AEP-NRC-2010-58, Application for Technical Specification Improvement to Eliminate Requirements for Hydrogen Recombiners and Hydrogen Monitors Using the Consolidated Line Item Improvement Process

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Application for Technical Specification Improvement to Eliminate Requirements for Hydrogen Recombiners and Hydrogen Monitors Using the Consolidated Line Item Improvement Process
ML102590353
Person / Time
Site: Cook  American Electric Power icon.png
Issue date: 09/08/2010
From: Gebbie J
Indiana Michigan Power Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
AEP-NRC-2010-58
Download: ML102590353 (42)
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Text

INDIANA MICHIGAN Indiana Michigan Power POWER* One Cook Place Bridgman, MI 49106 A unit ofAmerican Electric Power IndianaMichiganPower.coom September 8, 2010 AEP-NRC-2010-58 10 CFR 50.90 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

Donald C. Cook Nuclear Plant Unit 1 and Unit 2 Docket Nos. 50-315 and 50-316 Application for Technical Specification Improvement to Eliminate Requirements for Hydrogen Recombiners and Hydrogen Monitors Using the Consolidated Line Item Improvement Process

Dear Sir or Madam:

Pursuant to 10 CFR 50.90, Indiana Michigan Power Company (I&M) hereby requests an amendment to the Technical Specifications (TSs) for Donald C. Cook Nuclear Plant (CNP) Unit 1 and Unit 2.

The proposed amendment will delete the TS requirements related to hydrogen recombiners and hydrogen monitors. The proposed. TS changes support implementation of the revisions to

'10 CFR 50.44, "Standards for Combustible Gas Control System in Light-Water-Cooled Power Reactors," that became effective on October 16, 2003. The changes are consistent with Revision 1 of NRC-approved Industry/Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler, TSTF-447, "Elimination of Hydrogen Recombiners and Change to Hydrogen and Oxygen Monitors." The availability of this TS improvement was announced in the Federal Register on September 25, 2003 as part of the consolidated line item improvement process.

Enclosure 1 to this letter provides an affirmation statement pertaining to the information contained herein. Enclosure 2 provides a description of the proposed change, the requested confirmation of applicability, and plant-specific verifications and commitments. Enclosure. 3 provides the commitment made in this letter in tabular form. Attachment 1 and Attachment 2 to this letter provide, respectively, the existing Unit 1 and Unit 2 TS pages marked to show the proposed changes. Attachment 3 and 4 provide, respectively, Unit 1 and Unit 2 TS pages with the proposed changes incorporated. Implementation of TSTF-447 also involves various changes to the TS Bases. The TS Bases changes will be submitted with a future update in accordance with Unit 1 and Unit 2 TS 5.5.12, "Technical Specifications (TS) Bases Control Program."

I&M requests approval of the proposed license amendment in accordance with the normal NRC review schedule for such changes, with the amendment being implemented within 120 days of NRC approval.

U. S. Nuclear Regulatory Commission AEP-NRC-2010-58 Page 2 In accordance with 10 CFR 50.91, a copy of this application, with enclosures and attachments, is being provided to the designated Michigan state officials. Should you have any questions, please contact Mr. Michael K. Scarpello, Regulatory Affairs Manager, at (269) 466-2649.

Sincerely, Joel P. Gebbie Site Vice President JRW/jmr

Enclosures:

1. Affirmation
2. Description and Assessment - Proposed License Amendment to Eliminate Technical Specification Requirements for Hydrogen Recombiners and Hydrogen Monitors
3. Regulatory Commitment Attachments:
1. Donald C. Cook Nuclear Plant Unit 1 Technical Specification Pages Marked To Show Proposed Changes.
2. Donald C. Cook Nuclear Plant Unit 2 Technical Specification Pages Marked To Show Proposed Changes.
3. Donald C. Cook 'Nuclear Plant Unit 1 Technical Specification Pages With Proposed Changes Incorporated.
4. Donald C. Cook Nuclear Plant Unit 2 Technical Specification Pages With Proposed Changes Incorporated.

c: J. T. King, MPSC S. M. Krawec, AEP Ft. Wayne, w/o enclosures & attachments MDEQ - WHMD/RPS NRC Resident Inspector M. A. Satorius, NRC Region III P. S. Tam - NRC Washington DC

Enclosure I to AEP-NRC-2010-58 AFFIRMATION I, Joel P. Gebbie, being duly sworn, state that I am Site Vice President of Indiana Michigan Power Company (I&M), that I am authorized to sign and file this request with the Nuclear Regulatory Commission on behalf of I&M, and that the statements made and the matters set forth herein pertaining to I&M are true and correct to the best of my knowledge, information, and belief.

Indiana Michigan Power Company Joel P. Gebbie Site Vice President SWORN TO AND SUBSCRIBED BEFORE ME THIS £I DAY OFS-- *j* , 2010 SNotary Public My Commission Expires (Q [ 13

Enclosure 2 to AEP-NRC-2010-58 Description and Assessment -

Proposed License Amendment to Eliminate Technical Specification Requirements for Hydrogen Recombiners and Hydrogen Monitors

1.0 INTRODUCTION

The proposed License amendment deletes Technical Specification (TS) 3.6.8, "Hydrogen Recombiners," and deletes references to hydrogen monitors in TS 3.3.3, "Post Accident Monitoring (PAM) Instrumentation." The proposed TS changes support implementation of the revisions to 10 CFR 50.44, "Standards for Combustible Gas Control System in Light-Water-Cooled Power Reactors," that became effective on October 16, 2003. Deletion of the requirements for the hydrogen recombiner and references to hydrogen monitors results in administrative changes to the TS Table of Contents and TS 5.6.6, "Post Accident Monitoring Report," which were otherwise unaffected by this proposed amendment.

The changes are consistent with Revision 1 of NRC-approved industry/Technical Specification Task Force (TSTF) Standard Technical Specification Change Traveler, TSTF-447, "Elimination of Hydrogen Recombiners and Change to Hydrogen and Oxygen Monitors." The availability of this TS improvement was announced in the Federal Register on September 25, 2003 as part of the consolidated line item improvement process (CLIIP).

2.0 PROPOSED CHANGE

Consistent with the NRC-approved Revision 1 of TSTF-447, the proposed Unit 1 and Unit 2 TS changes include:

TS 3.3.3 Condition D Note Deleted TS 3.3.3 Condition E Two hydrogen monitor Deleted channels inoperable Surveillance Requirement Hydrogen monitor, Deleted (SR) 3.3.3.2 channel calibration SR 3.3.3.3 Channel calibration Modified of functions other than hydrogen monitors Table 3.3.3-1 Function 11, hydrogen monitors Deleted TS 3.6.8 Hydrogen Recombiners Deleted Other TS changes included in this application are limited to administrative changes that resulted directly from the deletion of the above requirements related to hydrogen recombiners and hydrogen monitors.

to AEP-NRC-2010-58 Page 2 As described in NRC-approved Revision 1 of TSTF-447, the changes to TS requirements and associated administrative changes to other TSs result in changes to various TS Bases sections.

The TS Bases changes will be submitted with a future update in accordance with Unit 1 and Unit 2 TS 5.5.12, "Technical Specifications (TS) Bases Control Program."

3.0 BACKGROUND

The background for this application is adequately addressed by the NRC Notice of Availability published on September 25, 2003 (68 FR 55416), TSTF-447, the documentation associated with the 10 CFR 50.44 rulemaking, and other related documents.

4.0 REGULATORY REQUIREMENTS AND GUIDANCE The applicable regulatory requirements and guidance associated with this application are adequately addressed by the NRC Notice of Availability published on September 25, 2003 (68 FR 55416), TSTF-447, the documentation associated with the 10 CFR 50.44 rulemaking, and other related documents.

5.0 TECHNICAL ANALYSIS

I&M has reviewed the Safety Evaluation (SE) published on September 25, 2003 (68 FR 55416) as part of the CLIIP Notice of Availability. This verification included a review of the NRC staff's SE, as well as the supporting information provided to support TSTF-447. I&M has concluded that the justifications presented in the TSTF proposal and the SE prepared by the NRC staff are applicable to the Donald C. Cook Nuclear Plant (CNP) Unit 1 and Unit 2 and justify this proposed amendment for the incorporation of the changes to the CNP Unit 1 and Unit 2 TSs.

6.0 REGULATORY ANALYSIS

A description of this proposed change and its relationship to applicable regulatory requirements and guidance was provided in the NRC Notice of Availability published on September 25, 2003 (68 FR 55416), TSTF-447, the documentation associated with the 10 CFR 50.44 rulemaking, and other related documents.

6.1 Verification and Commitments As discussed in the model SE published in the Federal Register on September 25, 2003 (68 FR 55416) for this TS improvement, I&M is making the following verifications and regulatory commitments:

1., I&M has verified that a hydrogen monitoring system capable of diagnosing beyond design-basis accidents is installed at CNP Unit 1 and Unit 2 and is making a regulatory commitment to maintain that capability. The hydrogen monitor system will be included in the CNP Unit 1 and Unit 2 Technical Requirements Manuals. This regulatory commitment will be implemented by the date that this proposed amendment is implemented. The requirements for hydrogen recombiners will not be relocated.

2. CNP Unit 1 and Unit 2 do not have inerted containments.

to AEP-NRC-2010-58 Page 3 7.0 NO SIGNIFICANT HAZARDS CONSIDERATION I&M has reviewed the proposed no significant hazards consideration determination published on September 25, 2003 (68 FR 55416) as part of the CLIIP. I&M has concluded that the proposed determination presented in the notice is applicable to CNP Unit 1 and Unit 2 and the determination is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91 (a).

8.0 ENVIRONMENTAL EVALUATION I&M has reviewed the environmental evaluation included in the model SE published on September 25, 2003 (68 FR 55416) as part of the CLIIP. I&M has concluded that the staff's findings presented in that evaluation are applicable to CNP Unit 1 and Unit 2 and the evaluation is hereby incorporated by reference for this application.

9.0 PRECEDENT This application is being made in accordance with the CLIIP. Other than the administrative items identified below, I&M is not proposing variations or deviations from the TS changes described in TSTF-447 or the NRC staff's model SE published on September 25, 2003 (68 FR 55416).

Administrative variations from the TS changes described in TSTF-447:

  • TSTF-447 did not include changes to the Table of Contents. I&M has included pages from the TS Table of Contents that have been changed to reflect deletion of TS 3.6.8, "Hydrogen Recombiners." This variation is proposed for completeness.
  • TSTF-447 reflects the TS LCO and Condition numbers from the standard Westinghouse TS of NUREG-1431. I&M has used the corresponding CNP-specific TS LCO and Condition numbers. This variation is proposed for consistency with the CNP TS numbering.
  • TSTF-447 renumbered all instrument Functions that follow "Hydrogen Monitors" in Table 3.3.3-1. I&M has inserted the term "Deleted" in place of "Hydrogen Monitors" in Table 3.3.3-1 and left the remaining Function numbers unchanged. This variation is proposed to minimize the number of site procedures that must be changed to implement the proposed amendment.
  • TSTF-447 did not include any changes to SRs because there are no SRs that are unique to the hydrogen monitors in NUREG-1431. I&M has included changes to SR 3.3.3.2 and SR 3.3.3.3. This variation is proposed to recognize that the CNP TSs have SRs that apply only to the hydrogen monitors.

At least 25 other pressurized water reactor nuclear power plants have received NRC approval of license amendments to implement provisions of TSTF-447, including the four other plants which, like CNP, incorporate an ice condenser into their containment design.

to AEP-NRC-2010-58 Page 4

10.0 REFERENCES

Federal Register Notice: "Notice of Availability of Model, Application Concerning Technical Specification Improvement To Eliminate Hydrogen Recombiner Requirement, and Relax the Hydrogen and Oxygen Monitor Requirements for Light Water Reactors Using the Consolidated Line Item Improvement Process,". published September 25, 2003 (68 FR 55416).

Enclosure 3 to AEP-NRC-2010-58 REGULATORY COMMITMENT The following table identifies those actions committed to by Indiana Michigan Power Company (I&M) in this document. Any other actions discussed in this submittal represent intended or planned actions by I&M. They are described to the Nuclear Regulatory Commission (NRC) for the NRC's information and are not regulatory commitments.

Commitment Date I&M will maintain a hydrogen monitoring system capable of This regulatory commitment will diagnosing beyond design-basis accidents at CNP Unit 1 and be implemented by the date Unit 2. The hydrogen monitor system will be included in the that this proposed amendment CNP Unit 1 and Unit 2 Technical Requirements Manuals. is implemented.

Attachment 1 to AEP-NRC-2010-58 DONALD C. COOK NUCLEAR PLANT UNIT 1 TECHNICAL SPECIFICATION PAGES MARKED TO SHOW CHANGES Table of Contents page 3 of 5 3.3.3-2 3.3.3-3 3.3.3-4 3.3.3-5 3.6.8-1 3.6.8-2 5.6-4

UNIT 1 APPENDIX A TECHNICAL SPECIFICATIONS TABLE OF CONTENTS Chapter/Specification Paqe 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators ...................................... ......... . ......... .3.5.1-1 3 .5 .2 E C C S - O pe rating ........................................................................................................... 3 .5 .2-1 3.5.3 ECCS - Shutdown ........................................................... 3.5.3-1 3.5.4 Refueling Water Storage Tank (RWST) .......................... ........ 3.5.4-1 3.5.5 Seal Injection Flow ............................................... 3.5.5-1 3.6 CONTAINMENT SYSTEMS 3 .6 .1 C o nta in me nt ............................................................................... ............................. 3 .6 .1-1 3 .6 .2 C ontainm ent A ir Locks ................................................................................................... 3 .6 .2-1 3.6.3 Containment Isolation Valves ......................................... 3.6.3-1 3.6.4 Containment Pressure .............................................. 3.6.4-1 3.6.5 Containment Air Temperature ......................................... 3.6.5-1 3.6.6 Containment Spray System .......................................................................... 3.6.6-1 3.6.7 Spray Additive System .............................................. 3.6.7-1 3.6.8 Hydrg R bnes ....................................... 3.6.8-1 3.6.9 Distributed Ignition System (DIS) ................................................................ 3.6.9-1 3.6.10 Containment Air Recirculation/Hydrogen Skimmer (CEQ) System................ 3.6.10-1 3 .6 .1 1 Ic e Be d .................................................................... ....................................................... 3 .6 .1 1-1 3.6.12 Ice Condenser Doors ............................................... 3.6.12-1 3.6.13 Divider Barrier Integrity............................... .............. 3.6.13-1 3.6.14 Containm ent R ecirculation D rains .................................................................................. 3.6.14-1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) .........................-............. ...... 1 Table 3.7.1-1, OPERABLE Main Steam Safety Valves versus Maximum Allowable P o we r ....................................................................................................................... 3 .7 .1 -3 Table 3.7.1-2, Main Steam Safety Valve Lift Settings....................... 3.7.1-4 3.7.2 Steam Generator Stop Valves (SGSVs) . .................................. 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MF RV s ) .. ................................................................................................................. 3 .7 .3- 1 3.7.4 Steam Generator (SG) Power Operated Relief Valves (PORVs)................. 3.7.4-1 3.7.5 Auxiliary Feedwater (AFW) System ...................... .... ................................... .. 3.7.5-1 3.7.6 C ondensate Storage Tank (C ST) .................................................................................... 3.7.6-1 3.7.7 Component Cooling Water (CCW) System ................................ 3.7.7-1 3.7.8 Essential Service Water (ESW) System ..................... ............. 3.7.8-1 3.7.9 Ultim ate Heat S ink (UHS ) ......... ...............................

.. ................................. ............ 3.7.9-1 3.7.10 Control Room Emergency Ventilation (CREV) System ........................... 3.7.10-1 3.7.11 Control Room Air Conditioning (CRAC) System ............................................................ 3.7.11-1 3.7.12 Engineered Safety Features (ESF) Ventilation System .................................................. 3.7.12-1 3.7.13 Fuel Handling Area Exhaust Ventilation (FHAEV) System ........................ 3.7.13-1 Cook Nuclear Plant'Unit 1 Page 3 of 5 'Amendment No. 287

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. NOTE D.1 Restore all but one channel 7 days Not*app,,able, t to OPERABLE status.

hdrgen monitor One or more Functions with two or more required channels inoperable.

E. Two hydrogeR mo*nitor E.1 Rettore o*Re hydrogen 72- houers chanelsinoeralemoni~tor channel to O PE=R ABLEF statu F-E. Required Action and F--. 1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C No for the channel.

D,-r-E- not met.

GH.As required by Required G1.I Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action F- .1 and referenced in AND Table 3.3.3-1.

Gfl.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> IJ=.As required by Required ]=@.1 Initiate action in accordance Immediately Action F-J. 1 and with Specification 5.6.6.

referenced in Table 3.3.3-1.

Cook Nuclear Plant Unit 1 1.3.3-2 Amendment No. 287

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

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

These SRs apply to each PAM instrumentation Function in Table 3.3.3-1, except where identified in the SR.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 Perform CHANNEL CALIBRPATION for Function 92 days SR 3.3.3.3 --------------------- NOTE ----------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for FU-ntiOns 24 months other than Fu-nction 11.

Cook Nuclear Plant Unit 1 3.3.3-3 Amendment No. 1287

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION F-E.1

1. Neutron Flux 2
2. Steam Generator Pressure (per steam generator) 2
3. Reactor Coolant System (RCS) Hot Leg 2 Temperature (Wide Range)
4. RCS Cold Leg Temperature (Wide Range) 2
5. RCS Pressure (Wide Range)
6. Reactor Coolant Inventory Tracking System 2 (Reactor Vessel Level Indication)
7. Containment Water Level 2 2
8. Containment Pressure (Narrow Range)
9. Penetration Flow Path Containment Isolation Valve Position
10. Containment Area Radiation (High Range) 2
11. Hydogen e ete 2
12. Pressurizer Level
13. Steam Generator Water Level (Wide Range) 4 GE
14. Condensate Storage Tank Level GE
15. Core Exit Temperature - Quadrant 1 2(c)
16. Core Exit Temperature - Quadrant 2 2(c) GE
17. Core Exit Temperature - Quadrant 3 2 (c)

GE

18. Core Exit Temperature - Quadrant 4 2(d)
19. Secondary Heat Sink Indication

.(per steam generator)

(a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) A channel consists of one core exit thermocouple (CET).

(d) Any combination of two instruments per steam generator, including Steam Generator Water Level (Narrow Range) and Auxiliary Feedwater Flow, can be used to satisfy Function 19 OPERABILITY requirements.

Cook Nuclear Plant Unit 1 3.3.3-4 Amendment No. 287

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 2 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION F-E.1

20. Emergency Core Cooling System Flow (per train) 2(e)
21. Containment Pressure (Wide Range)' 2 GI
22. Refueling Water Storage Tank Level 2
23. RCS Subcooling Margin Monitor 1IM
24. Component Cooling Water Pump Circuit Breaker 2 HP Status
25. Containment Recirculation Sump Water Level 2 GW1 (e) Any combination of two instruments per train, including Centrifugal Charging Pump Flow, Safety Injection Pump Flow, Centrifugal Charging Pump Circuit Breaker Status, and Safety Injection Pump Circuit Breaker Status, can be used to satisfy Function 20 OPERABILITY requirements.

(f) An OPERABLE plant process computer (PPC) subcooling margin readout can be used as a substitute for an inoperable Function 23, RCS Subcooling Margin Monitor.

Cook Nuclear Plant Unit 1 3.3.3-75. Amendment No. 287,1299

Hydrogene 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 tHyd~ogen ReGgmb;ReFs-[elted t

I "- A m,(3 +WG nVciroGEnR reoonRal Bei cu~ri AlbiN Ir, ADII I-r-V.

AGT9N-9 CONDITION REQU)IIRE=DACTION COPEIN TIME A. One hydrogen .1 Rstr oe 30-days recombinerioperable. recomnbiner to OPERABL-E-BR.Twofe hydrogen B.1 Verify by administrative. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> recombiners inoperable,- means that the hydrogen ma tained.

AND B3.-2 Retreoe hydroge 7-days.

reco~mbiner to OPERABLE 6tatu&s C. Required Action ad C1 Be in MODE 3. 6hu-associated Completion TimRe not met.

Cook Nuclear Plant Unit 1 S3.6.8-1 Amendrnent No. 287

Hydrogen Recombfiners SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Pe~form a Sy~tern function-Al tfest forF each hydrogen 24 M.G~ths, SR 3.6.8.2 Visually examine each hydrogen recOmbiner2 mnh enclosure and verify there ie no evidence of abnormal conditions.

S 3.6.8..3. Perform a resistanc tgrud test for each heater 24-ME)RthS phae.e

-:L 4 A .. ~..4. LI... flfl7 600, UUIeaj i P1-itLUIlL. I a.U.e.D C PrieRiufieRt INGO. 46-

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 Post Accident Monitoring Report When a report is required by Condition B or J=@ of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.7, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,
b. Active degradation mechanisms found,
c. Nondestructive examination techniques utilized for each degradation mechanism,
d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,
e. Number of tubes plugged during the inspection outage for each active degradation mechanism,
f. Total number and percentage of tubes plugged to date, and
g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

Cook Nuclear Plant Unit 1 5.6-4, Amendment No. 2874,288, 298

Attachment 2 to AEP-NRC-2010-58 DONALD C. COOK NUCLEAR PLANT UNIT 2 TECHNICAL SPECIFICATION PAGES MARKED TO SHOW CHANGES Table of Contents page 3 of 5 3.3.3-2 3.3.3-3 3.3.3-4 3.3.3-5 3.6.8-1 3.6.8-2 5.6-4

UNIT 2 APPENDIX A TECHNICAL SPECIFICATIONS TABLE OF CONTENTS Chapter/Specification Paqe 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accum ulators .......... ......................................................... ................ ........ 3.5.1-1 3 .5 .2 E C C S - O perating ..................................................... ................................................. 3 .5 .2-1 3 .5 .3 E C C S - S hutdow n ............................................ I.......................................................... ,3 .5 .3-1 3.5.4 Refueling Water Storage Tank (RWST) .................................. 3.5.4-1 3.5.5 Seal Injection Flow ................................................ 3.5.5-1.

3.6 CONTAINMENT SYSTEMS 3.6.1 Containment.......6................................ . ........... 3.6.1-1 3.6.2 Containment Air Locks................... .......................... 3.6.2-1 3.6.3 Containment Isolation Valves ......................................... 3.6.3-1 3.6.4 Containment Pressure .............................................. 3.6.4-1 3.6.5 Containment Air Temperature .............................................. 3.6.5-1 3.6.6 Containment Spray System...................................I ..... 3.6.6-1 3.6.7 Spray Additive System .............................................. 3.6.7-1 3.6.8 Hydrogen Recombinerse leted....................................... 3.6.8-1 3.6.9 D istributed Ignition S ystem (D IS ) ................................................................................... 3.6.9-1 3.6.10 Containment Air Recirculation/Hydrogen Skimmer (CEQ) System ................................ 3.6.10-1 3.6.11 Ice Bed ........................................................ 3.6.11-1 3.6.12 Ice Condenser Doors ............................................... 3.6.12-1 3.6 .13 D ivider B arrier Integ rity ................................................ .... ......................................... 3 .6.13-1 3.6.14 Containment Recirculation Drains ..... . ......................................

.... 3.6.14-1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) .................................... 3.7.1-1 Table 3.7.1-1, OPERABLE Main Steam Safety Valves versus Maximum Allowable Power ............................................................. .................. 3.7.1-3 Table 3.7.1-2, Main Steam Safety Valve Lift Settings ....................... 3.7.1-4 3.7.2 Steam Generator Stop Valves (SGSVs) .................................. 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs)..... ........... ................ 3.7.3-1 3.7.4 Steam Generator (SG) Power Operated Relief Valves. (PORVs)..................3.7.4-1 3.7.5 Auxiliary Feedwater (AFW) System ........ . .'.................. 3.7.5-1 3.7.6 Condensate Storage Tank (CST)...................................... 3.7.6-1 3.7.7 Component Cooling Water (CCW) System .................... I..........3.7.7-1 3.7.8 Essential'Service Water (ESW) System ....... ......................

........ 3.7.8-1 3.7.9 Ultimate Heat Sink (UHS)................... ......................... 3.7.9-1 3.7.10 Control Room Emergency. Ventilation (CREV) System....................... 3.7.10-1 3.7.11 Control Room Air Conditioning (CRAC) System ............................... ................... ........ 3.7.11-1 3.7.12 Engineered Safety Features (ESF) Ventilation System ........................ 3.7.12-1

.3.7.13 Fuel Handling Area Exhaust Ventilation (FHAEV) System ..................... 3.7.13-1 Cook Nuclear Plant Unit 2 Page 3 of 5' Amendment No. 269

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. NOTE D.1 Restore all but one channel 7 days N*tapp.,abe*t*, to OPERABLE status:

hydrogen monlitorF One or more Functions with two or more required channels inoperable.

E. Two hydro geR FnRItGr E.11 Restore oRe hydrogen 7"2 h*Fs channels inoperable, monitor channel to.

OPER'ABLE status.

A. Required Action and . 1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition CT Ro for the channel, D-er--E not met.

Gf.As required by Required GE.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action FR.1 and referenced in AND Table 3.3.3-1.

GtE.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> I=l@.As required by Required Mg. 1 Initiate action in accordance Immediately Action F-*[1 and with Specification 5.6.6.

referenced in Table 3.3.3-1.

Cook Nuclear Plant Unit 2 ý3.3.3-2 Amendment No..269

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS NO I-------------------------------------------------------------

These SRs apply to each PAM instrumentation Function in Table 3.3.3-1, except where identified in the SR.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 Perform CHANNEL CALIBRAPT!ON for F'unction 2, .ays SR 3.3.3.3 NOTE----------------

Neutron detectors are excluded from CHANNEL CALl BRATION.

Perform CHANNEL CALIBRATION for F'R-tiGRs 24 months other than Fu6nction 11.

Cook Nuclear Plant Unit 2 3.3.3-3 Amendment"No.. 269

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION F--J.1

1. Neutron Flux 2
2. Steam Generator Pressure (per steam generator) 2
3. Reactor Coolant System (RCS) Hot Leg 2 Temperature (Wide Range)
4. RCS Cold Leg Temperature (Wide Range) 2
5. RCS Pressure (Wide Range) 2
6. Reactor Coolant Inventory Tracking System 2 (Reactor Vessel Level Indication)
7. Containment Water Level 2
8. Containment Pressure (Narrow Range) 2
9. Penetration Flow Path Containment Isolation Valve 2 per penetration flow Position path(a)(b)
10. Containment Area Radiation (High Range) 2
11. ydrogen Moito e ete G
12. Pressurizer Level 2
13. Steam Generator Water Level (Wide Range) 4
14. Condensate Storage Tank Level 1
15. Core Exit Temperature - Quadrant 1 2(c).
16. Core Exit Temperature - Quadrant 2 2(c).
17. Core Exit Temperature - Quadrant 3 2(c)
18. Core Exit Temperature - Quadrant 4 2 (d)
19. Secondary Heat Sink Indication (per steam aenerator)

(a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) A channel consists of one core exit thermocouple (CET).

(d) Any combination of two instruments per steam generator, including Steam Generator Water Level (Narrow Range) and Auxiliary Feedwater Flow, can be used to satisfy Function 19 OPERABILITY requirements.

Cook Nuclear Plant Unit 2 3.3.3-4 Amendment No. 269

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 2 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION. REQUIRED CHANNELS ACTION F-- 1

20. Emergency.Core Cooling.System Flow (per train) 2(e)
21. Containment Pressure (Wide Range) 2
22. Refueling Water Storage Tank Level 2
23. RCS.Subcooling Margin Monitor 1(0
24. Component Cooling Water Pump Circuit Breaker 2 Status
25. Containment Recirculation Sump Water Level 2G*

(e) Any combination of two instruments per train, including Centrifugal Charging Pump Flow, Safety Injection Pump Flow, Centrifugal Charging Pump Circuit Breaker Status, and Safety Injection Pump Circuit Breaker Status, can be used to satisfy Function 20 OPERABILITY requirements.

(f) An OPERABLE plant process computer (PPC) subcooling margin readout can be used as a substitute for an inoperable Function 23, RCS Subcooling Margin Monitor.

Cook Nuclear Plant Unit 2 3.3.3-5 Amendment No. 26-9, 282

Hydrogen Recombiners 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Hvdrooen RecombinerdDeletedl H j-.vd .... -- r-I. . . .

i ii i X .......

w" A.h.14 Two hydirogen reGOmRDln~ers shail be UPLKRLL.-R-E ADDI I'ADIII ITV. RAnIr-IC I -- A.,, 1)

C-ON .DITIO-N REQUIRED ACINCOMPLETION TIME A. One h.ydrogen. A.! Restore hydroge 30-days recobie ioeable., . recom~biner to- OPERARL-E-status.

B. Two hydrogen B.li Verify by administrativeI a recomnbiner-s inpeale eans that the hydrogen control function is ma ntaimied.

AND B.2 Restore one hydrogen 7 days reGcombiner to OPE=RABLE-status.

C'. Required Action and Ci Be in MODE 3. 6-heuFs associated Completion Time not met, Cook Nuclear Plant Unit 2 3.6.8-1 Amendment No. 269

Hydrogen Recom~biners SURVEILLAbNCE REQUIREMENTS SURVEIL. ANCE FREQUENCY S-R 2_.6_.8.1 Pe~form a Gystem fuinctional test for each hydrogen 24 MOnthrE FeGEGmboneF SR 3.6.8.2 Visually examine each hydrogen recombibner 24-.e the enclosure and verify there is no evidence et abnormal cnditn ioR.

SR 3-56.8.3 Perform a resistance to grou nd test for each heater 241-menth 1, Ki 01- 1 1-4, A---,J- Kl- ')t-'rl tzp IV tv U ý"v V 8ý1 it W. HU"HIM. .. . - ___

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 Post Accident Monitoring Report When a report is required by Condition B or of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring,.the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.7, Steam Generator (SG) Program. The report shall include:-

a. The scope of inspections performed on each SG,
b. Active degradation mechanisms found,
c. Nondestructive examination techniques utilized for each degradation mechanism,
d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,
e. Number of tubes plugged during the inspection outage for each active degradation mechanism,
f. Total number and percentage of tubes plugged to date, and
g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

Cook Nuclear Plant Unit 2 5.6 -4 Amendment No. 269, 27-0, 279

Attachment 3 to AEP-NRC-2010-58 DONALD C. COOK NUCLEAR PLANT UNIT 1 TECHNICAL SPECIFICATION PAGES WITH PROPOSED CHANGES INCORPORATED Table of Contents page 3 of 5 3.3.3-2 3.3.3-3 3.3.3-4 3.3.3-5 3.6.8-1 5.6-4

UNIT 1 APPENDIX A TECHNICAL SPECIFICATIONS TABLE OF CONTENTS Chapter/Specification Paqe 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators .................................................... 3.5.1-1 3.5.2 ECCS - Operating ................................................. 3.5.2-1 3.5.3 ECCS - Shutdown ................................................. 3.5.3-1 3.5.4 Refueling W ater Storage Tank (RW ST) ......................................................................... 3.5.4-1 3.5.5 Seal Injection Flow ................................................ 3.5.5-1 3.6 CONTAINMENT SYSTEMS 3.6.1 C ontainm ent ............................. ........... ...................................................... 3.6.1-1 3.6.2 Containment Air Locks .............................................. 3.6.2-1 3.6.3 C ontainm ent Isolation V alves ......................................................................................... 3.6.3-1 3.6.4 C ontainm ent P ressure .................................................................................................  : 3.6.4-1 3.6.5 Containment Air Temperature ......................................... 3.6.5-1 3.6.6 Containment Spray System .......................................... 3.6.6-1 3.6.7 Spray Additive System .............................................. 3.6.7-1 3.6.8 Deleted ........................................................ 3.6.8-1 3.6.9 D istributed Ignition S ystem (D IS ) ................................................................................... 3.6.9-1 3.6.10 Containment Air Recirculation/Hydrogen Skimmer (CEQ) System ................................. 3.6.10-1 3.6.11 Ice Bed.. ....................................................... 3.6.11-1 3.6 .12 Ice C ondenser D oors ..................................................................................................... 3.6 .12-1 3.6 .13 D ivider B arrier Integrity .................................................................................................. 3 .6 .13-1 3.6.14 Containment Recirculation Drains ................................. ..... 3.6.14-1.

3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) .................................... 3.7.1-1 Table 3.7.1-1, OPERABLE Main Steam Safety Valves versus Maximum Allowable Power.......................................................3.7.1-3 Table 3.7.1-2, Main Steam Safety Valve Lift Settings .................................................. 3.7.1-4 3.7.2 Steam Generator Stop Valves (SGSVs) ................................... 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs) .................................................................... 3.7.3-1 3.7.4 Steam Generator (SG) Power Operated Relief Valves (PORVs) .. ........... .... 3.7.4-1 3.7.5 Auxiliary Feedwater (AFW) System.................... ...................... 3.7.5-1 3.7.6 C ondensate Storage Tank (C ST) ................................................................................ 3.7.6-1 3.7.7 Component Cooling Water (CCW) System ................................ 3.7.7-1 3.7.8 Essential Service Water (ESW) System .................................. 3.7.8-1 3.7.9 Ultim ate Heat S ink (U HS ) .................................................................................... .......... 3.7.9-1 3.7.10 Control Room Emergency Ventilation (CREV) System........................ 3.7.10-1 3.7.11 Control Room Air Conditioning (CRAC) System ............................................................. 3.7.11-1 3.7.12 Engineered Safety Features (ESF) Ventilation System. ....................... 3.7.12-1 3.7.13ý Fuel Handling Area Exhaust Ventilation (FHAEV) System. ..................... 3.7.13-1 Cook Nuclear Plant Unit 1 . Page 3 of 5 Amendment No. 297

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more Functions D.1 Restore all but one channel 7 days with two or more to OPERABLE status.

required channels inoperable.

E. Required Action and E.1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C or for the channel.

D not met.

F. As required by Required F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action E.1 and referenced in AND Table 3.3.3-1.

F.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> G. As required by Required G.1 Initiate action in accordance Immediately Action E.1 and with Specification 5.6.6.

referenced in Table 3.3.3-1.

Cook Nuclear Plant Unit 1 3.3.3-2 Amendment No. 2 PAM Instrumentation 33.3 SURVEILLANCE REQUIREMENTS

NOTE. --------------------------------------------------

These SRs apply to each PAM instrumentation Function in Table 3.3.3-1, except where identified in the SR.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 Deleted.

SR 3.3.3.3 ---------------------- NOTE ----- -----------

Neutron detectors are excluded from CHANNEL CALl BRATION.

Perform CHANNEL CALIBRATION. 24 months Cook Nuclear Plant Unit 1 3.3.3-3 Amendment No..287

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION E.1

1. Neutron Flux 2 F
2. Steam Generator Pressure (per steam generator) 2 F
3. Reactor Coolant System (RCS) Hot Leg 2 F Temperature (Wide Range)
4. RCS Cold Leg Temperature (Wide Range) 2 F
5. RCS Pressure (Wide Range) 2 F
6. Reactor Coolant Inventory Tracking System 2 G (Reactor Vessel Level Indication)
7. Containment Water Level 2 F
8. Containment Pressure (Narrow Range) 2 F
9. Penetration Flow Path Containment Isolation Valve 2 per penetration flow F Position path(a)(b)
10. Containment Area Radiation (High Range) 2 G
11. Deleted
12. Pressurizer Level 2 F
13. Steam Generator Water Level (Wide Range) 4 F
14. Condensate Storage Tank Level 1 G
15. Core Exit Temperature - Quadrant 1 2(c) F
16. Core Exit Temperature - Quadrant 2 2(c) F
17. Core Exit Temperature - Quadrant 3 2(c) F
18. Core Exit Temperature - Quadrant 4 2(c) F
19. Secondary Heat Sink Indication 2 (d) F (per steam generator)

(a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) A channel consists of one core exit thermocouple (CET).

(d) Any combination of two instruments per steam generator, including Steam Generator Water Level (Narrow Range) and Auxiliary Feedwater Flow, can be used to satisfy Function 19 OPERABILITY requirements.

Cook Nuclear Plant Unit 1 3.3.3-4 Amendment No. 297

PAM Instrumentation

. 3.3.3 Table 3.3.3-1 (page 2 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION E.1

20. Emergency Core Cooling System Flow (per train) 2(e) F
21. Containment Pressure (Wide Range) 2 F
22. Refueling Water Storage Tank Level 2 F
23. RCS Subcooling Margin Monitor 1 (f) F
24. Component Cooling Water Pump Circuit Breaker 2 G Status
25. Containment Recirculation Sump Water Level 2 F (e) Any combination of two instruments per train, including Centrifugal Charging Pump Flow, Safety Injection Pump Flow, Centrifugal Charging Pump Circuit Breaker Status, and Safety Injection Pump Circuit Breaker Status, can be used to satisfy Function 20 OPERABILITY requirements.

(f) An OPERABLE plant process computer (PPC) subcooling margin readout can be used as a substitute for an inoperable Function 23, RCS Subcooling Margin Monitor.

Cook Nuclear Plant Unit 1 3.3.3-5 Amendment No. 287, 2-99

3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Deleted Cook Nuclear Plant Unit 1 3.6.8-1 .:Amendment No. 2-97

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 Post Accident Monitorinq Report When a report is required by Condition B or G of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.7, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,
b. Active degradation mechanisms found,
c. Nondestructive examination techniques utilized for each degradation mechanism,
d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,
e. Number of tubes plugged during the inspection outage for each active degradation mechanism,
f. Total number and percentage of tubes plugged to date, and
g. The results of condition monitoring,jincluding the results of tube pulls and in-situ testing. \I Cook Nuclear Plant Unit 1 "5.6-4 Amendment No. 287-, 288, 28N

Attachment 4 to AEP-NRC-2010-58 DONALD C. COOK NUCLEAR PLANT UNIT 2 TECHNICAL SPECIFICATION PAGES WITH PROPOSED CHANGES INCORPORATED Table of Contents page 3 of 5 3.3.3-2 3.3.3-3 3.3.3-4 3.3.3-5 3.6.8-1 5.6-4

UNIT 2 APPENDIX A TECHNICAL SPECIFICATIONS TABLE OF CONTENTS Chapter/Specification Paqe 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3 .5 .1 Accu m u lato rs ..................................................... ................... ........................ 3 .5 .1-1 3.5.2 ECCS - Operating .......................................................................... 3.5.2-1 3.5.3 ECCS - Shutdown .................. ........................ 3.5.3-1 3.5.4 Refueling W ater Storage Tank (RW ST) ................. :...................... ................ ........... 3.5.4-1 3.5.5 Seal Injection Flow ...... .................................................. 3.5.5-1 3.6 CONTAINMENT SYSTEMS 3 .6 .1 C o nta in m e nt ............................. .......................................................... ........... ..... ........3 .6 .1-1 3.6 .2 C ontainm ent A ir Locks ................. .................................. ........................... .............. 3 .6 .2-1 3.6.3 Containment Isolation Valves ......................................... 3.6.3-1 3.6 .4 C ontainm ent P ressure .......... ....................................................................................... 3.6 .4-1 3.6.5 Containment Air Temperature......................................... 3.6.5-1 3.6.6 Containment Spray System........................................... 3.6.6-1 3.6 .7 S pray A dditive S ystem ................................................................................................... 3 .6 .7-1 3 .6 .8 D e le te d .......................................................................................................................... 3 .6 .8 -1 3.6.9 D istributed Ignition System (D IS ) ................................................................................... 3.6.9-1 3.6.10 Containment Air Recirculation/Hydrogen Skimmer (CEQ) System ................................. 3.6.10-1 3.6.11 Ice Bed ............................................. ....... 3.6.11-1 3.6.12 Ice Condenser Doors ............................................... 3.6.12-1 3.6.13 Divider Barrier Integrity............................................ 3.6.13-1 3.6.14 Containment Recirculation Drains............... ....................... 3.6.14-1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) .................................... 3.7.1-1 Table 3.7.1-1, OPERABLE Main Steam Safety Valves versus Maximum Allowable P o w e r..... ........ ......................................................................................................... 3 .7 .1-3 Table 3.7.1-2, Main Steam Safety Valve Lift Settings. ....................... 3.7.1-4 3.7.2 Steam Generator Stop Valves (SGSVs) ........................ ................ ............ 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs)... .................................. ...... ................................................. 3.7.3-1 3.7.4 Steam Generator (SG) Power Operated Relief Valves (PORVs) ................. 3.7.4-1 3.7.5 Auxiliary Feedw ater (AFW) System ....................................................................  ;......... .3.7.5-1 3.7.6 Condensate Storage Tank (CST) ................... .. .....................

... 3.7.6-1 3.7.7 Component Cooling Water (CCW) System . ............................... 3.7.7-1 3.7.8 Essential Service Water (ESW) System ............. ..... ................ 3.7.8-1 3.7.9 Ultimate Heat Sink (UHS)....... ....................................... 3.7.9-1 3.7.10 Control Room Emergency Ventilation (CREV) System....................... .. ................ 3.7.10-1

,3.7.11 Control Room Air Conditioning (CRAC) System ........................... 3.7,11-1 3.7.12 Engineered Safety Features (ESF) Ventilation System .............. ... ........... 3.7.12-1 3.7.13 Fuel Handling Area Exhaust Ventilation (FHAEV) System ........................ 3.7.13-1 Cook Nuclear Plant Unit 2 Page3 of 5 Amendment No. 269

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED, ACTION COMPLETION TIME D. One or more Functions D.1 Restore all but one channel 7 days with two or more to OPERABLE status.

required channels inoperable.

E. Required Action and E. 1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C or for the channel.,

D not met.

F. As required by Required F.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action E.1 and referenced in AND Table 3.3.3-1.

F.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> G. As required by Required G.1 Initiate action in accordance. Immediately Action E.1 and with Specification 5.6.6.

referenced in Table 3.3.3-1.

Cook Nuclear Plant Unit 2 3.3.3-2 Amendment No. 2-69'

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

No I------------------------------------------------------------

These SRs apply to each PAM instrumentation Function in Table 3.3.3-1, except where identified in the SR.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.,

SR 3.3.3.2 Deleted.

SR 3.3.3.3 - -------------------- NOTE ----------------

Neutron detectors are excluded from CHANNEL CALl BRATION.

Perform CHANNEL CALIBRATION. 24 months Cook Nuclear Plant Unit 2 .3.3.3-3 Amendment No, 2-69

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION E.1

1. Neutron Flux 2 F
2. Steam Generator Pressure (per steam generator) 2 F
3. Reactor Coolant System (RCS) Hot Leg 2 F Temperature (Wide Range)
4. RCS Cold Leg Temperature (Wide Range) 2 F
5. RCS Pressure (Wide Range) 2 F
6. Reactor Coolant Inventory Tracking System 2 G (Reactor Vessel Level Indication)
7. Containment Water Level 2 F
8. Containment Pressure (Narrow Range) 2 F
9. Penetration Flow Path Containment Isolation Valve 2 per penetration flow F Position path(a)(b)
10. Containment Area Radiation (High Range) 2 G
11. Deleted
12. Pressurizer Level 2 F
13. Steam Generator Water Level (Wide Range) 4 F
14. Condensate Storage Tank Level 1 G
15. Core Exit Temperature - Quadrant 1 2(c) F
16. Core Exit Temperature - Quadrant 2 2(c) F
17. Core Exit Temperature - Quadrant 3 2(c) F
18. Core Exit Temperature - Quadrant 4 2(c) F
19. Secondary Heat Sink Indication 2(d) F (per steam generator)

(a) Not required for isolation valves Whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(c) A channel consists of one core exit thermocouple (CET).

(d) Any combination of two instruments per steam generator, including Steam Generator Water Level (Narrow Range) and Auxiliary Feedwater Flow, can be used to satisfy Function 19 OPERABILITY requirements.

Cook Nuclear Plant Unit 2A 3.3.3-4 Amendment No. 269

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 2 of 2)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM REQUIRED FUNCTION REQUIRED CHANNELS ACTION E.1

20. Emergency Core Cooling System Flow (per train) 2(e) F
21. Containment Pressure (Wide Range) 2 F
22. Refueling Water Storage Tank Level 2 F
23. RCS Subcooling Margin Monitor 1(0 F
24. Component Cooling Water Pump Circuit Breaker 2 G Status
25. Containment Recirculation Sump Water Level 2 F (e) Any combination of two instruments per train, including Centrifugal Charging Pump Flow, Safety Injection Pump Flow, Centrifugal Charging Pump Circuit Breaker Status, and Safety Injection Pump Circuit Breaker Status, can be used to satisfy Function 20 OPERABILITY requirements.

(f) An OPERABLE plant process computer (PPC) subcooling margin readout can be used as a substitute for an inoperable Function 23, RCS Subcooling Margin Monitor.

Cook Nuclear Plant Unit 2 3.3.3-5 Amendment No. 269, 282

3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Deleted Cook Nuclear Plant Unit 2 3.6.8-1 Amendment No. 2&9

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 Post Accident Monitoring Report When a report is required by Condition B or G of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.7 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.7, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,
b. Active degradation mechanisms found,
c. Nondestructive examination techniques utilized for each degradation mechanism,
d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,
e. Number of tubes plugged during the inspection outage for each active degradation mechanism,
f. Total number and percentage of tubes plugged to date, and
g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

Cook Nuclear Plant Unit 2 5.6-4 Amendment No. 2468, 2-7-0, 27-9

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