Text

Issuance of Renewed Facility Operating License No. DPR-49 for Duane Arnold Energy
	ML102930524
Person / Time
Site:	Duane Arnold
Issue date:	12/16/2010
From:	Harris B; License Renewal Projects Branch 1
To:	Costanzo C; NextEra Energy Duane Arnold
	HARRIS B, NRR/DLR/RPB1, 415-2277
Shared Package
ML102930590	List: ML102930524; ML102930570; ML102930586; NRC-2008-0618, Federal Register Notice on Nextera Energy Duane Arnold Notice of Issuance of Renewed Facility Operating License DPR-49 for an Additional 20 Year Period;
References
	Download: ML102930524 (364)
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UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 December 16, 2010 Mr. Christopher Costanzo Vice President, Nuclear Plant Support NextEra Energy Duane Arnold, LLC P.O. Box 14000 Juno Beach, FL 33408-0420

SUBJECT:

ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO. DPR-49 FOR DUANE ARNOLD ENERGY CENTER

Dear Mr. Costanzo:

The U.S. Nuclear Regulatory Commission (NRC) has issued Renewed Facility Operating License No. DPR-49 for the Duane Arnold Energy Center (DAEC). The NRC issued the renewed facility operating license based on the staff's review of your application dated September 30,2008, as supplemented by letters submitted to the NRC through August 18, 2010. The technical specifications for DAEC were not amended as a result of the NRC's review.

Renewed Facility Operating License No. DPR-49 expires at midnight on February 21, 2034.

The technical basis for issuing the renewed license appears in NUREG-1955, "Safety Evaluation Report Related to the License Renewal of the Duane Arnold Energy Center,"

published in November 2010. The results of the environmental reviews related to the issuance of the renewed license appear in NUREG-1437, Supplement 42, "Generic Environmental Impact Statement for License Renewal of Nuclear Plants: Regarding Duane Arnold Energy Center Final Report," published in October 2010. contains Renewed Facility Operating License No. DPR-49 with attachments, Appendix A, "Technical Specifications," and Appendix B, "Additional Conditions." is a copy of the related Federal Register notice of issuance of the renewed license.

The original has been sent to the Office of the Federal Register for publication.

C. Costanzo -2 If you have any questions regarding this issue, please feel free to contact me at 301-415-2277 or bye-mail at brian.harris2@nrc.gov.

Brian K. Harris, Project Manager Reactor Projects Branch 1 Division of license Renewal Office of Nuclear Reactor Regulation Docket No. 50-331

Enclosures:

As stated cc: See next page

7590-01-P UNITED STATES NUCLEAR REGULATORY COMMISSION DOCKET NO. 50-331 NEXTERA ENERGY DUANE ARNOLD, LLC DUANE ARNOLD ENERGY CENTER NOTICE OF ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO. DPR-49 FOR AN ADDITIONAL 20-YEAR PERIOD Notice is hereby given that the U.S. Nuclear Regulatory Commission (the Commission) has issued renewed facility operating license No. DPR-49 to NextEra Energy Duane Arnold, LLC (licensee), the operator of the Duane Arnold Energy Center (DAEC). Renewed facility operating license No. DPR-49 authorizes operation of DAEC by the licensee at reactor core power levels not in excess of 1912 megawatts thermal in accordance with the provisions of the DAEC renewed license and its technical specifications.

The notice also serves as the record of decision for the renewal of facility operating license No. DPR-49, consistent with Title 10 of the Code of Federal Regulations Section 51.103 (10 CFR 51.103). As discussed in the final Supplemental Environmental Impact Statement (FSEIS) for DAEC, dated October 2010, the Commission has considered a range of reasonable alternatives that included generation from oil, wind, solar, hydropower, geothermal, wood waste, municipal solid waste, other biomass-derived fuels, fuel cells, delayed retirement, and conservation measures. The factors considered in the record of decision can be found in the supplemental environmental impact statement (SEIS) for DAEC.

Enclosure 2

-2 DAEC is a boiling-water reactor located in Palo, Iowa. The application for the renewed license complied with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations. As required by the Act and the Commission's regulations in 10 CFR Chapter 1, the Commission has made appropriate findings, which are set forth in the license. Prior public notice of the action involving the proposed issuance of the renewed license and of an opportunity for a hearing regarding the proposed issuance of the renewed license was published in the Federal Register on February 17, 2009 (73 FR 67895).

For further details with respect to this action, see: (1) FPL Duane Arnold, LLC's license renewal application for Duane Arnold Energy Center dated September 30,2008, as supplemented by letters dated through August 18, 2010; (2) the Commission's safety evaluation report (NUREG-1955), published in November 2010 ; (3) the licensee's updated safety analysis report; and (4) the Commission's final environmental impact statement (NUREG-1437, Supplement 42), for the Duane Arnold Energy Center, published in October 2010. These documents are available at the NRC's Public Document Room, One White Flint North, 11555 Rockville Pike, Rockville, Maryland 20852, and can be viewed from the NRC Public Electronic Reading Room at http://www.nrc.gov/reading-rm/adams.html.

Copies of renewed facility operating license No. DPR-49, may be obtained by writing to the U.S. Nuclear Regulatory Commission, Washington, D.C. 20555-0001, Attention: Director, Division of License Renewal. Copies of the Duane Arnold Energy Center safety evaluation report (NUREG-1955) and the final environmental impact statement (NUREG-1437, Supplement 42) may be purchased from the National Technical Information Service, U.S. Department of Commerce, Springfield, Virginia 22161 (http://www.ntis.gov), 703-605-6000, or Attention: Superintendent of Documents,

-3 (http://www.gpoaccess.gov), 202-512-1800. All orders should clearly identify the NRC publication number and the requestor's Government Printing Office deposit account number or VISA or MasterCard number and expiration date.

Dated at Rockville, Maryland, this 16th day of December, 2010.

FOR THE NUCLEAR REGULATORY COIVIMISSION Brian E. Holian, Director Division of License Renewal Office of Nuclear Reactor Regulation

NEXTERA ENERGY DUANE ARNOLD. LLC CENTRAL IOWA POWER COOPERATIVE CORN BELT POWER COOPERATIVE DOCKET 50-331 DUANE ARNOLD ENERGY CENTER RENEWED FACILITY OPERATING LICENSE Renewed License No. DPR-49 1, The Nuclear Regulatory Commission (the Commission) having found that:

A. The application for license filed by FPL Energy Duane Arnold, LLC,' Central Iowa Power Cooperative and Corn Belt Power Cooperative (the licensees) complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),

and the Commission's rules and regulations set forth in 10 CFR Chapter I and all required notifications to other agencies or bodies have been duly made; B. Construction of the Duane Arnold Energy Center (facility) has been substantially completed in conformity with Construction Permit No. DPPR-70; the application, as amended; the provisions of the Act; and the rules and regulations of the Commission; C. The facility will operate in conformity with the application, as amended; the provisions of the Act; and the rules and regulations of the Commission; D. There is reasonable assurance: (i) that the activities authorized by this renewed operating license can be conducted without endangering the health and safety of the public; and (ii) that such activities will be conducted in compliance with the rules and regulations of the Commission; E. NextEra Energy Duane Arnold, LLC is technically qualified and NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative are financially qualified to engage in the activities authorized by this renewed operating license in accordance with the rules and regulations of the Commission; F. The licensees have satisfied the applicable' provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G. The issuance of this renewed operating license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental costs and considering available alternatives, the issuance of renewed Facility Operating License No. DPR-49 is in accordance with 10 CFR Part 50, Appendix D, of the Commission's regulations and all applicable requirements of said Appendix D have been satisfied;

'On April 16, 2009, the name "FPL Energy Duane Arnold, LLC" was changed to "NextEra Energy Duane Arnold, LLC."

Renewed License No. DPR-49

-2 I. The receipt, possession, and use of source, by-product and special nuclear material as authorized by this renewed operating license will be in accordance with the Commission's regulations in 10 CFR Part 30 and 70, including 10 CFR Section 30.33, 70.23 and 70.31.

2. Renewed Facility Operating License No. DPR-49 is hereby issued to NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative (CIPCO) and Corn Belt Power Cooperative (Corn Belt) to read as follows:

A. This renewed operating license applies to the Duane Arnold Energy Center, a boiling water reactor and associated equipment (the facility), owned by NextEra Energy Duane Arnold, LLC, Central Iowa Power Cooperative and Corn Belt Power Cooperative and operated by NextEra Energy Duane Arnold, LLC. The facility is located on NextEra Energy Duane Arnold, LLC's, Central Iowa Power Cooperative's and Corn Belt Power Cooperative's site near Palo in Linn County, Iowa. This site consists of approximately 500 acres adjacent to the Cedar River and is described in the "Final Safety AnalysiS Report" as supplemented and amended (Amendments 1 through 14) and the Environmental Report as supplemented and amended (Supplements 1 through 5).

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) NextEra Energy Duane Arnold, LLC, pursuant to Section104b of the Act and 10 CFR Part 50, "Licensing of Production and Utilization Facilities," to possess, use and operate the facility; and CIPCO and Corn Belt to possess the facility at the deSignated location in Linn County, Iowa, in accordance with the procedures and limitations set forth in this license; (2) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Part 70, to receive, possess and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Updated Final Safety Analysis Report, as supplemented and amended as of June 1992 and as supplemented by letters dated March 26, 1993, and November 17, 2000.

(3) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (4) l'JextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30, 40 and 70, to receive, possess and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated radioactive apparatus components; (5) NextEra Energy Duane Arnold, LLC, pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not to separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

Renewed License No. DPR-49

- 3 C. This renewed operating license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I; Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1) Maximum Power Level NextEra Energy Duane Arnold, LLC is authorized to operate the Duane Arnold Energy Center at steady state reactor core power levels not in excess of 1912 megawatts (thermal).

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 276, are hereby incorporated in the license. NextEra Energy Duane Arnold, LLC shall operate the facility in accordance with the Technical Specifications.

(a) For Surveillance Requirements (SRs) whose acceptance criteria are modified, either directly or indirectly, by the increase in authorized maximum power level in 2.C.(1) above, in accordance with Amendment No. 243 to Facility Operating License DPR-49, those SRs are not required to be performed until their next scheduled performance, which is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment No. 243.

(b) Deleted.

(3) Fire Protection Next Era Energy Duane Arnold, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the Duane Arnold Energy Center and as approved in the SER dated June 1, 1978, and Supplement dated February 10, 1981, subject to the following provision:

Next Era Energy Duane Arnold, LLC may make changes to the approved fire protection program without prior approval of the Commission only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

(4) The licensee is authorized to operate the Duane Arnold Energy Center following installation of modified safe-ends on the eight primary recirculation system inlet lines which are described in the licensee letter dated July 31, 1978, and supplemented by letter dated December 8, 1978.

(5) Physical Protection NextEra Energy Duane Arnold, LLC shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, Renewed License No. DPR-49

-4 and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The combined set of plans, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Duane Arnold Energy Center Physical Security Plan," submitted by letter dated May 16, 2006.

(6) Deleted (7) Additional Conditions The Additional Conditions contained in Appendix B, as revised through Amendment No. 260, are hereby incorporated into this license. NextEra Energy Duane Arnold, LLC shall operate the facility in accordance with the Additional Conditions.

(8) The licensee is authorized to revise the Updated Final Safety Analysis Report by deleting the footnote for Section 9.1.4.4.5 which states: "'"'The NRC has not endorsed the reactor building crane as single-failure proof (Reference 9)," and by deleting Reference 9 of the references for Section 9.1.

(9) Mitigation Strategy License Condition Develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (10) The licensee shall implement and maintain all Actions required by Attachment 2 to NRC Order EA-06-137, issued June 20,2006, except the last action that requires incorporation of the strategies into the site security plan, contingency plan, emergency plan and/or guard training and qualification plan, as appropriate.

Renewed License No. DPR-49

- 5 (11) The information in the UFSAR supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), shall be incorporated into the UFSAR no later than the next scheduled update required by 10 CFR 50.71 (e) following the issuance of this renewed operating license. Until this update is complete, the licensee may not make changes to the information in the supplement. Following incorporation into the UFSAR, the need for prior Commission approval of any changes will be governed by 10 CFR 50.59.

(12) The UFSAR supplement, as revised, submitted pursuant to 10 CFR 54.21 (d),

describes certain future activities to be completed prior to and/or during the period of extended operation. The licensee shall complete these activities in accordance with Appendix A of NUREG-1955, "Safety Evaluation Report Related to the License Renewal of Duane Arnold Energy Center," dated November 2010, as supplemented by letter from the licensee to the NRC dated November 23, 2010. The licensee shall notify the NRC in writing when activities to be completed prior to the period of extended operation are complete and can be verified by NRC inspection.

(13) The licensee shall implement the most recent staff-approved version of the Boiling Water Reactor Vessels and Internals Project (BWRVIP) Integrated Surveillance Program (ISP) as the method to demonstrate compliance with the requirements of 10 CFR Part 50, Appendix H. Any changes to the BWRVIP ISP capsule withdrawal schedule must be submitted for staff review and approval. Any changes to the BWRVIP ISP capsule withdrawal schedule which affects the time of withdrawal of any surveillance capsules must be incorporated into the licensing basis. If any surveillance capsules are removed without the intent to test them, these capsules must be stored in a manner which maintains them in a condition which would support re-insertion into the reactor pressure vessel if necessary.

D. This license is effective as of the date of issuance and shall expire at midnight February 21,2034.

FOR THE NUCLEAR REGULATORY COMMISSION

L~

Office of Nuclear Reactor Regulation

Enclosures:

1. Appendix A Technical Specifications

2. Appendix B Additional Conditions Date of Issuance: December 16,2010 Renewed License No. DPR-49

ML102930590 (PKG) ML102930524 (LTR) ML102930586 (FRN)

ML102930570 (LlC)

OFFICE PM:RPB1:DLR i LADLR .. Tech Editor

PM:LPL3-1 :DORL BC:LPL3-1 :DORL NAME BHarris i IKing KAzariah- KFeintuch RPascarelii Kribbs DATE 10/28/10 10/27/10 11/03/10 11/15/10 11/29/10 OFFICE BC:RPB1:DLR D:DLR:NRR *OGC*NLO D:NRR PM:RPB1:DLR NAME BPham

BHelian LSubin ELeeds BHarris i (MGalioway for)

DATE 12/03/10 12/10/10 12/03/10 12/16/10 I 12/16/10 Letter to C. Costanzo from B. Harris dated December 16,2010

SUBJECT:

ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO. DPR-49 FOR DUANE ARNOLD ENERGY CENTER DISTRIBUTION:

HARD COPY:

DLRRF E-MAIL:

PUBLIC [or NON-PUBLIC, if appropriate]

RidsNrrDlr Resource RidsNrrDlrRpb1 Resource RidsNrrDlrRpb2 Resource RidsNrrDlrRerb Resource RidsNrrDlrRpob Resource RidsNrrDraApla Resource RidsOgcMailCenter Resource B. Harris M. Spencer K. Feintuch V. Dricks, RIV

TABLE OF CONTENTS 1.0 USE AND APPLICATION.. ........... 1.1-1 1.1 Definitions. . . ......... 1.1-1 1.2 Logical Connectors . . . . . . . . . . . . . . . . . . . 1.2-1 1.3 Completion Times . . . . . . . . . . . . . . . . . . . . 1.3-1 1.4 Frequency . . . . . . . . . . . . . . . . . . . . . . . 1.4-1 2.0 SAFETY LIMITS (SLs). . . ........ 2.0-1 2.1 SLs. . . ......... 2.0-1 2.2 SL Violations.. ........... 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY . . . . 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY . . . . . . . . 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS . . . . . . . . . . . . . . . 3.1-1 3.1.1 SHUTDOWN MARGIN (SDM) .. 3.1-1 3.1.2 Reactivity Anomalies .. 3.1-5 3.1.3 Control Rod OPERABILITY . . . . . . . . . . . . . . 3.1-7 3.1.4 Control Rod Scram Times . . . . . . . . . . . . . . 3.1-12 3.1.5 Control Rod Scram Accumulators . . . . . . . . . . . 3.1-15 3.1.6 Rod Pattern Control .. ... 3.1-18 3.1.7 Standby Liquid Control (SLC) System . . ... . .. . 3.1-20 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves 3.1-25 3.2 POWER DISTRIBUTION LIMITS ........ 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE . 3.2-1 (APLHGR) . . . . . . . . . . . . . . . . . ... . 3.2-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) . . . . . . . . 3.2-2 3.3 INSTRUMENTATION . . 3.3-1 3.3.1.1 Reactor Protection System (RP5) Instrumentation . 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation . . . . . 3.3-10 3.3.2.1 Control Rod Block Instrumentation . . . . . . . . . 3.3-15 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation . . . 3.3-21 3.3.3.2 . Remote Shutdown System ......... 3.3-25 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) 3.3-Instrumentation . . . . . . . . . . . . . . . . . 3.3-27 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation . . . . . . 3.3-30 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation 3.3-32 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation . . . . . . . . . . ... . . . . . 3.3-46 3.3.6.1 Primary Containment Isolation Instrumentation . . 3.3-50 3.3.6.2 Secondary Containment Isolation Instrumentation 3.3-62 3.3.6.3 Low-Low Set (LLS) Instrumentation . . . . . . . . . 3.3-66 3.3.7.1 Standby Filter Unit (SFU) System Instrumentation . . 3.3-70 3.3.8.1 Loss of Power (LOP) Instrumentation . . . . . . . . 3.3-72 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring . . .. . 3.3-76 (continued)

DAEC i Amendment 223

TABLE OF CONTENTS (continued) 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . 3.4-1 3.4.1 Recirculation Loops Operating . . . . . . . . . . . 3.4-1 3.4:2 Jet Pumps . ... . 3.4-4 3.4.3 Safety Relief Valves (SRVs) and Safety Valves (SVs) 3.4-6 3.4.4 RCS Operational LEAKAGE . . . . . . . . . . . . . . 3.4-8 3.4.5 RCS Leakage Detection Instrumentation . . . . . . . 3.4-10 3.4.6 RCS Specific Activity . . . . . . . . . . . . . . . 3.4-13 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown . . . . . . . . . . . . . . 3.4-15 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System- Cold Shutdown . . . 3.4-18 3.4.9 RCS Pressure and Temperature (P/T) Limits . . . . . 3.4-20 3.4.10 Reactor Steam Dome Pressure . . . . . . . . . . . . 3.4-25 3.5 -EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM . . . . . . . . . . . . 3.5-1 3.5.1 ECCS -Operating . . . . . . . . . . . . . . . . . . 3.5-1 3.5.2 ECCS-Shutdown . . . . . . . . . . . . . . . . . . . 3.5-8 3.5.3 RCIC System ...... . ........ . . . . . 3.5-12 3.6 CONTAINMENT SYSTEMS . . . . . . . . . . . . . . . . . . 3.6-1 3.6.1.1 Primary Containment .... ....... . . . . . 3.6-1 3.6.1.2 Primary Containment Air Lock . . . . . 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs). 3.6-8 3.6.1.4 Drywell Air Temperature . . . . . . . . . . . . . . 3.6-16 3.6.1.5 Low-Low Set (LLS) Valves . . . . . . . . . . . . . . 3.6-17 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers . . . . . . . . . . . . . . . . . . . . 3.6-19 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers . . . 3.6-22 3.6.2.1 Suppression Pool Average Temperature . . . . . . . . 3.6-24 3.6.2.2 Suppression Pool Water Level . ..... 3.6-27 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool. .3.6-27 Cooling . . . . . . 3.6-28 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray. 3.6-30 3.6.3.1 Containment Atmosphere Dilution (CAD) System . . . . 3.6-32 3.6.3.2 Primary Containment Oxygen Concentration . . . . . . 3.6-34 3.6.4.1 Secondary Containment . . . . . . . . . . . . . . . 3.6-35 3.6.4.2 Secondary Containment.Isolation Valves/Dampers (SCIV/Ds) .......... 3.6-37 3.6.4.3 Standby Gas Treatment (SBGT) System . . . . . . . . 3.6-41 3.7 PLANT SYSTEMS . .. .3.7-1 3.7.1 Residual Heat Removal Service Water (RHRSW) System . 3.7-1 3.7.2 River Water Supply (RWS) System and Ultimate Heat Sink (UHS) . . ... . 3.7-3 3.7.3 Emergency Service Water (ESW) Syste m . 3.7-5 3.7.4 Standby Filter Unit (SFU) System . . . . . . . . . . 3.7-7 3.7.5 Control Building Chiller (CBC) System . . . . . . . 3.7-11 (continued)

DAEC ii Anendment 223

TABLE OF CONTENTS 3.7 PLANT SYSTEMS (continued) 3.7.6 Main Condenser Offgas ................................... 3.7-14 3.7.7 Main Turbine Bypass System ............................. 3.7-16 3.7.8 Spent Fuel Storage Pool Water Level ....... ............. 3.7-18 3.7.9 Control Building/Standby Gas Treatment Instrument Air System ............. ................. 3.7-19 3.8 ELECTRICAL POWER SYSTEMS .................................... 3.8-1 3.8.1 AC Sources - Operating ................................. 3.8-1 3.8.2 AC Sources - ShuL'own .................................. 3.8-11 3.8.3 Diesel Fuel Oii. Lube Oil, and Starting Air ..... ....... 3.8-14 3.8.4 DC Sources - Operfting ................................. 3.8-17 3.8.5 DC Sources - Shutdown .................................. 3.8-21 3.8.6 Battery Cell Parameters ................................ 3.8-23 3.8.7 Distribution Systems - Operating ........ ............... 3.8-27 3.8.8 Distribution Systems - Shutdown ......... ............... 3.8-30 3.9 REFUELING OPERATIONS ....................................... 3.9-1 3.9.1 Refueling Equipment Interlocks ......... ............... 3.9-1 3.9.2 Refuel Position One-Rod-Out Interlock ...... ........... 3.9-3 3.9.3 Control Rod Position ................................... 3.9-5 3.9.4 Control Rod Position Indication ...... ................ 3.9-6 3.9.5 Control Rod OPERABILITY - Refueling ......... ........... 3.9-8 3.9.6 Reactor Pressure Vessel (RPV) Water Level ..... ....... 3.9-9 3.9.7 Residual Heat Removal (RHR) - High Water Level ........ 3.9-10 3.9.8 Residual Heat Removal (RHR) - Low Water Level ......... 3.9-13 3.10 SPECIAL OPERATIONS 3..........

3.10-1 3.10.1 System Leakage and Hydrostatic Testing Operation ....... 3.10-1 3.10.2 Reactor Mode Switch Interlock Testingerloc Testin

. ... 3.10-4 3.10.3 Single Control Rod Withdrawal - Hot Shutdown ........... 3.10-6 3.10.4 Single Control Rod Withdrawal - Cold Shutdown ......... 3.10-9 3.10.5 Single Control Rod Drive (CRD)

Removal - Refueling ................................ 3.10-13 3.10.6 Multiple Control Rod Withdrawal - Refueling ............ 3.10-16 3.10.7 Control Rod Testing - Operating ............. .3.10-18 3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling ..... ........... 3.10-20 4.0 DESIGN FEATURES .......................................... 4.0-1 4.1 Site Location .......................................... 4.0-1 4.2 Reactor Core .......................................... 4.0-1 4.3 Fuel Storage .......................................... 4.0-2 5.0 ADMINISTRATIVE CONTROLS ......................................... 5.0-1 5.1 Responsibility .......................................... 5.0-1 5.2 Organization .......................................... 5.0-2 5.3 Unit Staff Qualifications ................ ................. 5.0-5 5.4 Procedures .......................................... 5.0-6 5.5 Programs and Manuals ...................................... 5.0-7 5.6 Reporting Requirements ..................................... 5.0-19 5.7 High Radiation Area ....................................... 5.0-22 DAEC iii Amendment No. M 51N 0 9 599

TABLE OF CONTENTS B 2.0 SAFETY LIMITS (SLs) ................... B 2.0-1 B 2.1.1 Reactor Core SLs ................. B 2.0-1 B 2.1.2 Reactor Coolant System (RCS) Pressure SL . . . . B 2.0-6 B 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY . B 3.0-1 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY . . . . . B 3.0-10 B 3.1 REACTIVITY CONTROL SYSTEMS . . . ; . . . . . . . . . . B 3.1-1 B 3.1.1 SHUTDOWN MARGIN (SDM) . . . . . . . . . . . . . . B 3.1-1 B 3.1.2 Reactivity Anomalies . . . . . . . . . . . . . . . B 3.1-9 B 3.1.3 Control Rod OPERABILITY . . . . . . . . . . . . . B 3.1-14 B 3.1.4 Control Rod Scram Times . . . . . . . . . . . . . B 3.1-23 B 3.1.5 Control Rod Scram Accumulators . . . . . . . . . . B 3.1-28 B 3.1.6 Rod Pattern Control ............... B 3.1-34 B 3.1.7 Standby Liquid Control (SLC) System . . . . . . . B 3.1-39 B 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves B 3.1-45 B 3.2 POWER DISTRIBUTION LIMITS ........ B 3.2-1 B 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) . ...... . . . . . . .. . . . . B 3.2-1 B 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) . . . . . . . B 3.2-6 B 3.3 INSTRUMENTATION .. .............. . B 3.3-1 B 3.3.1.1 *Reactor Protection System (RPS) Instrumentation B 3.3-1 B 3.3.1.2 Source Range Monitor (SRM) Instrumentation . . . . B 3.3-37 B 3.3.2.1 Control Rod Block Instrumentation . . . . B 3.3-46 B 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation. B 3.3-58 B 3.3.3.2 -Remote Shutdown System . . . . . . . . . . . . . . B 3.3-70 B 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation . . . . . . . . . . . . B 3.3-77 B 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation . . . . . B 3.3-88 B 3.3.5.1 Emergency Core Cooling System (ECCS)

Instrumentation . . . . . . . . . . . . . . . . B 3.3-97 B 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation . . . . . . . . . . B 3.3-140 B 3.3.6.1 Primary Containment Isolation Instrumentation. B 3.3-151 B 3.3.6.2 Secondary Containment Isolation Instrumentation B 3.3-190 B 3.3.6.3 Low-Low Set (LLS) Instrumentation . . . . . . . . B 3.3-201 B 3.3.7.1 Standby Filter Unit (SFU) System Instrumentation . B 3.3-209 B 3.3.8.1 Loss of Power (LOP) Instrumentation . . . . . . . B 3.3-215 B 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ..... . ........ . . . . B 3.3-224 (continued)

DAEC i Amendment 223

TABLE OF CONTENTS (continued)

B 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . B 3.4-1 B 3.4.1 Recirculation Loops Operating . . . . ... . . . . B 3.4-1 B 3.4.2 Jet Pumps ........... B 3.4-10 B 3.4.3 Safety Relief Valves (SRVs) and Safety Valves (SVs) B 3.4-15 B 3.4.4 RCS Operational LEAKAGE . . . . . . . . . . . . . B 3.4-21 B 3.4.5 RCS Leakage Detection Instrumentation . . . . . . B 3.4-27 B 3.4.6 RCS Specific Activity . . . . . . . . . . . . . . B 3.4-33 B 3.4.7 Residual Heat Removal. (RHR) Shutdown Cooling System-Hot Shutdown . . . . . . . . B 3.4-37 B 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown . . . B 3.4-43 B 3.4.9 RCS Pressure and Temperature (PIT) Limits . . . . B 3.4-49 B 3.4.10 Reactor Steam Dome Pressure . . . . . . . . . . . B 3.4-59 B 3.5 -EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM . . . . . . . . . . . B 3.5-1 B 3.5.1 ECCS -Operating . . ... . . . . . . . . . . . . . B 3.5-1 B 3.5.2 ECCS -Shutdown . . . . . . . . . . . . . . . . . . B 3.5-21 B 3.5.3 RCIC System ................... B 3.5-27 B 3.6 CONTAINMENT SYSTEMS ................. B 3.6-1 B 3.6.1.1 Primary Containment . . . . . . . . . . . . . . . B 3.6-1 B 3.6.1.2 Primary Containment Air Lock . . . . . . . . . . . B 3.6-6 B 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . . . B 3.6-14 B 3.6.1.4 Drywell Air Temperature . . . . . . . . . . . . . B 3.6-30 B 3.6.1.5 Low-Low Set (LLS) Valves . . . . . . . . . . . . . B 3.6-33 B 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers . ... . . . . . . . . ... . . . . . . B 3.6-37 B 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers . . B 3.6-43 B 3.6.2.1 Suppression Pool Average Temperature . . . . . . . B 3.6-49 B 3.6.2.2 Suppression Pool Water Level . . . . . . . . . . . B 3.6-55 B 3.6.2.3 Residual Heat Removal MRHR) Suppression Pool Cooling . . . . . . . . . . . . . . . . . . . . B 3.6-59 B 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray B 3.6-65 B 3.6.3.1 Containment Atmosphere Dilution (CAD) System . . . B 3.6-69 B 3.6.3.2 Primary Containment Oxygen Concentration . . . . . B 3.6-74 B 3.6.4.1 Secondary Containment . B 3.6-78 B 3.6.4.2 Secondary Containment Isolation Valves/Dampers (SCIV/Ds) . . . . . . B 3.6-83 B 3.6.4.3 Standby Gas Treatment (SBGT) System. B 3.6-90 B 3.7 PLANT SYSTEMS . . . . . . . . . . . . . . . . . . . . B 3.7-1 B 3.7.1 Residual Heat Removal Service Water (RHRSW) System B 3.7-1 B 3.7.2 River Water Supply (RWS) System and Ultimate Heat Sink (UHS) .. B 3.7-7 B 3.7.3 Emergency Service Water (ESW) System. B 3.7-13 B 3.7.4 Standby Filter Unit (SFU) System . . . . . . . . . B 3.7-18 B 3.7.5 Control Building Chiller (CBC) System . . . . . . B 3.7-25 (continued)

DAEC ii Amendment 223

TABLE OF CONTENTS B 3.7 PLANT SYSTEMS (continued)

B 3.7.6 Main Condenser Offgas . . . . . . . . . . . . . B 3.7-30 B 3.7.7 Main Turbine Bypass System . . . . . . . . . . . B 3.7-33 B 3.7.8 Spent Fuel Storage Pool Water Level . . . . . . B 3.7-37 B 3.8 ELECTRICAL POWER SYSTEMS . . . . . . . . . . . . .. B 3.8-1 B 3.8.1 AC Sources- Operating . . . . . . . . . . . .. B 3.8-1 B 3.8.2 AC Sources- Shutdown . . . . B 3.8-26 B 3.8.3 Diesel Fuel Oil. Lube Oil. and Starting Air. B 3.8-32 B 3.8.4 DC Sources- Operating . . . . . . . . . . . . . B 3.8-41 B 3.8.5 -DC Sources-Shutdown . . . . . . . . . . . . . . B 3.8-52 B 3.8.6 Battery Cell Parameters . . . . . . . . . . . . B 3.8-56 B 3.8.7 Distribution Systems - Operating . . . . . . . . B 3.8-63 B 3.8.8 Distribution Systems- Shutdown . . . ... . . . . B 3.8-74 B 3.9 REFUELING OPERATIONS .... B 3.9-1 B 3.9.1 Refueling Equipment Interlocks. . . . . . . . . B 3.9-1 B 3.9.2 Refuel Position One-Rod-Out Interlock . . . . . B 3.9-5 B 3.9.3 Control Rod Position . . . . . . . . . . . . . . B 3.9-9 B 3.9.4 Control Rod Position Indication . . . . . . . . B 3.9-12 B 3.9.5 Control Rod OPERABILITY- Refueling . . . . . . . B 3.9-16 B 3.9.6 Reactor Pressure Vessel (RPV) Water Level . . . B 3.9-19 B 3.9.7 Residual Heat Removal (RHR)- High Water Level B 3.9-22 B 3.9.8 Residual Heat Removal (RHR)- Low Water Level B 3.9-27 B 3.10 SPECIAL OPERATIONS ............... B 3.10-1 B 3.10.1 System Leakage and Hydrostatic Testing Operation B 3.10-1 B 3.10.2 Reactor Mode Switch Interlock Testing . . . . . B 3.10-6 B 3.10.3 Single Control Rod Withdrawal- Hot Shutdown B 3.10-11 B 3.10.4 Single Control Rod Withdrawal- Cold Shutdown B 3.10-16 B 3.10.5 Single Control Rod Drive (CRD)

Removal - Refueling . B 3.10-21 B 3.10.6 Multiple Control Rod Withdrawal'- Refueling . . . B 3.10-26 B 3.10.7 Control Rod Testing - Operating . . . . . . . . . B 3.10-29 B 3.10.8 SHUTDOWN MARGIN (SDM) Test -Refueling ..... B 3.10-33 DAEC iii Amendment 223

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

NOTE-------------------------------------

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific HEAT GENERATION RATE planar height and is equal to the sum of the (APLHGR) heat generation rate per unit length of fuel rod for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle at the height.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY and the CHANNEL FUNCTIONAL TEST.

Calibration of instrument channels with Resistance Temperature [etector (RTD) or thermocouple sensors may consist -,f an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps. I (continued)

DAEC 1.1-1 Amendment No. 234 OCT 0 3 2000

I . Definitions 1.1 1.1 Definitions ;cont-,nued)

I CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

DAEC 1.1-2 (continued)

Amendment No. 234 (CT 0 3 2000

Definitions 1.1 1.1 Definitions (continued)

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT I-131 DOSE EQUIVALENT 1-131 shall be that concentration of I-131 (microcuries/ml), that alone would produce the same dose as the quantity and isotopic I mixture of 1-131, I-132, 1-133, I-134, and I-135 actually present. The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11. "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1989 and FGR 12, "External Exposure to Radionuclides in Air. Water, and Soil," 1993.

END OF CYCLE The EOC RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP TRIP time interval from initial signal generation by (EOC RPT) SYSTEM RESPONSE the associated turbine stop valve limit switch or TIME from when the turbine control valve hydraulic oil control oil pressure drops below the pressure switch setpoint to actuation of the breaker secondary (auxiliary) contact. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

1.1-3 (continued)

DAEC 1.1-3 Amendment 240

Definitions 1.1

.1 Definitions (continued)

EAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell, such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known not to interfere with the operation of leakage detection systems;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE:

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE.

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test TEST of all logic components required for OPERABILITY I of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power RATIO (MCPR) ratio (CPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience transition boiling, divided by the actual assembly operating power.

Transition boiling means the boiling regime between nucleate and film boiling. Transition boiling is the regime in which both nucleate and (continued)

CAEC 1.1-4 Amendment No. 234 OCT 0 3 26f3

. ' j4 - , I

_ .i 1.1 Definitions (contilnLIEd-)

MINIMUM CRITICAL POWER film boiling occur intermittently with neither RATIO (MCPR) (continued) type being completely stable.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE - OPERABILITY A system, subsystem, division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 1912 MWt. I REACTOR PROTECTION The RPS RESPONSE TIME shall be that time interval SYSTEM (RPS) RESPONSE from when the monitored parameter exceeds its RPS TI ME trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

DAEC 1.1-5 Amendment2Zi,243 11OV 0 6 2031

Definitions 1.1 1.1 Definitions (continued)

SHUTDOWN MARGIN (SDM) SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that:

a. The reactor is xenon free:

b. The moderator temperature is 680 F (200C): and

c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn with the core in its most reactive state during the operating cycle. With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems.

channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems.

channels, or other designated components are tested during n Surveillance Frequency intervals.

where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

(continued)

DAEC 1.1-6 Amendment 223

Definitions 1.1 1.1 Definitions (continued)

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TURBINE BYPASS SYSTEM The TURBINE BYPASS SYSTEM RESPONSE RESPONSE TIME TIME consists .of two components:

a. The time from initial movement of the main turbine stop valve or control valve until. 80%

of the turbine bypass capacity is established:

and

b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve.

The response time may be measured by means of any series of sequential. overlapping, or total steps so that the entire response time is measured.

DAEC 1.1-7 Amendment 223

Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES REACTOR MODE AVERAGE REACTOR MODE TITLE SWITCH POSITION COOLANT TEMPERATURE

(.)

1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot NA Standby 3 Hot Shutdown(a) Shutdown > 212 4 Cold Shutdown(a) Shutdown < 212 5 Refueling(b) Shutdown or Refuel NA (a) All reactor vessel head closure bolts fully tensioned.

(b) One or more reactor vessel head closure bolts less than fully tensioned.

DAEC 1.1-8 Amendment 223

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between. and yet connect. discrete Conditions. Required Actions. Completion Times.

Surveillances, and Frequencies. The only logical connectors that appear in.TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e.. left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.

When logical connectors are used to state a Condition.

Completion Time, Surveillance, or Frequency. only the first level of logic is used. and the logical connector is left justified with the statement of the Condition. Completion Time. Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

DAEC 1 .2-1 Amendment 223

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify . . .

AND A.2 Restore . . .

In this example the logical connector AND is used to indicate that when in Condition A. both Required Actions A.1 and A.2 must be completed.

(continued)

DAEC 1.2-2 Amendment 223

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip . . .

OR A.2.1 Verify . . .

AND A.2.2.1 Reduce . . .

OR A.2.2.2 Perform . . .

OR A.3 Align . . .

This example represents a more complicated use of logical connectors. Required Actions A.1. A.2. and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen. then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND.

Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices. only one of which must be performed.

DAEC 1.2-3 Amendment 223

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with-each stated Condition are Required Action(s) and Completion Times(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g.. inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If.situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions. separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that-required entry into the Condition.

Once a Condition has been entered. subsequent divisions.

subsystems. components. or variables expressed in the Condition. discovered to be inoperable or not within limits.

will not result in separate entry into the Condition unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure. with Completion Times based on initial entry into the Condition.

(continued)

DAEC 1.3-1 Amendment 223

Completion Times 1.3 1.3 Completion Times DESCRIPTION However, when a subsequent division, subsystem. component.

(continued) or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension. two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability:

and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time. as measured from the initial entry into the Condition, plus an additional 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division, subsystem, component or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Speci fi cati ons.

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e..

"once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ." where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery . . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Condition A and B in Example 1.3-3 may not be extended.

(continued)

DAEC 1.3-2 Amendment 223

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be in MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND in MODE 4 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . the time allowed for reaching MODE 4 is the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months because the total time allowed for reaching MODE 4 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3. the time allowed for reaching MODE 4 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

(continued)

DAEC 1.3-3 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

ACTIONS .

CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

When a pump is declared inoperable. Condition A is entered.

If the pump is not restored to OPERABLE status within 7 days. Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered. Conditions A and B are exited. and therefore. the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable. Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump.

The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3. if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired. LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

(continued)

DAEC 1.3-4 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

While in LCO 3.0.3. if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired. LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status. the Condition A Completion Time is not reset. but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed. provided this does not result in the second pump being inoperable for

> 7 days.

(continued)

DAEC 1.3-5 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of.

failure to meet the LCO C. One C.1 Restore .72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X Function X subsystem subsystem to inoperable. OPERABLE status.

AND OR One C.2 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y subsystem subsystem to inoperable. OPERABLE status.

(continued)

DAEC 1.3-6 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X subsystem and one Function Y subsystem are inoperable. Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem.

starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time. Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired.

operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e.. initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. Inthis example, without the separate Completion Time.

it would be possible to alternate between Conditions A. B.

and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO.

The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO.

This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance. the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met.

instead of at the time the associated Condition was entered.

(continued)

DAEC 1.3-7 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves to OPERABLE inoperable. status.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a Per valve basis.

Declaring subsequent valves inoperable. while Condition A is still in effect. does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status.

the Condition A Completion Time is not reset. but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (plus the extension) expires while one or more valves are still inoperable.

Condition B is entered.

(continued)

DAEC 1.3-8 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

ACTIONS

NOTE----------------------------

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition. the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable.

Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable. Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

(continued)

DAEC 1.3-9 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires. Condition B is entered for that valve.

If the Completion Times associated with subsequent valves in Condition A expire. Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status. Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times. Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable. SR 3.x.x.x. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to 5 50%

RTP.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated Completion Time not met.

(continued)

DAEC 1 .3-10 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2. to each performance after the initial performance.

The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.1 is followed and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2). Condition B is entered.

- If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met. Condition B is entered.

If after entry into Condition B. Required Action A.1 or A.2 is met. Condition B is exited and operation may then continue in Condition A.

(continued)

DAEC 1.3-11 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem inoperable. isolated. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

B. Required B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

If after Condition A is entered. Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2). Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered. but continues from the time Condition A was initially entered. If Required Action A.1 (continued)

DAEC 1.3-12 Amendment 223

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued) is met after Condition B is entered. Condition B is exited and operation may continue in accordance with Condition A.

provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When "Immediately" is used as a Completion Time. the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.

DAEC 1.3-13 Amendment 223

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

The use of "met" or "performed" in these instances conveys specific meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance (continued)

DAEC 1 .4-1 Amendment 258

Frequency 1.4 1.4 Frequency DESCRIPTION criteria. Some Surveillances contain notes that modify (continued) the Frequency of performance or the conditions during which the acceptance criteria must be satisfied. For these Surveillances, the MODE-entry restrictions of SR 3.0.4 may not apply. Such a Surveillance isnot required to be performed prior to entering a MODE or other specified condition in the Applicability of the associated LCO ifany of the following three conditions are satisfied:

a. The Surveillance is not required to be met in the MODE or other specified condition to be entered; or

b. The Surveillance is required to be met in the MODE or other specified condition to be entered, but has been performed within the specified Frequency (i.e.,.

it is current) and is known not to be fail6d; or

c. The Surveillance is required to be met, but not performed, in the MODE or other specified condition to be entered, and is known not to be failed.

Examples 1.4-3. 1.4-4, 1.4-5, and 1.4-6 discusses these special situations.

(continued) 1.4-2 Amendment 258 DAEC DAEC 1.4-E Amendment 258

Frequency 1.4 1.4 Frequency (continued)

EXA1PLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS _

SURVEI LLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time.

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other.specified condition in the Applicability of the [CO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4). then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4.

(continued)

DAEC 1.4-3 Amendment Nb. 258 Create BGkZ 6~1 - 2 q -0

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 (continued)

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 2 25%

RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level < 25% RTP to

Ž 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "'AND"). This type of Frequency does not qualify for the extension allowed by SR 3.0.2.

"Thereafter" indicates future performances must be established per SR 3.0.2. but only after a specified condition is first met (i.e.. the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

(continued)

DAEC 1.4-4 Amendment Nb. 258 po -Kc9&- ?6 Wn

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

N()TE---------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after ~ 25% RTP.

Perform channel adjustment. 7 days The interval continues whether or not the unit operation is

< 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches ~ 25% RTP to perform the Surveillance. The Surveillance is still considered to be within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day interval (plus the extension allowed by SR 3.0.2), but operation was < 25% RTP, it would not constitute a failure of the SR or failure to meet the LC(). Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (plus the extension allowed by SR 3.0.2) with power ~ 25%

RTP.

()nce the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval (plus the extension allowed by SR 3.0.2), there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

(continued)

DAEC 1.4-5 Amendment No. 271

Frequency 1.4 1.4 Frequency EXAMPLES *EXAMPLE 1,4-4 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE--------------------

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to bemet until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance wiere not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2). but the unit was not in MODE 1, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

(continued)

DAEC 1.4-6 Amendment Nb. 258 60W tw* h&4 6 W &- C? V-ew~5

I .

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-5 (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE--------------------

Only required to'be met in MODE 1.

Perform complete cycle of the valve 7 days The interval continues, whether or not the unit operation is in MODE 1, 2 or 3 (the assumed Applicability of the associated LCO) between performances.

As the Note modifies the required performance of the Surveillance, the Nbte is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is not in MODE 1, this Note allows entry into and operation in MODES 2 and 3 to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency" if completed prior to entering MODE 1. Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was not in MODE 1. it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not result in entry into M4ODE 1.

Once the unit reaches MODE 1. the requirement for the Surveillance to be performed within its specified Frequency applies and would require that the Surveillance had been performed.. If the Surveillance were not performed prior to entering MODE 1, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

(continued)

DAEC 1.4-7 Amendment Nl.258 b"r-AW eV &-c0/?V-Cpa

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-6 (continued)

SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY

NOTE--------------------

Not required to be in MODE 3.

Verify parameter is within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Example 1.4-6 specifies that the requirements of this Surveillance do not have to be met while the unit is in MODE 3 (the assumed Applicability of the associated LCO is MODES 1.

2, and 3). The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance.

Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months interval (plus the extension allowed by SR 3.0.2), and the unit was-in MODE 3, there would be no failure of the-SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES to enter MODE 3, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change does not result in entry into MODE 2. Prior to entering MODE.2 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

DAEC 1.4-8 Amendment Nb. 258 uemiKm- fV, id6 6 - -

2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs 2.1.1.1 Fuel Cladding Integrity - With the reactor steam dome pressure < 785 psig or core flow < 10% rated core flow:

THERMAL POWER shall be < 21.7% RTP.

2.1.1.2 MCPR - With the reactor steam dome pressure 2 785 psig and core flow > 10% rated core flow:

MCPR shall be 2 1.10 for two recirculation loop operation or 2 1.12 for single recirculation loop operation.

2.1.1.3 Reactor Vessel Water Level - Reactor vessel water level shall be greater than 15 inches above the top of active irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be < 1335 psig.

2.2 SL Violations With any SL violation, the following actions shall be completed within 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months s:

2.2.1 Restore compliance with all SLs; and 2.2.2 Fully insert all insertable rods.

DAEC 2.0-1 Amendment Z ,243 NOV 0 6 2031

LOO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCos shall be met during the MODES or other specified conditions in the Applicability, except as provided in L*2O 3.0.2, LCO 3.0.7, and LCO 3.0.8.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Ccapletion Time (s), completion of the Required Action(s) is not required, unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which' the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 2 within 9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months ;

b. MODE 3 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 4 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are conpleted that permit operation in accordance with the LCO or ACTIONS, carpletion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, and 3.

LOO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; (continued)

DAEC 3.0-1 Amendment 263

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 b. After performance of a risk assessment addressing (continued) inoperable systems and components, consideration of the results, determination of the acceptability of entering the MIODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in 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.

I LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. Inthis event, an evaluation shall be performed in accordance with Specification 5.5.11, "Safety Function Determination Program (SFDP)." 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.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

(continued)

DAEC 3.0-2 AlID 255 i

f A LCOApplicabilit 3.0 3.0 LC0 APPLICABILITY (continued)

ICO 3.0.7 Special Operations LCOs in Section 3.10 allow specified Technical Specifications (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Special Operations LCOs is optional. When a Special Operations 112 is desired to be met but is not met, the ACTIONS of the Special Operations LCO shall be met. When a Special Operations 112 is not desired to be met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with the other applicable Specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:

a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; or

b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met.

DAEC 3.0-3 3rmendment 263

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR.

Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as 'once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per. ..

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

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 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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.

(continued)

DAEC 3.04 Amendment No246

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

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.

I DAEC 3.0-5 AMD 255 I

- n t. - .,

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be:

a. 2 0.38% Ak/k, with the highest worth control rod analytically determined: or

b. 2 0.28% Ak/k. with the highest worth control rod determined by test.

APPLICABILITY: - MODES 1. 2. 3. 4. and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limits A.1 Restore SDM to within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in MODE 1 or 2. limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

C. SDM not within limits C.1 Initiate action to Immediately in MODE 3. fully insert all insertable control rods.

D. SDM not within limits D.1. Initiate action to Immediately in MODE 4. fully insert all insertable control rods.

AND (continued)

DAEC 3.1-1 Amendment 223

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary containment to OPERABLE status.

AND D.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one Standby Gas Treatment (SBGT).

subsystem to OPERABLE status.

AND D.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each required secondary containment penetration flow path not isolated.

E. SDM not within limits E.1 Suspend CORE Immediately in MODE 5. ALTERATIONS except for control rod insertion and fuel assembly removal.

AND E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

DAEC 3.1-2 Amendment 223

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore secondary .

containment to OPERABLE status.

AND E.4 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore one SBGT subsystem to OPERABLE status.

AND E.5 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore isolation capability in each requi red secondary containment penetration flow path not isolated.

DAEC 3.1-3 Amendment 223

SDM 3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY I

SR 3.1.1.1 Verify SDM is: Prior to each in vessel fuel

.a. > 0.38% Ak/k with the highest worth movement during control rod analytically determined: fuel loading or sequence

b. ; 0.28% Ak/k with the highest worth AND control rod determined by test.

Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after criticality following fuel movement within the reactor pressure vessel or control rod replacement DAEC 3.1-4 Amendment 223

Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 The reactivity difference between the monitored rod density and the predicted rod density shall be within +/- 1% Ak/k.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months difference not within reactivity difference limit. to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

DAEC 3.1-5 Amendment 223

Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.1.2.1 Verify core reactivity difference between Once within

.the monitored rod density and the predicted 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after rod density is within + 1% Ak/k. reaching equilibrium conditions following startup after fuel movement within the reactor pressure vessel or control rod replacement AND 1000 MWD/T thereafter during operations in MODE 1 DAEC 3.1-6 Amendment 223

Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

--- ---------------- NOTE-------------------------------------

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control ------------NOTE-------------

rod stuck. Rod Worth Minimizer (RWM) may be bypassed as allowed by LCO 3.3.2.1. "Control Rod Block Instrumentation." if required, to allow continued operation.

A.1 Verify stuck control Immediately rod separation criteria are met.

AND A.2 Disarm the associated 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Control Rod Drive (CRD).

AND (continued)

DAEC 3.1-7 Amendment 223

Control Rod OPERABILITY 3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Perform SR 3.1.3.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months each withdrawn from discovery of OPERABLE control Condition A rod. concurrent with THERMAL POWER greater than the Low Power Setpoint (LPSP) of the AND RWM.

A.4 Perform SR 3.1.1.1 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B. Two or more B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months withdrawn control rods stuck.

C. One or more control C.1 -----------NOTE-----------

rods inoperable for RWM may be reasons other than bypassed as allowed Condition A or B. by LCO 3.3.2.1, if required, to allow insertion of inoperable control rod and continued operation.

Fully insert inoperable 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months control rod.

AND (continued)

DAEC 3.1-8 Amendment 271 Corrected by letter dated 11/21/08

Control Rod OPERABILITY 3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

D. --------- NOTE--------- D.1 Restore compliance 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Not applicable when with BPWS.

THERMAL POWER

> 10% RTP. OR D.2 Restore control rod 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Two or more inoperable to OPERABLE status.

control rods not in compliance with Banked Position Withdrawal Sequence (BPWS) and not separated by two or more OPERABLE control rods.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A.

C. or D. not met.

OR Nine or more control rods inoperable.

DAEC 3.1-9 Amendment 223

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.1.3.2 ---------------------------NOTE---------------------------

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than 20% RTP.

Insert each withdrawn control rod at least one 31 days notch.

SR 3.1.3.3 Verify each control rod scram time from fUlly In accordance withdrawn to notch position 04 is with SR 3.1.4.1

~ 7 seconds. and SR 3.1.4.2 SR 3.1.3.4 Verify each withdrawn control rod does not Each time the go to the withdrawn overtravel position. control rod is withdrawn to "full out" position Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling DAEC 3.1-10 Amendment No. 271

Control Rod OPERABILITY 3.1.3 This Page Intentionally Blank per Amendment DAEC 3.1-11 Amendment No. 271

Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 6 OPERABLE control rods shall be "slow." in accordance with Table 3.1.4-1: .and .

b. No more than 2 OPERABLE control rods that are "slow" shall occupy adjacent locations.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months LCO not met.

SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

During single control rod scram time Surveillances. the Control Rod Drive (CRD) pumps shall be isolated from the associated scram accumulator.

SURVEILLANCE

FREQUENCY SR 3.1.4.1 Verify each control rod scram time is Prior to within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure a 800 psig. 40% RTP after each refueling AND (continued)

DAEC 3.1-12 Amendment 223

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 (continued) Prior to exceeding 40% RTP after each reactor shutdown

. 120 days SR 3.1.4.2 -Verify each affected control rod scram time Prior to is within the limits of Table 3.1.4-1 with exceeding reactor steam dome pressure > 800 psig. 40% RTP after work on control rod or CRD System that could affect scram time AND Prior to exceeding 40%

RTP after fuel movement within the reactor pressure vessel DAEC 3.1-13 Amendment 223

Control Rod Scram Times 3.1.4 Table 3.1.4-1 (page 1 of 1)

Control Rod Scram Times

~()TE:S---------------------------------------------------------

3. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."

4. Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod OPERABILITY," for control rods with scram times> 7 seconds to notch position

04. These control rods are inoperable, in accordance with SR 3.1.3.3, and are not considered "slow."

SCRAM TIMES(a) (seconds) when RE:ACTOR STEAM DOME NOTCH POSITIO~ PRE:SSURE: ~ 800 psig 46 0.44 38 0.93 26 1.83 06 3.35 (b) Maximum scram time from fully withdrawn position, based on de-energization of scram pilot valve solenoids at time zero.

DAEC 3.1-14 Amendment No. 271

Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 Each control rod scram accumulator shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A.1 -------- NOTE---------

accumulator inoperable Only applicable if with reactor steam the associated dome pressure control rod scram 2 900 psig. time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod scram time "slow."

OR A.2 Declare the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated control rod inoperable.

(continued)

DAEC 3.1-15 Amendment 223

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION R REQUIRED ACTION COMPLETION TIME B. Two or more control B.1 Restore charging 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from rod scram accumulators water header pressure discovery of inoperable with to 2 940 psig. Condition B reactor steam dome concurrent with pressure a 900 psig. charging water header pressure

< 940 psig AND B.2.1 --- NOTE---------

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod scram time "sllow."

OR B.2.2 Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod inoperable.

(continued)

DAEC 3.1-16 Amendment 223

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more control C.1 Verify all control Immediately upon rod scram accumulators rods associated with. discovery of inoperable with, inoperable charging water reactor steam dome accumulators are header pressure pressure < 900 psig. fully inserted. < 940 psig AND C.2 Declare the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated control rod inoperable.

D. Required Action and D.1 -------- NOTE---------

associated Completion Not applicable if all Time of Required inoperable control Action B.1 or C.1 not rod scram met. accumulators are associated with fully inserted control rods.

Place the reactor Immediately mode switch in the Shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator 7 days pressure is 2 940 psig.

DAEC 3.1-17 .Amendment 223

Rod Pattern Control 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Rod Pattern Control LCO 3.1.6 OPERABLE control rods shall comply with the requirements of the Banked Position Withdrawal Sequence (BPWS).

APPLICABILITY: MODES 1 and 2 with THERMAL POWER < 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more OPERABLE A.1 -------- NOTE---------

control rods not in Rod Worth Minimizer compliance with BPWS. (RWM) may be bypassed as allowed by LCO 3.3.2.1. "Control Rod Block Instrumentation."

Move associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod(s) to correct position.

OR A.2 Declare associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months control rod(s) inoperable.

(continued)

DAEC 3.1-18 Amendment 223

Rod Pattern Control 3.1.6 ACTIONS (continued)

CONDITION -REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 --------NOTE-------

control rods not in Rod Worth Minimizer compliance with BPWS. (RWM) may be bypassed as allowed by LCO 3.3.2.1.

Suspend withdrawal of Immediately control rods.

AND B.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the Shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with BPWS.

DAEC 3.1-19 Amendment 223

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO .3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLC subsystem A.1 Restore SLC subsystem 7 days inoperable. to OPERABLE status.

B. Two SLC subsystems B.1 Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable. subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

DAEC 3;1-20 Amendment 223

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pentaborate solution is within the limits of Figure 3.1.7-1.

SR 3.1.7.2 Verify temperature of sodium pentaborate 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months solution is within the limits of Figure 3.1.7-2.

SR 3.1.7.3 Verify temperature of pump suction piping 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is within the limits of Figure 3.1.7-2.

SR 3.1.7.4 Verify continuity of explosive charge. 31 days SR 3.1.7.5 Verify the concentration of boron in 31 days solution is within the limits of Figure 3.1.7-1. AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or boron is added to solution AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the limits of Figure 3.1.7-2 (continued)

DAEC 3.1-21 Amendment 223

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each pump develops a flow rate In accordance 2 26.2 gpm at a discharge pressure . . with the 2 1150 psig. Inservice Testing Program SR 3.1.7.7 Verify flow through one SLC subsystem from 24 months on a

-pump into reactor pressure vessel. STAGGERED TEST BASIS SR 3.1.7.8 Verify all heat traced piping between 24 months storage tank and pump suction is unblocked.

AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the limits of Figure 3.1.7-2 DAEC 3.1-22 Amendment 223

SLC System 3.1.7 1I 14 a

4 .

0 - Acceptable -_

M B, 13 i, .

Z c OZ; r-

\ / to 12 (2804, 11.8) -____

11 1500 2000 2500 3000 3500 AVAILABLE VOLUME OF SOLULION IN TANK (Pfflons)

I Figure 3.1.7-1 (page 1 of 1)

Sodium Pentaborate Solution Volume Versus Concentration ReQuirements DAEC 3.1-23 Amendment No. 236

SLC System 3.1.7 110 100 90 iL w

c- 80 IL LuJ Lij 70 60 50 11 12 13 14 15 CONCENTRATION (Weight Percent Pentaborate in Solution)

Figure 3.1.7-2 (page 1 of 1)

Sodium Pentaborate Solution Temperature Versus Concentration Requirements DAEC 3.1-24 Revision A

SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTES-------------------

1. Separate Condition entry is allowed for each SDV vent and drain line.

2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent A.1 Isolate the 7 days or drain lines with associated line.

pne valve inoperable.

B. One or more SDV vent B.1 Isolate the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or drain lines with associated line.

both valves inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

I DAEC 3.1-25 AEC 5imt. 259

SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 -------------------NOTE--------------------

Not required to be met on vent and drain valves closed during the performance of SR 3.1.8.2.

Verify each SDV vent and drain valve is 31 days open.

SR 3.1.8.2 Cycle each SDV vent and drain valve to the In accordance fully closed and fully open position. with the Inservice Testing Program SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months

a. Closes in < 30 seconds after receipt of an actual or simulated scram signal: and

b. Opens when the actual or simulated scram signal is reset.

DAEC 3.1-26 Amendment 223

3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER > 21.7%' RTP. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 21.7% RTP. I Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all :%PLHGRs are less than or equal Orce .W4',n to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 21.7% RTP I AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter DAEC 3.2-1 AmendmentZZ1, 243 t0V 0 6 2091

3.2 POWJER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (rs1CPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER Ž 21.7% RTP. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits. within limits.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 21.7% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2., Ver 'fi a'1 IKPRs are greater than or equal Once within to the limits specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 21.7% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter (continued)

DAEC 3.2-2 AmendmentZY,243 r 0V 0 6 2031

MCPR 3.2.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.2.2 Determine the MCPR limits. Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.1 AND Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each completion of SR 3.1.4.2.

DAEC 3.2-3 Amendment 223

RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.1-1.

ACTIONS

---------------------- NOTE-------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION l_COMPLETION TIME A. One or more required A.1 *Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable. trip-.-

OR A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

B. One or more Functions B.1 Place channel in one 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one or more- trip system in trip.

required channels inoperable in both DR trip systems.

B.2 Place one trip system 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in trip.

(continued)

DAEC 3.3-1 Amendment 223

.1- . .- . .

ACTIONS (continued)

COUDITION REOUIRED ACTION COMPLETION TIME C. One or more Functions .1 Restore RPS trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability.

capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A. Table 3.3.1.1-1 for B, or C not met. the channel.

E. As required by E.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Action D.1 to < 26% RTP. I and referenced in Table 3.3.1.1-1.

F. As required by F.i Be in MODE 2. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by H.1 Tr liate action to Immediately Required Action D.1 fully insert all and referenced in insertable control Table 3.3.1.1-1. rods in core cells containing one or more fuel assemblies.

DAEC 3.3-2 AmendmentZZj,243 R~'G § ^,.

SURVEILLANCE REQUIREMENTS

1TES--------------------

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.1.2 ------------------ NOTE-------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERM1AL POWER > 21.7% RTP. I Verify the absolute difference between 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the Average Power Range Monitor (APRM) channels and the calculated power is

< 2% RTP plus any gain adjustment required by LCO 3.4.1, "Recirculation Loops Operating," while operating at >

21.7% RTP. I SR 3.3.1.1.3 Perform a functional test of each 7 days automatic scram contactor.

SR 3.3.1.1.4 ------------------NOTE-------------------

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days (continued)

DAEC 3.3-3 AmendmenIZZ,243 V 0 0 231i S0

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 7 days SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST.

SR 3.3.1.1.6 Verify the Source Range Monitor (SRM) and Prior to Intermediate Range Monitor (IRM) channels withdrawing overlap. SRMs from the fully inserted position SR 3.3.1.1.7 ------------------NOTE-------------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.8 Calibrate the local power range monitors. 1000 MWD/T average core exposure SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.10 Calibrate the trip units. 92 days.

SR 3.3.1.1.11 Perform CHANNEL CALIBRATION. 92 days (continued)

DAEC 3.3-4 Amendment 223

- l. b* . -! L I- _- 7 i . :l

- . .t SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.12 ------- CTES----------

1. NleUtron de-ectors are excluded.

2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 184 days SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.1.1.14 ------------------ NOTES------------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHArINEL CALIBRATION. 24 months SR 3.3.2.1.2 5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.16 Verify Turbine Stop Valve-Closure and 24 months Turbine Control Valve Fast Closure, Trip Oil Pressure - Low Functions are not bypassed when THERMAL POWER is

> 26% RTP. I (continued)

DAEC 3.3-5 Amendment221,243 1{ON' 0 G 2M91

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.17 Adjust the channel to conform to a 24 months calibrated flow signal.

24 months on a SR 3.3.1.1.18 Verify the RPS RESPONSE TIME is within STAGGERED TEST limits. BASIS SR 3.3.1.1.19 Verify the RPS logic system response time 24 months on a is within limits. STAGGERED TEST BASIS DAEC 3.3-6 Amendment 223

- : : - .. Z- - -- .7 - -- . ,

Table 3.3.1.1-1 (page I c' 3)

Rea tor Pro~ectior. System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.l REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron 2 2 G SR 3.3.1.1.1 S 125,125 divisions o!

Flux - High SR 3.3.1.1.4 full scale SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19 5 (a) 2 H SR 3.3.1.1.1 < 125/125 divisions of SR 3.3.1.1.5 full scale SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19

b. Inop 2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.15 SR 3.3.1.1.19 S(a) 2 H SR 3.3.1.1.5 NA SR 3.3.1.1.15 SR 3.3.1.1.19

2. Average Power Range Monitors

a. Neutron 2 2 G SR 3.3.1.1.1 S 16.6% RTP Flux- SR 3.3.1.1.4 Upscale, SR 3.3.1.1.7 Startup SR 3.3.1.1.8 SR 3.3.1.1.12 SR 3.3.1.1.15 SR 3.3.1.1.19

b. Flow Biased - 1 2 F SR 3.3.1.1.1 < (0.55W + 67.7) (b) (C)

High SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.15 SR 3.3.1.1.17 SR 3.3.1.1.19 (Continued)

(a) With any control rod withdrawn from a core cei containing one or more fuel assemblies.

(b) When reset for single loop operation per LCO 3.4.1, 'Recirculation Loops Operating,' the following Allowable Value applies:

< (0.55W + 61.4) (c)

I The trip setpoints may be reset by adjusting APRM gain or by recalibrating the APRMs.

(c) W is equal to the percentage of the dnve flow, where 100% drive flow Is that required to achieve 100% core flow at 100% RTP. I DAEC 3.3-7 Amendment ZZ, 243 N"OV 0 G 2001

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors (continued)

c. High Value Clamp 1 2 F SR 3.3.1.1.2 s 121.6X RTP SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.12 SR 3.3.1.1.15 SR 3.3.1.1.19

d. Inop _ 1,2 2 G SR 3.3.1.1;3 MA SR 3.3.1.1.9 SR 3.3.1.1.15 SR 3.3.1.1.19

3. Reactor Vessel Steaw 1,2 2 G SR 3.3.1.1.3 s 1069.2 psig Dome Pressure - High SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.15 SR 3.3.1.1.18 SR 3.3.1.1.19

4. Reactor Vessel Water 1,2 2 G SR 3.3.1.1.1 2 165.6 inches Level - Low SR 3.3.1.1.3 . ,,

SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.18 SR 3.3.1.1.19

5. Main Steam Isolation 1 4 F SR 3.3.1.1.3 s 10X closed Valve - Closure , SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19

6. Drywell Pressure- High 1,2 2 G SR 3.3.1.1.3 s 2.2 psig SR 3;3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15 SR '3.3.1.1.19 (continued)

DAEC 3.3-8 Amendment 223

Table 3.3.1.1-1 (page 3 c 3)

Reactor Prc:ection Sys:err. Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLAtJCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

7. Scram Discharge Volume Water Level - High

a. Resistance 1,2 2 G SR 3.3.1.1.3 S 769 ft -

Temperature SR 3.3.1.1.10 3.0 inches Detector SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19 5 (a) 2 H SR 3.3.1.1.3 S 769 ft-SR 3.3.1.1.10 3.0 inches SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19

b. Float Switch 1,2 2 G SR 3.3.1.1.3 < 769 ft -

SR 3.3.1.1.9 2.8 inches SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19 5 (a) H SR 3.3.1.1.3 S 769 ft -

SR 3.3.1.1.9 2.8 inches SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.19

8. Turbine Stop Valve - > 264 .4 E SR 3.3.1.1.3 c 100% closed I Closure RTP SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.19

9. Turbine Control Valve 2 26%,o 2 E SR 3.3.1.1.3 > 465 psig Fast Cosure, Tnp Oil RTP SR 3.3.1.1.9 Pressure - Low SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.19

10. Reactor Mode Switch - 1,2 1 G SR 3.3.1.1.13 NA Shutdown Position SR 3.3.1.1.15 Sa) 1 H SR 3.3.1.1.13 NA SR 3.3.1.1.15

11. Manual Scram 1,2 G SR 3.3.1.1.9 NA SR 3.3.1.1.15 5(a) H SR 3.3.1.1.9 NA SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

DAEC 3.3-9 Amendment2ZY, 243

['!V 0 G 2001

SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SRMs inoperable in to OPERABLE status.

MODE 2 with Intermediate Range Monitors (IRMs) on Range 2 or below.

B. Three required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 withdrawal.

with IRMs on Range 2 or below.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

(continued)

DAEC 3.3-10 Amendment 223

SRM Instrumentation 3.3.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more required D.1 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SRMs inoperable in insertable control MODE 3 or 4. rods.

D.2 Place reactor mode 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months switch in the shutdown position.

E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except MODE 5. for control rod insertion.

E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

DAEC 3.3-11 Amendment 223

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

NOTE---------------------------

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2.2 ------------------NOTES------------------

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months located in:

a. The fueled region:

b. The core quadrant where CORE ALTERATIONS are being performed. when the associated SRM is included in the fueled region: and

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed.

when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

DAEC 3.3-12 Amendment 223

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.4 --------------- NOTE-------------------

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Verify count rate is 2 3.0 cps. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months during CORE ALTERATIONS A2D 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.1.2.5 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.2.6 ------------------NOTE-------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.1.2.7 ------------------NOTES------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. 24 months DAEC 3.3-13 Amendment 223

SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CONDITIONS CHANNELS REQUIREMENTS

1. Source Range Monitor 2(e) 3 SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.2.7 3,4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.6 SR 3.3.1.2.7 5 2 (b)Cc) SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.7 (a) With IRMs on Range 2 or below.

(b) Only one SRM channel is required to be OPERABLE during spiral offload or reload when the fueled region includes only that SRM detector.

Cc) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.

DAEC 3.3-14 Amendment 223

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Rod Block Monitor A.1 Restore RBM channel 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel to OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion in trip.

Time of Condition A not met.

fiR Two RBM channels inoperable.

C. Rod Worth Minimizer C.1 Suspend control rod Immediately (RWM) inoperable movement except by during reactor scram.

startup.

D2 (continued)

DAEC 3.3-15. Amendment 223

Control Rod Block Instrumentation 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.1 Verify 2 12 rods Immediately withdrawn.

DR C.2.1.2 Verify by Immediately administrative methods that startup with RWM inoperable has not been performed in the last calendar year.

C.2.2 Verify movement of During control control rods is in rod movement compliance with Banked Position Withdrawal Sequence (BPWS) by a second licensed operator or other qualified member of the technical staff.

D. RWM inoperable during D.1 Verify movement of During control reactor shutdown. control rods is in rod movement compliance with BPWS by a second licensed operator or other qualified member of the technical staff.

(continued)

DAEC 3.3-16 Amendment 223

Control Rod Block Instrumentation 3.3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more Reactor E.1 Suspend control rod Immediately Mode Switch -Shutdown withdrawal.

Position channels inoperable.

E.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.

2. When an RBM channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days (continued)

DAEC 3.3-17 Amendment 223

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.2 ------------------NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at

10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 ------------------NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is s 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.4 ------------------NOTE-------------------

Neutron detectors are excluded.

Verify the RBM: 184 days

a. Low Power Range- Upscale Function is not bypassed when THERMAL POWER is 2 29% and < 64% RTP.

b. Intermediate Power Range-Upscale Function is not bypassed when THERMAL POWER is 2 64% and < 84% RTP.

c. High Power Range- Upscale Function is not bypassed when THERMAL POWER is 2 84% RTP.

(continued)

DAEC 3.3-18 Amendment 223

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.5 ------------------ NOTE-------------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 184 days SR 3.3.2.1.6 ------------------NOTE-------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.7 Verify control rod sequences input to the Prior to RWM are in conformance with BPWS. declaring RWM OPERABLE following loading of sequence into RWM DAEC 3.3-19 Amendment 223

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1.1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor a.' Low Power Range - Upscale (a) 2 SR 3,3.2.1.1 1 115.5/125 SR 3.3.2.1.4 divisions of SR 3.3.2.1.5 full scale

b. Intermediate Power Range - (b) 2 SR 3.3.2.1.1 < 109.7/125 Upscale SR 3.3.2.1.4 divisions of SR 3.3.2.1.5 full scale

c. High Power Range - Upscale (c),(d) 2 SR 3,3.2.1.1 _ 105.9/125 SR 3.3.2.1.4 divisions of SR 3.3.2.1.5 full scale d Inop (d),(e) 2 SR 3.3.2.1.1 NA

e. *Downscale (d),(e) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.5

.f. Bypass Time Delay (d),(e) 2 SR 3.3.2.1.1 < 2.0 seconds SR 3.3.2.1.5

2. Rod Worth Minimizer 1 (f) 2 1) 1 SR 3.3.2.1.2 NA SR 3,3.2.1.3 SR 3.3.2.1.7

3. Reactor Mode Switch - Shutdown (g) 2 SR 3,3.2.1.6 NA Position (a) THERMAL POWER > 30% and < 65% RTP and MCPR < 1.70.

(b) THERMAL POWER > 65% and < 85% RTP and MCPR < 1.70.

(c) THERMAL POWER > 85% and < 90% RTP and MCPR < 1.70.

(d) THERMAL POWER > 90% RTP and MCPR < 1.40.

(e) THERMAL POWER > 30% and < 90% RTP and MCPR < 1.70.

(f) With THERMAL POWER < 10% RTP, except dudng the reactor shutdown process if the coupling of each withdrawn control rod has been confirmed, (g) Reactor mode switch in the shutdown position.

DAEC 3.3-20 Amendment No. 268

PAM Instrumentation 3.3.3.1 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.

APPLICABILITY: . MODES 1 and 2.

ACTIONS

NOTE------------------------------------

Separate Condition entry is allowed for each Function. For Function 6. Separate Condition entry is allowed for each penetration flow path.

I CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required 30 days with one required channel to OPERABLE channel inoperable. status.

B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A Specification 5.6.6.

not met.

C. One or more Functions C.1 Restore one required 7 days with two required channel to OPERABLE channels inoperable. status.

(continued)

AMD 255 DAEC 3.3-21 I

PAM Instrumentation 3.3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3.1-1 for not met. the channel.

E. As required by E.1 Be inMODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action D.1 and referenced in Table 3.3.3.1-1.

F. As required by F.1 Initiate action in Immediately Required Action D.1 accordance with and referenced in Specification 5.6.6.

Table 3.3.3.1-1.

DAEC 3.3-22 Amendment 223

PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

These SRs apply to each Function in Table 3.3.3.1-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHANNEL CHECK. 31 days SR 3.3.3.1.2 Perform CHANNEL CALIBRATION. 24 months DAEC 3.3-23 Amendment 223

PAM Instrumentation 3.3.3.1 Table 333.1-1 (page I ot 1)

Post Acddent M*1ordng Instnrnerntbaon cONDmoIOS REIERNCED, REQUIRED FROM REQUW1m FUNcnIoN CHANNELS ACION D.1

1. Reator Steam Done Pressure 2 E

2. Reactor Vessel Water Lrvd

a. wideRange 2 E

b. FuelZone 2 E

3. Suppression Pod Water Level 2 E

4. DryweslPrsure

a. tNarowRangc 2 E

b. WkdeRange 2 E S. Prmary Contalinment kea Radiation

a. Drywel 2 F

b. Suppresslon Chamber 2 F

6. PavPostUon 2perpenetration E

wpath (aXb)

I (a) Not requied tcr slatbon valves whose associated penetraton flow path Is Isolated by at kast one closed and deactivated automatic valve, dcosed manual valve, bMMd flange, or check valve with flow through thevalvc secured.

(b) Only one pos tlon hIdcation channel Is required tor penetratlon Pow paths with only one Installed cx&rl room kedatlon channe.

DAEC 3.3-24 Amendment No. 254

Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System f

LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS Separate Condition entry is allowed for each Function. 1.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required 30 days Functions inoperable. Function to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 1Z hours associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Verify each required control circuit and 24 months transfer switch is capable of performing the intended function.

(continued)

DAEC 3.3-25 2AMD 255

Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.3.2.2 Perform CHANNEL CALIBRATION for each 24 months required instrumentation channel.

DAEC 3.3-26 Amendment 223

1- rifT7, lo 'l-: . s - i;I

. e. . _

3.3 I NSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1 a. Two channels per trip system for each EOC-RPT instrumentation Function listed below shall be OPERABLE:

1. Turbine Stop Valve (TSV) - Closure; and

2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure-Low.

OR

b. LCO 3.2.2 "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for inoperable EOC-RPT as specified in the COLR are made applicable.

APPLICABILITY: THERMAL POWER > 26% RTP. I ACTI ONS

NOTE --------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION l REOUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

OR A.2 -------- NOTE --------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trip.

(continued)

DAEC 3.3-27 AmendmentZ0M, 243 6'lD2L,,1

aJ11ZH

-t¢u?-mr-tfT.L ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more FunctioNns B.1 Restore EOC-RPT trip 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with EOC-RPT trip J capability.

capability not maintained. OR AND 5.2 Apply the tM1CPR limit 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for inoperable MCPR limit for EOC-RPT as specified inoperable EOC-RPT in the COLR.

not made applicable.

C. Required Action and C.1 Remove the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion recircluation pump Time not met. from service.

OR C.2 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to < 26% RTP.

I SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

When a channel is placed in an inoperable status solely for perDrrmanc- r; required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains EOC-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days (continued)

DAEC 3.3-28 Amendment 273,243

["",._ f.r A __

7 J,~~

~ ~

I SURVEILLANCE REOUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.2 Perform CHANNEL CALIBRATION. The 24 months Allowable Values shall be:

TSV - Closure: < 10% closed; and TCV Fast Closure, Trip Oil Pressure - Low:

> 465 psig.

SR 3.3.4.1.3 Perform LOGIC SYSTEM FUNCTIONAL TEST 24 months including breaker actuation.

SR 3.3.4.1.4 Verify TSV - Closure and TCV Fast Closure, 24 months Trip Oil Pressure - Low Functions are not bypassed when THERMAL POWER is > 26 % RTP.

I SR 3.3.4.1.5 Verify the EOC-RPT SYSTEM RESPONSE TIME 24 months on a is within limits. STAGGERED TEST BASIS DAEC 3.3-29 AmendmentiZM,243 INOV 0 G 2001

ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation LCO 3.3.4.2 Two channels in a trip system for each ATh'S-RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level- Low Low; and

b. Reactor Steam Dome Pressure- High.

APPLICABILITY: - MODE 1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One Function with one A.1 Restore ATWS-RPT trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or more channels capability.

inoperable.

B. Both Functions with B.1 Restore ATWS-RPT trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ATWS-RPT trip capability for one capability not Function.

maintained.

C. Required Action and C.1 Remove the associated 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion recirculation pump Time not met. from service.

BD C.2 Be in MODE 2. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months DAEC 3.3-30 Amendment 223

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK on the Reactor 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vessel Water Level - Low Low Function.

SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. 12 months SR 3.3.4.2.3 Perform CHANNEL CALIBRATION. The 12 months Allowable Values shall be:

a. Reactor Vessel Water Level- Low Low

> 112.65 inches; and

b. Reactor Steam Dome Pressure- High:

< 1154.2 psig.

SR 3.3.4.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST 24 months including breaker actuation.

DAEC 3.3-31 Amendment 223

ECCS Instrumentati on 3.3.5.1 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.

APPLICABILITY: According to Iable 3.3.5.1-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the'Condition Immediately inoperable. referenced in Table 3.3.5.1-1 for the channel.

(continued).

DAEC 3.3-32 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. As required by B.1 --------NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1. 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.a. 1.b. 2.a.

and 2.b.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when redundant loss of feature(s) ECCS initiation initiation capability capability for is inoperable. feature(s) in two or more low pressure ECCS subsystems AND B.2 -------- NOTE---------

Only applicable for Functions 3.a and 3.b.

Declare High Pressure 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Coolant Injection discovery of (HPCI) System loss of HPCI inoperable. initiation capability B.3 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

(continued)

DAEC 3.3-33 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION JCOMPLETION TIME C. As required by C.1 -------- NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1. 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.c. l.e. 2.c and 2.e.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) discovery of inoperable. loss of initiation capability for two or more low pressure ECCS subsystems An C.2 -------- NOTES--------

1. Only applicable in Modes 1. 2.

and 3.

2. Only applicable for Functions 2.g. 2.h. 2.i.

and 2.j.

Declare Low Pressure 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Coolant Injection discovery of (LPCI) subsystem loss of Loop inoperable. Selection capability AND C.3 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued)

DAEC 3.3-34 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by D.1 -------- NOTE---------

Required Action A.1 Only applicable if and referenced in HPCI pump suction is Table 3.3.5.1-1. not aligned to the suppression pool.

Declare HPCI System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of HPCI suction transfer capability AD~

D.2.1 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

DR.

D.2.2 Align the HPCI pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

(continued)

DAEC 3.3-35 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION JCOMPLETION TIME E. As required by E.1 -------- NOTES--------

P-aioirPd n'Mtinn A.1 1. Only applicab'e dnd referenced rn inMODES 1. 2.

Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.d and 2.f.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) discovery of inoperable. loss of initiation capability for two or more minimum flow valves in the low pressure .4..

ECCS subsystems ADf 7 days E.2 Restore channel to OPERABLE status.

F. As required by F.1 Restore channel to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action A.1 OPERABLE status.

and referenced in Table 3.3.5.1-1.

(continued)

DAEC 3.3-36 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. As required by G.1 Declare Automatic 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 Depressurization discovery of and referenced in System (ADS) valves loss of ADS Table 3.3.5.1-1. inoperable. initiation capability in both trip logics G.2 Place channel in 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from trip. discovery of inoperable channel concurrent with HPCI or Reactor Core Isolation Cooling (RCIC) inoperable 8 days (continued)

DAEC, 3.3-37 Amendment 223

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by H.1 Declare ADS valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of ADS Table 3.3.5.1-1. initiation capability in both trip logics AD H.2 Restore channel to 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months from OPERABLE status. discovery of inoperable channel concurrent with HPCI or RCIC inoperable AND 8 days I. Required Action and I.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B. inoperable.

C. D. E. F. G or H not met.

DAEC 3.3-38 Amendment 223

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1.d. 2.f. 3.c. 3.d. 3.e. and 3.f:.and (b)for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions other than 1.d. 2.f. 3.c. 3.d. 3.e. and 3.f provided the associated Function (or the redundant Function for Functions 4 and 5) maintains ECCS initiation or loop selection capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.5.1.3 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 92 days SR 3.3.5.1.5 Perform CHANNEL FUNCTIONAL TEST. 12 months SR 3.3.5.1.6 Perform CHANNEL CALIBRATION. 12 months (continued)

DAEC 3.3-39 Amendment 223

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.1.7 Perform CHANNEL CALIBRATION. 18 months SR 3.3.5.1.8 Perform CHANNEL CALIBRATION. 24 months SR 3.3.5.1.9 - Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-40 Amendment 223

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MMES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Core Spray System

a. Reactor Vessel Water 1,2,3, 4 Cb) B SR 3.3.5.1.1 2 38.3 inches Level - Low Low Low SR 3.3.5.1.3 4 (a), 5 (a) SR 3.3.5.1.8 SR 3.3.5.1.9

b. Drywell Pressure - 1,2,3 4 (b) B SR 3.3.5.1.3 s 2.19 psig High SR 3.3.5.1.8 SR 3.3.5.1.9

c. Reactor Steam Dome 1,2,3 C SR 3.3.5.1.3 2 363.3 psig Pressure - Low SR 3.3.5.1.8 and s 485.1 (injection Permissive) SR 3.3.5.1.9 psig 4(a), 5 (a) B SR 3.3.5.1.3 2 363.3 psig SR 3.3.5.1.8 and s 485.1 SR 3.3.5.1.9 psig

d. Core Spray Pump 1,2,3, 1 per E SR 3.3.5.1.3 2 256.6 gpm Discharge Flow - Low pump SR 3.3.5.1.8 and (Bypass) 4 (a), 5 (a) SR 3.3.5.1.9 s 2382.1 gpm

e. Core Spray Pump Start 1,2,3, 1 per C SR 3.3.5.1.8 2 2.6 seconds Time Delay Relay pump SR 3.3.5.1.9 and s 6.8 4 Ca), 5 (a) seconds

f. 4.16 kV Emergency Bus 1, 2, 3, I per F SR 3.3.5.1.5 s 3500 V Sequential Loading pump SR 3.3.5.1.6 Relay 4 (a), 5 (a) SR 3.3.5.1.9

2. Low Pressure Coolant Injection (LPCI) System

a. Reactor Vessel Water 1,2,3, B SR 3.3.5.1.1 2 38.3 inches Level - Low Low Low SR 3.3.5.1.3 4 (a), 5(a) SR 3.3.5.1.8 SR 3.3.5.1.9

b. Drywell Pressure - 1,2,3 B SR 3.3.5.1.3 s 2.19 psig High SR 3.3.5.1.8 SR 3.3.5.1.9 (continued)

(a) When associated ECCS subsystem~s) are required to be OPERABLE per LCO 3.5.2, ECCS-Shutdown.

(b) Also required to initiate the associated Diesel Generator CDG).

DAEC 3.3-41 Amendment 223

. ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5)

Emergency Core Cooling System InstrLumentation APPLICABLE CONDITIONS MODES REQUIRED REFERENCED OR OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI System (continued)

c. Reactor Steam Dome 1,2,3 4 C SR 3.3.5.1.3 2 363.3 psig Pressure - Low SR 3.3.5.1.8 and s 485.1 (Injection Permissive) SR 3.3.5.1.9 psig 4 (a), 5(a) 4 B SR 3.3.5.1.3 a 363.3 psig SR 3.3.5.1.8 and s 485.1 SR 3.3.5.1.9 psig

d. Reactor Vessel Shroud 1,2,3 4 B SR 3.3.5.1.1 2 -40.89 Level - Low SR 3.3.5.1.2 inches SR 3.3.5.1.4 SR 3.3.5.1.9

e. Low Pressure Coolant 1,2,3, 1 per C SR 3.3.5.1.8 Injection Pump PUP SR 3.3.5.1.9 Start - Time Delay 4 Ca), 5 (a)

Relay Pumps A & B 2 8.8 seconds and s 11.2 seconds Pumps C & D 2 13.8 seconds and s 33.5 seconds

f. Low Pressure 1,2,3, 1 per E SR 3.3.5.1.3 2 471.8 gpm Coolant Injection Pump loop SR 3.3.5.1.8 and Discharge Flow- Low 4 (a), 5 (a) SR 3.3.5.1.9 s 3676.6 gpm (Bypass)

9. LPCI Loop Select - 1,2,3 4 C SR 3.3.5.1.1 a 112.65 Reactor Vessel Water SR 3.3.5.1.2 inches Level-Low-Low SR 3.3.5.1.6 SR 3.3.5.1.9

h. LPCI Loop Select - 1,2,3 4 C SR 3.3.5.1.2 2 887 psig Reactor Steam Dome SR 3.3.5.1.4 Pressure - Low SR 3.3.5.1.9 (continued)

(a) When associated ECCS subsystem~s) are required to be OPERABLE per LCO 3.5.2, ECCS - Shutdown.

DAEC 3.3-42 Amendment 223

ECCS Instrumentati on 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI System (continued)

i. LPCI Loop Select - 1,2,3 4 per C SR 3.3.5.1.1 s 7.8 psid Recirculation Pump pump SR 3.3.5.1.2 Differential Pressure SR 3.3.5.1.8 SR 3.3.5.1.9

j. LPCI Loop Select - 1,2,3 4 C SR 3.3.5.1.1 2 0.13 psid Recirculatifn Riser SR 3.3.5.1.2 and s 2.07 Differential Pressure SR 3.3.5.1.4 psid SR 3.3.5.1.9

k. 4.16 kV Emergency Bus 1,2,3 2 F SR 3.3.5.1.5 s 3500 V Sequential Loading SR 3.3.5.1.6 Relay SR 3.3.5.1.9 4(a), 5 (a) 1 F SR 3.3.5.1.5 s 3500 V SR 3.3.5.1.6 SR 3.3.5.1.9

3. High Pressure Coolant Injection CHPCI) System

a. Reactor Vessel Water 1, 4 B SR 3.3.5.1.1 z 112.65 Level- Low Low SR 3.3.5.1.3 inches 2(C), 3 (c) SR 3.3.5.1.6 SR 3.3.5.1.9

b. Drywell Pressure - 1, 4 B SR 3.3.5.1.3 s 2.19 psig High 2(c) (c) SR 3.3.5.1.8 2(c 3( SR 3.3.5.1.9

c. Reactor Vessel Water 1, 2 C SR 3.3.5.1.1 s 214.8 Level -High SR 3.3.5.1.3 inches 2 (c), 3 (C) SR 3.3.5.1.6 SR 3.3.5.1.9

d. Condensate Storage 1, 2 D SR 3.3.5.1.3 a 11.6 inches Tank Level - Low SR 3.3.5.1.8 2 (c), 3 (C) SR 3.3.5.1.9 (continued)

(a) When the associated ECCS subsystem(s) are required to be OPERABLE per LCO 3.5.2, ECCS - Shutdown.

(c) With reactor steam dome pressure > 150 psig.

DAEC 3. 3-43 Amendment 223

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5)

Emergency Core Cooling System Instrumentation Applicable Conditions Modes or Required Referenced Other Channels From Specified Per Required Surveillance Allowable Function Conditions Function Action A.1 Requirements Value

3. HPCI System (continued)

e. Suppression Pool Water 1, 2 D SR 3.3.5.1.3 5 5.9 inches Level - High SR 3.3.5.1.8 2(c), 3(c) SR 3.3.5.1.9

f. High Pressure Coolant 1, Injection Pump 1 E SR 3.3.5.1.3 2 264.2 gpm Discharge Flow - Low 2(c), 3(c) SR 3.3.5.1.8 and (Bypass) SR 3.3.5.1.9 5 2025.1 gpm

4. Automatic Depressurization System (ADS) Trip logic A

a. Reactor Vessel Water 1, 2 G SR 3.3.5.1.1 2 38.3 Level - Low Low Low SR 3.3.5.1.3 inches 2 (d) 3 (d) SR 3.3.5.1.8 SR 3.3.5.1.9

b. Automatic 1, 1 H SR 3.3.5.1.3

125 seconds Depressurization SR 3.3.5.1.8 System Timer 2 (d) 3 (d) SR 3.3.5.1.9 I

c. Reactor Vessel Water 1, 1 G SR 3.3.5.1.1 2 166.1 Level - Low SR 3.3.5.1.3 Inches (Confirmatory) 2(d) 3 (d) SR 3.3.5.1.8 SR 3.3.5.1.9

d. CoreSprayPump 1, 2 H SR3.3.5.1.3 2 114.2psig Discharge SR 3.3.5.1.8 and Pressure - High 2(d), 3(d) SR 3.3.5.1.9 s 177.0 psig

e. Low Pressure Coolant 1, 4 H SR 3.3.5.1.3 2 103.8 psig Injection Pump SR 3.3.5.1.8 and Discharge Pressure - 2 (d), 3(d) SR 3.3.5.1.9

147.0 psig High (continued)

(c) With reactor steam dome pressure > 150 psig.

(d) With reactor steam dome pressure > 100 psig.

DAEC 3.3-44 Amendment No. 245 FEB 2 S 2002

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5)

Emergency Core Cooling System Instrumentation Applicable Conditions Modes or Required Referenced Other Channels From Specified Per Required Surveillance Allowable Function Conditions Function Action A.1 Requirements Value

5. ADS Trip Logic B

a. Reactor Vessel Water 1, 2 G SR 3.3.5.1.1 z 38.3 inches Level - Low Low Low 2 (d), 3 (d) SR 3.3.5.1.3 SR 3.3.5.1.8 SR 3.3.5.1.9

b. Automatic 1, 1 H SR 3.3.5.1.3

125 seconds Depressurization 2 (d), 3 (d) SR 3.3.5.1.8 System Timer SR 3.3.5.1.9 I

c. Reactor Vessel Water 1, 1 G SR 3.3.5.1.1 k 166.1 Level - Low 2 (d), 3(d) SR 3.3.5.1.3 inches (Confirmatory) SR 3.3.5.1.8 SR 3.3.5.1.9

d. Core Spray Pump 1, 2 H SR 3.3.5.1.3 114.2 psig Discharge 2(d), 3(d) SR 3.3.5.1.8 and Pressure - High SR 3.3.5.1.9

177.0 psig

e. Low Pressure Coolant 1, 4 H SR 3.3.5.1.3 Ž 103.8 psig Injection Pump SR 3.3.5.1.8 and Discharge 2(d 3 (d) SR 3.3.5.1.9 5 147.0 psig Pressure - High (d) With reactor steam dome pressure > 100 psig.

DAEC 3.3-45 Amendment No. 245 FES 26 2002

RCIC System Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.2 The RCIC System instrumentation for each Function in Table-3:3;5.2-1 shal-lbe OPERABLE.

APPLICABILITY: MODE 1.

MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION [ REQUIRED ACTION ICOMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel.

1. 4 B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of RCIC Table 3.3.5.2-1. initiation capability AD1f B.2 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

I i (continued)

DAEC 3.3-46 Amendment 223

RCIC System Instrumentation 3.3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Restore channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Required Action A.1 OPERABLE status.

and referenced in Table 3.3.5.2-1.

D. As required by D.1 -------- NOTE---------

Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.2-1. not aligned to the suppression pool.

Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of RCIC suction transfer capability D.2.1 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

D.2.2 Align RCIC pump 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months suction to the suppression pool.

E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.

Time of Condition B.

C. or D not met.

DAEC 3.3-47 Amendment 223

RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 3: and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Function 1 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.2.3 Perform CHANNEL CALIBRATION. 12 months SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-48 Amendment 223

RCIC System Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS FROM REQUIRED SURVEILLANCE ALLOWABLE FUNCTION PER FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water 4 B SR 3.3.5.2.1 2 112.65 inches Level - Low Low SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.5

2. Reactor Vessel Water 2 C SR 3.3.5.2.1 s 214.8 inches Level - High SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.5

3. Condensate Storage Tank 2 D SR 3.3.5.2.2 2 11.6 inches Level - Low SR 3.3.5.2.4 SR 3.3.5.2.5 DAEC 3.3-49 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment Isolation Instrumentation LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.1-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for channels inoperable. trip. Functions 2.a.

2.b. 6.b. and 6.c 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions other than Functiors 2.a. 2.b. and AM 6.b. and 6.c A.2 -------- NOTE---------

Only applicable for Function 7.a.

Inhibit containment 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months spray system.

(continued)

DAEC 3.3-50 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more automatic B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with capability.

isolation capability not maintained.

C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A Table 3.3.6.1-1 for or B not met. the channel.

D. As required by D.1 Isolate associated 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 main steam line and referenced in (MSL).

Table 3.3.6.1-1.

2B D.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Am D.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. As required by E.1 Be in MODE 2. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Required Action C.1 and referenced in Table 3.3.6.1-1.

(continued)

DAEC 3.3-51 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. As required by F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

G. [Deleted]

H. As required by H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Required Action C.1 and referenced in AND Table 3.3.6.1-1.

H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action and associated Completion Time for Condition F not met.

I. As required by I.1 Declare Standby 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 Liquid Control (SLC) and referenced in System inoperable.

Table 3.3.6.1-1.

OR I.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

(continued)

DAEC 3.3-52 Amendment No. 231 t'!~, 0 1 20D0

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. As required by J.1 Initiate action to Immediately Required Action C.1 restore channel to and referenced in OPERABLE status.

Table 3.3.6.1-1.

DR J.2 Initiate action to Immediately isolate the Residual Heat Removal (RHR)

Shutdown Cooling System.

K. As required by K.1 --------NOTE---------

Required Action C.1 Only applicable if and referenced in inoperable channel is Table 3.3.6.1-1. not in trip.

Declare associated Immediately Suppression Pool Cooling/Spray subsystem(s) inoperable.

OR K.2 -------- NOTE---------

Only applicable if inoperable channel is in trip.

Immediately Declare Primary Containment inoperable.

(continued)

DAEC 3.3-53 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME L. As required by L.1 Isolate the primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 containment vent and and referenced in purge penetration Table 3.3.6.1-1. flow paths.

L.2 Establish 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months administrative control of the primary containment vent and purge valves using continuous monitoring of alternate instrumentation.

DAEC 3.3-54 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Function 5.a; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions other than 5.a provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.1.2 Perform CHANNEL CHECK; 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.6.1.3 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.6.1.4 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. 92 days SR 3.3.6.1.6 Perform CHANNEL CALIBRATION. 184 days SR 3.3.6.1.7 Perform CHANNEL CALIBRATION. 12 months (continued)

DAEC 3.3-55 Amendment No. 231

-JUN0 i 2XO

Primary Containment Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.1.8 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.1.9 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-56 Amendment No. 231 J1tu 0 i au0

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page I of 5)

Primary Containment Isolation instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

1. Main Steam Line Isolation

a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 > 38.3 inches Level - Low Low Low SR 3.3.6.1.4 SR 3.3.6.1.8 SR 3.3.6.1.9

b. Main Steam Line 1 2 E SR 3.3.6.1.4 > 821 pslg Pressure - Low SR 3.3.6.1.5 SR 3.3.6.1.9

c. Main Steam Line 1,2,3 2 per D SR 3.3.6.1.1 < 138% rated Flow - High MSL SR 3.3.6.1.4 steam flow SR 3.3.6.1.5 SR 3.3.6.1.9

d. Condenser 1, 2(a), 2 D SR 3.3.6.1.4 > 7.2 inches Backpressure - High (a) SR 3.3.6.1.8 Hg vacuum 3 SR 3.3.6.1.9

e. Main Steam Une Tunnel 1,2,3 4 D SR 3.3.6.1.2 < 205.1°F Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.7 SR 3.3.6.1.9 I

f. Turbine Building 1,2,3 4 D SR 3.3.6.1.2 < 205.1°F Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.7 SR 3.3.6.1.9 (continued)

(a) When any turbine stop valve is greater than 90% open or when the key-locked bypass switch Is In the NORM Position.

DAEC 3.3-57 Amendment No. 261

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

2. Primary Containment Isolation

a. Reactor Vessel Water 1,2,3 2 H SR 3.3.6.1.1 a 165.6 inches Level - Low SR 3.3.6.1.4 SR 3.3.6.1.8 SR 3.3.6.1.9

b. Drywell Pressure - High 1,2,3 2 H SR 3.3.6.1.4 s 2.2 psig SR 3.3.6.1.8 SR 3.3.6.1.9

c. Offgas Vent Stack - 1(C), 2(c), 1 L SR 3.3.6.1.2 (b)

High Radiation SR 3.3.6.1.4 3(c) SR 3.3.6.1.8 SR 3.3.6.1.9

d. Reactor Building 1,2,3 1 H SR 3.3.6.1.2 s 12.8 mR/hr Exhaust Shaft - SR 3.3.6.1.4 High Radiation . SR 3.3.6.1.8 SR 3.3.6.1.9

e. Refueling Floor 1,2,3 1 H SR 3.3.6.1.2 i 10.6 mR/hr Exhaust Duct - SR 3.3.6.1.4 High Radiation SR 3.3.6.1.8 SR 3.3.6.1.9

3. High Pressure Coolant Injection (HPCI) System Isolation

a. HPCI Steam Line Flow - 1,2,3 1 F SR 3.3.6.1.4 s 409 inches High SR 3.3.6.1.8 (inboard)

SR 3.3.6.1.9 silO inches (outboard)

(continued)

(b) ALlowable value is determined in accordance with the ODAM.

Cc) During venting or purging of primary containment.

DAEC 3.3-58 Amendment 223

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 5)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEIlUANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C1 REQUIREMENTS VALUE

3. HPCI System Isolation (continued)

b. HPUI Steam Supply Une 1,2,3 2 F SR 3.3.6.1.4 > 50 psig and Pressure - Low SR 3.3.6.1.8 < 147.1 psig SR 3.3.6.1.9

c. HPCI Turbine 1,2,3 2 F SR 3.3.6.1.4 _..2.5 psig Exhaust Diaphragm SR 3.3.6.1.8 Pressure - High SR 3.3.6.1.9

d. Drywell Pressure -High 1,2,3 1 F SR 3.3.6.1.4 < 2.2 psig SR 3.3.6.1.8 SR 3.3.6.1.9

e. Suppression Pool 1,2,3 1 F SR 3.3.6.1.2 < 153.3-F Area Ambient SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.8 SR 3.3.6.1.9

f. HPCI Leak Detection 1,2,3 1 F SR 3.3.6.1.4 N/A Time Delay SR 3.3.6.1.8 SR 3.3.6.1.9

g. Suppression Pool Area 1,2,3 1 F SR 3.3.6.1.2 51.5F Ventilation SR 3.3.6.1.4 Differential SR 3.3.6.1.8 Temperature - High SR 3.3.6.1.9

h. HPCI Equipment Room 1,2,3 1 F SR 3.3.6.1.2 < 178.3-F Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.8 SR 3.3.6.1.9 I. HPCI Room Ventilation 1,2,3 1 F SR 3.3.6.1.2 < 51.5F Differential SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.8 SR 3.3.6.1.9 (continued)

DAEC 3.3-59 Amendment No. 231 JUN 0 1 2000

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.36..1-1 (page 4 of S)

'J) Primary Contarnmeit Isolabon Inurnumentaton APPUCA8LE CONDITIONS MODES OR REQU1RED REFERENCED OTHER CHANNELS FROr SPECIFIED PERuRIP REQUIRED SURVEfLANCE ALLOWAUX FUNCrION CONDITIONS SYSTV4 ACnON C.1 REQUIREMENTS VALUE

4. AmOr Core Isolation Cooling (R5C) Sysm tsolaUon

a. RaIC Sbmm Le 1,2.3 1 F SR 3..6.1.4 'S 164 Indie l ow-High SR 3.3.6.1.8 Onboard)

SR 3.3.6.1.9 1S9 Inches (oudboar)

b. RCIC Stbam Supply 1,2,3 2 F SR 3.3.6.1.4 Og "50.3 IUne Pressure - Low SR 3J.6.1.8 SR 3.3.6.1.9 C. RCICTurbiWe 1.2.3 2 F SR 3.3.6.1.4 z33psIg Extioust Diaphragm SR 3.3.6.1.6 Pressre - HIgh SR 3.3.6.1.9

d. SDrwell Prnure - 1,2,3 1 F SR 3.3.6.L4 < 22 psIc Hwgh SR 3.3.6.1.8 SA 3.3.6.1.9 e.RCC Suppresson 1.2,3 1 F SR 3.3.6..2 5153.30F PO Area Ambient SR 33.6.1.4 Temperature.- H1h SR 3.3.6.1.3 SR 3.3.6.1.9 F. RCIC ek Detectoen 1.2,3 f F SR 3.3.6.1.4 W/A lnme Delay SR 3.3.6.1.8 SR 3.3.6.1.9

g. RCIC Suppression Pool 1,2,3 1 F SR 3.3.6.1.2 sS1.SF Area Ventilton SR 3.3.6.1.4 Differental SR 3.3.6.1.1 Temperature - High SR 3.3.6.1.9

h. RCC Enulpment Rom 1.2,3 1 F SR 33.6.1.2I 17.3-F Temperature- High SR 3.3.6.1.4 SR 3.3.6.1.0 SR 3.3.6.1.9 L RCIC Room 1,2.3 1 F SR 3.3.6.1.2 SI.S F Venuotion SR 33.6.1.4 DViferenUtal SR 33.6.1.8 Temperature- High SR 33.6.1.9 (contnued)

DAEC 3.3-60 Amendment No. 231

'JU"I 0 1 ZOO

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 5)

Primary Containment Isolation Instrunentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

5. Reactor Water Cleanup (RUCU) System Isolation

a. Differential Flow- 1,2,3 1 F SR 3.3.6.1.2 s 59 gpii High SR 3.3.6.1.4 SR 3.3.6.1.8 SR 3.3.6.1.9

b. Area Temperature -High 1,2,3 1(d) F SR 3.3.6.1.2 i 133.3 F SR 3.3.6.1.4 SR 3;3.6.1.8 SR 3.3.6.1.9

c. Area Ventilation 1,2,3 1(d) F SR 3.3.6.1.2 Differential SR 3.3.6.1.4 Temperature- High SR 3.3.6.1.8 SR 3.3.6.1.9 RWCU Pump Room s 22.5'F RWCU Pump A Room 5 23.5F RWCU Pump B Room 5 34.5F RWCU Heat Exch. Room 5 51.51F iCe)

d. SLC System Initiation 1,2 I SR 3.3.6.1.9 NA

e. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 2 112.65 Level - Low Low SR 3.3.6.1.4 inches SR 3.3.6.1.7 SR 3.3.6.1.9

f. Area Near TIP Room 1.2,3 1 F SR 3.3.6.1.2 s 115.70F Ambient Temperature - SR 3.3.6.1.4 High SR 3.3.6.1.8 SR 3.3.6.1.9

6. Shutdown Cooling System Isolation

a. Reactor Steam Dome 1,2,3 1 F SR 3.3.6.1.4 5 152.7 psig Pressure- High SR 3.3.6.1.5 SR 3.3.6.1.9

b. Reactor Vessel Water 3,4,5 J SR 3.3.6.1.1 2 165.6 inches Level - Low SR 3.3.6.1.4 SR 3.3.6.1.8 SR 3.3.6.1.9

c. Drywell Pressure - 1.2,3 2 F SR 3.3.6.1.4 s 2.2 psig High SR 3.3.6.1.8 SR 3.3.6.1.9

7. Containment Cooling System Isolation

a. Containment Pressure - 1,2,3 K SR 3.3.6.1.3 a 1.25 psig High SR 3.3.6.1.8 SR 3.3.6.1.9 Cd) Each Trip System trust have either an OPERABLE Function 5.b or an OPERABLE Function 5.c channel in both (d) Each Trip System must have either an OPERABLE Function 5.b or an OPERABLE Function 5.c channel in both the RWCU pump area and in the RWCU heat exchanger area.

Ce) SLC System Initiation only inputs into one of the two trip systems.

(f) .Only one trip system required in MODES 4 and 5 when RHR Shutdown Cooling System integrity maintained.

DAEC 3.3-61

. Amendment 22:I

Secondary Containment Isolation Instrumentation 3.3.6.2 3.3 INSTRUMENTATION 3.3.6.2 Secondary Containment Isolation Instrumentation LCO 3.3.6.2 The secondary containment isolation 'instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.2-1.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for inoperable. trip. Functions 1 and 2 AmI 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Functions 3 and 4 B. One or more Functions B.1 Restore secondary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with secondary containment isolation containment isolation capability.

capability not maintained.

(continued)

DAEC 3.3-62 Amendment 223

Secondary Containment Isolation Instrumentation 3.3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1.1 Isolate secondary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion containment.

Time of Condition A or B not met.

C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Secondary Containment Isolation Valves/Dampers (SCIV/Ds) inoperable.

C.2.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Standby Gas Treatment (SBGT) subsystem(s) in operation.

C.2.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SBGT subsystem(s) inoperable.

DAEC 3.3-63 Amendment 223

Secondary Containment Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS

--- -------------------- NOTES------------------------------------

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.2.2 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.6.2.3 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-64 Amendment 223

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPtlCABLE MODES OR REQUIRED OTHER CHANNELS SPECIFIED PER SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1,2,3, 2 SR 3.3.6.2.1 k 165.6 Inches Level- Low (a) SR 3.3.6.2.3 SR 3.3.6.2.4 SR 3.3.6.2.5

2. Drywell Pressure - High 1,2,3 2 SR 3.3.6.2.3 S 2.2 psig SR 3.3.6.2.4 SR 3.3.6.2.5

3. Reactor BuIlding Exhaust 1,2,3, 1 SR 3.3.6.2.2 . 12.8 mR/hr Shaft - High Radiation (a) SR 3.3.6.2.3 I SR 3.3.6.2.4 SR 3.3.6.2.5

4. Refueling Floor Exhaust 1,2,3, 1 SR 3.3.6.2.2 S 10.6 mR/hr Duct-High Radiation (a) SR 3.3.6.2.3 I SR 3.3.6.2.4 SR 3.3.6.2.5 (a) During operations with a potential for draining the reactor vessel.

DAEC 3.3-65 Amendment 237 APR 16 2001

LLS Instrumentation 3.3.6.3 3.3 INSTRUMENTATION 3.3.6.3 Low-Low Set (ULS) Instrumentation LCO 3.3.6.3 The LLS valve instrumentation for each Function in Table 3.3.6.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve A.1 Restore channel(s) to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable due to OPERABLE status.

inoperable channel(s).

B. One or more Safety B.1 Restore channel(s) to Prior to I Relief Valves (SRVs) OPERABLE status. entering MODE 2 with one Function 3 or 3 from MODE 4 channel inoperable.

C. --------NOTE-------- C.1 Restore at least two 14 days Separate Condition channels per SRV to entry is allowed for OPERABLE status.

.each SRV.

One or more SRVs with two or more Function 3 channels inoperable.

(continued)

DAEC 3.3-66 AMD 255 l

LLS Instrumentation 3.3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Declare the Immediately associated Completion associated LLS Time of Condition A. valve(s) inoperable.

B. or C not met.

DR Both LLS valves inoperable due to inoperable channels.

SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains LLS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL FUNCTIONAL TEST for 92 days portion of the channel outside primary containment.

SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.3.3 Perform CHANNEL CALIBRATION. 92 days (continued)

DAEC 3.3-67 Amendment 223

LLS Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. 184 days SR 3.3.6.3.5 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.3.6 - Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-68 Amendment 223

LLS Instrumentation 3.3.6.3 Table 3.3.6.3-1 (page 1 of 1)

Low-Low Set Instrumentation REQUIRED CHANNELS PER SURVEILLANCE ALLOWABLE FUNCTION FUNCTION REQUIREMENTS VALUE

1. Reactor Vessel Steam Dowme per LLS valve SR 3.3.6.3.2 s 1069.21 psig Pressure- High SR 3.3.6.3.3 SR 3.3.6.3.6

2. Low-Low Set Pressure Setpoints 2 per LLS valve SR 3.3.6.3.2 Low:

SR 3.3.6.3.4 Open z 1014 psig SR 3.3.6.3.6 and s 1045 psig CLose 2 893.4 psig and s 925 psig High:

Open a 1019 psig and s 1050 psig Close a 893.4 psig and s 930 psig

3. Tailpipe High Pressure 3 per SRV SR 3.3.6.3.1 s 99 psig SR 3.3.6.3.5 SR 3.3.6.3.6 DAEC 3.3-69 Amendment 223

SFU System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Standby Filter Unit (SFU) System Instrumentation LCO 3.3.7.1 Two channels of the Control Building Intake Area Radiation -

High Function shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During Operations with a Potential for Draining the Reactor Vessel (OPDRVs).

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both channels A.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. SFU subsystem(s) inoperable.

fiR A.2 Place associated SFU 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem(s) in the isolation mode.

DAEC '3.3-70 Amendment 223

SFU System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

NOTE-------------------------------------

When a :nannel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be celayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the other channel is OPERABLE.

SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.7.1.3 Perform CHANNEL CALIBRATION. The 24 months Allowable Value shall be s 5 mR/hr. I SR 3.3.7.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC ".3-71 Amendment 240

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

When the associated Diesel Generator is required to be.

OPERABLE by LCO 3.8.2. "AC Sources-Shutdown."

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Function 1 A.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or 3 channels trip.

inoperable.

B. One or more Function 2 B.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from channels inoperable. Diesel Generator (DG) discovery of inoperable. loss of initiation capability for feature(s) in one or both divisions B.2 Place channel in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months trip.

(continued)

DAEC 3.3-72 Amendment 223

LOP Instrumentation 3.3.8.1 ACTIONS (continued)

CONDITION .REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

DAEC 3.3-73 Amendment 223

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS

NOTES------------------------------------

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances. entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. 12 months SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. 12 months SR 3.3.8.1.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.8.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months DAEC 3.3-74 Amendment 223

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation REQUIRED CHANNELS SURVEILLANCE ALLOWABLE FUNCTION PER BUS REQUIREMENTS VALUE

1. 4.16 kV Emergency Bus Undervoltage (Loss of Voltage)

a. Bus Undervoltage SR 3.3.8.1.2 ? 595 V and SR 3.3.8.1.4 .s2275 V SR 3.3.8.1.5

2. 4.16 kV Emergency Bus Undervoltage (Degraded Voltage)

a. Bus Undervoltage 4 SR 3.3.8.1.1 ? 3780 V and SR 3.38.1.3 .s3822 V SR 3.3.8.1.5

b. Time Delay 4 SR 3.3.8.1.1 ? 7.92 seconds and SR 3.3.8.1.3 .s 8.5 seconds SR 3.3.8.1.5

3. 4.16 kV Emergency Transformer 2 SR 3.3.8.1.2 ~2450V Supply Undervoltage SR 3.3.8.1.3 SR 3.3.8.1.5 DAEC 3.3-75 Amendment 2/~

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS Electrical Protection Assemblies (EPAs) shall be OPERABLE for each inservice RPS motor generator set or alternate power supply.

APPLICABILITY: MODES 1 and 2.

MODES 3. 4 and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months power supplies with inservice power one EPA inoperable. supply(s) from service.

B. One or both inservice B.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power supplies with inservice power both EPAs inoperable. supply(s) from service.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met in MODE 1 or 2 (continued)

DAEC 3.3-76 Amendment 223

RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to Immediately associated Completion fully insert all Time of Condition A insertable control or B not met in rods-in core cells MODE 3. 4 or 5 with containing one or any control rod more fuel assemblies.

withdrawn from a core cell containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 ------------------NOTE-------------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4. when in MODE 4 for 2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The 24 months Allowable Values shall be:

a. Overvoltage s 132 V.

b. Undervoltage 2 108 V.

c. Underfrequency 2 57 Hz.

SR 3.3.8.2.3 Perform a system functional test. 24 months DAEC 3.3-77 Amendment 223

Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 Two recirculation loops with matched pump speeds shall be in operation with core flow as a function of THERMAL POWER outside the Exclusion Region specified in the COLR, OR One recirculation loop may be in operation with core flow as a function of THERMAL POWER outside the Exclusion Region specified in the COLR and with the following limits applied when the associated LCO is applicable:

a. LCO 3.2.1. "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)." single loop operation limits specified in the COLR:

b. LCO 3.2.2. "MINIMUM CRITICAL POWER RATIO (MCPR)." single loop operation limits specified in the COLR: and

c. LCO 3.3.1.1. "Reactor Protection System (RPS)

Instrumentation." Function 2.b (Average Power Range Monitors Flow Biased High Scram), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No recirculation loops A.1 Place the reactor Immediately in operation. mode switch in the Shutdown position.

(continued)

DAEC 3.4-1 Amendment 223

Recirculation Loops Operating 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or two B.1 Initiate action to Immediately recirculation loops in exit the Exclusion operation in the Region.

Exclusion Region of the power/flow map described in the Core Operating Limits Report.

C. Recirculation pump C.1 Trip one 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months speed mismatch not recirculation pump.

within limits.

D. Requirements of the D.1 Satisfy requirements 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months LCO not met for of the LCO.

reasons other than Conditions A. B or C.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition C or D not met.

DAEC 3.4-2 Amendment 223

Reci I*.: 'i _4-;-.,

E ^-.- .- __,_- _

_ I -

l SURVEILLANCE REOUIREMiENTS SURVEILLANCE FREOUENCY SR 3.4.1.1 ------------------- NOTE---------------------

Not required tc be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation pump speed mismatch 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months with both recirculation pumps at steady state operation is as follows:

a. The speed of the faster pump shall be c 135% of the speed of the slower pump when operating at < 69.4 % RTP.

I

b. The speed of the faster pump shall be

< 122% of the speed of the slower pump when operating at 2 69.4 % RTP.

I SR 3.4.1.2 Verify core flow as a function of core 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months THERMAL POWER is outside the Exclusion Region shown in the COLR.

DAEC 3.4-3 AmendmentZ?7,243 re'V 0 0 2001

Jet Pumps 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Jet Pumps LCO 3.4.2 All jet pumps shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable.

DAEC 3.4-4 Amendment 223

SURV'CELLAI'ICE RPQUIRrEHrTS_

SURVET LLtiCE FRE"OUE1CY S- 3 . . --------------- -----------------------

1. Lot reqAired to be r Until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the associated recircuIlation loop is in. operaz-.3On.

2. [lot requiied to b- perforimed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 21.7% RTP.

3. Criterion c is only applicable when pump speed is < 60%' rated speed.

Verify at least one of the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months criteria (a. b or c, as applicable) is satisfied for each operating recirculation loop:

a. Recirculation pump flow to speed ratio differs by < E%from established patterns, and jet pump loop flow to recirculation pump speed ratio differs bv < 5K from established patterns.

b. Each J-e pump diffuser zo lower plenum dif-feent--ial PressuL! differs by < 20%

from eszablished patterns.

. he recircuIation plump ;- C': , to '

ratio, jet pump loop flow to recirculation pump speed ratio, and jet pump diffuser to lower plenum differential pressure ratios are evaluated as being acceptable.

DAEC 3.4-5 Afeendmentlig,243 tJOV C 6 2001

SRVs and SVs 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety Relief Valves (SRVs) and Safety Valves MSVs)

LCO 3.4.3 The safety function of 8 SRVs and SVs shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SRV or SV A.1 Restore the valve to 30 days inoperable. OPERABLE status.

B. Two SRVs or SVs B.1 Restore one valve to 7 days inoperable. OPERABLE status.

C. Required Action C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and associated Completion Time of AND Condition A or B not met. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Three or more SRVs or SVs inoperable.

DAEC 3.4-6 Amendment 223

SRVs and SVs 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 Verify the safety function lift setpoints In accordance of the SRVs and SVs are as follows: with the Inservice Number of Setpoint Testing Program SRVs (1si3) 1 1110 +/- 33.0 1 1120 +/- 33.0 2 1130 +/- 33.0 2 1140 +/- 33.0 Number of Setpoint SVs (psaL.

2 1240 +/- 36.0 Following testing, lift settings shall be within +/- 1%.

SR 3.4.3.2 ------------------- NOTE---------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each SRV opens when manually 24 months actuated.

DAEC 3.4-7 Amendment No. 228 SEP 2 2 1G99

RCS Operational LEAKAGE 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Operational LEAKAGE LCO 3.4.4 RCS operational LEAKAGE shall be limited to:

a. 5 5 gpm unidentified LEAKAGE: '

b. < 25 gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period: and

c. 5 2 gpm increase in unidentified LEAKAGE within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period in MODE 1.

APPLICABILITY: MODES 1. 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months not within limit. within limits.

OR Total LEAKAGE not within limit.

B. Unidentified LEAKAGE B.1 Reduce unidentified 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months increase not within LEAKAGE increase to limit. within limits.

OR (continued)

DAEC 3.4-8 Amendment 223

RCS Operational LEAKAGE 3.4.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Verify source of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months unidentified LEAKAGE increase is not service sensitive type 304 or type 316 austenitic stainless steel.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND or B not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify RCS unidentified and total LEAKAGE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and unidentified LEAKAGE increase are within limits.

DAEC 3.4-9 Amendment 223

RCS Leakage Detection Instrumentation 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Leakage Detection Instrumentation LCO 3.4.5 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One channel of the Drywell Sump System; and

b. One channel of the Primary Containment Air Sampling System.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS _ _

CONDITION REQUIRED ACTION COMPLETION TIME A. Required Drywell Sump A.1 Restore required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months System Inoperable. Drywell Sump System to OPERABLE status. Il B. Required Primary 8.1 Initiate action to Immediately Containment Air restore required Sampling System Primary Containment inoperable. Air Sampling System to OPERABLE status.

(continued)

OAEC 3.4-10 I AMD 255

RCS Leakage Detection Instrumentation 3.4.5 ACTIONS (continued) _

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Drywell Sump C.1 Restore required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months System inoperable. Drywell Sump System to OPERABLE status.

AmQ Required Primary Containment C.2 Restore required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Air Sampling Primary Containment System inoperable. Air Sampling System to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or AU C not met.

0.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.4-11 AfID 255 1

RCS Leakage Detection Instrumentation 3.4.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Perform a CHANNEL CHECK of required Primary 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Containment Air Sampling System.

SR 3.4.5.2 Perform a CHANNEL FUNCTIONAL TEST of 31 days required Primary Containment Air Sampling System instrumentation. equipment drain sump flow integrator, and floor drain sump

.flow integrator.

SR 3.4.5.3 Perform a CHANNEL FUNCTIONAL TEST of 92 days required equipment drain sump flow timer and floor drain sump flow timer.

SR 3.4.5.4 Perform a CHANNEL CALIBRATION of required 92 days Primary Containment Air Sampling System instrumentation, equipment drain sump flow integrator, and floor drain sump flow integrator.

SR 3.4.5.5 Perform a CHANNEL CALIBRATION of required 12 months equipment drain sump flow timer and floor drain sump flow timer.

DAEC 3.4-12 Amendment 223

RCS Specific Activity 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Specific Activity LCO 3.4.6 The specific activity of the reactor coolant shall be limited to DOSE EQUIVALENT I-131 specific activity S 0.2 pCi /gm.

APPLICABILITY: MODE 1.

MODES 2 and 3 with any main steam line not isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor coolant -------- NOTE-specific activity LCO 3.0.4.c is applicable.

> 0.2 pCi/gm and .

5 2.0 pCi/gm DOSE EQUIVALENT I-131. A.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months EQUIVALENT 1-131.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT 1-131 to within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion EQUIVALENT 1-131.

Time of Condition A not met. AD B.2.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months steam lines.

Reactor Coolant specific activity > 2.0 QB pCi/gm DOSE EQUIVALENT I-131.

(continued)

DAEC 3.4-13 A14D 255' I

RCS Specific Activity 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.2.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREME!NTS SURVEILLANCE FREQUENCY SR 3.4.6.1 -------------------NOTE--------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 7 days I-131 specific activity is s 0.2 jiCi/gm. I DAEC 3.4-14 Amendment 240

RHR Shutdown Cooling System - Hot Shutdown 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown LCO 3.4.7 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

-NOTES

1. Both required RHR shutdown cooling subsystems and recirculation pumps may not be in operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One required RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for the performance of Surveillances.

APPLICABILITY: MODE 3, with reactor steam dome pressure < the RCIC Steam Supply Line Pressure - Low isolation pressure.

ACTIONS

NTE----------------------------------

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

I CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Initiate action to Immediately RHR shutdown cooling restore required RHR subsystems inoperable. shutdown cooling subsystem~s) to OPERABLE status.

A(cD

___(continued) ___

DAEC 3.4-15 I AMD 255

RHR Shutdown Cooling System- Hot Shutdown 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Verify by 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months administrative means an alternate method' of decay heat removal is available for each required inoperable RHR shutdown cooling subsystem.

AND A.3 Be in MODE 4. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. No RHR shutdown B.1 Initiate action to Immediately cooling subsystem in restore one RHR operation. shutdown cooling subsystem or one AND recirculation pump to operation.

No recirculation pump in operation. AND B.2 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from coolant circulation discovery of no by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.3 Monitor reactor Once per hour coolant temperature and pressure.

DAEC 3.4-16 Amendment 223

RHR Shutdown Cooling System- Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 -------------------NOTE--------------------

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .after reactor steam dome pressure is < the RCIC Steam Supply Line Pressure - Low isolation pressure.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Verify one required RHR shutdown cooling subsystem or recirculation pump is

.operating.

DAEC 3.4-17 Amendment 293 W..---

RHR Shutdown Cooling System - Cold Shutdown 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown LCO 3.4.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

NOTES---------------------------

1. Both required RHR shutdown cooling subsystems and recirculation pumps may not be in operation for up to 2 I hours per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One required RHR shutdown cooling subsystem may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for the performance of Surveillances.

APPLICABILITY: MODE 4.

ACTIONS

NOTE---------------------------------------

Separate Condition entry is allowed for each shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Verify by 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RHR shutdown cooling administrative means subsystems inoperable. an alternate method AND of decay heat removal is available for each Once per inoperable required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RHR shutdown cooling thereafter subsystem.

(continued)

DAEC 3.4-18 Amendment No. 234 OCT o ' 2&3g

RHR Shutdown Cooling System -Cold Shutdown 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR shutdown B.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND AND No recirculation pump in operation. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Monitor reactor Once per hour coolant temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one required RHR shutdown cooling 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months subsystem or one recirculation pump is operating.

DAEC 3.4-19 Amendment 223

RCS P/T Limits 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 RCS Pressure and Temperature (P/T) Limits LCO 3.4.9 RCS pressure. RCS temperature. RCS heatup and cooldown rates, and the recirculation pump starting temperature requirements shall be maintained within limits.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Restore parameter(s) 30 minutes Required Action A.2 to within limits.

shall be completed if this Condition is AND entered.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for Requirements of the continued operation.

LCO not met in MODE 1.

2. or 3.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

DAEC 3.4-20 Amendment 223

RCS P/T Limits 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. --------- NOTE----- C.1 Initiate action to Immediately Required Action C.2 restore parameter(s) shall be completed if to within limits.

this Condition is entered. AND C.2 Determine RCS is Prior to Requirements of the acceptable for entering MODE 2 LCO not met in other operation. or 3.

than MODES 1. 2.

and 3.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 -------------------NOTE--------------------

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify: 30 minutes

a. RCS pressure and RCS temperature are within the applicable limits in Figure 3.4.9-1.

b. RCS heatup and cooldown rates are s 200F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period during inservice leak and hydrostatic testing (Curve A).

c. RCS heatup and cooldown rates are s 100'F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period during non-nuclear heating (Curve B) and nuclear heating (Curve C).

(continued)

DAEC 3.4-21 Amendment 224 OCT 0 1 199

RCS P/T Limits 3.4.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.9.2 Verify RCS pressure and RCS temperature are Once within within the criticality limits specified in 15 minutes Figure 3.4.9-1. prior to control rod withdrawal for the purpose of achieving criticality SR 3.4.9.3 --------------------NOTE-------------------

Only required to be met.in MODES 1. 2. 3, and 4 during recirculation pump startup.

Verify the difference between the bottom Once within head coolant temperature and the Reactor 15 minutes Pressure Vessel (RPV) coolant temperature prior to each is < 145 0F. startup of a reci rcul ati on pump SR 3.4.9.4 -------------------NOTE--------------------

Only required to be met in MODES 1. 2. 3.

and 4 during recirculation pump startup.

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop to be started and the RPV coolant prior to each temperature is s 500F. startup of a recirculation pump (continued)

DAEC 3.4-22 Amendment 223

RCS P/T Limits 3.4.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.9.5 - -------------- NOTE--------------------

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify temperatures at the reactor vessel 30 minutes head flange and the shell adjacent to the head flange are > 740F.

SR 3.4.9.6 -------------------NOTE-----------------

Not required to be performed until 30 minutes after RCS temperature < 800F in MODE 4.

Verify temperatures at the reactor vessel 30 minutes head flange and the shell adjacent to the head flange are > 740F.

SR 3.4.9.7 ------------------- NOTE-------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RCS temperature s 100OF in MODE 4.

Verify temperatures at the reactor vessel 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months head flange and the shell adjacent to the head flange are > 740F.

DAEC 3.4-23 Amendment 223

. -RCSP/T Limi3ts.4 3.4.9 Curve A (EFPY) 25 32 B C 1400 A-System Fydrotest Limit with Fu I in Vessel (200 /hr heatup/cool own rate) 1200 .B- Non-Nuc ear Heating Limit, Valid t 32 ,

EFPY (100° /hr heatup/cool own rate)

-:1000 C - Nuclear qCore Critical) ,

._ Limit, Valid tb 32 EFPY (1000 Ihr .

a, heatup/cool own rate) .

cL 800 0

C-U, Bottom Head J En a, Curve A .

600 0

0 Bottom Head ./

CZ, Curve B a)

_ 400 3

a, C)

U)

CD L.

200 EL 0

0.0 50.0 100.0 150.0 200.0 250.0 300.0 Minimum Reactor Vessel Metal Temperature (F)

Figure 3.4.9-1 (page 1 of 1)

Pressure Versus Minimum Temperature Valid to Thirty-two Full Power Years, per Appendix G of 1 OCFR50

^1 A

- A

~ - -

- .f l-e .d-3UA_efl -- N U A-_A_

, 2-53---- -

I

Reactor Steam Dome Pressure 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Reactor Steam Dome Pressure LCO 3.4.10 The reactor steam dome pressure shall be s 1025 psig.

APPLICABILITY: MODES 1 and 2.

.ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam 15 minutes pressure not within dome pressure to limit. within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify reactor steam dome pressure is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s 1025 psig.

DAEC 3.4-25 Amendment 223

ECCS- Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS.(ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of four safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except High Pressure Coolant Injection (HPCI) is not required to be OPERABLE with reactor steam dome pressure S 150 psig and ADS valves are not required to be OPERABLE with reactor steam dome pressure < 100 psig.

ACTIONS iNOTE-----------------------------------

LCO 3.0.4.b Is not applicable to HPCI.

-- -- - . -- -- . . - . - -- - . . - - -- - . -- . - - . - I CONDITION REQUIRED ACTION COMPLETION TIME A. One Residual Heat A.1 Restore RHR pump to 30 Days Removal (RHR) pump OPERABLE status.

inoperable.

B. One low pressure ECCS B.1 Restore low pressure 7 days subsystem inoperable ECCS subsystem to for reasons other than OPERABLE status.

Condition A.

C. One Core Spray C.1 Restore Core Spray 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystem inoperable. subsystem to OPERABLE A-No status.

One or two RHR pump(s) XB inoperable. C.2 Restore RHR pump(s) 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

D. Both Core Spray D.1 Restore one Core 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystems inoperable. Spray subsystem to OPERABLE status.

(continued)

DAEC 3.5-1 AJMD 255

ECCS- Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be inMODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A. AND B. C. or D nQt met.

E.2 Be inMODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. HPCI System F.1 Verify by Immediately inoperable. administrative means RCIC System is OPERABLE.

AND F.2 Restore HPCI System 14 days to OPERABLE status.

G. HPCI System G.1 Restore HPCI System 7 days inoperable. to OPERABLE status.

AND OR One RHR pump G.2 Restore RHR pump to 7 days inoperable. OPERABLE status.

H. HPCI System H.1 Restore HPCI System 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. to OPERABLE status.

AND OR One low pressure ECCS H.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystem is ECCS subsystem to inoperable for reasons OPERABLE status.

other than Condition A.

I. HPCI System I.1 Restore HPCI System 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. to OPERABLE status.

AND OR One ADS valve I.2 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

(continued)

DAEC 3.5-2 Amendment 223

ECCS- Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Required Action and J.1 Be in Mode 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition F. AND G. H. or I not met..

J.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months dome pressure to S 150 psig.

K. One ADS valve K.1 Restore ADS valve to 30 days inoperable. OPERABLE status.

L. One ADS valve L.1 Restore ADS valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND OR One low pressure ECCS L.2 Restore low pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystem inoperable ECCS subsystem to for reasons other than OPERABLE status.

Condition A.

M. Two or more ADS valves M.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable.

AND OR M.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Required Action and dome pressure to associated Completion < 100 psig.

Time of Condition K or L not met.

(continued)

DAEC 3.5-3 Amendment 223

ECCS- Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME N. Two or more low N.1 Enter LCO 3.0.3. Immediately pressure ECCS subsystems inoperable for reasons other than Condition C or D.

OR HPCI System and two or more ADS valves inoperable.

OR HPCI System and two or more low pressure ECCS subsystems inoperable.

OR One ADS valve and two or more low pressure ECCS subsystems inoperable.

OR One ADS valve and HPCI System and one low pressure ECCS subsystem inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray 31 days subsystem. the piping is filled with water from the pump discharge valve to the injection valve.

(continued)

DAEC 3.5-4 Amendment 223

ECCS- Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.2 --------------- NOTE---------------------

The low pressure coolant injection (LPCI)system may be considered OPERABLE during alignment and operation for decay heat removal in MODE 3. if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem 31 days power operated and automatic valve in the flow path, that is not locked. sealed. or otherwise secured in position, is in the correct position.

SR 3.5.1.3 Verify a 100 day supply of nitrogen exists 31 days for each ADS accumu ator.

SR 3.5.1.4 Verify the following ECCS pumps develop the In accordance specified flow rate against a system head with the corresponding to the specified reactor Inservice pressure. Testing Program SYSTEM HEAD NO. CORRESPONDING OF TO A REACTOR SYSTEM FLOW RATE PUMPS PRESSURE OF Core Spray 2 2718 gpm 1 > 113 psig LPCI 2 4320 gpm 1 2 20 psig.

(continued)

DAEC 3.5-5 Amendment 223

ECCS- Operati ng 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5 -------------------NOTE--------------------

Not required to be performed until 1? hours after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure 5 1025 and In accordance a 940 psig. the HPCI pump can develop a with the flow rate a 2700 gpm against a system head Inservice corresponding to reactor pressure. Testing Program SR 3.5.1.6 -------------------NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure < 160 psig. 24 months the HPCI pump can develop a flow rate 2 2700 gpm against a system head corresponding to reactor pressure.

SR. 3.5.1.7 -------------------NOTES-------------------

1. Vessel injection/spray may be excluded.

2. For the LPCI System, the Surveillance may be met by any series of sequential and/or overlapping steps. such that the LPCI Loop Select function is tested.

Verify each ECCS injection/spray subsystem 24 months actuates on an actual or simulated automatic initiation signal.

(continued)

DAEC 3.5-6 Amendment 223

ECCS- Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.8- ---------- NOTE-----------

Valve actuation may be excluded. eI Verify the ADS actuates on an actual or 24 months simulated automatic initiation signal.

SR 3.5.1.9 ------------------ NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve opens when manually 24 months actuated.

DAEC 3.5-7 Amendment 223

ECCS -Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION X. COOLING (RCIC) SYSTEM 3.5.2 ECCS- Shutdown LCO 3.5.2 Two low pressure ECCS subsystems shall be OPERABLE.

APPLICABILITY: MODE 4.

MODE 5. except with the spent fuel storage pool gates removed and water level a 21 ft 1 inch over the top of the reactor pressure vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ECCS A.1 Restore required ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystem inoperable. subsystem to OPERABLE status.

B. Required Action and B.1 Initiate action to Immediately associated Completion suspend Operations Time of Condition A With a Potential for not met. Draining the Reactor Vessel (OPDRVs).

C. Both required ECCS C.1 Initiate action to Immediately subsystems inoperable. suspend OPDRVs.

AND C.2 Restore one ECCS 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months subsystem to OPERABLE status.

(continued)

DAEC 3..5-8 Amendment 223

ECCS - Shutdown 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 D.1 Initiate action to Immediately and associated restore Secondary .

Completion Time not Containment to met. OPERABLE status.

AND D.2 Initiate action to Immediately restore one Standby Gas Treatment subsystem to OPERABLE status.

AND D.3 Initiate action to Immediately restore isolation capability in each required Secondary Containment penetration flow path not isolated.

SURVEILLANCEREQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify. for each required Low Pressure 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Coolant Injection (LPCI) subsystem. the suppression pool water level is 2 7.0 ft.

(continued)

DAEC 3.5-9 Amendment 223

ECCS -Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for each required Core Spray (CS) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months subsystem. the:

a. Suppression pool water level is 2 8.0 ft: or

b. -----------------NOTE-----------------

Only one required CS subsystem may take credit for this option during OPDRVs.

Condensate storage tank water level in one CST is 2 11 ft or 2 7 ft in both CSTs.

SR 3.5.2.3 Verify, for each required ECCS subsystem. 31 days the piping is filled with-water from the pump discharge valve to the injection valve.

SR 3.5.2.4 ------------- NOTE-------------------

One LPCI subystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

Verify each required ECCS subsystem power operated and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the 31 days correct position.

(continued)

DAEC 3.5-10 Amendment 223

ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the specified flow rate against a system head In accordance corresponding to the specified reactor with the pressure. Inservice SYSTEM HEAD Testing NO. CORRESPONDING Program OF TO A REACTOR SYSTEM FLOW RATE PUMPS PRESSURE OF CS 2 2718 gpm 1 ;- 113 psig LPCI 2 4320 gpm 1 a 20 psig SR 3.5.2.6 -------------------NOTES-------------------

1. Vessel injection/spray may be excluded.

2. For the LPCI System. the surveillance may be met by any series of sequential and/or overlapping steps, such that the LPCI Loop Select function is tested.

Verify each required ECCS subsystem 24 months actuates on an actual or simulated automatic initiation signal.

DAEC 3.5-11 Amendment 223

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System A.1 Verify by Immediately inoperable. administrative means High Pressure Coolant Injection System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AU B.2 Reduce reactor steam 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months dome pressure to

< 150 psig.

DAEC 3.5-12 AMD 255-.

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System piping is filled 31 days with water from the pump discharge valve to the injection valve.

SR 3.5.3.2 Verify each RCIC System ower operated and 31 days automatic valve in the fow path. that is not locked. sealed. or otherwise secured in position, is in the correct position.

SR 3.5.3.3 ------------------- NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify. with reactor pressure s 1025 psig In accordance and a 940 psig. the RCIC pump can develop a with the flow rate a 400 gpm against a system head Inservice corresponding to reactor pressure. Testing Program SR 3.5.3.4 -------------------NOTE--------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with reactor pressure - 160 psig. 24 months the RCIC pump can develop a flow rate 2 400 gpm against a system head corresponding to reactor pressure.

(continued)

DAEC 3.5-13 Amendment 223

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.5 -------------------NOTE----------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation 24 months signal.

DAEC 3.5-14 Amendment 223

Primary Containment 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment LCO 3.6.1.1 Primary containment shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. containment to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.6-1 Amendment 223

Primary Containment 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and In accordance leakage rate testing except for primary with the containment air lock testing. in Primary accordance with the Primary Containment Containment Leakage Rate Program. Leakage Rate Program.

SR 3.6.1.1.2 Verify suppression chamber pressure does 24 months not increase at a rate > 0.009 psi per minute tested over a 10 minute period at a differential pressure of > 1.0 psid.

DAEC 3.6-2 Amendment 223

Primary Containment Air Lock 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Lock LCO 3.6.1.2 The primary containment air lock shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS

NOTES------------------------------------

1. Entry and exit is permissible to perform repairs of the air lock components.

2. Enter applicable Conditions and Required Actions of LCO 3.6.1.1. "Primary Containment." when air lock leakage results in exceeding overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One primary ---------- NOTES------------

containment air lock 1. Required Actions A.1, door inoperable. A.2. and A.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls.

A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

AND (continued)

DAEC 3.6-3 Amendment 223

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Lock the OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months door closed.

AND A.3 -------- NOTE---------

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed.

B. Primary containment ------------NOTES------------

air lock interlock 1. Required Actions B.1, mechanism inoperable. B.2. and B.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry into and exit from containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

AND (continued)

DAEC 3.6-4 Amendment 223

Primary Containment Air Lock 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed.

AND B.3 --------NOTE---------

Air lock doors in high radiation areas or areas with limited access due to inerting may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed.

C. Primary containment C.1 Initiate action to Immediately air lock inoperable evaluate primary for reasons other than containment overall Condition A or B. leakage rate per LCO 3.6.1.1, using current air lock test results.

AND C.2 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months closed.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued)

DAKC 3.6-5 Amendment 223

Primary Containment Air Lock 3.6.1.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.6-6 Amendment 223

Primary Containment Air Lock 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 NOTES------------------

1: An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria Applicable to SR 3.6.1.1.1.

Perform required primary containment air In accordance lock leakage rate testing in accordance with the with the Primary Containment Leakage Rate Primary Testing Program. Containment Leakage Rate The acceptance criterion for air lock Testing testing is overall air lock leakage rate Program.

< 0.05 La when tested at 2 Pa-SR 3.6.1.2.2 Verify only one door in the primary 24 months containment air lock can be opened at a time.

DAEC 3.6-7 Amendment 223

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCO 3.6.1.3 Each PCIV. except reactor building-to-suppression chamber vacuum breakers, shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3 MODES 4 and 5 for Shutdown Cooling System Isolation Valves when the associated instrumentation is required to be OPERABLE per LCO 3.3.6.1. "Primary Containment Isolation Instrumentation."

ACTIONS

NOTES------------------------------------

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1. "Primary Containment." when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1. 2. and 3.

CONDITION REQUIRED ACTION COMPLETION TIME A. ---------NOTE--------- A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months except Only applicable to penetration flow path for main steam penetration flow paths by use of at least line with two PCIVs. one closed and de-activated AND automatic valve.

One or more closed manual valve. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for main penetration flow paths blind flange, or steam line with one PCIV check valve with flow inoperable except for through the valve MSIV or purge valve secured.

leakage not within limits. (n u (continued)

DAEC 3.6-8 Amendment 223

PCIVs 3.6.1.3 CONDITION I REQUIRED ACTION I COMPLETION TIME

. (continued) A.2 --- NOTES---------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the Once oer 31 days affected for solation penetration flow devices outside path is isolated. primary containment AND Prior to entering MODE 2 or 3 from MODE '. if primary containment was de-inzrted while in MrCDE 4, if not performed within the :revious 92 days, for isola ion devices insice primary containment (continued)

DAEC 3.6-9 Amendment No. 234 OCT 0 3 2000

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REWUIRED ACTION COMPLETION TIME B. -- NOTE--------- B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path penetration flow paths by use of at least with two PCIVs. one closed and de-activated automatic valve, One or more penetration closed manual valve, flow paths with two or blind flange.

PCIVs inoperable except for MSIV or purge valve leakage not within limits.

C. --------- NOTE--------- C.1 Isolate the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to penetration flow path penetration flow paths by use of at least with only one PCIV. one closed and de-activated automatic valve, One or more closed manual valve, penetration flow paths or blind flange.

with one PCIV inoperable. AND C.2 ------- NOTES-------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

(continued)

DAEC 3.6-10 AendOCent No. 234 OCT 0 -a 2Ceg

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Verify the affected Once per 31 days I penetration flow path is isolated.

D. One or more D.1 Restore leakage to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow paths within limits.

with one or more MSIVs not within leakage limits.

E. One or more E.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months penetration flow paths penetration flow path with one or more by use of at least containment purge one closed and valves not within de-activated purge valve leakage automatic valve, limits. closed manual valve, or blind flange.

AND E.2 -------- NOTE---------

Only required to be performed if a purge valve with resilient seal is used to satisfy Required Action E.1.

Restore leakage to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months within limits.

AND E.3 -------- NOTES--------

1. Isolation devices I in high radiation areas may be verified by use of administrative means.

(continued)

DAEC 3.6-11 Amendment No. 234 OCT Os 2000

PCIVs 3.6.1.3 ACTI ONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.3 ------- NOTES--------

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path for isolation is isolated. device outside containment F. Required Action and F.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion AND Time of Condition A, B. C. D, or E not met F.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months in MODE 1. 2, or 3.

G. Required Action and G.1 Initiate action to Immediately associated Completion suspend OPDRVs within Time of Condition A, the Residual Heat B, C, D, or E not met Removal (RHR) for PCIV(s) required Shutdown Cooling to be OPERABLE during System.

MODE 4 or 5.

OR G.2 Initiate action to Immediately restore valve(s) to OPERABLE status.

DAEC 3.6-12 Amendment No. 234 OCT 9° 2rt3

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 ------------------NOTE-------------------

Not required to be met when the 18 inch primary containment purge valves are open for inerting. de-inerting pressure control. ALARA or air quality considerations for personnel entry. or Surveillances that require the valves to be open.

Verify each 18 inch primary containment 31 days purge valve is closed.

SR 3.6.1.3.2 Verify continuity of the traversing 31 days incore probe (TIP) shear isolation valve explosive charge.

SR 3.6.1.3.3 Verify the isolation time of each power In accordance operated automatic PCIV. except for with the MSIVs. is within limits. Inservice Testing Program SR 3.6.1.3.4 Perform leakage rate testing for each 184 days primary containment purge valve with resilient seals. AID Once within 92 days after opening the valve (continued)

DAEC 3.6-13 Amendment 223

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.5 Verify the isolation time of each MSIV is In accordance

> 3 seconds and < 5 seconds. with the Inservice Testing Program SR 3.6.1.3.6 ----------- NOTE----------------------

For the MSIVs, this SR may be met by any series of sequential, overlapping, or total system steps, such that proper operation is verified.

Verify each automatic PCIV actuates to 24 months the isolation position on an actual or simulated isolation signal.

SR 3.6.1.3.7 Verify a representative sample of reactor 24 months instrumentation line EFCVs actuate on a simulated instrument line break to restrict flow.

SR 3.6.1.3.8 Remove and test the explosive squib from In accordance each shear isolation valve of the TIP with the System. Inservice Testing Program (continued)

DAEC 3.6-14 Amendment No. 230 DEC 2 ° 1999

PCIVs 3.6.1.3 FREQUENCY SR 3.6.1.3.9 Verify leakage rate through each MSIV is In accordance

5: 100 seth and that the combined maximum with the Primary pathway leakage rate for all four main steam Containment lines is ~ 200 seth when tested at ~ 24 psig. Leakage Rate Testing Program DAEC 3.6-15 Amendment No. 276

Drywell Air Temperature 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Drywell Air Temperature LCO 3.6.1.4 Drywell average air temperature shall be < 135 0F.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air limit. temperature to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify drywell average air temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within limit.

DAEC 3.6-16 Amendment 223

LLS Valves 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Low-Low Set (LLS) Valves LCO 3.6.1.5 The LLS function of two safety/relief valves shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve A.1 Restore LLS valve to 14 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Two LLS valves inoperable.

DAEC 3.6-17 Amendment 223

LLS Valves 3.6.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 ------------------NOTE-------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each LLS valve opens when manually 24 months actuated.

SR 3.6.1.5.2 -------------- NOTE-------------------

Valve actuation may be excluded.

Verify the LLS System actuates on an 24 months actual or simulated automatic initiation signal.

DAEC 3.6-18 Amendment 223

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers LCO 3.6.1.6 Each reactor building-to-suppression chamber vacuum breaker assembly shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each reactor building-to-suppression chamber vacuum breaker assembly.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two reactor A.1 Close the open vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months building-to- breaker assembly suppression chamber valve.

vacuum breaker assemblies with one valve not closed.

B. One or two reactor B.1 Close one open vacuum 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months building-to- breaker assembly suppression chamber valve.

vacuum breaker assemblies with both valves not closed.

C. One reactor building- C.1 Restore the vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to-suppression chamber breaker assembly to vacuum breaker OPERABLE status.

assembly with one or two valves inoperable for opening.

(continued)

DAEC 3.6-19 Amendment 223

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two reactor building- D.1 Restore both valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to-suppression chamber in one vacuum breaker vacuum breaker assembly to OPERABLE assemblies with one or status.

two valves inoperable for opening.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time not met. AND E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ------------------NOTES------------------

1. Not required to be met for vacuum breaker assembly valves that are open during Surveillances.

2. Not required to be met for vacuum breaker assembly valves open when performing their intended function.

Verify each vacuum breaker assembly valve 14 days is closed.

SR 3.6.1.6.2 Perform a functional test of each vacuum 92 days breaker assembly valve.

(continued)

DAEC 3.6-20 Amendment 223

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.6.3 Verify the opening setpoint of each 12 months vacuum breaker assembly valve is

< 0.614 psid.

DAEC 3.6-21 Amendment 223

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers LCO 3.6.1.7 Six suppression chamber-to-drywell vacuum breakers shall be OPERABLE for opening.

AND Seven suppression chamber-to-drywell vacuum breakers shall be closed, except when performing their intended function.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore one vacuum 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months suppression chamber- breaker to OPERABLE to-drywell vacuum status.

breaker inoperable for opening.

B. One suppression B.1 Close the open vacuum 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months chamber-to-drywell breaker.

vacuum breaker not closed.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.6-22 Amendent 223

Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 ------------------NOTE-------------------

Not required to be met for vacuum.

breakers that are open during Surveillances.

Verify each vacuum breaker is closed. 14 days SR 3.6.1.7.2 Perform a functional test of each 31 days required vacuum breaker.

SR 3.6.1.7.3 Verify the opening setting of each 24 months required vacuum breaker is s 0.5 psid.

DAEC 3.6-23 Amendent 223

Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS 3.6.2.1 Suppression Pool Average Temperature LCO 3.6.2.1 Suppression pool average temperature shall be:

a. s 951F when any OPERABLE intermediate range monitor (IRM) is > 25/40 divisions of full scale on Range 7 and no testing that adds heat to the suppression pool is being performed;

b. s 105OF when any OPERABLE IRM channel is > 25/40 divisions of full scale on Range 7 and testing that adds heat to the suppression pool is being performed; and

c. s 110OF when all OPERABLE IRM channels are s 25/40 divisions of full scale on Range 7.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS _

CONDITION REQUIRED ACTION -COMPLETION TIME A. Suppression pool A.1 Verify suppression Once per hour average temperature pool average

> 950F but s 110 0F. temperature s 110 0F.

AD . A Any OPERABLE IRM A.2 Restore suppression 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months channel > 25/40 pool average divisions of full temperature to scale on Range 7. s 950F.

An Not performing testing that adds heat to the suppression pool.

(continued)

DAFC 3.6-24 Amendment 223

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Reduce THERMAL POWER 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion until all OPERABLE Time of Condition A IRM channels z 25/40 not met. divisions of full scale on Range 7.

C. Suppression pool CA. Suspend all testing Immediately average temperature that adds heat to the

> 105 0F. suppression pool.

AND Any OPERABLE IRM channel > 25/40 divisions of full scale on Range 7.

AND Performing testing that adds heat to the suppression pool.

D. Suppression pool D.1 Place the reactor Immediately average temperature mode switch in the

> 1100F but < 120 0F. Shutdown position.

AND D.2 Verify suppression Once per pool average 30 minutes temperature s 1200F.

AND D.3 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

DAEC 3.6-25 Amendment 223

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Suppression pool E.1 Depressurize the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months average temperature reactor vessel to

> 120 0F. < 200 psig.

AND E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1.1 Verify suppression pool average 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature is within the applicable limits. AND 5 minutes when performing testing that adds heat to the suppression pool DAEC 3.6-26 Amendment 223

Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be 2 10.11 ft and s 10.43 ft.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months level not within pool water level to limits. within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within limits.

DAEC 3.6-27 Amendment 223

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR pump A.1 Restore RHR pump to 30 days inoperable. OPERABLE status.

B. One RHR pump in each B.1 Restore one RHR pump 7 days suppression pool to OPERABLE status.

cooling subsystem inoperable.

C. One RHR suppression C.1 Restore RHR 7 days pool cooling subsystem suppression pool inoperable for reasons cooling subsystem to other than Condition OPERABLE status.

A.

D. Two RHR suppression D.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool cooling suppression pool subsystems inoperable cooling subsystem to for reasons other than OPERABLE status.

Condition B.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.6-28 Amendment 223

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify by administrative means each RHR 31 days suppression pool cooling subsystem manual. power operated and automatic valve in the flow path that is not locked, sealed. or otherwise secured in position is in the correct position or can be aligned to the correct position.

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance 2 4800 gpm through the associated heat with the exchanger while operating in the Inservice suppression pool cooling mode. Testing Program DAEC 3.6-29 Amendment 223

RHR Suppression Pool Spray 3.6.2.4 3.6 CONTAINMENT SYSTEMS 3.6.2.4 Residual Heat Removal (RHR) Suppression Pool Spray LCO 3.6.2.4 Two RHR suppression pool spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 30 days pool spray subsystem suppression pool inoperable. spray subsystem to OPERABLE status.

B. Two RHR suppression B.1 Restore one RHR 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months pool spray subsystems- suppression pool inoperable. spray subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AN C.2. Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAtC, 3.6-30 Amendment 223

RHR Suppression Pool Spray 3.6.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.4.1 Verify by an air test that the 60 months suppression pool spray header and nozzles are unobstructed.

DAEC 3.6-31 Amendment 223

CAD System 3.6.3.1 3.6 CONTAINMENT SYSTEMS 3.6.3.1 Containment Atmosphere Dilution (CAD) System The requirement for the CAD System is deleted per Amendment DAEC 3.6-32 Amendment 265

CAD System 3.6.3.1 This page is intentionally blank per Amendment DAEC 3.6-33 Amendment 265

Primary Containment Oxygen Concentration 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment Oxygen Concentration LCO 3.6.3.2 The primary containment oxygen concentration shall be

< 4.0 volume percent.

APPLICABILITY: MODE 1 during the time period:

a. From 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is > 15% RTP following startup. to

b. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to reducing THERMAL POWER to < 15% RTP prior to reactor shutdown.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore oxygen 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months oxygen concentration concentration to not within limit. within limit.

B. Required Action and B.1 Reduce THERMAL POWER 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion to - 15% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Verify primary containment oxygen. 7 days concentration is within limits.

K)

DAEC 3.6-34 Amendment 223

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During Operations with a Potential for Draining the Reactor Vessel (OPDRVs).

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1, containment to 2, or 3. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Secondary containment C.1 --------NOTE--------

inoperable during LCO 3.0.3 is not OPDRVs. applicable.

Initiate action to Immediately suspend OPDRVs.

(continued) I DAEC 3.6-35 Amendment 237 APR 16 2001

Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify all secondary containment 31 days equipment hatches are closed.

SR 3.6.4.1.2 -- ------- NOTE----

Doors in high radiation areas may be verified by administrative means.

Verify that either the outer door(s) or 31 days the inner door(s) in each secondary containment access opening are closed.

SR 3.6.4.1.3 Verify each SBGT subsystem can maintain 24 months on a

> 0.25 inch of vacuum water gauge in the STAGGERED TEST secondary containment at a flow rate BASIS

' 4000 cfm.

DAEC 3.6-36 Amendment 237 APR o12001

SCIV/Ds 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves/Dampers (SCIV/Ds)

LCO 3.6.4.2 Each SCIV/D shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

During Operations with a Potential for Draining the Reactor I Vessel (OPDRVs).

ACTIONS

- -----------------------------NOTES-----------------------------------

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIV/Ds.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow paths penetration flow path with one SCIV/D by use of at least inoperable. one closed and de-activated automatic valve/damper, closed manual valve, or blind flange.

(continued)

DAEC 3.6-37 Amendment 237 APR 1 6 2,ul

SCIV/Ds 3.6.4.2 ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. (continued) A.2 -------- NOTES--------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration fldw path is isolated.

B. --------- NOTE--------- B.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to penetration flow path penetration flow paths by use of at least with two isolation one closed and valves/dampers. de-activated automatic valve/damper, closed One or more penetration manual valve, or flow paths with two blind flange.

SCIV/Ds inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or AND B not met in MODE 1, 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

DAEC 3.6-38 Amendment No. 234 OC T CI 2CJ9!

SCIV/Ds 3.6.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 --------- NOTE---------

associated Completion LCO 3.0.3 is not

- Time of Condition A applicable.

or B not met during OPDRVs.

Initiate action to Immediately suspend OPDRVs.

DAEC 3.6-39 Amendment 237 APR 1 2 o1

SCIV/Ds 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 Verify the isolation time of each power 92 days operated automatic SCIV/D is within limits.

SR 3.6.4.2.2 Verify each automatic SCIV/D actuates to 24 months the isolation position on an actual or simulated actuation signal.

DAEC 3.6-40 Amendment 223

SBGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SBGT) System LCO 3.6.4.3 Two SBGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3.

During Operations with a Potential for Draining the Reactor I

Vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SBGT subsystem A.1 Restore SBGT 7 days inoperable. subsystem to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and ------------ NOTE------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met during OPDRVs. I C.1 Place OPERABLE SBGT Immediately subsystem in operation.

OR (continued)

DAEC 3.6-41 Amendment 237 APR ILG 2001

SBGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Initiate action to Immediately suspend OPDRVs.

D. Two SBGT subsystems D.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3.

E. Two SBGT subsystems E.1 -------- NOTE---------

inoperable during LCO 3.0.3 is not OPDRVs. applicable.

Initiate action to Immediately suspend OPDRVs.

(continued)

DAEC 3.6-42 Amendment 237 APR 1G 2§"1

SBGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SBGT subsystem for 2 10 31 days continuous hours with heaters operating.

SR 3.6.4.3.2 ------------------NOTE---------------------

When a SBGT subsystem is placed in an inoperable status solely for the performance of VFTP testing required by this Surveillance on the other subsystem, entry into associated Conditions and Required Actions may be delayed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Perform required SBGT filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SBGT subsystem actuates on an 24 months actual or simulated initiation signal.

SR 3.6.4.3.4 Verify each SBGT filter cooler bypass 24 months damper can be opened and the fan started.

I DAEC 3.6-43 Amendment 237 APR 1 6 2001

RHRSW System 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Residual Heat Removal Service Water (RHRSW) System LCO 3.7.1 Two RHRSW subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHRSW pump A.1 Restore RHRSW pump to 30 days I inoperable. OPERABLE status.

B. One RHRSW pump in each B.1 Restore one RHRSW 7 days subsystem inoperable. pump to OPERABLE status.

C. One RHRSW subsystem C.1 -NOTE---

inoperable for reasons Enter applicable other than Conditions and Condition A. Required Actions of LCO 3.4.7, "Residual Heat Removal (RHR)

Shutdown Cooling System-Hot Shutdown,"

for. RHR shutdown cooling made inoperable by RHRSW System.

Restore RHRSW 7 days subsystem to OPERABLE status.

(continued)

DAEC 3.7-1 AMD 255 1

RHRSW System 3.7.1 ACTIONS (continued)

CONDITION . REQUIRED ACTION COMPLETION TIME D. Both RHRSW subsystems ------------NOTE-------------

inoperable for reasons Enter applicable Conditions other than and Required Actions of Condition B. LCO 3.4.7 for RHR shutdown cooling made inoperable by RHRSW System.

D.1 Restore one RHRSW subsystem to OPERABLE status. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify each RHRSW subsystem power operated 31 days and automatic valve in the flow path, that is not locked. sealed. or otherwise secured in position. is in the correct position or can be aligned to the correct position.

DAEC 3.7-2 Amendment 223

RWS System and UHS 3.7.2 3.7 PLANT SYSTEMS 3.7.2 River Water Supply (RWS) System and Ultimate Heat Sink (UHS)

LCO 3.7.2 Two RWS subsystems and UHS shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RWS subsystem A.1 Restore the RWS 7 days inoperable. subsystem to OPERABLE status.

B. Required Action and ------ -NOTE--------------

associated Completion Enter applicable Conditions Time of Condition A and Required Actions of LCO not met. 3.4.7. "Residual Heat Removal (RHR) Shutdown Cooling OR System-Hot Shutdown." for RHR shutdown cooling made Both RWS subsystems inoperable by RWS System.

inoperable.

OR B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months UHS inoperable. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.7-3 Amendment 223

RWS System and UHS 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Verify the river water level is ?: 725.2 ft mean 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months sea level.

SR 3.7.2.2 Verify the average river water temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s 95°F.

SR 3.7.2.3 -------------------------N()TE-------------------------

Not required to be performed until river depth

< 2 feet at the intake structure.

Verify the river water depth is ?: 12 inches. 7 days SR 3.7.2.4 Verify each RWS subsystem power operated 31 days and automatic valve in the flow paths servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.2.5 Verify the river water depth?: 12 inches. 92 days SR 3.7.2.6 Verify each RWS subsystem actuates on an 24 months actual or simulated initiation signal.

DAEC 3.7-4 Amendment No. 272

ESW System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Emergency Service Water (ESW) System LCO 3.7.3 Two ESW subsystems shall be OPERABLE.

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ESW subsystem --------- NOTES------------

inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1. "AC Sources-Operating." for diesel generator made inoperable by ESW System.

2. Enter applicable Conditions and Required Actions of LCO 3.4.7.

"Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown." for RHR shutdown cooling made inoperable by ESW System.

A.1 Restore the ESW subsystem to OPERABLE status. 7 days B. Required Action B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Associated Completion Time of AND Condition A not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Both ESW subsystems inoperable.

DAEC 3.7-5 Amendment 223

ESW System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE 1*

FREQUENCY SR 3.7.3.1 ----------------- NOTE-------------------

Isolation of flow to individual components does not render ESW System inoperable.

Verify each ESW subsystem power operated 31 days and automatic valve in the flow paths servicing safety related systems or components. that is not locked. sealed.

or otherwise secured in position. is in the correct position.

SR 3.7.3.2 Verify each ESW subsystem actuates on an 24 months actual or simulated initiation signal.

DAEC - 3.7-6 Amendment 223

SFU System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Standby Filter Unit (SFU) System LCO 3.7.4 Two SFU subsystems shall be OPERABLE.

..--------------- NO TE ------------------------------

The control building envelope (CBE) boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiated fuel assemblies in the secondary containment, During CORE ALTERATIONS, During Operations with a Potential for Draining the Reactor Vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SFU A.1 Restore SFU subsystem to 7 days subsystem OPERABLE status.

inoperable for reasons other than Condition B.

B. One or more SFU B.1 Initiate actions to implement Immediately subsystems mitigating actions.

inoperable due to inoperable CBE AND boundary in B.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months MODES 1, 2, and ensure CBE occupant

3. exposures to radiological hazards will not exceed limits and verify by administrative means that CBE occupants are protected from smoke and chemical hazards.

AND B.3 Restore CBE boundary to 90 days OPERABLE status.

DAEC 3.7-7 Amendment No. 269.

SFU System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B AND not met in MODE 1,2, or

3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and -- - ---------- NOTE------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not met during movement D.1 Place OPERABLE Immediately of irradiated fuel SFU subsystem in the assemblies in the isolation mode.

secondary containment, during OR CORE ALTERATIONS, or during OPDRVs. D.2.1 Suspend movement Immediately of irradiated fuel assemblies in the secondary containment.

AND D.2.2 Suspend CORE Immediately ALTERATIONS.

AND D.2.3 Initiate action to Immediately suspend OPDRVs.

E. Both SFU subsystems E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

(continued) 69 DAEC 3.7-8 Amendment No?

SFU System 3.7.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Both SFU subsystems - NOTE -----------

inoperable during LCO 3.0.3 is not applicable.

movement of irradiated fuel assemblies in the F.1 Suspend movement Immediately secondary containment, of irradiated fuel during CORE assemblies in the ALTERATIONS, or secondary during OPDRVs. containment.

OR AND One or more SFU F.2 Suspend CORE Immediately subsystems inoperable ALTERATIONS.

due to an inoperable CBE boundary during AND movement of irradiated fuel assemblies in the F.3 Initiate action to Immediately secondary containment, suspend OPDRVs.

during CORE ALTERATIONS, or during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Operate each SFU subsystem for 31 days

> 15 minutes.

SR 3.7.4.2 Perform required SFU filter testing in In accordance accordance with the Ventilation Filter Testing with the VFTP Program (VFTP).

(continued)

DAEC 3.7-9 Amendment No.269

SFU System 3.7.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.4.3 Verify each SFU subsystem actuates on an 24 months actual or simulated initiation signal.

SR 3.7.4.4 Perform required CBE unfiltered air inleakage In accordance testing in accordance with the Control Building with the Envelope Habitability Program. Control Building Envelope Habitability Program DAEC 3.7-10 Amendment No. 2 6 9

CBC System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Control Building Chiller (CBC) System LCO 3.7.5 Two CBC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of irradiatedfuel assemblies in the secondary containment, During CORE ALTERATIONS, During Operations with a Potential for Draining the Reactor Vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CBC subsystem A.1 Restore CBC 30 days inoperable, subsystem to OPERABLE status.

B., Two CBC subsystems B.1 Verify control building Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable, area temperatures

< 900 F.

AND B.2 Restore one CBC 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion, Time of Condition A or B AND not met in MODE 1, 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

DAEC 3.7-11 Amendment 267

CBC System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and ------------- NOTE--------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A- --------------------

not met during movement of D.1 Place OPERABLE. CBC subsystem in operation.

Immediately I irradiated fuel assemblies in the OR secondary containment, during D.2.1 Suspend movement of Immediately CORE irradiated fuel ALTERATIONS, or assemblies in the during OPDRVs. secondary containment.

AND D.2.2 Suspend CORE Immediately ALTERATIONS.

AND D.2.3 Initiate action to Immediately suspend OPDRVs.

(continued)

DAECC 3.7-12 Amendment 267

CBC SyQstem 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION fCOMPLETION TIME E. Required Action and --------------- NOTE ---------------

associated Completion LCO 3.0.3. is not applicable.

Time of Condition B not met during movement E.1 Suspend movement Immediately of irradiated fuel of irradiated fuel assemblies in the assemblies in the secondary containment,, secondary during CORE containment.

ALTERATIONS, or during OPDRVs. AND E.2 Suspend CORE Immediately ALTERATIONS.

AND E.3 Initiate action to Immediately suspend OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each CBC subsystem has the 92 days capability to remove the available heat load.

DAEC 3.7- 130 Amendment 267

Main Condenser Offgas 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Main Condenser Offgas LCO 3.7.6 The gross gamma activity rate of the noble gases measured at the Steam Jet Air Ejector (SJAE) offgas pretreatment monitor shall be 5 1.0 Ci/second after decay of 30 minutes.

APPLICABILITY: MODE 1.

MODES 2 and 3 with any main steam line not isolated and SJAE in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity A.1 Restore gross gamma 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months rate of the noble activity rate of the gases not within noble gases to within limit. limit.

B. Required Action and B.1 Isolate all main 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion steam lines.

Time not met.

OR B.2 Isolate SJAE. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR B.3.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND B.3.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months DAEC 3.7-14 Amendment 223

Main Condenser Offgas 3.7.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 NOTE--------------------

Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation.

Verify the gross gamma activity rate of the 31 days noble gases is s 1.0 Ci/second after decay of 30 minutes. AND Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after a 2 50% increase in the nominal steady state fission gas release after factoring out increases due to changes in THERMAL POWER level DAEC 3.7-15 Amendment 223

t. -, -*.--.-

3.7 PLANT SYSTEMS 3.7.7 The Main Turbine Bypass Syste-m LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.

OR LCO 3.2.2. "MINIMUM CRITICAL POWER RATIO (MCPR)," limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.

APPLICABILITY: THERMAL POWER 2 21.7% RTP.

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion to < 21.7% RTP. I Time not met.

DAEC 3.7-16 AmendmentZZI,243 I J0'GG 2U01

Main TLurCi-fe typass S.szIm

' . 1.

KI SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify one complete cycle of each main 92 days I turbine bypass valve.

SR 3.7.7.2 Perform a system functional test. 24 months SR 3.7.7.3 Verify the TURBINE BYPASS S'YSTEM RESPONSE 24 months TIME is within limits.

DAEC 3.7-17 3 22,1jj Amen ee 4o01

Spent Fuel Storage Pool Water Level 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Spent Fuel Storage Pool Water Level LCO 3.7.8 The spent fuel storage pool water level shall be > 36 ft.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel storage pool.

ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage A.1 --- NOTE---------

pool water level not LCO 3.0.3 is not within limit. applicable.

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 Verify the spent fuel storage pool water 7 days level is 2 36 ft.

DAEC, 3.7-18 Amendment 223

CB/SBGT Instrument Air System 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Control Building/Standby Gas Treatment (CB/SBGT) Instrument Air System LCO 3.7.9 Two CB/SBGT Instrument Air subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CB/SBGT A.1 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from Instrument Air feature(s), supported discovery of subsystem by the inoperable Condition A inoperable. CB/SBGT Instrument Air concurrent with subsystem, inoperable inoperability of when the redundant redundant required required feature(s) feature(s) are inoperable.

AND A.2. Restore the CB/SBGT 7 days Instrument Air subsystem to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time of AND Condition A not met. B.2. Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Both CB/SBGT Instrument Air subsystems inoperable.

DAEC 3.7-19 Amendment No. 227 JUN 0 9 1s99

CB/SBGT Instrument Air System 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CB/SBGT Instrument Air 31 days compressor for 2 20 minutes.

SR 3.7.9.2 Verify each CB/SBGT Instrument Air 92 uRvs subsystem actuates on an actual or simulated initiation signal and maintains air pressure a 75 psig in the receiver.

DAEC 3.7-20 Amendment No. 227 JUn 0 9 1993

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class IE AC Electrical Power Distribution System; and

b. Two diesel generators (DGs).

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE---------------------------------

W-----------

LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One offsite circuit A.1 Perfotm SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. for OPERABLE offsite circuit. AND Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter AND A.2 Restore offsite Prior to circuit to OPERABLE entering MODE 2 status. from MODE 3 or 4 (continued)

DAEC 3.8-1 1

255 IAND

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One DG inoperable. B.1 Perform SR 3.8.1.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for OPERABLE offsite circuit(s). AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AD B.2 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from feature(s). supported discovery of by the inoperable DG. Condition B inoperable when the concurrent with redundant required inoperability of feature(s) are redundant inoperable. required feature(s)

(continued)

DAEC 3.8-2 Amendment 223

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B13 Determine'OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DG is not inoperable due to common cause failure.

AND

-------------- NOTE --------------

Not required to be performed when the cause of the inoperableDG is pre-planned, preventive maintenance and testing.

B.4 Perform SR 3.8.1.2 for Once per 72 OPERABLE DG. hours AND B.5 Restore DG to 7 days OPERABLE status.

AND 8 days from discovery of failure to meet LCO expect for Condition A

4. 4.

C. Two offsite circuits C.1 Declare required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from inoperable. feature(s) inoperable discovery of Condition when the redundant C concurrent with required feature(s) are inoperability of inoperable. redundant required IV(oLUI tnud AND (continued)

DAEC 3.8-3 Amendment No. 270

AC Sources - Operating 3.8.1 CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Restore one offsite 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months circuit to OPERABLE status. AND 8 days from discovery of failure to meet LCO except for Condition A D. Two DGs inoperable. D.1 Restore one DG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time of Condition A, B, AND C, or D not met.

E.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. Three or more AC F. 1 Enter LCO 3.0.3. Immediately sources inoperable.

DAEC 3.8-4 Amendment No. 270

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and 7 days indicated powaer availability for each offsite circuit.

SR 3.8.1.2 - ---------------NOTES-------------------

1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be.used for this SR as recommended by the manufacturer.

When modified start procedures are not used. the time, voltage. and frequency tolerances of SR 3.8.1.7 must be met.

3. When a DG is placed in an inoperable status solely for the performance of testing required by Required Actions B.3 or B.4. entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Verify each DG starts from standby 31 days conditions and achieves steady state voltage 2 3744v and s 4576v and frequency 2 59.5Hz and < 60.5Hz.

(continued)

DAEC 3.8-5 Amendment 223

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) -

SURVEILLANCE FREQUENCY SR 3.8.1.3 -------------------NOTES---

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow, without shutdown.

a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded 31 days and operates for 2 60 minutes at a load 2 2750kw and < 2950kw.

SR 3.8.1.4 Verify each day tank contains 2 220 gal of 31'days fuel oil.

SR 3.8.1.5 Check for the presence of water in the fuel 31 days oil in each day tank and remove water as necessary.

(continued)

DAEC 3.8-6 Amendment 223

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR -3.8.1.6 Verify the fuel oil transfer system 31 days operates to transfer fuel oil from storage tank to the day tank.

SR 3.8.1.7 -------------------NOTE--------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby 184 days condition and achieves:

a. in s 10 seconds, voltage 2 3744V and frequency 2 59.5Hz; and

b. steady state. voltage 2 3744V and s 4576V and frequency 2 59.5Hz and s 60.5Hz.

SR 3.8.1.8 ------------------NOTE-------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify automatic slow transfer 24 months of AC power supply from the Startup Transformer to the Standby Transformer.

(continued)

DAEC 3.8-7 Amendment 225 FEB 1 7 1999

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 ------------------NOTE--------------------

This Surveillance shall not be performed in MODE 1 or 2. However. credit may be taken for unplanned events that satisfy this SR.

Verify each DG rejects a load greater than 24 months or equal to its associated single largest post-accident load. and:

a. Following load rejection, the frequency is s 64.5Hz.

b. Within 1.3 seconds following load rejection. the voltage is 2 3744V and s 4576V.

c. Within 3.9 seconds following load rejection. the frequency is 2 59.5Hz and 5 60.5Hz.

SR 3.8.1.10 ------------------NOTE--------------------

This Surveillance shall not be performed in MODE 1. 2 or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are 24 months bypassed on an actual or simulated Loss of Offsite Power (LOOP) signal or on-an actual or simulated ECCS initiation signal except:

a. Engine overspeed: and

b. Generator lockout.

(continued)

DAEC 3.8-8 Amendment 223

AC Sources - ODerating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 ------------------ NOTE--------------------

This Surveillance shall not be performed in MODE 1. 2 or 3. However. credit may be taken for unplanned events that satisfy this SR.

Verify under manual control each DG: 24 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source: and

c. Returns to ready-to-load operation.

SR 3.8.1.12 NOTE--------------------

This Surveillance shall not be performed in MODE 1. 2 or 3. However. credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced 24 months load block is 2 2 seconds.

(continued)

DAEC 3.8-9 Amendment 223

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 --- -------- NOTES----------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1. 2. or 3.

However. credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of 24 months offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a. De-energization of essential buses:

b. Load shedding from essential buses; and

c. DG auto-start from standby condition and:

1. energizes permanently connected loads in < 10 seconds.

2. energizes auto-connected emergency loads in the proper timed sequence.

3. achieves steady state voltage 2 3744V and s 4576V.

4. achieves steady state frequency 2 59.5Hz and , 60.5Hz. and

5. supplies permanently connected and auto-connected emergency loads for

> 5 minutes.

DAEC 3.8.-10 Amendment 223

AC Sources -Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources-Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class lE AC electrical power distribution subsystem(s) required by LCO 3.8.8.

"Distribution Systems -Shutdown": and

b. One Diesel Generator (DG) capable of supplying one division of the. onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8.

APPLICABILITY: MODES 4 and 5.

During movement of irradiated fuel assemblies in the secondary containment.

DAEC 3.8-11 Amendment 223

AC Sources - Shutdown 3.8.2 ACTIONS

NOTE-----------------------------------

LCO 3.0.3 is not applicable.

CONDITION I REQUIRED ACTION I COMPLETION TIME A. One required offsite ------------ NOTE-------------

circuit inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8. with one required division de-energized as a result of Condition A.

A.1 Declare affected Immediately required feature(s).

with no offsite power available.

inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND A.2.3 Initiate action to Immediately suspend Operations with a Potential for Draining the Reactor Vessel (OPDRVs).

AND A.2.4 Initiate action to Immediately restore required offsite power circuit to OPERABLE status.

(continued)

DAEC 3.8-12 Amendment 223

AC Sources - Shutdown 3.8.2 ACTIONS (continued)

CONDITION RECUIRED ACTION COMPLETION TIME B. One required DG B.1 Suspend CORE Immediately inoperable. ALTERATIONS.

AND B.2 Suspend movement of Immediately irradiated fuel assemblies in secondary containment AND B.3 Initiate action to Immediately suspend OPDRVs.

AND B.4 Initiate action to Immediately restore required DG to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.8.2.1 -------------------

NOTE'--------------------

1. The following SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.9 through SR 3.8.1.13.

2. SR 3.8.1.13 is considered to be met without the ECCS initiation signals OPERABLE when the ECCS initiation signals are not required to be OPERABLE per Table 3.3.5.1-1.

For AC sources required t: be OPERABLE, the In accordance SRs of Specification 3.8.:, except SR 3.8.1.8, with applicable are applicable. SRs DAEC 3.8-13 Amnendment No. 234 OCT 03 2090

Diesel Fuel Oil. Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil. Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required Diesel Generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS For Conditions B. E. and F. separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel oil level A.1 Restore fuel oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months

< 36.317 gal and level to within

> 31.238 gal in limits.

storage tank.

B. One or more DGs with B.1 Restore lube oil 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months lube oil inventory inventory to within

< 257 gal and limits.

> 221 gal.

C. Stored fuel oil total C.1 Restore fuel oil 30 days particulates not total particulates to within limit. within limit.

(continued)

DAEC 3.8-14 Amendment 223

Diesel Fuel Oil. Lube Oil. and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. New fuel oil D.1 Restore stored fuel 30 days properties not within oil properties to limits. within limits.

E. One or more DGs with E.1 Restore required 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months required starting air starting air receiver receiver pressures pressure to within

< 150 psig and limits.

2 75 psig.

F. Required Action and F.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs with diesel fuel oil, lube oil. or starting air subsystem not within limits for reasons other than Condition A. B. C. D.

or.E.

DAEC 3.8-15 Amendment 223

Diesel Fuel Oil. Lube Oil. and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify fuel oil storage tank contains 31 days

> 36.317 gal of fuel.

SR 3.8.3.2 Verify lube oil inventory is 2 257 gal for 31 days each DG.

SR 3.8.3.3 Verify fuel oil properties of new and In accordance stored fuel oil are tested in accordance with the Diesel with, and maintained within-the limits of. Fuel Oil the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify required air start receiver pressure 31 days is 2 150 psig.

SR 3.8.3.5 Check for the presence of water in the fuel 31 days oil in the fuel oil storage tank and remove water as necessary.

DAEC 3.8-16 Amendment 223

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 Both Division 1 and Division 2 125 VDC electrical power subsystems and the 250 VDC electrical power subsystem shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME A. One 125 VDC electrical A.1 Restore 125 VDC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months power subsystem electrical power inoperable. subsystem to OPERABLE status.

OR NOTE: May be used on a A.2.1 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition one-time-only basis for feature(s), supported by A concurrent with inoperability of each battery division. the inoperable 125 VDC redundant required feature(s).

source, inoperable when the redundant required feature(s) are inoperable.

AND A.2.2 Restore 125 VDC electrical power 10 days subsystem to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time of Condition A not AND met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. 250 VDC electrical power C.1 Declare associated Immediately subsystem inoperable. supported features inoperable.

D. Two or more DC electrical D.1 Enter LCO 3.0.3 Immediately power subsystems inoperable.

DAEC 3.8-17 Amendment No. 247 OCT 0 1 202

DC Sources - Operating 3.8.4 SURVEILLANCEREQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is a 126 V 7 days on float charge for the 125 VDC battery and 2 252 V for the 250 VDC battery.

SR 3.8.4.2 Verify no visible corrosion at battery 92 days terminals and connectors.

Verify battery connection resistance within limits.

SR 3.8.4.3 Verify battery cells, cell plates, and 12 months racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.

SR 3.8.4.4 Remove visible corrosion and verify battery 12 months cell to cell and terminal connections are coated with anti-corrosion material.

SR 3.8.4.5 Verify battery connection resistance within 12 months limits.

(continued)

DAEC 3.8-18 Amendment 223

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

NOTE--------------------

This Surveillance shall not be performed on the required battery chargers in MODE 1. 2 or 3. However, credit may be taken for unplanned events that satisfy this SR.

SR 3.8.4.6 Verify each required battery charger 24 months supplies g 300 amps at 2 129 V for the 125 VDC subsystem and > 200 amps at z 258 V for the 250 VDC subsystem.

SR 3.8.4.7 -------------------NOTES-------------------

1. The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.

2. This Surveillance shall not be performed in MODE 1. 2. or 3.

However. credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to 24 months supply. and maintain in OPERABLE status.

the required emergency loads for the design duty cycle when subjected to a battery service test.

(continued)

DAEC 3.8-19 Amendment 223

DC Sources -Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued' SURVEILLANCE FREQUENCY 6

SR 3.8.4.8 -------------------NOTE--------------------

This Surveillance shall not be performed in MODE 1. 2. or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is k 80X of the 60 months manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test. ARD 12 months when battery shows degradation or has reached 85%

of expected life with capacity

< 100% of

-manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity - 100%

of manufacturer's rating DAtC 3.8-20 Amendment 223

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources -Shutdown LCO 3.8.5 DC electrical power subsystems shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.8. "Distribution Systems- Shutdown."

APPLICABILITY: MODES 4 and 5.

During movement of irradiated fuel assemblies in the secondary containment.

ACTIONS

NOTE--------------------------------------

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected Immediately DC electrical power required feature(s) subsystems inoperable. inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AND (continued)

DAEC 3.8-21 Amendment 223

DC Sources - Shutdown 3.8.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for.

draining the reactor vessel.

AND A.2.4 Initiate action to Immediately restore required DC electrical power subsystems to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 -------------------NOTE--------------------

The following SRs are not required to be performed: SR 3.8.4.7 and SR 3.8.4.8.

For DC electrical power subsystems required In accordance to be OPERABLE the following SRs are with applicable applicable: SRs SR 3.8.4.1 .SR 3.8.4.4 SR 3.8.4.7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8.

SR 3.8.4.3 SR 3.8.4.6 DAEC 3.8-22 Amendment 223

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for the Division I and Division II 125 VDC and the 250 VDC batteries shall be within limits. I APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

NOTE--------------------------

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Verify pilot cell 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one or more electrolyte level and battery cell float voltage meet parameters not within Table 3.8.6-1 Table 3.8.6-1 Category C limits. I Category A or B limits. AND A.2 Verify parameters for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months required battery AND cells meet Table 3.8.6-1 Category C limits. Once per 7 days thereafter AND A.3 Restore parameters 31 days for required battery cells to Table 3.8.6-1 Category A and B limits.

(continued)

DAEC 3.8-23 Amendment No. 234 OCT o 2UQa

Battery Cell Parameters 3.8.6 ACTIONS (continued)

CONDITION l REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.

Time of Condition A not met.

OR One or more batteries with average electrolyte temperature of the representative cells not within limits.

OR One or more batteries with one or more battery cell parameters for required battery cells not within Table 3.8.6-1 Category C limits.

DAEC 3.8-24 Anendment No. 234 OCT 0 3 2000

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet 7 days Table 3.8.6-1 Category A limits.

SR 3.8.6.2 Verify battery cell parameters meet 92 days Table 3.8.6-1 Category B limits.

AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after battery discharge

< 110 V for 125 V and

<220 V for 250 V AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after battery overcharge

> 150 V for 125 V and

> 300 V for 250 V SR 3.8.6.3 Verify average electrolyte temperature of 92 days representative cells is 2 651F for each battery.

DAEC 3.8-25 Amendment 223

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameter Requirements CATEGORY A:

LIMITS FOR EACH CATEGORY B: CATEGORY C:

DESIGNATED PILOT LIMITS FOR EACH LIMITS FOR EACH PARAMETER CELL CONNECTED CELL CONNECTED CELL Electrolyte > Minimum level > Minimum level Above top of Level indication mark, indication mark, plates, and not and 5 14 inch above and < 'S inch above overflowing maximum level maximum level indication mark(a) indication mark(a)

Float 2.13 V 22.13 V > 2.07 V Voltage Specifi 1.195 a 1.190 Not more than GravitySb)(c) 0.020 below AND average of all connected cells Average of all connected cells AND

> 1.200 Average of all connected cells t 1.190 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. Level correction is not required, however, when on float charge and battery charging current is

< 2 amps.

(c) A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific gravity requirements. specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

DAEC 3.8-26 Amendment 223

Distribution Systems - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Distribution Systems -Operating LCO 3.8.7 The following AC and DC electrical power distribution subsystems shall be OPERABLE:

a. Division 1 and Division 2 AC electrical power distribution subsystems:

b. Division 1 and Division 2 125 VDC electrical power distribution subsystems:

c. 250 VDC electrical power distribution subsystem:

d. Intake structure electrical power distribution subsystems: and

e. 125 VDC RCIC Motor Control Center (MCC).

APPLICABILITY: MODES 1. 2. and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more AC A.1 Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power power distribution distribution subsystems to AND subsystems inoperable. OPERABLE status.

except for the intake 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from structure electrical discovery of power distribution failure to meet subsystems. LCO 3.8.7.a or b B. One or more essential B.1 Restore the 125 VDC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 125 VDC electrical electrical power power distribution distribution AND subsystems inoperable subsystems to except for the RCIC OPERABLE status. 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from MCC. discovery of failure to meet LCO 3.8.7.a or b (continued)

DAEC 3.8-27 Amendment 223

Distribution Systems -Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or AD B not met.

C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. One or both intake D.1 Declare the Immediately structure electrical associated River power distribution Water Supply subsystem(s) subsystem(s) inoperable. inoperable.

E. 250 VDC electrical E.1 Declare.associated Immediately power distribution supported features subsystem inoperable. inoperable.

F. 125 VDC RCIC MCC F.1 Declare associated Immediately inoperable. supported features inoperable.

G. Two or more electrical G.1 Enter LCO 3.0.3. Immediately power distribution subsystems inoperable that result in a loss of function,.for reasons other than Condition D.

DAEC 3.8-28 Amendment 223

Distribution Systems - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and 7 days indicated power availability to required AC and DC electrical power distribution subsystems.

SR 3.8.7.2 Verify proper coordination of the LPCI 24 months Swing Bus circuit breakers.

DAEC 3.8-29 Amendment 223

Distribution Systems - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems -Shutdown LCO 3.8.8 The necessary portions of the AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 4 and 5.

During movement of irradiated fuel assemblies in the secondary containment.

ACTIONS

NOTE------------------------------------

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC or DC electrical supported required power distribution features(s) subsystems inoperable. inoperable.

A.2.1. Suspend CORE Immediately ALTERATIONS.

A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the secondary containment.

AM A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

AD (continued)

DAEC 3.8-30 Amendment 223

Distribution Systems -Shutdown 3.8.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to Immediately restore required AC and DC electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and 7 days indicated power availability to required AC and DC electrical power distribution subsystems.

DAEC 3.8-31 Amendment 223

Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 The refueling equipment interlocks associated with the Refuel position shall be OPERABLE.

APPLICABILITY: During in-vessel fuel movement with equipment associated with the interlocks when the reactor mode switch is in the Refuel position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel Immediately refueling equipment fuel movement with interlocks inoperable. equipment associated with the inoperable interlock(s).

DAEC 3.9-1 Amendment 223

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of 7 days the following required refueling equipment interlock inputs:

a. All-rods-in,

b. Refuel platform position.

c. Refuel platform fuel grapple. fuel loaded.

d. Refuel platform fuel grapple fully retracted position.

e. Refuel platform frame mounted hoist.

fuel loaded. and

f. Refuel platform monorail mounted hoist. fuel loaded.

DAEC 3.9-2 Amendment 223

Refuel Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.

APPLICABILITY: MODE 5 with the reactor mode switch in the Refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refuel position one- A.1 Suspend control rod Immediately rod-out interlock withdrawal.

inoperable.

AND A.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in Refuel 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months position.

(continued)

DAEC 3.9-3 Amendment 223

Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.2.2 -------------------NOTE--------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST. 7 days DAEC 3.9-4 Amendment 223

Control Rod Position 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.

APPLICABILITY: When loading fuel assemblies into the core.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more control A.1 Suspend loading fuel Immediately rods not fully assemblies into the inserted. core.

SURVEILLANCE REQUIREMENTS ____

SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months DAEC 3.9-5 Amendment 223

Control Rod Position Indication 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 The control rod "full-in" position indication for each control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each required position indication.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more .required A.1.1 Suspend in-vessel Immediately control rod position fuel movement.

indications inoperable.

AND A.1.2 Suspend control rod Immediately withdrawal.

AND A.1.3 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

OR (continued)

DAEC 3.9-6 Amendment 223

Control Rod Position Indication 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert the control rod associated with the inoperable position indicator.

AND A.2.2 Initiate action to Immediately disarm the control rod drive associated with the fully inserted control rod.

SURVEILLANCE REQUIREMENT .

SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify the required position indication has Each time the no "full-in" indication on each control rod control rod is that is not "full-in." withdrawn from the "full-in" position DAEC 3.9-7 Amendment 223

Control Rod OPERABILITY -Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY- Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or mnore withdrawn A.1 Initiate action to Immediately control rods fully insert inoperable. inoperable withdrawn control rods.

SURVEILLANCE REQUIREMENTS .

SURVEILLANCE FREQUENCY SR 3.9.5.1 ------------------NOTE---------------------

Not required to be performed until 7 days after the control rod is withdrawn.

Insert each withdrawn control rod at least 7 days one notch.

SR 3.9.5.2 Verify each withdrawn control rod scram 7 days accumulator pressure is 2 940 psig.

DAEC 3.9-8 Amendment 223

RPV Water Level 3.9.6 3.9 REFUELING OPERATIONS

. 3.9.6 Reactor Pressure'Vessel (RPV) Water Level LCO 3.9.6 RPV water level shall be 2 23 ft above the top of the irradiated fuel assemblies seated within the RPV.

APPLICABILITY: During movement of irradiated fuel assemblies within the RPV.

During movement of new fuel assemblies or handling of control rods within the RPV, when irradiated fuel assemblies are seated within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit. fuel assemblies and handl-ing of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is 2 23 ft above the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months top of the irradiated fuel assemblies seated within the RPV.

DAEC 3.9-9 Amendment 223

RHR-High Water Level 3.9.7 3.9 REFUELING OPERATIONS a.9.7 Residual Heat Removal (RHR) - High Water Level 0O 3.9.7 One RHR shutdown cooling subsystem shall be OPERABLE; and in operation when reactor coolant temperature 2 150 OF.

NOTE----------------------------

The required RHR shutdown cooling subsystem may not be in operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the Reactor Pressure Vessel (RPV) and the water level > 21 ft-1 inch above the top of the RPV flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME Required RHR shutdown A.1 Verify by 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months cooling subsystem administrative means inoperable. an alternate method AND of decay heat removal is available. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter B. Required Action and B.1 Suspend loading Immediately associated Completion irradiated fuel Time of Condition A assemblies into the not met.. RPV.

AND (continued)

IDAEC 3.9-10 Amendment No. 234 OCT 0 3 2000

RHR-High Water Level 3.9.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to Immediately restore secondary containment to OPERABLE status.

AND B.3 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.

AND B.4 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

(continued)

DAEC 3.9-11 Amendment 223

RHR-High Water Level 3.9.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. No RHR shutdown C.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery cooling subsystem in coolant of no reactor coolant operation with circulation by circulation reactor coolant an alternate temperature Ž 150'F. method.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AM' C.2 Monitor reactor Once per hour coolant temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is operating when rea&tor coolant temperature is k 150 F.

DAEC 3.9-12 Amendment 223

RHR-Low Water Level 3.9.8

,1-3.9 REFUELING OPERATIONS 3.9.8 Residual Heat Removal (RHR) - Low Water Level LCO 3.9.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and one RHR shutdown cooling subsystem shall be in operation.

NOTE---------------------------

The required operating shutdown cooling subsystem may not be in operation for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the Reactor Pressure Vessel (RPV) and the water level < 21 ft-1 inch above the top of the RPV flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required A.1 Verify by 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RHR shutdown cooling administrative means subsystems inoperable. an alternate method AND of decay heat removal is available for each Once per inoperable required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RHR shutdown cooling thereafter subsystem.

B. Required Action and B.1 Initiate action to Immediately associated Completion restore secondary Time of Condition A containment to not met. OPERABLE status.

AND (continued)

DAEC 3.9-13 Amendment No. 234 OCT 0 3 2000

RHR-Low Water Level 3.9.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to Immediately restore one standby gas treatment subsystem to OPERABLE status.

AND B.3 Initiate action to Immediately restore isolation capability in each required secondary containment penetration flow path not isolated.

C. No RHR shutdown C.1 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from cooling subsystem in coolant circulation discovery of no operation. by an alternate reactor coolant method. circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND C.2 Monitor reactor Once per hour coolant temperature.

DAEC 3.9-14 Amendment 223

RHR-Low Water Level 3.9.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is operating.

DAEC -3.9-15 Amendment 223

System Leakage and Hydrostatic Testing Operation 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 System Leakage and Hydrostatic Testing Operation LCO 3.10.1 The average reactor coolant temperature specified in Table 1.1-1 for MODE 4 may be changed to "NA," and operation considered not to be in MODE 3; and the requirements of LCO 3.4.8, "Residual Heat Removal (RHR) Shutdown Cooling System -

Cold Shutdown," may be suspended, to allow reactor coolant temperature > 212'F:

For performance of a system leakage or hydrostatic test,

As a consequence of maintaining adequate pressure for a system leakage or hydrostatic test, or

" As a consequence of maintaining adequate pressure for control rod scram time testing initiated in conjunction with a system leakage or hydrostatic test, provided the following MODE 3 LCOs are met:

a. LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," Functions 1, 3, and 4 of Table 3.3.6.2-1;

b. LCO 3.6.4.1, "Secondary Containment";

c. LCO 3.6.4.2, "Secondary Containment Isolation Valves/Dampers (SCIV/Ds)"; and

d. LCO 3.6.4.3, "Standby Gas Treatment (SBGT) System."

APPLICABILITY: MODE 4 with average reactor coolant temperature > 212 0 F.

DAEC 3.10-1 Amendment 264

System Leakage and Hydrostatic Testing Operation 3.10.1 ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTE---------

above requirements not Required Actions to met. be in MODE 4 include reducing average reactor coolant temperature to

< 212 0F.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Suspend activities Immediately that could increase the average reactor coolant temperature or pressure.

AND A.2.2 Reduce average 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months reactor coolant temperature to

< 212 0F.

DAEC 3.10-2 Amendment 223

System Leakage and Hydrostatic Testing Operation 3.10.1 SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.10.1.1 Perform the applicable SRs for the required According to MODE 3 LCOs. the applicable SRs DAEC 3.10-3 Amendment 223

Reactor Mode Switch Interlock Testing 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Reactor Mode Switch Interlock Testing LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 for MODES 3. 4. and 5 may be changed to include the Run.

Startup/Hot Standby, and Refuel position. and operation considered not to be in MODE 1 or 2. to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or more fuel assemblies: and

b. No CORE ALTERATIONS are in progress.

APPLICABILITY: MODES 3 and 4 with the reactor mode switch in the Run, Startup/Hot Standby, or Refuel position.

MODE 5 with the reactor mode switch in the Run or Startup/Hot Standby position.

ACTIONS CONDITION . REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except met. for control rod insertion.

AND A.2 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

DAEC 3.10-4 Amendment 223

Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the Shutdown position.

OR A.3.2 -------- NOTE---------

Only applicable in MODE 5.

Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the Refuel position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months in core cells containing one or more fuel assemblies.

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DAEC 3.10-5 Amendment 223

Single Control Rod Withdrawal -Hot Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal -Hot Shutdown LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3 may be changed to include the Refuel position.

and operation considered not to be in MODE 2. to allow withdrawal of a single control rod, provided the following requirements are met:

a. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock":

b. LCO 3;9.4. "Control Rod Position Indication":

c. All other control rods are fully inserted: and

d. 1. LCO 3.3.1.1. "Reactor Protection System (RPS)

Instrumentation." MODE 5 requirements for Functions l.a. 1.b. 7.a. 7.b. 10. and 11 of Table 3.3.1.1-1.

LCO 3.3.8.2. "Reactor Protection System (RPS)

Electric Power Monitoring." and LCO 3.9.5. "Control Rod OPERABILITY- Refueling."

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed: at which time LCO 3.1.1. "SHUTDOWN MARGIN (SDM)." MODE 3 requirements. may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the Refuel position.

DAEC 3.10-6 Amendment 223

Single Control Rod Withdrawal- Hot Shutdown*

3.10.3 ACTIONS

NOTE--------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION I REQUIRED ACTION [ COMPLETION TIME A. One or more of the A.I --------NOTES--------

above requirements not 1. Required Actions met. to fully insert all insertable control rods include placing the reactor mode switch in the Shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods,.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the Shutdown position.

DAEC 3.10-7 Amendment 223

Single Control Rod Withdrawal- Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.3.2 -------------------NOTE-----r----

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

SR 3.10.3.3 Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, are fully inserted.

DAEC 3.10-8 Amendment 223

Single Control Rod Withdrawal- Cold Shutdown 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Withdrawal -Cold Shutdown LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1

-for MODE 4 may be changed to include the Refuel position.

and operation considered not to be in MODE 2. to allow withdrawal of a single control rod, and subsequent removal of the associated Control Rod Drive (CRD) if desired.

provided the following requirements are met:

a. All other control rods are fully inserted:

b. 1. LCO 3.9.2. "Refuel Position One-Rod-Out Interlock,"

and LCO 3.9.4. "Control Rod Position Indication."

OR

2. A control rod withdrawal block is inserted:

c. 1. LCO 3.3.1.1. "Reactor Protection System (RPS)

Instrumentation." MODE 5 requirements for Functions l.a. 1.b. 7.a, 7.b. 10. and 11 of Table 3.3.1.1-1.

LCO 3.3.8.2. "Reactor Protection System (RPS)

Electric Power Monitoring." and LCO 3.9.5. "Control Rod OPERABILITY- Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed: at which time LCO 3.1.1. "SHUTDOWN MARGIN (SDM)." MODE 4 requirements, may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor mode switch in the Refuel position.

DAEC 3.10-9 . Amendment 223

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS

NOTE-------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION. REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTES--------

above requirements not 1. Required Actions met with the affected to fully insert control rod. all insertable insertable. control rods include placing the reactor mode switch in the Shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the Shutdown position.

I .1.

(continued)

DAEC 3. 10-10 Amendment 223

Single Control Rod Withdrawal -- Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of Immediately above requirements not the control rod and met with the affected removal of associated control rod not CRD.

insertable.

AND B.2.1 Initiate action to Immediately fully insert all control rods.

OR B.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.4.2 ------------------- NOTE--------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.

Verify all control rods. other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

(continued)

DAEC 3. 10-11 EAmendment 223

Single Control Rod Withdrawal- Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod being withdrawn. are fully inserted.

SR 3.10.4.4 --------------- NOTE--------------------

.Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.

Verify a control rod withdrawal block is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inserted.

DA~EC 3.10-12 Amendment 223

Single CRD Removal - Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Single Control Rod Drive (CRD) Removal- Refueling LCO 3.10.5 The requirements of LCO 3.3.1.1. "Reactor Protection System (RPS) Instrumentation": LCO 3.3.8.2. "Reactor Protection System (RPS) Electric Power Monitoring": LCO 3.9.1.

"Refueling Equipment Interlocks": LCO 3.9.2. "Refuel Position One-Rod-Out Interlock": LCO 3.9.4. "Control Rod Position Indication": and LCO 3.9.5. "Control Rod OPERABILITY-Refueling." may be suspended in MODE 5 to allow the removal of a single CRD associated with a control rod withdrawn from a core cell containing one or more fuel assemblies. provided the following requirements are met:

a. All other control rods are fully inserted:

b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed:

c. A control rod withdrawal block is inserted and LCO 3.1.1. "SHUTDOWN MARGIN (SDM)," MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod: and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of Immediately above requirements not the CRD mechanism.

met.

AND (continued)

DAEC 3.10-13 Amendment 223

Single CRD Removal- Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert all control rods.

OR A.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all control rods. other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod withdrawn for the removal of the associated CRD. are fully inserted.

SR 3.10.5.2 Verify all control rods. other than the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months control rod withdrawn for the removal of the associated CRD. in a five by five array centered on the control rod withdrawn for the removal of the associated CRD. are disarmed.

SR 3.10.5.3 Verify a control rod withdrawal block is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inserted.

SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 (continued)

DAEC 3.10-14 Amendment 223

Single CRD Removal- Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.5.5 Verify no other CORE ALTERATIONS are in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months progress.

DAEC 3.10-15 Amendment 223

Multiple Control Rod Withdrawal - Refueling 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Multiple Control Rod Withdrawal - Refueling LCO 3.10.6 The requirements of LCO.3.9.3. "Control Rod Position":

LCO 3.9.4. "Control Rod Position Indication": and LCO 3.9.5.

"Control Rod OPERABILITY- Refueling." may be suspended. and the "full in" position indicators may be bypassed for any number of control rods in MODE 5. to allow withdrawal of these control rods. removal of associated Control Rod Drives (CRDs). or both. provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells associated with each control rod or CRD to be removed:

b. All other control rods in core cells containing one or more fuel assemblies are fully inserted: and

c. Fuel assemblies shall only be loaded in compliance with an approved reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3. LCO 3.9.4. or LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal of Immediately above requirements not control rods and met. removal of associated CRDs.

AND A.2 Suspend loading fuel Immediately assemblies.

AND (continued)

DAEC 3.10-16 Amendment 223

Multiple Control Rod Withdrawal - Refueling 3.10.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Initiate action to Immediately fully insert all control rods in core cells containing one or more fuel assemblies.

OR A.3.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from core cells associated with each control rod or CRD removed.

SR 3.10.6.2 Verify all other control rods in core cells 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months containing one or more fuel assemblies are fully inserted.

SR 3.10.6.3 ------------------- NOTE--------------------

Only required to be met during fuel loading.

Verify fuel assemblies being loaded are in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months compliance with an approved reload sequence.

DAEC 3.10-17 Amendment 223

Control Rod Testing - Operating 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 Control Rod Testing- Operating LCO 3.10.7 The requirements of LCO 3.1.6. "Rod Pattern Control." may be suspended to allow performance of SDM demonstrations.

control rod scram time testing, and control rod friction testing. provided:

a. The Banked Position Withdrawal Sequence requirements of SR 3.3.2.1.7 are changed to require the control rod sequence to conform to the specified test sequence.

OR

b. The RWM is bypassed: the requirements of LCO 3.3.2.1.

"Control Rod Block Instrumentation." Function 2 are suspended: and conformance to the approved control rod sequence for the specified test is verified by a second licensed operator or other qualified member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO 3.1.6 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance Immediately LCO not met. of the test and exception to LCO 3.1.6.

DAEC 3.10-18 Amendment 223

Control Rod Testing -Operating 3.10.7 SURVEILLANCE REQUIREMENTS .

SURVEILLANCE FREQUENCY SR 3.10.7.1 -------------------NOTE--------------------

Not required to be met if SR 3.10.7.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the specified test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.7.2 -------------------NOTE--------------------

Not required to be met if SR 3.10.7.1 satisfied.

Verify control rod sequence input to the Prior to RWM is in conformance with the approved control rod control rod sequence for the specified movement test.

DAEC 3. 10-19 Amendment 223

SDM Test - Refueling 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 SHUTDOWN MARGIN (SDM) Test- Refueling LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5 may be changed to include the Startup/Hot Standby position. and operation considered not to be in MODE 2. to allow SDM testing, provided the following requirements are met:

a. LCO 3.3.1.1, "Reactor Protection System Instrumentation." MODE 2 requirements for Functions 2.a and 2.d of Table 3.3.1.1-1:

b. 1. LCO 3.3.2.1. "Control Rod Block Instrumentation,"

MODE 2 requirements for Function 2 of Table 3.3.2.1-1. with the Banked Position Withdrawal Sequence requirements of SR 3.3.2.1.7 changed to require the control rod sequence to conform to the SDM test sequence.

OR

2. Conformance to the approved control rod sequence for the SDM test is verified by a second licensed operator or other qualified member of the technical staff:

c. Each withdrawn control rod shall be coupled to the associated CRD:

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out mode;

e. No other CORE ALTERATIONS are in progress: and

f. CRD charging water header pressure > 970 psig.

APPLICABILITY: MODE 5 with the reactor mode switch in Startup/Hot Standby position.

DAEC 3.10-20 Amendment 223

SDM Test - Refueling 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---------- NOTE-------- -------------NOTE------------

Separate Condition Rod Worth Minimizer may be entry is allowed for bypassed as allowed by each control rod. LCO 3.3.2.1. "Control Rod Block Instrumentation." if required. to allow insertion One or more of inoperable control rod and control rods not continued operation.

coupled to its associated CRD.

A.1 Fully insert 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months inoperable control rod.

AND A.2 Disarm the 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated CRD.

B. One or more of the LCO B.1 Place the reactor Immediately requirements not met mode switch in the for reasons other than Shutdown or Refuel Condition A. position.

DAEC 3.10-21 Amendment 223

SDM Test- Refueling 3.10.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for LCO According to 3.3.1.1. Functions 2.a and 2.d of Table the applicable 3.3.1.1-1. SRs SR 3.10.8.2 -------------------NOTE--------------------

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for According to LCO 3.3.2.1. Function 2 of Table 3.3.2.1-1. the applicable SRs SR 3.10.8.3 -------------------NOTE--------------------

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

(continued)

DAEC 3.10-22 Amendment 223

SDM Test - Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control-rod does not Each time the go to the withdrawn overtravel position. control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure 7 days 2 970 psig.

DAEC 3.10-23 Amendment 223

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The plant site, which consists of approximately 500 acres. is adjacent to the Cedar River approximately 2.5 miles northeast of the Village of Palo. Iowa. Distance from the reactor centerline to the nearest site boundary is approximately 2000 ft. The boundary of the exclusion area defined in 10 CFR 100 is delineated by the property lines. The distance to the outer boundary of the low population zone is 6 miles. The plan of the site is shown on UFSAR Figures 1.2-1 and 1.2-2.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall consist of not more than 368 fuel assemblies. Each assembly shall consist of a matrix of Zircalloy or ZIRLO fuel rods with an initial composition of natural or slightly enriched uranium dioxide CUD 2) as fuel material, and water rods. Limited substitutions of zirconium alloy or stainless steel filler rods 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 NRC staff approved codes and methods and have been shown by tests or analyses to comply with all safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 89 cruciform shaped control rod assemblies. The control materials shall be boron carbide and hafnium metal, as approved by the NRC.

(continued)

DAEC 4.0-1 Amendment 223

Design Features 4.0 K) 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having the following limits for maximum k-infinity in the normal reactor core configuration at cold conditions and maximum lattice-average U-235 enrichment weight percent:

k-o wt %

i) 7x7 and 8x8 pin arrays < 1.31 < 4.6 (Holtec and PaR racks) ii) 9x9 and lOxlO pin arrays < 1.29

4.95 (Holtec racks) iii) 9x9 and lOxlO pin arrays < 1.39 < 4.95 (PaR racks)

b. ke < 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in 9.1 of the UFSAR; and

c. A nominal 6.060 inches for HOLTEC designed and 6.625 inches for PaR designed center to center distance between fuel assemblies placed in the storage racks.

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum k-infinity of 1.31 in the normal reactor core configuration at cold conditions;

b. ke < 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR;

c. ke < 0.90 if dry, which includes an allowance for uncertainties as described in Section 9.1 of the UFSAR; and

d. A nominal 6.625 inch center to center distance between fuel assemblies placed in storage racks.

(continued)

DAEC 4.0-2 Amendment No. 226 JUN 0 3 1399

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 831 ft.- 2 3/4 in.

4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 3152 fuel assemblies in a vertical orientation, including no more than 323 fuel assemblies stored in the cask pit in accordance with UFSAR Section 9.1.

The new fuel storage vault is equipped with racks for storage of up to 110 fuel assemblies in a vertical orientation.

DAEC 4.0-3 Amendment 223

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager or his designee shall approve. prior to implementation. each proposed test. experiment or modification to systems or equipment that affects nuclear safety.

5.1.2 The Operations Shift Manager shall be responsible for the control room command function. During any absence of the Operations Shift Manager from the control room while the unit is in MODE 1. 2. or

3. an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the Operations Shift Manager from the control room while the unit is in MODE 4 or 5. an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

DAEC 5.0-1 Amendment 223

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions. or in equivalent forms of documentation. These requirements including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in the Technical Specifications shall be documented in the UFSAR or QA Program

Description:

b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant:

c. The corporate-officer with direct responsibility for the plant shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating.

maintaining, and providing technical support to the plant to ensure nuclear safety: and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager: however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

(continued)

DAEC 5.0-2 Amendment 223

Organ ization 5.2 5.2 Organization (continued) 5.2.2 Unit Staff The unit staff organization shall also include the following:

a. A non-licensed operator shall be assigned to the reactor when containing fuel and an additional non-licensed operator shall be assigned to the reactor when operating in MODES 1, 2, or 3.

b. Shift crew composition shall meet the requirements stipulated herein and in 10 CFR 50.54(m).

c. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.g for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

d. A person qualified to implement radiation protection procedures shall be on site when fuel is in the reactor. The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

e. Not used.

f. The Operations Manager or Operations Supervisors shall hold an SRO license.

(continued)

DAEC 5.0-3 Amendment No. 274

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

9. An individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift. This function is not required in MODES 4 and 5.

DAEC 5.0-4 Amendment No. 248 OCT 0 2 2Wl2

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications referenced for comparable positions in ANSI/ANS 3.1-1978. The radiation protection manager shall meet or exceed the qualifications of Regulatory Guide 1.8. September 1975.

5.3.2 For the purpose of 10 CFR 55.4. a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1. perform the functions described in 10 CFR 50.54(m).

DAEC 5.0-5 Amendment 223

Procedures 5.4 i , 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established. implemented. and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33. Revision 2. Appendix A. February 1978:

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737. Supplement 1.

as stated in Generic Letter 82-33:

c. Quality assurance for effluent and environmental monitoring:

d. Fire Protection Program implementation: and

e. All programs specified in Specification 5.5.

.DAEC 5.0-6 Amendment 223

Programs and Manuals 5.5 5.0 ADMINISTRATiVE CONTROLS 5.5 Programs ana Manuals The following programs shall be established. implemented and maintained.

5.5.1 Offsite Dose Assessment Manual (ODAM)

a. The ODAM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODAM shall also contain the radioactive effluent controls and radiological environmental monitoring activities and descriptions of the information that should be included in the Annual Radiological Environmental Operating Report and Radioactive Material Release Report required by Specification 5.6.2 and Specification 5.6.3.

c. Licensee initiated changes to the ODAM:

1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

a. Sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and

b. A determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I. and not adversely impact the accuracy or reliability of effluent dose or setpoint calculations;

2. Shall become effective after the approval of the plant manager; and

3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODAM as a part of or concurrent with the Radioactive Material Release Report for the period of the report in which any change in the ODAM was made. Each change shall be identified by (continued)

DAEC 5.0-7 Amendment No. 234 OCT 0 3 2L000

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Assessment Manual (ODAM) (continued) markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include Core Spray, High-Pressure Coolant Injection, Residual Heat Removal, Reactor Core Isolation Cooling, Reactor Water Cleanup (only to second isolation valve). Post Accident Sampling (until such time as a modification eliminates PASS as a potential leakage path),

Containment Atmospheric Monitoring, Control Rod Drive (scram discharge volume only) and Liquid Radviaste (only Reactor Building Floor and Equipment Drain sump pumps, piping, and tanks up to and including collector tanks). The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; ahd

b. System leak test requirements for each system at least once per 24 months.

The provisions of SR 3.0.2 are applicable.

5.5.3 [Deleted]

(continued)

DAEC 5.0-8 Amendment lb. 258 em,-

" as,

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.4 Radioactive Effluent Controls Program This program. conforming to 10 CFR 50.36a. provides for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODAM. shall be implemented by procedures. and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODAM:

b. Limitations on the concentrations of radioactive material released in liquid effluents from the site to unrestricted areas. conforming to ten times (10x) the concentrations listed in Appendix B. Table 2. Column 2 to 10 CFR 20.1001 - 20.2402:

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents pursuant to 10 CFR 20.1302 and with the methodology and parameters in the ODAM:

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released to unrestricted areas. conforming to 10 CFR 50. Appendix I:

e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODAM at least every 31 days:

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that the appropriate portions of these systems which were used to establish compliance with the design objectives in 10 CFR

50. Appendix I. Section II be used when specified to provide reasonable assurance that releases of radioactive material in liquid and gaseous effluents be kept as low as reasonably achievable:

(continued)

DAEC 5.0-9 Amendment 223

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be limited to the following:

1. For noble gases: less than or equal to a dose rate of 500 mrem/yr to the whole body and less than or equal to a dose rate of 3000 mrem/yr to the skin, and

2. For lodine-131, iodine-133, tritium, and for all radionuclides in particulate form with half lives > 8 days: less than or equal to a dose rate of 1500 mrem/yr to any organ;

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents to areas beyond the site boundary, conforming to 10 CFR 50, Appendix l;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released to areas beyond the site boundary, conforming to 10 CFR 50, Appendix l; and

j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the UFSAR Section 5.3.3, cyclic and transient occurrences to ensure that components are maintained within the design limits.

DAEC 5.0-10 (continued)

Corrected by NRC Letter dated October 28, 2002 Amendment No. 248 (RF- &ZLWJ 6t lO -a9q-Q6a MA)

Programs and Manuals I

5.5 5.5 Programs and Manuals (continued) 5.5.6 Inservice e-stina Program This program provides controls for inservice testing of ASME Code Class 1, 2. and 3 components. The program shall include the I

following:

a. Testing Frequencies specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda are as follows:

ASME -oiler and Pressure Vessel Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice actni ties tprstinn a;tivitipq Weekly'! At least once per 7 days Monthly At least once per 31 days Biquarterly At least once per 46 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing inservice testing activities:

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

(continued)

DAEC 5.0-11 Amendment No. 234 UCT 0 3 2000

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.7 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems.

The tests described in Specifications 5.5.7.a and 5.5.7.b shall be performed once per 12 months for standby service. after 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of system operation. following significant painting. fire or chemical release in any ventilation zone communicating with the system. after any structural maintenance on the system housing.

and after each partial or complete replacement of the HEPA filter train or charcoal adsorber. respectively.

The test described in Specification 5.5.7.c shall be performed once per 12 months for standby service. after 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of system operation and following significant painting. fire or chemical release in any ventilation zone communicating with the system.

The tests described in Specifications 5.5.7.d and 5.5.7.e shall be performed annually.

For the SBGT System only, the test described in Specification 5.5.7.f shall be performed after each complete or partial replacement of the HEPA filter bank and after any structural maintenance on the system housing.

For the SBGT System only. the test described in Specification 5.5.7.g shall be performed in conjunction with the tests described in Specification 5.5.7.c.

a. Demonstrate for each of the ESF systems that an inplace test of the HEPA filters shows a penetration and system bypass at the value specified and at the system flowrate specified below:

ESF Ventilation System Penetration Flowrate (cfm) and System Bypass (%)

SBGT System < 0.1 3600 - 4400 SFU System < 1.0 900 - 1100 (continued)

DAEC 5.0-12 Amendment 223

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass at the value specified and at the system flowrate specified below:

ESF Ventilation System Penetration Flowrate (cfm) and System Bypass (%)

SBGT System < 0.1 3600 - 4400 SFU System < 1.0 900 - 1100

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described *in Regulatory Guide 1.52 Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 300C and the relative humidity specified below:

ESF Ventilation System Penetration Relative Humidity SBGT System < 0.5% > 70%

SFU System < 5.0% > 95%

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters (SBGT System only), and the charcoal adsorbers is less than the value specified below and at the system flowrate specified as follows:

(continued)

Amendment N6. 235 DAEC 5.0-13 DEC 2 7 2X1

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Delta P (inches wg) Flowrate (cfm)

SBGT System < 11 3600 - 4400 SFU System < 6 900 - 1100

e. Demonstrate that the heaters for the SBGT System dissipate k 22 kW.

f. Demonstrate that air distribution is uniform within 20% of averaged flow per unit across SBGT System HEPA filters.

g. Visually inspect the SBGT System charcoal adsorber to ensure no flow blockage has occurred.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Prooram This program provides controls for potentially explosive gas mixtures contained in the Offgas System downstream of the.

recombiners and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks. The liquid radwaste quantities shall be determined in accordance with Standard Review Plan. Section 15.7.3. "Postulated Radioactive Release due to Tank Failures".

The program shall include:

a. The limits for concentrations of hydrogen in the Offgas System downstream of the recombiners and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e..

whether or not the system is designed to withstand a hydrogen explosion):

(continued)

DAEC 5.0-14 Amendment 223

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

b. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is s 50 curies, excluding tritium and dissolved or entrained noble gases. The liquid radwaste storage tanks in the Low-Level Radwaste Processing and Storage Facility are considered unprotected outdoor tanks.

The provisions of SR 3.9.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

5.5.9 Diesel Fuel Oil Testina Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. An API gravity within limits,

2. A viscosity within limits for ASTM 2-D fuel oil, and

3. Water and sediment within limits;

b. Viscosity, water and sediment for stored ASTI1 2-D fuel oil are within limits every 31 days; and

c. Total particulate.concentration of the stored fuel oil is

< 10 mg/l when tested every 92 days.

The provisions of SR 3..2 and SR 3.0.3 are applicab.e to the Diesel Fuel Oil Testing Program testing frequencies.

(continued)

DAEC 5.0-15 Amendment No. 234 OCT 0o 2000

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.10 Technical Specif-:ations (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technica, Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. A change in the TS incorporated in the license; or

2. A change to the UFSAR or Bases that requires NRC apprcval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the UFSAR.

d. Proposed changes that meet the criteria of Specification 5.5.10b above shall be reviewed and approved by the NRC prior to implementation. Changes to-the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.11 Safety Function Cetermination Program (SFDP)

This program ensures loss of safety function is detected and appropriate acticns taken. Upon entry into LCO 3.0.6. an evaluation shall :e made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory E:tions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supporte- system Condition and Required Actions. This program implements the requirements of LCO 3.0.6.

a. The SFDP sr.zll contain the following:

1. Prov. ions for cross division checks to ensure a loss of the capability to perform the safety function assured in the accident analysis does not go undeTected; (continued)

DAEC 5.0-16 Amendment lo. 241 I~ to 20-3

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Safety Function Determination Program (SFDP) (continued)

2. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

3. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

4. Other appropriate limitations and remedial or compensatory actions.

b. A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

1. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or

2. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or

3. A required system redundant to support system(s) for the supported systems (1) and (2) above is also inoperable.

c. 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. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.12 Primary Containment Leakage Rate Testing Program

a. A program shall be established to implement the leakage rate testing of the primary containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions.

b. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak Test Program," dated September 1995, as modified by the following exceptions to NEI 94-01, Rev. 0, "Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J":

1. The first Type A test after the September 1993 Type A test shall be performed no later than September 2008.

(continued)

DAEC 5.0-17 Amendment No. 276

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Primary Containment Leakage Rate Testing Program (continued)

2. Exemption from Section liLA of 10 CFR Part 50, Appendix J, Option B, to allow the contribution from Main Steam pathway leakage to be excluded from the overall integrated leakage rate from Type A tests.

3. Exemption from Section III.B of 10 CFR Part 50, Appendix J, Option B, to allow the contribution from Main Steam pathway leakage to be excluded from the sum of the leakage rates from Type B and Type C tests.

c. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 45.7 psig.

d. The maximum allowable primary containment leakage rate, La, at Pa, shall be 2.0% of primary containment air weight per day.

e. Leakage Rate acceptance criteria are:

1. Primary Containment leakage rate acceptance criterion is ::; 1.0 La. During the first startup following testing in accordance with this program, the leakage rate acceptance criteria are: ::; 0.60 La for the Type B and Type C tests; and, ::; 0.75 La for the Type A tests; and

2. The air lock testing acceptance criterion is overall air lock leakage rate::; 0.05 La when tested at 2 Pa.

f. The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.

5.5.13 Control Building Envelope Habitability Program A Control Building Envelope (CBE) Habitability Program shall be established and implemented to ensure that CBE habitability is maintained such that, with an OPERABLE Standby Filter Unit System, CBE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CBE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a. The definition of the CBE and the CBE boundary.

b. Requirements for maintaining the CBE boundary in its design condition including configuration control and preventive maintenance.

(continued)

DAEC 5.0-18 Amendment No. 276

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Control Buildinq Envelope Habitability Progqram (continued)

c. Requirements for (i) determining the unfiltered air inleakage past the CBE boundary into the CBE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CBE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

d. Measurement, at designated locations, of the CBE pressure relative to all external areas adjacent to the CBE boundary during the pressurization mode of operation by one subsystem of the SFU System, operating at the flow rate required by the VFTP, at a Frequency of 24 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 24 month assessment of the CBE boundary.

e. The quantitative limits on unfiltered air inleakage into the CBE.

These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air leakage limits for hazardous chemicals must ensure that the exposure of CBE occupants to these hazards will be within the assumptions in the licensing basis.

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CBE habitability, determining CBE unfiltered inleakage, and measuring CBE pressure and assessing the CBE.boundary as required by paragraphs c and d, respectively.

DAFC 5.0-18a Amendment No. 269

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 DELETED I

5.6.2 Annual Radiological Environmental Ogeratina Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Assessment Manual (ODAM), and in 10 CFR 50, Appendix I. Sections IV.B.2. IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken durin9 the period pursuant to the locations specified in the table and figures in the ODAM. as well as summarized and tabulated results of these analyses and measurements in the format of the table in Regulatory Guide 4.8. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

(continued)

DAEC 5.0-19 Amendment No. 256

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.3 Radioactive Material Release Report The Radioactive Material Release Report covering the operation of the unit during the previous calendar year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a sumnary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODAM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

5.6.4 DELETED 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1. The Average Planar Linear Heat Generation Rate (APLHGR) for Specification 3.2.1;

2. The Minimum Critical Power Ration (MCPR) for Specification 3.2.2; and

3. Exclusion Region in the Power/Flow Map for Specification 3.4.1.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC in General Electric Standard Application for Reactor Fuel.

NEDE-24011-P-A, (GESTAR II). The revision number is the one approved at the time the reload fuel analyses are performed.

(continued)

DAEC 5.0-20 Amendment No. 256

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

c. The core operating limits shall be determined such that all applicable limits (e.g.. fuel thermal mechanical limits.

core thermal hydraulic limits. Emergency Core Cooling Systems (ECCS) limits. nuclear limits such as SDM. transient analysis limits. and accident analysis limits) of the safety analysis are met.

d. The COLR. including any midcycle revisions or supplements.

shall be provided upon issuance for each reload cycle to the NRC.

5.6.6 PAM Report When a report is required by Condition B or F of LCO 3.3.3.1.

"Post Accident Monitoring (PAM) Instrumentation." a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method(s) of monitoring, describe the degree to which the alternate method(s) are equivalent to the installed PAM channels. justify the areas in which they are not equivalent. the cause of the inoperability. and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

DAEC 5.0-21 Amendment 223

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601 (a) and (b) of 10 CFR Part 20:

5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b. Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously displays radiation dose rates in the area; or

2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area, or

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (continued)

DAEC 5.0-22 Amendment No. 248 OCT 0 2. 2W2

High Radiation Area 5.7 5.7 High Radiation Area (continued)

(i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at 30 Centimeters from the Radiation Source or from any Surface Penetrated by the Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1. All such door and gate keys shall be maintained under the administrative control of the shift supervisor, radiation protection manager, or his or her designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

(continued)

DAEC 5.0-23 Amendment No. 248 OCT 0 220

High Radiation Area 5.7 5.7 High Radiation Area (continued)

b. Access to, and activities in, each area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached with an appropriate alarm setpoint, or

2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

(continued)

DAEC 5.0-24 Amendment No. 248 Corrected by NRC Letter dated October 28, 2002

[ tba- Q Ob,;k )

High Radiation Area 5.7 5.7 High Radiation Area (continued)

4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

f. Such individual areas that are within a larger area where no enclosure exists for the purpose of locking and where no enclosure can reasonably be constructed around the individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible flashing light shall be activated at the area as a warning device.

DAEC r.0-25 Amendment No. 248 OCT 0 2 202

APPENDIX B ADDITIONAL CONDITIONS OPERATING LICENSE NO. DPR-49 NextEra Energy Duane Arnold, LLC (the term licensee in Appendix B refers to NextEra Energy Duane Arnold, LLC or prior license holders) shall comply with the following conditions on the schedule noted below:

Amendment Number Additional Conditions Implementation Date 223 NextEra Energy Duane Arnold, LLC is This amendment is authorized to relocate certain effective immediately requirements included in Appendix and shall be implemented A to licensee-controlled documents. within 180 days of the date Implementation of this amendment of this amendment.

shall include the relocation of these requirements to the appropriate documents, as described in the licensee's application dated October 30, 1996, as supplemented and consolidated in its March 31, 1998, submittal. These relocations were evaluated in the NRC staff's Safety Evaluation enclosed with this amendment.

260 (1) At the time of the closing of the transfer This amendment is of the license from Interstate Power and effective immediately Light Company (IPL) to FPLE Duane and shall be implemented Arnold,* IPL shall transfer to FPLE Duane within 30 days of the date Arnold* IPL's decommissioning funds of this amendment.

accumulated as of such time, with a aggregate minimum value of at least $186 million, and FPLE Duane Arnold* shall deposit such funds in an external decommissioning trust fund established by FPLE Duane Arnold* for DAEC. NextEra Energy Duane Arnold shall take all necessary steps to ensure that this external trust fund is maintained in accordance with the requirements of the order approving the license transfer, NRC regulations, and consistent with the safety evaluation supporting the order. The trust agreement shall be in a form acceptable to the NRC.

On April 16, 2009, the name "FPL Energy Duane Arnold, LLC" was changed to "NextEra Energy Duane Arnold, LLC."

Amendment No. 275

-2 Amendment Number Additional Conditions Implementation Date 260 (2) By the date of closing of the transfer This amendment is of the 70 percent ownership interest in effective immediately DAEC from IPL to FPLE Duane Arnold,* and shall be implemented FPLE Duane Arnold* shall obtain a parent within 30 days of the date company guarantee from FPL Group of this amendment.

Capital in an initial amount of at least

$75 million (in 2005 dollars) to provide additional decommissioning funding assurance regarding such ownership interest, which guarantee must be in accordance with NRC regulations regarding such documents.

Required funding levels shall be recalculated annually and, as necessary, NextEra Energy Duane Arnold shall either obtain appropriate adjustments to the parent guarantee or otherwise provide any additional decommissioning funding assurance necessary for NextEra Energy Duane Arnold to meet NRC requirements under 10 CFR 50.75.

260 (3) NextEra Energy Duane Arnold shall take no action to cause FPL Group Capital, or its successors and assigns, to void, cancel, or modify its $50 million contingency commitment to NextEra Energy Duane Arnold, as represented in the license transfer application, or cause it to fail or perform or impair its performance under the commitment, or remove or interfere with NextEra Energy Duane Arnold's ability to draw upon the commitment, without the prior written consent from the NRC. An executed copy of the Support Agreement shall be submitted to the NRC no later than 30 days after completion of the license transfer. Also, NextEra Energy Duane Arnold shall inform the NRC in writing any time that it draws upon the $50 million commitment.

On April 16, 2009, the name "FPL Energy Duane Arnold, LLC" was changed to "NextEra Energy Duane Arnold, LLC."

Amendment No. 275

ML102930524

Contents

Text

SUBJECT:

Dear Mr. Costanzo:

Enclosures:

Enclosures:

SUBJECT:

Description:

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