optical and instrumental surfaces exposed to the effluent gases must be cleaned prior to performing the zero (low-level) and high-level drift adjustments; the optical surfaces and instrumental surfaces must be cleaned when the cumulative automatic zero compensation, if applicable, exceeds 4 percent opacity. The CPMS must be calibrated prior to use for the purposes of complying with this section. The CPMS must be checked daily for indication that the system is responding. If the CPMS system includes an internal system check, results must be recorded and checked daily for proper operation. (7) (i) A CMS is out of control if - (A) The zero (low-level), mid-level (if applicable), or high-level calibration drift (CD) exceeds two times the applicable CD specification in the applicable performance specification or in the relevant standard; or (B) The CMS fails a performance test audit (e.g., cylinder gas audit), relative accuracy audit, relative accuracy test audit, or linearity test audit; or (C) The COMS CD exceeds two times the limit in the applicable performance specification in the relevant standard. (ii) When the CMS is out of control, the owner or operator of the affected source shall take the necessary corrective action and shall repeat all necessary tests which indicate that the system is out of control. The owner or operator Progress Energy Florida, Inc. 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APPENDIX NESHAP SUBPART A General Provisions shall take corrective action and conduct retesting until the performance requirements are below the applicable limits. The beginning of the out-of-control period is the hour the owner or operator conducts a performance check (e.g., calibration drift) that indicates an exceedance of the performance requirements established under this part. The end of the out-of-control period is the hour following the completion of corrective action and successful demonstration that the system is within the allowable limits. During the period the CMS is out of control, recorded data shall not be used in data averages and calculations, or to meet any data availability requirement established under this part. (8) The owner or operator of a CMS that is out of control as defined in paragraph (c)(7) of this section shall submit all information concerning out-of-control periods, including start and end dates and hours and descriptions of corrective actions taken, in the excess emissions and continuous monitoring system performance report required in § 63.10(e)(3). (d) Quality control program. (1) The results of the quality control program required in this paragraph will be considered by the Administrator when he/she determines the validity of monitoring data. (2) The owner or operator of an affected source that is required to use a CMS and is subject to the monitoring requirements of this section and a relevant standard shall develop and implement a CMS quality control program. As part of the quality control program, the owner or operator shall develop and submit to the Administrator for approval upon request a site-specific performance evaluation test plan for the CMS performance evaluation required in paragraph (e)(3)(i) of this section, according to the procedures specified in paragraph (e). In addition, each quality control program shall include, at a minimum, a written protocol that describes procedures for each of the following operations: (i) Initial and any subsequent calibration of the CMS; (ii) Determination and adjustment of the calibration drift of the CMS; (iii) Preventive maintenance of the CMS, including spare parts inventory; (iv) Data recording, calculations, and reporting; (v) Accuracy audit procedures, including sampling and analysis methods; and (vi) Program of corrective action for a malfunctioning CMS. (3) The owner or operator shall keep these written procedures on record for the life of the affected source or until the affected source is no longer subject to the provisions of this part, to be made available for inspection, upon request, by the Administrator. If the performance evaluation plan is revised, the owner or operator shall keep previous (i.e., superseded) versions of the performance evaluation plan on record to be made available for inspection, upon request, by the Administrator, for a period of 5 years after each revision to the plan. Where relevant, e.g., program of corrective action for a malfunctioning CMS, these written procedures may be incorporated as part of the affected source's startup, shutdown, and malfunction plan to avoid duplication of planning and recordkeeping efforts. (e) Performance evaluation of continuous monitoring systems - (1) General. When required by a relevant standard, and at any other time the Administrator may require under section 114 of the Act, the owner or operator of an affected source being monitored shall conduct a performance evaluation of the CMS. Such performance evaluation shall be conducted according to the applicable specifications and procedures described in this section or in the relevant standard. (2) Notification of performance evaluation. The owner or operator shall notify the Administrator in writing of the date of the performance evaluation simultaneously with the notification of the performance test date required under § 63.7(b) or at least 60 days prior to the date the performance evaluation is scheduled to begin if no performance test is required. (3) (i) Submission of site-specific performance evaluation test plan. Before conducting a required CMS performance evaluation, the owner or operator of an affected source shall develop and submit a site-specific performance evaluation test plan to the Administrator for approval upon request. The performance evaluation test plan shall include the evaluation program objectives, an evaluation program summary, the performance evaluation schedule, data quality objectives, and both an internal and external QA program. Data quality objectives are the pre-evaluation expectations of precision, accuracy, and completeness of data. (ii) The internal QA program shall include, at a minimum, the activities planned by routine operators and analysts to provide an assessment of CMS performance. The external QA program shall include, at a minimum, systems audits that include the opportunity for on-site evaluation by the Administrator of instrument calibration, data validation, sample logging, and documentation of quality control data and field maintenance activities. (iii) The owner or operator of an affected source shall submit the site-specific performance evaluation test plan to the Administrator (if requested) at least 60 days before the performance test or performance evaluation is scheduled to begin, or on a mutually agreed upon date, and review and approval of the performance evaluation test plan by the Administrator will occur with the review and approval of the site-specific test plan (if review of the site-specific test plan is requested). (iv) The Administrator may request additional relevant information after the submittal of a site-specific performance evaluation test plan. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-27 of 45

APPENDIX NESHAP SUBPART A General Provisions (v) In the event that the Administrator fails to approve or disapprove the site-specific performance evaluation test plan within the time period specified in § 63.7(c)(3), the following conditions shall apply: (A) If the owner or operator intends to demonstrate compliance using the monitoring method(s) specified in the relevant standard, the owner or operator shall conduct the performance evaluation within the time specified in this subpart using the specified method(s); (B) If the owner or operator intends to demonstrate compliance by using an alternative to a monitoring method specified in the relevant standard, the owner or operator shall refrain from conducting the performance evaluation until the Administrator approves the use of the alternative method. If the Administrator does not approve the use of the alternative method within 30 days before the performance evaluation is scheduled to begin, the performance evaluation deadlines specified in paragraph (e)(4) of this section may be extended such that the owner or operator shall conduct the performance evaluation within 60 calendar days after the Administrator approves the use of the alternative method. Notwithstanding the requirements in the preceding two sentences, the owner or operator may proceed to conduct the performance evaluation as required in this section (without the Administrator's prior approval of the site-specific performance evaluation test plan) if he/she subsequently chooses to use the specified monitoring method(s) instead of an alternative. (vi) Neither the submission of a site-specific performance evaluation test plan for approval, nor the Administrator's approval or disapproval of a plan, nor the Administrator' failure to approve or disapprove a plan in a timely manner shall - (A) Relieve an owner or operator of legal responsibility for compliance with any applicable provisions of this part or with any other applicable Federal, State, or local requirement; or (B) Prevent the Administrator from implementing or enforcing this part or taking any other action under the Act. (4) Conduct of performance evaluation and performance evaluation dates. The owner or operator of an affected source shall conduct a performance evaluation of a required CMS during any performance test required under § 63.7 in accordance with the applicable performance specification as specified in the relevant standard. Notwithstanding the requirement in the previous sentence, if the owner or operator of an affected source elects to submit COMS data for compliance with a relevant opacity emission standard as provided under § 63.6(h)(7), he/she shall conduct a performance evaluation of the COMS as specified in the relevant standard, before the performance test required under § 63.7 is conducted in time to submit the results of the performance evaluation as specified in paragraph (e)(5)(ii) of this section. If a performance test is not required, or the requirement for a performance test has been waived under § 63.7(h), the owner or operator of an affected source shall conduct the performance evaluation not later than 180 days after the appropriate compliance date for the affected source, as specified in § 63.7(a), or as otherwise specified in the relevant standard. (5) Reporting performance evaluation results. (i) The owner or operator shall furnish the Administrator a copy of a written report of the results of the performance evaluation simultaneously with the results of the performance test required under § 63.7 or within 60 days of completion of the performance evaluation if no test is required, unless otherwise specified in a relevant standard. The Administrator may request that the owner or operator submit the raw data from a performance evaluation in the report of the performance evaluation results. (ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under § 63.7 and described in § 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation under this paragraph. The copies shall be provided at least 15 calendar days before the performance test required under § 63.7 is conducted. (f) Use of an alternativemonitoring method - (1) General. Until permission to use an alternative monitoring procedure (minor, intermediate, or major changes; see definition in § 63.90(a)) has been granted by the Administrator under this paragraph (f)(1), the owner or operator of an affected source remains subject to the requirements of this section and the relevant standard. (2) After receipt and consideration of written application, the Administrator may approve alternatives to any monitoring methods or procedures of this part including, but not limited to, the following: (i) Alternative monitoring requirements when installation of a CMS specified by a relevant standard would not provide accurate measurements due to liquid water or other interferences caused by substances within the effluent gases; (ii) Alternative monitoring requirements when the affected source is infrequently operated; (iii) Alternative monitoring requirements to accommodate CEMS that require additional measurements to correct for stack moisture conditions; (iv) Alternative locations for installing CMS when the owner or operator can demonstrate that installation at alternate locations will enable accurate and representative measurements; (v) Alternate methods for converting pollutant concentration measurements to units of the relevant standard; Progress Energy Florida, Inc. 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APPENDIX NESHAP SUBPART A General Provisions (vi) Alternate procedures for performing daily checks of zero (low-level) and high-level drift that do not involve use of high-level gases or test cells; (vii) Alternatives to the American Society for Testing and Materials (ASTM) test methods or sampling procedures specified by any relevant standard; (viii) Alternative CMS that do not meet the design or performance requirements in this part, but adequately demonstrate a definite and consistent relationship between their measurements and the measurements of opacity by a system complying with the requirements as specified in' the relevant standard. The Administrator may require that such demonstration be performed for each affected source; or (ix) Alternative monitoring requirements when the effluent from a single affected source or the combined effluent from two or more affected sources is released to the atmosphere through more than one point. (3) If the Administrator finds reasonable grounds to dispute the results obtained by an alternative monitoring method, requirement, or procedure, the Administrator may require the use of a method, requirement, or procedure specified in this section or in the relevant standard. If the results of the specified and alternative method, requirement, or procedure do not agree, the results obtained by the specified method, requirement, or procedure shall prevail. (4) (i) Request to use alternativemonitoring procedure. An owner or operator who wishes to use an alternative monitoring procedure must submit an application to the Administrator as described in paragraph (f)(4)(ii) of this section. The application may be submitted at any time provided that the monitoring procedure is not the performance test method used to demonstrate compliance with a relevant standard or other requirement. If the alternative monitoring procedure will serve as the performance test method that is to be used to demonstrate compliance with a relevant standard, the application must be submitted at least 60 days before the performance evaluation is scheduled to begin and must meet the requirements for an alternative test method under § 63.7(f). (ii) The application must contain a description of the proposed alternative monitoring system which addresses the four elements contained in the definition of monitoring in § 63.2 and a performance evaluation test plan, if required, as specified in paragraph (e)(3) of this section. In addition, the application must include information justifying the owner or operator's request for an alternative monitoring method, such as the technical or economic infeasibility, or the impracticality, of the affected source using the required method. (iii) The owner or operator may submit the information required in this paragraph well in advance of the submittal dates specified in paragraph (f)(4)(i) above to ensure a timely review by the Administrator in order to meet the compliance demonstration date specified in this section or the relevant standard. (iv) Application for minor changes to monitoring procedures, as specified in paragraph (b)(1) of this section, may be made in the site-specific performance evaluation plan. (5) Approval of request to use alternative monitoringprocedure. (i) The Administrator will notify the owner or operator of approval or intention to deny approval of the request to use an alternative monitoring method within 30 calendar days after receipt of the original request and within 30 calendar days after receipt of any supplementary information that is submitted. If a request for a minor change is made in conjunction with site-specific performance evaluation plan, then approval of the plan will constitute approval of the minor change. Before disapproving any request to use an alternative monitoring method, the Administrator will notify the applicant of the Administrator's intention to disapprove the request together with -- (A) Notice of the information and findings on which the intended disapproval is based; and (B) Notice of opportunity for the owner or operator to present additional information to the Administrator before final action on the request. At the time the Administrator notifies the applicant of his or her intention to disapprove the request, the Administrator will specify how much time the owner or operator will have after being notified of the intended disapproval to submit the additional information. (ii) The Administrator may establish general procedures and criteria in a relevant standard to accomplish the requirements of paragraph (f)(5)(i) of this section. (iii) If the Administrator approves the use of an alternative monitoring method for an affected source under paragraph (f)(5)(i) of this section, the owner or operator of such source shall continue to use the alternative monitoring method until he or she receives approval from the Administrator to use another monitoring method as allowed by § 63.8(f). (6) Alternative to the relative accuracy test. An alternative to the relative accuracy test for CEMS specified in a relevant standard may be requested as follows: (i) Criteriafor approval of alternativeprocedures. An alternative to the test method for determining relative accuracy is available for affected sources with emission rates demonstrated to be less than 50 percent of the relevant standard. The owner or operator of an affected source may petition the Administrator under paragraph (f)(6)(ii) of this section to substitute the relative accuracy test in section 7 of Performance Specification 2 with the procedures in section 10 if the results of a performance test conducted according to the requirements in § 63.7, or other tests performed following the criteria in § 63.7, demonstrate that the emission rate of the pollutant of interest in the units of the relevant standard is less than 50 percent of the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the owner or operator may petition the Administrator to substitute the relative accuracy test with the procedures in section 10 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-29 of 45

APPENDIX NESHAP SUBPART A General Provisions of Performance Specification 2 if the control device exhaust emission rate is less than 50 percent of the level needed to meet the control efficiency requirement. The alternative procedures do not apply if the CEMS is used continuously to determine compliance with the relevant standard. (ii) Petition to use alternative to relative accuracy test. The petition to use an alternative to the relative accuracy test shall include a detailed description of the procedures to be applied, the location and the procedure for conducting the alternative, the concentration or response levels of the alternative relative accuracy materials, and the other equipment checks included in the alternative procedure(s). The Administrator will review the petition for completeness and applicability. The Administrator's determination to approve an alternative will depend on the intended use of the CEMS data and may require specifications more stringent than in Performance Specification 2. (iii) Rescission of approval to use alternative to relative accuracy test. The Administrator will review the permission to use an alternative to the CEMS relative accuracy test and may rescind such permission if the CEMS data from a successful completion of the alternative relative accuracy procedure indicate that the affected source's emissions are approaching the level of the relevant standard. The criterion for reviewing the permission is that the collection of CEMS data shows that emissions have exceeded 70 percent of the relevant standard for any averaging period, as specified in the relevant standard. For affected sources subject to emission limitations expressed as control efficiency levels, the criterion for reviewing the permission is that the collection of CEMS data shows that exhaust emissions have exceeded 70 percent of the level needed to meet the control efficiency requirement for any averaging period, as specified in the relevant standard. The owner or operator of the affected source shall maintain records and determine the level of emissions relative to the criterion for permission to use an alternative for relative accuracy testing. If this criterion is exceeded, the owner or operator shall notify the Administrator within 10 days of such occurrence and include a description of the nature and cause of the increased emissions. The Administrator will review the notification and may rescind permission to use an alternative and require the owner or operator to conduct a relative accuracy test of the CEMS as specified in section 7 of Performance Specification 2. (g) Reduction of monitoring data. (1) The owner or operator of each CMS must reduce the monitoring data as specified in paragraphs (g)(1) through (5) of this section. (2) The owner or operator of each COMS shall reduce all data to 6-minute averages calculated from 36 or more data points equally spaced over each 6-minute period. Data from CEMS for measurement other than opacity, unless otherwise specified in the relevant standard, shall be reduced to 1-hour averages computed from four or more data points equally spaced over each 1-hour period, except during periods when calibration, quality assurance, or maintenance activities pursuant to provisions of this part are being performed. During these periods, a valid hourly average shall consist of at least two data points with each representing a 15-minute period. Alternatively, an arithmetic or integrated 1-hour average of CEMS data may be used. Time periods for averaging are defined in § 63.2. (3) The data may be recorded in reduced or nonreduced form (e.g., ppm pollutant and percent 02 or ng/J of pollutant). (4) All emission data shall be converted into units of the relevant standard for reporting purposes using the conversion procedures specified in that standard. After conversion into units of the relevant standard, the data may be rounded to the same number of significant digits as used in that standard to specify the emission limit (e.g., rounded to the nearest 1 percent opacity). (5) Monitoring data recorded during periods of unavoidable CMS breakdowns, out-of-control periods, repairs, maintenance periods, calibration checks, and zero (low-level) and high-level adjustments must not be included in any data average computed under this part. For the owner or operator complying with the requirements of § 63. 10(b)(2)(vii)(A) or (B), data averages must include any data recorded during periods of monitor breakdown or malfunction. § 63.9 Notification requirements. (a) Applicability and general information. (1) The applicability of this section is set out in § 63. 1(a)(4). (2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions. (3) If any State requires a notice that contains all the information required in a notification listed in this section, the owner or operator may send the Administrator a copy of the notice sent to the State to satisfy the requirements of this section for that notification. (4) (i) Before a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in § 63.13). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-30 of 45

APPENDIX NESHAP SUBPART A General Provisions (ii) After a State has been delegated the authority to implement and enforce notification requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit notifications to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each notification submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any notifications at its discretion. (b) Initial notifications. (1) (i) The requirements of this paragraph apply to the owner or operator of an affected source when such source becomes subject to a relevant standard. (ii) If an area source that otherwise would be subject to an emission standard or other requirement established under this part if it were a major source subsequently increases its emissions of hazardous air pollutants (or its potential to emit hazardous air pollutants) such that the source is a major source that is subject to the emission standard or other requirement, such source shall be subject to the notification requirements of this section. (iii) Affected sources that are required under this paragraph to submit an initial notification may use the application for approval of construction or reconstruction under § 63.5(d) of this subpart, if relevant, to fulfill the initial notification requirements of this paragraph. (2) The owner or operator of an affected source that has an initial startup before the effective date of a relevant standard under this part shall notify the Administrator in writing that the source is subject to the relevant standard. The notification, which shall be submitted not later than 120 calendar days after the effective date of the relevant standard (or within 120 calendar days after the source becomes subject to the relevant standard), shall provide the following information: (i) The name and address of the owner or operator; (ii) The address (i.e., physical location) of the affected source; (iii) An identification of the relevant standard, or other requirement, that is the basis of the notification and the source's compliance date; (iv) A brief description of the nature, size, design, and method of operation of the source and an identification of the types of emission points within the affected source subject to the relevant standard and types of hazardous air pollutants emitted; and (v) A statement of whether the affected source is a major source or an area source. (3) [Reserved] (4) The owner or operator of a new or reconstructed major affected source for which an application for approval of construction or reconstruction is required under § 63.5(d) must provide the following information in writing to the Administrator: (i) A notification of intention to construct a new major-emitting affected source, reconstruct a major-emitting affected source, or reconstruct a major source such that the source becomes a major-emitting affected source with the application for approval of construction or reconstruction as specified in § 63.5(d)(1)(i); and (ii) [Reserved] (iii) [Reserved] (iv) [Reserved]; and (v) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date. (5) The owner or operator of a new or reconstructed affected source for which an application for approval of construction or reconstruction is not required under § 63.5(d) must provide the following information in writing to the Administrator: (i) A notification of intention to construct a new affected source, reconstruct an affected source, or reconstruct a source such that the source becomes an affected source, and (ii) A notification of the actual date of startup of the source, delivered or postmarked within 15 calendar days after that date. (iii) Unless the owner or operator has requested and received prior permission from the Administrator to submit less than the information in § 63.5(d), the notification must include the information required on the application for approval of construction or reconstruction as specified in § 63.5(d)(1)(i). (c) Request for extension of compliance. If the owner or operator of an affected source cannot comply with a relevant standard by the applicable compliance date for that source, or if the owner or operator has installed BACT or technology to meet LAER consistent with § 63.6(i)(5) of this subpart, he/she may submit to the Administrator (or the State with an approved permit program) a request for an extension of compliance as specified in § 63.6(i)(4) through § 63.6(i)(6). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-31 of 45

APPENDIX NESHAP SUBPART A General Provisions (d) Notification that source is subject to special compliance requirements. An owner or operator of a new source that is subject to special compliance requirements as specified in § 63.6(b)(3) and § 63.6(b)(4) shall notify the Administrator of his/her compliance obligations not later than the notification dates established in paragraph (b) of this section for new sources that are not subject to the special provisions. (e) Notification of performance test. The owner or operator of an affected source shall notify the Administrator in writing of his or her intention to conduct a performance test at least 60 calendar days before the performance test is scheduled to begin to allow the Administrator to review and approve the site-specific test plan required under § 63.7(c), if requested by the Administrator, and to have an observer present during the test. (f) Notification of opacity and visible emission observations. The owner or operator of an affected source shall notify the Administrator in writing of the anticipated date for conducting the opacity or visible emission observations specified in § 63.6(h)(5), if such observations are required for the source by a relevant standard. The notification shall be submitted with the notification of the performance test date, as specified in paragraph (e) of this section, or if no performance test is required or visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the initial performance test required under § 63.7, the owner or operator shall deliver or postmark the notification not less than 30 days before the opacity or visible emission observations are scheduled to take place. (g) Additional notification requirementsfor sources with continuous monitoring systems. The owner or operator of an affected source required to use a CMS by a relevant standard shall furnish the Administrator written notification as follows: (1) A notification of the date the CMS performance evaluation under § 63.8(e) is scheduled to begin, submitted simultaneously with the notification of the performance test date required under § 63.7(b). If no performance test is required, or if the requirement to conduct a performance test has been waived for an affected source under § 63.7(h), the owner or operator shall notify the Administrator in writing of the date of the performance evaluation at least 60 calendar days before the evaluation is scheduled to begin; (2) A notification that COMS data results will be used to determine compliance with the applicable opacity emission standard during a performance test required by § 63.7 in lieu of Method 9 or other opacity emissions test method data, as allowed by § 63.6(h)(7)(ii), if compliance with an opacity emission standard is required for the source by a relevant standard. The notification shall be submitted at least 60 calendar days before the performance test is scheduled to begin; and (3) A notification that the criterion necessary to continue use of an alternative to relative accuracy testing, as provided by § 63.8(f)(6), has been exceeded. The notification shall be delivered or postmarked not later than 10 days after the occurrence of such exceedance, and it shall include a description of the nature and cause of the increased emissions. (h) Notification of compliance status. (1) The requirements of paragraphs (h)(2) through (h)(4)of this section apply when an affected source becomes subject to a relevant standard. (2) (i) Before a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit to the Administrator a notification of compliance status, signed by the responsible official who shall certify its accuracy, attesting to whether the source has complied with the relevant standard. The notification shall list - (A) The methods that were used to determine compliance; (B) The results of any performance tests, opacity or visible emission observations, continuous monitoring system (CMS) performance evaluations, and/or other monitoring procedures or methods that were conducted; (C) The methods that will be used for determining continuing compliance, including a description of monitoring and reporting requirements and test methods; (D) The type and quantity of hazardous air pollutants emitted by the source (or surrogate pollutants if specified in the relevant standard), reported in units and averaging times and in accordance with the test methods specified in the relevant standard; (E) If the relevant standard applies to both major and area sources, an analysis demonstrating whether the affected source is a major source (using the emissions data generated for this notification); (F) A description of the air pollution control equipment (or method) for each emission point, including each control device (or method) for each hazardous air pollutant and the control efficiency (percent) for each control device (or method); and (G) A statement by the owner or operator of the affected existing, new, or reconstructed source as to whether the source has complied with the relevant standard or other requirements. (ii) The notification must be sent before the close of business on the 6 0 th day following the completion of the relevant compliance demonstration activity specified in the relevant standard (unless a different reporting period is Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-32 of 45

APPENDIX NESHAP SUBPART A General Provisions specified in the standard, in which case the letter must be sent before the close of business on the day the report of the relevant testing or monitoring results is required to be delivered or postmarked). For example, the notification shall be sent before close of business on the 60th (or other required) day following completion of the initial performance test and again before the close of business on the 60th (or other required) day following the completion of any subsequent required performance test. If no performance test is required but opacity or visible emission observations are required to demonstrate compliance with an opacity or visible emission standard under this part, the notification of compliance status shall be sent before close of business on the 30th day following the completion of opacity or visible emission observations. Notifications may be combined as long as the due date requirement for each notification is met. (3) After a title V permit has been issued to the owner or operator of an affected source, the owner or operator of such source shall comply with all requirements for compliance status reports contained in the source's title V permit, including reports required under this part. After a title V permit has been issued to the owner or operator of an affected source, and each time a notification of compliance status is required under this part, the owner or operator of such source shall submit the notification of compliance status to the appropriate permitting authority following completion of the relevant compliance demonstration activity specified in the relevant standard. (4) [Reserved] (5) If an owner or operator of an affected source submits estimates or preliminary information in the application for approval of construction or reconstruction required in § 63.5(d) in place of the actual emissions data or control efficiencies required in paragraphs (d)(1)(ii)(H) and (d)(2) of § 63.5, the owner or operator shall submit the actual emissions data and other correct information as soon as available but no later than with the initial notification of compliance status required in this section. (6) Advice on a notification of compliance status may be obtained from the Administrator. (i) Adjustment to time periods orpostmark deadlinesfor submittal and review of required communications. (1) (i) Until an adjustment of a time period or postmark deadline has been approved by the Administrator under paragraphs (i)(2) and (i)(3) of this section, the owner or operator of an affected source remains strictly subject to the requirements of this part. (ii) An owner or operator shall request the adjustment provided for in paragraphs (i)(2) and (i)(3) of this section each time he or she wishes to change an applicable time period or postmark deadline specified in this part. (2) Notwithstanding time periods or postmark deadlines specified in this part for the submittal of information to the Administrator by an owner or operator, or the review of such information by the Administrator, such time periods or deadlines may be changed by mutual agreement between the owner or operator and the Administrator. An owner or operator who wishes to request a change in a time period or postmark deadline for a particular requirement shall request the adjustment in writing as soon as practicable before the subject activity is required to take place. The owner or operator shall include in the request whatever information he or she considers useful to convince the Administrator that an adjustment is warranted. (3) If, in the Administrator's judgment, an owner or operator's request for an adjustment to a particular time period or postmark deadline is warranted, the Administrator will approve the adjustment. The Administrator will notify the owner or operator in writing of approval or disapproval of the request for an adjustment within 15 calendar days of receiving sufficient information to evaluate the request. (4) If the Administrator is unable to meet a specified deadline, he or she will notify the owner or operator of any significant delay and inform the owner or operator of the amended schedule. (j) Change in information alreadyprovided. Any change in the information already provided under this section shall be provided to the Administrator in writing within 15 calendar days after the change. § 63.10 Recordkeeping and reporting requirements. (a) Applicability and general information. (1) The applicability of this section is set out in § 63. 1(a)(4). (2) For affected sources that have been granted an extension of compliance under subpart D of this part, the requirements of this section do not apply to those sources while they are operating under such compliance extensions. (3) If any State requires a report that contains all the information required in a report listed in this section, an owner or operator may send the Administrator a copy of the report sent to the State to satisfy the requirements of this section for that report. (4) (i) Before a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-33 of 45

APPENDIX NESHAP SUBPART A General Provisions requirements shall submit reports to the appropriate Regional Office of the EPA (to the attention of the Director of the Division indicated in the list of the EPA Regional Offices in § 63.13). (ii) After a State has been delegated the authority to implement and enforce recordkeeping and reporting requirements established under this part, the owner or operator of an affected source in such State subject to such requirements shall submit reports to the delegated State authority (which may be the same as the permitting authority). In addition, if the delegated (permitting) authority is the State, the owner or operator shall send a copy of each report submitted to the State to the appropriate Regional Office of the EPA, as specified in paragraph (a)(4)(i) of this section. The Regional Office may waive this requirement for any reports at its discretion. (5) If an owner or operator of an affected source in a State with delegated authority is required to submit periodic reports under this part to the State, and if the State has an established timeline for the submission of periodic reports that is consistent with the reporting frequency(ies) specified for such source under this part, the owner or operator may change the dates by which periodic reports under this part shall be submitted (without changing the frequency of reporting) to be consistent with the State's schedule by mutual agreement between the owner or operator and the State. For each relevant standard established pursuant to section 112 of the Act, the allowance in the previous sentence applies in each State beginning 1 year after the affected source's compliance date for that standard. Procedures governing the implementation of this provision are specified in § 63.9(i). (6) If an owner or operator supervises one or more stationary sources affected by more than one standard established pursuant to section 112 of the Act, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required for each source shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the latest compliance date for any relevant standard established pursuant to section 112 of the Act for any such affected source(s). Procedures governing the implementation of this provision are specified in § 63.9(i). (7) If an owner or operator supervises one or more stationary sources affected by standards established pursuant to section 112 of the Act (as amended November 15, 1990) and standards set under part 60, part 61, or both such parts of this chapter, he/she may arrange by mutual agreement between the owner or operator and the Administrator (or the State permitting authority) a common schedule on which periodic reports required by each relevant (i.e., applicable) standard shall be submitted throughout the year. The allowance in the previous sentence applies in each State beginning 1 year after the stationary source is required to be in compliance with the relevant section 112 standard, or 1 year after the stationary source is required to be in compliance with the applicable part 60 or part 61 standard, whichever is latest. Procedures governing the implementation of this provision are specified in § 63.9(i). (b) General recordkeeping requirements. (1) The owner or operator of an affected source subject to the provisions of this part shall maintain files of all information (including all reports and notifications) required by this part recorded in a form suitable and readily available for expeditious inspection and review. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. At a minimum, the most recent 2 years of data shall be retained on site. The remaining 3 years of data may be retained off site. Such files may be maintained on microfilm, on a computer, on computer floppy disks, on magnetic tape disks, or on microfiche. (2) The owner or operator of an affected source subject to the provisions of this part shall maintain relevant records for such source of - (i) The occurrence and duration of each startup, shutdown, or malfunction of operation (i.e., process equipment); (ii) The occurrence and duration of each malfunction of the required air pollution control and monitoring equipment; (iii) All required maintenance performed on the air pollution control and monitoring equipment; (iv) Actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) when such actions are different from the procedures specified in the affected source's startup, shutdown, and malfunction plan (see § 63.6(e)(3)); (v) All information necessary to demonstrate conformance with the affected source's startup, shutdown, and malfunction plan (see § 63.6(e)(3)) when all actions taken during periods of startup, shutdown, and malfunction (including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation) are consistent with the procedures specified in such plan. (The information needed to demonstrate conformance with the startup, shutdown, and malfunction plan may be recorded using a "checklist," or some other effective form of recordkeeping, in order to minimize the recordkeeping burden for conforming events); (vi) Each period during which a CMS is malfunctioning or inoperative (including out-of-control periods); Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-34 of 45

APPENDIX NESHAP SUBPART A General Provisions (vii) All required measurements needed to demonstrate compliance with a relevant standard (including, but not limited to, 15-minute averages of CMS data, raw performance testing measurements, and raw performance evaluation measurements, that support data that the source is required to report); (A) This paragraph applies to owners or operators required to install a continuous emissions monitoring system (CEMS) where the CEMS installed is automated, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. An automated CEMS records and reduces the measured data to the form of the pollutant emission standard through the use of a computerized data acquisition system. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this section, the owner or operator shall retain the most recent consecutive three averaging periods of subhourly measurements and a file that contains a hard copy of the data acquisition system algorithm used to reduce the measured data into the reportable form of the standard. (B) This paragraph applies to owners or operators required to install a CEMS where the measured data is manually reduced to obtain the reportable form of the standard, and where the calculated data averages do not exclude periods of CEMS breakdown or malfunction. In lieu of maintaining a file of all CEMS subhourly measurements as required under paragraph (b)(2)(vii) of this sections, the owner or operator shall retain all subhourly measurements for the most recent reporting period. The subhourly measurements shall be retained for 120 days from the date of the most recent summary or excess emission report submitted to the Administrator. (C) The Administrator or delegated authority, upon notification to the source, may require the owner or operator to maintain all measurements as required by paragraph (b)(2)(vii), if the administrator or the delegated authority determines these records are required to more accurately assess the compliance status of the affected source. (viii) All results of performance tests, CMS performance evaluations, and opacity and visible emission observations; (ix) All measurements as may be necessary to determine the conditions of performance tests and performance evaluations; (x) All CMS calibration checks; (xi) All adjustments and maintenance performed on CMS; (xii) Any information demonstrating whether a source is meeting the requirements for a waiver of recordkeeping or reporting requirements under this part, if the source has been granted a waiver under paragraph (f) of this section; (xiii) All emission levels relative to the criterion for obtaining permission to use an alternative to the relative accuracy test, if the source has been granted such permission under § 63.8(f)(6); and (xiv) All documentation supporting initial notifications and notifications of compliance status under § 63.9. (3) Recordkeeping requirementfor applicabilitydeterminations.If an owner or operator determines that his or her stationary source that emits (or has the potential to emit, without considering controls) one or more hazardous air pollutants regulated by any standard established pursuant to section 112(d) or (f), and that stationary source is in the source category regulated by the relevant standard, but that source is not subject to the relevant standard (or other requirement established under this part) because of limitations on the source's potential to emit or an exclusion, the owner or operator must keep a record of the applicability determination on site at the source for a period of 5 years after the determination, or until the source changes its operations to become an affected source, whichever comes first. The record of the applicability determination must be signed by the person making the determination and include an analysis (or other information) that demonstrates why the owner or operator believes the source is unaffected (e.g., because the source is an area source). The analysis (or other information) must be sufficiently detailed to allow the Administrator to make a finding about the source's applicability status with regard to the relevant standard or other requirement. If relevant, the analysis must be performed in accordance with requirements established in relevant subparts of this part for this purpose for particular categories of stationary sources. If relevant, the analysis should be performed in accordance with EPA guidance materials published to assist sources in making applicability determinations under section 112, if any. The requirements to determine applicability of a standard under § 63.1 (b)(3) and to record the results of that determination under paragraph (b)(3) of this section shall not by themselves create an obligation for the owner or operator to obtain a title V permit. (c) Additional recordkeeping requirementsfor sources with continuous monitoring systems. In addition to complying with the requirements specified in paragraphs (b)(1) and (b)(2) of this section, the owner or operator of an affected source required to install a CMS by a relevant standard shall maintain records for such source of - (1) All required CMS measurements (including monitoring data recorded during unavoidable CMS breakdowns and out-of-control periods); (2)-(4) [Reserved] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-35 of 45

APPENDIX NESHAP SUBPART A General Provisions (5) The date and time identifying each period during which the CMS was inoperative except for zero (low-level) and high-level checks; (6) The date and time identifying each period during which the CMS was out of control, as defined in § 63.8(c)(7); (7) The specific identification (i.e., the date and time of commencement and completion) of each period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during startups, shutdowns, and malfunctions of the affected source; (8) The specific identification (i.e., the date and time of commencement and completion) of each time period of excess emissions and parameter monitoring exceedances, as defined in the relevant standard(s), that occurs during periods other than startups, shutdowns, and malfunctions of the affected source; (9) [Reserved] (10) The nature and cause of any malfunction (if known); (11) The corrective action taken or preventive measures adopted; (12) The nature of the repairs or adjustments to the CMS that was inoperative or out of control; (13) The total process operating time during the reporting period; and (14) All procedures that are part of a quality control program developed and implemented for CMS under § 63.8(d). (15) In order to satisfy the requirements of paragraphs (c)(10) through (c)(12) of this section and to avoid duplicative recordkeeping efforts, the owner or operator may use the affected source's startup, shutdown, and malfunction plan or records kept to satisfy the recordkeeping requirements of the startup, shutdown, and malfunction plan specified in § 63.6(e), provided that such plan and records adequately address the requirements of paragraphs (c)(10) through (c)(12). (d) General reporting requirements. (1) Not-withstanding the requirements in this paragraph or paragraph (e) of this section, the owner or operator of an affected source subject to reporting requirements under this part shall submit reports to the Administrator in accordance with the reporting requirements in the relevant standard(s). (2) Reporting results of performance tests. Before a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of any performance test under § 63.7 to the Administrator. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator shall report the results of a required performance test to the appropriate permitting authority. The owner or operator of an affected source shall report the results of the performance test to the Administrator (or the State with an approved permit program) before the close of business on the 60th day following the completion of the performance test, unless specified otherwise in a relevant standard or as approved otherwise in writing by the Administrator. The results of the performance test shall be submitted as part of the notification of compliance status required under § 63.9(h). (3) Reporting results of opacity or visible emission observations.The owner or operator of an affected source required to conduct opacity or visible emission observations by a relevant standard shall report the opacity or visible emission results (produced using Test Method 9 or Test Method 22, or an alternative to these test methods) along with the results of the performance test required under § 63.7. If no performance test is required, or if visibility or other conditions prevent the opacity or visible emission observations from being conducted concurrently with the performance test required under § 63.7, the owner or operator shall report the opacity or visible emission results before the close of business on the 30th day following the completion of the opacity or visible emission observations. (4) Progressreports. The owner or operator of an affected source who is required to submit progress reports as a condition of receiving an extension of compliance under § 63.6(i) shall submit such reports to the Administrator (or the State with an approved permit program) by the dates specified in the written extension of compliance. (5) (i) Periodic startup, shutdown, and malfunction reports. If actions taken by an owner or operator during a startup, shutdown, or malfunction of an affected source (including actions taken to correct a malfunction) are consistent with the procedures specified in the source's startup, shutdown, and malfunction plan (see Sec. 63.6(e)(3)), the owner or operator shall state such information in a startup, shutdown, and malfunction report. Such a report shall identify any instance where any action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the affected source's startup, shutdown, and malfunction plan, but the source does not exceed any applicable emission limitation in the relevant emission standard. Such a report shall also include the number, duration, and a brief description for each type of malfunction which occurred during the reporting period and which caused or may have caused any applicable emission limitation to be exceeded. Reports shall only be required if a startup, shutdown, or malfunction occurred during the reporting period. The startup, shutdown, and malfunction report shall consist of a letter, containing the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, that shall be submitted to the Administrator semiannually (or on a more frequent basis if specified otherwise in a relevant standard or as established otherwise by the permitting authority in the source's title V permit). The startup, shutdown, and malfunction report shall be delivered or postmarked by the 30th day following the end of each calendar half (or other calendar reporting period, as appropriate). If the owner or operator is required to submit excess emissions and continuous monitoring system performance (or other periodic) reports under this part, the startup, shutdown, and malfunction Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-36 of 45

APPENDIX NESHAP SUBPART A General Provisions reports required under this paragraph may be submitted simultaneously with the excess emissions and continuous monitoring system performance (or other) reports. If startup, shutdown, and malfunction reports are submitted with excess emissions and continuous monitoring system performance (or other periodic) reports, and the owner or operator receives approval to reduce the frequency of reporting for the latter under paragraph (e) of this section, the frequency of reporting for the startup, shutdown, and malfunction reports also may be reduced if the Administrator does not object to the intended change. The procedures to implement the allowance in the preceding sentence shall be the same as the procedures specified in paragraph (e)(3) of this section. (ii) Immediate startup, shutdown, and malfunction reports. Notwithstanding the allowance to reduce the frequency of reporting for periodic startup, shutdown, and malfunction reports under paragraph (d)(5)(i) of this section, any time an action taken by an owner or operator during a startup, shutdown, or malfunction (including actions taken to correct a malfunction) is not consistent with the procedures specified in the affected source's startup, shutdown, and malfunction plan, and the source exceeds any applicable emission limitation in the relevant emission standard, the owner or operator shall report the actions taken for that event within 2 working days after commencing actions inconsistent with the plan followed by a letter within 7 working days after the end of the event. The immediate report required under this paragraph (d)(5)(ii) shall consist of a telephone call (or facsimile (FAX) transmission) to the Administrator within 2 working days after commencing actions inconsistent with the plan, and it shall be followed by a letter, delivered or postmarked within 7 working days after the end of the event, that contains the name, title, and signature of the owner or operator or other responsible official who is certifying its accuracy, explaining the circumstances of the event, the reasons for not following the startup, shutdown, and malfunction plan, and describing all excess emissions and/or parameter monitoring exceedances which are believed to have occurred. Notwithstanding the requirements of the previous sentence, after the effective date of an approved permit program in the State in which an affected source is located, the owner or operator may make alternative reporting arrangements, in advance, with the permitting authority in that State. Procedures governing the arrangement of alternative reporting requirements under this paragraph (d)(5)(ii) are specified in Sec. 63.9(i). (e) Additional reporting requirementsfor sources with continuous monitoring systems - (1) General. When more than one CEMS is used to measure the emissions from one affected source (e.g., multiple breechings, multiple outlets), the owner or operator shall report the results as required for each CEMS. (2) Reporting results of continuous monitoring system performance evaluations. (i) The owner or operator of an affected source required to install a CMS by a relevant standard shall furnish the Administrator a copy of a written report of the results of the CMS performance evaluation, as required under § 63.8(e), simultaneously with the results of the performance test required under § 63.7, unless otherwise specified in the relevant standard. (ii) The owner or operator of an affected source using a COMS to determine opacity compliance during any performance test required under § 63.7 and described in § 63.6(d)(6) shall furnish the Administrator two or, upon request, three copies of a written report of the results of the COMS performance evaluation conducted under § 63.8(e). The copies shall be furnished at least 15 calendar days before the performance test required under § 63.7 is conducted. (3) Excess emissions and continuous monitoring system performance report and summary report. (i) Excess emissions and parameter monitoring exceedances are defined in relevant standards. The owner or operator of an affected source required to install a CMS by a relevant standard shall submit an excess emissions and continuous monitoring system performance report and/or a summary report to the Administrator semiannually, except when - (A) More frequent reporting is specifically required by a relevant standard; (B) The Administrator determines on a case-by-case basis that more frequent reporting is necessary to accurately assess the compliance status of the source; or (C) [Reserved]. (ii) Request to reduce frequency of excess emissions and continuous monitoring system performance reports. Notwithstanding the frequency of reporting requirements specified in paragraph (e)(3)(i) of this section, an owner or operator who is required by a relevant standard to submit excess emissions and continuous monitoring system performance (and summary) reports on a quarterly (or more frequent) basis may reduce the frequency of reporting for that standard to semiannual if the following conditions are met: (A) For 1 full year (e.g., 4 quarterly or 12 monthly reporting periods) the affected source's excess emissions and continuous monitoring system performance reports continually demonstrate that the source is in compliance with the relevant standard; (B) The owner or operator continues to comply with all recordkeeping and monitoring requirements specified in this subpart and the relevant standard; and (C) The Administrator does not object to a reduced frequency of reporting for the affected source, as provided in paragraph (e)(3)(iii) of this section. (iii) The frequency of reporting of excess emissions and continuous monitoring system performance (and summary) reports required to comply with a relevant standard may be reduced only after the owner or operator notifies the Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-37 of 45

APPENDIX NESHAP SUBPART A General Provisions Administrator in writing of his or her intention to make such a change and the Administrator does not object to the intended change. In deciding whether to approve a reduced frequency of reporting, the Administrator may review information concerning the source's entire previous performance history during the 5-year recordkeeping period prior to the intended change, including performance test results, monitoring data, and evaluations of an owner or operator's conformance with operation and maintenance requirements. Such information may be used by the Administrator to make a judgment about the source's potential for noncompliance in the future. If the Administrator disapproves the owner or operator's request to reduce the frequency of reporting, the Administrator will notify the owner or operator in writing within 45 days after receiving notice of the owner or operator's intention. The notification from the Administrator to the owner or operator will specify the grounds on which the disapproval is based. In the absence of a notice of disapproval within 45 days, approval is automatically granted. (iv) As soon as CMS data indicate that the source is not in compliance with any emission limitation or operating parameter specified in the relevant standard, the frequency of reporting shall revert to the frequency specified in the relevant standard, and the owner or operator shall submit an excess emissions and continuous monitoring system performance (and summary) report for the noncomplying emission points at the next appropriate reporting period following the noncomplying event. After demonstrating ongoing compliance with the relevant standard for another full year, the owner or operator may again request approval from the Administrator to reduce the frequency of reporting for that standard, as provided for in paragraphs (e)(3)(ii) and (e)(3)(iii) of this section. (v) Content and submittal datesfor excess emissions and monitoring system performance reports. All excess emissions and monitoring system performance reports and all summary reports, if required, shall be delivered or postmarked by the 30th day following the end of each calendar half or quarter, as appropriate. Written reports of excess emissions or exceedances of process or control system parameters shall include all the information required in paragraphs (c)(5) through (c)(13) of this section, in § 63.8(c)(7) and § 63.8(c)(8), and in the relevant standard, and they shall contain the name, title, and signature of the responsible official who is certifying the accuracy of the report. When no excess emissions or exceedances of a parameter have occurred, or a CMS has not been inoperative, out of control, repaired, or adjusted, such information shall be stated in the report. (vi) Summary report.As required under paragraphs (e)(3)(vii) and (e)(3)(viii) of this section, one summary report shall be submitted for the hazardous air pollutants monitored at each affected source (unless the relevant standard specifies that more than one summary report is required, e.g., one summary report for each hazardous air pollutant monitored). The summary report shall be entitled "Summary Report - Gaseous and Opacity Excess Emission and Continuous Monitoring System Performance" and shall contain the following information: (A) The company name and address of the affected source; (B) An identification of each hazardous air pollutant monitored at the affected source; (C) The beginning and ending dates of the reporting period; (D) A brief description of the process units; (E) The emission and operating parameter limitations specified in the relevant standard(s); (F) The monitoring equipment manufacturer(s) and model number(s); (G) The date of the latest CMS certification or audit; (H) The total operating time of the affected source during the reporting period; (I) An emission data summary (or similar summary if the owner or operator monitors control system parameters), including the total duration of excess emissions during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of excess emissions expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total duration of excess emissions during the reporting period into those that are due to startup/shutdown, control equipment problems, process problems, other known causes, and other unknown causes; (J) A CMS performance summary (or similar summary if the owner or operator monitors control system parameters), including the total CMS downtime during the reporting period (recorded in minutes for opacity and hours for gases), the total duration of CMS downtime expressed as a percent of the total source operating time during that reporting period, and a breakdown of the total CMS downtime during the reporting period into periods that are due to monitoring equipment malfunctions, nonmonitoring equipment malfunctions, quality assurance/quality control calibrations, other known causes, and other unknown causes; (K) A description of any changes in CMS, processes, or controls since the last reporting period; (L) The name, title, and signature of the responsible official who is certifying the accuracy of the report; and (M) The date of the report. (vii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is less than 1 percent of the total operating time for the reporting period, and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report shall be Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-38 of 45

APPENDIX NESHAP SUBPART A General Provisions submitted, and the full excess emissions and continuous monitoring system performance report need not be submitted unless required by the Administrator. (viii) If the total duration of excess emissions or process or control system parameter exceedances for the reporting period is 1 percent or greater of the total operating time for the reporting period, or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, both the summary report and the excess emissions and continuous monitoring system performance report shall be submitted. (4) Reporting continuous opacity monitoring system data produced during a performance test. The owner or operator of an affected source required to use a COMS shall record the monitoring data produced during a performance test required under § 63.7 and shall furnish the Administrator a written report of the monitoring results. The report of COMS data shall be submitted simultaneously with the report of the performance test results required in paragraph (d)(2) of this section. (f) Waiver of recordkeeping or reporting requirements. (1) Until a waiver of a recordkeeping or reporting requirement has been granted by the Administrator under this paragraph, the owner or operator of an affected source remains subject to the requirements of this section. (2) Recordkeeping or reporting requirements may be waived upon written application to the Administrator if, in the Administrator's judgment, the affected source is achieving the relevant standard(s), or the source is operating under an extension of compliance, or the owner or operator has requested an extension of compliance and the Administrator is still considering that request. (3) If an application for a waiver of record-keeping or reporting is made, the application shall accompany the request for an extension of compliance under § 63.6(i), any required compliance progress report or compliance status report required under this part (such as under § 63.6(i) and § 63.9(h)) or in the source's title V permit, or an excess emissions and continuous monitoring system performance report required under paragraph (e) of this section, whichever is applicable. The application shall include whatever information the owner or operator considers useful to convince the Administrator that a waiver of recordkeeping or reporting is warranted. (4) The Administrator will approve or deny a request for a waiver of recordkeeping or reporting requirements under this paragraph when he/she - (i) Approves or denies an extension of compliance; or (ii) Makes a determination of compliance following the submission of a required compliance status report or excess emissions and continuous monitoring systems performance report; or (iii) Makes a determination of suitable progress towards compliance following the submission of a compliance progress report, whichever is applicable. (5) A waiver of any recordkeeping or reporting requirement granted under this paragraph may be conditioned on other recordkeeping or reporting requirements deemed necessary by the Administrator. (6) Approval of any waiver granted under this section shall not abrogate the Administrator's authority under the Act or in any way prohibit the Administrator from later canceling the waiver. The cancellation will be made only after notice is given to the owner or operator of the affected source. § 63.11 Control device requirements. (a) Applicability. The applicability of this section is set out in Sec. 63. 1(a)(4). (b) Flares. (1) Owners or operators using flares to comply with the provisions of this part shall monitor these control devices to assure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators using flares shall monitor these control devices. (2) Flares shall be steam-assisted, air-assisted, or non-assisted. (3) Flares shall be operated at all times when emissions may be vented to them. (4) Flares shall be designed for and operated with no visible emissions, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. Test Method 22 in appendix A of part 60 of this chapter shall be used to determine the compliance of flares with the visible emission provisions of this part. The observation period is 2 hours and shall be used according to Method 22. (5) Flares shall be operated with a flame present at all times. The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. (6) An owner/operator has the choice of adhering to the heat content specifications in paragraph (b)(6)(ii) of this section, and the maximum tip velocity specifications in paragraph (b)(7) or (b)(8) of this section, or adhering to the requirements in paragraph (b)(6)(i) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-39 of 45

APPENDIX NESHAP SUBPART A General Provisions (i) (A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume) or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity Vmax, as determined by the following equation: Vmax = (XH2 - KI)

  • K2 Where:

Vmax = Maximum permitted velocity, m/sec. K, = Constant, 6.0 volume-percent hydrogen. K2 = Constant, 3.9 (m/sec)/volume-percent hydrogen. XH2 = The volume-percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in § 63.14). (B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (b)(7)(i) of this section. (ii) Flares shall be used only with the net heating value of the gas being combusted at 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted at 7.45 MJ/scm (200 Btu/scf) or greater if the flare is non-assisted. The net heating value of the gas being combusted in a flare shall be calculated using the following equation: n HT = K EDCiHi i=l Where: HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 'C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 'C. K = Constant = 1.740 x 10-7 (1/ppmv)(g-mole/scm)(MJ/kcal); where the standard temperature for (g-mole/scm) is 20 'C. Ci = Concentration of sample component i in ppmv on a wet basis, as measured for organics by Test Method 18 and measured for hydrogen and carbon monoxide by American Society for Testing and Materials (ASTM) D1946-77 or 90 (Reapproved 1994) (incorporated by reference as specified in § 63.14). Hi = Net heat of combustion of sample component i, kcal/g-mole at 25 'C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95. (incorporated by reference as specified in § 63.14) if published values are not available or cannot be calculated. n = Number of sample components. (7) (i) Steam-assisted and nonassisted flares shall be designed for and operated with an exit velocity less than 18.3 m/sec (60 ft/sec), except as provided in paragraphs (b)(7)(ii) and (b)(7)(iii) of this section. The actual exit velocity of a flare shall be determined by dividing by the volumetric flow rate of gas being combusted (in units of emission standard temperature and pressure), as determined by Test Method 2, 2A, 2C, or 2D in appendix A to 40 CFR part 60 of this chapter, as appropriate, by the unobstructed (free) cross-sectional area of the flare tip. (ii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, equal to or greater than 18.3 m/sec (60 ft/sec) but less than 122 m/sec (400 ft/sec), are allowed if the net heating value of the gas being combusted is greater than 37.3 MJ/scm (1,000 Btu/scf). (iii) Steam-assisted and nonassisted flares designed for and operated with an exit velocity, as determined by the method specified in paragraph (b)(7)(i) of this section, less than the velocity Vmax, as determined by the method specified in this paragraph, but less than 122 m/sec (400 ft/sec) are allowed. The maximum permitted velocity, Vmax, for flares complying with this paragraph shall be determined by the following equation: Log1o(Vmax)=(HT +28.8)/31.7 Where: Vmx = Maximum permitted velocity, m/sec. 28.8 = Constant. 31.7 = Constant. HT = The net heating value as determined in paragraph (b)(6) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-40 of 45

APPENDIX NESHAP SUBPART A General Provisions (8) Air-assisted flares shall be designed and operated with an exit velocity less than the velocity Vma,. The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation: Vmx = 8.71 + 0.708(HT) Where: Vmax = Maximum permitted velocity, m/sec. 8.71 = Constant. 0.708 = Constant. HT = The net heating value as determined in paragraph (b)(6)(ii) of this section. § 63.12 State authority and delegations. (a) The provisions of this part shall not be construed in any manner to preclude any State or political subdivision thereof from (1) Adopting and enforcing any standard, limitation, prohibition, or other regulation applicable to an affected source subject to the requirements of this part, provided that such standard, limitation, prohibition, or regulation is not less stringent than any requirement applicable to such source established under this part; (2) Requiring the owner or operator of an affected source to obtain permits, licenses, or approvals prior to initiating construction, reconstruction, modification, or operation of such source; or (3) Requiring emission reductions in excess of those specified in subpart D of this part as a condition for granting the extension of compliance authorized by section 112(i)(5) of the Act. (b) (1) Section 112(1) of the Act directs the Administrator to delegate to each State, when appropriate, the authority to implement and enforce standards and other requirements pursuant to section 112 for stationary sources located in that State. Because of the unique nature of radioactive material, delegation of authority to implement and enforce standards that control radionuclides may require separate approval. (2) Subpart E of this part establishes procedures consistent with section 112(1) for the approval of State rules or programs to implement and enforce applicable Federal rules promulgated under the authority of section 112. Subpart E also establishes procedures for the review and withdrawal of section 112 implementation and enforcement authorities granted through a section 112(1) approval. (c) All information required to be submitted to the EPA under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act, provided that each specific delegation may exempt sources from a certain Federal or State reporting requirement. The Administrator may permit all or some of the information to be submitted to the appropriate State agency only, instead of to the EPA and the State agency. § 63.13 Addresses of State air pollution control agencies and EPA Regional Offices. (a) All requests, reports, applications, submittals, and other communications to the Administrator pursuant to this part shall be submitted to the appropriate Regional Office of the U.S. Environmental Protection Agency indicated as follows: EPA Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North Carolina, South Carolina, Tennessee). Director; Air, Pesticides and Toxics Management Division; Atlanta Federal Center, 61 Forsyth Street; Atlanta, GA 30303-3104. (b) All information required to be submitted to the Administrator under this part also shall be submitted to the appropriate State agency of any State to which authority has been delegated under section 112(1) of the Act. The owner or operator of an affected source may contact the appropriate EPA Regional Office for the mailing addresses for those States whose delegation requests have been approved. (c) If any State requires a submittal that contains all the information required in an application, notification, request, report, statement, or other communication required in this part, an owner or operator may send the appropriate Regional Office of the EPA a copy of that submittal to satisfy the requirements of this part for that communication. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-41 of 45

APPENDIX NESHAP SUBPART A General Provisions § 63.14 Incorporations by reference. (a) The materials listed in this section are incorporated by reference in the corresponding sections noted. These incorporations by reference were approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are incorporated as they exist on the date of the approval, and notice of any change in these materials will be published in the Federal Register. The materials are available for purchase at the corresponding addresses noted below, and all are available for inspection at the Office of the Federal Register, 800 North Capitol Street, NW., suite 700, Washington, DC, at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC, and at the EPA Library (MD-35), U.S. EPA, Research Triangle Park, North Carolina. (b) The following materials are available for purchase from at least one of the following addresses: American Society for Testing and Materials (ASTM), 100 Barr Harbor Drive, Post Office Box C700, West Conshohocken, PA 19428-2959; or ProQuest, 300 North Zeeb Road, Ann Arbor, MI 48106. (1) ASTM D523-89, Standard Test Method for Specular Gloss, IBR approved for § 63.782. (2) ASTM D1193-77, 91, Standard Specification for Reagent Water, IBR approved for Appendix A: Method 306, Sections 7.1.1 and 7.4.2. (3) ASTM D1331-89, Standard Test Methods for Surface and Interfacial Tension of Solutions of Surface Active Agents, IBR approved for Appendix A: Method 306B, Sections 6.2, 11.1, and 12.2.2. (4) ASTM D1475-90, Standard Test Method for Density of Paint, Varnish Lacquer, and Related Products, IBR approved for § 63.788, Appendix A. (5) ASTM D1946-77, 90, 94, Standard Method for Analysis of Reformed Gas by Gas Chromatography, IBR approved for § 63.11(b)(6). (6) ASTM D2369-93, 95, Standard Test Method for Volatile Content of Coatings, IBR approved for § 63.788, Appendix A. (7) ASTM D2382-76, 88, Heat of Combustion of Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method), IBR approved for § 63.11(b)(6). (8) ASTM D2879-83, 96, Test Method for Vapor Pressure-Temperature Relationship and Initial Decomposition Temperature of Liquids by Isoteniscope, IBR approved for § 63.111 of Subpart G. (9) ASTM D3257-93, Standard Test Methods for Aromatics in Mineral Spirits by Gas Chromatography, IBR approved for § 63.786(b). (10) ASTM 3695-88, Standard Test Method for Volatile Alcohols in Water by Direct Aqueous-Injection Gas Chromatography, IBR approved for § 63.365(e)(1) of Subpart 0. (11) ASTM D3792-91, Standard Method for Water Content of Water-Reducible Paints by Direct Injection into a Gas Chromatograph, IBR approved for § 63.788, Appendix A. (12) ASTM D3912-80, Standard Test Method for Chemical Resistance of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for § 63.782. (13) ASTM D4017-90, 96a, Standard Test Method for Water in Paints and Paint Materials by the Karl Fischer Titration Method, IBR approved for § 63.788, Appendix A. (14) ASTM D4082-89, Standard Test Method for Effects of Gamma Radiation on Coatings for Use in Light-Water Nuclear Power Plants, IBR approved for § 63.782. (15) ASTM D4256-89, 94, Standard Test Method for Determination of the Decontaminability of Coatings Used in Light-Water Nuclear Power Plants, IBR approved for § 63.782. (16) ASTM D4809-95, Standard Test Method for Heat of Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), IBR approved for § 63.11(b)(6). (17) ASTM E180-93, Standard Practice for Determining the Precision of ASTM Methods for Analysis and Testing of Industrial Chemicals, IBR approved for § 63.786(b). (18) ASTM E260-91, 96, General Practice for Packed Column Gas Chromatography, IBR approved for §§ 63.750(b)(2) and 63.786(b)(5). (19) Reserved (20) Reserved (21) ASTM D2099-00, Standard Test Method for Dynamic Water Resistance of Shoe Upper Leather by the Maeser Water Penetration Tester, IBR approved for § 63.5350. (24) ASTM D2697-86 (Reapproved 1998), "Standard Test Method for Volume Nonvolatile Matter in Clear or Pigmented Coatings," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1), 63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1), 63.4941(b)(1), and 63.5160(c). (25) ASTM D6093-97 (Reapproved 2003), "Standard Test Method for Percent Volume Nonvolatile Matter in Clear or Pigmented Coatings Using a Helium Gas Pycnometer," IBR approved for Sec. Sec. 63.3161(f)(1), 63.3521(b)(1), 63.3941(b)(1), 63.4141(b)(1), 63.4741(b)(1), 63.4941(b)(1), and 63.5160(c). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-42 of 45

APPENDIX NESHAP SUBPART A General Provisions (26) ASTM D1475-98 (Reapproved 2003), "Standard Test Method for Density of Liquid Coatings, Inks, and Related Products," IBR approved for Sec. Sec. 63.3151(b), 63.3941(b)(4), 63.3941(c), 63.3951(c), 63.4141(b)(3), 63.4141(c), and 63.455 1(c). (27) ASTM D 6522-00, Standard Test Method for Determination of Nitrogen Oxides, Carbon Monoxide and Oxygen concentrations in Emissions from Natural Gas Fired Reciprocating Engines, Combustion Turbines, Boilers, and Process heaters Using Portable Analyzers, IBR approved for Sec. 63.9307(c)(2). (28) [Reserved] (29) ASTM D6420-99, Standard Test Method for Determination of Gaseous Organic Compounds by Direct Interface Gas Chromatography-Mass Spectrometry, IBR approved for §§ 63.5799 and 63.5850. (30) ASTM E 515-95 (Reapproved 2000), Standard Test Method for Leaks Using Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2). (31) ASTM D5291-02, Standard Test Methods for Instrumental Determination of Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants, IBR approved for Sec. 63.3981, appendix A. (32) ASTM D5965-02, "Standard Test Methods for Specific Gravity of Coating Powders," IBR approved for Sec. Sec. 63.3151(b) and 63.3951(c). (33) ASTM D6053-00, Standard Test Method for Determination of Volatile Organic Compound (VOC) Content of Electrical Insulating Varnishes, IBR approved for Sec. 63.3981, appendix A. (34) E145-94 (Reapproved 2001), Standard Specification for Gravity-Convection and Forced-Ventilation Ovens, IBR approved for Sec. 63.4581, Appendix A. (35) [Reserved] (36) ASTM D5066-91 (Reapproved 2001), "Standard Test Method for Determination of the Transfer Efficiency Under Production Conditions for Spray Application of Automotive Paints-Weight Basis," IBR approved for Sec. 63.3161(g). (37) ASTM D5087-02, "Standard Test Method for Determining Amount of Volatile Organic Compound (VOC) Released from Solventborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. Sec. 63.3165(e) and 63.3176, appendix A. (38) ASTM D6266-00a, "Test Method for Determining the Amount of Volatile Organic Compound (VOC) Released from Waterborne Automotive Coatings and Available for Removal in a VOC Control Device (Abatement)," IBR approved for Sec. 63.3165(e). (c) The materials listed below are available for purchase from the American Petroleum Institute (API), 1220 L Street, NW., Washington, DC 20005. (1) API Publication 2517, Evaporative Loss from External Floating-Roof Tanks, Third Edition, February 1989, IBR approved for § 63.111 of subpart G of this part. (2) API Publication 2518, Evaporative Loss from Fixed-roof Tanks, Second Edition, October 1991, IBR approved for § 63.150(g)(3)(i)(C) of subpart G of this part. (3) API Manual of Petroleum Measurement Specifications (MPMS) Chapter 19.2, Evaporative Loss From Floating-Roof Tanks (formerly API Publications 2517 and 2519), First Edition, April 1997, IBR approved for § 63.1251 of subpart GGG of this part. (d) State and Local Requirements. The materials listed below are available at the Air and Radiation Docket and Information Center, U.S. EPA, 401 M St., SW., Washington, DC. (1) California Regulatory Requirements Applicable to the Air Toxics Program,January 5, 1999, IBR approved for § 63.99(a)(5)(ii) of subpart E of this part. (2) New Jersey's Toxic CatastrophePrevention Act Program, (July 20, 1998), Incorporation By Reference approved for § 63.99 (a)(30)(i) of subpart E of this part. (3) (i) Letter of June 7, 1999 to the U.S. Environmental Protection Agency Region 3 from the Delaware Department of Natural Resources and Environmental Control requesting formal full delegation to take over primary responsibility for implementation and enforcement of the Chemical Accident Prevention Program under Section 112(r) of the Clean Air Act Amendments of 1990. (ii) Delaware Department of Natural Resources and Environmental Control, Division of Air and Waste Management, Accidental Release Prevention Regulation, sections 1 through 5 and sections 7 through 14, effective January 11, 1999, IBR approved for § 63.99(a)(8)(i) of subpart E of this part. (iii) State of Delaware Regulations Governing the Control of Air Pollution (October 2000), IBR approved for § 63.99(a)(8)(ii)-(v) of subpart E of this part. (e) The materials listed below are available for purchase from the National Institute of Standards and Technology, Springfield, VA 22161, (800) 553-6847. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-43 of 45

APPENDIX NESHAP SUBPART A General Provisions (1) Handbook 44, Specificiations, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices 1998, IBR approved for § 63.1303(e)(3). (2) [Reserved] (f) The following material is available from the National Council of the Paper Industry for Air and Stream Improvement, Inc. (NCASI), P. 0. Box 133318, Research Triangle Park, NC 27709-3318 or at http://www.ncasi.org: NCASI Method DI/MEOH-94.02, Methanol in Process Liquids GC/FID (Gas Chromatography/Flame Ionization Detection), August 1998, Methods Manual, NCASI, Research Triangle Park, NC, IBR approved for § 63.457(c)(3)(ii) of subpart S of this part. (g) The materials listed below are available for purchase from AOAC International, Customer Services, Suite 400, 2200 Wilson Boulevard, Arlington, Virginia, 22201-3301, Telephone (703) 522-3032, Fax (703) 522-5468. (1) AOAC Official Method 978.01 Phosphorus (Total) in Fertilizers, Automated Method, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (2) AOAC Official Method 969.02 Phosphorus (Total) in Fertilizers, Alkalimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (3) AOAC Official Method 962.02 Phosphorus (Total) in Fertilizers, Gravimetric Quinolinium Molybdophosphate Method, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (4) AOAC Official Method 957.02 Phosphorus (Total) in Fertilizers, Preparation of Sample Solution, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (5) AOAC Official Method 929.01 Sampling of Solid Fertilizers, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (6) AOAC Official Method 929.02 Preparation of Fertilizer Sample, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (7) AOAC Official Method 958.01 Phosphorus (Total) in Fertilizers, Spectrophotometric Molybdovanadophosphate Method, Sixteenth edition, 1995, IBR approved for § 63.626(d)(3)(vi). (h) The materials listed below are available for purchase from The Association of Florida Phosphate Chemists, P.O. Box 1645, Bartow, Florida, 33830, Book of Methods Used and Adopted By The Association of Florida Phosphate Chemists, Seventh Edition 1991, IBR. (1) Section IX, Methods of Analysis for Phosphate Rock, No. 1 Preparation of Sample, IBR approved for § 63.606(c)(3)(ii) and § 63.626(c)(3)(ii). (2) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus -- P205 or Ca3(PO4)2, Method A-Volumetric Method, IBR approved for § 63.606(c)(3)(ii) and § 63.626(c)(3)(ii). (3) Section IX, Methods of Analysis for Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method B -- Gravimetric Quimociac Method, IBR approved for § 63.606(c)(3)(ii) and § 63.626(c)(3)(ii). (4) Section IX, Methods of Analysis For Phosphate Rock, No. 3 Phosphorus-P205 or Ca3(PO4)2, Method C -- Spectrophotometric Method, IBR approved for § 63.606(c)(3)(ii) and § 63.626(c)(3)(ii). (5) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method A -- Volumetric Method, IBR approved for § 63.606(c)(3)(ii), § 63.626(c)(3)(ii), and § 63.626(d)(3)(v). (6) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method B -- Gravimetric Quimociac Method, IBR approved for § 63.606(c)(3)(ii), § 63.626(c)(3)(ii), and § 63.626(d)(3)(v). (7) Section XI, Methods of Analysis for Phosphoric Acid, Superphosphate, Triple Superphosphate, and Ammonium Phosphates, No. 3 Total Phosphorus-P205, Method C -- Spectrophotometric Method, IBR approved for § 63.606(c)(3)(ii), § 63.626(c)(3)(ii), and § 63.626(d)(3)(v). (i) The following materials are available for purchase from at least one of the following addresses: ASME International, Orders/Inquiries, P.O. Box 2900, Fairfield, NJ 07007-2900; or Global Engineering Documents, Sales Department, 15 Inverness Way East, Englewood, CO 80112. (1) ASME standard number QHO-1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii). (2) ASME standard number QHO- 1a- 1996 Addenda to QHO- 1-1994, "Standard for the Qualification and Certification of Hazardous Waste Incinerator Operators," IBR approved for Sec. 63.1206(c)(6)(iii). (3) ANSI/ASME PTC 19.10-1981, "Flue and Exhaust Gas Analyses [Part 10, Instruments and Apparatus]," IBR approved for Sec. Sec. 63.865(b), 63.3166(a)(3), 63.3360(e)(1)(iii), 63.3545(a)(3), 63.3555(a)(3), 63.4166(a)(3), 63.4362(a)(3), 63.4766(a)(3), 63.4965(a)(3), 63.5160(d)(1)(iii), 63.9307(c)(2), and 63.9323(a)(3). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-44 of 45

APPENDIX NESHAP SUBPART A General Provisions (j) The following material is available for purchase from: British Standards Institute, 389 Chiswick High Road, London W4 4AL, United Kingdom. (1) BS EN 1593:1999, Non-destructive Testing: Leak Testing--Bubble Emission Techniques, IBR approved for Sec. 63.425(i)(2). (2) [Reserved] (k) The following material may be obtained from U.S. EPA, Office of Solid Waste (5305W), 1200 Pennsylvania Avenue, NW., Washington, DC 20460: (1) Method 9071B, "n-Hexane Extractable Material(HEM) for Sludge, Sediment, and Solid Samples," (Revision 2, April 1998) as published in EPA Publication SW-846: "Test Methods for Evaluating Solid Waste, Physical/Chemical Methods." The incorporation by reference of Method 9071B is approved for Section 63.7824(e) of Subpart FFFFF of this part. § 63.15 Availability of information and confidentiality. (a) Availability of information. (1) With the exception of information protected through part 2 of this chapter, all reports, records, and other information collected by the Administrator under this part are available to the public. In addition, a copy of each permit application, compliance plan (including the schedule of compliance), notification of compliance status, excess emissions and continuous monitoring systems performance report, and title V permit is available to the public, consistent with protections recognized in section 503(e) of the Act. (2) The availability to the public of information provided to or otherwise obtained by the Administrator under this part shall be governed by part 2 of this chapter. (b) Confidentiality. (1) If an owner or operator is required to submit information entitled to protection from disclosure under section 114(c) of the Act, the owner or operator may submit such information separately. The requirements of section 114(c) shall apply to such information. (2) The contents of a title V permit shall not be entitled to protection under section 114(c) of the Act; however, information submitted as part of an application for a title V permit may be entitled to protection from disclosure. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPA-45 of 45

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Subpart ZZZZ-National Emissions Standardsfor HazardousAir Pollutantsfor Stationary ReciprocatingInternal Combustion Engines Source: 69 FR 33506, June 15, 2004, unless otherwise noted. What This Subpart Covers § 63.6580 What is the purpose of subpartZZZZ? Subpart ZZZZ establishes national emission limitations and operating limitations for hazardous air pollutants (HAP) emitted from stationary reciprocating internal combustion engines (RICE) located at major and area sources of HAP emissions. This subpart also establishes requirements to demonstrate initial and continuous compliance with the emission limitations and operating limitations. [73 FR 3603, Jan. 18, 2008] § 63.6585 Am I subject to this subpart? You are subject to this subpart if you own or operate a stationary RICE at a major or area source of HAP emissions, except if the stationary RICE is being tested at a stationary RICE test cell/stand. (a) A stationary RICE is any internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition. (b) A major source of HAP emissions is a plant site that emits or has the potential to emit any single HAP at a rate of 10 tons (9.07 megagrams) or more per year or any combination of HAP at a rate of 25 tons (22.68 megagrams) or more per year, except that for oil and gas production facilities, a major source of HAP emissions is determined for each surface site. (c) An area source of HAP emissions is a source that is not a major source. (d) If you are an owner or operator of an area source subject to this subpart, your status as an entity subject to a standard or other requirements under this subpart does not subject you to the obligation to obtain a permit under 40 CFR part 70 or 71, provided you are not required to obtain a permit under 40 CFR 70.3(a) or 40 CFR 71.3(a) for a reason other than your status as an area source under this subpart. Notwithstanding the previous sentence, you must continue to comply with the provisions of this subpart as applicable. (e) If you are an owner or operator of a stationary RICE used for national security purposes, you may be eligible to request an exemption from the requirements of this subpart as described in 40 CFR part 1068, subpart C. [69 FR 33506, June 15, 2004, as amended at 73 FR 3603, Jan. 18, 2008] § 63.6590 What parts of my plant does this subpartcover? This subpart applies to each affected source. (a) Affected source. An affected source is any existing, new, or reconstructed stationary RICE located at a major or area source of HAP emissions, excluding stationary RICE being tested at a stationary RICE test cell/stand. (1) Existing stationaryRICE. (i) For stationary RICE with a site rating of more than 500 brake horsepower (HP) located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before December 19, 2002. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-1 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (ii) For stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006. (iii) For stationary RICE located at an area source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006. (iv) A change in ownership of an existing stationary RICE does not make that stationary RICE a new or reconstructed stationary RICE. (2) New stationaryRICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after December 19, 2002. (ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006. (iii) A stationary RICE located at an area source of HAP emissions is new if you commenced construction of the stationary RICE on or after June 12, 2006. (3) Reconstructed stationaryRICE. (i) A stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in §63.2 and reconstruction is commenced on or after December 19, 2002. (ii) A stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions is reconstructed if you meet the definition of reconstruction in §63.2 and reconstruction is commenced on or after June 12, 2006. (iii) A stationary RICE located at an area source of HAP emissions is reconstructed if you meet the definition of reconstruction in §63.2 and reconstruction is commenced on or after June 12, 2006. (b) Stationary RICE subject to limited requirements. (1) An affected source which meets either of the criteria in paragraph (b)(1)(i) through (ii) of this section does not have to meet the requirements of this subpart and of subpart A of this part except for the initial notification requirements of §63.6645(h). (i) The stationary RICE is a new or reconstructed emergency stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions; or (ii) The stationary RICE is a new or reconstructed limited use stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions. (2) A new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis must meet the initial notification requirements of §63.6645(h) and the requirements of §§63.6625(c), 63.6650(g), and 63.6655(c). These stationary RICE do not have to meet the emission limitations and operating limitations of this subpart. (3) A stationary RICE which is an existing spark ignition 4 stroke rich burn (4SRB) stationary RICE located at an area source, an existing spark ignition 4SRB stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source, an existing spark ignition 2 stroke lean burn (2SLB) stationary RICE, an existing spark ignition 4 stroke lean burn (4SLB) stationary RICE, an existing compression ignition (CI) stationary RICE, an existing emergency stationary RICE, an existing limited use stationary RICE, or an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, does not have to meet the requirements of this subpart and of subpart A of this part. No initial notification is necessary. (c) Stationary RICE subject to Regulations under 40 CFR Part 60. An affected source that is a new or reconstructed stationary RICE located at an area source, or is a new or reconstructed stationary RICE located at a major source of HAP emissions and is a spark ignition 2 stroke lean burn (2SLB) stationary RICE with a site rating of less than 500 brake HP, a spark ignition 4 stroke lean burn (4SLB) stationary RICE with a site rating of less than 250 brake HP, or a 4 stroke rich burn (4SRB) stationary RICE with a site rating of less than or equal to 500 brake HP, a stationary RICE with a site rating of less than or equal to 500 brake HP which combusts landfill or digester gas equivalent to 10 percent or more of the gross heat input Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-2 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines on an annual basis, an emergency or limited use stationary RICE with a site rating of less than or equal to 500 brake HP, or a compression ignition (CI) stationary RICE with a site rating of less than or equal to 500 brake HP, must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines. No further requirements apply for such engines under this part. [69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008] § 63.6595 When do I have to comply with this subpart? (a) Affected Sources. (1) If you have an existing stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the applicable emission limitations and operating limitations no later than June 15, 2007. (2) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart no later than August 16, 2004. (3) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions after August 16, 2004, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source. (4) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008. (5) If you start up your new or reconstructed stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source. (6) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions before January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart no later than January 18, 2008. (7) If you start up your new or reconstructed stationary RICE located at an area source of HAP emissions after January 18, 2008, you must comply with the applicable emission limitations and operating limitations in this subpart upon startup of your affected source. (b) Area sources that become major sources. If you have an area source that increases its emissions or its potential to emit such that it becomes a major source of HAP, the compliance dates in paragraphs (b)(1) and (2) of this section apply to you. (1) Any stationary RICE for which construction or reconstruction is commenced after the date when your area source becomes a major source of HAP must be in compliance with this subpart upon startup of your affected source. (2) Any stationary RICE for which construction or reconstruction is commenced before your area source becomes a major source of HAP must be in compliance with the provisions of this subpart that are applicable to RICE located at major sources within 3 years after your area source becomes a major source of HAP. (c) If you own or operate an affected source, you must meet the applicable notification requirements in §63.6645 and in 40 CFR part 63, subpart A. [69 FR 33506, June 15, 2004, as amended at 73 FR 3604, Jan. 18, 2008] Emission and OperatingLimitations § 63.6600 What emission limitations and operating limitations must I meet if I own or operate a stationaryRICE with a site rating of more than 500 brake HP located at a major source of HAP emissions? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-3 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you own or operate an existing, new, or reconstructed spark ignition 4SRB stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table la to this subpart and the operating limitations in Table lb to this subpart which apply to you. (b) If you own or operate a new or reconstructed 2SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, a new or reconstructed 4SLB stationary RICE with a site rating of more than 500 brake HP located at major source of HAP emissions, or a new or reconstructed CI stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you. (c) If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the emission limitations in Tables la and 2a to this subpart or operating limitations in Tables lb and 2b to this subpart: an existing 2SLB stationary RICE, an existing 4SLB stationary RICE, or an existing Cl stationary RICE; a stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis; an emergency stationary RICE; or a limited use stationary RICE. [73 FR 3605, Jan. 18, 2008] § 63.6601 What emission limitations must I meet if I own or operate a 4SLB stationaryRICE with a site ratingof greater than or equal to 250 brake HPand less than 500 brake HP located at a major source of HAP emissions? If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at major source of HAP emissions manufactured on or after January 1, 2008, you must comply with the emission limitations in Table 2a to this subpart and the operating limitations in Table 2b to this subpart which apply to you. [73 FR 3605, Jan. 18, 2008] General ComplianceRequirements § 63.6605 What are my general requirementsfor complying with this subpart? (a) You must be in compliance with the emission limitations and operating limitations in this subpart that apply to you at all times, except during periods of startup, shutdown, and malfunction. (b) If you must comply with emission limitations and operating limitations, you must operate and maintain your stationary RICE, including air pollution control and monitoring equipment, in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during startup, shutdown, and malfunction. Testing and Initial Compliance Requirements § 63.6610 By what date must I conduct the initialperformancetests or other initialcompliance demonstrations ifI own or operate a stationaryRICE with a site rating of more than 500 brake HP located at a major source of HAP emissions? If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions you are subject to the requirements of this section. (a) You must conduct the initial performance test or other initial compliance demonstrations in Table 4 to this subpart that apply to you within 180 days after the compliance date that is specified for your stationary RICE in §63.6595 and according to the provisions in §63.7(a)(2). (b) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you must demonstrate initial compliance with either the proposed emission limitations or the promulgated emission limitations no later than February 10, 2005 or no later than 180 days after startup of the source, whichever is later, according to §63.7(a)(2)(ix). Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-4 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004 and own or operate stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, and you chose to comply with the proposed emission limitations when demonstrating initial compliance, you must conduct a second performance test to demonstrate compliance with the promulgated emission limitations by December 13, 2007 or after startup of the source, whichever is later, according to §63.7(a)(2)(ix). (d) An owner or operator is not required to conduct an initial performance test on units for which a performance test has been previously conducted, but the test must meet all of the conditions described in paragraphs (d)(1) through (5) of this section. (1) The test must have been conducted using the same methods specified in this subpart, and these methods must have been followed correctly. (2) The test must not be older than 2 years. (3) The test must be reviewed and accepted by the Administrator. (4) Either no process or equipment changes must have been made since the test was performed, or the owner or operator must be able to demonstrate that the results of the performance test, with or without adjustments, reliably demonstrate compliance despite process or equipment changes. (5) The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load. [69 FR 33506, June 15, 2004, as amended at 73 FR 3605, Jan. 18, 2008] § 63.6611 By what date must I conduct the initialperformance tests or other initialcompliance demonstrationsif I own or operate a 4SLB SI stationaryRICE with a site rating of greaterthan or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions? If you own or operate a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must conduct an initial performance test within 240 days after the compliance date that is specified for your stationary RICE in §63.6595 and according to the provisions specified in Table 4 to this subpart, as appropriate. [73 FR 3605, Jan. 18, 2008] § 63.6615 When must I conduct subsequentperformance tests? If you must comply with the emission limitations and operating limitations, you must conduct subsequent performance tests as specified in Table 3 of this subpart. § 63.6620 What performance tests and otherprocedures must I use? (a) You must conduct each performance test in Tables 3 and 4 of this subpart that applies to you. (b) Each performance test must be conducted according to the requirements in §63.7(e)(1) and under the specific conditions that this subpart specifies in Table 4. The test must be conducted at any load condition within plus or minus 10 percent of 100 percent load. (c) You may not conduct performance tests during periods of startup, shutdown, or malfunction, as specified in §63.7(e)(1). (d) You must conduct three separate test runs for each performance test required in this section, as specified in §63.7(e)(3). Each test run must last at least 1 hour. (e)(1) You must use Equation 1 of this section to determine compliance with the percent reduction requirement: Ci -C x100=R (Eq. 1) Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-5 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Where: C,= concentration of CO or formaldehyde at the control device inlet, C,,= concentration of CO or formaldehyde at the control device outlet, and R = percent reduction of CO or formaldehyde emissions. (2) You must normalize the carbon monoxide (CO) or formaldehyde concentrations at the inlet and outlet of the control device to a dry basis and to 15 percent oxygen, or an equivalent percent carbon dioxide (C0 2 ). If pollutant concentrations are to be corrected to 15 percent oxygen and CO 2concentration is measured in lieu of oxygen concentration measurement, a CO 2correction factor is needed. Calculate the CO 2 correction factor as described in paragraphs (e)(2)(i) through (iii) of this section. (i) Calculate the fuel-specific F. value for the fuel burned during the test using values obtained from Method 19, section 5.2, and the following equation: 

     - 0.209 Fd
     =                  (Eq 2)

Where: Fo = Fuel factor based on the ratio of oxygen volume to the ultimate CO 2 volume produced by the fuel at zero percent excess air. 0.209 = Fraction of air that is oxygen, percent/100. Fd = Ratio of the volume of dry effluent gas to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu). F, = Ratio of the volume of CO 2 produced to the gross calorific value of the fuel from Method 19, dsm 3 /J (dscf/10 6 Btu). (ii) Calculate the CO 2 correction factor for correcting measurement data to 15 percent oxygen, as follows: 

        -.         (Eq. 3)

Where: X,, 2= CO 2 correction factor, percent. 5.9 = 20.9 percent 02-15 percent 02, the defined O 2correction value, percent. (iii) Calculate the NOx and SO 2 gas concentrations adjusted to 15 percent O 2 using CO 2as follows: C4 = C, % x (Eq. 4) 

            %C0 2 Where:

%C0 2= Measured CO 2 concentration measured, dry basis, percent. (f) If you comply with the emission limitation to reduce CO and you are not using an oxidation catalyst, if you comply with the emission limitation to reduce formaldehyde and you are not using NSCR, or if you comply with the emission limitation to limit the concentration of formaldehyde in the stationary RICE exhaust and you are not using an oxidation catalyst or NSCR, you must petition the Administrator for operating limitations to be established during the initial performance test and Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-6 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines continuously monitored thereafter; or for approval of no operating limitations. You must not conduct the initial performance test until after the petition has been approved by the Administrator. (g) If you petition the Administrator for approval of operating limitations, your petition must include the information described in paragraphs (g)(1) through (5) of this section. (1) Identification of the specific parameters you propose to use as operating limitations; (2) A discussion of the relationship between these parameters and HAP emissions, identifying how HAP emissions change with changes in these parameters, and how limitations on these parameters will serve to limit HAP emissions; (3) A discussion of how you will establish the upper and/or lower values for these parameters which will establish the limits on these parameters in the operating limitations; (4) A discussion identifying the methods you will use to measure and the instruments you will use to monitor these parameters, as well as the relative accuracy and precision of these methods and instruments; and (5) A discussion identifying the frequency and methods for recalibrating the instruments you will use for monitoring these parameters. (h) If you petition the Administrator for approval of no operating limitations, your petition must include the information described in paragraphs (h)(1) through (7) of this section. (1) Identification of the parameters associated with operation of the stationary RICE and any emission control device which could change intentionally ( e.g., operator adjustment, automatic controller adjustment, etc.) or unintentionally ( e.g., wear and tear, error, etc.) on a routine basis or over time; (2) A discussion of the relationship, if any, between changes in the parameters and changes in HAP emissions; (3) For the parameters which could change in such a way as to increase HAP emissions, a discussion of whether establishing limitations on the parameters would serve to limit HAP emissions; (4) For the parameters which could change in such a way as to increase HAP emissions, a discussion of how you could establish upper and/or lower values for the parameters which would establish limits on the parameters in operating limitations; (5) For the parameters, a discussion identifying the methods you could use to measure them and the instruments you could use to monitor them, as well as the relative accuracy and precision of the methods and instruments; (6) For the parameters, a discussion identifying the frequency and methods for recalibrating the instruments you could use to monitor them; and (7) A discussion of why, from your point of view, it is infeasible or unreasonable to adopt the parameters as operating limitations. (i) The engine percent load during a performance test must be determined by documenting the calculations, assumptions, and measurement devices used to measure or estimate the percent load in a specific application. A written report of the average percent load determination must be included in the notification of compliance status. The following information must be included in the written report: the engine model number, the engine manufacturer, the year of purchase, the manufacturer's site-rated brake horsepower, the ambient temperature, pressure, and humidity during the performance test, and all assumptions that were made to estimate or calculate percent load during the performance test must be clearly explained. If measurement devices such as flow meters, kilowatt meters, beta analyzers, stain gauges, etc. are used, the model number of the measurement device, and an estimate of its accurate in percentage of true value must be provided. § 63.6625 What are my monitoring, installation,operation, and maintenance requirements? Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-7 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (a) If you elect to install a CEMS as specified in Table 5 of this subpart, you must install, operate, and maintain a CEMS to monitor CO and either oxygen or CO 2at both the inlet and the outlet of the control device according to the requirements in paragraphs (a)(1) through (4) of this section. (1) Each CEMS must be installed, operated, and maintained according to the applicable performance specifications of 40 CFR part 60, appendix B. (2) You must conduct an initial performance evaluation and an annual relative accuracy test audit (RATA) of each CEMS according to the requirements in §63.8 and according to the applicable performance specifications of 40 CFR part 60, appendix B as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1. (3) As specified in §63.8(c)(4)(ii), each CEMS must complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute period. You must have at least two data points, with each representing a different 15-minute period, to have a valid hour of data. (4) The CEMS data must be reduced as specified in §63.8(g)(2) and recorded in parts per million or parts per billion (as appropriate for the applicable limitation) at 15 percent oxygen or the equivalent CO 2 concentration. (b) If you are required to install a continuous parameter monitoring system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and maintain each CPMS according to the requirements in §63.8. (c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must monitor and record your fuel usage daily with separate fuel meters to measure the volumetric flow rate of each fuel. In addition, you must operate your stationary RICE in a manner which reasonably minimizes HAP emissions. (d) If you are operating a new or reconstructed emergency 4SLB stationary RICE with a site rating of greater than or equal to 250 and less than or equal to 500 brake HP located at a major source of HAP emissions, you must install a non-resettable hour meter prior to the startup of the engine. [69 FR 33506, June 15, 2004, as amended at 73 FR 3606, Jan. 18, 2008] § 63.6630 How do I demonstrateinitialcompliance with the emission limitationsand operatinglimitations? (a) You must demonstrate initial compliance with each emission and operating limitation that applies to you according to Table 5 of this subpart. (b) During the initial performance test, you must establish each operating limitation in Tables lb and 2b of this subpart that applies to you. (c) You must submit the Notification of Compliance Status containing the results of the initial compliance demonstration according to the requirements in §63.6645. Continuous Compliance Requirements § 63.6635 How do I monitor and collect data to demonstrate continuous compliance? (a) If you must comply with emission and operating limitations, you must monitor and collect data according to this section. (b) Except for monitor malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), you must monitor continuously at all times that the stationary RICE is operating. (c) You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must, however, use all the valid data collected during all other periods. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-8 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines § 63.6640 How do I demonstrate continuous compliance with the emission limitations and operatinglimitations? (a) You must demonstrate continuous compliance with each emission limitation and operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you according to methods specified in Table 6 of this subpart. (b) You must report each instance in which you did not meet each emission limitation or operating limitation in Tables la and lb and Tables 2a and 2b of this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650. If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE. (c) [Reserved] (d) Consistent with §§63.6(e) and 63.7(e)(1), deviations from the emission or operating limitations that occur during a period of startup, shutdown, or malfunction are not violations if you demonstrate to the Administrator's satisfaction that you were operating in accordance with §63.6(e)(1). For new, reconstructed, and rebuilt stationary RICE, deviations from the emission or operating limitations that occur during the first 200 hours of operation from engine startup (engine bum-in period) are not violations. Rebuilt stationary RICE means a stationary RICE that has been rebuilt as that term is defined in 40 CFR §94.1 l(a). (e) You must also report each instance in which you did not meet the requirements in Table 8 to this subpart that apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart: An existing 2SLB stationary RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing emergency stationary RICE, an existing limited use emergency stationary RICE, or an existing stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in Table 8 to this subpart, except for the initial notification requirements: a new or reconstructed stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new or reconstructed emergency stationary RICE, or a new or reconstructed limited use stationary RICE. [69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3606, Jan. 18, 2008] Notifications, Reports, and Records § 63.6645 What notifications must I submit and when? (a) If you own or operate a stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions or a new or reconstructed 4SLB stationary RICE with a site rating of greater than or equal to 250 HP located at a major source of HAP emissions, you must submit all of the notifications in §§63.7(b) and (c), 63.8(e), (0(4) and (f)(6), 63.9(b) through (e), and (g) and (h) that apply to you by the dates specified. (b) As specified in §63.9(b)(2), if you start up your stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart, you must submit an Initial Notification not later than December 13, 2004. (c) If you start up your new or reconstructed stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions on or after August 16, 2004, you must submit an Initial Notification not later than 120 days after you become subject to this subpart. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-9 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (d) As specified in §63.9(b)(2), if you start up your stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions before the effective date of this subpart and you are required to submit an initial notification, you must submit an Initial Notification not later than July 16, 2008. (e) If you start up your new or reconstructed stationary RICE with a site rating of equal to or less than 500 brake HP located at a major source of HAP emissions on or after March 18, 2008 and you are required to submit an initial notification, you must submit an Initial Notification not later than 120 days after you become subject to this subpart. (f) If you are required to submit an Initial Notification but are otherwise not affected by the requirements of this subpart, in accordance with §63.6590(b), your notification should include the information in §63.9(b)(2)(i) through (v), and a statement that your stationary RICE has no additional requirements and explain the basis of the exclusion (for example, that it operates exclusively as an emergency stationary RICE if it has a site rating of more than 500 brake HP located at a major source of HAP emissions). (g) If you are required to conduct a performance test, you must submit a Notification of Intent to conduct a performance test at least 60 days before the performance test is scheduled to begin as required in §63.7(b)(1). (h) If you are required to conduct a performance test or other initial compliance demonstration as specified in Tables 4 and 5 to this subpart, you must submit a Notification of Compliance Status according to §63.9(h)(2)(ii). (1) For each initial compliance demonstration required in Table 5 to this subpart that does not include a performance test, you must submit the Notification of Compliance Status before the close of business on the 30th day following the completion of the initial compliance demonstration. (2) For each initial compliance demonstration required in Table 5 to this subpart that includes a performance test conducted according to the requirements in Table 3 to this subpart, you must submit the Notification of Compliance Status, including the performance test results, before the close of business on the 60th day following the completion of the performance test according to §63.10(d)(2). [73 FR 3606, Jan. 18, 2008] § 63.6650 What reports must I submit and when? (a) You must submit each report in Table 7 of this subpart that applies to you. (b) Unless the Administrator has approved a different schedule for submission of reports under §63.10(a), you must submit each report by the date in Table 7 of this subpart and according to the requirements in paragraphs (b)(1) through (5) of this section. (1) The first Compliance report must cover the period beginning on the compliance date that is specified for your affected source in §63.6595 and ending on June 30 or December 31, whichever date is the first date following the end of the first calendar half after the compliance date that is specified for your source in §63.6595. (2) The first Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date follows the end of the first calendar half after the compliance date that is specified for your affected source in §63.6595. (3) Each subsequent Compliance report must cover the semiannual reporting period from January 1 through June 30 or the semiannual reporting period from July 1 through December 31. (4) Each subsequent Compliance report must be postmarked or delivered no later than July 31 or January 31, whichever date is the first date following the end of the semiannual reporting period. (5) For each stationary RICE that is subject to permitting regulations pursuant to 40 CFR part 70 or 71, and if the permitting authority has established dates for submitting semiannual reports pursuant to 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6 (a)(3)(iii)(A), you may submit the first and subsequent Compliance reports according to the dates the permitting authority has established instead of according to the dates in paragraphs (b)(1) through (4) of this section. (c) The Compliance report must contain the information in paragraphs (c)(1) through (6) of this section. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-10 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (1) Company name and address. (2) Statement by a responsible official, with that official's name, title, and signature, certifying the accuracy of the content of the report. (3) Date of report and beginning and ending dates of the reporting period. (4) If you had a startup, shutdown, or malfunction during the reporting period, the compliance report must include the information in §63.10(d)(5)(i). (5) If there are no deviations from any emission or operating limitations that apply to you, a statement that there were no deviations from the emission or operating limitations during the reporting period. (6) If there were no periods during which the continuous monitoring system (CMS), including CEMS and CPMS, was out-of-control, as specified in §63.8(c)(7), a statement that there were no periods during which the CMS was out-of-control during the reporting period. (d) For each deviation from an emission or operating limitation that occurs for a stationary RICE where you are not using a CMS to comply with the emission or operating limitations in this subpart, the Compliance report must contain the information in paragraphs (c)(1) through (4) of this section and the information in paragraphs (d)(1) and (2) of this section. (1) The total operating time of the stationary RICE at which the deviation occurred during the reporting period. (2) Information on the number, duration, and cause of deviations (including unknown cause, if applicable), as applicable, and the corrective action taken. (e) For each deviation from an emission or operating limitation occurring for a stationary RICE where you are using a CMS to comply with the emission and operating limitations in this subpart, you must include information in paragraphs (c)(1) through (4) and (e)(1) through (12) of this section. (1) The date and time that each malfunction started and stopped. (2) The date, time, and duration that each CMS was inoperative, except for zero (low-level) and high-level checks. (3) The date, time, and duration that each CMS was out-of-control, including the information in §63.8(c)(8). (4) The date and time that each deviation started and stopped, and whether each deviation occurred during a period of malfunction or during another period. (5) A summary of the total duration of the deviation during the reporting period, and the total duration as a percent of the total source operating time during that reporting period. (6) A breakdown of the total duration of the deviations during the reporting period into those that are due to control equipment problems, process problems, other known causes, and other unknown causes. (7) A summary of the total duration of CMS downtime during the reporting period, and the total duration of CMS downtime as a percent of the total operating time of the stationary RICE at which the CMS downtime occurred during that reporting period. (8) An identification of each parameter and pollutant (CO or formaldehyde) that was monitored at the stationary RICE. (9) A brief description of the stationary RICE. (10) A brief description of the CMS. (11) The date of the latest CMS certification or audit. (12) A description of any changes in CMS, processes, or controls since the last reporting period. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-11 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (f) Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a Compliance report pursuant to Table 7 of this subpart along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance report includes all required information concerning deviations from any emission or operating limitation in this subpart, submission of the Compliance report shall be deemed to satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority. (g) If you are operating as a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must submit an annual report according to Table 7 of this subpart by the date specified unless the Administrator has approved a different schedule, according to the information described in paragraphs (b)(1) through (b)(5) of this section. You must report the data specified in (g)(1) through (g)(3) of this section. (1) Fuel flow rate of each fuel and the heating values that were used in your calculations. You must also demonstrate that the percentage of heat input provided by landfill gas or digester gas is equivalent to 10 percent or more of the total fuel consumption on an annual basis. (2) The operating limits provided in your federally enforceable permit, and any deviations from these limits. (3) Any problems or errors suspected with the meters. § 63.6655 What records must I keep? (a) If you must comply with the emission and operating limitations, you must keep the records described in paragraphs (a)(1) through (a)(3), (b)(1) through (b)(3) and (c) of this section. (1) A copy of each notification and report that you submitted to comply with this subpart, including all documentation supporting any Initial Notification or Notification of Compliance Status that you submitted, according to the requirement in §63.10(b)(2)(xiv). (2) The records in §63.6(e)(3)(iii) through (v) related to startup, shutdown, and malfunction. (3) Records of performance tests and performance evaluations as required in §63.10(b)(2)(viii). (b) For each CEMS or CPMS, you must keep the records listed in paragraphs (b)(1) through (3) of this section. (1) Records described in §63.10(b)(2)(vi) through (xi). (2) Previous ( i.e., superseded) versions of the performance evaluation plan as required in §63.8(d)(3). (3) Requests for alternatives to the relative accuracy test for CEMS or CPMS as required in §63.8(f)(6)(i), if applicable. (c) If you are operating a new or reconstructed stationary RICE which fires landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, you must keep the records of your daily fuel usage monitors. (d) You must keep the records required in Table 6 of this subpart to show continuous compliance with each emission or operating limitation that applies to you. § 63.6660 In what form and how long must I keep my records? (a) Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1). (b) As specified in §63.10(b)(1), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-12 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (c) You must keep each record readily accessible in hard copy or electronic form on-site for at least 2 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1). You can keep the records off-site for the remaining 3 years. Other Requirements and Information § 63.6665 What parts of the General Provisionsapply to me? Table 8 to this subpart shows which parts of the General Provisions in §§63.1 through 63.15 apply to you. If you own or operate any stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions (except new or reconstructed 4SLB engines greater than or equal to 250 and less than or equal to 500 brake HP), a stationary RICE located at an area source of HAP emissions, or any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with any of the requirements of the General Provisions: An existing 2SLB RICE, an existing 4SLB stationary RICE, an existing CI stationary RICE, an existing stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, an existing emergency stationary RICE, or an existing limited use stationary RICE. If you own or operate any of the following RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, you do not need to comply with the requirements in the General Provisions except for the initial notification requirements: A new stationary RICE that combusts landfill gas or digester gas equivalent to 10 percent or more of the gross heat input on an annual basis, a new emergency stationary RICE, or a new limited use stationary RICE. [73 FR 3606, Jan. 18, 2008] § 63.6670 Who implements and enforces this subpart? (a) This subpart is implemented and enforced by the U.S. EPA, or a delegated authority such as your State, local, or tribal agency. If the U.S. EPA Administrator has delegated authority to your State, local, or tribal agency, then that agency (as well as the U.S. EPA) has the authority to implement and enforce this subpart. You should contact your U.S. EPA Regional Office to find out whether this subpart is delegated to your State, local, or tribal agency. (b) In delegating implementation and enforcement authority of this subpart to a State, local, or tribal agency under 40 CFR part 63, subpart E, the authorities contained in paragraph (c) of this section are retained by the Administrator of the U.S. EPA and are not transferred to the State, local, or tribal agency. (c) The authorities that will not be delegated to State, local, or tribal agencies are: (1) Approval of alternatives to the non-opacity emission limitations and operating limitations in §63.6600 under §63.6(g). (2) Approval of major alternatives to test methods under §63.7(e)(2)(ii) and (f) and as defined in §63.90. (3) Approval of major alternatives to monitoring under §63.8(f) and as defined in §63.90. (4) Approval of major alternatives to recordkeeping and reporting under §63.10(f) and as defined in §63.90. (5) Approval of a performance test which was conducted prior to the effective date of the rule, as specified in §63.6610(b). § 63.6675 What definitions apply to this subpart? Terms used in this subpart are defined in the Clean Air Act (CAA); in 40 CFR 63.2, the General Provisions of this part; and in this section as follows: Area source means any stationary source of HAP that is not a major source as defined in part 63. Associated equipment as used in this subpart and as referred to in section 112(n)(4) of the CAA, means equipment associated with an oil or natural gas exploration or production well, and includes all equipment from the well bore to the point of custody transfer, except glycol dehydration units, storage vessels with potential for flash emissions, combustion turbines, and stationary RICE. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-13 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines CAA means the Clean Air Act (42 U.S.C. 7401 et seq., as amended by Public Law 101-549, 104 Stat. 2399). Compression ignition means relating to a type of stationary internal combustion engine that is not a spark ignition engine. Custody transfer means the transfer of hydrocarbon liquids or natural gas: After processing and/or treatment in the producing operations, or from storage vessels or automatic transfer facilities or other such equipment, including product loading racks, to pipelines or any other forms of transportation. For the purposes of this subpart, the point at which such liquids or natural gas enters a natural gas processing plant is a point of custody transfer. Deviation means any instance in which an affected source subject to this subpart, or an owner or operator of such a source: (1) Fails to meet any requirement or obligation established by this subpart, including but not limited to any emission limitation or operating limitation; (2) Fails to meet any term or condition that is adopted to implement an applicable requirement in this subpart and that is included in the operating permit for any affected source required to obtain such a permit; or (3) Fails to meet any emission limitation or operating limitation in this subpart during malfunction, regardless or whether or not such failure is permitted by this subpart. (4) Fails to satisfy the general duty to minimize emissions established by §63.6(e)(1)(i). Diesel engine means any stationary RICE in which a high boiling point liquid fuel injected into the combustion chamber ignites when the air charge has been compressed to a temperature sufficiently high for auto-ignition. This process is also known as compression ignition. Dieselfuel means any liquid obtained from the distillation of petroleum with a boiling point of approximately 150 to 360 degrees Celsius. One commonly used form is fuel oil number 2. Digestergas means any gaseous by-product of wastewater treatment typically formed through the anaerobic decomposition of organic waste materials and composed principally of methane and CO 2. Dual-fuel engine means any stationary RICE in which a liquid fuel (typically diesel fuel) is used for compression ignition and gaseous fuel (typically natural gas) is used as the primary fuel. Emergency stationaryRICE means any stationary RICE whose operation is limited to emergency situations and required testing and maintenance. Examples include stationary RICE used to produce power for critical networks or equipment (including power supplied to portions of a facility) when electric power from the local utility (or the normal power source, if the facility runs on its own power production) is interrupted, or stationary RICE used to pump water in the case of fire or flood, etc. Stationary RICE used for peak shaving are not considered emergency stationary RICE. Stationary ICE used to supply power to an electric grid or that supply power as part of a financial arrangement with another entity are not considered to be emergency engines. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may be operated for the purpose of maintenance checks and readiness testing, provided that the tests are recommended by the manufacturer, the vendor, or the insurance company associated with the engine. Required testing of such units should be minimized, but there is no time limit on the use of emergency stationary RICE in emergency situations and for routine testing and maintenance. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed prior to June 12, 2006, may also operate an additional 50 hours per year in non-emergency situations. Emergency stationary RICE with a site-rating of more than 500 brake HP located at a major source of HAP emissions that were installed on or after June 12, 2006, must comply with requirements specified in 40 CFR 60.4243(d). Four-stroke engine means any type of engine which completes the power cycle in two crankshaft revolutions, with intake and compression strokes in the first revolution and power and exhaust strokes in the second revolution. Gaseousfuel means a material used for combustion which is in the gaseous state at standard atmospheric temperature and pressure conditions. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-14 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Gasoline means any fuel sold in any State for use in motor vehicles and motor vehicle engines, or nonroad or stationary engines, and commonly or commercially known or sold as gasoline. Glycol dehydration unit means a device in which a liquid glycol (including, but not limited to, ethylene glycol, diethylene glycol, or triethylene glycol) absorbent directly contacts a natural gas stream and absorbs water in a contact tower or absorption column (absorber). The glycol contacts and absorbs water vapor and other gas stream constituents from the natural gas and becomes "rich" glycol. This glycol is then regenerated in the glycol dehydration unit reboiler. The "lean" glycol is then recycled. Hazardousairpollutants (HAP) means any air pollutants listed in or pursuant to section 112(b) of the CAA. ISO standardday conditions means 288 degrees Kelvin (15 degrees Celsius), 60 percent relative humidity and 101.3 kilopascals pressure. Landfill gas means a gaseous by-product of the land application of municipal refuse typically formed through the anaerobic decomposition of waste materials and composed principally of methane and CO 2. Lean burn engine means any two-stroke or four-stroke spark ignited engine that does not meet the definition of a rich burn engine. Limited use stationaryRICE means any stationary RICE that operates less than 100 hours per year. Liquefied petroleum gas means any liquefied hydrocarbon gas obtained as a by-product in petroleum refining of natural gas production. Liquidfuel means any fuel in liquid form at standard temperature and pressure, including but not limited to diesel, residual/crude oil, kerosene/naphtha (jet fuel), and gasoline. Major Source, as used in this subpart, shall have the same meaning as in §63.2, except that: (1) Emissions from any oil or gas exploration or production well (with its associated equipment (as defined in this section)) and emissions from any pipeline compressor station or pump station shall not be aggregated with emissions from other similar units, to determine whether such emission points or stations are major sources, even when emission points are in a contiguous area or under common control; (2) For oil and gas production facilities, emissions from processes, operations, or equipment that are not part of the same oil and gas production facility, as defined in §63.1271 of subpart HHH of this part, shall not be aggregated; (3) For production field facilities, only HAP emissions from glycol dehydration units, storage vessel with the potential for flash emissions, combustion turbines and reciprocating internal combustion engines shall be aggregated for a major source determination; and (4) Emissions from processes, operations, and equipment that are not part of the same natural gas transmission and storage facility, as defined in §63.1271 of subpart HHH of this part, shall not be aggregated. Malfunction means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner which causes, or has the potential to cause, the emission limitations in an applicable standard to be exceeded. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Natural gas means a naturally occurring mixture of hydrocarbon and non-hydrocarbon gases found in geologic formations beneath the Earth's surface, of which the principal constituent is methane. Natural gas may be field or pipeline quality. Non-selective catalytic reduction (NSCR) means an add-on catalytic nitrogen oxides (NOx) control device for rich burn engines that, in a two-step reaction, promotes the conversion of excess oxygen, NOx, CO, and volatile organic compounds (VOC) into C0 2 , nitrogen, and water. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-15 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Oil and gas productionfacility as used in this subpart means any grouping of equipment where hydrocarbon liquids are processed, upgraded ( i.e., remove impurities or other constituents to meet contract specifications), or stored prior to the point of custody transfer; or where natural gas is processed, upgraded, or stored prior to entering the natural gas transmission and storage source category. For purposes of a major source determination, facility (including a building, structure, or installation) means oil and natural gas production and processing equipment that is located within the boundaries of an individual surface site as defined in this section. Equipment that is part of a facility will typically be located within close proximity to other equipment located at the same facility. Pieces of production equipment or groupings of equipment located on different oil and gas leases, mineral fee tracts, lease tracts, subsurface or surface unit areas, surface fee tracts, surface lease tracts, or separate surface sites, whether or not connected by a road, waterway, power line or pipeline, shall not be considered part of the same facility. Examples of facilities in the oil and natural gas production source category include, but are not limited to, well sites, satellite tank batteries, central tank batteries, a compressor station that transports natural gas to a natural gas processing plant, and natural gas processing plants. Oxidation catalyst means an add-on catalytic control device that controls CO and VOC by oxidation. Peaking unit or engine means any standby engine intended for use during periods of high demand that are not emergencies. Percent load means the fractional power of an engine compared to its maximum manufacturer's design capacity at engine site conditions. Percent load may range between 0 percent to above 100 percent. Potential to emit means the maximum capacity of a stationary source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the stationary source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. For oil and natural gas production facilities subject to subpart HH of this part, the potential to emit provisions in §63.760(a) may be used. For natural gas transmission and storage facilities subject to subpart HHH of this part, the maximum annual facility gas throughput for storage facilities may be determined according to §63.1270(a)(1) and the maximum annual throughput for transmission facilities may be determined according to §63.1270(a)(2). Productionfield facility means those oil and gas production facilities located prior to the point of custody transfer. Productionwell means any hole drilled in the earth from which crude oil, condensate, or field natural gas is extracted. Propanemeans a colorless gas derived from petroleum and natural gas, with the molecular structure C3H 8 . Responsible official means responsible official as defined in 40 CFR 70.2. Rich burn engine means any four-stroke spark ignited engine where the manufacturer's recommended operating air/fuel ratio divided by the stoichiometric air/fuel ratio at full load conditions is less than or equal to 1.1. Engines originally manufactured as rich burn engines, but modified prior to December 19, 2002 with passive emission control technology for NOx(such as pre-combustion chambers) will be considered lean burn engines. Also, existing engines where there are no manufacturer's recommendations regarding air/fuel ratio will be considered a rich burn engine if the excess oxygen content of the exhaust at full load conditions is less than or equal to 2 percent. Site-ratedHP means the maximum manufacturer's design capacity at engine site conditions. Spark ignition means relating to either: A gasoline-fueled engine; or any other type of engine a spark plug (or other sparking device) and with operating characteristics significantly similar to the theoretical Otto combustion cycle. Spark ignition engines usually use a throttle to regulate intake air flow to control power during normal operation. Dual-fuel engines in which a liquid fuel (typically diesel fuel) is used for CI and gaseous fuel (typically natural gas) is used as the primary fuel at an annual average ratio of less than 2 parts diesel fuel to 100 parts total fuel on an energy equivalent basis are spark ignition engines. Stationary reciprocatinginternal combustion engine (RICE) means any reciprocating internal combustion engine which uses reciprocating motion to convert heat energy into mechanical work and which is not mobile. Stationary RICE differ from mobile RICE in that a stationary RICE is not a non-road engine as defined at 40 CFR 1068.30, and is not used to propel a motor vehicle or a vehicle used solely for competition. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-16 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Stationary RICE test cell/stand means an engine test cell/stand, as defined in subpart PPPPP of this part, that tests stationary RICE. Stoichiometric means the theoretical air-to-fuel ratio required for complete combustion. Storage vessel with the potentialfor flash emissions means any storage vessel that contains a hydrocarbon liquid with a stock tank gas-to-oil ratio equal to or greater than 0.31 cubic meters per liter and an American Petroleum Institute gravity equal to or greater than 40 degrees and an actual annual average hydrocarbon liquid throughput equal to or greater than 79,500 liters per day. Flash emissions occur when dissolved hydrocarbons in the fluid evolve from solution when the fluid pressure is reduced. Subpart means 40 CFR part 63, subpart ZZZZ. Surface site means any combination of one or more graded pad sites, gravel pad sites, foundations, platforms, or the immediate physical location upon which equipment is physically affixed. Two-stroke engine means a type of engine which completes the power cycle in single crankshaft revolution by combining the intake and compression operations into one stroke and the power and exhaust operations into a second stroke. This system requires auxiliary scavenging and inherently runs lean of stoichiometric. [69 FR 33506, June 15, 2004, as amended at 71 FR 20467, Apr. 20, 2006; 73 FR 3607, Jan. 18, 2008] Tablelato SubpartZZZZ of Part63-Emission Limitationsfor Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HP Located at a Major Source of HAP Emissions [As stated in §63.6600, you must comply with the following emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions at 100 percent load plus or minus 10 percent] For each... You must meet the following emission limitations...

1. 4SRB a. reduce formaldehyde emissions by 76 percent or more. If you commenced construction or reconstruction stationary RICE between December 19, 2002 and June 15, 2004, you may reduce formaldehyde emissions by 75 percent or more until June 15, 2007; or
b. limit the concentration of formaldehyde in the stationary RICE exhaust 350 ppbvd or less at 15 percent 02.

[73 FR 3607, Jan. 18, 2008] Tablelbto SubpartZZZZ of Part 63-OperatingLimitationsfor Existing, New, and Reconstructed Spark Ignition, 4SRB Stationary RICE >500 HPLocated at a Major Source of HAP Emissions [As stated in §§63.6600, 63.6630 and 63.6640, you must comply with the following operating emission limitations for existing, new and reconstructed 4SRB stationary RICE >500 HP located at a major source of HAP emissions] __For each... F You must meet the following operating limitation...

1. 4SRB stationary RICE complying with the a. maintain your catalyst so that the pressure drop across the catalyst requirement to reduce formaldehyde emissions by 76 does not change by more than 2 inches of water at 100 percent load percent or more (or by 75 percent or more, if plus or minus 10 percent from the pressure drop across the catalyst applicable) and using NSCR; measured during the initial performance test; and Por 4SRB stationary RICE complying with the b. maintain the temperature of your stationary RICE exhaust so that requirement to limit the concentration of the catalyst inlet temperature is greater than or equal to 750 'F and formaldehyde in the stationary RICE exhaust to 350 less than or equal to 1250 'F.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-17 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines ippbvd or less at 15 percent O 2and using NSCR.

2. 4SRB stationary RICE complying with the Comply with any operating limitations approved by the requirement to reduce formaldehyde emissions by 76 Administrator.

percent or more (or by 75 percent or more, if applicable) and not using NSCR; or 4SRB stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust to 350 ppbvd or less at 15 percent O 2and not using NSCR. [73 FR 3607, Jan. 18, 2008] Table2ato Subpart ZZZZ of Part63-Emission Limitationsfor New and Reconstructed2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB StationaryRICE >_250 HP Located at a Major Source of HAP Emissions [As stated in §§63.6600 and 63.6601, you must comply with the following emission limitations for new and reconstructed lean bum and new and reconstructed compression ignition stationary RICE at 100 percent load plus or minus 10 percent] For each... You must meet the following emission limitation...

1. 2SLB a. reduce CO emissions by 58 percent or more; stationary RICE or
b. limit concentration of formaldehyde in the stationary RICE exhaust to 12 ppmvd or less at 15 percent 02. If you commenced construction or reconstruction between December 19, 2002 and June 15, 2004, you may limit concentration of formaldehyde to 17 ppmvd or less at 15 percent O 2 until June 15, 2007.
2. 4SLB a. reduce CO emissions by 93 percent or more; stationary RICE or
b. limit concentration of formaldehyde in the stationary RICE exhaust to 14 ppmvd or less at 15 percent 02.
3. CI a. reduce CO emissions by 70 percent or more; stationary RICE or
b. limit concentration of formaldehyde in the stationary RICE exhaust to 580 ppbvd or less at 15 percent 02.

[73 FR 3608, Jan. 18, 2008] Table2bto Subpart ZZZZ of Part63-OperatingLimitationsfor New and Reconstructed2SLB and Compression Ignition Stationary RICE >500 HP and 4SLB Burn StationaryRICE >_250 HP Located at a Major Source of HAP Emissions [As stated in §§63.6600, 63.6601, 63.6630, and 63.6640, you must comply with the following operating limitations for new and reconstructed lean burn and new and reconstructed compression ignition stationary] I For each... You must meet the following operating limitation... Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-18 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines

1. 2SLB and 4SLB stationary RICE and CI stationary RICE a. maintain your catalyst so that the pressure drop complying with the requirement to reduce CO emissions and using an across the catalyst does not change by more than 2 oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI inches of water at 100 percent load plus or minus 10 stationary RICE complying with the requirement to limit the percent from the pressure drop across the catalyst that concentration of formaldehyde in the stationary RICE exhaust and was measured during the initial performance test; and using an oxidation catalyst b. maintain the temperature of your stationary RICE exhaust so that the catalyst inlet temperature is greater than or equal to 450 OF and less than or equal to 1350 OF.
2. 2SLB and 4SLB stationary RICE and CI stationary RICE Comply with any operating limitations approved by complying with the requirement to reduce CO emissions and not the Administrator.

using an oxidation catalyst; or 2SLB and 4SLB stationary RICE and CI stationary RICE complying with the requirement to limit the concentration of formaldehyde in the stationary RICE exhaust and not using an oxidation catalyst [73 FR 3608, Jan. 18, 2008] Table 3 to SubpartZZZZ of Part63-Subsequent PerformanceTests [As stated in §§63.6615 and 63.6620, you must comply with the following subsequent performance test requirements] For each... Complying with the requirement to... You must...

1. 2SLB and 4SLB stationary RICE and CI Reduce CO emissions and not using a Conduct subsequent performance stationary RICE CEMS tests semiannually.'
2. 4SRB stationary RICE with a brake Reduce formaldehyde emissions Conduct subsequent performance horsepower >5,000 tests semiannually.'
3. Stationary RICE (all stationary RICE Limit the concentration of formaldehyde Conduct subsequent performance subcategories and all brake horsepower ratings) in the stationary RICE exhaust tests semiannually.'

'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests. Table 4 to SubpartZZZZ of Part 63-Requirementsfor PerformanceTests [As stated in §§63.6610, 63.6611, 63.6620, and 63.6640, you must comply with the following requirements for performance tests for stationary RICE] Complying with For each., the requirement According to the following too... You must... Using... requirements...

1. 2SLB, a. Reduce CO i. Measure the O2 at (1) Portable CO and O 2analyzer (a) Using ASTM D6522-00 4SLB, and emissions the inlet and outlet of (2005)a(incorporated by reference, CI the control device; see §63.14). Measurements to stationary and determine 02 must be made at the RICE same time as the measurements for CO concentration.

ii. Measure the CO at (1) Portable CO and O 2analyzer (a) Using ASTM D6522-00 the inlet and the (2005)a(incorporated by reference, Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-19 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines outlet of the control see §63.14) or Method 10 of 40 device CFR, appendix A. The CO concentration must be at 15 percent 02, dry basis.

2. 4SRB a. Reduce i. Select the sampling (1) Method 1 or 1A of 40 CFR (a) Sampling sites must be located stationary formaldehyde port location and the part 60, appendix A at the inlet and outlet of the control RICE emissions number of traverse §63.7(d)(1)(i) device.

points; and ii. Measure 02 at the (1) Method 3 or 3A or 3B of 40 (a) Measurements to determine 02 inlet and outlet of the CFR part 60, appendix A, or concentration must be made at the control device; and ASTM Method D6522-00 same time as the measurements for (2005). formaldehyde concentration. iii. Measure moisture (1) Method 4 of 40 CFR part 60, (a) Measurements to determine content at the inlet appendix A, or Test Method 320 moisture content must be made at and outlet of the of 40 CFR part 63, appendix A, the same time and location as the control device; and or ASTM D 6348-03 measurements for formaldehyde concentration. iv. Measure (1) Method 320 or 323 of 40 (a) Formaldehyde concentration formaldehyde at the CFR part 63, appendix A; or must be at 15 percent 02, dry inlet and the outlet of ASTM D6348-03b, provided in basis. Results of this test consist of the control device ASTM D6348-03 Annex A5 the average of the three 1-hour or (Analyte Spiking Technique), longer runs. the percent R must be greater than or equal to 70 and less than or equal to 130

3. Stationary a. Limit the i. Select the sampling (1) Method 1 or 1A of 40 CFR (a) If using a control device, the RICE concentration of port location and the part 60, appendix A sampling site must be located at formaldehyde in number of traverse §63.7(d)(1)(i) the outlet of the control device.

the stationary points; and RICE exhaust ii. Determine the 02 (1) Method 3 or 3A or 3B of 40 (a) Measurements to determine 02 concentration of the CFR part 60, appendix A, or concentration must be made at the stationary RICE ASTM Method D6522-00 same time and location as the exhaust at the (2005) measurements for formaldehyde sampling port concentration. location; and iii. Measure moisture (1) Method 4 of 40 CFR part 60, (a) Measurements to determine content of the appendix A, or Test Method 320 moisture content must be made at stationary RICE of 40 CFR part 63, appendix A, the same time and location as the exhaust at the or ASTM D 6348-03 measurements for formaldehyde sampling port concentration. location; and iv. Measure (1) Method 320 or 323 of 40 (a) Formaldehyde concentration formaldehyde at the CFR part 63, appendix A; or must be at 15 percent 02, dry exhaust of the ASTM D6348-03b, provided in basis. Results of this test consist of stationary RICE ASTM D6348-03 Annex A5 the average of the three 1-hour or (Analyte Spiking Technique), longer runs. the percent R must be greater than or equal to 70 and less than Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-20 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 

                   .       .      11
                                   .    .Lor                  equal to 130 aYoU may also use Methods 3A and 10 as options to ASTM-D6522-00 (2005). You may obtain a copy of ASTM-D6522-00 (2005) from at least one of the following addresses: American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106.

byou may obtain a copy of ASTM-D6348-03 from at least one of the following addresses: American Society for Testing and Materials, 100 Barr Harbor Drive, West Conshohocken, PA 19428-2959, or University Microfilms International, 300 North Zeeb Road, Ann Arbor, MI 48106. [73 FR 3609, Jan. 18, 2008] Table 5 to Subpart ZZZZ of Part 63-InitialCompliance With Emission Limitations and OperatingLimitations [As stated in §§63.6625 and 63.6630, you must initially comply with the emission and operating limitations as required by the following] Complying with the For each ... requirement to... You have demonstrated initial compliance if...

1. 2SLB and 4SLB a. Reduce CO emissions and i. the average reduction of emissions of CO determined from the stationary RICE using oxidation catalyst, and using initial performance test achieves the required CO percent reduction; and CI stationary a CPMS and RICE ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in §63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.
2. 2SLB and 4SLB a. Reduce CO emissions and not i. The average reduction of emissions of CO determined from the stationary RICE using oxidation catalyst initial performance test achieves the required CO percent reduction; and CI stationary and RICE ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in §63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.
3. 2SLB and 4SLB a. Reduce CO emissions, and i. You have installed a CEMS to continuously monitor CO and either stationary RICE using a CEMS O 2or CO 2 at both the inlet and outlet of the oxidation catalyst and CI stationary according to the requirements in §63.6625(a); and RICE ii. You have conducted a performance evaluation of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B; and iii. The average reduction of CO calculated using §63.6620 equals or exceeds the required percent reduction. The initial test comprises the first 4-hour period after successful validation of the CEMS.

Compliance is based on the average percent reduction achieved during the 4-hour period.

4. 4SRB stationary a. Reduce formaldehyde i. The average reduction of emissions of formaldehyde determined RICE emissions and using NSCR from the initial performance test is equal to or greater than the Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-21 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in §63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.

5. 4SRB stationary a. Reduce formaldehyde i. The average reduction of emissions of formaldehyde determined RICE emissions and not using NSCR from the initial performance test is equal to or greater than the required formaldehyde percent reduction; and ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in §63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.
5. Stationary RICE a. Limit the concentration of i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary 02, dry basis, from the three test runs is less than or equal to the RICE exhaust and using oxidation formaldehyde emission limitation; and catalyst or NSCR ii. You have installed a CPMS to continuously monitor catalyst inlet temperature according to the requirements in §63.6625(b); and iii. You have recorded the catalyst pressure drop and catalyst inlet temperature during the initial performance test.
7. Stationary RICE a. Limit the concentration of i. The average formaldehyde concentration, corrected to 15 percent formaldehyde in the stationary 02, dry basis, from the three test runs is less than or equal to the RICE exhaust and not using formaldehyde emission limitation; and oxidation catalyst or NSCR ii. You have installed a CPMS to continuously monitor operating parameters approved by the Administrator (if any) according to the requirements in §63.6625(b); and iii. You have recorded the approved operating parameters (if any) during the initial performance test.

Table 6 to SubpartZZZZ of Part63-Continuous Compliance With Emission Limitations and OperatingLimitations [As stated in §63.6640, you must continuously comply with the emissions and operating limitations as required by the following] Complying with the requirement to For each ... o.n i . You must demonstrate continuous compliance by...

1. 2SLB and 4SLB a. Reduce CO emissions and using an i. Conducting semiannual performance tests for CO to stationary RICE and oxidation catalyst, and using a CPMS demonstrate that the required CO percent reduction is CI stationary RICE achieved'; and ii. Collecting the catalyst inlet temperature data according to F__ 1§63.6625(b); and

_ _iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-22 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 1operating limitations for the catalyst inlet temperature; and

v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.
2. 2SLB and 4SLB a. Reduce CO emissions and not i. Conducting semiannual performance tests for CO to stationary RICE and using an oxidation catalyst, and using demonstrate that the required CO percent reduction is CI stationary RICE a CPMS achieved 1 ; and ii. Collecting the approved operating parameter (if any) data

__according to §63.6625(b); and __iii. Reducing these data to 4-hour rolling averages; and iv. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.

3. 2SLB and 4SLB a. Reduce CO emissions and using a i. Collecting the monitoring data according to §63.6625(a),

stationary RICE and CEMS reducing the measurements to 1-hour averages, calculating CI stationary RICE the percent reduction of CO emissions according to §63.6620; and ii. Demonstrating that the catalyst achieves the required percent reduction of CO emissions over the 4-hour averaging period; and iii. Conducting an annual RATA of your CEMS using PS 3 and 4A of 40 CFR part 60, appendix B, as well as daily and periodic data quality checks in accordance with 40 CFR part 60, appendix F, procedure 1.

4. 4SRB stationary a. Reduce formaldehyde emissions [.Collecting the catalyst inlet temperature data according to RICE and using NSCR §63.6625(b); and

_ _ii. Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; and iv. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.

5. 4SRB stationary a. Reduce formaldehyde emissions i. Collecting the approved operating parameter (if any) data RICE and not using NSCR according to §63.6625(b); and

[ii. reducing these data to 4-hour rolling averages; iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test.

5. 4SRB stationary Reduce formaldehyde emissions Conducting semiannual performance tests for formaldehyde RICE with a brake to demonstrate that the required formaldehyde percent horsepower >5,000 reduction is achieved'.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-23 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines

7. Stationary RICE Limit the concentration of i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE to demonstrate that your emissions remain at or below the exhaust and using oxidation catalyst formaldehyde concentration limit ' ; and
                                                                  !

or NSCR ii. Collecting the catalyst inlet temperature data according to 

                                                                   §63.6625(b); and

__iii. F_ Reducing these data to 4-hour rolling averages; and ivg.Maintaining the 4-hour rolling averages within the _operating limitations for the catalyst inlet temperature; and

v. Measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test.
8. Stationary RICE Limit the concentration of i. Conducting semiannual performance tests for formaldehyde formaldehyde in the stationary RICE to demonstrate that your emissions remain at or below the exhaust and not using oxidation formaldehyde concentration limit'; and Iaccording catalyst or NSCR ii. Collecting the approved operating parameter (if any) data to §63.6625(b); and

___ii. Reducing these data to 4-hour rolling averages; and iii. Maintaining the 4-hour rolling averages within the operating limitations for the operating parameters established during the performance test. 'After you have demonstrated compliance for two consecutive tests, you may reduce the frequency of subsequent performance tests to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation, or you deviate from any of your operating limitations, you must resume semiannual performance tests. Table 7 to Subpart ZZZZ of Part 63-Requirementsfor Reports [As stated in §63.6650, you must comply with the following requirements for reports] You must submit the report.. You must submit a(n) The report must contain...

1. Compliance report a. If there are no deviations from any emission limitations i. Semiannually according to the or operating limitations that apply to you, a statement that requirements in §63.6650(b).

there were no deviations from the emission limitations or operating limitations during the reporting period. If there were no periods during which the CMS, including CEMS and CPMS, was out-of-control, as specified in 

                                   §63.8(c)(7), a statement that there were not periods during which the CMS was out-of-control during the reporting period; or
b. If you had a deviation from any emission limitation or i. Semiannually according to the operating limitation during the reporting period, the requirements in §63.6650(b).

information in §63.6650(d). If there were periods during which the CMS, including CEMS and CPMS, was out-of-Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-24 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 

                                       -ontrol, as specified in §63.8(c)(7), the information in
                                       §63.6650(e); or
c. If you had a startup, shutdown or malfunction during i. Semiannually according to the the reporting period, the information in §63.10(d)(5)(i) requirements in §63.6650(b).
2. An immediate startup, a. Actions taken for the event; and i. By fax or telephone within 2 shutdown, and malfunction report working days after starting if actions addressing the startup, actions inconsistent with the shutdown, or malfunction were plan.

inconsistent with your startup, shutdown, or malfunction plan during the reporting period

b. The information in §63.10(d)(5)(ii). i. By letter within 7 working days after the end of the event unless you have made alternative arrangements with the permitting authorities.

(§63.10(d)(5)(ii))

3. Report a. The fuel flow rate of each fuel and the heating values i. Annually, according to the that were used in your calculations, and you must requirements in §63.6650.

demonstrate that the percentage of heat input provided by landfill gas or digester gas, is equivalent to 10 percent or more of the gross heat input on an annual basis; and

b. The operating limits provided in your federally i. See item 3.a.i.

enforceable permit, and any deviations from these limits; and

c. Any problems or errors suspected with the meters i. See item 3.a.i.

Table 8 to SubpartZZZZ of Part 63-Applicability of GeneralProvisions to Subpart ZZZZ [As stated in §63.6665, you must comply with the following applicable general provisions] General provisions Applies to citation Subject of citation subpart Explanation §63.1General 

       §63.1      -              applicability of the General Provisions                                  Yes

§63.2 [Definitions Yes Additional terms defined in §63.6675. §63.3 Units and abbreviations Yes §63.4 Prohibited activities and circumvention Yes §63.5 Construction and reconstruction Yes _§63.6(a) _Applicability 1[Yes 11 §63.6(b)(1)-(4) Compliance dates for new and I _ _ reconstructed sources §63.6(b)(5) Notification Yes §63.6(b)(6) [Reserved] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-25 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 

§63.6(b)(7)            Compliance dates for new and            Yes reconstructed area sources that become major sourcesn
§63.6(c)(1)-(2)        Compliance dates for existing sources    Yes
§63.6(c)(3)-(4)        [Reserved]                                        F
§36.6(c)(5)            Compliance dates for existing area      Yes Isources that become major sources 1§63.6(d)              I[Reserved]                                        F
§63.6(e)(1)          ]Operation   and maintenance              Yes
§63.6(e)(2)          ][[Reserved]
§63.6(e)(3)          1 Startup, shutdown, and malfunction plan
§63.6(f)(1)            Applicability of standards except       Yes during startup shutdown malfunction (SSM)

[§63.6(f)(2) [Methods for determining compliance Yes [§63.6(f)(3) ]Finding of compliance Yes F [§63.6(g)(1)-(3) ][Use of alternate standard Yes 

§63.6(h)               Opacity and visible emission standards No         Subpart ZZZZ does not contain opacity or visible I                                                     emission standards.
§63.6()
 §3I)                ]Compliance extension procedures and criteria                                IYes       F 1§63.60)              ]Presidential compliance exemption        Yes
§63.7(a)(l)-(2)       Performance test dates                   YeSubpart           ZZZZ contains performance test dates at u§§63.6610 and 63.6611.
§63.7(a)(3)           CAA section 114 authority                YFs 1§63.7(b)(1)          iNotification of performance test
§63.7(b)(2)           Notification of rescheduling                       Fes
§63.7(c)              Quality assurance/test plan                               ___
§63.7(d)         -    Testing facilities                       Yes
§63.7(e)(1)           Conditions for conducting performance Yes tests
§63.7(e)(2)           Conduct of performance tests and reduction of data Yes     lSubpart ZZZZ specifies test methods at §63.6620.
§63.7(e)(3)           Test run duration                        Yes
§63.7(e)(4)           Administrator may require other testing Yes Progress Energy Florida, Inc.                                                                   Permit No. 0170004-024-AV Crystal River Power Plant                                                                           Title V Permit Renewal Page NESHAPZ-26 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines under section 114 of the CAA I 

§63.7(f)             Alternative test method provisions        Yes
§63.7(g)             Performance test data analysis,
                    ýrecordkeeping, and reporting
§63.7(h)             Waiver of tests                           Yes
§63.8(a)(1)        1Applicability requirements of monitoring             Yes       Subpart ZZZZ contains specific requirements for monitoring at §63.6625.
§63.8(a)(2)          Performance specifications                Yes
§63.8(a)(3)          [Reserved]
§63.8(a)(4)          Monitoring for control devices            No

_§63.8(b)(1) _Monitoring Yes 

§63.8(b)(2)-(3)      Multiple effluents and multiple           Yes

_monitoring _ systems 

§63.8(c)(1)          Monitoring system operation and           Yes imaintenance

[§63.8(c)(1)(i) 

§63.8(c)(1)(ii) A Routine and predictable SSM SSM not in Startup Shutdown Yes F

Malfunction Plan 

§63.8(c)(1)(iii)     Compliance with operation and            Yes

[maintenance requirements [§63.8(c)(2)-(3) Monitoring system installation Yes 

§63.8(c)(4)
§63.8(c)(4)          Continuous monitoring system (CMS)        Yes       Except that subpart ZZZZ does not require

[requirements Continuous Opacity Monitoring System (COMS). [§63.8(c)(5) COMS minimum procedures No Subpart ZZZZ does not require COMS. [§63.8(c)(6)-(8) CMS requirements Yes Except that subpart ZZZZ does not require COMS. [§63.8(d) [CMS quality control Yes 

§63.8(e)             CMS performance evaluation               Yes      lExcept  for §63.8(e)(5)(ii), which applies to

_________ ________________ JCOMS. [§63.8(f)(l)-(5) ]Alternative monitoring method Yes [§63.8(f)(6) IAlternative to relative accuracy test ][Yes __ 

§63.8(g)            Data reduction                             Yes      Except that provisions for COMS are not applicable. Averaging periods for demonstrating compliance are specified at §§63.6635 and 63.6640.
§63.9(a)             Applicability and State delegation of   LYes

[notification requirements Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-27 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines 

§63.9(b)(I)-(5)           Initial notifications                        Yes      Except that §63.9(b)(3) is reserved.
§63.9(c)                  Request for compliance extension             Yes
§63.9(d)                  Notification of special compliance          Yes

_requirements for new sources 

§63.9(e)                ][Notification of performance test             Yes
§63.9(f)                  Notification of visible emission             No      Subpart ZZZZ does not contain opacity or VE I(VE)/opacity test                                     standards.
§63.9(g)(1)               Notification of performance evaluation       Yes
§63.9(g)(2)               Notification of use of COMS data            No        Subpart ZZZZ does not contain opacity or VE standards.

alternative to RATA is exceeded 

§63.9(h)(1)-(6)           Notification of compliance status           Yes       Except that notifications for sources using a CEMS are due 30 days after completion of

_______________ of__submittal deadlinesperformance evaluations. §63.9(h)(4) is reserved. 

§63.9(i)                  Adjustment of submittal deadlines            Yes

[§63.90) [Change in previous information Yes 

§63.10(a)                 Administrative provisions for record        Yes
                         §keeping/reporting
§63.10(b)(1)            ]Record retention                              Yes
§63.10(b)(2)(i)-(v) ]Records related to SSM                            Yes
§63.10(b)(2)(vi)-         Records                                      Yes (xi)
§63.10(b)(2)(xii)         Record when under waiver                     Yes
§63.10(b)(2)(xiii)
                     ]RATA Records when using alternative to            Yes    ]For CO standard if using RATA alternative.
§63.10(b)(2)(xiv)       IRecords of supporting documentation           Yes
§63.10(b)(3)            ][Records of applicability determination       Yes
§63.10(c)                 Additional records for sources using          es      Except that §63.10(c)(2)-(4) and (9) are reserved.

(CEMS (Y [§63.10(d)(1) ]General reporting requirements Yes 

§63.10(d)(2)              Report of performance test results           Yes
§63.10(d)(3)              Reprting opacity or VE observations         No        Subpart ZZZZ does not contain opacity or VE stanusdards.
§63.10(d)(4)              Progress reports                                             _        __
§63.10(d)(5)              Startup, shutdown, and malfunction          Yes Progress Energy Florida, Inc.                                                                          Permit No. 0170004-024-AV Crystal River Power Plant                                                                                   Title V Permit Renewal Page NESHAPZ-28 of 29

APPENDIX NESHAP SUBPART ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines IIreports 

§63.10(e)(1) and     Additional CMS reports (2)(i)                   Z j§63.10(e)(2)(ii)     ICOMS-related report                    No        Subpart ZZZZ does not require COMS.
§63.10(e)(3)         Excess emission and parameter         ]1Yes       Except that §63.10(e)(3)(i)(C) is reserved.

exceedances reports 

§63.10(e)(4)         Reporting COMS data                     No       [Subpart ZZZZ does not require COMS.
§63.10(f)            Waiver for recordkeeping/reporting      Yes
§63.11Flares                                                1No
§63.12               State authority and delegations         Yes
§63.13               Addresses                               Yes
§63.14               Incorporation by reference              Yes
§63.15               Availability of information             Yes

[73 FR 3610, Jan. 18, 2008] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page NESHAPZ-29 of 29

APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009) RR1. Reporting Schedule. This table summarizes information for convenience purposes only. It does not supersede any of the terms or conditions of this permit. Report Reporting Deadline(s) Related Condition(s) Plant Problems/Permit Deviations Immediately upon occurrence (See RR2.d.) RR2, RR3 Malfunction Excess Emissions Report Quarterly (if requested) RR3 Semi-Annual Monitoring Report Every 6 months RR4 Annual Operating Report April 1 RR5 Annual Emissions Fee Form and Fee March 1 RR6 Annual Statement of Compliance Within 60 days after the end of each calendar year RR7 (or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement); and Within 60 days after submittal of a written agreement for transfer of responsibility, or Within 60 days after permanent shutdown. Notification of Administrative Permit As needed RR8 Corrections Notification of Startup after Minimum of 60 days prior to the intended startup RR9 Shutdown for More than One Year date or, if emergency startup, as soon as possible after the startup date is ascertained Permit Renewal Application 225 days prior to the expiration date of permit TV17 Test Reports Maximum 45 days following compliance tests TR8 (Permitting Note: See permit Section III. Emissions Units and Specific Conditions,for any additional Emission Unit-specific reporting requirements.] RR2. Reports of Problems.

a. Plant Operation-Problems. If the permittee is temporarily unable to comply with any of the conditions of the permit due to breakdown of equipment or destruction by hazard of fire, wind or by other cause, the permittee shall immediately notify the Department. Notification shall include pertinent information as to the cause of the problem, and what steps are being taken to correct the problem and to prevent its recurrence, and where applicable, the owner's intent toward reconstruction of destroyed facilities. Such notification does not release the permittee from any liability for failure to comply with Department rules.
b. If, for any reason, the permittee does not comply with or will be unable to comply with any condition or limitation specified in this permit, the permittee shall immediately provide the Department with the following information:

(1) A description of and cause of noncompliance; and (2) The period of noncompliance, including dates and times; or, if not corrected, the anticipated time the noncompliance is expected to continue, and steps being taken to reduce, eliminate, and prevent recurrence of the noncompliance. The permittee shall be responsible for any and all damages which may result and may be subject to enforcement action by the Department for penalties or for revocation of this permit.

c. When requested by the Department, the permittee shall within a reasonable time furnish any information required by law which is needed to determine compliance with the permit. If the permittee becomes Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR- 1 of 4

APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009) aware the relevant facts were not submitted or were incorrect in the permit application or in any report to the Department, such facts or information shall be corrected promptly.

d. "Immediately" shall mean the same day, if during a workday (i.e., 8:00 a.m. - 5:00 p.m.), or the first business day after the incident, excluding weekends and holidays; and, for purposes of Rule 62-4.160(15) and 40 CFR 70.6(a)(3)(iii)(B), "promptly" or "prompt" shall have the same meaning as "immediately".

[Rule 62-4.130, Rule 62-4.160(8), Rule 62-4.160(15), and Rule 62-213.440(1)(b), F.A.C.; 40 CFR 70.6(a)(3)(iii)(B)] RR3. Reports of Deviations from Permit Requirements. The permittee shall report in accordance with the requirements of Rule 62-210.700(6), F.A.C. (below), and Rule 62-4.130, F.A.C. (condition RR2.), deviations from permit requirements, including those attributable to upset conditions as defined in the permit. Reports shall include the probable cause of such deviations, and any corrective actions or preventive measures taken. Rule 62-210.700(6): In case of excess emissions resulting from malfunctions, each owner or operator shall notify the Department or the appropriate Local Program in accordance with Rule 62-4.130, F.A.C. (See condition RR2.). A full written report on the malfunctions shall be submitted in a quarterly report, if requested by the Department. [Rules 62-213.440(1)(b)3.b., and 62-210.700(6)F.A.C.] RR4. Semi-Annual Monitoring Reports. The permittee shall submit reports of any required monitoring at least every six (6) months. All instances of deviations from permit requirements must be clearly identified in such reports. [Rule 62-213.440(1)(b)3.a., F.A.C.] RR5. Annual Operating Report.

a. The permittee shall submit to the Compliance Authority, each calendar year, on or before April 1, a completed DEP Form No 62-210.900(5), "Annual Operating Report for Air Pollutant Emitting Facility",

for the preceding calendar year.

b. Emissions shall be computed in accordance with the provisions of Rule 62-210.370(2), F.A.C.

[Rules 62-210.370(2) & (3), and 62-213.440(3)(a)2., F.A.C.] RR6. Annual Emissions Fee Form and Fee. Each Title V source permitted to operate in Florida must pay between January 15 and March 1 of each year, an annual emissions fee in an amount determined as set forth in Rule 62-213.205(1), F.A.C.

a. If the Department has not received the fee by February 15 of the year following the calendar year for which the fee is calculated, the Department will send the primary responsible official of the Title V source a written warning of the consequences for failing to pay the fee by March 1. If the fee is not postmarked by March 1 of the year due, the Department shall impose, in addition to the fee, a penalty of 50 percent of the amount of the fee unpaid plus interest on such amount computed in accordance with Section 220.807, F.S. If the Department determines that a submitted fee was inaccurately calculated, the Department shall either refund to the permittee any amount overpaid or notify the permittee of any amount underpaid. The Department shall not impose a penalty or interest on any amount underpaid, provided that the permittee has timely remitted payment of at least 90 percent of the amount determined to be due and remits full payment within 60 days after receipt of notice of the amount underpaid. The Department shall waive the collection of underpayment and shall not refund overpayment of the fee, if the amount is less than 1 percent of the fee due, up to $50.00. The Department shall make every effort to provide a timely assessment of the adequacy of the submitted fee. Failure to pay timely any required annual emissions fee, penalty, or interest constitutes grounds for permit revocation pursuant to Rule 62-4.100, F.A.C.
b. Any documentation of actual hours of operation, actual material or heat input, actual production amount, or actual emissions used to calculate the annual emissions fee shall be retained by the owner for a minimum of five (5) years and shall be made available to the Department upon request.
c. A completed DEP Form 62-213.900(1), "Major Air Pollution Source Annual Emissions Fee Form", must be submitted by a responsible official with the annual emissions fee.

[Rules 62-213.205(1), (1)(g), (1)(i) & (1)(j), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-2 of 4

APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009) RR7. Annual Statement of Compliance.

a. The permittee shall submit a Statement of Compliance with all terms and conditions of the permit that includes all the provisions of 40 CFR 70.6(c)(5)(iii), incorporated by reference at Rule 62-204.800, F.A.C., using DEP Form No. 62-213.900(7). Such statement shall be accompanied by a certification in accordance with Rule 62-213.420(4), F.A.C., for Title V requirements and with Rule 62-214.350, F.A.C.,

for Acid Rain requirements. Such statements shall be submitted (postmarked) to the Department and EPA: (1) Annually, within 60 days after the end of each calendar year during which the Title V permit was effective, or more frequently if specified by Rule 62-213.440(2), F.A.C., or by any other applicable requirement; and (2) Within 60 days after submittal of a written agreement for transfer of responsibility as required pursuant to 40 CFR 70.7(d)(1)(iv), adopted and incorporated by reference at Rule 62-204.800, F.A.C., or within 60 days after permanent shutdown of a facility permitted under Chapter 62-213, F.A.C.; provided that, in either such case, the reporting period shall be the portion of the calendar year the permit was effective up to the date of transfer of responsibility or permanent facility shutdown, as applicable.

b. In lieu of individually identifying all applicable requirements and specifying times of compliance with, non-compliance with, and deviation from each, the responsible official may use DEP Form No. 62-213.900(7) as such statement of compliance so long as the responsible official identifies all reportable deviations from and all instances of non-compliance with any applicable requirements and includes all information required by the federal regulation relating to each reportable deviation and instance of non-compliance.
c. The responsible official may treat compliance with all other applicable requirements as a surrogate for compliance with Rule 62-296.320(2), Objectionable Odor Prohibited.

[Rules 62-213.440(3)(a)2. & 3. and (b), F.A.C.] RR8. Notification of Administrative Permit Corrections.

a. A facility owner shall notify the Department by letter of minor corrections to information contained in a permit. Such notifications shall include:

(1) Typographical errors noted in the permit; (2) Name, address or phone number change from that in the permit; (3) A change requiring more frequent monitoring or reporting by the permittee; (4) A change in ownership or operational control of a facility, subject to the following provisions: (a) The Department determines that no other change in the permit is necessary; (b) The permittee and proposed new permittee have submitted an Application for Transfer of Air Permit, and the Department has approved the transfer pursuant to Rule 62-210.300(7), F.A.C.; and (c) The new permittee has notified the Department of the effective date of sale or legal transfer. (5) Changes listed at 40 CFR 72.83(a)(1), (2), (6), (9) and (10), adopted and incorporated by reference at Rule 62-204.800, F.A.C., and changes made pursuant to Rules 62-214.340(1) and (2), F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-7651o; (6) Changes listed at 40 CFR 72.83(a)(1 1) and (12), adopted and incorporated by reference at Rule 62-204.800, F.A.C., to Title V sources subject to emissions limitations or reductions pursuant to 42 USC ss. 7651-765 lo, provided the notification is accompanied by a copy of any EPA determination concerning the similarity of the change to those listed at Rule 62-210.360(1)(e), F.A.C.; and (7) Any other similar minor administrative change at the source.

b. Upon receipt of any such notification, the Department shall within 60 days correct the permit and provide a corrected copy to the owner.
c. After first notifying the owner, the Department shall correct any permit in which it discovers errors of the types listed at Rules 62-210.360(1)(a) and (b), F.A.C., and provide a corrected copy to the owner.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-3 of 4

APPENDIX RR FACILITY-WIDE REPORTING REQUIREMENTS (Version Dated 09/17/2009)

d. For Title V source permits, other than general permits, a copy of the corrected permit shall be provided to EPA and any approved local air program in the county where the facility or any part of the facility is located.

[Rule 62-210.360, F.A.C.] RR9. Notification of Startup. The owners or operator of any emissions unit or facility which has a valid air operation permit which has been shut down more than one year, shall notify the Department in writing of the intent to start up such emissions unit or facility, a minimum of 60 days prior to the intended startup date.

a. The notification shall include information as to the startup date, anticipated emission rates or pollutants released, changes to processes or control devices which will result in changes to emission rates, and any other conditions which may differ from the valid outstanding operation permit.
b. If, due to an emergency, a startup date is not known 60 days prior thereto, the owner shall notify the Department as soon as possible after the date of such startup is ascertained.

[Rule 62-210.300(5), F.A.C.] RR1O. Report Submission. The permittee shall submit all compliance related notifications and reports required of this permit to the Compliance Authority. {See front of permit for address and phone number.) RR11. EPA Report Submission. Any reports, data, notifications, certifications, and requests required to be sent to the United States Environmental Protection Agency, Region 4, should be sent to: Air, Pesticides & Toxics Management Division, United States Environmental Protection Agency, Region 4, Sam Nunn Atlanta Federal Center, 61 Forsyth Street SW, Atlanta, GA 30303-8960. Phone: 404/562-9077. RR12. Acid Rain Report Submission. Acid Rain Program Information shall be submitted, as necessary, to: Department of Environmental Protection, 2600 Blair Stone Road, Mail Station #5510, Tallahassee, Florida 32399-2400. Phone: 850/488-6140. Fax: 850/922-6979. RR13. Report Certification. All reports shall be accompanied by a certification by a responsible official, pursuant to Rule 62-213.420(4), F.A.C. [Rule 62-213.440(1)(b)3.c, F.A.C.] RR14. Certification by Responsible Official (RO). In addition to the professional engineering certification required for applications by Rule 62-4.050(3), F.A.C., any application form, report, compliance statement, compliance plan and compliance schedule submitted pursuant to Chapter 62-213, F.A.C., shall contain a certification signed by a responsible official that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. Any responsible official who fails to submit any required information or who has submitted incorrect information shall, upon becoming aware of such failure or incorrect submittal, promptly submit such supplementary information or correct information. [Rule 62-213.420(4), F.A.C.] RR15. Confidential Information. Whenever an applicant submits information under a claim of confidentiality pursuant to Section 403.111, F.S., the applicant shall also submit a copy of all such information and claim directly to EPA. Any permittee may claim confidentiality of any data or other information by complying with this procedure. [Rules 62-213.420(2), and 62-213.440(1)(d)6., F.A.C.] RR16. Forms and Instructions. The forms used by the Department in the Title V source operation program are adopted and incorporated by reference in Rule 62-213.900, F.A.C. The forms are listed by rule number, which is also the form number, and with the subject, title, and effective date. Copies of forms may be obtained by writing to the Department of Environmental Protection, Division of Air Resource Management, 2600 Blair Stone Road, Tallahassee, Florida 32399-2400, by contacting the appropriate permitting authority or by accessing the Department's web site at: http://www.dep.state.fl.us/air/rules/forms.htm.

a. Major Air Pollution Source Annual Emissions Fee Form (Effective 10/12/2008).
b. Statement of Compliance Form (Effective 06/02/2002).
c. Responsible Official Notification Form (Effective 06/02/2002).

[Rule 62-213.900, F.A.C.: Forms (1), (7) and (8)] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page RR-4 of 4

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008) Unless otherwise specified in the permit, the following testing requirements apply to each emissions unit for which testing is required. The terms "stack" and "duct" are used interchangeably in this appendix. TR1. Required Number of Test Runs. For mass emission limitations, a compliance test shall consist of three complete and separate determinations of the total air pollutant emission rate through the test section of the stack or duct and three complete and separate determinations of any applicable process variables corresponding to the three distinct time periods during which the stack emission rate was measured; provided, however, that three complete and separate determinations shall not be required if the process variables are not subject to variation during a compliance test, or if three determinations are not necessary in order to calculate the unit's emission rate. The three required test runs shall be completed within one consecutive five-day period. In the event that a sample is lost or one of the three runs must be discontinued because of circumstances beyond the control of the owner or operator, and a valid third run cannot be obtained within the five-day period allowed for the test, the Secretary or his or her designee may accept the results of two complete runs as proof of compliance, provided that the arithmetic mean of the two complete runs is at least 20% below the allowable emission limiting standard. [Rule 62-297.310(1), F.A.C.] TR2. Operating Rate During Testing. Testing of emissions shall be conducted with the emissions unit operating at permitted capacity. If it is impractical to test at permitted capacity, an emissions unit may be tested at less than the maximum permitted capacity; in this case, subsequent emissions unit operation is limited to 110 percent of the test rate until a new test is conducted. Once the unit is so limited, operation at higher capacities is allowed for no more than 15 consecutive days for the purpose of additional compliance testing to regain the authority to operate at the permitted capacity. Permitted capacity is defined as 90 to 100 percent of the maximum operation rate allowed by the permit. [Rule 62-297.310(2), F.A.C.] TR3. Calculation of Emission Rate. For each emissions performance test, the indicated emission rate or concentration shall be the arithmetic average of the emission rate or concentration determined by each of the three separate test runs unless otherwise specified in a particular test method or applicable rule. [Rule 62-297.310(3), F.A.C.] TR4. Applicable Test Procedures.

a. Required Sampling Time.

(1) Unless otherwise specified in the applicable rule, the required sampling time for each test run shall be no less than one hour and no greater than four hours, and the sampling time at each sampling point shall be of equal intervals of at least two minutes. (2) Opacity Compliance Tests. When either EPA Method 9 or DEP Method 9 is specified as the applicable opacity test method, the required minimum period of observation for a compliance test shall be sixty (60) minutes for emissions units which emit or have the potential to emit 100 tons per year or more of particulate matter, and thirty (30) minutes for emissions units which have potential emissions less than 100 tons per year of particulate matter and are not subject to a multiple-valued opacity standard. The opacity test observation period shall include the period during which the highest opacity emissions can reasonably be expected to occur. Exceptions to these requirements are as follows: (a) For batch, cyclical processes, or other operations which are normally completed within less than the minimum observation period and do not recur within that time, the period of observation shall be equal to the duration of the batch cycle or operation completion time. (b) The observation period for special opacity tests that are conducted to provide data to establish a surrogate standard pursuant to Rule 62-297.310(5)(k), F.A.C., Waiver of Compliance Test Requirements, shall be established as necessary to properly establish the relationship between a proposed surrogate standard and an existing mass emission limiting standard. (c) The minimum observation period for opacity tests conducted by employees or agents of the Department to verify the day-to-day continuing compliance of a unit or activity with an applicable opacity standard shall be twelve minutes.

b. Minimum Sample Volume. Unless otherwise specified in the applicable rule or test method, the minimum Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-1 of 6

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008) sample volume per run shall be 25 dry standard cubic feet.

c. Required Flow Rate Range. For EPA Method 5 particulate sampling, acid mist/sulfur dioxide, and fluoride sampling which uses Greenburg Smith type impingers, the sampling nozzle and sampling time shall be selected such that the average sampling rate will be between 0.5 and 1.0 actual cubic feet per minute, and the required minimum sampling volume will be obtained.
d. Calibrationof Sampling Equipment. Calibration of the sampling train equipment shall be conducted in accordance with the schedule shown in Table 297.3 10-1, F.A.C.

TABLE 297.310-1 CALIBRATION SCHEDULE MINIMUM ITEM CALIBRATION REFERENCE INSTRUMENT TOLERANCE FREQUENCY Liquid in glass Annually ASTM Hg in glass ref. +/-2% thermometer thermometer or equivalent or thermometric points Bimetallic Quarterly Calib. liq. in glass 50 F thermometer Thermocouple Annually ASTM Hg in glass ref. 50 F thermometer, NBS calibrated reference and potentiometer Barometer Monthly Hg barometer or NOAA station +/-1% scale Pitot Tube When required or By construction or measurements See EPA Method 2, Fig. when damaged in wind tunnel D greater than 16" 2-2 & 2-3 and standard pitot tube Probe Nozzles Before each test Micrometer +/- 0.001" mean of at or when nicked, least three readings; Max. dented, or deviation between corroded readings, 0.004" Dry Gas Meter 1. Full Scale: Spirometer or calibrated wet test or 2% and Orifice When received, dry gas test meter Meter when 5% change observed, annually

2. One Point:

Semiannually

3. Check after Comparison check 5%

each test series

e. Allowed Modification to EPA Method 5. When EPA Method 5 is required, the following modification is allowed: the heated filter may be separated from the impingers by a flexible tube.

[Rule 62-297.310(4), F.A.C.] TR5. Determination of Process Variables.

a. Required Equipment. The owner or operator of an emissions unit for which compliance tests are required shall install, operate, and maintain equipment or instruments necessary to determine process variables, such as process weight input or heat input, when such data are needed in conjunction with emissions data to determine the compliance of the emissions unit with applicable emission limiting standards.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-2 of 6

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008)

b. Accuracy of Equipment. Equipment or instruments used to directly or indirectly determine process variables, including devices such as belt scales, weight hoppers, flow meters, and tank scales, shall be calibrated and adjusted to indicate the true value of the parameter being measured with sufficient accuracy to allow the applicable process variable to be determined within 10% of its true value.

[Rule 62-297.310(5), F.A.C.] TR6. Sampling Facilities. Permittees that are required to sample mass emissions from point sources shall install stack sampling ports and provide sampling facilities that meet the requirements of this condition. Sampling facilities include sampling ports, work platforms, access to work platforms, electrical power, and sampling equipment support. All stack sampling facilities must also comply with all applicable Occupational Safety and Health Administration (OSHA) Safety and Health Standards described in 29 CFR Part 1910, Subparts D and E.

a. Permanent Test Facilities. The owner or operator of an emissions unit for which a compliance test, other than a visible emissions test, is required on at least an annual basis, shall install and maintain permanent stack sampling facilities.
b. Temporary Test Facilities. The owner or operator of an emissions unit that is not required to conduct a compliance test on at least an annual basis may use permanent or temporary stack sampling facilities. If the owner chooses to use temporary sampling facilities on an emissions unit, and the Department elects to test the unit, such temporary facilities shall be installed on the emissions unit within 5 days of a request by the Department and remain on the emissions unit until the test is completed.
c. Sampling Ports.

(1) All sampling ports shall have a minimum inside diameter of 3 inches. (2) The ports shall be capable of being sealed when not in use. (3) The sampling ports shall be located in the stack at least 2 stack diameters or equivalent diameters downstream and at least 0.5 stack diameter or equivalent diameter upstream from any fan, bend, constriction or other flow disturbance. (4) For emissions units for which a complete application to construct has been filed prior to December 1, 1980, at least two sampling ports, 90 degrees apart, shall be installed at each sampling location on all circular stacks that have an outside diameter of 15 feet or less. For stacks with a larger diameter, four sampling ports, each 90 degrees apart, shall be installed. For emissions units for which a complete application to construct is filed on or after December 1, 1980, at least two sampling ports, 90 degrees apart, shall be installed at each sampling location on all circular stacks that have an outside diameter of 10 feet or less. For stacks with larger diameters, four sampling ports, each 90 degrees apart, shall be installed. On horizontal circular ducts, the ports shall be located so that the probe can enter the stack vertically, horizontally or at a 45 degree angle. (5) On rectangular ducts, the cross sectional area shall be divided into the number of equal areas in accordance with EPA Method 1. Sampling ports shall be provided which allow access to each sampling point. The ports shall be located so that the probe can be inserted perpendicular to the gas flow.

d. Work Platforms.

(1) Minimum size of the working platform shall be 24 square feet in area. Platforms shall be at least 3 feet wide. (2) On circular stacks with 2 sampling ports, the platform shall extend at least 110 degrees around the stack. (3) On circular stacks with more than two sampling ports, the work platform shall extend 360 degrees around the stack. (4) All platforms shall be equipped with an adequate safety rail (ropes are not acceptable), toe board, and hinged floor-opening cover if ladder access is used to reach the platform. The safety rail directly in line with the sampling ports shall be removable so that no obstruction exists in an area 14 inches below each sample port and 6 inches on either side of the sampling port.

e. Access to Work Platform.

(1) Ladders to the work platform exceeding 15 feet in length shall have safety cages or fall arresters with Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-3 of 6

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008) a minimum of 3 compatible safety belts available for use by sampling personnel. (2) Walkways over free-fall areas shall be equipped with safety rails and toe boards.

f. ElectricalPower.

(1) A minimum of two 120-volt AC, 20-amp outlets shall be provided at the sampling platform within 20 feet of each sampling port. (2) If extension cords are used to provide the electrical power, they shall be kept on the plant's property and be available immediately upon request by sampling personnel.

g. Sampling Equipment Support.

(1) A three-quarter inch eyebolt and an angle bracket shall be attached directly above each port on vertical stacks and above each row of sampling ports on the sides of horizontal ducts. (a) The bracket shall be a standard 3 inch x 3 inch x one-quarter inch equal-legs bracket which is 1 and one-half inches wide. A hole that is one-half inch in diameter shall be drilled through the exact center of the horizontal portion of the bracket. The horizontal portion of the bracket shall be located 14 inches above the centerline of the sampling port. (b) A three-eighth inch bolt which protrudes 2 inches from the stack may be substituted for the required bracket. The bolt shall be located 15 and one-half inches above the centerline of the sampling port. (c) The three-quarter inch eyebolt shall be capable of supporting a 500 pound working load. For stacks that are less than 12 feet in diameter, the eyebolt shall be located 48 inches above the horizontal portion of the angle bracket. For stacks that are greater than or equal to 12 feet in diameter, the eyebolt shall be located 60 inches above the horizontal portion of the angle bracket. If the eyebolt is more than 120 inches above the platform, a length of chain shall be attached to it to bring the free end of the chain to within safe reach from the platform. (2) A complete monorail or dual rail arrangement may be substituted for the eyebolt and bracket. (3) When the sample ports are located in the top of a horizontal duct, a frame shall be provided above the port to allow the sample probe to be secured during the test. [Rule 62-297.310(6), F.A.C.] TR7. Frequency of Compliance Tests. The following provisions apply only to those emissions units that are subject to an emissions limiting standard for which compliance testing is required.

a. General Compliance Testing.

(1) The owner or operator of a new or modified emissions unit that is subject to an emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission limiting standard prior to obtaining an operation permit for such emissions unit. (2) For excess emission limitations for particulate matter specified in Rule 62-210.700, F.A.C., a compliance test shall be conducted annually while the emissions unit is operating under soot blowing conditions in each federal fiscal year during which soot blowing is part of normal emissions unit operation, except that such test shall not be required in any federal fiscal year in which a fossil fuel steam generator does not burn liquid and/or solid fuel for more than 400 hours other than during startup. (3) The owner or operator of an emissions unit that is subject to any emission limiting standard shall conduct a compliance test that demonstrates compliance with the applicable emission limiting standard prior to obtaining a renewed operation permit. Emissions units that are required to conduct an annual compliance test may submit the most recent annual compliance test to satisfy the requirements of this provision. In renewing an air operation permit pursuant to sub-subparagraph 62-210.300(2)(a)3.b., c., or d., F.A.C., the Department shall not require submission of emission compliance test results for any emissions unit that, during the year prior to renewal: (a) Did not operate; or (b) In the case of a fuel burning emissions unit, burned liquid and/or solid fuel for a total of no more than 400 hours. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-4 of 6

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008) (4) During each federal fiscal year (October 1 - September 30), unless otherwise specified by rule, order, or permit, the owner or operator of each emissions unit shall have a formal compliance test conducted for: (a) Visible emissions, if there is an applicable standard; (b) Each of the following pollutants, if there is an applicable standard, and if the emissions unit emits or has the potential to emit: 5 tons per year or more of lead or lead compounds measured as elemental lead; 30 tons per year or more of acrylonitrile; or 100 tons per year or more of any other regulated air pollutant; and (c) Each NESHAP pollutant, if there is an applicable emission standard. (5) An annual compliance test for particulate matter emissions shall not be required for any fuel burning emissions unit that, in a federal fiscal year, does not burn liquid and/or solid fuel, other than during startup, for a total of more than 400 hours. (6) For fossil fuel steam generators on a semi-annual particulate matter emission compliance testing schedule, a compliance test shall not be required for any six-month period in which liquid and/or solid fuel is not burned for more than 200 hours other than during startup. (7) For emissions units electing to conduct particulate matter emission compliance testing quarterly pursuant to paragraph 62-296.405(2)(a), F.A.C., a compliance test shall not be required for any quarter in which liquid and/or solid fuel is not burned for more than 100 hours other than during startup. (8) Any combustion turbine that does not operate for more than 400 hours per year shall conduct a visible emissions compliance test once per each five-year period, coinciding with the term of its air operation permit. (9) The owner or operator shall notify the Department, at least 15 days prior to the date on which each formal compliance test is to begin, of the date, time, and place of each such test, and the test contact person who will be responsible for coordinating and having such test conducted for the owner or operator. (10) An annual compliance test conducted for visible emissions shall not be required for units exempted from air permitting pursuant to subsection 62-210.300(3), F.A.C.; units determined to be insignificant pursuant to subparagraph 62-213.300(2)(a)1., A.C., or paragraph 62-213.430(6)(b), F.A.C.; or units permitted under the General Permit provisions in paragraph 62-210.300(4)(a) or Rule 62-213.300, F.A.C., unless the general permit specifically requires such testing.

b. Special Compliance Tests. When the Department, after investigation, has good reason (such as complaints, increased visible emissions or questionable maintenance of control equipment) to believe that any applicable emission standard contained Department rule or in a permit issued pursuant to those rules is being violated, it shall require the owner or operator of the emissions unit to conduct compliance tests which identify the nature and quantity of pollutant emissions from the emissions unit and to provide a report on the results of said tests to the Department.
c. Waiver of Compliance Test Requirements. If the owner or operator of an emissions unit that is subject to a compliance test requirement demonstrates to the Department, pursuant to the procedure established in Rule 62-297.620, F.A.C., that the compliance the emissions unit with an applicable weight emission limiting standard can be adequately determined by means other than the designated test procedure, such as specifying a surrogate standard of no visible emissions for particulate matter sources equipped with a bag house or specifying a fuel analysis for sulfur dioxide emissions, the Department shall waive the compliance test requirements for such emissions units and order that the alternate means of determining compliance be used, provided, however, the provisions of paragraph 62-297.310(7)(b), F.A.C., shall apply.

[Rule 62-297.310(7), F.A.C.] TR8. Test Reports.

a. The owner or operator of an emissions unit for which a compliance test is required shall file a report with the Department on the results of each such test.
b. The required test report shall be filed with the Department as soon as practical but no later than 45 days Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-5 of 6

APPENDIX TR FACILITY-WIDE TESTING REQUIREMENTS (Version Dated 09/12/2008) after the last sampling run of each test is completed.

c. The test report shall provide sufficient detail on the emissions unit tested and the test procedures used to allow the Department to determine if the test was properly conducted and the test results properly computed. As a minimum, the test report, other than for an EPA or DEP Method 9 test, shall provide the following information.

(1) The type, location, and designation of the emissions unit tested. (2) The facility at which the emissions unit is located. (3) The owner or operator of the emissions unit. (4) The normal type and amount of fuels used and materials processed, and the types and amounts of fuels used and material processed during each test run. (5) The means, raw data and computations used to determine the amount of fuels used and materials processed, if necessary to determine compliance with an applicable emission limiting standard. (6) The type of air pollution control devices installed on the emissions unit, their general condition, their normal operating parameters (pressure drops, total operating current and GPM scrubber water), and their operating parameters during each test run. (7) A sketch of the duct within 8 stack diameters upstream and 2 stack diameters downstream of the sampling ports, including the distance to any upstream and downstream bends or other flow disturbances. (8) The date, starting time and duration of each sampling run. (9) The test procedures used, including any alternative procedures authorized pursuant to Rule 62-297.620, F.A.C. Where optional procedures are authorized in this chapter, indicate which option was used. (10) The number of points sampled and configuration and location of the sampling plane. (11) For each sampling point for each run, the dry gas meter reading, velocity head, pressure drop across the stack, temperatures, average meter temperatures and sample time per point. (12) The type, manufacturer and configuration of the sampling equipment used. (13) Data related to the required calibration of the test equipment. (14) Data on the identification, processing and weights of all filters used. (15) Data on the types and amounts of any chemical solutions used. (16) Data on the amount of pollutant collected from each sampling probe, the filters, and the impingers, are reported separately for the compliance test. (17) The names of individuals who furnished the process variable data, conducted the test, analyzed the samples and prepared the report. (18) All measured and calculated data required to be determined by each applicable test procedure for each run. (19) The detailed calculations for one run that relate the collected data to the calculated emission rate. (20) The applicable emission standard and the resulting maximum allowable emission rate for the emissions unit plus the test result in the same form and unit of measure. (21) A certification that, to the knowledge of the owner or his authorized agent, all data submitted are true and correct. When a compliance test is conducted for the Department or its agent, the person who conducts the test shall provide the certification with respect to the test procedures used. The owner or his authorized agent shall certify that all data required and provided to the person conducting the test are true and correct to his knowledge. [Rule 62-297.310(8), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TR-6 of 6

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) Operation TM1. General Prohibition. A permitted installation may only be operated, maintained, constructed, expanded or modified in a manner that is consistent with the terms of the permit. [Rule 62-4.030, Florida Administrative Code (F.A.C.)] TV2. Validity. This permit is valid only for the specific processes and operations applied for and indicated in the approved drawings or exhibits. Any unauthorized deviation from the approved drawings, exhibits, specifications, or conditions of this permit may constitute grounds for revocation and enforcement action by the Department. [Rule 62-4.160(2), F.A.C.] TV3. Proper Operation and Maintenance. The permittee shall properly operate and maintain the facility and systems of treatment and control (and related appurtenances) that are installed and used by the permittee to achieve compliance with the conditions of this permit, as required by Department rules. This provision includes the operation of backup or auxiliary facilities or similar systems when necessary to achieve compliance with the conditions of the permit and when required by Department rules. [Rule 62-4.160(6), F.A.C.] TV4. Not Federally Enforceable. Health, Safety and Welfare. To ensure protection of public health, safety, and welfare, any construction, modification, or operation of an installation which may be a source of pollution, shall be in accordance with sound professional engineering practices pursuant to Chapter 471, F.S. [Rule 62-4.050(3), F.A.C.] TV5. Continued Operation. An applicant making timely and complete application for permit, or for permit renewal, shall continue to operate the source under the authority and provisions of any existing valid permit or Florida Electrical Power Plant Siting Certification, and in accordance with applicable requirements of the Acid Rain Program, applicable requirements of the CAIR Program, and applicable requirements of the Hg Budget Trading Program, until the conclusion of proceedings associated with its permit application or until the new permit becomes effective, whichever is later, provided the applicant complies with all the provisions of subparagraphs 62-213.420(1)(b)3., F.A.C. [Rules 62-213.420(1)(b)2., F.A.C.] TV6. Changes Without Permit Revision. Title V sources having a valid permit issued pursuant to Chapter 62-213, F.A.C., may make the following changes without permit revision, provided that sources shall maintain source logs or records to verify periods of operation:

a. Permitted sources may change among those alternative methods of operation allowed by the source's permit as provided by the terms of the permit;
b. A permitted source may implement operating changes, as defined in Rule 62-210.200, F.A.C., after the source submits any forms required by any applicable requirement and provides the Department and EPA with at least 7 days written notice prior to implementation. The source and the Department shall attach each notice to the relevant permit; (1) The written notice shall include the date on which the change will occur, and a description of the change within the permitted source, the pollutants emitted and any change in emissions, and any term or condition becoming applicable or no longer applicable as a result of the change; (2) The permit shield described in Rule 62-213.460, F.A.C., shall not apply to such changes;
c. Permitted sources may implement changes involving modes of operation only in accordance with Rule 62-213.415, F.A.C.

[Rule 62-213.410, F.A.C.] TV7. Circumvention. No person shall circumvent any air pollution control device, or allow the emission of air pollutants without the applicable air pollution control device operating properly. [Rule 62-210.650, F.A.C.] Compliance TV8. Compliance with Chapter 403, F.S., and Department Rules. Except as provided at Rule 62-213.460, Permit Shield, F.A.C., the issuance of a permit does not relieve any person from complying with the requirements of Chapter 403, F.S., or Department rules. [Rule 62-4.070(7), F.A.C.] Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-I of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) TV9. Compliance with Federal, State and Local Rules. Except as provided at Rule 62-213.460, F.A.C., issuance of a permit does not relieve the owner or operator of a facility or an emissions unit from complying with any applicable requirements, any emission limiting standards or other requirements of the air pollution rules of the Department or any other such requirements under federal, state, or local law. [Rule 62-210.300, F.A.C.] TV10. Binding and enforceable. The terms, conditions, requirements, limitations and restrictions set forth in this permit, are "permit conditions" and are binding and enforceable pursuant to Sections 403.141, 403.727, or 403.859 through 403.861, F.S. The permittee is placed on notice that the Department will review this permit periodically and may initiate enforcement action for any violation of these conditions. [Rule 62-4.160(1), F.A.C.] TVll. Timely information. When requested by the Department, the permittee shall within a reasonable time furnish any information required by law which is needed to determine compliance with the permit. If the permittee becomes aware the relevant facts were not submitted or were incorrect in the permit application or in any report to the Department, such facts or information shall be corrected promptly. [Rule 62-4.160(15), F.A.C.] TV12. Halting or reduction of source activity. It shall not be a defense for a permittee in an enforcement action that maintaining compliance with any permit condition would necessitate halting of or reduction of the source activity. [Rule 62-213.440(1)(d)3., F.A.C.] TV13. Final permit action. Any Title V source shall comply with all the terms and conditions of the existing permit until the Department has taken final action on any permit renewal or any requested permit revision, except as provided at Rule 62-213.412(2), F.A.C. [Rule 62-213.440(1)(d)4., F.A.C.] TV14. Sudden and unforeseeable events beyond the control of the source. A situation arising from sudden and unforeseeable events beyond the control of the source which causes an exceedance of a technology-based emissions limitation because of unavoidable increases in emissions attributable to the situation and which requires immediate corrective action to restore normal operation, shall be an affirmative defense to an enforcement action in accordance with the provisions and requirements of 40 CFR 70.6(g)(2) and (3), hereby adopted and incorporated by reference. [Rule 62-213.440(1)(d)5., F.A.C.] TV15. Permit Shield. Except as provided in Chapter 62-213, F.A.C., compliance with the terms and conditions of a permit issued pursuant to Chapter 62-213, F.A.C., shall, as of the effective date of the permit, be deemed compliance with any applicable requirements in effect, provided that the source included such applicable requirements in the permit application. Nothing in this condition or in any permit shall alter or affect the ability of EPA or the Department to deal with an emergency, the liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance, or the requirements of the Federal Acid Rain Program or the CAIR Program. [Rule 62-213.460, F.A.C.] TV16. Compliance With Federal Rules. A facility or emissions unit subject to any standard or requirement of 40 CFR, Part 60, 61, 63 or 65, adopted and incorporated by reference at Rule 62-204.800, F.A.C., shall comply with such standard or requirement. Nothing in this chapter shall relieve a facility or emissions unit from complying with such standard or requirement, provided, however, that where a facility or emissions unit is subject to a standard established in Rule 62-296, F.A.C., such standard shall also apply. [Rule 62-296.100(3), F.A.C.] Permit Procedures TV17. Permit Revision Procedures. The permittee shall revise its permit as required by Rules 62-213.400, 62-213.412, 62-213.420, 62-213.430 & 62-4.080, F.A.C.; and, in addition, the Department shall revise permits as provided in Rule 62-4.080, F.A.C. & 40 CFR 70.7(f). TV18. Permit Renewal. The permittee shall renew its permit as required by Rules 62-4.090, 62.213.420(1) and 62-213.430(3), F.A.C. Permits being renewed are subject to the same requirements that apply to permit issuance at the time of application for renewal. Permit renewal applications shall contain that information Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-2 of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) identified in Rules 62-210.900(1) [Application for Air Permit - Long Form], 62-213.420(3) [Required Information], 62-213.420(6) [CAIR Part Form], F.A.C. Unless a Title V source submits a timely and complete application for permit renewal in accordance with the requirements this rule, the existing permit shall expire and the source's right to operate shall terminate. For purposes of a permit renewal, a timely application is one that is submitted 225 days before the expiration of a permit that expires on or after June 1, 2009. No Title V permit will be issued for a new term except through the renewal process. [Rules 62-213.420 & 62-213.430, F.A.C.] TV19. Insignificant Emissions Units or Pollutant-Emitting Activities. The permittee shall identify and evaluate insignificant emissions units and activities as set forth in Rule 62-213.430(6), F.A.C. TV20. Savings Clause. If any portion of the final permit is invalidated, the remainder of the permit shall remain in effect. [Rule 62-213.440(1)(d)1., F.A.C.] TV21. Suspension and Revocation.

a. Permits shall be effective until suspended, revoked, surrendered, or expired and shall be subject to the provisions of Chapter 403, F.S., and rules of the Department.
b. Failure to comply with pollution control laws and rules shall be grounds for suspension or revocation.
c. A permit issued pursuant to Chapter 62-4, F.A.C., shall not become a vested property right in the permittee. The Department may revoke any permit issued by it if it finds that the permit holder or his agent:

(1) Submitted false or inaccurate information in his application or operational reports. (2) Has violated law, Department orders, rules or permit conditions. (3) Has failed to submit operational reports or other information required by Department rules. (4) Has refused lawful inspection under Section 403.091, F.S.

d. No revocation shall become effective except after notice is served by personal services, certified mail, or newspaper notice pursuant to Section 120.60(7), F.S., upon the person or persons named therein and a hearing held if requested within the time specified in the notice. The notice shall specify the provision of the law, or rule alleged to be violated, or the permit condition or Department order alleged to be violated, and the facts alleged to constitute a violation thereof.

[Rule 62-4. 100, F.A.C.] TV22. Not federally enforceable. Financial Responsibility. The Department may require an applicant to submit proof of financial responsibility and may require the applicant to post an appropriate bond to guarantee compliance with the law and Department rules. [Rule 62-4.110, F.A.C.] TV23. Emissions Unit Reclassification.

a. Any emissions unit whose operation permit has been revoked as provided for in Chapter 62-4, F.A.C.,

shall be deemed permanently shut down for purposes of Rule 62-212.500, F.A.C. Any emissions unit whose permit to operate has expired without timely renewal or transfer may be deemed permanently shut down, provided, however, that no such emissions unit shall be deemed permanently shut down if, within 20 days after receipt of written notice from the Department, the emissions unit owner or operator demonstrates that the permit expiration resulted from inadvertent failure to comply with the requirements of Rule 62-4.090, F.A.C., and that the owner or operator intends to continue the emissions unit in operation, and either submits an application for an air operation permit or complies with permit transfer requirements, if applicable.

b. If the owner or operator of an emissions unit which is so permanently shut down, applies to the Department for a permit to reactivate or operate such emissions unit, the emissions unit will be reviewed and permitted as a new emissions unit.

[Rule 62-210.300(6), F.A.C.] TV24. Transfer of Permits. Per Rule 62-4.160(11), F.A.C., this permit is transferable only upon Department approval in accordance with Rule 62-4.120, F.A.C., as applicable. The permittee shall be liable for any non-compliance of the permitted activity until the transfer is approved by the Department. The permittee transferring the permit shall remain liable for corrective actions that may be required as a result of any Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-3 of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) violations occurring prior to the sale or legal transfer of the facility. The permittee shall also comply with the requirements of Rule 62-210.300(7), F.A.C., and use DEP Form No. 62-210.900(7). [Rules 62-4.160(11), 62-4.120, and 62-210.300(7), F.A.C.] Rights. Title, Liability, and Agreements TV25. Rigbhs. As provided in Subsections 403.987(6) and 403.722(5), F.S., the issuance of this permit does not convey any vested rights or any exclusive privileges. Neither does it authorize any injury to public or private property or any invasion of personal rights, nor any infringement of federal, state, or local laws or regulations. This permit is not a waiver of or approval of any other Department permit that may be required for other aspects of the total project which are not addressed in this permit. [Rule 62-4.160(3), F.A.C.] TV26. Title. This permit conveys no title to land or water, does not constitute State recognition or acknowledgment of title, and does not constitute authority for the use of submerged lands unless herein provided and the necessary title or leasehold interests have been obtained from the State. Only the Trustees of the Internal Improvement Trust Fund may express State opinion as to title. [Rule 62-4.160(4), (F.A.C.] TV27. Liability. This permit does not relieve the permittee from liability for harm or injury to human health or welfare, animal, or plant life, or property caused by the construction or operation of this permitted source, or from penalties therefore; nor does it allow the permittee to cause pollution in contravention of F.S. and Department rules, unless specifically authorized by an order from the Department. [Rule 62-4.160(5), F.A.C.] TV28. Agreements.

a. The permittee, by accepting this permit, specifically agrees to allow authorized Department personnel, upon presentation of credentials or other documents as may be required by law and at reasonable times, access to the premises where the permitted activity is located or conducted to:

(1) Have access to and copy any records that must be kept under conditions of the permit; (2) Inspect the facility, equipment, practices, or operations regulated or required under this permit; and, (3) Sample or monitor any substances or parameters at any location reasonably necessary to assure compliance with this permit or Department rules. Reasonable time may depend on the nature of the concern being investigated.

b. In accepting this permit, the permittee understands and agrees that all records, notes, monitoring data and other information relating to the construction or operation of this permitted source which are submitted to the Department may be used by the Department as evidence in any enforcement case involving the permitted source arising under the Florida Statutes or Department rules, except where such use is prescribed by Sections 403.111 and 403.73, F.S. Such evidence shall only be used to the extent it is consistent with the Florida Rules of Civil Procedure and appropriate evidentiary rules.
c. The permittee agrees to comply with changes in Department rules and Florida Statutes after a reasonable time for compliance; provided, however, the permittee does not waive any other rights granted by Florida Statutes or Department rules.

[Rules 62-4.160(7), (9), and (10), F.A.C.] Recordkeeping and Emissions Computation TV29. Permit. The permittee shall keep this permit or a copy thereof at the work site of the permitted activity. [Rule 62-4.160(12), F.A.C.] TV30. Recordkeeping.

a. Upon request, the permittee shall furnish all records and plans required under Department rules. During enforcement actions, the retention period for all records will be extended automatically unless otherwise stipulated by the Department.
b. The permittee shall hold at the facility or other location designated by this permit records of all monitoring information (including all calibration and maintenance records and all original strip chart recordings for continuous monitoring instrumentation) required by the permit, copies of all reports required by this permit, and records of all data used to complete the application for this permit. These Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-4 of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) materials shall be retained at least five (5) years from the date of the sample, measurement, report, or application unless otherwise specified by Department rule.

c. Records of monitoring information shall include:

(1) The date, exact place, and time of sampling or measurements, and the operating conditions at the time of sampling or measurement; (2) The person responsible for performing the sampling or measurements; (3) The dates analyses were performed; (4) The person and company that performed the analyses; (5) The analytical techniques or methods used; (6) The results of such analyses. [Rules 62-4.160(14) and 62-213.440(1 )(b)2., F.A.C.] TV31. Emissions Computation. Pursuant to Rule 62-210.370, F.A.C., the following required methodologies are to be used by the owner or operator of a facility for computing actual emissions, baseline actual emissions, and net emissions increase, as defined at Rule 62-210.200, F.A.C., and for computing emissions for purposes of the reporting requirements of subsection 62-210.370(3) and paragraph 62-212.300(1)(e), F.A.C., or of any permit condition that requires emissions be computed in accordance with Rule 62-210.370, F.A.C. Rule 62-210.370, F.A.C., is not intended to establish methodologies for determining compliance with the emission limitations of any air permit. For any of the purposes specified above, the owner or operator of a facility shall compute emissions in accordance with the requirements set forth in this subsection.

a. Basic Approach. The owner or operator shall employ, on a pollutant-specific basis, the most accurate of the approaches set forth below to compute the emissions of a pollutant from an emissions unit; provided, however, that nothing in this rule shall be construed to require installation and operation of any continuous emissions monitoring system (CEMS), continuous parameter monitoring system (CPMS), or predictive emissions monitoring system (PEMS) not otherwise required by rule or permit, nor shall anything in this rule be construed to require performance of any stack testing not otherwise required by rule or permit.

(1) If the emissions unit is equipped with a CEMS meeting the requirements of paragraph 62-210.370(2)(b), F.A.C., the owner or operator shall use such CEMS to compute the emissions of the pollutant, unless the owner or operator demonstrates to the department that an alternative approach is more accurate because the CEMS represents still-emerging technology. (2) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C, but emissions of the pollutant can be computed pursuant to the mass balance methodology of paragraph 62-210.370(2)(c), F.A.C., the owner or operator shall use such methodology, unless the owner or operator demonstrates to the department that an alternative approach is more accurate. (3) If a CEMS is not available or does not meet the requirements of paragraph 62-210.370(2)(b), F.A.C., and emissions cannot be computed pursuant to the mass balance methodology, the owner or operator shall use an emission factor meeting the requirements of paragraph 62-210.370(2)(d), F.A.C., unless the owner or operator demonstrates to the department that an alternative approach is more accurate.

b. Continuous Emissions Monitoring System (CEMS).

(1) An owner or operator may use a CEMS to compute emissions of a pollutant for purposes of this rule provided: (a) The CEMS complies with the applicable certification and quality assurance requirements of 40 CFR Part 60, Appendices B and F, or, for an acid rain unit, the certification and quality assurance requirements of 40 CFR Part 75, all adopted by reference at Rule 62-204.800, F.A.C.; or, (b) The owner or operator demonstrates that the CEMS otherwise represents the most accurate means of computing emissions for purposes of this rule. (2) Stack gas volumetric flow rates used with the CEMS to compute emissions shall be obtained by the most accurate of the following methods as demonstrated by the owner or operator: (a) A calibrated flowmeter that records data on a continuous basis, if available; or Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-5 of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009) (b) The average flow rate of all valid stack tests conducted during a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit. (3) The owner or operator may use CEMS data in combination with an appropriate f-factor, heat input data, and any other necessary parameters to compute emissions if such method is demonstrated by the owner or operator to be more accurate than using a stack gas volumetric flow rate as set forth at subparagraph 62-210.370(2)(b)2., F.A.C., above.

c. Mass Balance Calculations.

(1) An owner or operator may use mass balance calculations to compute emissions of a pollutant for purposes of this rule provided the owner or operator: (a) Demonstrates a means of validating the content of the pollutant that is contained in or created by all materials or fuels used in or at the emissions unit; and, (b) Assumes that the emissions unit emits all of the pollutant that is contained in or created by any material or fuel used in or at the emissions unit if it cannot otherwise be accounted for in the process or in the capture and destruction of the pollutant by the unit's air pollution control equipment. (2) Where the vendor of a raw material or fuel which is used in or at the emissions unit publishes a range of pollutant content from such material or fuel, the owner or operator shall use the highest value of the range to compute the emissions, unless the owner or operator demonstrates using site-specific data that another content within the range is more accurate. (3) In the case of an emissions unit using coatings or solvents, the owner or operator shall document, through purchase receipts, records and sales receipts, the beginning and ending VOC inventories, the amount of VOC purchased during the computational period, and the amount of VOC disposed of in the liquid phase during such period.

d. Emission Factors.

(1) An owner or operator may use an emission factor to compute emissions of a pollutant for purposes of this rule provided the emission factor is based on site-specific data such as stack test data, where available, unless the owner or operator demonstrates to the department that an alternative emission factor is more accurate. An owner or operator using site-specific data to derive an emission factor, or set of factors, shall meet the following requirements. (a) If stack test data are used, the emission factor shall be based on the average emissions per unit of input, output, or gas volume, whichever is appropriate, of all valid stack tests conducted during at least a five-year period encompassing the period over which the emissions are being computed, provided all stack tests used shall represent the same operational and physical configuration of the unit. (b) Multiple emission factors shall be used as necessary to account for variations in emission rate associated with variations in the emissions unit's operating rate or operating conditions during the period over which emissions are computed. (c) The owner or operator shall compute emissions by multiplying the appropriate emission factor by the appropriate input, output or gas volume value for the period over which the emissions are computed. The owner or operator shall not compute emissions by converting an emission factor to pounds per hour and then multiplying by hours of operation, unless the owner or operator demonstrates that such computation is the most accurate method available. (2) If site-specific data are not available to derive an emission factor, the owner or operator may use a published emission factor directly applicable to the process for which emissions are computed. If no directly-applicable emission factor is available, the owner or operator may use a factor based on a similar, but different, process.

e. Accounting for Emissions During Periodsof Missing Datafrom CEMS, PEMS, or CPMS. In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of missing data from CEMS, PEMS, or CPMS using other site-specific data to generate a reasonable estimate of such emissions.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Pennit Renewal Page TV-6 of 7

APPENDIX TV TITLE V GENERAL CONDITIONS (Version Dated 09/17/2009)

f. Accounting for Emissions During Periods of Startup and Shutdown. In computing the emissions of a pollutant, the owner or operator shall account for the emissions during periods of startup andshutdown of the emissions unit.
g. Fugitive Emissions. In computing the emissions of a pollutant from a facility or emissions unit, the owner or operator shall account for the fugitive emissions of the pollutant, to the extent quantifiable, associated with such facility or emissions unit.
h. Recordkeeping. The owner or operator shall retain a copy of all records used to compute emissions pursuant to this rule for a period of five years from the date on which such emissions information is submitted to the department for any regulatory purpose.

[Rule 62-210.370(1) & (2), F.A.C.] Responsible Official TV32. Designation and Update. The permittee shall designate and update a responsible official as required by Rule 62-213.202, F.A.C. TV33. Asbestos. This permit does not authorize any demolition or renovation of the facility or its parts or components which involves asbestos removal. This permit does not constitute a waiver of any of the requirements of Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, National Emission Standard for Asbestos, adopted and incorporated by reference in Rule 62-204.800, F.A.C. Compliance with Chapter 62-257, F.A.C., and 40 CFR 61, Subpart M, Section 61.145, is required for any asbestos demolition or renovation at the source. [40 CFR 61; Rule 62-204.800, F.A.C.; and, Chapter 62-257, F.A.C.] TV34. Refrigerant Requirements. Any facility having refrigeration equipment, including air conditioning equipment, which uses a Class I or II substance (listed at 40 CFR 82, Subpart A, Appendices A and B), and any facility which maintains, services, or repairs motor vehicles using a Class I or Class II substance as refrigerant must comply with all requirements of 40 CFR 82, Subparts B and F, and with Chapter 62-281, F.A.C. TV35. Open Burning Prohibited. Unless otherwise authorized by Rule 62-296.320(3) or Chapter 62-256, F.A.C., open burning is prohibited. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page TV-7 of 7

APPENDIX U LIST OF UNREGULATED EMISSIONS UNITS AND/OR ACTIVITIES. Unregulated Emissions Units and/or Activities. An emissions unit which emits no "emissions-limited pollutant" and which is subject to no unit-specific work practice standard, though it may be subject to regulations applied on a facility-wide basis (e.g., unconfined emissions, odor, general opacity) or to regulations that require only that it be able to prove exemption from unit-specific emissions or work practice standards. The below listed emissions units and/or activities are neither 'regulated emissions units' nor 'insignificant emissions units'. E.U. ID No. Brief Description of Emissions Units and/or Activity 017 Fuel and lube oil tanks and vents1 2 018 Sewage treatment, water treatment, lime storage 019 Two 3500 kW diesel generators associated with Unit 3-Notes:

1. This unregulated emissions unit consists of the following facilities:

Associated with Units 1 and 2: Number 2 fuel oil, 210,000 gal capacity, tank # 10. Lube oil vents, one each at Unit 1 and 2. Rotoclone with air filter at Unit 1. Oil vent at Unit 1. Associated with Unit 3: Equipment diesel tanks, tanks 2 through 8, 15, 16, 22 and 23, capacities from 30 gallons to 30,118 gallons. Lube oil tank, 25,000 gallon capacity, tank #9. Two small cooling towers west of Main Building. Two lube oil vents. Associated with Units 4 and 5: Number 2 fuel oil, 256,200 gal capacity, tank # 1, and 255,318 gal capacity, tank # 2. Equipment diesel tanks, tanks 3 and 4, capacity of 250 gallons, each. Lube oil tank, 30,000 gallon capacity, tank #16. Lube oil vents. Associated with the Crystal River Site: Equipment diesel tanks, E.O.F. #01, capacity of 2,000 gallons and E.O.F. # 02, capacity of 25 gallons. Waste oil tank, Garage # 01, 150 gallon capacity. Mineral spirits tanks, O.C. # 01, 80 gallon capacity, N. Sub. # 04, 1,100 gallon capacity. Transmission oil tanks, N. Sub. # 01 through 03, capacity of 1,100 gallons each. UST for diesel-2 @ 10,000 gallons each and one @ 20,000 gal UST for gasoline - 1 @ 10,000 gallons

2. This unregulated emissions unit consists of the following facilities:

Associated with Units 1, 2, 4 and 5: Water treatment systems for all EUSGUs. Sewage treatment plant. Lime storage.

3. These engines meet the 40 CFR 63, Subpart ZZZZ definition of "existing units", there are no unit specific applicable requirements that must be met pursuant to this rule at this time.

Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page U-1 of 1

ATTACHMENTS (INCLUDED FOR CONVENIENCE) The following attachments are included for convenient reference: Figure 1, Summary Report-Gaseous and Opacity Excess Emission and Monitoring System Performance (40 CFR 60, July, 1996). Table H, Permit Summary. Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal

FIGURE 1--

SUMMARY

REPORT--GASEOUS AND OPACITY EXCESS EMISSION AND MONITORING SYSTEM PERFORMANCE (INCLUDED FOR CONVENIENCE) [Note: This form is referenced in 40 CFR 60.7, Subpart A-General Provisions] Pollutant (Circle One): SO 2 NO, TRS H2 S CO Opacity Reporting period dates: From to Company: Emission Limitation: Address: Monitor Manufacturer: Model No.: Date of Latest CMS Certification or Audit: Process Unit(s)

Description:

Total source operating time in reporting period 1: Emission data summary 1 CMS performance summary1

1. Duration of excess emissions in reporting period due to: 1. CMS downtime in reporting period due to:
a. Startup/shutdow n ................................................. a. Monitor equipment malfunctions ......................... .
b. Control equipment problems ............................... b. Non-Monitor equipment malfunctions ................
c. Process problem s ................................................. c. Quality assurance calibration ............................... .
d. O ther know n causes ............................................ d. O ther know n causes .............................................
e. U nknow n causes .................................................. e. U nknow n causes ..................................................
2. Total duration of excess emissions ....................... 2. Total CM S D owntim e ..........................................
3. Total duration of excess emissions x (100) / [Total 3. [Total CMS Downtime] x (100) / [Total source source operating time] ...........................................  % operating tim e] ................................................ . ..... %2 2

I 2 For For opacity, recordperiod: the reporting all timesIf the in total minutes. durationFor gases, record of excess all timesis in emissions hours. or greater of the total operating time or 1 percent the total CMS downtime is 5 percent or greater of the total operating time, both the summary report form and the excess emission report described in 40 CFR 60.7(c) shall be submitted. Note: On a separatepage, describe any changes since last quarter in CMS, process or controls. I certify that the information contained in this report is true, accurate, and complete. Name: Signature: Date: Title: Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal

TABLE H PERMIT HISTORY E.U. Issue Expiration Extended Revised ID No. Description Permit No. Date Date Date Date(s) 001 Unit 1 AO 09-169341 12/20/89 12/18/94 2/11/94 2/6/97 6/30/99 002 Unit 2 AO 09-191820 5/21/91 5/21/96 6/24/91 2/11/94 2/6/97 6/30/99 001 & Units I and 2 0170004-002-AO 9/16/96 002 Used Oil Firing (Mod. of above permits) 004, 003, Units 4 & 5, & Cooling Towers for 4 & 5 PSD Permit 3/30/78 11/30/88 015 PSD-FL-007 2/27/80 004, Power Plant Siting Certification, Units 4 & 5 PA 77-09 11/21/78 2/22/80 003 (Incl. Limits on Sulfur for Units 1 & 2) 5/22/80 5/6/82 2/2/84 7/3/84 9/12/97 6/30/99 006, 008, 009, Units 1 & 2 Flyash Handling System (Sources 1, 4 &5) AC 09-184438 11/9/90 10/31/91 010 AC 09-256791 11/17/94 01/15/96 (Replaced AC 09-184438) 008 Units 1 & 2 Flyash Transfer Silo (Source 3) AO 09-193593 3/26/91 10/31/91 006,008,009, Units 1 & 2 Flyash Handling System (Sources 1, 3, 4 & 5) AO 09-202440 11/8/91 10/31/96 010 014 Units 1 & 2 Bottom/Economizer Ash Handling System AC 09-235915 10/4/93 6/1/94 014 Units 1 & 2 Bottom Ash Handling AO 09-248541 7/21/94 7/15/99 012 Diesel Generators AO 09-205952 4/27/92 3/31/97 013 Four Helper Cooling Towers AC 09-162037 & PSD- 8/29/90 10/1/93 12/1/93 FL-139 013 Four Helper Cooling Towers AO 09-236827 10/20/93 10/1/98 All Initial Title V Permit 0170004-004-AV 01/01/00 12/31/04 3/29/01 All Title V Renewal 0170004-009-AV 01/01/04 12/31/09 020 New Cooling Tower 0170004-010-AC 04/03/06 04/30/07 Title V Revision to Include Cooling Tower 0170004-011-AV 06/09/06 12/31/09 Trial Burn of PRB Coal 0170004-012-AC 04/26/06 05/01/07 003,004 SCR project on Units 4 and 5 0170004-013-AC 03/02/07 03/02/10 016 Coal Yard Modification 0170004-014-AC 12/15/06 06/30/08 016 Title V Revision to Include Coal Yard Modification 0170004-015-AV 02/22/07 12/31/09 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page H- I of 2

TABLE H PERMIT HISTORY E.U. Issue Expiration Extended Revised ID No. Description Permit No. Date Date Date Date(s) 003, 004 FGD Project Units 4 and 5 0170004-016-AC 05/18/07 11/01/11 001 -004 BART Project 0170004-017-AC 02/26/09 07/01/14 013,027 Unit 3 Uprate Cooling Tower 0170004-018-AC 10/12/07 10/12/12 003, 004 Units 4 and 5 Control Project 0170004-019-AC 02/26/09 11/01/11 001-004 Title V CAIR Revision 0170004-020-AC 01/30/09 12/31/09 003, 004 Units 4 and 5 Upgrades 0170004-022-AC 05/11/09 11/01/11 003,004 Revisions for Alkali Injection on Units 4 and 5 0170004-023-AC All Title V Renewal 0170004-024-AV 01/01/10 12/31/14 ID Number Changes (for tracking purposes): From: Facility ID No.: 09TPA0004 To: Facility ID No.: 0170004 Progress Energy Florida, Inc. Permit No. 0170004-024-AV Crystal River Power Plant Title V Permit Renewal Page H-2 of 2

U. S. Nuclear Regulatory Commission Response to 3F0410-04 Request for Documents RAI 3-1 Crystal River Mariculture Center Juvenile Releases

PROGRESS ENERGY CRYSTAL RIVER MARICULTURE CENTER FINGERLING/JUVENILE RELEASE

SUMMARY

RED RED DRUM SPOTTED SPO EDSTRIPED YEAR SEATROUT DR U M_ _ L A R V A E_ T R O UT_ LA VAEA PINK SHRIMP LARVAE _M U _ L _ LE_ T_ _ __ PIGFISH _ __ __ SILVER PERCH STONE CRAB _ __ BLUE CRAB _ _ _ _ __ 1992 17,519 0 0 0 0 0 0 0 0 0 1993 169,165 0 6,908 0 0 0 0 0 0 0 1994 12,204 0 55,304 0 0 0 0 0 0 0 1995 26,900 0 60,189 0 12,000 0 0 0 0 0 1996 50,795 0 32,994 0 7,750 0 0 0 0 0 1997 0 0 0 0 0 pond trials 0 0 0 0 1998 157,833 800,000 171,350 425,000 0 pond trials 0 0 0 0 1999 67,227 575,500 40,536 290,000 34,541 25,000 first feeding 0 0 0 0 larvae controlled spawning/I ,300,000 2000 285,366 0 11,000 0 9,839 0 first feeding 0 0 0 larvae/pond trial (none released) 2001 16,251 0 130 0 91,079 indoor culture 0 0 0 0 controlled 2002 4,070 0 250,054 0 36,934 indoor culture 0 spawning/pond trial 0 0 1 _(none released) 2003 125,064 0 163,200 0 49755 500,000 first 0 39,942 first feeding 692,000 zoea stage I controlled spawning and feeding larvae larvae pond trial (none released) 2004 15,000 0 16,500 0 0 0 0 0 4,000,000 Zoea I 35,000,000 Zoea I 2005 0 0 4,768 0 87,374 0 0 0 8,767,055 Zoea I 31,447,656 Zoea I 2006 0 0 81,700 0 42,830 0 0 0 14,851,847 Zoea 1 15,475,245 Zoea 1 2007 0 0 70,000 0 43,000 0 0 0 4,729,060 Zoea 1 11,823,380 Zoea 1 2008 0 0 75,180 0 0 0 0 0 0 0 2009 0 0 92,000 0 0 0 0 0 0 0 'Totals 947,394 1,375.500 1,131,813 715,00 415,02 525,000 first 39,942 first feeding 32,347,962 zoea 93,746,281 Z1 t feeding larvae 0 larvae stage I

U. S. Nuclear Regulatory Commission Response to 3F0410-04 Request for Documents RAI 3-2 & RAI 5-1 Env Support Document Crystal River Unit 3 South Cooling Tower Laydown Area, Citrus County, Florida}}

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