RS-17-011, License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications
| ML17055A631 | |
| Person / Time | |
|---|---|
| Site: | Byron, Braidwood  |
| Issue date: | 02/23/2017 |
| From: | Gullott D Exelon Generation Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| RS-17-011 | |
| Download: ML17055A631 (81) | |
Text
{{#Wiki_filter:4300 Winfield Road Warrenville, IL 60555 A..- Exelon Generation 630 657 2000 office RS-17-011 10 CFR 50.90 February 23, 2017 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-001 Braidwood Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. 50-456 and 50-457 Byron Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. 50-454 and 50-455
Subject:
License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Exelon Generation Company, LLC (EGC) requests amendments to Renewed Facility Operating License Nos. NPF-72 and NPF-77 for Braidwood Station, Units 1 and 2, and Renewed Facility Operating License Nos. NPF-37 and NPF-66 for Byron Station, Units 1 and 2. The proposed amendment removes time, cycle, or modification-related items from the Operating Licenses (OLs) and Technical Specifications (TS). Additionally, the proposed amendment makes editorial and formatting changes. The time, cycle, or modification-related items have been implemented or superseded, are no longer applicable, and no longer need to be maintained in their associated OLs or TS. Attachment 1 provides an evaluation of the proposed change. Attachments 2 and 3 provide the existing TS pages marked up to show the proposed changes. Attachments 4 and 5 provide the existing TS Bases pages marked up to show the proposed changes. The proposed Bases changes are provided for information only. EGC requests approval of the proposed license amendment by February 23, 2018. Once approved, the amendment shall be implemented within 30 days. The proposed changes have been reviewed and approved by the Braidwood Station and Byron Station Plant Operations Review Committees in accordance with the requirements of the EGC Quality Assurance Program.
February 23, 2017 U.S. Nuclear Regulatory Commission Page 2 In accordance with 10 CFR 50.91, "Notice for public comment; State consultation," paragraph (b), EGC is notifying the State of Illinois of this application for license amendment by transmitting a copy of this application, with attachments, to the designated Illinois Official. There are no regulatory commitments contained within this letter. Should you have any questions concerning this letter, please contact Ryan Sprengel at (630) 657-2814. 1 declare under penalty of perjury that the foregoing is true and correct. Executed on the 23rd day of February 2017. Respectfully, David M. Gullott Manager Licensing Exelon Generation Company, LLC Attachments:
- 1. Evaluation of Proposed Changes
- 2. Proposed Technical Specification Changes for Braidwood Station, Units 1 and 2
- 3. Proposed Technical Specification Changes for Byron Station, Units 1 and 2
- 4. Proposed Technical Specification Bases Changes for Braidwood Station, Units 1 and 2
- 5. Proposed Technical Specification Bases Changes for Byron Station, Units 1 and 2 cc: NRC Regional Administrator, Region III, USNRC NRC Senior Resident Inspector Braidwood Station NRC Senior Resident Inspector Byron Station Illinois Emergency Management Agency Division of Nuclear Safety
ATTACHMENT 1 Evaluation of Proposed Changes
Subject:
License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications 1.0
SUMMARY
DESCRIPTION 2.0 DETAILED DESCRIPTION 2.1 REASON FOR THE PROPOSED CHANGES
2.2 DESCRIPTION
OF PROPOSED OPERATING LICENSE CONDITION DELETIONS
2.3 DESCRIPTION
OF PROPOSED TECHNICAL SPECIFICATION CHANGES
2.4 DESCRIPTION
OF PROPOSED EDITORIAL AND FORMATTING CHANGES
3.0 TECHNICAL EVALUATION
4.0 REGULATORY EVALUATION
4.1 APPLICABLE REGULATORY REQUIREMENTS/CRITERIA 4.2 NO SIGNIFICANT HAZARDS CONSIDERATION DETERMINATION
4.3 CONCLUSION
S
5.0 ENVIRONMENTAL CONSIDERATION
6.0 REFERENCES
Page 1 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications 1.0
SUMMARY
DESCRIPTION In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Exelon Generation Company, LLC (EGC) requests amendments to Renewed Facility Operating License Nos. NPF-72 and NPF-77 for Braidwood Station, Units 1 and 2, and Renewed Facility Operating License Nos. NPF-37 and NPF-66 for Byron Station, Units 1 and 2. The proposed amendment removes time, cycle, or modification-related items from the Operating Licenses (OLs) and Technical Specifications (TS). The time, cycle, or modification-related items have been implemented or superseded, are no longer applicable, and no longer need to be maintained in their associated OLs or TS. Additionally, the proposed amendment makes editorial and formatting changes. Specifically, the proposed amendment deletes obsolete License Conditions related to first performances of associated Control Room Envelope (CRE) habitability surveillance, assessment and measurement tests for both Braidwood Station and Byron Station. The other License Condition proposed for deletion includes removal of TS associated with AREVA NP Inc. (AREVA NP) fuel for Braidwood Station, Unit 1 only. The License Conditions proposed for deletion pertain to actions or dates that have been completed and are no longer applicable. Further, the proposed amendment deletes text tied to completed refueling outages, system outages, or operating cycles and are no longer needed. 2.0 DETAILED DESCRIPTION 2.1 Reason for the Proposed Changes The proposed changes are meant to remove time, cycle, or modification-related items from the OLs and TS. These items have been implemented or superseded, are no longer applicable, and no longer need to be maintained in their associated OLs or TS. With each proposed change, other than changes editorial in nature, associated evidence is identified to support the implementation as appropriate. Historically, conditions, exceptions, or exemptions that are date, cycle, or modification-related have been captured in the OLs or TS. Over time, the actions or requirements that these items prescribe are implemented, and the issues no longer need to be reflected in the OLs or TS. In an effort to clarify, and avoid any confusion regarding the current requirements contained in the OL or TS, EGC is proposing the administrative removal of these items from the OLs and the TS for Braidwood Station and Byron Station. In addition, a review was performed to identify inconsistencies in format within the Braidwood Station and Byron Station TS. The review utilized the improved Standard Technical Specifications (STS), Revision 1 (Reference 1) and the Writer's Guide for Plant-Specific Improved Technical Specifications (WG), TSTF-GG-05-01 (Reference 2). STS Revision 1 is the basis for TS format for Braidwood Station and Byron Station. The WG utilized for the review incorporates updates since STS Revision 1, but also describes the STS Revision 1 format. The existing format, using STS Revision 1, will not be changed. The results of these reviews were used as input for the proposed editorial and formatting changes. A complete listing of all proposed changes is provided in Table 2-1. Page 2 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications 2.2 Description of Proposed Operating License Condition Deletions Braidwood Station, Unit 1 Item ID 1, Table 2-1. Appendix C, page 1. Revise, "Additional Condition," removing text related to operation during Cycles 15, 16, and 17 with AREVA NP fuel. The proposed text to delete is as follows: During operation in Cycles 15, 16, and 17, up to eight (8) AREVA NP Advanced Mark-BW(A) fuel assemblies containing fuel pellets incorporating homogeneous poisons may be placed in nonlimiting Unit 1 core locations provided the fuel cycle designs are developed such that the TS 2.1.1.3 Safety Limit equation for Westinghouse fuel is bounding. The design basis for the AREVA NP fuel rod centerline melt follows that given in BAW-1 01 62P-A, "TACO3-Fuel Pin Thermal Analysis Computer Code," October 1989, and BAW-10184P-A, "GDTACO-Urania Gadolinia Fuel Pin Thermal Analysis Code," February 1995. Cycles 15, 16, and 17 are complete for Braidwood Station, Unit 1; therefore, this OL Condition is no longer required and can be removed from this section of the OL. Braidwood Station, Unit 1 and 2 Item ID 2, Table 2-1. Appendix C, page 2. Delete Braidwood Station Units 1 and 2 OL Conditions (Amendment 146). The first performances of the associated CRE habitability surveillance, assessment and measurement are complete, see Table 2-2. Successive performances of the surveillances, assessments, and measurements will follow the respective frequencies identified in TS 5.5.18.c and 5.5.18.d. With the first performances complete for Braidwood Station, Units 1 and 2, these OL Conditions are no longer required and can be removed from this section of the OLs. Byron Station, Units 1 and 2 Item ID 3, Table 2-1. Appendix C, page 2. Delete Byron Station Units 1 and 2 OL Conditions (Amendment 151). The first performances of the associated CRE habitability surveillance, assessment and measurement are complete, see Table 2-2. Successive performances of the surveillances, assessments, and measurements will follow the respective frequencies identified in TS 5.5.18.c and 5.5.18.d. With the first performances complete for Byron Station, Units 1 and 2, these OL Conditions are no longer required and can be removed from this section of the OLs. 2.3 Description of Proposed Technical Specification Changes Item ID 5, Table 2-1. Braidwood Station Unit 1 TS, page 2.0-1. Delete Safety Limits (SLs) 2.1.1.3.b and 2.1.1.3.c. AREVA NP fuel is no longer in the core (Braidwood Station Unit 1) and will not be reinserted into the core. This item is tied to Item ID 1 discussed previously, proposed for removal as Cycles 15, 16, and 17 are complete for Braidwood Station, Unit 1, therefore, this SL text is no longer required and can be removed. Associated editorial change to remove sub-item "a." break-out and make consistent with Byron Station TS. With AREVA NP fuel no longer Page 3 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications utilized by Braidwood Station Unit 1, these SLs are no longer required and can be removed from this section of the TS. Item ID 14, Table 2-1. Byron Station TS, pages 3.7.8-1 and 3.7.8-2. Delete the NOTE for CONDITION A, delete current CONDITION B in entirety, renumber CONDITIONs C and D to B and C respectively, and modify CONDITION C text to reference "A or B" vs. "A, B or C." Byron Station refueling outage 15 is complete, therefore, the NOTE and CONDITION B is no longer required and can be removed from this section of the TS. Corresponding TS Bases changes, Item ID 28, are provided for information and approval of the Bases is not requested. Item ID 15, Table 2-1. Braidwood Station TS, pages 3.7.8-(all). Re-unite the Unit 1 and 2 TS pages, resulting in removal of changes implemented for a one-time 2A SX pump repair. The Braidwood Station Unit 2 planned SX System outage is complete, and the complete-by date of January 23, 2017 is passed making the changed implemented for the one-time 2A SX pump repair obsolete. Only proposed changes to the current Braidwood Station Unit 1 TS are to the footer identifying Units 1 & 2. Corresponding TS Bases changes, Item ID 27, are provided for information and approval of the Bases is not requested. Item ID 22, Table 2-1. Braidwood Station TS, page 4.0-1. Revise the second sentence of 4.2.1, to remove ", with exceptions as noted below, ". Also, delete the second paragraph of 4.2.1. AREVA NP fuel is no longer in the core (Braidwood Station Unit 1) and will not be reinserted into the core. This item is tied to Item IDs 1 and 5 discussed previously, proposed for removal as Cycles 15, 16, and 17 are complete for Braidwood Station, Unit 1, therefore, this SL text is no longer required and can be removed. Item ID 26, Table 2-1. Byron Station TS and Braidwood Station TS, page 5.5-21. Delete ", as modified by the following exceptions:" at the end of the first paragraph. Also, delete exceptions 1 and 2. The Type A tests have been completed, and the performance dates have passed, making this text obsolete. See Table 2-3 for the Type A test performance dates. 2.4 Description of Proposed Editorial and Formatting Changes Table 2-1 identifies all changes including editorial and formatting changes and changes previously identified. The basis for the editorial and formatting changes is sourced from one or more of the following: STS Revision 1, WG, consistency within or among the respective station TS, or guidance from within the TS (e.g., Section 1.2 of TS). The editorial and formatting changes not previously identified, and with no additional discussion other than Table 2-1, are: Item IDs 4, 6-13, 16-21, and 23-25. Page 4 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications Table 2-1 Complete Listing of Proposed Changes Item ID_ _Page BYR BWD Description of Proposed Change Delete second half of the Braidwood Station Unit 1 License Condition (Amendment 145). AREVA NP fuel is no longer in OL the core (Braidwood Station, Unit 1) and not to be reinserted Appendix into the core. Cycles 15, 16, and 17 are complete 1 C-1 X Braidwood Station, Unit 1). Delete Braidwood Station Units 1 and 2 License Conditions (Amendment 146). License Amendment 146 has been OL implemented, and the first performances of the associated Appendix CRE habitability surveillances, assessments and 2 C-2 X measurements are complete. Delete Byron Station Units 1 and 2 License Conditions OL (Amendment 151). The first performances of the associated Appendix CRE habitability surveillances, assessments and 3 C-2 X measurements are complete. Replace current bottom single line with double line, one space below last text. From the STS Revision 1 (Reference 4 2.0-1 X X 1) and WG Reference 2. Delete Safety Limits (SLs) 2.1.1.3.b and 2.1.1.3.c. AREVA NP fuel is no longer in the core (Braidwood Station Unit 1) and not to be reinserted into the core. Remove sub-item "a." break-out and make consistent with 5 2.0-1 X Byron Station SLs. Replace current bottom single line with double line, one 6 3.0-4 X X space below last text. From STS and WG. Replace current bottom single line with double line, one 7 3.0-6 X X space below last text. From STS and WG. Delete the period "." at the end of SR 3.1.7.1 FREQUENCY. 8 3.1.7-2 X X From WG. Delete "(continued)" following SURVEILLANCE REQUIREMENTS as "(continued)" following SR 3.3.1.8, only, 9 3.3.1-13 X is appropriate. From STS and WG. Delete "(continued)" following SURVEILLANCE REQUIREMENTS as "(continued)" following SR 3.3.1.8, only, 10 3.3.1-14 X is appro riate. From STS and WG. Add header at top of page "CONDITION, REQUIRED 11 3.4.15-3 X X ACTION, COMPLETION TIME". From STS and WG. Add "(continued)" below the table on the bottom right to 12 3.7.1-1 X X indicate continuation of table. From STS and WG. Add header at top of page "CONDITION, REQUIRED 13 3.7.1-2 X ACTION, COMPLETION TIME". From STS and WG. Page 5 of 9
ATTACHMENT Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications Item ID Page BYR BWD Description of Proposed Change Delete the NOTE for CONDITION A, Byron refueling outage 15 for Unit 2 is complete. Delete current CONDITION B in entirety, Byron refueling outage 15 for Unit 2 is complete. Renumber CONDITIONs C and D to B and C respectively. 3.7.8-1 Modify new CONDITION C to reference "A or B" vs. "A, B or 14 3.7.8-2 X C" due to deleting CONDITION B. Re-unite TS pages for Braidwood Station Units 1 and 2. Remove 2A SX changes, by deleting Braidwood Station Unit 2 specific pages. Current Unit 1 pages to become Units 1 15 3.7.8-(all) X and 2. Change left tab formatting of CONDITION C, left justify "AND" with the statement of the Condition. From Byron TS 16 3.7.9-2 X 1.2, Logical Connectors, sub-section BACKGROUND. Change left tab formatting of CONDITION E, left justify "OR" with the statement of the Condition. From Byron and Braidwood TS 1.2, Logical Connectors, sub-section 17 3.7.10-3 X X BACKGROUND. Delete the period "." at the end of SR 3.7.10.4 FREQUENCY. 18 3.7.10-4 X_ _ From WG. _ Add header at top of page "CONDITION, REQUIRED 19 3.8.4-2 X X ACTION, COMPLETION TIME". From STS and WG. Delete "(continued)" following ACTIONS as "(continued)" following CONDITION A., only, is appropriate. From STS 20 3.8.5-2 X X and WG. Delete "(continued)" following ACTIONS as "(continued)" following CONDITION A., only, is appropriate. From STS 21 3.8.8-2 X and WG. Revise 4.2.1, second sentence, remove ', with exceptions as noted below, '. Delete the second paragraph in 4.2.1, AREVA NP fuel is no longer in the core (Braidwood Station Unit 1) and not to be reinserted into the core (related to TS 2.1.1.3). Cycles 15, 16, and 17 are complete (Braidwood 22 4.0-1 X Station, Unit 1). Change heading to "4.0 DESIGN FEATURES". Note, delete
"(continued)" because section concluded on prior page.
23 4.0-2 X X From STS and WG. Replace current bottom single line with double line, one space below last text. Note, Byron Station TS current page 24 4.0-2 X X 4.0-3, see next item. From STS and WG. Roll page 4.0-3 (section 4.3.2 and 4.3.3) to 4.0-2, delete page 4.0-3. For consistency between Byron and Braidwood 25 4.0-3 X Stations TS. Page 6 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications Item ID Page BYR BWD Descri tion of Proposed Change Delete', as modified by the following exceptions:' at the end of the first paragraph. Delete exception 1 and 2. Allowance 26 5.5-21 X X for 15 year periodicity of Type A tests has passed. Re-unite Braidwood Station Units 1 and 2 pages in Bases B 3.7.8 3.7.8, removing changes due to 2A SX repairs. Delete Unit 2 27 all X only bases pages. See item ID 12. Remove Byron Station Bases 3.7.8 text tied to the B 3.7.8-4, corresponding TS changes in 3.7.8. Byron refueling outage 28 5 X 15 for Unit 2 is complete. See item ID 11. Table 2-2 CRE Habitability Completion S ecification Byron Com letion Date Braidwood Com letion Date 5.5.18.c. i 1/16/2009 1/9/2009 5.5.18.c.(ii) _ 4/3/2012 211112011 5.5.18.d Train A 6/26/2008 7/27/2008 5.5.18.d Train B 8/7/2008 7/26/2008 Table 2-3 Tvne A Test Performance Dates Station/Unit Performance Date Byron Station Unit 1 9/27/2012 Byron Station Unit 2 9/26/2014 Braidwood Station Unit 1 9/27/2013 Braidwood Station Unit-2 5/13/2014
3.0 TECHNICAL EVALUATION
All proposed changes are administrative in nature and require no technical analysis.
4.0 REGULATORY EVALUATION
4.1 Applicable Regulatory Requirements/Criteria 10 CFR 50.36 details the information that must be included in each station's TS. The proposed changes modify or delete time, cycle, or modification-related items that have been implemented or superseded, and are no longer applicable. The proposed changes have no impact on current Safety Limits, Limiting Safety System Settings, Limiting Control Settings, Limiting Conditions for Operation, Surveillance Requirements, Design Features, or Administrative Controls. Therefore, EGC concludes that the methods used to comply with 10 CFR 50.36 are not modified by the proposed changes, and the requirements continue to be met. 4.2 No Significant Hazards Determination In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," EGC is requesting amendments to OL Nos. NPF-72 and NPF-77 for Braidwood Station, Units 1 and 2, and OL Nos. NPF-37 and NPF-66 for Byron Station, Units 1 Page 7 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications and 2. The proposed amendments provide for the administrative removal of time, cycle, or modification-related items from the OLs at both stations. These items have been implemented or superseded, are no longer applicable, and therefore, no longer need to be maintained in their associated OL. Additionally, the proposed amendment makes editorial and formatting changes. EGC has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:
- 1. Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?
Response: No The initial conditions and methodologies used in the accident analyses remain unchanged. The proposed changes do not change or alter the design assumptions for the systems or components used to mitigate the consequences of an accident. Therefore, accident analyses results are not impacted. All changes proposed by EGC in this amendment request are administrative in nature, and are removing one-time requirements that have been satisfied, items that are no longer applicable, or are editorial. There are no physical changes to the facilities, nor any changes to the station operating procedures, limiting conditions for operation, or limiting safety system settings. Therefore, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.
- 2. Does the proposed amendment create the possibility of a new or different kind of accident from any previously evaluated?
Response: No None of the proposed changes affect the design or operation of any system, structure, or component in the plants. The safety functions of the related structures, systems, or components are not changed in any manner, nor is the reliability of any structure, system, or component reduced by the revised surveillance or testing requirements. The changes do not affect the manner by which the facility is operated and do not change any facility design feature, structure, system, or component. No new or different type of equipment will be installed. Since there is no change to the facility or operating procedures, and the safety functions and reliability of structures, systems, or components are not affected, the proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated. Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any previously evaluated. Page 8 of 9
ATTACHMENT 1 Evaluation of Proposed Changes License Amendment Request to Delete Obsolete License Conditions and Revise Technical Specifications
- 3. Does the proposed amendment involve a significant reduction in a margin of safety?
Response: No The proposed changes are administrative in nature and have no impact on the margin of safety of any of the TS. There is no impact on safety limits or limiting safety system settings. The changes do not affect any plant safety parameters or setpoints. The OL Conditions have been satisfied as required. Therefore, the proposed changes do not involve a significant reduction in a margin of safety. Based on the above, EGC concludes that the proposed changes do not involve a significant hazards consideration as set forth in 10 CFR 50.92(c), "Issuance of Amendment." 4.3 Conclusions In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.
5.0 ENVIRONMENTAL CONSIDERATION
The proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). The proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.
6.0 REFERENCES
NUREG-1431, "Standard Technical Specifications for Westinghouse Plants," Revision 1, dated April 1995. (N RC ADAMS Accession No. ML13196A405)
- 2. TSTF-GG-05-01, "Writer's Guide for Plant-Specific Improved Technical Specifications,"
Revision 1, dated August 2010. Page 9 of 9
ATTACHMENT Proposed Technical Specification Changes for Braidwood Station, Units 1 and 2
APPENDIX C ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-72 The licensee shall comply with the following conditions on the schedules noted below; Amendment Implementation Number Additional Condition Date 145 The safety limit equation specified in TS 2.1.1.3 With imple-regarding fuel centerline melt temperature (i.e., less mentation of than 5080 °F, decreasing by 58 °F per 10,000 the amend-MWD/MTU burnup as described in WCAP-12610-P-A, ment "VANTAGE+ Fuel Assembly Reference Core Report," April 1995) is valid for uranium oxide fuel without the presence of poisons mixed homogeneously into the fuel pellets. If fuel pellets incorporating homogeneous y Item ID - 1 poisons are used, the topical report documenting the fuel centerline melt temperature basis must be reviewed and approved by the NRC and referenced in this license condition. TS 2.1.1.3 must be modified to also include the fuel centerline melt temperature limit for the fuel with homogeneous poison. During opereltion-in-Cycles 15, 1-6,-anda~up--to-eight-($)-AREVA NP Advanced Mark-- BW(-A-)-fuel-assemblies-containing fuel pellets incorpor-acing-homogeneous poisons may be placed in
)-ion 41-1 liting-Unit- 1-core Io cetio^s-provided the-fuel cycle designs are-developcd such that-the-TS-2-.1.1-.L-3-Safety '
Limit equaltion for t"Jes'tingheuse fuel is- bounding- The
.~`
~."jigil
((.,, basis f^r tife AREV~ A ~1,1P fuel rod centarll ne 0 1 11 f II0jvv, that glv,an In SAW-101 v2P A~"TA~i0.'.~ Fuel PIn Ti cr iiiul r~-ii,a"'ll j/sls FL'rpiiiI-COdC,"-OCtFZb2r 1111801, and B0AIN-10184P-A, "GDTACOUrania Gadolinia Fuel Pin Therr rul ^ nalysis Code," February 11-1911105. AMENDMENT NO. , 60
Item I D - 2 3 ADDITIONAL GONDITIQN5 FAC11,ITY QPERATINC OUNSE NO. F-7 he licensee Shall comply with the following conditions oii the schedules nola Amendment IM Number Date 146 Upon implementation of Amendment No. 146 adopting With imple-TSTF448, Revision 3, the determination of control room mentation of the
,envelope (CRE) unfiltered air inleakage as required by amendment SR 3.7.10.4, in accordance with TS 5.5.18.c.(I), the assessment of CRE habitability as required by Spec;ticaticn 5.5.18.c.(ii), and the measurement 0 CRE pressue as required by Spedficatlon 5.5.18.d, hall be consider d'met. Following Implementation:
(a) The rst performance of SR 3.7.110.4, in accordance with Specification 5, a.18.c.(i), shall be withiri.the specified Fre7.2004.of 6 years, plus the 1 L-month attowanf SR 3.0.2, as measured frorn November the date of the most recent successful tracer gas test, as stated in the Feb*uary t, 2005 letter response to Generic Letter 2M3-J1, or within the nexQ 16 months if the time ablod since the most recent successful tracer "gas test Is greater than 6 years. (b) The first performance of the 'perdodic assessmant of CRE habitability, Specification shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as r6aasured from November 7, 2004, the date of the m~ntst recent s%iccessful tracer gas test, as stated Iri he February 7, 2005 fetter response to Ger"ric Letter 2003-01, or within the next !9 months if the time period since- the most recent successful tracer gas test is greater than 3 years. (c) The first performance of the periodic measurement of CRE pressure, Spectfication 5.5.18A shag be within 18 months, plus the 138 days allowed by SR 3.0.2, as measured from the date of the most recent* successful pressure measurement test, or within 138 days if not performed previously. AM
_ -Al ADQITIONAt, -QONQ,ITIQNS FACILITY OPeRATING 10ENS _E, NQ. NPF-77 The licensee shall comply with the following conditions on the schedules noted below_ Amerxfniant ImOementauon Nor Addhignal Coditktn mate 146 Upon l~nptementatbn of Amendment No. 146 adopting Pti With imPle-TSTF-448, Revision 3. the detaffnination-or control roam mentatlon of the envelope (CRE) unuttered air Inteakage as requW by amendment
`,SR 3.7.10.4, In accordance with TS 5.5.18.c(l), the ai aseasment of CRE habltablilty as required by Sp~ritketion 5.5.18.c.(1). and the measurement pi CRE pressure as required by Specification 5.5.18.d,shall be aVna -met. Folbwing Implemantatbn:
(a) first perkwunce of SR-3.7.140.4' in accoldencs with Specification 5:5.18.c. ft sha8 be w" the specified Frequency of 6 years, plus Me 10-,month allowanf-,e of SR 3.0.2, as measured fi-om November 7. 2004. the date of the most recent succesdful tracer gas test. as stated in the Fehruarv"7. 2005 letter response to Generic Letter 20.'1<AI . or within the next 18 months If the ttrrtie.., pertod skide the most recent succenfW tracer gas test Is greater than 6 years. (b) The f d padomonce of the, periodic . assessrient of CRE habitabdity. Specification 5.5.1, 7c.(U), shag be within 3 years, plus the 9-mor'~th allowance of SR 3.0.20 as i!tieasured from Wivernber 7. 2004, the date of the most recent ucce sfuI tracer gat test, as statdd'hs h6 Febivary 7, 2Q05 letter response to Generic Letter 2003-01, or within the next 9 monCi If the lime period skve the most recent successful. tracer gas teat is greater then 3 years. (c) The first performance of the periodic measurement of CRE pressure, Specfication 5.5.18.d; shall be within IS months, plus the 138 days allowed by SR 3.0.2, as measured from the date of the most recent successful pressure measurement lest, or within 138 days R not performed previously. AMENDMENT NO, 160
SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded. 2.1.1.1 In MODE 1, the Departure from Nucleate Boiling Ratio (DNBR) shall be maintained >_ 1.24 for the WRB-2 DNB correlation for a thimble cell, >_ 1.25 for the WRB-2 DNB correlation for a typical cell and >_ 1.19 for the ABB-NV DNB correlation for a thimble cell and a typical cell. 2.1.1.2 In MODE 2, the DNBR shall be maintained >_ 1.17 for the WRB-2 DNB correlation, and >_ 1.13 for the ABB-NV DNB correlation and >_ 1.18 for the WLOP DNB correlation. =tem D 5 ---~ 2.1.1.3 In MODES 1 and 2, the peak fuel centerline temperature shall be maintained a sf-e~-A-e*s-:-
< 5080°F decreasing by 58°F per 10,000 MWD/MTU burnup Fnv l,ln~f i use f in1 A f'y f rNT O * ,* * * :
- NEW MUM r ..
- i 11 W
11
- Mai
*r orLa yWWWe I 2.1.2 RCS Pressure SL In MODES 1, 21 3, 4, and 5, the RCS pressure shall be maintained
<_ 2735 psig.
2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour. 2.2.2 If SL 2.1.2 is violated: Item ID-4 2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour. 2.2.2 I X compliance wi Vw~
i.CO Appl i cabi 1 -i ty 3.0 3.0 LCO Applicability LCO 3.0.7 Exception LCOs allow specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Exception LCOs is optional. When an Exception LCO is desired to be met but is not met, the ACTIONS of the Exception LCO shall be met. When an Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications. LCO 3.0.8 LCOs, including associated ACTIONs, shall apply to each unit individually, unless otherwise indicated. Whenever the LCO refers to a system or component that is shared by both units, the ACTIONs will apply to both units simultaneously.
SR Applicability 3.0 3.0 SR APPLICABILITY SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement 'to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours and the risk impact shall be managed. If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4 This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. SR 3.0.5 SRs shall apply to each unit individually, unless otherwise indicated. BRAIDWOOD UNITS I & 2 3.0 6 Amendment 34
Rod Position Indication 3.1.7 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME C. One demand position C.1.1 Verify by Once per 8 hours indicator per bank administrative means inoperable for one or all DRPIs for the more banks. affected bank(s) are OPERABLE. AND C.1.2 Verify the most Once per 8 hours withdrawn rod and the least withdrawn rod of the affected bank(s) are _< 12 steps apart. OR C.2 Reduce THERMAL POWER 8 hours to _< 50% RTP. D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of Prior to the group demand position for the full criticality indicated range of rod travel. after each removal of the reactor head. Item ID - 8 BRAIDWOOD UNITS 1 & 2 3.1.7 2 Amendment-98
Item I D - 9 CIS .io~i 3.3.1 SURVEILLANCE REQUIREMENTS {conLinued4 SURVLI I I ANC f_R[ QUI NCY SR 3.3.1.8 (continued) In accordance with the Surveillance Frequency Control Program SR3.3.1.9 ------------------- NOTE -------------------- Verification of setpoint is not required. Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 ------------------- NOTE -------------------- This Surveillance shall include verification that the time constants are adjusted to the prescribed values. Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR3.3.1.11 ------------------- NOTE -------------------- Neutron detectors are excluded from CHANNEL CALIBRATION. Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued) BRAIDWOOD UNITS 1 & 2 3.3.1 13 Amendment 7-1
'Ic'y y y -'I<- Item 11) .- 11 y Insert table header RCS Leakage Detection Instrumentation 3.4.15 Y (Condition, Required Action, Completion Time) _irX ~~otnu v I%<.,V1 IA i I %.0 r It. 1, 1 Vi i U ItA v. 1 uV I I I 11VVL .!. V 1 IUU1 J associated Compl et i on Time not met. AND D.2 Be in MODE 5. 36 hours E. All required monitors E.1 Enter LCO 3.0.3. Immediately inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance atmosphere radioactivity monitor. with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance containment sump monitor. with the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program BRAIDWOOD UNITS 1 & 2 3.4.15 3 Amendment 1-'a
MSSV, 3.7.1 3.7 PI ANT SYSTEMS 3.7.1 Main Steam Safely Valves (MSSVs) LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE. APPLICABILIIY: MODES 1, 2, and 3. ACTIONS
------------------------------------- NOTE -------------------- -----------------
Separate Condition entry is allowed for each MSSV. CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam A.1 Reduce THERMAL POWER 4 hours generators with one or to less than or equal more MSSVs inoperable. to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. AND A.2 ------- NOTE -------- Only required in Mode 1. Reduce the Power 36 hours Range Neutron Flux - High reactor trip setpoint to less than or equal to the Maximum Allowable RTP specified in Table 3.7.1-1 for she number of OPERABLE MSSVs. (continued) Item I D - 12 Insert'(continued)' BRA T DWOOD JNI-S & 2 3.7.1 1 Amendment 12-8
SX System 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Essential Service Water, (SX) System LCO 3.7.8 The following SX trains shall be OPERABLE:
- a. Two unit-specific SX trains; and
- b. One opposite-unit SX train for unit-specific support.
APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION I REQUIRED ACTION I COMPLETION TIME A. One unit-specific SX A.1 -------- NOTES -------- train inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources-Operating," for Emergency Diesel Generator made inoperable by SX.
- 2. Enter applicable Conditions and Required Actions of LCO 3.4.6 1 "RCS Loops-MODE 4," for Residual Heat Removal loops made inoperable by SX.
Restore unit-specific 72 hours SX train to OPERABLE status. (continued) Item ID - 15 Re-unite Units 1 and 2 pages BRAIDWOOD iE UNITS 1 & 2 3.7.8 1 Amendment -160-
SX System 3.7.8 ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME B. Opposite-unit SX train B.1 Restore opposite-unit 7 days inoperable. SX -train to OPERABLE status. C. Required Action and C.1 Be in MODE 3. 6 hours associated Completion Time of Condition A or AND B not met. C.2 Be in MODE 5. 36 hours Item ID - 15 Re-unite Units 1 and 2 pages BRAIDWOOD UNITS 1 & 2 3.7.8 2 Amendment GO-
SX System 3.7.8 SURVEILLANCE REQUIREMENTS SURVEI LLANCL I RI QULNCY SR3.7.8.1 ------------------- NOTE -------------------- Isolation of SX flow to individual components does not render the SX System inoperable. Verify each unit-specific SX manual, power In accordance operated, and automatic valve in the flow with the path servicing safety related equipment, Surveillance that is not locked, sealed, or otherwise Frequency secured in position, is in the correct Control Program position. SR3.7.8.2 ------------------- NOTE -------------------- Not required when opposite unit is in MODE 1 7 2, 3, or 4. Operate the opposite-unit SX pump for In accordance
>_ 15 minutes. with the Surveillance Frequency Control Program SR 3.7.8.3 Cycle each opposite-unit SX crosstie valve In accordance that is not secured in the open position with the with power removed. Surveillance Frequency Control Program SR 3.7.8.4 Verify each unit-specific SX automatic In accordance valve in the flow path that is not locked, with the sealed, or otherwise secured in position, Surveillance actuates to the correct position on an Frequency actual or simulated actuation signal. Control Program SR 3.7.8.5 Verify each unit-specific SX pump starts In accordance automatically on an actual or simulated with the actuation signal. Surveillance Frequency Control Program Item ID - 15 Re-unite Units 1 and 2 pages BRAIDWOOD UNITS 1 & 3.7.8 3 Amendment -16.5
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Item ID - 17 VC Filtration System Further indent 'OR' 3.7.10 ACTIONS (continued) CONDII- ION RI QUIRED ACTION COMPLETION TIME. E. two VC Filtration E.1 Suspend movement of Immediately System trains irradiated fuel inoperable in MODE 5 assemblies. or 6, or during movement of irradiated AND f e assemblies. E.2_ Suspend positive Immediately
-6f~- 01Z reactivity additions.
nr more VC Filtration System trains inoperable due Lo an inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies. F. Two VC Filtration F.1 Enter LCO 3.0.3. Immediately System trains inoperable in MODE 1, 29 3, or 4 for reasons other than Condition B. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each VC Filtration System train In accordance with: with the Surveillance
- a. Flow through the makeup system filters Frequency for >_ 15 continuous minutes with the Control Program heaters operating; and
- b. Flow through the recirculation charcoal adsorber for >_ 15 minutes.
(continued) BRAIDWOOD UNITS 1 & 2 3.7.10 3 Amendment 44 Item ID - 19 Insert table header DC Sources-Operating 3.8.4 (Condition, Required Action, Completion Time) 117 power division crosstie breaker crosstied to between the crosstied opposite-unit DC divisions. electrical power subsystem that has an inoperable battery charger, while opposite unit is in MODE 19 2, 3, or 4. C. One DC electrical C.1 --------- NOTE -------- power division Only required when crosstied to opposite unit has an opposite-unit DC inoperable battery. electrical power --------------------- subsystem with an inoperable source, Verify opposite-unit Once per while opposite unit is DC bus load 12 hours in MODE 5, 6, or _< 200 amps. defueled. AND C.2 Open at least one 7 days crosstie breaker between the crosstied divisions. D. One DC electrical D.1 Restore DC electrical 2 hours power subsystem power subsystem to inoperable for reasons OPERABLE status. other than Condition A l B, or C. E. Required Action and E.1 Be in MODE 3. 6 hours Associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours BRAIDWOOD UNITS 1 & 2 3.8.4 2 Amendment 4 Item ID - 20 DC Sources-Shiikhwri ACTIONS -E-Ee44nued CONDITION RI-QUIRE D ACTION COMPI FTION TIME A. (continued) A.M Suspend CORE Immediately ALTERATIONS. AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies. AND A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions. AND A.2.4 Initiate action to Immediately restore required DC electrical power subsystem to OPERABLE status. AND A.2.5 Declare affected Low Immediately Temperature Overpressure Protection feature(s) inoperable. (continued) BRAIDWOOD UNITS I & 2 3.8.5 2 Amendment 24
m ID ID - 21 Inverters-Shutdown G 3.8.8 ACTIONS ( enti nu d4 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Suspend CORE Immediately ALTERATIONS. AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies. AND A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions. AND A.2.4 Initiate action to Immediately restore required inverters to OPERABLE status. AND A.2.5 Declare affected Low Immediately Temperature Overpressure Protection feature(s) inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.8.8.1 verify correct inverter voltage and breaker In accordance alignment to required AC instrument buses. with the Surveillance Frequency Control Program BRAIDWOOD UNITS 1 & 2 3.8.8 2 Amendment 165"1-6
Design f eacures 4.0 4.0 DESIGN FEATURES 4.1 Site 4.1.1 Site Location The site is located in Reed Township, approximately 20 mi (32 km) south-southwest of the city of Joliet in northern Illinois. 4.1.2 Exclusion Area Boundary (EAB) The EAB shall not be less than 1591 ft (485 meters) from the outer containment wall. 4.1.3 Low Population Zone (LPZ) The LPZ shall be a 1.125 mi (1811 meter) radius measured from the Y--Y-- Item ID - 22 midpoint between the two reactors. 4.2 Reactor Core 4.2.1 Fuel Assembli The reactor shall contain 193 fuel assemblies. Each assembly,, Ada t-k~e~cc- apt an s-a-s--new-l-ebd ; s hall consist of a matrix of Zircaloy, ZIRLO°, or Optimized ZIRLO" clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods or vacancies for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.
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. . * . . . . C 4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control material shall be silver indium cadmium, hafnium, or a mixture of both types.
BRAIDWOOD UNITS 1 & 2 4.0 1 Amendment 9a
Y Y Y Y Y Y' Item ID - 23 Change heading Design Features 4.0 4.0 DESIGN FEATURES .KSIGN_FEATURES (cnnti_ } 4.3 Fuel Storage 4.3.1 Criticality The spent fuel storage racks are designed and shall be maintained, as applicable, with:
- a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;
- b. For Holtec spent fuel pool storage racks, k,,,., _< 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Holtec International Report HI-982094, "Criticality Analysis for Byron/Braidwood Rack Installation Project," Project No. 80944, 1998; C. For Holtec spent fuel pool storage racks, a nominal 10.888 inch north-south and 10.574 inch east-west center to center distance between fuel assemblies placed in Region 1 racks; and
- d. For Holtec spent fuel pool storage racks, a nominal 8.97 inch center to center distance between fuel assemblies placed in Region 2 racks.
4.3.2 Drainage The spent fuel pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 410 ft, 0 inches. 4.3.3 Capacity The spent fuel pool is designed and shall be maintained with a storage capacity limited to no more than 2984 fuel assemblies.
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.15 Safety Function Determination Program (SFDP) (continued) The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. 5.5.16 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, September 1995 and NL I 94-01, Revision 0, a-sm the fell et 'Y mlD It: 26
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s-hU 11beF'rfeir- ffl U nit yele 18 The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 42.8 psig for Unit 1 and 38.4 psig for Unit 2 The maximum allowable containment leakage rate, La, at Pa, shall be 0.20% of containment air weight per day. Leakage Rate acceptance criteria are:
- a. Containment leakage rate acceptance criterion is <_ 1.0 La.
During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are
< 0.60 La for the Type B and C tests and < 0.75 La for Type A tests; and BRAIDWOOD UNITS 1 & 2 5.5 21 Amendment 1~5-
ATTACHMENT Proposed Technical Specification Changes for Byron Station, Units 1 and 2
ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-37 T icensee shall comply with the following conditions on the schedules noted Amendme Implementation Number Additional Condition Date 151 Upon implementation of Amendment No. 151 With imple-adopting TSTF-448, Revision 3, the determination mentation of the of control room envelope (CRE) unfiltered air amendment i, leakage as required by SR 3.7.10.4, in / abpordance with TS 5.5.18.c.(i), the assessmep' of C14E habitability as required by Specification / 5.5.12 c.(ii), and the measurement of CRE,pressure as reg01~'red by Specification 5.5.18.d, sha f be consider met. Following implementatR (a) The first performance of SR 3'7.10.4, in accor8A~nce with Specification 5.5.18.c.0), shall be 'thin the specifi - Frequency of 6 years, plu the 18-mon allowance of SR 3.0.2, as me sured fr November 1, 2004, the date of the\most/recent successful tracer gas test, as state Yin the January 31, 2005 letter response t `Generic Letter 2003-01, or within the next 8 nths if the time period since the mrZirecen successful tracer gas test is great, r than 6 y qrs. (b) The first/performance of th6 periodic assessment of CRE habitabiikly, Spe c fication 5.5.18.c.(ii), shall\ Ie within 3 ye rs, plus the 9-month allowano~-. of SR
. .2, as measured from Novemb&, 1, 2004,
~he date of the most recent successful tracer gas test, as stated in the January 31, ` 005
/ letter response to Generic Letter 2003- 1, or
/ within the next 9 months if the time period\
since the most recent successful tracer gas,, test is greater than 3 years. (c) The first performance of the periodic measurement of CRE pressure, Specification 5.5.18.d, shall be within 18 months, plus the 138 days allowed by SR 3.0.2, as measured from the date of the most recent successful pressure measurement test, or within 138 days if not performed previously. AMEN
Item I D - 3 ADDITIONAL CONDITIONS FACILITY OPERATING LICENESE NO. NPF-66 The licen , ee shall comply with the following conditions on the schedules noted be',ow: Amendment implementation Number Additional Condition Date 151 Upon implementation of Amendment No. 151 adopting With TSTF7448, Revision 3, the determination of control room implementation envelope (CRE) unfiltered air inleakage as required by SR of the 3.7.10.4\in accordance with TS 5.5.18.c.(i), the assessment amendment of CRE hablitability as required by Specification 5.F:18.c.(ii), and the measurement of CRE pressure as required by Specification 5,5.18.d, shall be considered met. Following implementation: (a) The first performance of SR 3.7.10.4, in accordance with Specifica%ion 5.5.18.0i), s all be within the specified Frequency of 6 year /,plus the 18-month allowance of SR 3,0.2, as measured from November 1, 2004, the dat, of the most recent successful tracer gas 4es , as stated in the January 31, 2005 letter ;`esponse to Generic Letter 2003-01, or within the;ney,t 18 months if the time period since the mo, ~recent successful tracer gas test is greater than 6 years. (b) The first performance of the pen% dic assessment of CRE habitabi;ity, Specification 5.5.18.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from November 1, 2004, the date of the most recent successful tracer ga test, as stated/in the January 31, 2005 letter resp onse to Generic Letter 2003-01, or within the next 9 months if t -ie time period since the most recent successful t cer gas test is greater than 3 years. The first performance of the periodic measurement, of CRE pressure, Specification 5.5.18.d, shall be within 18 months, plus the 138 days allowed by SR 3.0.2, as measured from the date of the most recent successful pressure measurement test, or within 138 days if not performed previously. Renewed License N&; NPF-66
S I_s 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in the COLR; and the following SLs shall not be exceeded. 2.1.1.1 In MODE 1, the Departure from Nucleate Boiling Ratio (DNBR) shall be maintained >_ 1.24 for the WRB-2 DNB correlation for a thimble cell, >_ 1.25 for the WRB-2 DNB correlation for a typical cell and >_ 1.19 for the ABB-NV DNB correlation for a thimble cell and a typical cell. 2.1.1.2 In MODE 2, the DNBR shall be maintained >_ 1.17 for the WRB-2 DNB correlation, and >_ 1.13 for the ABB-NV DNB correlation and _> 1.18 for the WLOP DNB correlation. 2.1.1.3 In MODES 1 and 2, the peak fuel centerline temperature shall be maintained < 5080°F, decreasing by 58°F per 10,000 MWD/MTU burnup. 2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, the RCS pressure shall be maintained
< 2735 psig.
2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour. 2.2.2 If SL 2.1.2 is violated: 2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour. 2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes. Item ID - 4
.0 - I Nmenamen
CO A1)1)1 i cak) i 1 i ty 3.0 3.0 LCO Applicability ICO 3.0.7 Exception LCOs allow specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Exception LCOs is optional. When an Exception LCO is desired to be met but is not met, -the ACTIONS of the Exception LCO shall be met. When an Exception LCO is not desired -to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications. LCO 3.0.8 LCOs, including associated ACTIONs, shall apply to each unit individually, unless otherwise indicated. Whenever -the LCO refers to a system or component that is shared by both units, the ACTIONs will apply to both units simultaneously.
SR Applicability 3.0 3.0 SR APPLICABILITY SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement -to declare -the LCO not met may be delayed, from the time of discovery, up to 24 hours or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours and the risk impact shall be managed. If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4. This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit. SR 3.0.5 SRs shall apply to each unit individually, unless otherwise Item ID - 7 UNITS 1 & 2 - 3.0 - 6 Amendment
Rod Po,, i [ion 11, 1d i cal. iorl 3.7./ ACTIONS (continued) CONDITION REQUIRED ACTION COMPII-- LION IIMF C. One demand position C.1.1 Verify by Once per 8 hours indicator per bank administrative means inoperable for one or all DRPIs for the more banks. affected bank(s) are OPERABLE. AND C.1.2 Verify the most Once per 8 hours withdrawn rod and the least withdrawn rod of the affected bank(s) are
<_ 12 steps apart.
OR C.2 Reduce THERMAL POWER 8 hours to <_ 50% RTP. D. Required Action and D.1 Be in MODE 3. 6 hours associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of Prior to the group demand position for the full criticality indicated range of rod travel after each removal of the reactor head. r J1 Item ID - 8 BYRON UNITS 1 & 2 3.1.7 2 Amendment 10v
E I D - 10 RTS Instrum(,W.(-:1tion 3.3.1 SURVEILLANCE REQUIREMENTS ( eenti n eE4 SURVEII.1_ANCE f- RCQUENCY SR 3.3.1.8 (continued) In accordance with the Surveillance Frequency Control Program SR3.3.1.9 ------------------- NOTE -------------------- Verification of setpoint is not required. Perform TADOT. In accordance with the Surveillance Frequency Control Program SR 3.3.1.10 ------------------- NOTE -------------------- This Surveillance shall include verification that the time constants are adjusted to the prescribed values. Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 ------------------- NOTE -------------------- Neutron detectors are excluded from CHANNEL CALIBRATION. Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program (continued) BYRON UNITS 1 & 2 3.3.1 14 Amendment -8
Item ID-11 Insert table header RCS Leakage Detection Instrumentation 3.4.15 (Condition, Required Action, Completion Time) associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours E. All required monitors E.1 Enter LCO 3.0.3. Immediately inoperable. SURVEILLANCE REOUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program SR 3.4.15.2 Perform COT of the required containment In accordance atmosphere radioactivity monitor. with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required In accordance containment sump monitor. with the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required In accordance containment atmosphere radioactivity with the monitor. Surveillance Frequency Control Program BYRON UNITS 1 & 2 3.4.15 3 Amendment 85-
MSSVs 3./.]-
- 3. 7 PLANT SYSTEMS 3.1.1 Main Steam Safety Valves (MSSVs)
LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS
NOTE -------------------------------------
Separate Condition entry is allowed for each MSSV. CONDITION I REQUIRED ACTION I COMPLETION TIME A. One or more steam A.1 Reduce THERMAL POWER 4 hours generators with one or to less than or equal more MSSVs inoperable. to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. 111 A.2 ------- NOTE ----- Only required in Mode 1. Reduce the Power 36 hours Range Neutron Flux-High reactor trip setpoint to less than or equal to the Maximum Allowable RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. (continued). Item ID - 12 BYRON UNITS 1 & 2 3.7.1 1 Amendment 4-3-3
Item ID - 13 MSSVs Insert table header 3.7.1 (Condition, Required Action, Completion Time) associated Completion Time not met. AND OR 13.2 Be in MODE 4. 12 hours One or more steam generators with > 4 MSSVs inoperable. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 ------------------- NOTE -------------------- Only required to be performed in MODES 1 and 2. Verify each required MSSV lift setpoint per In accordance Table 3.7.1-2 in accordance with the with the Inservice Testing Program. Following Inservice testing, lift setting shall be within +/- 1%. Testing Program BYRON UNITS 1 & 2 3.7.1 2 Amendment 34
SX System 3.7.8 3.7 PI AN1 SYSTEMS 3.1.8 I.ssential Service Water (SX) System L-CO 3.1.8 The following SX trains shall be OPERABLE:
- a. Two unit-specific SX trains; and
- b. One opposite-unit SX train for unit-specific support.
APPLICABILITY: MODES 1 9 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, N&T-E A.1 -------- NOTES -------- ii -Ea 1-e -e 1. Enter applicable Un-,'1a,1_4 Conditions and f-ep4--a,&emen-t 0.4:7 1hike Required Actions of LCO 3.8.1 1 "AC s-e-l-a nI I~e-~ Sources-r; ^ 1 c 8-1, a m4 Operating," for I+V, i-V.)g--~n-i~ Emergency Diesel
-Ref He~-i-ng Generator made Unit 21-`s inoperable by SX.
PgnnL_ G G ^r-
- 2. Enter applicable Conditions and Required Actions One unit-specific SX of LCO 3.4.6, train inoperable. "RCS Loops-MODE 4 1 " for Residual Heat Removal loops Item ID - 14 made inoperable by SX.
Restore unit-specific 72 hours SX train to OPERABLE status. (continued) BYRON UNITS 1 & 2 3.7.8 1 Amendment 168
SX System 3.7.8 = 1t emID - 14 Q T I ONS (continued) Unit CONDITION 1 NGTE db ivci ing 8_4 REQUIRED ACI- ION
~I -
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-G. Opposite-unit SX train C.1 Restore opposite-unit 7 days inoperable. SX train to OPERABLE status.
C C 9% Required Action and Time of Condition A, er G not met . a
~ Q.
C LJ or B D.1 AND D.2 Be in MODE 3. Be in MODE 5. 6 hours 36 hours Item ID - 14 Item ID - 14 Renumber CONDITIONs C and D Change'A, B or C'to'A or B' BYRON UNITS 1 & 2 3.7.8 2 Amendment 1 Item ID - 16 Further UHS 3.1.9 indent 'AND' ACTIONS (continued) CONDITION RFQUIRFD ACTION COMPLETION TIME C. Outside air wet bulb C.1 Verify OPERABLE SXCT 1. hour rature > 76°F. -fans are capable of being powered by an H-AfffAND T OPERABLE emergency power source. n ectrical division not capable AND of providing power -to at least one OPFRABIE C.2 Restore SXCT fan 72 hours SXCT fan. configuration such that each electrical division is capable of providing power to at least one OPERABLE SXCT fan. D. SX pump discharge D.1 Be in MODE 3. 6 hours water temperature
> 96°F. AND D.2 Be in MODE 5. 36 hours E. One or more basin E.1 Restore both basin 6 hours level(s) < 60%. levels to _> 60%.
(continued) BYRON UNITS 1 & 2 3.7.9 2 Amendment -143
Item ID-17 VC Filtration System 3.7.10 Further indent 'OR' ACTIONS (continued) CONDITION REQUIRED ACTION COMPLETION TIME
- 1. Two VC Filtration E.1 Suspend movement of Immediately System trains irradiated fuel inoperable in MODE 5 assemblies.
or 6, or during movement of AND irradiated fuel assemblies. E.2 Suspend positive Immediately reactivity additions.
-6f~ OR more VC Filtration System trains inoperable due to an inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies.
F. Two VC Filtration F.1 Enter LCO 3.0.3. Immediately System trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each VC Filtration System train In accordance with: with the Surveillance
- a. Flow through the makeup system filters Frequency for >_ 15 continuous minutes with the Control Program heaters operating; and
- b. Flow through the recirculation charcoal adsorber for >_ 15 minutes.
(continued) BYRON UNITS 1 & 2 3.7.10 3 Amendment --1-&3-
VC IiItration System 3.7.10 SURVEILLANCE REQUIREMENTS (continued) SURVEILLANCE FREQUENCY SR 3.7.10.2 Perform required VC Filtration System In accordance filter testing in accordance with the with the VFTP Ventilation Filter Testing Program (VFTP). SR 3.7.10.3 Verify each VC Filtration System train In accordance actuates on an actual or simulated with the actuation signal. Surveillance Frequency Control Program SR 3.7.10.4 Perform required CRE unfiltered air In accordance inleakage testing in accordance with the with the Control Room Envelope Habitability Program. Control Room Envelope Habitability P rog r am
/
f BYRON UNITS 1 & 2 3.7.10 4 Amendment 4 ~
x `( `( `( `( `( `( `C `( Y `( `( `( Item ID - 19 Insert table header DC Sources-Operating }- (Condition, Required Action, Completion Time) 3.8.4 power division crosstie breaker crosstied to between the crosstied opposite-unit DC divisions. electrical power subsystem that has an inoperable battery charger, while opposite unit is in MODE 19 2, 3, or 4. C. One DC electrical C.1 --------- NOTE -------- power division Only required when crosstied to opposite unit has an opposite-unit DC inoperable battery. electrical power --------------------- subsystem with an inoperable source, Verify opposite-unit Once per while opposite unit is DC bus load 12 hours in MODE 5, 6, or <_ 200 amps. defueled. AND C.2 Open at least one crosstie breaker 7 days between the crosstied divisions. D. One DC electrical D.1 Restore DC electrical 2 hours power subsystem power subsystem to inoperable for reasons OPERABLE status. other than Condition A, B, or C. E. Required Action and E.1 Be in MODE 3. 6 hours Associated Completion Time not met. AND E.2 Be in MODE 5. 36 hours BYRON UNITS 1 & 2 3.8.4 2 Amendment +29-
ID - 20 DC Sources-Shutdown E ACT IONS cet- net 3.8.5 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) I A.2.1 Suspend CORE I Immediately ALTERATIONS. AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies. AND A.2.3 Initiate action to Immediately suspend operations involving positive reactivity additions. AND A.2.4 Initiate action to Immediately restore required DC electrical power subsystem to OPERABLE status. AND A.2.5 Declare affected Low Immediately Temperature Overpressure Protection feature(s) inoperable. (continued) BYRON UNITS I & 2 3.8.5 2 Amendment 149.
t Item 11 ) - 23
-:; heading Design Features 4.0 4.0 OLSIGN FCA-f URLS n E- c I cni F i RE&4 ent4- tue-d-~
4.3 Fuel Storage 4.3.1 Criticality The spent fuel storage racks are designed and shall be maintained, as applicable, with:
- a. Fuel assemblies having a maximum U-235 enrichment of, 5.0 weight percent;
- b. A k,,fr <_ 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Holtec International Report HI-982094, "Criticality Analysis
-for Byron/Braidwood Rack Installation Project," Project No.
80944 9 1998;
- c. A nominal 10.888 inch north-south and 10.574 inch east-west center to center distance between fuel assemblies placed in Region 1 racks; and
- d. A nominal 8.97 inch center to center distance between fuel assemblies placed in Region 2 racks.
Item ID - 25 Roll 4.3.2 and 4.3.3 to page 4.0-2 Item ID - 24 BYRON UNITS 1 & 2 4.0 2 Amendment 165-
Design Features 4.0 DESIGN FEATURES (continued) 4.3.? Drainage The spent fuel pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 410 ft, 0 inches. ~ 4.3.3 Capacity The spent fuel pool is desi cpned (-and shall be ma i rita i ned wi Lh a storage capacity limited to no more than 2984 fuel assemblies. Item ID - 25 Roll 4.3.2 and 4.3.3 to page 4.0-2 ID - 24 E N UNITS 1 & 2 -4.9 & Amendment
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1.5 Safety Function Determination Program (SFDP) (continued) The SFDP identifies where a loss of safety function exists. If loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which -the loss of safety function exists are required to be entered. 5.5.16 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, September 1995 and N E I 94-01, Revision 1temm: = 2261 ~x ~-~j;- the- f-o1 ~-owe-Ag_ t ~iICI 11A 11]~ nn
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The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa , is 42.8 psig for Unit 1 and 38.4 psig for Unit 2 The maximum allowable containment leakage rate, La , at Pa, shall be 0.20% of containment air weight per day. Leakage Rate acceptance criteria are:
- a. Containment leakage rate acceptance criterion is <_ 1.0 La.
During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and C tests and < 0.75 La for Type A tests; and BYRON - UNITS 1 & 2 5.5 - 21 Amendment 15B
TT,ACHMENT Proposed Technical Specification Bases Changes for Braidwood Station, Units 1 and 2
SX System B 3.7.8 B 3.7 PLANT SYSTEMS B 3.7.8 Essential Service Water, (SX) System BASES BACKGROUND The SX System provides a heat sink for the removal of process and operating heat from safety related components during a Design Basis Accident (DBA) or transient. During normal operation, and a normal shutdown, the SX System also provides this function for various safety related and nonsafety related components. The safety related function is covered by this LCO. The unit-specific SX System consists of two separate, electrically independent, 100% capacity, safety related, cooling water trains. Each train consists of a 100% capacity pump, piping, valving, and instrumentation. The pumps and valves are remote and manually aligned, except in the unlikely event of a Loss Of Coolant Accident (LOCA). The pumps are automatically started upon receipt of a safety injection signal or an undervoltage on the ESF bus, and all essential valves are aligned to their post accident positions (Diesel Generator (DG) supply valves are opened once the DG has reached sufficient rpm). The SX System is the backup water supply to the Auxiliary Feedwater System. The SX System includes provisions to crosstie the trains (unit-specific crosstie), as well as provisions to crosstie the units (opposite-unit crosstie). The opposite-unit crosstie valves (1SX005 and 2SX005) must both be open to accomplish the opposite-unit crosstie. The system is normally aligned with the unit-specific crosstie valves open and the opposite-unit crosstie valves closed. Additional information about the design and operation of the SX System, along with a list of the components served, is presented in the UFSAR, Section 9.2.1 (Ref. 1). Some of the functions served by the SX System are the removal of decay heat from the reactor via the Component Cooling Water (CC) System, the removal of heat from containment via the reactor containment fan coolers, and cooling of the DGs. BRAIDWOOD EH9 B 3.7.8 1 Revision SX System B 3.7.8 BASIS APPLICABLE The design basis of the SX System is for one SX train, in SAFETY ANALYSES conjunction with the CC System and a 100% capacity containment cooling system, to remove core decay heat following a design basis LOCA as discussed in the UFSAR, Section 6.2 (Ref. 2). This prevents the containment sump fluid From increasing in temperature during the recirculation phase following a LOCA and provides for a gradual reduction in the temperature of this fluid as it is supplied "to the Reactor Coolant System by the Emergency Core Cooling System pumps. The SX System is designed to perform its function with a single failure of any active component, assuming the loss of offsite power. The SX System, in conjunction with the CC System, also cools the unit from Residual Heat Removal (RHR) entry conditions, as discussed in the UFSAR, Section 5.4.7, (Ref. 3) to MODE 5 during normal and post accident operations. The time required for this evolution is a function of the number of CC and RHR System trains that are operating. One SX train is sufficient to remove decay heat during subsequent operations in MODES 5 and 6. Generic Letter 91-13 (Ref. 4) included risk-based recommendations for enhancing the availability of SX Systems, in the case of a loss of all SX to a particular unit. Crediting the opposite-unit SX System with an opposite-unit pump and the opposite-unit crosstie valves, was a part of the response to this Generic Letter. The unit-specific SX System satisfies Criterion 3 of 10 CFR 50.36(c)(2)(ii). The opposite-unit SX System satisfies Criterion 4 of 10 CFR 50.36(c)(2)(ii). Item ID - 27 BRAIDWOOD )- UNITS 1 & 2-C B 3.7.8 2 Revision SX System 13 3.7.8 BASES I_CO Two unit-specific SX Lrains are required to be OPLRABLE to provide the required redundancy Lo ensure that the system functions to remove post accident heat loads, assuming that the worst case single active failure occurs coincident with the loss of offsite power. A unit-specific SX train is considered OPERABLE during MODES 1, 2, 3, and 4 when:
- a. The pump is OPERABLE; and
- b. The associated piping, valves, and instrumentation and controls required to perform the safety related function are OPERABLE.
An opposite-unit SX train is considered OPERABLE during MODES 1, 2, 3, and 4 when:
- a. An opposite-unit pump is capable of performing its required unit-sp ?cific function (manually start and supply SX to the flow path);
- b. A flow path from the opposite unit is established, or capable of being established (including the opposite-unit cri Dsstie valves 1SX005 and 2SX005); and C. The associated piping, valves, and instrumentation and controls are capable of performing the crosstie function.
Item I D - 27 i BRAIDWOOD UNITS 1 & 2 B 3.7.8 3 Revision -C-
SX System B 3.7.8 13ASI-S APPLICABILITY In MODES 1, 2, 3, and 4, the unit-specific SX System is a normally operating system that is required to support the OPERABILITY of the equipment serviced by the SX System and required to be OPERABLE in these MODES. While a specific unit is in MODES 1, 2, 3, or 4, the opposite-unit SX System must be available (independent of the opposite unit's MODE or condition) for unit-specific support. This minimizes the risk associated with loss of all unit-specific SX. In MODES 5 and 6 the OPERABILITY requirements of the unit-specific SX System are determined by the systems it supports and there are no opposite-unit SX System requirements. ACTIONS A.1 If one unit-specific SX train is inoperable, action must be taken to restore OPERABLE status within 72 hours. In this Condition, the remaining OPERABLE SX train is adequate to perform the heat removal function. However, the overall reliability is reduced because a single failure in the OPERABLE SX train could result in loss of the SX System function in the short term. The 72 hour Completion Time is based on the redundant capabilities afforded by the OPERABLE train, and the low probability of a DBA occurring during this time period. Required Action A.1 is modified by two Notes. The first Note indicates that the applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources-Operating," should be entered if an inoperable SX train results in an inoperable emergency diesel generator. The second Note indicates that the applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops-MODE 4," should be entered if an inoperable SX train results in an inoperable decay heat removal train. These are exceptions to LCO 3.0.6 and ensure the proper actions are taken for these components.
- 27 EE BRAIDWOOD UNITS 1 & 2 B 3.7.8 4 Revision 4-~-
SX System B 3. 7.8 3ASI S ACIIONS (continued) B.I If the opposite-unit SX train is not OPERABLE for unit-specific support, action must be taken to restore OPERABLE status within 7 days. In this Condition, if a complete loss of unit-specific SX were to occur, the SX System function would be lost. The 7 day Completion Time is based on the capabilities of the unit-specific SX System and the low probability of a DBA with a loss of all unit-specific SX occurring during this time period. C.1 and C.2 If the unit-specific SX train or the opposite-unit SX train cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours and in MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging plant systems. em I D - 27 I E BRAIDWOOD UNITS I & 2 B 3.7.8 5 Revision -z-7
SX System B 3. 1.8 BASES SURVEILLANCE SR 3.7.8.1 REQUIREMENTS Verifying the correct alignment -for manual, power operated, and automatic valves in the unit-specific SX flow path provides assurance that -the proper flow paths exist for unit-specific SX operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior, to being locked, sealed, or secured. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. This SR is modified by a Note indicating isolation of the 9 components does not affect the OPERABILITY of the SX System. Isolation of components may render those components inoperable. SR 3.7.8.2 This SR verifies that the opposite-unit SX pump can be run for >_ 15 minutes. This SR does not require the opposite-unit pump to supply SX to the specific unit. SR 3.7.8.2 is modified by a note that only requires this surveillance to be performed when the opposite unit is in MODE 5 or 6 or has no fuel in the reactor vessel. If the opposite unit is in MODE 1, 2, 3, or 4, its SX System is normally operating. If the opposite unit is shut down, the credited SX pump may not be operating. Therefore, the Note requires the surveillance to be performed. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. BRAIDWOOD EUNITS 1 & 2 B 3.7.8 6 Revision 85-
SX System B 3.7.8 BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.7.8.3 This SR verifies proper operation of the opposite-unit SX cross-Lie valves Q SX005 and 2SX005). This Surveillance is not required if the opposite-unit SX crosstie valve is secured in the open position with power removed. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. SR 3.7.8.4 This SR verifies proper automatic operation of the unit-specific SX System valves on an actual or simulated actuation signal. The SX System is a normally operating system that cannot be fully actuated as part of normal testing. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. SR 3.7.8.5 This SR verifies proper automatic operation of the unit-specific SX pumps on an actual or simulated actuation signal. The SX System is a normally operating system that cannot be fully actuated as part of normal testing during normal operation. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. Item I D - 27 E BRAIDWOOD UNITS 1 & 2 B 3.7.8 7 Revision 8 SX System B 3.7.8 BASES REFERENCES 1. UFSAR, Section 9.2.1.
- 2. UFSAR, Section 6.2.
- 3. UFSAR, Section 5.4.7.
- 4. Generic Letter 91-13.
BRAIDWOOD UNITS 1& 2 B 3.7.8 8 Revision 0
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r Item ID - 27
ATTACHMENT Proposed Technical Specification Bases Changes for Byron Station, Units 1 and 2
SX System B 3. 7.8 BASES ACTIONS A.I If one unit-specific SX -train is inoperable, action must be taken to restore OPERABLE status within 72 hours. In this Condition, the remaining OPERABLE SX train is adequate to perform the heat removal function. However, the overall reliability is reduced because a single failure in the OPERABLE SX train could result in loss of the SX System function in the short term. The 72 hour Completion Time is based on the redundant capabilities afforded by the OPERABLE train, and the low probability of a DBA occurring during this time period. C.. . C A C* ... . . . .. .. .-. . *
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A , :e C_ l C. . .0 r C Required Action A.1 is modified by two Notes. The first Note indicates that the applicable Conditions and Required Actions of 1 Sources-Operating,"*
- be entered if an inoperable SX train results in an inoperable emergency diesel generator. The second Note indicates that the applicable Conditions and Required Actionsof 1 *
" RCS Loops-MODE*
- be entered inoperab le SX train results in an inoperable decay heat removal train.
These are .p
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.r ed-44,-i BYRON UNITS I & 2 B 3.7.8 4 Revision -q
SX System B 3.7.8 BASES ACTIONS (conL i rued)
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If -the opposite-unit SX train is not OPERABLE for unit-specific support, action must be taken to restore OPERABLE status within 7 days. In this Condition, if a complete loss of unit-specific SX were to occur, the SX System function would be lost. The 7 day Completion Time is based on the capabilities of the unit-specific SX System and the low probability of a DBA with a loss of all unit-specific SX occurring during this time period. If the unit-specific SX train or the opposite-unit SX train cannot be restored to OPERABLE status within the associated Completion Time, 'the unit must be placed in a MODE in which the LCO does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours and in MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.7.8.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the unit-specific SX flow path provides assurance that the proper flow paths exist for unit-specific SX operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to being locked, sealed, or secured. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. The Surveillance Frequency is controlled under the Surveillance Frequency Control Program. 5-BYRON UNITS 1 & 2 B 3.7.8 5 Revision 4-}}