Text

Rev 8 to Program Plan GGNS-M-189.1, Grand Gulf Nuclear Station Pump & Valve IST Program - Safety Related
	ML20199L571
Person / Time
Site:	Grand Gulf
Issue date:	11/26/1997
From:	; ENTERGY OPERATIONS, INC.
To:	;
Shared Package
ML20199L567	List: ML20199L561; ML20199L571;
References
	GGNS-M-189.1, NUDOCS 9712020058
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Entergy Operations, Inc. PROGRAM PLAN NO.: GGNS-M 189.1 :

Grand Gulf Nuclear 51otion REVISION NO. 8 Pump And Volve Inservice Testing Program PAGE: Cover Sheet l

.. j ENTERGY OPERATIONS, INC. .

GRAND GULF NUCLEAR STATION i

5 PUMP AND VALVE .

INSERVICE TESTING PROGRAM SAFETY RELATED r

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE:1 of 5 ,

REVISION STATUS SHEET ,

j REVISION

SUMMARY

REM ISSUE DATE QF&CRIPTION 0 - -

1 6/28/85 Added MP&L specification number, revised page numbenng format, revised data as noted, and issued for use.

2 11/24/86 Revised per DCP 81/5007, 84/0091 4, 86/4000, 83/3515, 84/4072, 86/0083, 82/5020 and 82/50201, and as noted. Issued for use.

3 4/27/80 Revised per SCN 87/0031 SCN 87/0002, SCN 87/0003. Engineenng Markups issued 10/13/87 Engineenng Markups issued 1/1/88, QDR 510-87, and as noted.

Revised page formats and specification number and title t 4 5/17/90 Revised to. R6 place Bechtel (GPD) format with SERl/NPE format, incorporate SCN 88-01, SCN 88-03, SCN $8-04, !

SCN 88-05, SCN 89-01, SCN 89-02, SCN 89-03, SCN 89-05, SCN 89-06, SCN 89-07, SCN 89-12, SCN 8913, SCN 89-14, SCN 89-15, SCN 89-16, SCN 90-01, SCN 90-02, SCN 90-03, SCN 90-04, SCN 90-05, SCN 90-06 SCN 90-07, SCN 90-08, SCH 90-09, SCN 9010, SCN 9011, SCN 90-12, SCN 90.13, SCN 90-14, ,

SCN 9015, SCN 90-16, SCN 90-17, SCN 90-18 SCN 9019, SCN 90-20, SCN

90-21 SCN 90-22, SCN 90-23, SCN 90-24, SCN 90-25, SCN 90-26, SCN 90-27, ;

SCN 90 28, SCN 90-29, SCN 90-30, SCN 90-31, and SCN 90-32, Replace MP&L references with SERI references; Replace P&lD/SFD references with P.DWG references; Modify method of tracking revision status of appendices, and, Make ;

editorial changes SCNs 8913 through 8916 and 90-01 through 90-32 include ct,anges required to comply with Genenc Letter 8944. Revision bars / clouds used to identify technical or extensive format changes, but not reference or mmor editorial changes 5 4/3/92 Revised to: Incorporate SCN 90-33, SCN 90-34, SCN 90-35, SCN 90-36, SCN 90-37 SCN 90-38, SCN 90 39, SCN 90-40, SCN 90-41, SCN 90-42, SCN 90-43, SCN 90-44, SCN 90-45, SCN 90-46, SCN 90-47, SCN 9101, SCN 9102, SCN 9103, and EAR M 568-88 Revision Bars / Clouds used to identify tecnnical or format changes.

6 7/9/93 Revised to mcorporate SCN 91-0006, SCN 92 0001, SCN 92-0002,3CN 92-0003, SCN 92-0004, SCN 92-0005, SCN 92-0007, SCN 93-0007, DMR 0330-90, CN 92-0102, Engineenng Markup dated 6/2/92, and Technical Specification Amendment 102. Removed P Drawing revision column from Applicable Systems section Revision bars / clouds used to identify technical or format changes Revision 6 changes include removal of IST Maximum Stroke Times, SCN 92-0006, SCN 92 0009 and SCN 92 0010 provided stroke tr ies that are no longer necessary, and are considered closed by Revision 6.

7 12/16/94 Revised to incorporate SCN 93-0008, SCN 93 0009 and SCN 93-0010 Also, revised test requirements for vanous equipment based upon reevaluation of safety functions using an increased level of aonservatism and made vanous editonal changes.

Bfy ISSUE DATE QFSCRIPTION m11$1r6teie46 -

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO,8 PAGE: 2 of 5 REVISION STATUS SHEET 3 g// gf $7 Update document to reflect testing requirements based on ASME Section XI Code.

1999 and change document type from Specification to Program Plan (NPEAP

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 i PAGE: 3 of 5 l REVISION STATUS SHEET I I

PAGE REVISION STATUS i l

PAGE NO. E PAGE NO. E PAGE NOi M !

Cover Sheet 8 Valve 35 8 Relief Requests 36 8 Review and 37 8 Approval Sheet - 8 1 8 38 8 ;

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2 8 39 8 Revision Status 3 8 40 8 1 8 4 -8 41- 8 .

2 8 42 8 3 8 Cold Shutdown 43 8 4 8 Justifications- 44 8 5 8 45 8 1 8 46 8 Table of Contents 2 8 47 8 1 8 3 8 48 8 '

2 8 4 8 49 8 3 8 5 8 50 8 4 8 6 8 51 8 5 8 7 8 8 8 Refueling Outage 9 8 Justifications Applicable Systems 10 8 1 8 1 8 11 8 2 8 2 8 12 8 3 8 3 8 13 8 4 8 ;

14 8 5 8 Introduction 15 8 6 8 1 8 16 8 7 8 2- 8 17 8 8 8 18 8 9 8 19 8 10 8 Valve Program 20 8 11 8 1 8 21 S 12 8 2 8 22 8

3. 8 23 8 Augmented 4 8 24 8 Valve Tests 5 8 25 .8 6 8 26 8 1 8 7 8 27 8 2 8 8 8 28 8 3 8 29 8 4 8 30 8 5 8 i 31 8 6 8 32 8 7 8 33 8 8 8 34 8 9 8 10 8 11 8 m180-ir6 hmtr8

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE: 4 of 5 REVIF.lON STATUS SHEET PAGE REVISION STATUS PAGE NO. E PAGE NO. M PAGE NO. M 12 8 E21 1 8 P75-3 8 13 8 E22-1 8 P75L4 8 14 8 E22 2 8 P81 1 8 15 8 E30L1 8 P812 8

' 16 8 E321 8 P813 8 17 8 E381 8 T41 1 8 18 8 E51 1 8 T421 8 19 8 E512 8 T48-1 8 20 8 E513 r, 251 1 8 21 8 E61 1 3 Notes 8 22 8 E612 8 23 8 E613 8 G331 8 Pump Program G332 8 1 8 Valve Summaries G36-1 8 2 8 G41-1 8 3 8 B21 1 8 G412 8 B212 8 G461 8 Pump Relief Requests 821 3 8 M23-1 8 1 8 B21-4 8 M41 1 8 2 8 B215 8 M61 1 8 3 8 B21-6 8 M71-1 8 4 8 B217 8 P11 1 8 5 8 B218 8 P21 1 8 6 8 B21-9 8 P41 1 8 7 8 821-10 8 P412 8 8 8 B21 11 8 P41-3 8 9 8 B21 12 8 P41-4 8 10 8 B21 13 8 P415 8 11 8 B21-14 8 P416 8 12 8 833-1 8 P421 8 13 8 C11 1 8 P42 2 8 C41 1 8 P441 8 Pump Summary D231 8 P45-1 8 E12-1 8 P4 5 .' 8 1 8 !

E12 2 8 PS2-1 8 2 8 .

E12-3 8 P53-1 8 !

E12-4 8 P60-1 8 E12 5 8 P641 8 E12 8 P66-1 8 E12-7 8 P71 1 8 E12 8 8 P72-1 8 E12-9 8 P75-1 8 E12-10 8 P75-2 8 l -.

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I PROGRAM PLAN NO. GGNS-M 189.1 i REVISION NO. 8 PAGE: 5 of 5 l REVISION STATUS SHEET t i

PAGE REVISION STATUS APPENDIX A REVISION STATUS l PAGE NO. E PAGE NO. M PAGE NO. E t 4

Cover Sheet 8 8 8 16 8 1 8 9 8 17 8 -

2 8 10 8 18 8 i

3 8 11 8 4 8 12 8 5 8 13 8 6 8 14 8 7 8 15 8 APPENDIX. B REVISION STATUS PAGE NO. E PAGE NO. M PAGE NO. M Cover Sheet 8 2 8 4 8 1 8 3 8 PCR/PCN Form 8 ,

APPENDIX C REVISION STATUS PAGE NO M PAGE NO. M PAGE NO. M Cover Sheet 8 3 8 6 8 1 8 4 8 2 8 5 8 ATTACHMENT 1: SAFETY EVALUATION APPLICABILITY REVIEW FORM REVISION STATUS PAGE NO.' E PAGE NO. M PAGE NO. M 1 8 2 8 I mit$.tr8 tent 46

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE: 1 of 5

.. TABLE OF CONTENTS !

FRONT SECTION Cover Sheet Review and Approval Sheet Revision Status Sheet TABLE OF CONTENTS APPLICABLE SYSTEMS INTRODUCTION VALVE PROGRAM PAGE NO. .

General 1 ,

Instructions 1 YALVE RELIEF REQUESTS PAGE NO.

Gerioric Relief Request VRR GEN-01 1 VRR B21-01: Nuclear Boiler System 3 COLD SHUTDOWN JUSTIFICATIONS PAGE NO.

CJ B2101 1 CJ B2102 2 CJ 82103 3 :

CJ 82104 4 CJ B2105 5 ,

CJ B2106 6 CJ 82107 7 CJ-821-08 8 CJ B2109 9 CJ B2110 10 CJ B21-11 11 Cc-B21 12 12

CJ B33-01 14 CJ E12 01 15 m1 Elr8ted48 t m --gy94- y e --+r-,e- e 9'wrE- e>*T+y' wi.. -pws- ,yey.- ,.s-+---g w---w--p - se ,,- + eci-- w--w w y-e cw- e v9.e,v'ab.-wr we- vN m4 '-'* #-*-

PROGRAM PLAN NO. GGNS-M 189.1 ,

REVISION NO. 8 PAGE: 2 of 5 .

._ TABLE OF CONTENTS COLD SHUTDOWN JUSTIFICATIONS PAGE NO. t CJ E12 02 16 CJ.E12-03 17

, CJ.E12 04 18 CJ E12 05 19 CJ E12 06 20 '

CJ E12 07 21 CJ E12 08 22 CJ E21 Ci 23 CJ E2102 24 l CJ E22-01 25 CJ.E32-01 26 CJ E38-01 28 CJ E38 02 29 CJ E5101 30 CJ E5102 31 CJ G33-01 32 CJ G33-02 33 CJ P42-01 34 CJ P42-02 35 CJ P42 03 36 CJ-P42 04 37 CJ-P44 01 38 CJ-P45 39 CJ-P52 40 C 1 P53-01 41 ,

CJ P53-02 42 CJ P53 43 C! P53-04 44 ,

CJ-P53-05 45 CJ P7101 46 CJ P72 01 47 CJ-P72 02 48 +

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PROGRAM PLAN NO, GGNS M 189,1 ,

REVISION NO 8 ;

PAGE: 3 of 5 :

i

.- TABLE OF CONTENTS- .

CJ P72 03 49 +

CJ P72 04 50 CJ-Z5101 51 REFUELING OUTAGE JUSTIFICATIONS PAGE NO.

RJ 821-01 1 RJ-C1101 2 RJ C1102 3 RJ C1103 4 RJ.C4101 5 RJ E30-01 6 -

RJ E38-01 7 RJ E5101 8 RJ E51-02 9 RJ-G33-01 10 RJ P4101 11 RJ P44-01 12 AUGMENTED VALVE TESTS AVT 82101 1 AVT B2102 2 AVT 82103 3 AVT C1101 4 AVT-C1102 5 AVT C11-03 0 AVT P44 01 7 AVT P44-02 8 AVT P53-01 9 AVT P7101 10 AVT-P75 01 11 AVT P75-02 12 AVT P75-03 13-AVT-P75-04 14 m)89-ir9de449 i

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PROGRAM PLAN NO. GGNS M-189.1 REVISION NO. 8 PAGE: 4 of 5 TABLE OF CONTENTS AUGMENTED VALVt: :ESTS (Continusj) PAGE NO.

AVT-P75 05 15 AVT P75 06. 16 AVT P8101 17 1 AVT P8102 19 AVT P81-03 20 AVT P8104 21 AVT 08105 23 VALVE

SUMMARY

LISTINGS BY SYSTEM NUMBER 821 G36 PS3 B33 G41 P60 C11 G46 P64 C41 M23 P66 D23 M41 P71 E12 M61 P72 E21 M71 P75 E22 P11 P81 E30 P21 T41 E32 P41 T42 E38 P42 T48 E51 P44 251 E61' P45 G33 PS2 i

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l PROGRAM PLAN NO GGNS-M-189.1-REVISION NO. 8 PAGE: 5 of 5 1

-- TABLE OF CONTENTS q

i PUMP PROGRAM PAGE NO.

General 1 Instructions 1 Scope of Tests 3 PUMP RELIEF REQUESTS PAGE NO.

PRR-E12-1: RHR System 1 PRR-E21 1: LPCS System 3 ,

PRR E221: HPCS System 5 PRR P75-01: Standby D/G System 7 PRR P8101: HPCS D/G System 12 PUMP

SUMMARY

LISTINGS i

APPENDICES APPENDIX TITLE Appendix A Bases for Maximum Stroke Times of Power Actuated Valves Appendix B Program Plan Change Request / Notice Appendix C Calculation of IST Maximum Stroke Times m189-ir6 out r8

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PROGRAM PLAN NO. GGNS-M-189.1 l REVISION NO. 8 PAGE: 1 of 3

-- APPLICABLE SYSTEMS ,

System P & 10 Number Numbet Name of System B21 1077A Nuc tar Boiler System 10778 1077C 10770 1077E B33 1078A Reactor Recirculation System 1078B 1078E C11 1081A Control Rod Drive Hydrau!!c System 10818 C41 1082 Standby Liquid Control System D23 1110A Drywell Monitoring System E12 1061D Residual Heat Removal System 1085A 10858 1085C 1085D E21 1087 Low Pressure Core Spray System E22 1086 High Pressure Core Spray Systern E30 1096 Suppression Pool Makeup System E31 1090A Leak Detection System 10908 E32 1097 MSIV Leakage Control System E38 1112 Feeav/ater Leakage Control System E51 1083A Reactor Cere Isolation Cooling System 10838

E61 1091 Combustible Gas Control Systems 11008 G33 1070 Reactor Water Cleanup System G36 10808 RWCU Filter /Demineralizer System 7

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PROGRAM PLAN NO. GGNS M-189.1

REVISION NO. 8' PAGE: 2 of 3 ,

APPLICABLE SYSTEMS System P&10 i Number Number fjpps of System C41 1063A ' Fuel Pool Cooling and Cleanup System 1088C 1088D

, 1088E G46 1089 FPCCU Filter /Demineralizer System M23 1124B Containment Personnel Air Locks 1124C M41 1100A Containment Cooling System 11008 1101 M61 1111A Containment Leak Rate Test System M71 1110A Containment and Drywell Instrument and Control System P11 1065 Condensate cnd Refueling Water Storage and Transfer-System P21 00338 Makeup Water Treatment System P41 1061A Standby Service Water System 10618 1061C 1061D P42 1063A Component Cooling Water System 1063B P44 1072A Plant Service Waiar System 1072B 1072H P45 1094A Floor and Equipment Drains System 10948 1094C 1094E

'PS2 1068A Service Air System PS3 1067A Instrument Air System 1067E P60 1099- Suppression Pool Cleanup System m189.tr81 ext r8

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 3 of 3 l

.. APPLICABLE SYSTEMS System P & ID Number Number Name of System P64 00358 Fire Protection System 0035E P66 ,

0034B Domestic Water System P71 1109A Plant Cnilled Water System 1109D 1109F P72 10728 Drywell Chilled Water System P75 1070A Standby Diesel Generator System 10708 1070C "070D P81 1093A HPCS Diesel Generator System 10938 1093C T41 1103A Auxiliary Building Ventilation System 4

T42 1104A Fuel Handling Area Ventilation System T48 1102A Standby Gas Treatment System 1102B Z51 0049 Control Room HVAC System m189 tr81 ext 48 ,

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PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE:1 of 2 INTRODUCTION This Program Plan contains the details for the second 120-month inservice Testing (IST) interval of safety related pumps and valves installed at the Grand Gulf Nuclear Station (GGNS), which is a General Electric BWR-6 design.

Commencing with the Preoperational/ Acceptance Test Program, baseline data for all m applicable ASME Class 1,2, and 3 pumps and valves was collected. The initial 120-month IST program commenced with commercial operation on July 1,1985, and was extended to January 1,1997 per Letter GNRI-96/00184. In addition, per the NRC letter

- the First Interval IST Program was to continue to be utilized until November 30,1997.

The secoad 120-month interval began on January 1,1997 and will continue through January 1,2007. The Second Interval IST Program (GGNS-M-189.1, Revision 8) becomes effective on December 1,1997 and remains in effect through the end of the second 120-month interval (January 1, 2007).

Based on the operating license date of June 16,1982,10 CFR 50 required that the GGNS IST program comply with tha 1977 Edition of the ASME Boiler and Pressure Vessel Code Section XI, " Rules for Inservice Inspection of Nuclear Power Plant Components," with Addenda through and including Summer 1979. However, paragraph 10 CFR 50.55a(g)(4)(iv) permitted the use of subsequent editions and addenda, provided that all related requirements of the respective editions or addenda are met. The initial 120-month IST program for pumps and valves was established in accordance with Subsections IWA, IWP and IWV of ASME Section XI Code,1980 Edition and Addenda through Winter 1980 (which was incorporated into 10 CFR by Federal Register dated December 31,1981, Volume 46, No. 251). The second 120-month IST program for pumps and valvss was developed using ASME Section XI,1989 Edition, Subsections IWP and IWV in accordance with 10 CFR 50.55a(b). The 1989 Edition of Section XI states that the rules for IST of pumps and valves are contained in ASME/AWSI Standard OM-1987, " Operation and Maintenance of Nuclear Power Plants," including 1988 addenda. ASME/ ANSI OMa-1988 Part 6. " Inservice Testing of Pumps in Light-Water Reactor Power Plants," (OM Part 6) and ASME/ ANSI OMa-1988 Part 10, " Inservice Testing of Valves in Light-Water Reactor Power Plants (OM Part 10) requirements are applied to pump and valve testing, respectively. OM Part 10 references OM-1987 Part 1,

" Requirements for Inservice Performance Testing of Nuclear Power Plant Pressure Relief Devices," (OM Part 1) for testing of pressure relief devices.

- OM Part 6 and Part 10 requirements are applied, respectively, to safety-related pumps with an emergency power source and safety-related valves. Safety related pumps and valves are those v.hich are required to perform a specific function in shutting down the reactor to the cold shutdown condition, maintaining the cold shutdown con'iition, or in mitigating the consequences of an accident. Some additional leak testing requirements at high/ low pressure interface boundaries in reactor coolant system piping are included 1

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 2 of 2 INTRODUCTION as committed in the GGNS FSAR Questions / Response 211.35 and 211.66. In addition, all valves subject to 10 CFR 50 Appendix J seat leakage testing are included.

The IST program scope includes those pumps and valves designated as ASME Code Class 1,2, or 3 and within the scope statements of OM Part 6 and Part 10 as delineated in 10 CFR 50.55a. As discussed in NRC Generic Letter 89-04, " Guidance on Developing Acceptable Inservice Testing Prograros," the intent of 10 CFR 50 Appendix A GDC-1 and Appendix B Criterion XI is that all components necessary for safe operation are to be tested to demonstrate they will perform satisfactorily in service. As such, the IST program also includes other pumps and valves deemed important to safety as

" augmented" IST components. GGNS has systems / components (e.g Diesel Generator systems) that were designed, fabricated, and constructed to ASME standards even though carrent research has determined that these systems / components did not need to comply with the very stringent ASME standards. Components within these systems are included in the IST Program Plan if they perform a safety function; however, these components are classified as "A" for " Augmented" rather than Cless "1", "2", or "3" The various test frequencies and activities for the valves and pumps are discussed in their respective sections of the IST program, and are listed in the summary listings. For those components where Code testing has been determined impracticable, requests for relief have been submitted in letter GNRO 97/00112 and are included as " Valve Relief Requests" or " Pump Relief Requests." Valves that are tested during cold shutdown or refueling outages in lieu of normal power operation (quarterly) testing are discussed in the " Cold Shutdown Justifications" and " Refueling Outage Justifications" provided.

Similar information is provided for " augmented" components.

The IST program utilizes currently available system drawings and Updated Final Safety Analysis Repvrt sections. Plant construction, modification, anu other conditions may necessitate changes to the program and the addition of Relief Requests. The specific revishn of the Piping and Instrument Drawings (P&lDs) and System Flow Diagrams (GFDt , used in the initial review were provided in the Table of Contents of earlier reWsions of the IST program. Later revisions of P&lDs and SFDs are reviewed, as part of the cosign change process, for conditions that may necessitate program modifications.

Program modifications are performed in accordance with GGNS procedures. The hierauhy of documents it such that the IST prograrn summary listings, along with P&lDs, are the officic! documents.

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE:1 of 8 VALVE PROGRAM GENERAL The valve test requirements are presented on the Valve Summary Listing forms, along with pertinent valve, system, and plant information. The forms, organized by systems, are to be used in conjunction with Piping and Instrument Diagrams (P&lDs). The P&lDs for each system are listed in the Applicable Systems section of this document.

The following pages contain instructional information to aid in the use of the Valve Summary Listings and are keyed to the various heading categories. At the end of this section, comments and explanatory notes of a general nature are given.

INSTRUCTIONS FOR USE OF VALVE

SUMMARY

LISTING FORM VALVE NO, Indicates velve number, including system number.

VALVE SIZE Size of each valve (in inches).

VA' VE TYPE Type of each valve:

AR - air release BA - ball B - butterfly valve C - check D - diaphragm G - gate valve GL - globe valve PC - pressure control RD - rupture disk RV - relief valve SC - stop check valve T - three-way valve TC - temperature control X - shear plug valve (explosive-actuated)

Valves types not included in this list are described in the " NOTES" column of the Summary Listing.

VALVE ACTUATOR Type of actuator (s) for each valve:

A - air EXP - explosive charge H - hand M - motor SA - self-actuated S - solenoid Combinations of actuator types are indicated as appropriate. Examples are H/SA for a stop check valve and A/SA for a testable check valve.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE:2 of 8 VALVE PROGRAM-P&lD NO.

COORD, P&lD number and coordinate of the P&lD at which each valve is located.

IST PASS IST Passive valves (designated by "P" in the Valve Summary Listing) are those valves which maintain obturator position and are not required to change obturator position to accomplish the required function (s) for shutting down the reactor to the safe shutdown condition, maintaining the reactor in safe shutdown, or in mitigating the consequences of an accident.

Valves that are locked or deenergized in their required positions, or are only repositioned from their safety position for the performance of surveillance procedures are considered passive. Valves that are periodically repositioned during plant operation are not considered passive. " Periodic" includes valve operations which occur as a result of normal operating procedures. Valve operations included within off-normal or emergency procedures are not considered periodic. Valve operations which eccur as a result of system startup or shutdown procedures, or infrequent operating procedures may be considered periodic depending upon the frequency of the operation.

For example, a valve has the active safety function to close, if open, on a LOCA signal to provide containment isolation. However, review of plant procedures indicates that the valve is not operated to the open position except for performance of IST surveillance procedures.

Therefore, this valve is considered IST Passive by the above definition.

Certain valves which do not fit the IST Passive category because they have an active safety function in one position have a passive function in the opposite position. The passive position for these valves is noted in the " Notes" column of the Valve Summary Listing.

IST CODE CLASS Designated as "1", "2", or "3" for ASME Code Class 1,2 or 3 within the scope of OMa-1988 Part 10. Designated as "A" (Augmented) for safety related non-ASME components, Also designated as "A" for components within certain systems (e.g., Diesel Generator) that were constructed to ASME standards even though such high standards were not mandatory, mtS t@esht$

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 3 of 8 VALVE PROGRAM CODE CAT Valve category as defined by ASME OM Part 10, for each nonexempt valve.

Category A Valves for which seat leakage is limited to a specific maximum amount in the closed position for fulfillment of their function (s).

Valves for which seat leakage is important may also be classified as Pressure isolation Valves (PlV), Containment Isolation Valves (CIV),

or both Pressure and Containment Isolation Valves.

Category B Valves for which seat leakage in the closed position is inconsequential for fulfillment of their function (s).

Category C Valves which are self-actuating in response to some system characteristic such as pressure (safety relief valves) or flow direction (check valves) for fulfillment of their function (s).

Category D Valves which are actuated by an energy source capable of only one 1 operation, such as rupture disks or explosive-actuated valves.

NOTE: Combined category valves are identified in this program when more than one Code category is needed to identify the valve functions.

Examples are C, A and C, B.

SAFETY POSITIONPcsition (close and/or open) the valve is required to be in to perform its safety function.

REQUIRED TESTS AND FREQUENCY Required valve tests for the respective safety position of each valve are indicated by an entry for the associated test frequency in the Summary Listing and are described below. These columns will describe the method (s) of testing for each valve, using the following test designations:

FS- Valve is full-stroke exercised to the position in which the valve is required to be to fulfill its safety function. The necessary valve ;

obturator movement shall be determined by exercising the valve while observing an appropriate indicator, such as indicating !!ghts which l signal the required change of obturator position, or by observing other '

l evidence, such as changes in system pressure, flow rate, level, l

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 4 of 8 VAi.VE PROGRAM temperature, or other positive means which reflect change of obturator position (OMa-1988 Part 10,4.2.1.2,4.2.1.3,4 3.2.2,4.3.2.4(a)).

PS- Partial-stroke exercising a check valve to an open position less than full open or less than that required to pass the maximum required accident condition flow rate (OMa-1988 Part 10,4.3.2.2). For power operated valves, exercising a valve to an intermediate position, versus full stroke open or full-stroke closed exercising (OMa-1988 Part 10, 4.2.1.2).

LT - Seat leakage test required by OMa-1988 Part 10,4.2.2.3, for Pressure Isolation Valves (ref. Tech Spec SR 3.4.6.1) and other Category A valves that are not containment isolation valves.

LJ - Seat leakage test required by 10 CFR 50, Appendix J (OMa-1988 Part

10, 4.2.2.2) for Containment Isolation Valves. Valves within the scope l of ASME OM Part 10 classified as Pressure and Containment Isolation Valves shall also be tested to the requirements of OMa-1988 Part 10, 4.2.2.3.

! ST- Measure and record valve full-stroke time (to the nearest second) to l the position required to fulfill its safety function (OMa-1988 Part 10,

! 4.2.1.4). Bases for maximum stroke times of power actuated valves are given in Appendix A.

FT- Observe operation of the actuator upon loss of valve actuating power (OMa-1988 Part 10,4.2.1.6); may be accomplished by observation of l valve indicating lights during normal valve operation or full-stroke l exercising, if normal valve stroking involves or simulates loss of valve actuating power.

l Pi- Verify valve operation corresponds to remote position indicators l (OMa-1988 Part 10,4.1). Only those remote indicators used for l inservice testing are required to be verified.

RV- Pressure relief devices are to be performance tested and/or visually inspected in accordance with OMa-1988 Part 10,4.3.1 which references the requirements of OM 1987 Part 1.

The number of relief valves that shall be tested each refueling outage shall be in accordance with OM-1987 Part 1,1.3 3 and 1.3.4.

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PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 5 of 8 VALVE PROGRAM EX- At least 20% of the charges in explosively actuated valves shall be fired and replaced every two (2) years (OMa-1988 Part 10,4.4.1.)

CD- Check valve disassembly and inspection in accordance with disassembly and inspection program procedures each refueling (OMa-1988 Part 10,4.3.2.4(c)). This test designation does not apply for sample plan disassembly and inspections as allowed by GL 89-04.

TEST FREQUENCY Q- Test performed once every 92 days (3 months).

C- Test performed every cold shutdown but not more frequently than once every 92 days (3 months).

Cold Shutdown Testing - GGNS will commence testing no later than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after cold shutdown condition is achieved, and will continue until all tests are ccmplete or the plant is ready to return to power.

This time requirement is necessary such that scheduling arrangements, appropriate valve lineups, and system adjustments can be made prior to valve testing. Any testing not completed at one cold shutdown will be performed during any subsequent cold shutdowns that may occur before refueling to meet the code-specified testing frequency. For planned cold shutdowns, wtiere GGNS will complete all the valves identified in the Inservice Testing Program for testing in the cold shutdown mods, exception to the 48-hour start time may be taken. In the case of frequent cold shutdowns, valve testing will not be performed more often than once every 92 days (3 months) for Category A, B, and C valves.

R- Test performed at each reactor refueling outage.

2Y- Test performed once every two years.

SY - All Class 1 pressure relief valves of each type and manufacturer ara to be tested within each subsequent 5 year period following the initial 5 year period, with a minimum of 20% of the valves tested within any 24 months. This 10% is to be previously untested valves (from the current 5 year period), if they exist.

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PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 6 of 8 VALVE PROGRAM If less than 20% of each type and manufacture of the group of all Class 1 pressure relief valves remain to be tested in the current 5 year period, then valves are to be retested as necessary such that at least 20% of each type and manufacture is tested within any 24 month

, period.

Classes 2 and 3 nonreciosing pressure relief devices are to be replaced every 5 years, unless historical data indicates a requirement for more frequent replacement.

10Y- All Classes 2 and 3 pressure relief valves of each type and manufactura are to be tested within each subsequent 10-year period following the initial 10-year period, with a minimum of 20% of the valves tested within any 48 months. This 20% is to be previously untested valves (from the current 10 year period), if they exist.-

If less than 20% of each type and manufacture of the group of all Classes 2 and 3 pressure relief valves remain to be tested in the current 10 year period, then valves aro to be retested as necessary such that at least 20% of each type and manufacture is tested within any 48 month period.

J- 10CFR50 Appendix J Type C leak rate tests are controlled by the GGNS Local Leak Rate Test (LLRT) Program. Refer to the LLRT Program for individual valve leakage test requirements.

REllEF REQUEST VRR- Relief Requests for valves that cannot be tested per Code requirements are provided in the Relief Requests section. The appropriate Valve Relief Request (VRR) number is provided in the Valve Summary Listing. Relief requests of a generic nature have been placed in the Relief Requests section.

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 7 of 8 VALVE PROGRAM CPLD SHUTDOWN / REFUELING OUTAGE JUSTIFICATIONS and AUGMENTED VALVE TEST Per paragraphs OMa-1988 Part 10,4.2.1.2 ano 4.3.2.2, valves that

< cannot be full stroke exercised during normal plant operation shall be full-stroke exercised during cold shutdowns or refueling outages.

Those valves that cannot be full-stroke exercised during normal plant operation and are tested during cold shutdowns are identified by the test frequency "C", and those that can only be full-stroke exercised during refueling outages are identified by the test frequency "R" in the Summary Listing. The referenced Cold Shutdown Justification (CJ) or Refueling Outage Justification (RJ) identifies the applicable valve (s) that cannot be full-stroke exercised during plant operation, or cold shutdown, and provides justification for deferring the tests to cold shutdown or refueling. Cold Shutdown and Refueling Outage Justifications are provided in the Cold Shutdown and Refueling Outage Justification section.

Certain check valves cannot be exercised full-stroke open or fully closed by any means other than disassembly and inspection. As allowed by Generic Letter 89-04, Position 2, those valves may be included in a sample disassembly and inspection program, and testing by disassembly of a sample from each group deferred to refueling outages. Valves that are full-stroke exercised in this manner are identified in " Refueling Outage Justifications". Justification for extension of the test frequency to refuelings is provided, and sample groups are identified.

Augmented Valve Test (AVT) descriptions are included for Augmented valves (IST Code Class "A"). These valves are tested to 10CFR50 Appendix B requirements rather than to 10CFR50.55a requirements.

NOTES Any explanatory notes required are provided or are referenced.

Specific notes for the Valve Summary Listing are included at the end of the Valve Summary Listing section.

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 8 of 8 VALVE PROGRAM Non-Intrusive Testina (NIT)

Non-intrusive testing (NIT) techniques, such as acoustic emission, ultrasonics, radiography, and magnetic proximity, are used to verify that certain check valve discs open fully during the exercising of the valves. The check valves to which NIT is applied are noted in the Valve Summary Listing. The NIT program used at GGNS utilizes the guidance provided in NRC Generic Letter 89-04 to ensure that NIT activities are controlled in a quality manner. NIT is considered to be "other positive means" of verifyinq obturator movement as allowed by OMa-1988 Pad 10,4.3.2.4(a).

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 1 OF4 VAINE RELIEF REQUESTS VALVE RELIEF REQUEST NO : VR R-GEN-01 System: Various Component: E38F002A E38F002B E38F003A E38F003B E51F079 E51F081 Catenory: C Qaggi Various Function: Various Impractical Test Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1) except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During operation each check valve shall be exercised or examined in a manner that venfies obturator travel to the full-open, or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). As an attemative to the testing in OM Part 10,4.3.2.4(a) or 4.3 2.4 (b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2,4(c)).

Basis For Relief:

Testing of check valves generally requires knowledge of the position of the disk or verification of the amount of flow passing through the valve. However, for some check valves the disk position or required flow values can not be ascertained. In some cases, establishing required flow for testing purposes may result in damage to plant equipment or is not possible.

Disassembly testing may be used to determine that a valve's disk will full-stroke exercise open or to venfy closure capability, as allowed by OM Part 10,4.3.2.4(c). Due to the scope of disassemb./

testing, the personnel hazards involved, planned maintenance activities and system operating restrictions, all valves requiring disassembly and inspection may not be available for such testing during each reactor refueling outage. Generic Letter 89-04 provides approval of Code deviations that are consistent with the NRC positions of the Generic Letter, Attachment 1. This relief raquest meets the guidelines of Position 2 of the Generic Letter for implementation of a check valve sample disassembly and inspection program.

Alternative Testfr}g:,

Where it is determined that it is ourdensome to disassemble and inspect all applicable valves each refueling outage, the following Sample Disassembly and Inspection Plan for groups of identical valves :n similar applications is employed. The requirements for grouping in accordance with this plan are explaineo below:

The Sample Disassembly and inspection Plan involves grouping valves of similar design, application and service conditions, and testing one valve in each group during each refueling

- outage. The grouping technique requires that for each valve in a group the following, as a minimum, be considered: design, manufacturer, size, model number, service, orientation, and materials of construct;on. Valve group size is limited to four valves, maximum.

When disassembly testing is performed valves shall be tested as follows:

PROGRAM Pl.AN NO. GGNS-M-189.1 REVISION NO. 8 l PAGE NO. 2 OF4 I VALVE RELIEF REQUESTS VALVE RELIEF REQUEST NO.: VRR-GEN-01 (a) At each disassembly it must be verified that the disastembled valve is capable of full-stroking and that the intemals of the valve are structurally sound (no loose, corroded, wom, or failed parts), if the disassembly is to venfy the full-stroke capability of the valve, the disk is to be 1 manually full stroke exercised. Full stroke motion of the obturator is to be revenfied immediately prior to completing reassembly. Check valves (e g., spring loaded lift check valves, or check valves with the obturator supported from the bonnet) that have their obturator disturbed before full-stroke t in is verified, are to be examined to determine if a condition exists that could prevent full. opening or reclosure of the obturator.

(b) A different valve of each group is required to be disassembled, inspected, and manually full-stroke exercised at each successive refueling outage, until the entire group has been tested. At least one valve from each group is to be disassembled and examined at each refueling outage.

Once this is completed, the sequence of disassembly must be repeated. All valves in each group are to be disassernbled and examined at least once every si.v years.

(c) Before retum to service, valves that were disassembled for examination or that received maintenance that could affect their performance, are to be exercised full-or part-stroke, with flow, if practicable.

(d) If disassembly is the only means of verifying the valves full stroke, the check valve should be partially strokcd quarterly or during cold shutdown, if practicable.

(e) If the disassembled valve is not capable of being full-stroke exercised or there is binding or failure of valve intemals, the remaining valves in that group must also be disassembled, inspected, and manually full-stroko exercised during the same outage.

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PROGRAM PLAN NO. GGNS-M 189.1

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REVISION NO. 8 PAGE NO. 3 of 4 ,

VALVE RELIEF REQUESTS VALVE RELIEF REQUEST NO.: VRR 821-01 System] B21 Nuclear Boiler System Component: 821F041A B21F0418 B21F041C B21F041D B21F041E B21F041F B21F041G B21F041K B21F047A B21F047C B21F047D B21F047G B21F047H B21F047L B21F051A B21F0518 B21F051C B21F051D B21F051F B21F051K CatenoN: C,8 Class: 1 Function: The MSRVs are closed for reactor coolant system boundary. The MSRVs open for overpressure protection and for Automatic Depressurization System (ADS) function (821F0410, F & K; B21F047A & L; B21r:051 A, B & C).

Imoractical Test Reauirements:

Category B valves are required to be tested to the safety position at least once every 3 months in accordance with ASME OM Part 10,4.2.

Basis For Relief:

Opening these valves during power operation would cause unnecessary transients in the reactor coolant system and require needless operation of the suppression pool cooling system Cycling of these valves during power operation significantly increases the risk of creating undesired seat leakage and/or escalating deterioration of valve seating surfaces due to such leakage. The initiation and continuaw of MSRV seat leakage increases the amount of valve contamination and may necessitate t.Walve decontamination efforts on the valve prior to testing. The creation of extensive seat leakab ww.d also require unnecessary operation of the suppression pool cooling system. In addition to the potential seat leakage issues, there is the possibility of an MSRV sticking open during testing at power thereby creating a LOCA. Although an inadvertently l stuck open MSRV is an analyzed event in the UFSAR, it is not the intent for testing to increase the risk of initiating such a casualty, in NUREG-1482, Guidelines for Inservice Testing at Nuclear Power Plants (April,1995) Section 4.3.4, the NRC Staff recommended reducing the number of challenges to the dual function Automatic Depressurization System (ADS) valves in order to reduce their failure rate. Since both ADS and non-ADS MSRVs perform dual function service, the same recommendation for reduction in the number of challenges to dual function operation is implied by inference for the non-ADS MSRVs. The Staff also noted that the ASME OM Committee was reviewing the categorization of safety and relief valves as Category C, rather than Category B,C, and stated that if the OM Committee determines these valves are Category C only, meeting the code requirements for Category A or B will be unnecessary.

The ASME OM Committee and Board on Nuclear Codes and Standards approved a change to the ASME Operation and Maintenance (OM) Code Section ISTC 1.2, which adds the fo!!owing statement:

l l " Category A and B safety and relief valves are excluded from the requirements of ISTC 4.1,

" Valve Position Verification" and ISTC 4.2, " Inservice Exercising Test."

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 4 of 4 VALVE RELIEF REQUESTS VALVE RELIEF REQUEST NO.: VRR-821-0.J Altnough this approval does not address the categorization of safety and rehef valves noted in NUREG-1482, it accomplishes the same objective, which is to limit inservice exercising of the valves when they are ir stalled in the plant. By excluding the safety and relief valves from Sections ISTC 4.1 and ISTC 4.2, the OM Committee has in fact determined that these valves are only subject to Category C testing. Although this approvalis to OM Code-1995, it addresses concems which have existed since Section XI to the ASME Boiler an. ~ *ressure Vessel Code was originally issued. The.'95 OM Code reouires safety and relief valves to meet the testing requirements of Appendix 1. Similarly, OMa-1988 requires safety and relief valves to meet the testing requirements of OM Part 1. Thus, it is reasonable to apply the OM Committee's determination (which was approved in NUREG-1482) to OMa-1988, Therefore, Category B testing and valve position venfication is not required.

Per OM 1987 Part 1, para 3.4.1.1(d), the MSRVs are required to be stroked at reduced system pressure to verify open and close capability. As noted above, valve Ftroking on live steam is not desirable. Additionally, it is GGNS's opinion that the purpose of this Part 1 requirement is to venfy correct installation of the air and electrical systems associated with the relief mode operation of the MSRV, Such confirmation can be accomplished without physically lifting the valve disk from the nozzle seat. Thus, GGNS believes that a de-coupled actuator test, as described in the Altemative Testing below, is sufficient to perform this installation verification and will provide an acceptable level of quality and safety Alternative Testina:

The MSRVs will be exercised to the open position by manual actuation of the valve control system during setpoint testing and certification activities on the test bench. The response time of MSRV actuation is measured and recorded during certification activities. This response time is well below 1 second, and corrective actions are required should the response time be exceeded, During installation in the plant following setpoint testing and certification, the valve stems will be uncoupled from their actuators. The air actuators will be exercised (without !ining the valve stems) to verify control signal continuity and proper air system configuration, following which the actuators will be re coupled to the valve stems.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.1 OF 51 COLD SHUTDOWN JUSYlFICATIONS .

COLD SHUTDOWN JUSTIFICATION NO.: CJ B21-01 System / Component Cateaory Class 821F022A A 1 821F0228 A 1 B21F022C A 1 B21F022D A 1 B21F028A A 1 B21F028B A 1 821F028C A 1 B21F028D A 1 Functio _nj Close for containment isolation.

Code Requirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2, 4.2.1.6, and 4.2.1.7. If full-stroke oxercising during plant operation is not practicable, it may be limited to part-stroke during plant operation and full-stroke during cold shutdowns (OM Part 10, 4.2.1.2(b)).

Justification:

These valves are poppet-type globe valves whose design requires flushing of the seat by flowing steam or water during, or just prior to, valve closure to prevent scoring of the seat. Part stroke exercising of these valves in a slow close mode can be accomplished during plant operation at any power level. However, full-stroke exercising and stroke time testing during power operation can only be performed after a significant decrease in power, to prevent a reactor power excursion and possible reactor scram resulting from a reactor pressure it. crease when the valve is closed.

Additionally, full-stroke exercising is not practicable during cold shutdowns because the steam flow necessary to prevent seat damage is not available and the steam lines would have to be filled with water to allow flushing prior to valve closure. Therefore, it is desirable to perform full-stroke exercising during start up from cold shutdown within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching a reactor pressure of 600 psig and prior to entry into Operational Condition 1 in accordance with Technical Specification 4.4.7.

Alternative Testina:

Part stroke exercise the valves every 3 months during power op3 ration. Full-stroke exercise the values during start-up from cold shutdown within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching a reactor pressure of 600 psig 9nd prior to entry into Operational Condition 1 in accordance with Technical Specification 4.4.7.

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FROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 2 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: QJ-82102 System / Component Catenorv Class 821F036A C,A 3 821F036B C,A 3 B21F036C C,A 3 B21F036D C,A 3 B21F036E C,A 3 B21F036F C,A 3 821F036G C,A 3 821F036H C,A 3 B21F036J C,A 3 B21F036K C,A 3 B21F036L C.A 3 B21F036M C,A 3 B21F036N C,A 3 B21FG36P C,A 3 B21F036R C,A 3 B21F036S C,A 3 B21F036T CA 3 B21F038U C,A 3 821F036V C,A 3 B21F036W C,A 3 Function:

Open to provide makeup air to maintain accumulator fully pressurized for relief valve operation.

Close to prevent loss of relief valve stored air supply.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4 and 4.3.2.5, During power operation, check valves shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercisir.g is not practicable during plant operation, it may be limited to full-stroke exercising tjuring cold shutdowne,(OM Part 10, 4.3.2.2(c)).

Justification:

These check valves are located in the drywell which is a high radiation area during power operation and are, therefore, inaccessible. Testing requires access to the valves. Ths.efore, full-stroke exercising of these valves is deferred to cold shutdown as permitted by CM Part 10, 4.3.2.2(c).

Alternative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 3 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ B2103 jyytem/ Component Cateoory Class B21F037A C 3 B21F037D C 3 B21F037F C 3 B21F037H C 3 B21F.037L C 3 B21F037N C 3 821F037R C 3 B21F037U C 3 B21F078A C 3 821F078D C 3 B21F078F C 3 B21F0'8H C 3 B21F078L C 3 B21F078N C 3 B21F078R C 3 B21F078U C 3 Eunction:

Open to provide vacuum relief in MSRV discharge line; Close to prevent MSRV discharge directly to drywell.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4 and 4.3.2.5. During power operation, check valves shall be exercised or examined in a manner tha' verifies obturator travel to the closed, full-open or partially open position required to fulfillits functior: (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during co'd shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

These check valves are located in the drywell which is a high radiation area during power operation and are, therefore, inaccessible. Testing requires access to the valves. Therefore, full-stroke exercising of these valves is deferred to cold shutdown as permitted by OM Part 10,4.3.2.2(c).

Alternative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.3.2.2(c).

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 4 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ 821-04 System / Component Catecorv Class 221F065A A 2 B21F065B A 2 Function:

Close manually for containment isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided t'y OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

821F065A and B are normally open valves in the feedwater piping to the reactor vessel. Exercising these valves during power operation would interrupt the flow of feedwater through the respective line and woud require a significant reduction of reactor power prior to testing to prevent a reactor scram.

Even at reduced power lecels, system pc.*.urbations and resultant fluctuations in vestel level create the potentici for a reactor scram (low vessel level) or turbine trip / reactor scram (high vessel level).

Therefore, full-stroke exercising is deferred to co'd shutdown as permitted by OM Part 10,4.2.1.2(c).

Sternative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGR.iM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 5 OF 51 COLD SHUTDOWN JUSTIFICATIOQQ COLD SHUTDOWN JUSTIFICATION NO.: CJ-821-05 System / Component Cateaory Class 821F098A B 2 ,

B21F0988 B 2 B21F098C B 2 821F098D B 2 Function: <

Close (manually) to provide for proper post-LOCA operation of M31V LCS.

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

B21F098A, B, C and D are normally open valves in the main steam lines to the tu2ine. Closure of any valve during power operation would interrupt steam flow through the respective steam line and could only be performed after a significent decrease in power, to prevent a reactor power excursion resulting from a pressure increase when the valve is closed. Therefore, full-stroke exercising of these valves is deferred to cold shutdowns as permitted by OM Part 10,4.2.1.2(c).

Alternative Testina:

Full-stroke exorcise valves during cold shutdowns per OM Part 10, 4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 6 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTCOWN JUSTIFICATION NO.: CJ-821-06 System / Component Cateaory Class 821F130A C,A 3 -

821F1308 C,A 3 Function:

Open to recharge ADS accumulators for long term relief valve operations; Close to prevent loss of relief' valve stored air supply.

Code Reauirements:

Active Category A valves shall be tested nominally overy 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check velves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4 and 4.3.2.5. If exercising is net practicable during plant operation, it may be limited to full-stroke exercising durirg cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)).

Justificatior);

B21F130A and B are check velves in the instrument air supply piping to the Automatic Depressurization System accumulators. The valves are located inside the drywell which is a high radiation area during power operation and is, therefore, inaccessible. Testing requires personnel access to the valves. Therefore, full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Alternative Testinu:

Full-stroke exercise valves during cold shutdown per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.- 7 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: ~ CJ-821-07 System / Component Category Class B21F147A B 3 B21F1478 8 3 Function:

Open manually to vent main steam line piping for post LOCA leakage control.

Code Rea'uirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 1C,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

821F147A/B are vent valves connected to the main steam drain lino. They are located in the main-steam tunnel which, during power operation, is a high radiation area and is inaccessible if either of these valves fai:ed open during testing, the steam line drain paths would not be available for use during shutdown because the steam woud be exhausted directly to the steam tunnel atmosphere through the failed open valve. The loss oi ain capability creates the potential for turbine water induction and resultant equipment damage. Therefore, full stroke exerc; sing of these valves is deferred to cold shutdowns as permitted by OM Part 10,4.2,1.2(c).

Alternative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 '

REVISION NO. 8 PAGE NO. 8 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD S!!UTDOWN JUSTIFICATION NO.: CJ 821-08 System / Component Category Class 821F803 C 2 Function:

Close to prevent backflow to feedwater during RCIC operation Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2,4 and 4.3.2.5. During power operation, check valves shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (CM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-strohe exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

B21F803 is a normally open check valve ir: ine "B" feedwater line to the reactor vessel. This valve is located in the main steam tunnel which is a high radiation area during power operation and is, therefore, inaccessible. Testing requires personnel access to the valve. Additionally, full-stroke axercising this valve would require stopping feedwater flow to the vessel through the asscciated feedwater line which is impracticable during power operation. Therefore, full-stroke exercising is deferred to cold shutdowns as permitted by OM Part 10,4.3.2.2(c).

Alternative Testina:

Full-stroke exercise valve during colel shutdowns per OM Part 10,4.3.2.2(c).

l PROGRAM PLAN NO. GGNS-M-189.1 1 i

REVISION NO. 8 PAGE NO. 9 OF 51 ,

l COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ B21-09 System / Component Category Class B21F024A C 3 821F024B C 3 B21F024C C 3 B21F024D C 3 821F029A C 2 821F029B C 2 821F029C C 2 B21F029D C 2 Function:

Close to retain MSIV accumulator air pressure for MSIV closure (air assist)

Code Recuirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4 and 4.3.2.5. During power operation, check valves shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

B21F024A/B/C/D and F029A/B/C/D are check valves in the air supply piping to the MSIV accumulators. These valves are located in the drywell (F024s) and main steam tunnel (F029s) which are high radiation areas during power operation and are, therefore, inaccessible. Testing requires personnel access to the vaives. Therefore, full-stroke exercising is deferred to cold shutdow,1s as permitted by OM Part 10, 4.3.2.2(c).

Alternative Testino:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.10 OF 51 COLD SHUTDOWN JUSTlFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ 821-10 Systeem/ Component Cateaory Class B21F152A C,A 2 B21F1528 C,A 2 B21F152C C,A 2 B21F152D C,A 2 B21F154A C,A 2 821F154B C,A 2 B21F154C C,A 2 821F1540 C,A 2 Function:

Close to prevent draining of the associated instrument reference leg upon failure of the Non-Q CRD system piping.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as

- provided by OM Part 10, 4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfies obturator tranl to the closed, full-open, or partially open position required to fulfillits function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)).

Justification:

B21F152A/B/C/D and F154A/B/C/D are check valves in the CRD purge supply to Reactor Vessel LevelIndicating System reference legs. Testing of the valves requires tne purge system to be removed from and retumed to service, creating the potential for perturbations in the instrument reference legs oue to pressure spikes or introduction of air. Such perturbations could result in

" indicated" level swings and unnecessary challenges of safety systems unless the instruments associated with the affected reference leg were removed from service, in some cases, removal of instruments from service would require lifting of leads in the circuitry which could result in trips /actuations if lifting / landing errors or a short circuit were to occur. Therefore, full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Ahernative Testina:

Full-stroke exercise valves during cold shutdown per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M 189.1 ;

REVISION NO. 8 PAGE NO.11 OF 51 COLD SHUTDOWN JUSTIFICATIONS :

COLD SHUTDOWN JUSTIFICATION NO.: CJ 821 11 System / Component Catenorv g[ gag B21F067A A 1 1 B21F067B A 1 B21F067C A 1 821F067D A 1 Function:<

Outboard containment isolation valves in main steam drain lines.

Code Reauireme nts:

Active Category A valves sha 1 be tested nominally every 3 months (OM Part 10,4.2.1.1), except as :

provided by OM Part 10,4.2.1.2,4.5 l.5, and 4.2.1.7. If exercising is not practicable during plart operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)). ,

211 @ c atl0 Q1 These valves are located in the main steam tunnel, which is inaccessible during power operation.

They are normally open during startup for steam drainage but are closed at about 55% power due to ;

concerns regarding postulated high energy line breaks near instrument tubing connections. By isolating the drain lines during high power operation, the lines may be considered as moderate -

er. orgy piping, as opposed to high energy piping which would require additional restraints to protect the instrurnent tubing runs of pressure transmitters on the main steam lines. Therefore, the valves must remain closed at high power.

Stroking the valves quarterly would require significant power reduction, and failum of the valves in the open position would require reactor shutdown for repairs.

Attornative,Jostina:

Full-stroke exercise valves during cold shutdowns per OM Part 10, 4.2.1.2(c).

a.,. , - - , . +. - -- - , n c, , - + - ~n,e-- -r -- .n

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO 8 i PAGE NO.12 OF Si ;

COLD SHUTDOWN JUSTIFICATIONS

COLD SHUTDOWN JUSTIFICATION NO.: CJ 82112 System / Component 91testm Qggg B21F100A C 3 821F1008 C 3 821F1000 C 3 B21F1000 C 3 B21F100E C 3 B21F100F C 3

- B21F100G C 3 B21F100H C 3 B21F100J C 3 B21F100K C 3 B21F100L C 3 -

B21F100M C 3 B21F100N C 3 B21F100P C 3 ,

B21F100R C 3 B21F100S C 3 B21F100T C 3 B21F100U C 3 B21F100V C 3 B21F100W C 3 S

b b

, , , ~.y_p. _,_--.w- .,3 _ , ,. . ,, , , , , ,,,

i PROGRAM Pt.AN NO. GGNS-M 189.1 l REVISION NO. 8 l PAGE NO.13 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTirlCATION NO.: Q1B7Jf i.2 Function:

Open to relieve vacuum in SRV bonnet vent line. Close to prevent steam discharge directly to the drywell.

Code Reauirements:

Check valves shall be exercised or examined nominally every 3 months in a manner that venfies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10, 4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. The necessary valve obturator movement shall be demonstrated by exercising the valve to the position required to fulfillits function. if a manual mechanical exerciser is used to move the obturator, the force or torque required to initiate movement (breakaway) shall be measured and recorded (OM Part 10,4.3 2.4(b)). If exercising is not practicable dunng plant operation,it may be limited to full stroke exercising during cold shutdowns sOM Part 10,4.3.2.2(c)).

Justification:

Design of these valves is such that the disc can be full-stroke exercised with a mechanical exerciser by inserting a small probe through the open-ended inlet piping. The open-ended inlet piping provides access to the valve intemals fur both disc movement and inspection of intemals for corroded, wom or otherwise damaged parts. However, these valves are located in the drywell which, during power operation, is a high radiation area and is inaccessible. Testing requires access to the valves and cannot be peformed dunng power operation. Therefore, these valves are to be tested by the method described above dunng cold shutdowns.

Alternative Testina:

Full-stroke exercising and examination of these valves is to be performed by gently lifting the disc from its seat to the full-open position with a mechanical exerciser (OM Part 10,4.3.2.4(b)) and visually observing that the disc retums to the closed position when released. While exercising the disc, qualified personnel are to inspect valve intemals fnr corrosion, wear or other indications of damage or degradation using lights, mirrors, borescopes, etc. as required to perform such inspection. This testing is to be performed during cold shutdowns in accordance with OM Part 10, 4.3.2.2(c).

__ ___ ._ _ . _ . _ _ _ . _ _ _ . _ _ . _ . . _ _ _ _ _ _ . ~ _ _ - _ _ _ _ _ _ - .. _ __..

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO.14 OF 51 f COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ 833-0.1 System / Component Cateaory gang 033F013A C 2 B33F0138 C 2 B33F017A C 2 B33F017B C 2 Function:-

Drywell isolation Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.2 ., and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a mann that venfies obturator travel to the closed, full open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

F013A, F0138, F017A and F0178 are normally open check valves in the recirculation pump seal injection water piping. These valves are located in the drywell, which is a high radiation area during ,

power operation, and are inaccessible. Testing requires access to toe valves. Therefore, full stroke exercising of these valves is deferred to cold shutdown as permitted by OM Part 10, 4.3.2.2(c).

Altern9tive Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10, 4.3.2.2(c).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO.15 OF 51 COLD SHUTDOWN JUSTlFICATiONS ,

COLD SHUTDOWN JUSTIFICATION NO.: CJ E12-01 System / Component Category gjggg, E12F008 A 1 E12F009 A 1 E12F023 A 1 E12F394 A 1 l

Function:

Close for containment / system isolation; Close for RCPB high-low pressure boundary isolation Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, end 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justificatiom These valves are in the RHR shutdown cooling suction piping (F008, F009) and RHR head spray piping (F023, F394), and cannot be exercised during power operation because they are pnivided with pressure interlocks to prevent opening at reactor pressures above 135 psig (approximately).

Thereforn, full stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c).

ANornative Testina:

"ull stroke exercise valves during cold shutdowns per OM Part 10, 4.2.1.2(c).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO.16 OF 51 COLD SHUTDOWN JUSTlFl0ATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E12 02 System /Commonent Catenory fdut E12F308 CA 2 Functiom Closes to isolate low pressure RHR piping from RCPB; Close for containment isolation j Cnde_Renuirementsl Active Category A valves shall be tested nominally every 3 months (OM Part 10,4 2.1.1), except as i provided by OM Part 10, 4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally i overy 3 months in a manner that venfies c')turator travel to the closed, full open, or partially open I position required to fulfillits function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part ,

10,4.3 2 2, 4.3.2.3, 4.3 2.4, and 4.3 2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)). ,

Justification:

E12F3rv % a stop check valve located in the RHR Shutdown Cooling suction piping inside the drywd to tfkW overpressure relief for thermal expansion of fluid trapped between E12F008 and F000 din ri MMulated accident conditions. Testing the valve requires personnel access to the valve which isn t ptnable because the valve location (drywell) is inaccessible during power operation.

Therefore, full stroke exercising of this valve is deferred to cold shutdowns as permitted by OM Part 10,4.2.1.2(c) ano 4.3.2.2(c).

Alternative Testina:

Full stroke exercise valve during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

1

~ _._ _,. ~_ , , _ . __ , . _ . _ _ _ _ _ _ , _ _ _ _ _ . _ _ . _ _

i PROGRAM PLAN NO GGNS M 189.1 REVISION NO. 8 PAGE NO.17 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTlFICATION NO.: CJ E12 03 System / Component Catenorv Q.l,s.n,g E12F041A C,A 1 E12F041B C,A 1 E12F041C C,A 1 Function:

Open for LPCI injection to Reactor Vessel; Close for containment isolation (F041C); Close for RCPB high low pressure boundary isolation Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10, 4 2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfies obturator travel to the closed, full epen, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), ext.ept as provided by OM Part

10. 4,3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10. 4.2.1.2(c) and 4.3.2.2(c)).

Justification:

During plant operation, check valves E12F041 A, B and C are subjected to reactor coolant system pressure on the downstream side which makes partial and full stroke exercising both with flow and with the test actuator impracticable. The LPCI pump discharge pressure is insufficient to open the associated check valve against full reactor pressure; the test actuator will not lift the check valve disk against full reactor pressure. Therefore, E12F041 A, B and C full stroke exercising is deferred to cold shutdown as permitted t y OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Attornative Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO.18 OF Si COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E12 04 System /Como9atDi Catenorv ,]Jagg E12F042A A 1 E12F0428 A 1 E12F042C A 1 Function:

Open for LPCl injection to Reactor Vessel; Close for containment isolation; Close for RCPB high-low pressure boundary isolation Code Reaulroments:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5 and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

JustWication:

During plant operation, downstream check valve E12F041 A (B, C) is subjected to reactor coolant system pressure on its downstream side. Upstream LPCI Injection Shutoff Valve, E12F042A (8, C),

is isolated from reactor pressure only by E12F041A (B, C). During plant operation the lower pressure rated piping is protected by normally closed valves E12F042A (0, C), and E12F041 A (B, C).

Pressure sensing instrumentation is provided to monitor pressure between the check valve and the injection shutoff valve to prevent opening the injection valve above a sensed pressure of approximately 500 psig, also providing protection for the low pressure upstream piping. Should 1 E12F041 A (0, C) leak during plant operation, testing of shutoff valve E12F042A (B, C) would be precluded without venting the piping section between valves E12F041 A (B, C) and E12F042A (B, C). Venting is considered impracticable due to personnel hazard and ALARA considerations from venting high pressure contaminated fluid to open (in some cases) drains. Depending upon the magnitude of the leakage, repressurization after venting may occur such that testing would be precluded. Therefore, E12F042A (B, C) full stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c).

Sternative Testino:

Full stroke exercise valves E12F042A (B, C) during cold shutdowns per OM Part 10,4.2.1.2(c).

T- wr&n 9 -mr- * - - -

PROGRAM PLAN NO GGNS M-163.1 REVISION NO. 8 PAGE NO.19 OF 51 COLD SHUTDOWN JUSTIFICATIONS >

COLD SHUTDOWN JUSTIFICATION NO.: CJ E12 05 t

gang 1Mit*.m/fdtmR20201 Catenorv E12F053A A 2 E12F0538 A 2 function:

Close for system isolation; Close for LPCI operation of RHR; Close for RCPB high-low pressure i boundary isolation Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.12,4.2.1.5, and 4.2.1.7, If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c))._

Justification:

E12F053A and B are the RHR shutdown cooling retum isolation valves. They are provided with an interlock to prevent opening at reactor pressure above 135 psig (approximately), and cannot be exercised dunng power operation. Therefore, full stroke exercising is deferred to cold shutdown as permrtted by OM Part 10,4.2.1.2(c).

Alternative Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

4 L

N I

ll

-u.,, -- - ,-g--s*r- % u -- c-. -+,.e4.g i-i1-,-+, .- -,

4 w% 7,,.,.-m9_w..g ,e-,.y y. w. ,%+--e--.,,.m ,, ., .,, _. #s--..- ,. ,-.-g,.- c---#, +

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 20 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-E12 06 System / Component Catenorv Class l

E12F050A CA 2 E12F050B C,A 2 l Function:

Close for RCPB high low pressure boundary isolation Code Rea'u irements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Pert 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c),4.3.2.2(c)).

Justification:

E12F050A and B are check valves in the RHR shutdown cooling piping downstream of F053A and B, respectively. Testing these valves to the closed position requires opening upstream valves F053A and B. Opening valves F053A and B during power is not possible because they are interlocked to prevent opening above approximately 135 psig reactor pressure. Therefore, F050A and B full stroke exercising is deferred to cold shutdowns as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Alternative Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c). The testing method is cc follows:

Valves E12F050A and B are full stroke exercised open by initiatior of RHR flow by opening valves E12F053A and B upstream during cold shutdowns. Valves E12F050A and B are full stroke closed when RHR flow is terminated by closing valves E12F053A and B. Verification of the closed position each cold shutdown is performed by opening test connection valves E12F058A and B and venfying the absence of pressurized flow,

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 21 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E12-07 System / Component Catenory ,QJg.g E12F066A B 2 E12F066B B 2 Function:

Closed to provide code boundary restoration of ECCS piping durin0 periods when the Attemate Decay Heat Removal System (ADHRS)is in operation.

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising ouring cold shutdowns (OM Part 10,4.2.1.2(c)).

JustWication:

The Alternate Decay Heat Removal System is out of service when the plant is in modes 1,2, and 3.

Therefore, valves E12F066A and F066B are passive during modes 1,2, and 3 and as such require only position indication testing. However, full stroke and stroke time testing are required during cold shutdowns and refueling outages if the ADHRS is placed in service. Operational readiness will be venfied by performing the altemative testing below.

Attornative Testina:

ADHRS valves E12F066A and F0668 shall be exercised within 30 days prior to retum of the system to operable status (OM Part 10,4.2.1.7) and every 3 months during ADHRS operation (OM Part 10, 4.2.1.1).

l

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 22 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E12 08 System / Component Catenory ,QJiggg E12F416 C 2 Function:

Closed to provide code boundary restoration of ECCS piping during periods when the Alternate Decay Heat Removal System (ADHRS) is in operation.

Code Reduirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that venfies obturator travel to the closed, full-open or partially open position required to fulfill its function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

The Ailernate Decay Heat Removal System is out of service when the plant is in modes 1,2, and 3.

Therefore, valve E12F416 is not required to be operable during modes 1,2, and 3. However, full-stroke testing is required during cold shutdowns and refueling outages if the ADHRS is placed in service. Operational readiness will be verified by performing the attemative testing below.

Alternative Testinn:

Valve E12F416 shall be exercised within 30 days prior to retum of the system to operable status (OM Part 10,4.3.2.5) and every 3 months during ADHRS operation (OM Part 10, 4.3.2.1).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 23 OF 51 COLD SHUTDOWN JUSTlFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E2101 System / Component Cateaory Class E21F006 C,A 1 Function:

Open for LPCS discharge to Reactor Vessel; Close for containment isolation; Close for RCPB high-low pressure boundary isolation.

.Qade Reaulroments: ,

~

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as '

provided by OM Part 10, 4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part ,

10,4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to fulbstroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)).

Justification:

During plant operation, check valve E21F006 is subjected to reactor coolant system pressure on the downstream side which makes partial and full stroke exercising both with flow and with the test actuator impracticable. The LPCS pump discharge pressure is insufficient to open the check valve against full reactor pressure; the test actuator will not lift the check valve disk against full reactor pressure. UFSAR Sections 6.3.4.2.3 and 6.3.4.2.4 Indicate tnat (flow) testing of the injection line portions of th6 system is to be performed witn the reactor shutdown to prevent unnecessary thermal stresses. Therefore, E21F006 fulLatroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c) and 4.3.2.2(c).

ANemative Testina:

Fulbstroke exercise valve E21F006 during cold shutdowns per OM Part 10, 4.2.1.2(c) and 4.3.2.2(c).

l

PROGF.AM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 24 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN sUSTIFICATION NO.: CJ E2102 System / Component Catenorv ,Q,lge E21F005 A 1 Function:

Open for LPCS injection to Reactor Vessel; Close for containt,1ent isolation; Close for RCPB high low pressure boundary isolation Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5 and 4.2.1.7. If exercising is not practicable during plant l operation, it may be limited to full stroke exercising during cold shutdowns (OM Par 110,4.2.1.2(c)). I Justification:

I During plant operation, downstream check valve E21F006 is subjected to reactor coolant system pressure on its downstream side. Upstream LPCS Injection Shutoff Valve, E21F005, is isolated from ;

reactor pressure only by E21F000. During plant operation the lower pressure rated piping upstream ,

of E21F005 is protected by normally closed valves E21F005 and E21F006. Pressure sensing !

instrumentation is provided to monitor pressure between the check valve and the injection shutoff valve to prevent opening the injection valve above a sensed pressure of 6pproximately 500 psig, also providing protection for the low pressure upstream piping. Should E21F006 leak dunng plant operation, testing of shutoff valve E21F005 would be precluded without venting the piping section between valves E21F006 and E21F005. Venting is censidered impracticable due to personnel hazard and ALARA considerations from venting high pressure contaminated fluid to open drains.

Depending upon the magnitude of the leakage, repressurization may occur such that testing wo;ld be precluded. Therefore, E21F005 full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Alternative Testina:

Full-stroke exercise valve E21F005 during cold shutdowns per Oies art 10,4.2.1.2(c).

i l ,._ . - . , , . _ _ _

l l

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 25 OF Si j COLD SHUTDOWN JUSTlFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E22 01 System / Component Catenorv ,Q,1 gag E22F005 C.A 1 Function: -

Open for HPCS Injection to Reactor Vessel; Close for Containment /Drywell isolation; Close for RCPB l high low pressure boundary isolaton Code Roo'uirementst Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10, 4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfios obturator travel to the closed, full open, or partially open position required to fulfill its function (OM Part 10, 4.3 0.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is noi practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)).

Justification: '

E22F005 is a testable check valve located in the High Pressure Core Spray injection piping inside the drywell. During plant operation, check valve E22F005 is subjected to reactor coolant system pressure on the downstream s!de. Therefore, full stroke exercising with the test actuator is impracticable. Full stroke exercising with flow is also impracticable, since pumping cold water into the reactor vessel during operation would cause undesirable thermal stresses, affect reactivity due to moderator temperature changes such that a reactor scram may occur, and would result in severe level swings that may also result in a reactor scram. Additionally, maximum required accident condition flow cannot be achieved with the reactor pressure greater than approximately 200 psig.

Therefore, full stroke exercising of this valve is deferred to cold shutdowns as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Alternative Testina:

Full stroke exercise valve during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 26 OF 51 COLD SHUTDOWN JUSTlFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E32 01 System / Component Catenorv gang )

E32F001A A 1 E32F001E A- 1 E32F001J A 1 !

E32F001N A 1 I E32F.002A B 2 E32F002E B 2 ,

E32F002) B 2 E32F002N 8 2 ,

E32F006 B 2 R32F007 B 2 ,

E32F008 8 2 E32F009 8 2 l

i I

, , , - . , - - - . . , - . . - - . . - . , . - . . ,. . . , , . - . . . , , . - . . ~ . . . . - . . . - - - _ . -

PROGRAM PLAN NO GGNS M-189.1 REVISION NO. 8 PAGE NO. 27 OF S1 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E32 01 Function:

(F001 A, E, J. N): Close (active) rranually or remain closed (passive) to provide containment isolation; Open (active) automatically, with permissives, after manual MSIV LCS initiation to provide for f

depressurization and long term bleed off downstream of the inboard MSIV; Close (active) automatically or remain closed (passive) to provide for system protection and limit release to the ;

environment.

(F002A, E, J. N): Open (active) automatically, with permissives, after manual MSIV LCS initiation to :

provide for depressurization and long te. ,e bleed-off downstream of the inboard MSIV; Close (active) or remain closed (passive) to provide for system protection and limit release to the environment.

(F006, F007): Open (active) automatically after manual MSIV LCS initiation and control system permissives satisfied to process MSIV leakage;. Close (active) or remain closed (passive) if control system permissives are not satisfied for system protection and limit release to the environment.

(F008, F009): Open (active) automatically after manual MSIV LCS initiation and control system permissives satisfied to depressurize the steam line downstream of the outboard MSIV; Close (active) automatically after steam line depressurization; Close (active) or remain closed (passive) to limit release to the environment.

Code Reaulroments:

. Active Category A and Category B valves shall be tested nominally every 3 months (OM Part 10, 4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1,7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.2.1.2(c)).

Justification:

The GGNS UFSAR, in section 6.7.1,

Main Steam isolation Valve Leakage Control System (MSIV.

LCS)", states that these valves are not to be tested during power operation in order to preclude the inadvertent dumping of radioactive steam due to equipment malfunction or operator error. In aMtion to the UFSAR statement, failure of these valves in the opon position, or gross leakage through the valves as a result of improper reseating, would highly contaminate the Auxiliary Building atmosphere. Contamination of the building atmosphere would pose substantial personnel radiation hazards and would al7 create a challenge to another safety system, i.e., the Standby Gas Treatment System.

Alternative Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO 8 PAGE NO. 28 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E38-01 System / Component Catenory fdut I E38F001A B 2 ;

E38F0018 8 1 Function:

Open for FWLC injection, close to isolate low pressure RHR and FWLC piping from feedwater pressure.

Code Reauirements: ,

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as !

provided by OM Part 10,4.2.1.2, 4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

System interlocks prevent opening F001 A and F001B except when feedwater line pressure is below set pressure (approximately 33 psig), and 821F065A and 821F0858 are closed (affects F001 A only).

During power operation, the interlocks cannot be satisfied, therefore, full-stroka exercising of F001 A and F0018 is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Alternative Testinni Full stroke exercise valves during cold shutdowns pc OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 29 OF S1 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E38-02 System / Component Cateaory Class E38F002A C 1 E38F0028 C 1 E38F003A C 2 E38F0038 C 2 Function:

Open for FWLC injection. Close on reverse flow to provide overpressure protection and prevent cross flow from one feedwater line to the other.

Code Reauirements:

Check valves shall be exereir. ' nominally every 3 months (OM Part 10,4.3.2.1) except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2 4, and 4.3.2.5. During ooeration eech check valve shall be exercised or examined in a neanner that venfies obturator travel to the full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.2(a)). As an alternative to the testing in OM Part 10,4.3 2.4(a) or 4.3.2.4 (b), disassembly every refuel:ng outage to venfy operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

Dunng power operation, these valves are held closed by feodwater pressure on the downstream side making full-stroke or part stroke open exercising impracticable. Additionally, system design does not provide adequate instrumentation or test connections for measuring flow through the valves, even dunng cold shutdowns. These valves are located in the main steam tunnelin the auxiliary building, which is a high radiation area and is inaccessible during power operation. Testing these valves in the closed diroction requires personnel access and can be performed only during shutdown conditions.

The valves are capable of being exercised closed and partially open during cold shutdowns, when the feedwater system is depressurized and the valve location is accessible.

Alternative Testina:

Exercise each valve closed and perform a partial-flow open test for each valve during cold shutdowns. These valves will receive disassemby testing on a sampling basis as desenbed in R3 fueling Justification RJ-E38-01.

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 30 OF 51 COLD SHUTDOWN JUSTIFICATIONS i COLD SHUTDOWN JUSTIFICATION NO.: CJ ES101 !

System / Component Catenory fdagg E51F063 A 1 E51F064 A 1 Function:

Open for RCIC operation; Close for containment isolation and for RCPB isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1,7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,42.1.2(c)).

Just6fication:

E51F063 and F064 are RCIC steam supply isolation valves. F063 is located in the drywell and F064 ,

is located in the steam tunnel, both of which are high radiation areas during power operation. Failure of either valve in the closed position would isolate the supply of steam to the RCIC turbine and result in a loss of system function. Plan' *.hutdown would be required by Tech Specs if repairs could not be made. Therefore, full stroke exercising of these valves is deferred to cold shutdowns as permitted by OM Part 10, 4.2.1.2(c).

AMernative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M 189.1 I REVISION NO. 8 PAGE NO. 31 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ E5102 System / Component Cateaory Class E51F065 C,A 2

iction

Open for RCIC flow to reactor vessel. Close for RCPB hl/ low pretsure boundary.

Code Reaulrements:

Check valves shall be exercised nominally every 3 months in a manner that venfies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.1, 4.3 2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.3.2.2(c)). For valves in a system declared inoperable or not required to be operable, the exercising test schedule need not be followed. If the test schedule is not followed, the valves shall be exercised within 3 months prior to placing the system in an operable status. (OM Part 10, 4.3.2.5). From that time forward, the schedule shall be followed.

Justification:

E51F065 is a check valve in the RCIC vesselinjection piping. To test this valve ret.,;res RCIC injection into the vessel which is impracticable dunng normal power operation oecause of the thermal stress to RCIC and feedwater piping and the effects on moderator temperature and reactivity.

Therefore, full-stroke open exercising of E51F065 is deferred to cold shutdown as permitted by OM Part 10, 4.3 2 2(e), and is to be performed during start-up from cold shutdown when the reactor is at a relatively low power level and nuclear steam is available to the RCIC turbine at a pressure of 150

(+ 15, -0) psig.

Alternative Testina:

Full-stroke open exercise valve E51F065 dunng start-up from cold shutdown when nuclear steam is available to ths RCIC turbine at a pressure of 150 (+15, -0) psig. The testing schedule is re-established following each refueling outage since the system has been out of service due to the lack of steam supply.

Valve is tested to the close position quarterly.

i PROGRAM PLAN NO. JGNS M 189.1 REVISION NO. 8 PAGE NO. 32 OF 51 ;

COLD SHUTDOWN JUSTIFICATIONS l COLD SHUTDOWN JUSTlFICATION NO.: CJ G33 01 System / Component Catenorv fdagg G33F001 A 1 G33F004 A 1 G33F039 A 2 G33F040 A 2 G33F053 A 2 G33F054 A 2 G33F252 A 1 Func+ ion:

Close for containment isolation (all) and SLC actuation (F001, F004).

Code Reauirements:

Active Category A valves shall be it sted nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4 2.1.5, and 4.2.1.7, if exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

The Reactor Water Cleanup System is in continuous service (post pump mode above 550 degrees F reactor coolant temperature) during normal plant operation for the purpose of maintaining reactor coolant chemistry within specified limits as required by Technical Specification 3.4.4. The system would be required to be removed from service in order to test these valves, creating the potential for exceeding coolant chemistry firnits. Therefore, full stroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Alternative Testina:

Full stroke exercise valves during cold shutdown per OM Part 10,4.2.1.2(c).

l.

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 33 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-G33-02 .

System / Component Catenory gnag G33F250 B 1 G33F251 B 1 G33F253 8 2 Function:

Close for drywell isolation (all) and SLC actuation (F250). ,

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification: i The Reactor Water Cleanup System is in continuous service (post pump mode above 350 degrees F reactor coolant temperature) during normal plant operation for the purpose of maintaining reactor coolant chemistry within specified limits as 'aquired by Technical Specification 3.4.4. The system would be required to be removed from servee in order to test these valves, creating the potential for ;

exceeding coolant chemistry limits. Therefore, full stroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c);

Alternative Testina:

Full stroke exercise valves during cold shutdown per OM Part 10, 4.2.1.2(c).

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_. . ._. _ ___ _ . _ .~. _ _ _ _ _ _ _ ._ _. . _ _ . __ __ . . _ . _

d PROGRAM PLAN NO. GGNS-M 189.1 i REVISION NO. 8 PAGE NO. 34 OF S1 .

I COLD SHUTDOWN JUSTIFICATIONS !

COLD SHUTDOWN JUSTIFCATION NO.: CJ P42-01 System / Component Catenorv ,QJagg l

P42F035 C,A 2 Function: ;

Close on reverse flow to provide containment isolation.

Code Reapirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfies obturator travel to the closed, full open, or partially open position required to fulfillits function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3 2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c) and 4.3.2.2(c)).

JustWication:

P41F035 is located in the CCW supply to the containment and drywell. Full stroke exercising this valve would require interrupting the supply of cooling water to the reactor recirculation pump motor bearings and pumps sosts and the RWCU non regenerative heat exchangers. During power operation, testing would require shutdown of both recirculation pumps and shutdown of the RWCU filter domineratlizers. With no reactor recirculation pumps in operation, Technical Specifications require reactor shutdown. Therefore, full stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Attornative Testina:

Full stroke exercise valve during cold shutdown per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

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PROGRAM PLAN NO. GGNS-M 189.1 l

REVISION NO. 8 PAGE NO. 35 OF S1 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ P42 0.2 l System / Component Category pdag P42F066 A P P42F067 A 2 P42F068 A 2 F Jnction:

Close to provide containment isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every : .ontr.s (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5 and 4.2.1.7. If exeresing is not practicable du-ing plant

, operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

P42F066 is located in the CCW supply piping and F067 and F068 are located in the CCW retum piping for the containtnent and drywell. Full stroke exercising these valves would require interrupting the supply of cooling water to the reactor recirculation pump motor bearings and pump seals and the RWCU non-regenerative heat exchangers. During power operation, testing would require shutdown of both recirculation pumps and shutdown of the RWCU filter domineralizers. With no reactor recirculation pumps in operation, Technical Specifications require reactor shutdown. Therefore, full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c).

Alternative Testina:

Full stroke exercise valves during cold shutdown per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8

PAGE NO. 36 OF Si COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ P42 03 System / Component Catenory piggg P42F115 C 2 Function:

Closes on reverse flow to provide drywell isolation.

Code Reauirements: >

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4 and 4.3.2.5. During power operation, check valves shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially

. open position required to fulfill its function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

P42F115 is located in the CCW supply piping to the drywell. Full-stroke exercising this valve would require interrupting the supply of cooling water to the reactor recirculation pump motor bearings and pump seals. During power operatir,n, loss of cooling water to the recirculation pumps would require shutdown of the pumps. With no 1 circulation pumps operating, Technical Specifications require reactor shutdown. Therefore, ful!-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.3.2.2(c).

Alternative Testina:

Full stroke exercise valve during cold shutdown per OM Part 10. 4.3.2.2(c).

l

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 37 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P42 04 System / Component Catenory gjlagg P42F114 B 2 P42F116 B 2 P42F117 B 2 Function:

Close to provide drywellisolation.

Code Renuirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2, 4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

P42F114 is located in the CCW suppl / piping and F116 & F117 are located in the CCW retum piping for the dr'mell. Full stroke exercising these valves would require interrupting the supply of cooling water to the reactor recirculation purr,p motor bearings and pumps seals. During power operation, loss of cooling water to the recirculation pumps would require shutdown of the pumps. With no recirculation pumps operating, Technical Specifications require reactor shutdown. Therefore, full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c).

Alternative Testino:

Full-stroke ev'.:icise valves during cold shutdown per OM Part 10, 4.2.1.2(c). ,

. 1 e

PROGRAM PLAN NO. GGNS-M 189.1 i REVISION NO. 8 PAGE NO. 38 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ P44-01 System / Component Catenory gli g P44F067 8 3 Function:

Provides interface between PSW and SSW systems.

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

F067 is interlocked with F068 (Auxiliary Building PSW Retum Isolation Valve) such that F068 closes as soon as F067 begins to open, and F068 cannot be reopened until F067 is full closed. Exercising F067 would result in a loss of cooling water flow through the drywell chillers which, during power operation, would cause drywell temperatJre and pressure to increase, creating the potential for a reactor scram and ECCS initiation. Therefore, exercising of F067 is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Ahernative Testina:

Full stroke exercise valve during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGRAM Pt.AN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 39 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P45-01 System / Component Cateoorv Class P45F003 B 2 P45F009 8 2 Function:

Dtywell isolation.

Code Reauirements:

Activo Category B valves shall be tested norninally every 3 months (OM Part 10,4.2.1.1), except as provided by GM Part 10,4.2.1.2,4.2.1.5 and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10, 4.2.1.2(c)).

Justitication:

F003 and F009 are normally open air-operated valves in the drywell floor drain (F003) and equipment drain (F009) sump pump discharge piping. The valves are loca+ed inside the drywell which is a high radiation area durhg power operation and is inacesssible, if, during power operation, either valve failed in the closed position, a portion of the ability to monitor reactor coolar,t system identified and/or unidentified leaka je would be lost. Valve repair would require a plant shutdown. Therefore, F003 and F009 full-stroka exercising is deferred to cold shutdown as permitted by CM Part 10,4.2.1.2(c).

Alternative Testinal Full-stroke exercise F003 and F009 dunng cold shutdown per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 40 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: Q.)-PS2-01 System / Component Catenory Class PS2F196 C 2 Function: ,

Drywell Isolation.

Code Reauirements:

Check valves shall be exercised nominally ev3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.' b. During plant operation, each check valve shall be exercised or examined in a manner that venties obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

P52F196 is a check valve in the service air supply to the drywell. This valve is located in the drywell which is a high radiation area during power operation and is inaccessible. Testing requires personnel access to the valve. Therefore, P52F196 full-stroke oxercising is deferred to cold shutdown as permitted by OM Part 10, 4.3.2.2(c).

Ahernative Testina:

Full-stroke exercise (closed) PS2F196 during cold shutdowns per OM Part 10,4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 41 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ.P53-ql System / Component Cateaory Class PS3F001 A 2 Function:

Open (passive) to provide initial stored air supply for relief valve operations. Close for containment isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

P53F001 is a containment isolation valve in the instrument air supply piping to the containment.

Exercising this vt've would isolate the supply of instrument air to various equipment including the Control Rod Drive flow control station, CRD scram valves and MSIV accumulators. Failure of the valve to re open during power operation would result in a loss of cooling water flow to the CRD's, random individual control rod scrams and, eventually, MSIVs drifting closed. A reactor scram would result. Therefore, P53F001 full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Alternative Testina:

Full-stroke exercise P53F001 dunng cold shutdowns per OM Port 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.- 42 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P53-02 System / Component Catenory gigg P"3F002 C,A 2 Function:

Open to provide initial stored air supply for relief valve operations. Close for containmant isolation. .

Code Reauirements: ,

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold thutdowns (OM Part 10,4.2.1.2(c),4.3.2.2(c)).

Justification:

P53F002 is a containment isolation check valve in the instrument air supply piping to the containment. Exercising this valve would isolate the supply of instrument air to various equipment including the Control Rod Drive flow control station, CRD scram valves and MSIV accumulators.

Failure of the valve to re-open during power operation would result in a loss of cooling water flow to the CRD's, random individual control rod scrams and, eventually, MSIV's drifting closed. A reactor scram would result. Therefore, P53F002 full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Alternative Testina:

Full-stroka exercise P53F002 during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 43 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P53-03 System / Component Cateaory gggg P53F006 C,A 2 Function:

Close for drywellisolation/ containment isolation. Open for resupoly of ADS air receivers and initial stored air supply for relief valve operations.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c),4.3.2.2(c)).

Justification:

P53F006 is a check valve in the instrument air eupply piping to the ADS receivers. This valve is located in the drywell which is a high radiation area during power operation and is inaccessible.

Testing requires personnel access to the valve and to a test connection downstream of the valve.

Therefore, P53F006 full-stroke exercising is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c) and 4 A.2.2(c).- Valve open function can be continuously monitored via ADS air receiver low pressure annunciation and control room indication of receiver pressure.

Attornative Testina:

Full-stroke exercise P53F006 during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

1 PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 44 OF 51' COLD SHUTOOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-PbJ-04 System / Component Catenorv glagg P53F007 B 2 Function:

Open (passive) to provide initial stored air supply for relief valve operations. Close for drywell isolation.

Code Reauirements:

Active category B valves are to be tested nominally every 3 months (OM Part 10,4.2.1,1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

P53F007 is a motor operated valve in the instrument air supply piping to the drywell, supplying air to the MSIV accumulators, SRV accumulators (non-ADS), ECCS testable check valves, and drywell floor and equipment drain sump discharge valves. Full-stroke exercising of this valve would isolate the air supply to the listed equipment. Failure of the valve to re-open during power operatic,.1 would result in a reactor scram due to MSIV's closing by spring force and steam fitw assist as the accumulators bled down. Also, the ability to transfer water from the drywell sumps and monitor leakage would be lost, as well as the power operation function of the non-ADS SRV's (after accumulators bled down). Therefore, P53F007 full stroke exercising is deferred to cold shutdowns as permitted by OM Part 10, 4.2.1.2(c).

Ahernative Testina:

Full stroke exercise P53F007 duing cold shutdowns per OM Part 10,4.2.1.2(c).

1:

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y y;,-.=---s,~ 'w.. .,-' . .

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 4b OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P53-05 System / Component Cateoory Class PS3F008 C 2 Function:

Open to provide initial stored air supply for relief valve operations. Close for drywell isolation.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

P53F008 is a check valve in the instrument air supply piping to the drywell. This valve is located in the drywell which is a high radiation area during power operation and is inaccessible. Testing requires personnel access to the valve. Therefore, P53F008 full-stroke excercising is deferred to cold shutdowns as permitted by OM Part 10,4.3.2.2(c).

Alternative Testina:

Full-stroke exercise P53F008 during cold shutdowns per OM Part 10,4.3.2.2(c).

f

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 -

PAGE NO. 46 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ P7101 jy3 tem / Component Cateaory Class P71F151 C,A 2 Function:

Containment isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c),4.3.2.2(c)).

Justification:

P71F151 is a normally open check valve in the plant chilled water supply to the containment cooling fan units. Exercising this valve would require interruption of the flow of cooling water to the containment cooling fan units which, during power operation, could significantly increase the temperature inside containment. This creates the potential for a plant shutdown to prevent exceeding the qualified temperature of equipment inside containment. Therefore, P71F151 full-stroke exercising is deferred to cold shutdowns as permitted by OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

Alternative Testina:

Full-stroke exercise valve during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 47 OF St COLD SHUTDOWN JUSTlFICATIONS l

l l

COLD SHUTDOWN CSTIFICATION NO.: QJ P72 01 System / Component Cateoory Class P72F121 A 2 P72F122 A 2 P72F123 A 2 Function:

Containment isolation.

Code Reauirements:

Active Category A valves shall be tested nomina!Iy every 3 months (OM Part ), 4.2.1.1), except as

.tvided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not ,'v s during plant operation, it may be limited to full-stroke exercising during cold shutdowns (Un. . t 10, 4.2.1.2(c)).

Justification:

P72F121 is a normally open valve in the Drywell Chilled Water System supply piping to the steam tunnel and drywell coolers. P72F122 and F123 are normally open valves in the return piping from the same areas. Full stroke exercising any of these valves would interrupt the flow of chilled water which, during power operation, would cause drywell temprature! pressure to increasa and steam tunnel temperature to increase, creating the potential for a reactor scram cnd ECCS initiation.

Therefore, full-stroke exercising these valves is deferred to cold shutdown as permitted by OM Part 10, 4.2.1.2(c).

Alternative Testino:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

l l

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 48 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P72-02 System /ComDonent CateQory Class P72F124 B 2 P72F125 B 2 P72F126 B 2 Function:

Drywell Isolation.

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited ia full-stroke exercisirig during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

P72F124 is a normally open valve in the Drywell Chilled Water System Suoply piping to the drywell coolers. P72F125 and F126 are normally open valves in the retum piping from the drywell. Full-stroke exercising any of these valves would interrupt the flow of chilled water which, during power operation, would cause drywell temperature / pressure to increase, creating the potential for a reactor scram and ECCS initiation. Therefore, full-stroke exercising these valves is deferred to cold shutdown as permitted by CM Part 10,4.2.1.2(c).

Alternative Testina:

Full stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 49 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-P72-03 System / Component Catsoorv Class P72F147 C 2 Function:

Drywellisolation.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2, 4.3.2.3,4.3.2.4 and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partically open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not pract4 Jie during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)).

Justification:

P72F147 is a normally open check valve in the Drywell Chilled Water System supply piping to the dryw',il coolers. Full-stroke exercising this valve would require interruption of the flow in chilled water whi,:h, during power operation, would cause drywell temperature /presure to increase, creating the potential for a reactor scram and ECCS initiation. Therefore, fullatroke exercising this valve is deferred to cold shutdown as permitted by OM Part 10,4.3.2.2(c).

Alternative Testina:

Full-stroke exercise valve during cold shutdowns per OM Part 10,4.' 2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 50 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ P72-04 System / Component Cateaory Class P72F165 C,A 2 Function:

Containment Isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10, 4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c),4.3.2.2(c)).

Justification:

P72F165 is a normally open check valve in the Drywell Chilled Water System supply piping to the drywell coolers and steam tunnel cooler. Full-stroke exercising this valve would require interruption of chilled water flow which, during power operation, would cause drywell temperature / pressure and steam tunnel temperature to increase, creating the potential for a reactor scram and ECCS initiation.

Therefc.e, full-stroke exercising this valve is deferred to cold shutdown as permitted by OM Part 10, 4.2.4.2(c) and 4.3.2.2(c).

d'ternative Testina:

Full stroke exercise valve during cold shutdowns per OM Part 10,4.2.1.2(c) and 4.3.2.2(c).

PROGRAM PLAN NO. GGNS-M-189.1 ,

REVISION NO. 8 i PAGE NO. 51 OF 51 COLD SHUTDOWN JUSTIFICATIONS COLD SHUTDOWN JUSTIFICATION NO.: CJ-Z51-01 System / Component Cateaory Class l Z51F007 8 3 251F016 B 3 l Function:

Close on control room isolation. Open (manually) following control room isolation aher time delay to :

revitalize atmosphere.

Code Reauirements:

Active Category B valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10,4.2.1.2(c)).

Justification:

The system design is such that, if either F007 or F016 are not fully closed, both standby fresh air units must be declared inoperable (SOI 04-S-01-Z51-1). These valves are designed to be manually opened and closed post accident (after a time delay) and must be closed at all other times to ensure the ability to isolate the control room. F007 and F016 are interlocked such that they cannot be opened unless the associated standby fresh air unit recirculation fan is running. When F007 or F016 ,

begin to open, the respective recirculation intake damper receives a signal to close. Considering a coincident loss-of offsite-power and the single failure of a division of ESF power during this evolution, l the associated recirculation fan would stop, and the recirculation damper on that train could be partially open with the standbv esh air valve partially closed. In this scenario, an unfiltered inleakage path to the control room woud r cist. GGNS Technical Specifications require the emergency filtration subsystems to be operable in all operational conditions. Since there is no time during which this system is not required to be operable, testing must be performed to appropriately minimize the consequences of potential accidents Therefore, the only practical time to perform valve stroke surveillances is during cold shutdown conditions as permitted by OM Part 10,4.2.1.2(c). Testing may also be scheduled during refueling outages for periods when core alterations, handling of irradiated fuelin the primary or secondary containments, and operations with a potential for draining the reactor vessel are suspended. Under these circumstances, design basis accidents and abnormal operational transients are not deemed credible, and the risks associated with an inoperable filtration system are negligible.

Alternative Testina:

Full-stroke exercise valves during cold shutdowns per OM Part 10,4.2.1.2(c). If any testing is performed during refueling outages, the testing will be scheduled such that it occurs when core alterations, handling of irradiated fuelin the primary or secondary containments, and operations with a potential for draining the reactor vessel have been suspended.

t PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.1 OF.12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ-821-01 -

System /Comnonent Cateoory Class B21F010A C,A 1 B21F0109 C,A 1 B21F032A' C,A 1 B21F0328 C,A 1 Function:

Open for flow to vessel (RCIC (F010B, F0328), RHR Altemate Shutdown Cooling and Feedwater Leakage Control). Close for containment isolation.

Code Reauirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that venfies obturator travel to the closed, full-open, or partially open position required to fulfillits function (OM Part 10,4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke exercising during refueling outages (OM Part 10, 4.2.1.2(e) and 4.3.2.2(e)).

Justification.1 Full-stroke exercising these valves closed would require stopping all flow to the vessel through the valve being tested. Since these lines complete the flow path to the vessel for feedwater, shutdown cooling mode of the Residual Heat Removal system, Reactor Core Isolation Cooling system and Reactor Water Cleanup system, it is necessary to maintain an open flow path in virtually all modes of plant operation. Only during extended outages such as refueling is it practicable to stop flow to the vessel through these valves. Leak rate testing of the valves during refueling outages, as required for the containment isolation function, provides assurance of the valves' ability to close and seat tightness. The valve's ability to full-stroke open can be verified during startup following refueling or during operation of RHR at full flow in the Shutdown Cooling Mode, after the valve has been tested to the closed position.

Alternative Testina:

Full-stroke exercise the valves to the open position during startup following refueling or during operation of RHR at full flow in the Shutdown Cooling Mode, after the valve has been tested to the closed position.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 2 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ C11-01 System / Component Cateoory Class C11F083 A 2 Function:

Close for containment ! solation.

Code Reabirements:

Active Category A valves shall be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke exercising during refueling outages (OM Part 10, 4.2.1.2(e)).

Justification:

F083 is a normally open valve in the CRD drive water supply piping to the containment. Exercising this valve would interrupt the supply of drive water and cooling water to the control rod drive hydraulic control units (HCUs) and the supply of sealinjection water to the reactor recirculation pumps, resulting in potential equipment damage if tested during power operation. Additionally, the test cannot be performed during each cold shutdown since at least one of the reactor recirculation pumps is usually kept running. Therefore, F083 full-stroke exercising is deferred to refueling outages as permitted by OM Part 10, 4.2.1.2(e).

Alternative Testina:

Full-stroke exercise valve during each refueling outage per OM Part 10,4.2.1.2(e).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 3 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ-C11-02 System / Component Cateaory Class C11F122 C,A 2 ,

Function:

Close on reverse flow for containment isolation.

Code Reauirements:

Active Category A valves shril be tested nominally every 3 months (OM Part 10,4.2.1.1), except as provided by OM Part 10,4.2.1.2,4.2.1.5, and 4.2.1.7. Check valves shall be exercised nominally every 3 months in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfillits function e(OM Part 10,4.3.2.1,4.3.2.2(a)), except as provided by OM Part 10,4.3.2.2, 4.3.2.3, 4.3.2.4, and 4.3.2.5. If exercising is not practicable during plant operation or cold shutdowns, it may be limited to t'ull-stroke exercising during refueling outages (OM Part 10, 4.2.1.2(e), and 4.3.2.2(e)).

Justification:

F122 is a normally open stop check valve in the CRD drive water supply piping to the containment.

Exercising this valve would require an interruption of dnve water and cooling water flow to the control rod drive hydraulic control units (HCUs) and seal injection water flow to the reactor recirculation pumps, resulting in potential equipment damage if tested during power operation. Additior. ally, the test cannot be performed during each cold shutdown since at least one of thc .cactor recirculation pumps is usually kept running. Therefore, F122 full-stroke exercising is deferred ti. refueling outages as permit *ed by OM Part 10, 4.2.1.2(e).

Alternative Testina:

Full-stroke exercise valve during each refueling outage per OM Part 10,4.2.1.2(e).

1 I

1

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 4 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: fMQ_1103 System / Component Cateaorv 91333 i C11-114 C 2 Function:

Open to allow flow frorn CRD overpiston area to SDV.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)). If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full stroke exercising during refueling outages (OM Part 10,4.3.2.2(e)).

Justification:

These valves are found on each of 193 control rod drive hydraulic control units. The scram dischargo header check valves are required to open to allow flow l rom the control rod drive overpiston area to the scram discharge volume. Because of the short duration of the control rod scram function (typically apprcximately 2 seconds or less), it is impractical to directly determine the valve position during the evem or to measure flow rate through the valve, and actual required flow rate is not known. Verifying that the associated control rod meets the scram insertion time limits specified in the Technical Speci'ications can be used to detect degradation of these valves. Any variation in the operability of a'iy valve will be detected by the testing currently required by GGNS Technical Specifications. The altemative testing specified meets the requirements of Position 7 of Generic Letter 89-04.

Alternative Testina:

Scram testing and control rod insertion timing will be performed in accordance with GGNS Technical Specifications (reactor coolant pressure greater than or equal to 950 psig and, during single control rod scram time tests, the control rod drive pumps isolated from the accumulators) which will verify proper operation of the 114 valves:

a. For all control rods prior to thermal power exceeding 40% of rated thermal power following core alterations or after a reactor shutdown that is greater than 120 days (SR 3.1.4.1),

b. Prior to exceeding 40% of rated thermal power, for specific individual control rods following maintenance on or modification to the control rod or control rod drive system which could affect scram time (SR 3.1.4.4), and

c. For a representative sample of control rods, at least once per 120 days of operation in Moda 1 (SR 3.1.4.2).

d) For specific individual control rods follOwing maintenance on or modification to the control rod or control rod drive system which could affect scram insertion time, prior to declanng the control rod operable and at any reactor steam dome pressure (SR 3.1.4.3).

PROGRAM PLAN NO. GGNS-M489.1 REVISION NO. 8 PAGE NO. 5 OF 12 REFUELING JUSTlFICATIONS REFUELING JUSTIFICATION NO.: RJ-C4101 System / Component Cateoorv Class C41F006 C 1 C41F007 C 1 C41F222 C 1 Function:,

Close for Drywell isolation (F006, F007); System isolation (F222). Open for injection (All)

Code Requirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2,2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)). If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke exercising during refueling outages (OM Part 10,4.3.2.2(e)).

Justification:

F006, F007 and F222 are stop check valves located in the SLC system injection line downstream of the squib (explosive) valves. F006 is located in containment and F007 & F222 are located ir. the drywell. All three valves are normally closed. F006 and F007 have active safety functions in both the closed and open positions and F222 has an active open function only. Exercising the valves to the full-open position is accomplished by initiating SLC system injection through the valves and venfying the required flow rate. This requires firiag of the squib valves and their subsequent replacement.

Valves F006 and F007 are tested closed after SLC injection testing by non-intrusive examination methods (e.g. radiography) to ensure that the disks are on their seats. Because these valves can only be full-stroke open tested by SLC initiation which will fire the squib valves and inject demineralized water, full stroke open and close exercising is deferred to refueling as permitted by OM Part 10, 4.3.2.2(e).

Alternative Testino:

Full-stroke exercise these valves during refueling per OM Part 10,4.3.2.2(e) by performing SLC injection testing as required by the GGNS Technical Specifications. Test valves in the open position by verifying the required flow rate is achieved through the valves. Test valves in the close position by non-intrusive examination methods (e.g., radiography) after injection testing.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 6 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ-E30-01 System / Component Cateoorv Class E30F003A C 2 E30F003B C 2 Function:

Open to prevent hydraulic locking of dump valves.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that venfies obturator travel to the closed, full-open or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)). If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke exercising during refueling outages (OM Part 10,4.3.2.2(e)).

Justification:

There are no test connections or isolation valves available for testing these valves in the open direction. These stop check valves can only be full-stroke tested in the open direction by disconnecting a flange upstream from each check valve and injecting air, nitrogen or water to cause the disc to open. When the flange is disconnected, there is only single-valve isolation from the upper containment pool. In addition, if the check valve were to stick in the open position, there would be an unisolable drain from the upper containment pool. The upper containment poolis required by GGNS Technical Specification to be maintained full during power operation. Due to the ILrge volume of potentially-contaminated water in the upper containment pool, it is not practicable to drain the upper containment pool below the dump line intakes, except during refueling outages.

Alternative Testino:

Both of these valves will be exerciseo to the open position only during refueling outages as allowed by OM Part 10, 4.3.2.2 (e). Nca-intrusive Testing (NIT) techniques, such as acoustic monitoring and analysis, ultrasonic monitoring, radiography, etc. will be used to verify that the check valve discs open fully during full-stroke testing.

1 PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 7 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ-E38-01 System / Component Cateaory CID.1 E38F002A C 1 E38F002B C 1 E38F003A C 2 E38F,003B C 2 Function:

Open for FWLC injection. Close on reverse flow to provide overpressure protect!on and prevent cross flow from one feedwater line to the other.

Code Reautrements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open or partially open position requ;.ed to fulfill its function (OM Part 10,4.3.2.2(a)). If exercising is not practicable during plant operation, it may be limited to full-stroke exercising during cold shutdowns (OM Part 10, 4.3.2.2(c)). If exercising is not practicable during plant operation or cold shutdowns, it may be limited to full-stroke exercising during refueling outages (OM Part 10,4.3.2.2(e)). As an attemative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4(b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

During power operation, these valves are held closed by feedwater pressure on the downstream side making full stroke or part-stroke open exercising impracticable. Additionally, system design does not provide adequate instrumentation or test connections for measuring flow through the valves, even during cold shutdowns. These valves are located in the main steam tunnel in the auxiliary building, which is a high radiation area and is inaccessible during power operation. Testing these valves in the closed direction requires personnel access and can be performed only during shutdown conditions.

The valves are capable of being exercised closed and partially open during cold shutdowns, when the feedwater system is depressurized. NRC Generic Letter 89-04, Position 2 recognizes check valve sample disassembly and inspection as an acceptable attemative testing method when full-stroke exercising is not practicable. Therefore, these valves are to be tested under a sample disassembly and inspection program that meets the requirements of Generic Letter 89-04, Position 2, for full-stroke open exercising as addressed in Relief Request VRR-GEN-01.

Alternative Testina:

These valves receive a partial-stroke test at cold shutdowns as described in CJ-E38-02.

Disassemble one valve every refueling outage per the requirements of Relief Request VRR-GEN-01 Perform a partial-flow test for any disassembled valve after reassembly.

2

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 8 OF 12 REFUELING JUSTlFICATIONS REFUELING JUSTIFICATION NO.: RJ-E5101 System / Component Cateaorv plagg E51F079 C 2 E51F081 C 2 Function:

Open to break vacuum resulting from steam condensation in the RCIC turbine exhaust line. Close to prevent exhausting steam directly to containment atmosphere.

Code Reauirementti Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). As an alternative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4 (b), disassembly every refueling nutage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

E51F079 and F081 are check valves (vacuum breakers) attached to the RCIC turbine exhaust line.

There are no installed flow measuring devices in the line and no flow p dh exists that can be used to pass flow through the valves for testing purposes. The valves can, however, be partial-stroke open exercised every 3 months. Therefore, these valves are to be partial-stroke exercised every 3 months and tested by disassembly every refueling outage as permitted by OM Part 10,4.3.2.4 (c).

Alternative Testino:

Verify closed and partial-stroke open exercise each valve every 3 months and following each disassembly. Disassemble one of the valves every refueling outage in accordance with guidance in Relief Request VRR-GEN-01.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 9 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ E5102 System / Component Cateaory _C_lagg E51F030 C 2 Function:

Open to provide RCIC pump suct:on from suppression pool. Close to prevent flow path from CST to suppression pool during suction transfer.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.2(a)). As an altemative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4 (b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

E51F030 is a check valve in the RCIC suction piping from the suppression pool. This valve can be close and partial-stroke open tested every 3 months. Since system design does not provide a RCIC test retum line to the suppression pool, full flow testing of this valve would require pumping " dirty" water from the suppression pool into either,1) the reactor vessel which, during power operation would cause thermal stresses to RCIC and Feedwater piping, and would adversely affect moderator chemistry, temperature and core reactivity or,2) into the condensate storage tank (CST), thereby contaminating the relatively clean water in the CST. The RCIC minimum flow line which retums to the suppression pool does not have the capacity for full flow testing. Therefore, this valve is to be close tested and partial-stroke open tested every 3 months. Full stroke open testing is to be accomplished by disassembly every refueling outage as permitted by OM Part 10,4.3.2.4(c).

Alternative Testina:

Close and part-stroke open exercise valve every 3 months. Disassemble valve every refueling outage per OM Part 10, 4.3.2.4(c).

i 1

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.10 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ-G33-01 System / Component Cateaory Class G33F052A C 2 G33F052B C 2 Function:

Close on reverse flow to allow proper operation of FWLC. Close on reverse flow to prevent the diversion of RCIC flow into the 'A' feedwater line (F0528 only).

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4,3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfillits function (OM Part 10,4.3.2.2(a)). As an altemative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4 (b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justificationn G33F052A and B are check valves located in parallel pipes which retum RCWU v'"er to the vessel via the main feedwater lines. Testing either of these valves during power operatit * 'ould require a signif,00 > reduction in reactor power to allow each feedwater line to be individually removed from service. Additionally, these valves are located in the main steam tunnel which is a high radiation area during power operation and is inaccessible. System design does not provide adequate test connections to test these valves individually, therefore, valve testing is to be accomplished by disassembly every refueling outage as permitted by OM Part 10,4.3.2.4(c)

Alternative Testina:

Disassemble both valves every refueling outage per OM Part 10,4.3.2.4(c).

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.11 OF 12 REFUELING JUSTIFICATIONS REFUELING JUSTIFICATION NO.: RJ P41-01 System / Component Qat,gg_ry pjgg P41F174 C 3 Function:

Close on reverse flow to pavent flow of SSW into TBCW.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partially open position required to fulfill its function (OM Part 10,4.3.2.2(a)). As an attemative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4 (b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

F174 is a check valve in the SSW/TBCW interface piping from the plant air compressors. Exercising the valve to the closed position would isolate the flow of cooling water through the compressors, resulting in increased temperatures and equipment trips with potential damage to the compressors.

The only plant conditions which allow shutdown of the compressors with minimal plant impact is during refueling outages. Therefore, valve testing is to be accomplished by disassembly every refueling outage as permitted by OM Part 10,4.3.2.4(c).

Alternative Testina:

Disassemble valve every refueling outage per OM Part 10,4.3.2.4(c).

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO.12 OF 12 REFUELING JUSTlFICATIONS REFUELING JUSTIFICATION NO.: RJ-P44-01 l

System / Component Catenory gggg P44F052 -C 3 Function:

Close to prevent flow of SSW into PSW.

Code Reauirements:

Check valves shall be exercised nominally every 3 months (OM Part 10,4.3.2.1), except as provided by OM Part 10,4.3.2.2,4.3.2.3,4.3.2.4, and 4.3.2.5. During plant operation, each check valve shall be exercised or examined in a manner that verifies obturator travel to the closed, full-open, or partially

open position required to fulfill its function (OM Part 10,4.3.2.2(a)). As an attemative to the testing in OM Part 10,4.3.2.4(a) or 4.3.2.4 (b), disassembly every refueling outage to verify operability of check valves may be used (OM Part 10,4.3.2.4(c)).

Justification:

F052 is a check valve in the SSW/PSW cross-tie piping. Exercising the valve would require a shutdown of the PSW system, resulting in a loss of cooling water flow to various equipment including drywell chillers and containment chillers. During plant operation, a shutdown of the drywell chillers would result in elevated drywell temperature and pressure which creates the potential for a reactor scram and ECCS initiation. Additionally, system design does not provide adequate instrumentation or test connections for verifying obturator position. Therefore, valve testing is to be accomplished by disassembly every refueling outage as permitted by OM Part 10,4.3.2.4(c).

Alternative Testino:

Disassemble valve every refueling outage per OM Part 10,4.3.2.4(c).

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 1 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-821-01 System: B21 Nuclesr Boiler System Component: 821F501AA B21F501 AB B21F501BA B21F501BB B21F501CA B21F501CB B21F501DA B21F501DB B21F502AA B21F502AB B21F502BA B21F502BB B21F502CA B21F502CB B21F502DA B21F502DB Catenorv: B Class: A Function: Close to v6,1t air from MSIV actuator, allowing MSIV to close.

Detailed Discussion:

B21F501's and F502's are solenoid valves which control MSIV B21F022A-D and B21F028A-D operation. Both the F501 and F502 valves associated with an MSIV must be deenergized for the MSIV to fast close. The solenoid valves do not have position indication and system design does not provide for testing tro valves individually. Therefore, these valves cannot be tested unless plant conditions allow MSIV operation. As discussed in Cold Shutdown Justification CJ-821-01, the MSIVs are tested during start-up from cold shutdown. Degradation of the F501s and F502s would affect the associated MSIV stroke time, therefore, measuring MSIV stroke time is an indirect method of monitoring acceptability of solenoid valve stroke time. Since the valves are de-energized to close (operation of the MSIV is done by control switch operation which de-energizes the solenoids (F501, F502)), fast closure of the MSIV also demonstrates the fail-safe feature of the pilot solenoids.

Test Method (s):

Closure testing of these valves is to be performed during the MSIV (B21F022A-D and B21F028A-D) full stroke testing described in CJ-821-01. Satisfactory MSIV operation demonstrates proper performance of the associated 821F501 and F502 valves.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8

. PAGE NO. 2 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-82102 System: 821 Nuclear Boiler System Component: B21F505A B21F505B B21F505C B21F505D B21F505E B21F505F B21F505G B21F505H B21F505J B21F505K B21F505L D21F505M B21F505N 821F505C B21F505R B21F505S B21F505T B21F505U B21F505V B21F505W B21F506A B21F506B B21F506C B21F506D B21F506E B21F506F B21F506G B21F506H B21F506J B21F506K B21F506L B21F506M B21F506N 821F506P B21F506R B21F506S B21F506T 821F506U B21F506V B21F506W Cateaory: B Class: A Function: Open to supply air to MSRV actuator to open MSRV; Close to isolate air to MSRV actuator to close MSRV Detailed Discussion:

821F505's and F506's are pilot air solenoid valves which control MSRV operation. The solenoid valves do not have position indication. Opening eFJ1er MSRV pilot air solenoid would cause the associated MSRV to open. As indicated in Valve Relief Request VRR 821-01, opening MSRVs at power would cause unnecessary transients and could result in a LOCA. Therefore, these valves cannot be tested unless plant conditions allow MSRV operation. As discussed in VRR 821-01, the MSRVs are tested during setpoint testing and certification activities on the test bench during refueling outages. Satisfactory MSRV operation demonstrates proper performance of the associated 821F505 and F506 solenoid valves.

Test Method (s}i Testing of these valves is performed during the MSRV testing described in VRR-821-01.

Satisfactory MSRV operation demonstrates proper performance of the associated B21F505 and F506 solenoid valves.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 3 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TEST!NG NO.: AVT-82103 System: 821 Nuclear Boiler System Component: 821F0378 B21F037C B21F037E B21F037G- 821F037J B21F037K B21F037M B21F037P B21F037S B21F037T B21F037V B21F037W B21F0788 B21F078C B21F078E B21F078G B21F078J B21F078K B21F078M B21F078P B21F078S B21F078T B21F078V B21F078W Cateoorv: C Class; A Function: Open to provide vacuum relief in MSRV discharge line; Close to prevent MSRV discharge directly to drywell.

Detal!ed Discussion:

These check valves are located in the drywell which is a high radiation area during power operation and are, therefore, inaccessible. Testing requires access to the valves which is available at cold shutdowns. Therefore, full-stroke exercising is deferred to cold shutdowns.

Test Method (s):

Full-stroke exercise valves during cold shutdowns.

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 4 OF 23 AUGMENTED VALVE TESTING AUGMENTED val VE TESTING NO.: AVT-C1101 System: C11 Control Rod Drive Hydraulic System Component: C11 115 C11 138 ;

Cateaory: C l Class: A Function: Provent backflow of necumulator (C11 115) or reactor water (C11 115 & C11 138) into CRD system if CRD pumps are off.

Detailed Discussion:

These valves are found on each of the 193 f ontrol rod drive hydraulic control units (HCUs).

Industry experience has shown that normal control rod motion will venfy the cooling water header check valve (C11 138) moving to its safety position (closed). This can be demonstrated because rod motion may not occur if this check valve were not closed.

Closure venfication of the charging water header check valves (C11 115) requires that the control rod dnve pumps be stopped to depressurize the chcrging water header This test cannot be performed dunng power operation because stopping the pumps results in a loss of cooling water to all control rod drives and seal damage could result. Additionally, this test cannot be performed dtring each cold shutdown because the control rod drive pumps supply seal water to the reactor recirculation pumps, and one of the recirculation pumps is usually kept running.

The alternative testing specified meets the requirements of Position 7 of Generic Letter 89-04.

Test Method (s):

1) Testing of the C11 138 valves will be accomplished by the observance of normal control rod motion dunng reactor startup and shutdown, and at least weekly for all fully withdrawn control rods and monthly for partally withdrawn control rods not electrically or hydraulically disabled, during performance of Technicc! Specification SR 3.1.3.2, as applicable.

2) Testing of the C11-115 valves will be performed per Technical Specification SR TR3.1.5.1 (at 13ast once every 18 months) by securing the CRD pump and measuring and recording the ti:ne, for up to 10 minutes, that each individual accumulator check valve maintains the associated accumulator pressure above the alarm setooint, starting at normal system operating prr,ssure.

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PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 !

PAGE NO. 5 OF 23 ;

AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-C1102 System: C11 Control Rod Drive Hydraulic System Component: C11 126 C11127 Catenory: B G13331 A Function: Provide exhaust path from CRD HCUs to SDV during a scram (C11 127). Provide flow path from CRD pumps and accumulators to the HCUs during scram (C11 126).

Detailed Discussion:

These valves are found on each of the 193 control rod drive hydraulic control units (HCUs).

The scram inlet and outlet valves (C11,126, C11a 17) full stroke in milu. seconds and are not equipped with indication for both positions; therefore, measuring their full stroke time is impracticable. Scram insertion time can be directly affected by full stroke time of these valves.

Venfying that the associated controi rod meets the scram insertion time limits specified in the Technical Specifications can be used to detect degradation of these valves.

The altemative testing specified meets the requirements of Position 7 of Generic Letter 89-04.

Test Methodis):

Scram testing and control rod insertion timing will be performed in accordance with GGNS Technical Specifications (reactor coolant pressure greater than or equal to 950 psig and, durir,,/

single control rod scram time tests, the control rod drive pumps isolated from the accumulators) which will venfy proper operation of the C11 126 and C11 127 valves:

a. For all control rods prior to thermal power exceeding 40% of rated thermal power following core alterations or after a reactor shutdown that is greater than 120 days (SR 3.1.4.1),

b. Pnor to exceeding 40% of rated thermal power, for specific individual control rods following maintenance on or modification to the control rod or control rod drive . ystem which could affect scram time (SR 3.1.4.4), and

c. For a representative sample of control rods, at least once per 120 days of operation in Mode 1 (SR 3.1.4.2),

d. For specific individual contrni rods following maintenance on or modification to the control rod or control rod drive system wh.ch could affect scram insertion time, prior to declaring the control rod operable and at any reactor steam dome pressure (SR 3.1.4.3).

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PROGRAM PLAN NO. GGNS-M 189.1 -

REVISION NO. 8 PAGE NO. 6 OF 23 j AUGMENTED VALVE TESTING !

AUGMENTED VALVE TESTING NO.: AVT C110)- !

1111tfDi C11 Control Rod Drive Hydraulic System ,

Component: C11F322 ;

Catenory: B .

Gaggi A Function:

Close manually for secondary containment isolation; provides interface between condensate system and control rod drive hydraulic system.

Detailed Discussion:

F322 is a normally open valve in the condensate supply piping to the CRD pumps suction.

Exercising this valve would require a system shutdown and a loss of drive water and cooling water supply la the control rod drive hydraulic control units and seal injection water supply to the reactor !

recirculation pumps, resulting in potential equipment damage if tested during power operation. t Additionally, the test cannot be performed during each cold shutdown since at least one of the ,

reactor recirculation pumps L usually kept running. Therefore, F322 full stroke exercising is deferred to refueling outagus.

Test Methodis):

Full stroke exercise valve during each refueling outage. [

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PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 7 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: /.VT P44 01 System: P44 Plant Service Water System C9mponent: P44F118 P44F119 P44F120 P44F121

,qatsgy; B Sitf3m A Functioni Close for Secondary Containment Isolation Detallert Discussion:

These valves are located in the PSW supply (F120, F121) and retum (F118, F119) piping for containment. Exercising any of these valves would introduce flow and pressure transients in the PSW system which could cause e trip of equipment such as the drywell chillers which are particularly sensitive to PSW flow perturbations. During power operation, a drywell chiller trip would result in elevated drywell temperature and pressure, creating the potential for a reactor scram and ECCS initiation. Therefore, full-stroke exercising of these valves is deferred to cold shutdowns.

Test Methodis):

Ful stroke exercise valves during cold shutdowns.

PROGRAM PLAN NO. GGNS-M-189.9 i REVISION NO. 8 PAGE NO. 8 OF 23 i AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT P44-02 System: P44 Plant Service Water System Component: P44F116 P44F117 P44F122 P44F123 Catenory: B pjans A Function': Close for secondary co,asinment isolation.

Detailed Discussion:

These valves are located in the PSW supply (F122, F123) and return (F116, F117) for the turbine building and provide cooling water flow through the TBCW heat exchangers. Because of the valves' long stroke time (90 to 100 seconds), cooling water flow through the TBCW heat exenangers will be reduced / isolated for an extended period of time, resulting in elevated TBCW temperatures, as well as the components being cooled. This creates the potential for loss or damage to equipment such as reactor feed pumps, main turbine condensate pump motor '

beanngs, heater drain pump bearings, condensate booster pump bearings, isophase bus and exciter. Therefore, full stroke exercising of these valves is deferred to cold shutdowns.

Test Method (s):

Full-stroke exercise valves during cold shutdowns.

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PROGRAM PLAN NO. GGNS M 189.1 ,

REVISION NO. 8 PAGE NO. 9 OF 23 AUGMENTE9 VALVE TESTING _

AUGMENTED'/ALVE TESTING NO.: AVT PS3-01 System: P53 Instrument Air System

, Component: P53F026A PS3F026B Catenory: B Class; A Functio.01 Open (passive) to provide initial stored air supply for relief valve operations. Close for ,

Auxiliary Building Isolation.

Detailed Discussicci P53F026A and F026B are normally open Secondary Containment isolation valves in the instrument air supply piping to the auxiliary building, containment and drywell. Ful' stroke exercising these valves would isoiate the air supply to these areas. Failure of the valves to re-

< open during power operation would adversely affect numerous components including MSIVs and CRD scram valves, resulting in random control rod insertions and MStVs drifting closed. A reactor scram would result. Therefore, PS3F026A and F0268 full-stroke exercising is deferred to cold shutdowns.

Test Methodfs):

Full stroke exercise P53F026A and F026B during cold shutdowns.

i PROGRAM PLAN NO. GGNS M 189.1 j REVISION NO. O PAGE NO.10 OF 23 l AUGMENTED VALVE TESTING !

1 AUGMENTED VALVE TESTING NO.: AVT.P71-01 System: P71 Plant Chilled Water System i Component: P71F304 P71F305 P71F306 P71F307 l

Catenory: B ;

fd3331 A j Functioni Auxiliary Building isolation, i Detailed Dianuggle.m P71F304, F305, F306 and F307 are normally open valves in the plant chilled water piping.

Closure of any of these valves will, due to design interlocks, trip the primary plant chilled water j pumps and the turbine building secondary chilled water pumps. Loss of the chilled water system ,

i during power operation would cause area termperatures to rise, possibly causing a plant shutdown before the chilled water system could be returned to service. Areas affected hclude the control bay, steam tunnel (outside containment), turbine building, containment, and diesel generator rooms. Therefore, P71F304, F305, F306 and F307 full stroke exercising is deferred to cold shutdowns. .

Test Method (s): :

Full stroke exercise during cold shutdowns.

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO.11 OF 23 AUGMENTED VALVE TESTING f AUGMENTED VALVE TESTING NO.: AVT P75-01 l System: P75. Standby Diesel Generator System Component: P75F007A P75F007B P75F034A P75F034B P75F038A P75F038B

' Catenory: C !

I Gja331 A Function: Open for jacket water flow (F007A/B) Close to prevent sho:1 cycling of Jacket water flow (F034A/B, F038A/B).

l Detailed Discussion: i Current system design does not provide the means to individually test these valves. Altematively, if indicated engine driven Jacket water pump discharge pressure is normal with the auxiliary Jacket r water pump not running, F007A/B are venfied to be open and F034A/B and F038A/B are venfied to be closed. This testing is to be performed during the diesel engine operability testing required by GGNS Technical Specifications.

i l Test Method (s):

At least once every 3 months, verify F007A/B open and F034A/B and F038A/B closed during diesel engine operability testing by observing proper engine driven Jacket water pump discharge pressure with the auxiliary jacket water pump not running.

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PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGF, NO. 12 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT P75 02 System: P75 St:.ndby Diesel Generator System Component: P75F507A P75F507B P75F507C P75F507D P75F508A P75F508B P75F508C P75F508D Catenory: B fdgggi A Function: Open to allow starting air flow to diesel. Close to maintain pressure in starting air storage tank to supply penumatic control system.

Detailed Discussion:

These valves are rapid acting and are not equipped with position indication; therefore, measuring their full-stroke time is impracticable. Venfying that the Diesel Generator starting time (using only one starting air subsystem after rolling the diesel using each air line individually) meets the time limits specified in the GGNS Technical Specifications can be used to detect degradation of these valves. If the diesel reaches rated speed within 10 seconds, the starting air valves will have stroked and passed full safety flow. Additionally, following an air roll of the diesel engine using each air start solenoid valve individually, venfication of the absence of air flow from the air start manifold vents confirms air start solenoid valve closure.

Test Method (s):

At least once every 3 months, the diesel will be rolled using each air line individually. This will prove that the valve opens. Additionally, following air rolling of the diesel engine using each air start solenoid valve individually, verification of the absence of air flow from the air start manifold vents confirms air start solenoid valve closure.

At least once every 3 months, during alternating starts, the diesel will also be started using only one starting air subsystem (two starting air lines) per the surveillance requirements in GGNS Technical Specification SR 3.8.1.2 which states:

" Verify each diesel generator starts from standby conditions and achieves, ia iess than or equal to 10 seconds, voltage greater than or equal to 3744 V and less than or equal to 4578 V and frequency greater than or equal to 50.0 Hz and less than or equal to 81.2 Hz."

If the diesel reaches rated speed within 10 seconds, the two starting air valves will have stroked and passed full safety flow.

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PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.13 OF 23 !

AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO : AVT P75-03 System: P75 Standby Diesel Generator System Component: P75F077A P75F077B Catenory: C fdaggi A Function': Open to allow fuel oil flow, Detailed Discussion:

Current system design does not provide the means to individually test these valves Attematively, if indicated engine driven fuel oil pump discharge pressure is normal with the auxiliary fuel oil pump not running, F077A/B are verified to be open. This testing is to be performed during the diesel engine operability testing required by GGNS Technical Specifications.

Test Method (s):

Ai: east once every 3 months, verify F077A/B open during diesel engine operability testing by observing proper engine driven fuel oil pump discharge pressure with the auxiliary fuel oil pump not running.

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I PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.14 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT P75-04 ,

System: P75 Standby Diesel Generator System Component: P75F050A P75F0508 P75F059A P75F0598 Catenory: C Qgggi A Function': Open to allow lube oil flow (F050A/B and F059A/B). Close to prevent draining of lube oil suction piping (F050A/B).

Detailed Discussion:

Current system design does not provide the means to individually test these valves. Altematively, if indicated engine drivea tube oil pump discharge pressure is normal with the auxiliary lube oil pump not running, FO'.. VB and F059A/B are venfied to be open. Also, F050A/B are venfied to have been closov ,,e , 'v operation because the suction line was full, allowing the pump to take suction. This testing is ca be performed during the diesel engine operability testing required by GGNS Technical Specifications.

Test Method (s):

At least once every 3 months, verify F050A/B and F059A/B open during diesel engine operability testing by observing proper engine ?,ven pump lube oil discharge pressure with the auxiliary tube oil pump not running. This also venfies F050A/B to hrsve been closed prior to starting the diesel.

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PROGRAM PLAN NO. GGNS M 180.1 REVISION NO. 8 PAGE NO.15 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-P75-05 System: P75 Standby Diesel Generator System Component: P75F080A P75F0808 P75F095A P75F0958 P75F096A P75F0968 i P75F097A P75F097B Catenory: C h- A Function: Open to allow lube oil flow (F080A/B, F095A/B, F096A/B, F097A/B). Close to prevent lube oil from flooding cylinder head rocker arms and turbocharger when engine is in standby (F080A/8, F095A/B).

Detailed Discussion:

Current s) <, sm design does not provide the means to individually test these valves. Altematively, if indicated insin lube oil loop pressure is normal with the av.viliary lube oil pump not running, F080A/B and F095A/B are verified to be open. F096A/B and F097A/B are verified open/ closed by observing proper turbocharger oil inlet pressure with oil flow lined up to left side /right side inlet strainers. Additionally, F080A/B and F095A/B are verified to have been closed prior to diesel start as verified by a normal engine startup. This testing is to be performed during the diesel engine operability testing required by GGNS Technical Specifications.

Test Method (s):

At least once every three months, verify F080A/B and F095A/B open during diesel engine operability testing by observing proper main lube oil loop pressure with the auxiliary lube oil pump not running, Venfy F096A/B and F097A/B open/ closed by observing proper turbocharger oilinlet pressure with oil flow lined up to inlet strainers on first one side, and then the other side. Verify F080A/B and F095A/B closed prior to diesel start by observing a normal en0 ine startup.

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PROGRAM PLAN NO. GGNS-M- 1.1 REVISION NO. 8 PAGE NO.16 OF 23 T

AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-P75-06 System: P75 Standby Diesel Generator System Component: P75F079A P75F079B P75F079C P75F079D P75F079E P75F079F P75F079G P75F079H Catenory: C Clang . A Function: Open to allow flow of starting air to diesel. Close to isolate independent / redundant trains.

Detailed Discussion:

The open function of these valves can be tested at the code required frequency. However current system design does not provide adequate instrumentation or test connections for venfying obturator position in the closed position. Therefore, testing for the close function is to be accomplished by valve disassembly every refueling outage.

Test Method (s):

Disassemble each valve every refueling outage.

PROGRAM PLAN NO. GGNS-M-189.1 I REVISION NO. 8 j PAGE NO.17 OF 23 l l

AUGMENTED VALVE TESTING i AUGMENTED VALVE TESTING NO.: AVT P81-01 l

System: P81 HPCS Diesel Generator System Component: P81F503A P81F503B P81F504A P81F504B l Catsory.1 o B Class: A Function: Open to allow starting air flow to air start motors for diesel engine start. Olose after engine start to vent control air from air relay valve, isolating starting air to air start motors and allowing pinion gear to retract.

Detailed Discussion:

P81F503A/B and F504A/B are located in the HPCS Diesel Generator air start piping. Current design does not provide the capability of individually testing these valves. These valves have neither local nor remote position indication, therefore, measuring their full-stroke time is impracticable. Venfying that the Diesel Generator starting time (using only two of the four starting ,

air subsystems after rolling tne diesel using each air line individually) meets the time limits specified in the GGNS Technical Specifications can be used to detect degradation of these valves. If the diesel reaches rated speed within 10 seconds, the starting air valves will have stroked and passed full safety flow. Satisfactory operation of the valves will be determined during diesel generator operability testing by performing the following:

The diesel will be rolled using each air start subsystem (consisting of one starting air line with one solenoid valve, one air relay valve, one check valve and two starting air motors) separately.

During this test, the air motor pinions will be observed to engage prior to the air start motors tuming. This will prove that each solenoid valve opens (by manual actuation), that each relay valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, the air motors will be observed to verify that the air motor pinions have disengaged and that the air motors have slowed and stopped. This venfies that each solenoid valve has closed (vented the air motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow.

The diesel will also be started using two of the four starting air subsystems and will be evaluated per Technical Specifications. This testing will be performed on a staggered basis such that all four subsystems are tested at least quarterty.

Test Methodis):

Test each valve at a frequency of at least once every three months by performing the following:

Roll the diesel using each air start subsystem (consisting of one starting air line with one solenoid valve, one air relay valve, one check valve and two starting air motors) separately. During this test, observe that the air motet pinions engage prior to the air start motors tuming. This will prove that each solenoid valve opens (by mariual actuation), that each relay valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, observe that the air motor pinions have disengaged and that the air motors

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.18 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT-P8101 have slowed and stopped. This venfies that each solenoid valve Ms closed (vented the air i motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow, i

Start the diesel using two of the four starting air subsystems and evaluate acceptable diesel I operation (including starting time) per Technical Specification SR3.1.8.2 which states:

"Ver'ify each diesel generator starts from standby conditions and achieves, in less than or equal to 10 seconds, voltage greater than or equal to 3744 V and less than or equal to 4576 V and frequency greater than or equal to 58.8 Hz and less than or equal to 61.2 Hz."

if the diesel reaches rated speed within 10 seconds, the two starting air valves and the two air relay valves associated with the two starting air subsystems used to start the diesel will be judged to have stroked open and passed their full safety flow, il e , , .-, . ww.,- ,. ----.------,---n--,, , , . ~ -- - , ,---,-,,--,.e r, , e

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.19 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT P81-02 System: P81 HPCS Diesel Generator System i Component: P81F059A P81F0598 P81F060A P81F060B Catenory: C ,

gaggi A Functioni Open to allow lube oil flow to turbocharger / idler gear shafts (F059A/B). Close to prevent flow from soak back pump from entering main lube oil header with engine in standby (F059A/B), and prevent short circuiting lube oil from main header (F060A/B). -

Detailed Discussion:

Current system design does not provide the means to individually test these valves Attematively.

- F059A/B can be venfied open and F060A/B can be verified closed by observing proper turbocharger oilinlet pressure when the engine is running and the soakback pump is stopped.

Additionally, F059A/B are venfied to have been closed prior to diesel start as verified by a normal engine startup. This testing is to be performed during the diesel engine operability testing required by GGNS Technical Specifications.

Test Method (s):

Test each valve at a frequency of at least once every three months by performing the following:

Venfy F059A/B open and F060A/B closed during diesel engine operability testing by observing i proper turbocharger oil inlet pressure with diesel engine running and soakback pump stoprod.

Venfy F059A/B closed prior to diesel start by observing a normal engine startup. j

. . . - . , . . . ~ . . - - - - ~ . . . - - - - . - - - . , . . - - - . . - .-, . . , . , - .

i

^

PROGRAM PLAN NO. GGNS M-989.1 REVISION NO. 8 PAGE NO. 20 OF 23 AUGMENTED VALVE TESTING ,

AUGMENTED VALVE TESTING NO.: AVT P8103 System: P81 HPCS Diesel Generator System Component: P81F034A P81F034B P81F035A P81F035B Catenory: C gggy A .

Functioni On engine start signal which energizes solenoid valves, close to prevent control air from reaching air relay valves. Open after starting air solenoid valves are deenergized, to vent control air line and allow air relay valves to close.

Detailed Discussion:

P81F034A/B and F035A/B are located in the HPCS Diesel Generator air start piping. Current design does not provide the capability of measuring flow through these valves therefore alternative testing is necessary. Satisfa: tory operation of the valves will be determined during diesel generator operability testing by performing the following:

The diesel will be rolled using each air start subsystem (consisting of one starting air line with one solenoid valve, one air relay valvei one check valve and two starting air motors) separately.

During this test, the air motor pinions will be observed to engage prior to the air start motors turning. This will prove that each solenoid valve opens (by manual actuation), that each relay i valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, the air motors will be observed to venfy that the air motor pinions have disengaged and that the air motors have slowed and stopped. Thi:5 venfies that each solenoid valve has closed (vented the air motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow.

Test Methodis):

Test each valve at a frequency of at least once every three months by performing the following:

Roll the diesel using each air statt subsystem (consisting of one Starting air line with one solenoid valve, one air relay valve, one check valve and two starting air motors) separately. During this test, observe that the air motor pinions engage prior to the air start motors turning. This will prove that each solenoid valve opens (by manual actuation), that each relay valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, observe that the air motor pinions have disengaged and that the air motors have slowed and stopped. This venfies that each solenoid WVJ has closed (vented the air motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow.

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE NO. 21 OF 23 AUGMENTED VALVE TESTING AUGMENTED VALVE TESTING NO.: AVT P8104 System: P81 HPCS Diesel Generator System Component: P81F053A P81F0538 P81F054A P81F0548 Cateaory: B Class: A Function: Open to allow starting air flow to air start motors to start diesel engine. Close after engine start to isolate starting air to air start motors arid allow pinion gear to retract.

Detailed Discussion:

P81F053A/B and F054A/B are located in the HPCS Diesel Generator air start piping. Current design does not provide the capability of individually testing these valves. These valves have neither local nor remote position indication, making measurement of full-stroke time impracticable.

Therefore, alternative testing is necessary. Venfying that the Diesel Generator starting time (using only two of the four starting air subsystems after rolling the diesel using each air line individually) meets the time limits specified in the GGNS Technical Specifications can be used to detect degradation of these valves. If the diesel reaches rated speed within 10 seconds, the valves will have stroked and passed full safety flow. Satisfactory operation of the valves will be determined during diesel generator operability testing by performing the following:

The diesel will be rolled using each air start subsystem (consisting of one starting ai-line with one solenoid valve, one air relay valve, one check valve and two starting air motors) separately.

During this test, the air motor pinions will be observed to engage prior to the air start motors turning. This will prove that each solenoid valve opens (by manual actuation), that each relay valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, the air motors will be observed to verify that the air motor pinions have disengaged and that the air motors have slowed and stopped. This venfies that each solenoid valve has closed (vented the air motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow.

The diesel will also be started using two of the four starting air subsystems and will be evaluated per Technical Specifications. This testing will be performed on a staggered basis such that all four subsystems are tested at least quarterly.

Test Method (s):

Test each valve at a frequency of at least once every three months by performing the following:

Roll the diesel using each air start subsystem (consisting of one starting air line with one solenoid valve, one air relay valve, one check valve and two starting air motors) separately. During this test, the air motor pinions will be observed to engage prior to the air start motors turning. This will prove that each solenoid valve opens, that each relay valve opens to admit air to the starting motor, and that each check valve closes.

After each air roll, the air motors obse've that the air motor pinions have disengaged and that the air motors have slowed and stopped This venfies that each solenoid valve has closed (vented i

PROGRAM PLAN NO. GGNS-M 189.1 -

REVISION NO. 8 ,

PAGE NO. 22 OF 23 AUGMENTED VALVE TESTING t AUGMENTED val.VE TESTING NO.: AVT P8104 ,

the air motors), that each air relay valve has closed (vented the air motors), and that each check valve has opened and passed its required safety flow.

Start the diesel using two of the four starting air subsystems and evaluate per Technical .

Specification SR 3.8.1.2 which stctos:

" Verify each diesel generator. starts from standby conditions and achieves, in less than or aquel i to 10 seconds, voltage greater than or equal to 3744 V and less than or equal to 4576 V and frequency greater than or equal to 58.8 Hz and less than or equal to 61.2 Hz."

If the diesel reaches rated speed within 10 seconds, the two starting air valves and the two air relay valves associated with the two starting air subsystems used to start the diesel will be judged to have stroked open and passed their full safety flow, 1

i b

l 4

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 23 OF 23 >

AUGMENTED VALVE TESTING ,

AUGMENTED VALVE TESTING NO.: AVT P8105 System: P81 HPCS Diesel Generator System .

Component: P81F064 Catenory: C Class: A Functio.Dd Open to direct air to the govemor air booster to ensure fast start of diesel generator.

Close to isolate redundant starting air trains.

Detailed Discussion:

P81F064 is a two-way check valve which opens to allow air flow from one inlet while closing to isolate the other inlet. Current system design does not provide the means to individually test this valve, therefore, attemative testing is necessary. Venfying that the Diesel Generator starting time (using only two of the four starting air subsystems) meets the time limits specified in the GGNS Technical Specifications can be used to detect degradation of this valve. If the diesel reaches rated speed witnin 10 seconds, the valve will be considered as having stroked and passed full safety flow. Satisfactory operation of the valve will be determined during diesel generator '

operability testing by performing the following:

The diesel will be started using two of the four starting air subsystems and will be evaluated per Technical Specifications. This testing will be performed on a staggered basis such that all four subsystems are tested at least quarterly.

Test Method (s):

Test each position of this two-way valve at a frequency of at least once every three months by performing the following:

Start the diesel using two of the four starting air subsystems and evaluate acceptable diesel operation (including starting time) per Technical Specifications.

]' ENTERGY OPERATIONS,INC PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND YALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. B21 -1 SYSTEM: B2 - Nucicar Boder Sysicm VAI.VE F & ID Ist j l! REQUIRED TESTS AND FREQUENCY j RE1JEF VALVE SIZE (im) MA . IST (Y)DE NE MFETY;h M- i REQtTST OTilER MA TYPE ACT. C(X

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ENTERGY OPERATIONS, INC. PROGRAM PLAN NO.GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. B21 -2 SYSTEM: B21 - Nuclear Boiler 5ysicm VALVE F & ID tsF ll REQUIRED TESTS AND FREQUENCY RELIEF VALVE St':E 0n) M). , 15T CUDE EN 15AfD.T) OTifEJL REQUEST N-NO- TYPE ACF. (VORD. FASS CLAS5 f MR F5 F5 LT 1J ST FT FI RV EX CD l (VRR) (CA'RIAVT) M)TES:

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} ll GL A M-1077D l I14 i i C il C Q J C C 2Y l' B215G29A I M-1077A 2 C l } } CMul49 C SA 11 4 C lC l l h B217039B 3 M-1077A 2 C fj j g CLICl49 l

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C SA B3 C li C 2Y !!

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ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS.M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. 821 -3 SYSTEM: B21 - Nuclear Boder Sptem VALVE F A ID IST '

REQUIRED TESTS AND FREQUENCY VALVE No. , l 857 - 0)DE UE }! RELIEF SIZE (im) [ SAFETY i REQUEST OTHER SO. TYPE ACT. M)ORD. FAss Gass N*j N F5 F5 LT IJ ST FT F1 RV EX (y ( O'RR) (C31UzA%T) NOTE 5:

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C SA 11 4 i C l C1 2Y l l 33t F3%M i M-IO77C 3 CA l 0 lC8 C182142 C SA fl 7 I C IC_ 2Y B21FG%N I M-1077C 3 C.A 1 O [C C182842 l

C SA H5 C hC 2Y I B211D%F 1 M-IO77C 3 O lC CA } C182842 C SA G5 i C IC 2Y B81}VMR I M-1077C 3 CA O j C CM12I42 C SA G4 C lC 2Y B2iF0365 3 M-1077C 3 C.n O }l C l C182142 C SA E7 C ji C 2Y l Il2 t t0%T I M-IO77C 3 CA O j C CM12342 '

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ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVir>10N NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM Yb1VE SUMMA RY LISTING - PAGE NO. B21 -4 SYSTEM: B2 i - Nucicar Boiler System VALFE F & ID isT l l REQUIRED TESTS AND FREQUENCY ( att1EF VALVE MIE Ost) No. , IsT (Y)DE "" 5AFETYI} -

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i ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. B21 -5 SYSTEM: B21 - Nuclear Boder Sysicm VA15E F A ID IST l ll REQUIRED TESTS AND FREQUENCY ErllEr VA1_VE SIIE (ht) MD. , isT (UDE G)DE '5AFETYi! l N-3 ( RE S~EST OTHER FA55 CIA 55

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C SA C5 +

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B2tF041A RV ASA M-1077E I CJ3 j O 1 SY SY SY j VRR-82141 D6 i C l SY SY SY ' '

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8 II21F047A M-1077E I CJi O j SY SY SY y,,,py,4, RV ASA 06 C i SY SY SY 1GIF047C 3 M-1077E 1 CJi ; O SY ! SY y SY : g RV ASA D6 l C SY I SY I SYl Il IGIF047D 8 M-1077E I CJ1 O l SY l SY SY RV ASA D6 C } Sy } SY SY fVRR4H148 fl IElt047G 8 M-1077E I CJ) } O l SY ) 5Y SY VRR432143 RV ASA D6 C SY SY

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ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING- PAGE NO. B21 -6 SYSTEM: 821 - Nuclear Botier System VALVE P A ID 15T I } REQUIRED TESTS AND FREQUENCY 4 REL Er VAD E $1ZE(ht) 50. . IST G)DE UM '5AFETY REQM3T OTHER CAT.

MA TYPE ACT. UM)RD. PA55 (1.A%5 lm FN f PS l LT LJ ST FT Pt RV EX CD (VRR) (CallEAYT) NOTE 5:

3 M-10M; Cy [}

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RV ASA G6 C SY : 5Y 5Y B21F051D 5 M-1077E I C.B 0 g SY SY SY l j RV ASA D6 i C ll 5Y SY SY l EUlF09tr 8 M-1077E I C.B O jl SY [ SY SY j.

VRR-B2148 RV ASA D6 C II SY l SY 5/ I IMIFOSIK 3 M-1077E I Cy 0 5Y SY q 27 j VRR-B2141 RV ASA D6 C !i SY SY SY !

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ENTERGY OPERATIONS,INC. PROGRAM PLAN NO.GGNS.M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. B21 -7 SYSTEM: B21 - Nuclear Boiler 33sem VALM1 F & ID IST l REQUIRED TESTS AND FREQUENCY REutF YALVE IST G)DE GmE :SAf1TY l SIZE {ia) NO. . REQtT.ST OTilER No. TYPE ACT. (TM)RD. PASS GASS M- Foi FS PS LT IJ ST FT F1 RV EX ;-) ODR) O M %T) NOTEN B21FD75A 10 M.1077E 3 0 ll C !! CJ-82143

C ll" C SA FS C ii~C-~ f B21F07tB 10 M.1377E A C O l C l A\T-B2343 C SA B6 C l C II B21F073C 10 M ".977E A C Ol C AtT.82143 C SA B6 C l C B21F073D to M 1077E 3 C O C CJ.821-03 C SA F5 C C B281V78E 10 M-1077E A C O l C 1 }{ l A%T-82143 C SA B6 C fC l} l B2tIO73F to M-1077E 3 C j O i C l l CJ-82143 C SA FS l C l. C i }

U217075G 10 M-1077E A C O C A%T-82143 C SA B6 C C U21F07 Ell to M-1077E 3 C O lC j CJ-B2143 C SA FS C lC fl i

i U2iF073J 10 M-1077E A C O lC AVT-82143 C SA B6 C 1C O

B21F078K C

10 SA M.3077E B6 A C

{C AVT-82143 C ll C 1121FU78L 10 M-1077E 3 C i O jC g c3432343 C SA FS I C iC !!

Il21FD73M to M-IO77E A C .

O ll C AgT.82343 l

C SA B6 C ll C H2tf07EN 10 M.1077E 3 C O l C C3-82143 l

C SA FS C l C I Il21F078P 10 M-1077E A C O {C l A\T412541 C SA 11 6 C IC I Il2 tlV78R 10 M-1077E 3 C O C CJ-B2143 C SA FS C C lulF0785 to M 1077E A C i 0 C AVT-B2143 l

C SA B6 , C C i

S I

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 i PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. H21 -8 SYSTEM: B21 - Nuclear Boder System vat.vt ra ID lst j l REQUIRED TESTS AND FREQUENCY i REUEF VOLVE MII(iss) SO. , 15T (X)DE NE SAFETY}

CAT.

g i RFQtT.5T OTilER l SO. TYPE ACT. m)RD. PA55 CLA5s }M is f Ps LT { IJ ST FT Pt l RV l EX CD j (vRR) (CARSAVT) NOTFA d21F073T {

10 M.1077E A C l 0 ll C { l } AYT-82143 ;

lC SA D6 ! C il C i i if IISifD73U 10 M 1077E 3 C 0 lj C l C SA FS i l

C kC { { y!

CJil214) i i h l IEIF073y 10 M.1077E A C l 0 C t AVT412141 l ] .

C SA H6 l I C 41 C e f !. fi B21F073w C

10 SA M-1077E H6 A

C QOb

}l C C II C 1 ' WT4CI-0) i I }

IMIF093A 28 l M-1077A 2 B C11ul45 h l $'

G M l G2 ) C !! C IC 2Y

)g 23 1M110981) o e M-1077A 2 B ll I l l h CLlul45 n2 d C i C i C 2r l 11 021F09sC G

28 M

M-1077D F2 2 B

[

i

_ _ {]

C Il C l C

[( 2Y _{ l l}

C1112843 U21F091D _ 23 M-1077D 2 H g _

i C1tul43 i G M 11 2 C ll C C 2Y i i B21FIGA 3 M-1077E 3 C O gC j CAH21-12 Mahanmar nerswer C SA C6 C li C_ i IMIFIDOD 3 M-1077E 3 C l 0 gC i l

l Clint.82 Mahanmal Emestner C SA C6 I C VC f ) l

' O InIFI0oC 3 u-8077E C lC Cru2182 uah.nmal Enerc=er C sA C6 l3 C iC l

1 IMIFlo u :21G M-1077E 3 C 1 O l C C1101-82 th turum ,

{ l [ '

C sA r6 i C i C ! i i 21/2 O lulFioot. M IO77E 3 C ! gC _

CLlui-12 Mahansc=1 Eustmer C SA C6 i C 11 C ll21FIDF 2 l '2 M-1077E 3 C ll 0 ij C

{ C1828-12 Mahanmal t;urswer C SA F6 ii C NC l luirnux; 23'2 M-IO77E 3 C

[ O j C ]__j _.

l I CLB21-12 Mahmall arsuer C sA C6 i C bC i i luiFluit 2l'2 _ _ M.io77E 3 C i O kC J }

Citul-82 u.w a ursner fC kC C sA F6 I 1

v ENTERGY OPERATIONS,1NC. PROGMAM PLAN NO. GGNS-M-189.1 GRAND CULi' NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE SUMMAMY LISTING - PAGE NO. B21 -9 SYSTEM: B21 - Nuclear Boiler System VAixE r a ID isT l REQUIRED TESTS AND FREQUENCY l RE1JEF IST CODE NE j MEQt'ENT OTIIER VAtVE SIZE 4h) 50- , l SAFETY NO. TYRE AcT. COOnD. FAW class CAT. j pos, ,3 ,, l L7 ,, l 37 l ,7 l ,, l ,y gx g, gj p mu) (cauJ/AVT) NOTES:

1121FIL3J 2IG M.IO77E 3 C[ O yC , j CJ.H21-12 Mchanscal Exercar C SA F6 l C il C i i

21/2 M-1077E 3 C O C l CJ-il21-11 Maharmal Enerciner B21FIOK C SA C6 C C l 21G C O CJ-Il21 Mahanical k.ncrmer H21F100L M-1077E 3 lC [

t- SA C6 C iC I B21FICOM 21G M-1077E 3 C O jC CLB21-12 %Iurmal Enrecuer C SA C6 C ll C H21FlON 2IG M-1077E 3 C 0 C i CJ-821-12 Mabzucal Emerer h .

C SA C6 C ll C , [ t B2IFinP 210 M-10777 3 C 0 C CJ-B21 12 Mahrecal Excrcser C SA F6 C C 214 M-1077E 3 C 0 C j CJ-il21-12 Maharncal Encrener H21Fl@R l

SA ! C C 1 5

r6 2 If2 C j C CJ.H21-12 Mahanical Excrtner il21Fl00S _

M-1077E 3 O l [

C SA F6 l C I C i li21FIC3T 21'2 _

M-1077E 3 C .I O lC CJ-821-12 Maharmal Emerem:r C SA F6 l C iC

!!21F1000 21/2 M-1077E 3 C O lC CJ-Il21-12 Maharmal Encrmer C SA C6 C !C

!!21FIGV 2 l'2 M-1077E 3 C O lC CJ-Il21-12 Maharucal Emermer

[

C S. . C6 i C iC I!21FICDw 214 M-1077E 3 C 0 C cJ.821-12 Maharncal Emercser l _ _

C SA C6 ? C C H21Fil) 4 M-1077A A B G A El C Q Q Q 2Y H7tFil4 4 M-1077A A B .. j O A FI C Q Q Q 2Y l n2ir:2 n _

i _j u.ionC 3 C.A a

! j iOY RV SA D2 C l 2Y l IOY ll21F12511 RV 1

SA M-107'C DS 3 C.A QO ll C

_]

2Y ,

l10Y fl0Y

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8

- PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE SUMM ARY LISTING - PAGE NO. 821 -10 SYSTEM: D21 -

Nuc! car Boiler System VAINE ' P a lD IST l REQUIRED TESTS AND FREQUENCY RF13EF VALVE SIZE (in.) IST (X)DE WDE ; SAD ETY

50. ,

CAT. REFEST 01 TIER NO. TYPE ACF. (X)ORD- PASS CLASS l pos FS PS LT)IJ ST FT ) PI l RV EX CD (VltR) (CJ.1tJ/AVF) M)TES:

821Fl25C' I M-1077C 3 o' A O 10Y -

RV SA D3 C 2Y 10Y B31Fl25D I M 1077C 3 C.A O 10Y

{

RV SA G3 C 2Y 10Y I B31FI25E I M-1077C 3 C.A O 10Y RV SA 'G5 C 2Y 10Y f121FI39F 1 M-1077C 3 C.A O ] 10Y RV SA O4 C i 2Y 10Y I!3tFI250 3 M-Id77C 3 C.A O 10Y RV SA E "t C 2Y 10Y ll3tFl3511 1 M-1077C 3 C.A Ol 10Y

{

RV SA G7 C l 2Y 10Y l Il31F129J l M-1077C 3 C.A O 10Y q RV SA GI C 2Y 10Y ll I!21F130A 2 M-1077C 3 C.A O lC CJ-il2146 C SA GS C i C 2Y ll3tFl30B 2 M-1077C 3 C.A Ol C } CJ-B2846 C SA E8 C j C 2Y l B31 FIG 7A 3'4 M-1077A 3 B O C C 2Y CJ432147

01. M E2 B31F147B 3/4 M-1077A 3 D l 0 C C 2Y CJ-B2147 UL M E2 ll3t Fl52A 3/8 M-107711 2 C,A CJ-il21-10

((

C SA 11 2 C C 2Y I}

f!21Fl5211 3 18 M-1077tl 2 C.A CJ-1121-10 C SA 11 6 C C 2Y ll21F192C 3/8 M-10778 2 C.A CJ-821-lo C SA G2 C C 2Y ll2iFl92D 3 18 M-IO77B 2 C,A j CJ-821-10 C SA F6 l C Cf 2Y 1121FI94 A 3 '8 M-1077B 2 C,A j CJ-l!21-10 C SA 11 2 C HC 2Y

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM vat-VE

SUMMARY

LISTING - PAGE NO. B21 -11

~

SYSTEM: B21 - Nuclear Boiler System VALVE VAIXE SIZE (im)

F a in No. , IST IST CODE MEl SAFETY REQUIRED TESTS AND FREQUENCY RELIEF REQt'EST OTHER NO. TYPE ACT. WORD. PASS CLASS CAT. pos' FS PS LT IJ ST PT PI RV EX CD (VRR) (C11tJ/AW) NOrES:

B31Fl5Cil -31 M-1077B 2 C.A CJ-B21-10

l C SA 11 6 1, C IC 2Y II31F154C li M-1077B 2 C.A CJ-B21-10 l ,

C SA G3 ! C C 21 B21F154D 31 M-1077B 2 C.A j} CJ-821-10 C SA F6 C hC 2Y B21F50l AA N/A A B AVT-B2141 T S N/A C C C C 02 t F50l All N/A A 13 AVT-82141 T S WA C C C C H21F50ll!A _

N/A A B i

,[ { AW-8214I T S N/A l} C l C C C 113tF501BU N/A A B AVT-82141 T S WA C C C C Il31f 50lCA N/A .A B I!3tFSCICB T S N/A N/A A B C C C C ]l}

AVT-li2141

_ *i AVT-82141 T S N/A C C C C B3tF50lDA N/A A B l j AVT-B2141

[T S N/A C C C C D21F501DU N/A A B l l AVT-B2141 T S N/A j C { C C C .

Il21F502 AA _

N/A A II l AVT-82141 T S N/A C } C C C h Il21F503AB N/A A B AVT-D2141 l

T S N/A C C C C i 1331F503:lA N/A A D l l l AVT-D2141 T S WA I C C 3 C C i U2tF502110 N/A A B l AVT-B2141 T S 'N/A C C C C H21F502CA N/A A Il l AYT-82841 T S mA C C , C C I

. _ . .. 1-,.- -

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. 821 -12 SYSTEM: B21 -

Nuclear Boiler System

. VAI.VE F A ID Isf l REQUIRED TESTS AND FREQUENCY RELIFF VAI.VE. SIZE (In.) No. , IST WDE WDE ! SAFETY OTHER REQUEST No. T) PE ACT. COORD. PASS C1 ASS CAT. l poi FSlFS 1.T 1J ST FT F1 RV EX CD (VRR) (C N A%T) MJTES:

I!31F502CB _

NA A B- l l A%T-B2141 T S N/A C iC I C C B31FS03DA N/A A B i AVF-!!2141 T S wA IC il JIC C C B21F502Df! N/A A B A%T-82141 T S N/A C C C C II31F505A M-1077E A II l 0 SY SY AVT412142 T S C7 [ C 3Y SY SY B21F509B M-1077E A 11 ij Ol SY SY l AVT412142 T S C7 l} C [ SY SY SY l If2?F505C M-1077E A B O SY SY l AVT-il2842 T S C7 C SY SY SY I

!!31F50SD M.IO77E A B 0 SY SY AVT-82142 T S F8 l C SY SY SY ll3tF505E M-1077E A B O j SY SY Ayy.g2342

_ l T S C7 C l SY SY SY I 1131F505F M-1077E A B O SY SY AVT-B2142 T S Fs C SY SY SY B21F505G M-IO77E A B O SY SY AVT-82142 T S C7 C SY SY 5?

I!31F5091I M 1077E A B ll O l SY SY AVT-il21-02 T S Fs C l SY SY SY B21F50$J T

M-1077E A B O ! SY SY j A%T-il2142 '

S F8 C i SY SY !Y {

ll21F505K M-1077E A II O SY SY AVT-il2142 T S C7 C SY SY SY I!21F505L M-1077E A 11 O SY SY { AVT412142 T S C7 C SY 5Y SY ll21F50$M M 1077E A II O SY SY AVT-il2142 T S C7 C SY SY SY ll3IF505N M-1077E A !! O SY SY AgT.B2142

{

T S C7 C SY SY SY l l

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM ,

VALVE

SUMMARY

LISTING - PA GE NO. B21 - 13 SYSTEM: B21 -

Nuclear Boiler System -

VAI.VE F A ID IST l REQUIRED TESTS AND FREQUENCY RELIEF VALVE ' SIZE On.) $0. . . IST G)DE WDE ' SAFETY ' REQUEST OTHER No. TYFF. ALT. U)ORD. FASS CLASS CAT- yes FS FS LT LJ ST IT F1 RV EX CD (VRR) (CallJ/A%T) SOTES:

B21F50SF M-1077E A B O SY SY ' AVT-B2142 "

[

T S F3 I C SY SY SY IMIF503R M-1077E A B o SY SY A%7-B2142 T S F8 C SY SY SY IEIF505S M-1077E A B O SY SY A%T412142 T S Fs C SY SY SY IUlF509T M-1077E A B O SY SY AVT-82142 T S Fs C SY SY SY IGIF505U M-1077E A B O SY SY l AVT-D2142 T S C7 C 5Y SY SY n Il3'F505V M-1077E A B O SY SY AVT-B2142 T S C7 C 5Y SY SY fulF509W M-1077E A B o SY SY l ANT.B21-02 T S C7 C SY SY SY I H21F506A M-1077E A B o SY SY AVT-D2142 T S Cs C SY SY SY IElF5%Il M-1077E A B O SY SY AVT-B2142 T S Cs C SY SY SY IUlF506C M-1077E A B O

SY SY A\T-B2142 T S Ca C l SY SY SY EMIF506D M-1077E A B O SY SY Ag7.B21-02 T S G7 C SY SY SY lulF506E M-1077E A 11 O SY SY l AVT-112142 T S Cs C SY W SY !

112tF506F M-1077E A B o 5'T SY AVT-82142 T S G7 C 5Y SY SY ll21F506G M-1077E A B O l SY SY A%T-82142 T S CS C i SY SY SY IMIF506tl M-1077E A B o j SY SY i .

A%T-ll2142 T S G7 7 I SY SY SY ll21F506J M 1077E A B O SY SY AVT-II21-02 T S 07 C SY SY SY

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION ' REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. B21 - 14 SYSTEM: B21 -

Nuclear Boiler System VALVE P a ID IST { REQUIRED TESTS AND FREQUENCY RELIFJ VAIRE SIZE (la) NO. , IST WDE MDE AM ETY -r N- REQUEST GUIER

50. TYPE ACT. UX)RD PASS CLASS lM 4

FS l Ps k LT f LJ ST IT Pt RV EX 'CD OIR) i MMAVT) SOFEs-821F506K M-1077E A B l 0 SY SY AVT-B2142 '

T S Cs i C SY SY SY IUIF5061 T S M-1077E Cs A

B QO il l

C f SY SY SY SY SY l

j AVT-B21-02 D21F506M M-1077E A II l 0 SY SY l [ AgT-B21-02 T S Cs l C SY SY SY { f II21F506N T

M-1077E A Bl 0 SY SY l AVT-B2142 S Cs l C SY SY SY l ECIF906P M-1077E A B f O SY l SY AVT-B2142 l

T S G7 I C SY l 3. $Y I fl31F506R M-1077E A B O SY j SY AVT-D2142 T

{

S G7 t C SY l SY SY 101F5065 M-1077E A P O SY , SY A%T-D21-02 T S G7 C SY l SY SY IMIF506T M-1077E I A B 0 SY SY j l A%T-82142 T

f S G7 I C SY SY SY j l IMIF506U M-1077E A B Ol SY i SY AVT-82142 T S C3 C i SY I SY SY IUlF506V M-1077E A B O j SY SY A%T-D2I42 T S C4 f{l C l SY SY SY D21F506W M-1077E A D 0 SY j A\T-D2142 T S Cs C hl{SY SY SY SY !

!!3 tFC33 24 M-1077D 2 C CAB 21-Os

_ l C SA Fa C l C

ENTERGY OPERATIONS, INC. E PROGRAM PLAN NO GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. 833 -1 SYSTEM: B33 - Reactor Recirculation System VALVE F A ID IST REQUIRED TESTS AND FREQUENCY RELIEF VALVE SIZE (ia) NO. , LST CUDE (X)DE -lSUUY RF5'EST OTHER NO. TYPE ACT. COORD- FASS CIA 55 M-l FOS FS l FS LT IJ ST FT FI MV EX CD (VRR) (CJ/RJ/AVT) NOTES:

B33Fol3A 3 '4 M-1078A 2 C l CJ-B33-01 SC ILSA D6 C ! C B33FIl38 - 3/4 M-1078E 2 C CJ-B3341 SC ILS A D4 C C I!33F0174 3/4 M-1078A 2 C i l CJ-U3341 l SC llSA D7 C l C l l 833F017B 3'4 , M-1078E 2 C CJ-83341 l

SC 115A D3 i C C ll33F019 3/4 M-1078A 2 B GL M OS C Q Q 2Y 833F020 l'4 M-1078A 2 B l GL M G7 C IQ Q 2Y D13F125 3>4 M-IO78!! 2 A GL M D7 ;j C Q J Q 2Y I!33FI26 3/4 M-1078B 2 A ]

GL M D7 C Q J Q 2Y {

^

B33F127 314 M-1078A 2 A I !

~

GL M II 7 C} Q J Q 2Y ll33Fl28 3/4 M-1078A 2 A

{

, GL M 11 7 C Q J Q 2Y t r

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. CII -1 SYSTEM: Cl1 - Control Rod Drise Hydraulic System i

VAI.VE r a lo tsi l REQUIRED TESTS AND FREQUENCY RELIFF VAI.VE SIZE (ht) 50- , IST CUDE CDDE ! SAFETY REWEST OTHER N-NO. TYPE ACT. WORD. PASS CIAE lM FS f P5 LT IJ ST FT PI RV EX CD (VRR) (CJ/IU!AVT) NOTES:

Cll-Il4 3 '4 M-1081B 2 C j 0 l} R RJ-Cll43 Wee 6 C SA G3 l 4 CII II5 1/2 M-108 t B A e i A\T<lla t %:e 6 C SA G6 C l -(

Cil-126 1/2 M-IC11B A B l 0 R R R AVT-Cll42 Nee 6 GL A G3 i y Cil-137 3?' M-1081B A B O {R R R AVT-Cll42 %ee 6 GL A G3 i Cil-138 t/2 M-10 SIB A C j AVT-Cli4l C SA GS C fl Q II Clif0f 0 i M-1081 A 2 B GL A l14 C Q Q Q 2Y CllF0tt 2 M-IO81A 2 B j l

GL A E6 C IQ Q Q 2Y l CllFbt) 2 M-108 t A 2 A I RJ<ll41 GL M C2 fC R J R 2Y CllF132 2 M-1081 A 2 C.A RJ<ll42 SC II'SA C2 1 C R J CilF128 314 M-1081 A P 2 A l-

01. II C2 C J 1 CliFISO I M-1081 A 2 B G A 11 5 C Q Q Q 2Y CliFist 2 M-1081 A 2 B GL J

A E7 C Q Q Q 2Y !

CilF323 6 M-108 t A A B AVT-Cil43 G M As C R ! R 2Y

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF *.UCLEAR STATION REVISION NO. 8 PUMP AND VALVE IN SERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. C41 -I SYSTEM: C41 - Standby Liquid Control System VAI.VE F & ID IST REQUIRED TESTS AND FREQUENCY RELIEF VALVE SI/J. (ht) NO. , IST CODE WDE SAFETY CAT. REQCEST OTHER SO. TYPE ACT- W ORD. PAS 5 CLASS pos-F5 PS LT LI ST FT FI RV EX CD (VRR) (CJ1U/AVT) NOT ES:

C4IF001A 3 M 1082 2 B O Q Q 2Y Clone emucm passive

GL M F4 C 2Y C41Fo lti 3 M-1082 1 2 D O Q Q 2Y Cluee pmhan passive Gl . M C4 f C 2Y C41FO4 A I I/2 M.1082 2 D 0 2Y X EXP F6 C41F004B I 1/2 M-1082 2 D 0 2Y l

X EXP D6 i C4t FO6 1 l '2 _ M-1082 I C O R RJ44141 Ewintrumve Testag SC stSA E7 C R I t '2 O C41FG7 M.1082 I C 1 gR RJ4.4141 Nwirieruneve Testeg, Valve SC SA E7 C ll R handmheel was rerrmved C4tF029A i I/2 M-1082 2 C O y 10Y RV SA F6 C }l 10Y C4tF0291) i 1/2 M-1082 2 C O ;0Y

{ l RV SA D6 C l 10Y l C4 t F033 A I I/2 M 1082 2 C O jQ C SA r6 C I2 C4tF03311 11/2 M-1082 2 C 0 Q l C SA D6 C Q I C4tFl50 3 M.IOS2 P 2 A j G 11 GI C J l' ,

C41Fl51 2 M.1082 P 2 C.A SC llSA G2 C J C4tF152 3/4 M 1082 P 2 A UL II F2 C J C41F222 11/2 M 1082 I C O ,

R RJC4141 Mn-trarumve Tesreg. Valve SC SA E7 0 l handwW was renunred

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 CRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. D23 -1 SYSTEM: D23 - Drywell Monitoring System VAX,VE F A ID IST l REQUIRED TESTS AND FREQUENCY RFLIEF VALVE SIZE (in) NO. , IST CODE CODE !sAlETY ' REQt'EST OTHER NO. TYPE ACT. COORD- PASS CLASS #~

lN F5 F5 LT IJ ST- FT P1 RV EX CD (YRR) (C.L1U!AVT) NOTES:

D33F591 3/4 M-1Il0A 2 A i GL M E6 C Q J Q 2Y l D23f593 3/4 M-III0A 2 A A GL M E6 C Q J Q 2Y 1 D33f593 314 M-ll10A 2 A l GL M D6 C { Q J Q 2Y D23F594 3/4 M-II10A 2 A GL- M D6 C Q lJ Q 2Y

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE IN3ERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -1 SYSTEM: EI2 - Residualllcat Removal System VALVE Ps.lD IsT l REQUIRED TESTS AND FREQUENCY I REL3EF VALVE SIZE (in.) No. , IST CODE WDE OTilER

[SA)ETY REQt'EST No. TYPE ACT. WORD. PASS C1 ASS CAT. pos-FS PS LT IJ ST FT P1 RV EX CD (vRR) (CJ/RJ/ OT) NOTES:

El2ft32 3 '4 M-1085fl P 2 A ,I GL 11 F4 I C J E12F003A 18 M-1085B 2 B 1 O Q Q 2Y GL M E8 !

E12FC338 18 M-1085A 2 B O Q Q 2Y GL M E3 E12fu4A 24 M.1085B 2 A O Q Q 2Y G M ) D4 C Q J Q 2Y E12FC34fl 24 M-10:5A 2 A l 0 iQ Q 2Y G M D7 l C lQ J Q 2Y E12F004C 24 M-1085C 2 A l 0 Q Q 2Y G M D6 l C Q J Q 2Y E12F009 I M-1085B 2 C,A O l 10Y RV SA E4 C i J 10Y E12F006A 18 M-108311 2 B l l G M D4 C i Q Q 2Y E12FC36B _

18 M-1085A 2 B G M D6 C Q Q 2Y El2FC38 20 M-1033g) I A c glgag G M F4 C C 2Y J C 2Y E12f1009 20 M-10 511 1 A CJ-E1241 O M F2 C $}l C 2Y J C 2Y Edfoll A 4 M-los311 P 2 A GL M E7 C J 2Y E12FollB 4 M-1085 A P 2 A l ll GL M E3 C J 2Y l F E12FoI7A I M 10851) 2 C.A 0 j 10Y '

RV SA D4 (i C i J 10Y El2Fol711 i M-1085 A 2 CA l 0 ll 10Y RV SA D6 ! C l J 10Y E12Fol7C 1 M-1085C 2 C.A O 10Y l

~{

RV SA C6 C )J 10Y l r

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTit . - PAGE NO. EI2 -2 SYSTEM: E12 - Residuallleat Removal System VAI.VE F A ID 15T REQUIRED TESTS AND FREQUENCY REllEF YAI.VE 887E (im) N0. . IST CODE NM lS.WETY REQUEST OFIIER

30. TYPE ALT. (t)ORD. FASS CIA 5S M* N FS FS LT IJ ST FT F1 RV EX CD OM) AMA%T) S us'Es-EI2F031 14 M-1085C 2 A l _

l OL M F4 C !Q J Q 2Y t 6 M.1085A I A l CJ-EI241 E121U23 GL M ' 11 3 C iC 2Y J C 2Y 18 M-10858 2 A O lQ Q 2Y El2F024A g _

O M F6 i C jQ J Q 2Y 18 M-1085 A 2 A O Q Q 2Y El2F024B O M F3 C Q J Q 2Y I C.A O 10Y E121025A M-1085B 2 RV SA G3 i C 8 10Y I C.A O IOY E!2F02SB M-1085A 2 RV SA G5 C fl J 10Y 2 C,A O 10Y E12Rt25C 3 M-1085C RV SA G4 C J IOY 18 M-1085B 2 A O Q Q 2Y }

El2F027A ,

O M G4 C Q J Q 2Y l la M-1085A 2 A O Q Q 2Y E12F0273

'l O M G5 C Q J Q 2Y 18 M.1085B 2 A O 'Q Q 2Y El21U28A O M 11 3 C Q J Q 2Y 18 M IC85A 2 A O Q Q 2Y El2F02813 G M 11 6 C Q J Q 2Y E12F03tA 18 M.IO85B 2 C l 0 Q {

C SA n$ fC Q j El2fD313 18 M-1085 A 2 C O lQ l C SA H6 C lQ [

El2F03tc 18 M-10 ESC 2 C O Q {

[

C SA C5 l C Q i 4 M-1085A 2 C.A O IOY El2F04 RV SA A4 C f J 10Y bf037A 12 M-1085tl 2 A GL M 11 3 C Q J Q 2Y

ENTERGY OPERATIONS,1NC. PROGRAM PLAN NO. CGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -3 l

SYSTEM: E12 - Residualifcat Removal System VALVE F A ID IST RELIEF lSA)ETYl REQUIRED TES13 AND FREQUENCY l

VALVE SIZE (ht) No. , IST CODE CODE l REQt'EST OTilER No. TYPE ACT. WORD. PASS Cm CAT.

l POS. f FS Ps LT IJ l ST FT FI RV EX CD FRR) (CML1/AVT) NOTES:

E12F03713 12 1-1085A 2 A l OL M 11 6 C l Q J Q 2Y E!2F040 4 M 10851) 2 B j

_ }l 01- $1 11 7 C IO Q 2Y ll E12F0GIA 14 M-108511 1 C,A O C 2Y CAE1243 l

C ASA 02 C C 2Y 2Y j E12F041H I4 M-1085 A I C,A O C 2Y CAEl243 C NSA 07 C C 2Y 2Y EI2F04tC 12 M-1085C I C.A O C 2Y CAE1243 '

C ASA G7 , C C 2Y J I 2Y El21042A 14 M-1085% I A O C C 2Y CJ-E12-04 O M G3 C C 2Y J C 2Y E12f0428 14 M-1085 A 1 A l 0 C C 2Y CJ-E1244 O M 06 I C C 2Y J C 2Y E!2F042C 12 M-1085C I p O C C 2Y CJ-E1244

]

O M G4 C C 2Y J C 2Y I E12tD44A 4 M-1085fl P 2 A i O !! II 2 . C J l E12F04411 4 M-1085A P 2 A l 0 !! 11 7 Cl J E12F046A 4 M-108511 2 C O OQ hirarumve Testmg4)uanerly C SA F5 k E12fT)4611 4 M-1085A 2 C O Q Netrarvuve Testmg4)uarterly C SA E6 EI2F046C 4 M 10850 2 C 3 IQ hl.arumve Testmghly C SA D5 I E12F047A 18 M-1085ft P 2 H O ,

2Y j O M C6 l i F12104713 18 M-1085 A P 2 B o 2Y O M C5 E121048A 18 M 108511 2 13 0 Q Q 2Y OL M E7 C Q Q 2Y

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -4 SYSTEM: E12 - Residual 11 cat Removal System VALVE P & ID isT REUEF VALVE SIZE (im) NO. , IST CUDE NE l5AFETY REQUIRED TESTS AND FREQUENCY RFQCEST' OTIIER No. TYPE ACT. LVORD. FA55 CLASS OT. pos F5 PS LT IJ ST FT F1 RV EX CD (VRR) QUAVT) NOTES:

E12F0488 18 M 1085A 2 B O Q Q 2Y Gl. M E2 C Q Q 2Y E12F049 4 M-10858 2 B ! ( {

O M OS fC IQ Q 2Y }

E12F050A 12 M-1085B 2 C.A CJ-E1246 l

C SA F3 C C 2Y l l EI2F0508 12 M-1085A 2 C.A 8 j CJ-E12-06 C SA F5 C C 2Y l !

El2F053A 12 M-10853 2 A j} CJ-EI245 l

GL M F4 C C 2Y C Yl 1 E12F09311 12 M 1085 A 2 A

                                                     .{                                                    j            CJ-E1245 Gl.      M        FS                       I   C      C      2Y     C      2Y                    I El2F099A         6         M-1085B           2    CA       O   l                            10Y RV       SA       C7                           C    l            J              10Y EI2F0558         6         M-1085 A          2    CA       Ol                               10Y             j RV       SA       C3                           C l               J              10Y              l EI2F056C        314        M-1085C     P     2     A                                                       1 GL        11      (15                          C                 J                        ]    l E12F060A       18         M-1085f t         2     B                                                 l

[ GL S ES ! C Q Q 2Y E12F0608 3/4 M-1085A 2 B { GL S FI C Q Q 2Y t EI2H41 3/4 M-1085A P 2 A l GL li G3 i C J E12F064A 4 M-1085fl 2 A 0 Q Q 2Y l o M C5 ,1 C Q J Q 2Y E12F06411 4 M-1085A 2 A 0 Q Q 2Y l l O M C6 I C Q J Q 2Y l EI2FC14C 4 M-1085C 2 A O Q O 2Y O M C5 C Q J Q 2Y EI21066A 18 M 1085tl 2 H O C C 2Y CJ-EI247 %e7 O M C3 i C C C 2Y

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -5 SYSTEM: E12 - ResidualIIcat Renxwal System VALVE P & ID INT REQti1 RED TESTS AND FREQUENCY REUEF VALVE SIZE (Im) NO. , IST (t)DE WDE $AFETY {r REQUEST OTHER

50. TYPE ACT. OtM)RD. PASS CLASS CAT. ros- lFS PS LT IJ ST PT FI RV EX CD OM) (GMAW NOTES:

El2F0668 _ IS M-1085A 2 B l O C C 2Y i CJ-E1247 Nese ? O M C8 C C C 2Y l E181V73A 2 M-1085B 2 A l GL M C7 C l Q J Q 2Y E12F0731) 2 M.1085A 2 A !} l 1 l GL M 11 3 l C i Q f J Q 2Y I E12F074A 2 M iO85B 2 B l GL M C6 C i Q Q 2Y El2F07411 2 M 1085A 2 B GL M 11 4 C Q Q 2Y E12F075A 3'4 M-1085Il 2 B GL S FS C Q Q 2Y El2107 Sit 3/4 M-1085A 2 B

GL S FI C Q Q 2Y El2FCJ2A i 1/2 M-1085B 2 B O Q Q 2Y GL M C4 E12fV82B 11/2 M-1085 A 2 B O Q Q 2Y l GL M C7 ) El3FC04A _ l 1/2 M.10858 2 C 0 Q SC ILSA C5 C i Q El2iV84tl I l'2 M-1085A 2 C O l Qj sC itsa C5 C i Q h El2108CC 4 l'2 M 1085C 2 C O Q g SC ILSA A4 C Q li EI2F0ijA i 1/2 M-1085Il 2 C O Q g sC lis^ C5 C Q H Ei2re89n I il2 j u-iO854 2 C O Q j sC nsA l C5 C Q ! El20089C 1I2 M-1085C 2 C O Q l sC IL3A A3 C Q i E12F094 O 18 M M-1061D O4 P 2 U C __ ] 2Y l Nee 2 l l

ENTERGY OPERATIONS,1NC. PROGRAM PLAN NO.GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -6 SYSTEM: E12 - RcsidualIIcat Removal S} stem VALVE ra lB isT NE1JFI VALVE SIZE (in.) NO. IST . CUDE N ll' MET.TYREQUIRED TESTS AND FREQUENCY CCAT. IlREQlT3?OTIIF.R NO. TYPE ACT. COORD. . PASS CIASS yog l ES PS LT IJ ST l FT F1 RV EX CD OW WMAM SOTEM: E12F096 18 M-106t D P 2 B i j- -j Nde2

O M G5 C 2Y I E12F099A 14 M-108511 A B O Q J j G 11 06 {

E12F09911 14 M 1085A A B O Q j l} G !! 03 } }{ E12FIO3A i 1/2 M.1085B P 2 C,A SC - IL$A fl7 C J El2F103B l Ii2 M-1085A P 2 C,A l SC ILSA B4 C I J E12F104A i 1/2 M 1085B P 2 C,A l ! SC I It2 ILSA B7 C l ) J EI2tl04B M-1085A P 2 C.A N SC ILSA 11 4 C II J E12Fl07A 3/4 M-1085B P 2 A { l Gl. Il 11 1 C I J EI2FIO7B 3/4 M-1085A P 2 A j UL 11 11 5 C i J E12F203 4 M 1085B A B [ j G A 06 f C I Q Q Q 2Y i ' I E12F282 M-1085A P 2 A ll

01. Il F3 C I J E12F213 1 M-1085A P 2 A i

[ j UI. Il F3 C {J F.F227 i M-108511 P 2 A j al- li D5 C T I E12F228 i M-108511 P 2 A GL 11 D5 C h

                                                                                                                      .J h

E12F234 i M-1085C P I A '

                                                                                                            }       l                                  4 GL         II      G6                              C                 l      '   J                                 l E12f249            3/4        M-lG85A       P      2     A l          N                                                                   f l                                                                                                                                                       O I                                       ot         si      n5                         i    C T--                        J                              h            I i

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS.M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E12 -7 . SYSTEM: El2 - Residual 11 cal Removal System VALVE P & ID Ist i REQUIRED TESTS AND FREQUENCY REIJEF VALVE SIZE (la) NO- . IST (1)DE CUDE ! SAFETY f REQUEST OTIII:R NO- TYPE ALT. (X)ORD. PAS 5 CLA.%S CAT. poi F5 PS LT LJ ST FT FI RV EX CD l (VRR) (CJ~elJ/AVT) NOTES: E12F250 3/4 M-1085A P 2 A . l - GL 11 D5 ! C f J El2F259 I M-1085B P 2 A I GL II E6 C l J El2F260 3 M 1085ft P 2 A l- l GL 11 E6 C l J l E12F261 1 M-1085B P 2 A GL If F6 C J E12F262 I M-1085B P 2 A GL 11 F6 C J E12F273 I I/2 M.1085A 2 C O Q SC It'SA D5 E32F274 I I/2 M-1085B 2 C 0 Q SC lt'5 A D3 E12F276 I M-1085A P 2 A GL li E3 C J E12F277 I M-1085A P 2 A Gl. II E3 C J , 1 E12F278 I I/2 M-1085C 2 C O Q SC llSA Il 2 E12F2m M-1085C P 2 A l GL 11 E5 C l J EI2F281 1 M-1085C P 2 A l GL II E4 C J l E12F290A I I/2 M.108511 2 A O Q Q 2Y GL M D5 C Q J Q 2Y t E12F290ll I tr2 M 1085A 2 A O Q Q 2Y Gl. M 11 5 C Q J Q 2Y E12F301 1/2 M-1085Il P 2 A l GL !! F7 C J El2F304 _ l.2 M-1085C P 2 A l _ GL ll F5 C l J !

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. CGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING- PAGE NO. E12 -8 SYSTEM: E12 - Residuallleat Removal System VALVE P a ID trT REQUIRED TESTS AND FREQUENCY RELIEF VALVE SIZE (in.) NO. , 15T ET)DE CT)DE l SAFETY REQt'EST OTilER No. TYPE ACT. COORD. PASS CIASS N- ps l LT fPOS ys IJ ST FT PI RV EX CD i (vRR) (CJ/R.LA%T) NOTES: E13F305 1/2 M-1085 A P 2 A { GL 11 F2 C J f

E12008 1/2 M-108511 2 C.A ! CJ-E1242 SC llSA F2 l C C 2Y J E13F310 1/2 M.1085f1 P 2 A GL 11 F6 C J E12Dil 1/2 M.1085C P 2 A l GL II F6 C l J E18Dl3 1/2 V-1085 A P 2 A GL 11 F3 C J E12n21 3/4 M-1085 A P 2 A y GL 11 E6 C J l E12D22 3/4 M-108511 P 2 A GL ll E5 C J El2O31 3/4 M-1085A P 2 A l GL 11 D5 C ! J El2F334 _ 1 M 1085A P 2 A GL 11 D5 C J E12F335 i M-1085A P 2 A GL 11 D5 C J E12F316 3/4 M-1085Il P 2 A GL 11 D5 C J El2O38 i M-108511 P 2 A GL 11 D5 C J E12F339 i M-108511 P 2 A GI. Il D$ C J E12F342 3/4 M-1085A P 2 A GL !! G3 C J E12F346 I M-10850 2 A l GL M F3 l C Q J Q 2Y El2n48 3/4 M-108511 A P 2 ( __ GL !! E$ l C J

ENTERGV OPERATIONS,INC. PF') GRAM PLAN NO. GCNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 - PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO.' E12 -9 SYSTEM: E12 - Residual Heat Removal System VALVE F A ID 15T REQUIRED TES13 AND FREQUENCY REUEF VALYE sI2E tht) No, IST CODE CODE f.uFETY REQUEST OTHER MD" TYPE ACT. CTM)RD. ~ PASS CLuS CAT. lpos FS PS LT IJ ST FT Pl RV EX CD [ (VitR) (CJ.'RJ/AVT) MyrEs: E12F349 3/4 M-1085B P 2 A { GL 11 D5 C l J EI2F350 3i4 M-1085A P 2 A l .y GL 11 7) 5 C l J E12F351 _ 3/4 M-1085A P 2 A l GL 11 E6 C t J E12F394 6 M-1085A i A CJ-E12-0) l @ G M 11 2 C iC 2Y J C 2Y ll E12FO 6 i M 1085C 2 C,A 1 SC ILSA F3 C IQ J EI2 FOS 3/4 M-1085C P 2 A GL !! F3 C J E12FCD9 3/4 M-s085C P 2 A GL !! F3 C J El2F416 ._. C 8 SA M-1085D 11 4 2 C {l C C CJ-E1248 EI2F423A F4 M-1085D 3 C l 0 l 10Y j RV SA F3 l C i 10Y g' E12F42311 3/4 M-1085D 3 C O 10Y RV SA C3 C 10Y E12F430A 3/4 M-1085B P 2 A G 11 G7 C J EI2F4300 3/4 M-1085A P 2 A l G 11 F2 ! C J E12F4)lA 3/4 M-108513 P 2 A l l GL 11 G7 C i J l E12F43111 3/4 M 1085A P 2 A } OL II F2 IC 1 J E12F412A 34 M-108511 P 2 A l l G 11 F7 C i J i E12F43211 3/4 M-1085A P 2 A G 11 F2 C J

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. ' E12 - 10

   ' SYSTEM: E12 - Residual!! cat Remm21 S 3stem VALVE         P & ID        IST                                                          RELIEF VALVE     b!IE(in)       NO. ,  IST  CODE  0)DE CAT.

l SAFETYREQUIRED TESTS AND FREQUENCY REQUEST OTHER NO. TYPE ACT. GM)RD. FASS CLA55 lm 95 PSlLT LJ ST FT FI RV EX CD (VRR) (1J1tJ/A%T) NOTES:

                   - 3/4                                                             '

EI2F433A 11-10858 P 2 A OL 11 F7 C 3 E18F033B 3'4 M-1085A F 2 A OL li F2 -C J _ _ _ _ _ - _-_ ___m______ __.___ _ _ _ _ __- _ - _.

ENTEFGV OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM l VALVE

SUMMARY

LISTING - PAGE NO. E21 -I SYSTEM: E21 - Low Pressure Core Spray System VALVE VALVE SIZE (in.) F A ID No.. . IST thT CODE CODE l SAFETY l REQUIRED TESTS AND FREQUENCY RELIEF REQl'EST OTiiER TYPE ACT. Pass CAT. pos-NO. COORD. CLASS FS PS LTlIJ ST FT Pl RV EX CD i OllR) (CJ.1LI/AVT) NOTE 5: E21lT)ol 24 M-1087 2 A O l 2Y opecpo emipasm , G M D6 C I Q J Q 2Y E21F003 16 M-1087 2 C 0 Q l C SA E2 C Q l E21F005 14 ' M-1087 i A O C C 2Y CJ-E2142 G M F5 C C 2Y J C 2Y E2 t FT)06 14 M-1087 I C,A O C 2Y cJ.E2141 C ASA F6 C C 2Y J 2Y E2tioll 4 M-1087 2 A O Q Q 2Y l G M E3 C Q J Q 2Y l E21Fol2 14 M-1087 P 2 A j E21Fol3 GL 3/4 M E5 M-1037 P 2 A C J 2Y ) GL 11 E6 C J E21F01 I t/2 M.1087 2 CA O l 30Y RV SA G5 C l J 10Y E2tF031 3/4 M-1087 2 CA O l 10Y { RV SA D6 C l J IOY i E21F034 I M-1087 2 C O lQ l SC Il$A F2 C l Q l E21F2e3 3/4 M-1081 P 2 A GL 'll F6 C J E21F207 I M lot 7 P l A GL 11 F6 C J E21F217 3/4 M-1087 P 2 A GL 11 E5 i C J E2tF218 3 '4 M-1087 P 2 A GL 11 E6 C J E21F221 l '2 M_ log 7 P 2 A l l GL !! E6 C l J -l E21F222 1/2 M-1087 P 2 A GL 11 E7 C J

ENTERGY OPERATIONS, INC. PROGH AM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM - VALVE

SUMMARY

LISTINC - PAGE NO. E22 -1 SYSTEM: E22 - High Pressure Core Spray System I VAI,VE P & ID IST REQUIRED TE5TS AND FREQUENCY RELIEF val VE - NO. , IST CODE CODE SAFETY

               %IZE (in)                                                                                       REQCEST   OTHER NO.       TYPE ACF.           GX)RD. Pass m     CAT. m       FN  PS LT   IJ ST  FT l PI   RV   EX CD     (VRR) (CARJ/AVT) NOTES:

E22F001 18 M-1086 2 B G M E8 C Q Q 2Y 4 E28F002 18 M-1086 2 C C SA E7 C Q E22F004 12 M-1086 i A O Q Q 2Y O M E4 C O 2Y J Q 2Y E23F005 14 M-1086 i C,A O C s 2Y CJ.E2241 C ASA E2 C C 2f J 2Y E22F006 i M-1086 2 C 0 l Q SC IISA CS C I, v E22F010 to M.1086 2 B GL M F4 C Q Q 2Y E22Foll 10 M.1086 2 B GL M G6 C O Q 2Y E22F012 4 M-1086 2 A O Q Q 2Y O M D5 C Q J Q 2Y E32tul4 3!4 M-1086 2 C,A O 10Y RV SA B5 C J 10Y E22F013 24 M-1086 2 A O Q Q 2Y O M C4 C Q T Q 2Y E22F016 24 M-1086 2 C O Q C SA C4 C Q - E22F021 3/4 M-1086 P 2 A l GL 11 D3 C J E22F023 12 M-1086 2 A GL M D4 C Q J Q 2Y , E22F024 _ I6 M.1086 2 C O Q

              'J         SA         E5                         C      Q E22F01?               I            M-loa 6         2   CA       O                                   10Y RV          SA         E5                         C                  J                10Y E22t039               I            M 1086          2    C                                                     i SC        li'S A       F4                         C      O                                      l

O ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM - VALVE

SUMMARY

LISTING - PAGE NO. E22 -2 , SYSTEM: E22 - Iligh Pressure Core Spray System VALVE P A ID IST I REQUIRED TESTS AND FREQUENCY RELIEF - VALVE SIZE (im) NO, IST CODE N SAFETY REQUEST OTHER NO. TYPE ACT. WORD, PA55 CIAs8 CAT. yOi FslPSlLT IJ - ST DT FI lRV EX CD (VER) (GUAVT) NOTES: E22F201_ 14 M-1086 P 2 A GL II E2 C l J E23F218 I M-1086 P i A { GL 31 D2 C j J E22F3cl i M-1086 P 2 A GL Il D4 C J E28F302 I M-1086 P 2 A GL 11 D4 C J E32F303 1/2 M-1086 P 2 A l GL 11 D4 C l J l E23F304 !!2 M-1086 P 2 A [ GL ll D3 l C J E22100 314 M-1086 P 2 A l G 11 B4 i C J - E23F801 3/4 M-IDS 6 P 2 A GL 11 B4 C J i o e s-

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E30 - 1 SYSTEM: E30 - Suppression Pool Makeup System VAISE F & ID IST REQUIRED TESTS AND FREQUENCY . REUEF VALVE NO- , IST CY)DE CODE SAFETY SIZE (km.) REQt'EST OTIIER NO- TYPE ACT. (Y)ORD. PASS CLASS N- POS. 63 PS LT IJ ST FT Pt RV EX CD (VRR) (C.LR.1/AVT) NOTES: B O Q Q 2y D0ft3tA _ 30 M-1096 2 y B M E7 fl DotC3IB 30 M-1096 2 B O l Q Q 2Y ( B M E3 l l O DOFD02A B 30 M M-1096 D7 2 B Q Q 2Y

                                                                                                 ]J DOF002B         30          M-1096         2     B    O     Q              Q      2Y B         M       D3 DOF003A         314         M-1096         2     C    O       R                                                    RJ-E3041   Netresumve Testeg SC        llSA     E6 DOF00311        3/4         M-1096         2     C    O       R                                                    RJ-E3041   Non-Intnsuve Testag SC        llSA     E4                                                                     I D0F391A         314         M-1096         2     A    O                             2Y             l                          Open pnenam pasuw .

GI- M C6 C Q J Q 2Y 1' DOF39 t B 3/4 M-1096 2 A O 2Y j open pondam pasaw GL M C4 C Q J Q 2Y l DOFS92A 3/4 M-1096 2 A O 2Y Open emaam passive GL M C6 C Q J Q 2Y DOF392B 3/4 M-1096 2 A O 2Y Open pmana pasave GL M C4 C Q J Q 2Y DOF$93A 3/4 M-1096 2 A O 2Y Open posamm passive GL M A6 C O J Q 2Y DOF393B 3/4 M-1096 2 A O 2Y Open pendam paseve GL M A4 C Q J Q 2Y D0F594A 3 '4 M-1096 2 A O l 2Y Open pontum panave GL M A6 C} Q J Q 2Y E30F59411 3/4 M-1096 2 A O 2Y Opcn paamm pasave GL M A4 C Q J Q 2Y

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VdLVE

SUMMARY

LISTING - PAGE NO. E32 - 1

SYSTEM: E32 - MSIV Leakage Control System VALVE F A ID IST . REQUIRED TES'IS AND FREQUENCY RELIEF VALVE SIZE (in.) 50. . IST CODE CODE' lS.tf1TY REQUEST OTHER No. TYPE ACT. COORD. PASS C1 ASS M* POS. FS PS LT IJ ST IT FI f RV EX CD (VRR) (C.L1U/AVF) NOTES: D3F001A I 1/2 M-1097 I A i 0 C C 2Y CJ-E3241

C'. M B5 fC C J C 2Y D3FOIE I 1/2 M-1097 i A O C C 2Y CAD 241 GL M G5 C C J C 2Y E33F00lj i I/2 M-1097 i A O C C 2Y j cj-D241 GL M D5 C C J C 2Y I E33F00lN I 1/2 M-1097 I .A O C C 2Y CJ-D241 GL M E5 C C J C 2Y E33F003A I l'2 M-1097 2 H O C C 2Y CIE32-01 GL M D5 C C C 2Y D2iM2E I t/2 C C 2Y GL M M-1097 GS 2 B (0C

{ C C 2Y t CLE3241 D2FU3J I 1/2 M luv7 2 B O C C 2Y CJ-D2-01 GL M D5 C C C 2Y D2iTMJ2N I I/2 M-1097 2 H O C C 2Y CJ-E3241 UL M E5 C C C 2Y E32FO6 2 M-1097 2 B O C C 2Y CJ-D241 GL M F2 C C C 2Y 2 M-1097 i o C C 2Y E33fDc7 2 B CJ-E3241 GL M F2 C C C 2Y E32F00s 2 M-1097 2 H O [C , C 2Y CJ-E3241 GL M F2 Cl C l C 2Y E33FQ 9 2 M-1097 2 H Ol C C 2Y . CJ-E3248 GL M F2 C i C C 2Y l D2F010 3/4 M-1097 2 C O Q SC li'SA F7 E32F0II 3'4 M-1097 2 C 0 Q SC ll/SA E3 C Q

                          ' ENTERGY OPERATIONS, INC.                                              PROGRAM PLAN NO. GCNS-M-189.1 GRAND GULF NUCLEAR STATION                                                         REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM                                            VALVE

SUMMARY

LISTING - PAGE NO. E38 - 1 SYSTEM: E38 - Fcedwater Leakage Control System VALVE F a ID . IST - l REQUIRED TESTS AND FREQUENCY REuEr VAL 4E SIZE (ist) NO. , IST CODE CODE SAFETY GT. REQUEST OTHER

     . No. TYPE ACT.        (Y)ORD. PAS 5 Ct. ASS         pos-FS   PS LT   LJ ST PT  FI  RV  EX CD     (VRR) (G11.5/A%T) NOT ES:

D8FD01A i 112 M-Ill2 2 B 0- C C 2Y CAE384I GL M B4 C C C 2Y D8F001B Gl. I 1/2 M M.Ill2 I B , O C. j C 2Y CAD 841 04 l C C C 2Y D8F003A 11/2 M-Ill2 I C O jR C RGE CAD 842 Sample DammenMy SC ILSA 06 C (C RJ-D841 . D8F002B 31/2 M-Ill2 C O R C I. REWI CADS-02 Sargle Daansembly - SC li'SA E6 C C RJ-D841 ; DSF003A I 1/2 M.1112 2 C O R C REMI C D842 Sample DisassenMy SC ILSA C6 C C RAD 8-01 D8HM)38 I l'2 M-III2 2 C O R C CADS 42 ScQ Dansmembly SC IL3A VRREMI Il6 C C- RADS-01

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF N'JCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. ESI - 1 SYSTEM: E51 - Reactor Core Isolation Cooling S3 stem VALVE P A ID IST REQUIRED TESTS AND FREQLENCY REl EF VALVE sl7E (in) 50. . IST CODE u)DE SAFETY OT. RFQtTST OTilER N O. TYPE ACT. PAM CLASS M j OX)RD.

                                                                                        -FsfPslLT          IJ ST IT PI           RV    EX (1)        (VRR)  (CJ RJ/A%T)   SOTES:

ESIDC31 16 M-108313 P 2 D l ! Replace every 3 years RD C7 l C l E5tfC34 1 M-1083B 2 11 O lj 2Y Open pmamm pamve l GL A 11 6 C ll Q Q Q 2Y l E91FC39 i M-108313 2 B O Q Q 2Y _ l UL A B7 C Q Q Q 2Y f ESIF010 G 6 M M-1083 A D4 2 11 l 0 C l lQ Qj

                                                                                                                 }          2Y 2Y l                          Open emamm paan E$1Foli                         6        M-1083 A         2      C     i    O        Q                                                     l

{ C SA D2 I C Q l ESif013 6 M-1083 A 2 A 0 Q Q 2Y l G M G5 i C Q 2Y Q 2Y E$1rol7 3'4 O RV SA M-1083 A E2 2 C C l 1

                                                                                                                           ] IOY
                                                                                                                               ! 10Y ESit0IS                      I I/2       M-108311         2      C          O                                                10Y RV                 SA      G4                              C                                                10Y E31Fol9                          2       M.1083A          2      A          O        Q                     Q            2Y                   j UL                 M        E4                             C        Q                  J  Q            2Y                   !

E31F022 4 .f-1083 A 2 B l J GL M F5 Q Q 2Y I E91F025 l 1/2 M-108311 2 B o 2Y Open psamm pamve {l

GL A E3 C ll Q Q Q 2Y E31F026 I l/2 M-108311 2 11 0 2Y .

Open punnm passive GL A D3 C Q Q Q 2Y O E311030 C 6 SA M 1083A 11 5 2 C i C ! { Q Q{ l R RJ-E51-02 thsassemble escry refucimg outage E$1F031 6 M.1083 A 2 A O ll Q Q 2Y G M 11 6 i C If Q J Q W ESil040 ,_ 20 M-1083 A 2 C O Q wie j E511'043 6 M.IO3311 2 . 11 O Q Q 2Y

ENTERGY OPER ATIONS, INC. FROGRAM PLAN NO. GGNS-M-189.1 CRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. ESI -2 SYSTEM: E51 - Reactor Core Isolation Cooling System VAIXE P A ID isT l REQUIRED TESTS AND FREQUENCY REl_lEF VALVE SIZE (k) IST CODE CUDE is.U ETY

50. ,

M- ; REQt'EST OFilER No. TYPE ACT. COORD. PASS CLG l POL Ps f Ps f I.T IJ ST FT PI RV EX l CD (VRR) (Cl3U/AVT) SOFEs: E5tF046 _ 2 M-108311 2 11 O Q Q 2Y GL M F6 E9tF047 2 M.1083tl 2 C O Q Nee 4 _ l SC ILSA 11 6 l E5tF05J 4 M-1083A 2 B l 0 M DS C lQ Q 2Y E91Hg3 10 A O M 108313 I l 2Y j CAESI41 Open pudum pasuw 0 M O5 C C 2Y J C I 2Y l E511064 10 M-1083B i A O 2Y CAE5141 Open p=ake pasaw G M G4 C C 2Y J C 2Y E5tF065 6 M.IO83 A 2 C.A O lC CAE5142 C SA 06 C j Q 2Y E9tF063 20 M 1083A 2 A O 2Y (p pwn. p ,,w

0 M C4 C Q J Q 2Y ! E31F072 3/4 M 1083k1 P 2 A l GI. Il 64 C l J FJIF076 i M.IOS3B i A li Gl. M 05 C Q 2Y J Q 2Y E51F077 _ 21/2 M 1083A 2 A O j 2Y Open ps.tum passsw G M C5 C ! Q J Q 2Y ESIF078 I l'2 M-1083A 2 A O 2Y open po. gam pas ve GI- M C6 C Q J Q 2Y E511079 21/2 M.1083 A 2 C O Q R RAE3141 Sample IAsassembly RRCN C SA CS C Qf ESIl081 21/2 M 1083A 2 C O Q R RJ-E51-01 Sample thsasocmlAy RR e al C SA C6 C Q E9tFOTO I M 1083A 2 C 1 O 10Y RV SA ES IC 10Y E51F095 2 M-Ic83tl 2 II 0 Q Q 2Y l Gl. M E4 l E51F204 6 M-1083A 2 C l 0 Q

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.I GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. ESI -3 SYSTEM: E51 - Reactor Core Isolation Cooling Sysem VAIXE F & ID INT i REQUIRED TESTS AND FREQUENCY I RELar7 VAI.YE ElZE (ht) MA , 15T . CODE CW lMFETYl . {f REQtTST OTHER MA TYPE M T. moRD. PA59 Ct.A55 CAT.

                                                                              ! m f is l F5 l LT tJ l ST FTlFI . RVlEXlC1DI (TRA)                                 (G RkA%T), W h E91F291           1          M-IOSJA              F              2       AN          {I                                                       ]

GL II E6 l} C II J i ESIF252 i M-los3A F 2 Al [ ? 8 l @ } GL II E6 I C l l Jl I H [ ; _ ESIF257 IG M-10E3A F 2 A l Q GL C i !! it l Cs 3 E31F234 3/4 M-IOS3A F 2 A l !) l GL II C4 i C f J f

                                                                                           '                                                  f E31F269 C

3'4 II M-1083A fl6 P 2 A[ I C l

                                                                                     !      l   fJ                                            i l

I E31F77J 3/4 M-1053A F 2 A y l @ GL II C I J li II 11 6 E3 f f278 3/4 M-1083A F 2 A l l l 0 Il !!6 C -

                                                                                     >                   Jl                           I E3tF273          3c4         M-1081A             F             2         A                       l                                       l    g                  l
                                                                                   }}

GL II L6 C ll IJ i li i Twkne Try & Throule Valw ESITTOT 4 M-IOS311 F A B O ll 2Y l f G M Es ii ! i

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M.139.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E61 -I SYSTEM: E61 - Combusuble Gas Control Systems VAIXE vAs.VE r A ID 15T 857 - (UDE N

                                                         !       I    REQUIRED TESTS AND FREQUENCY            f    RELIEF SIZE (in)       Mr.                      ! SAFETY l                                           f. REQCE5Y     OTHER (voan.              CAT-Mr      YYrE ACT.              r*S8 class        i ros. I r3 l rs l .Y l u l SY l FY l rs l xv Ex l Cn I O'RR)   puAm      xnEs            :

F/,IfDOI A 10 M_lgyi 2 C O 'i Q j y { 2Y l C SA E7 I C il Q l 2Y I Il FilF001B 10 M-109I 2 C ! O yQ l 2Y l j C SA D7 1 C il Q i l 2Y $ I IF002A Id M.IO91 2 C ti O nQ ZY f l C 5A F6 f C bQ 2Y h l LIIF002D 10 M.IO91 2 C h O yQl l l 2Y l g C SA D6 !i C il Q i i j 2Y I Q ELIFM)A 10 M.IO91 2 B q O gQ Q 2Y g B M F6 4 C 11 O Q 2Y 3 EflF001B 10 M-1091 2 11 y O yQ l Q 2Y j l g D M D6 Il C }l Q j Q 2Y l l 4 E.',1f 004A 10 i M.IO9I 2 C O ll Q j 2Y j q C 5A { E4 9 C 11 Q i i 2Y I I2 E34FWil to M.1091 2 C 1[ O HQ 2Y g C SA E2 !i C dQ 2Y li FLIFCISA 10 M.IO98 2 B O HQ j l jQj 2Y H M E4 il C ii V i I ! ('l 2Y 6 Falf005B 10 M-1091 2 B ll 0 yQ Q j 2Y l D M E3 0 C li Q Q j 2Y l ,1 8

E21FC37 _

M-1091 2 B p H l l g B A n7 N C fi Q l I jQ Q 2Y ji i E41F009 6 t M 1091 2 A g l g I l n A I ni e C uQi s Q Q 2Y i il F6tFUIO 6 M-1091 2 A !! _ l { n a n3 Il C it Q s Q'Q zY I f%IF017 14 M-le9: r 2 i y >

                                                                 !i cl.      n        ni                    i     C if             is                                1 taltv20             s      i M-109I          2    BB            H    j   l                           l       p o       e   I n7                       !!    C nQ i       i           O    Q    2Y    t        li l

Lalfo% j 6 M-Il008 2 A [ H l L l H A E7 h C il Q [ J Q Q 2Y l I

ENTERGY OPERATIONS, INC. TROGRAM PLAN NO. GGNS41-149.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E61 -2 SYSTEM: E61 - Combusible Gas Control Systems VAixt 15T y VALTE M/E On.) r a ID SO. , NT (.UDE (UDE L i MIETYP-- REQUIRED TESTS AND FREQUENCY

                                                                                                                                          -t h Rruts REQt F5T                    OillER So.        73 FE ACT.        (UORD. FASS C1A55 J

CAT. q pos p, F5 l F5 l LT l IJ - 5T f FT FI l RV . EXf(DN (VER) ICNAVO l NOFF5: FAIF037 A i 6_] M-Ilool3 2 {' l { j j l l H A \ E6 C H Q i l J lQl Qf ZY i i t U E617595A 14 j M-1098 2 A O ! (g,em piesmm pammw

                                                                                         }                           l 2Y                   p GL       M l 11 4                                d      C   h Q l       i          J       Q       l 2Y          l        4                                      i E61FS95H (          14             M-1091                    A          O         j                                }2 2

f4 } l ] [ {] e g en pmemm peusw f_GL M II e C tt Q l ! fJ IQl i 2Y l l i H 3'4 O y FAIF395C i M-1991 2 A l[h i l l 2Y j j l p open g%m pamew GL M l !!2 C it Q l J Qj i 2Y I f I d 34 O j F41F595D M-1091 2 A !! l } j_{ { 2Y l l_j ij opee pe.sa.m pas e GL M II , , C dQ I i 8 J iU I 2Y I I d 34

  %I F*%4 [

l GL u M-lO98 2 A }if O

                                                                                   ]                                 {Y        l            3                                         open ,         pe ne G4                                 C 0Q {                     J       Q       ! 2Y       !           d E6t F 5%H           34             M-1991             2      A    g     o               l                       l      2Y l               j                                         open pase m pen w l

GI M G4 9 C "Q I J 4Q} 2Y l i k F6t F596C 34 _. M-1091 2 A ll 0 p l l l l 2Y j j ge ponom peanw l GL M G2 h C dQ l IJ lQ t 2Y l 4 i ! E61F396D 1_ 3' 4 M M-1091 2 A ii O {_ { { 2Y j open pwamm pe-w f GL G3 h C lt U J lQ l 2Y d f6tF397A 34 M-IM A GL M 11 4 2 {OC ] i! ll Q l lJ Q 2Y { 2Y j ti (Openpunamreneew I E61FS973 34 l M-1091 2 A j' GL M } 11 4 { C0]

                                                                       . il   Q l

{ _1

i J Q { 2Y i 2V i i i i t open pn.imm pen w 34 OO E41F?97C [ l GL M M-1091

                                       !! 2 2 1 l

A

                                                                       !  C DQ !

{ {]_ i J tQ! 2Y 2Y E gwe reae l***' tair597D 34 u-IO98 l 2 A 0 jj [ } } { 2Y Open p wame pamese Gt u li , ! : C aQ ! i J tQ i 2Y i c 34 0]__ E61F m A M-1091 A 2Y iopen prisam pamew . Gt 14 u G4 l2 e C nQ O i ]i_]JiQi _ 1 2Y l i jl n ! E61 f $9*.13 ~j M-109I 2 A p 2Y lOpenpaustn.pe-se FT}C6F i l l l l l l !l 7;t u l G4 ! T il Q 2Y I_ ?! l 34 M-109I 2 A O l 2Y opeopnemmp a w E6t F5m? [ i l I l } { l p I Gl. M G2 ! C }i ii~b - '}l~ iOi N iiJ

                                                                                                              ~
                                                                                                                                !      I. II

ENTERGY OPERATIONS,INC PROGRAM PIAN NO. GGNbM-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. E61 -3 SYSTEM: E61 - Combustble Gas Control Systems vrtAE rarD IsT li l REQUIRED TESTS AND FREQUENCY RELiff VAtvr sizz om> x3. . IST CODE CODE MFEn' REQtTST OTHER CAT. (( g TvFE ACT, F955 CIAS$ N#1 CtM)RD. F? F5lLTl1J STlPT)FI RV EX ! CD 01 tit) fl1 LEA %T) M7TD: e3nr39sa 14 u-io9 2 A y zy op p

o ll ,

ct u o3 H e no s o zr e I

t ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. G33 - 1 SYSTEM: G33 - Reactor Water Cicanup Splem VAI.4 E F A ID i 157 il i REQUIRED TESTS AND FREQUENCY I! RELIEF VALVE 5 TIE (in) 50- , 19T CODE U M 05AFETY , 1 ! REQtEST UTifER

      .%O.       TYFE ACT.       G jostD. FASS CLAS5 CAT.} yog              is l FS     LT   IJ!STlFT      Pt RV EX     CD !      (VRR)    (CNAVT) NOTES:

G337001 6 M-1079 A ji CJ413 Mt I 3 ! l { l l { G M FS I C i C! i J CI 2Y I i G331002 , 3/4 M-3079 F I A ll f l l GL II F4 h C ll J l ! 6 M-1079 A C34}3 M t G336004 [ ll l lG M F4 L C 4C I 3 C 2Y M([ ; G33fE 3 4 ! M-1379 2 A l N l l l l G M l C6 I C il Q iJ Q i 2Y { } G3n034 4 A h-1079 { 2 l ll l l G M C7 e 1 C !! O J Q 2Y ! ll G33F039 6 M.3079 2 A ll ll ll { CJ413 Lot G M GS h C lj C J C 2Y II I G33F040 6 M-IO79 2 A ll ll CJ4}}MI G M G4 li C if C J C 2Y G33F032A 6 M-1079 2 C ll l RJ4}) M I C sA G7 I! C i R G33 FOS 2B C 6 SA M-1079 2 Cl l l RJ4333-01 11 7 i C l R G33FU$3 4 M-1079 2 A l CJ4}3M t 1 ll l 4 O M E2 I C ii C 3 C 2Y j 4 A G331094 _ G M M-8079 F2 2 { i ll C lt C 3 C 2Y CJ413348 34 ' M-10h A G33FOSS F 2 -

                                                                        }                          l                           l GL        Il       11 4                     .

C ll Jl Ji G13 tut 3/4 M-1079 F 2 A { ll t 1 I l UL If F2 [ C Ii } J ! f 14 G331079 GL II M-1079 C7 F 2 A { il C ii { J l ll G3M234 4 M-1079 A j B l! _ ll U A Gg If C ll Q Q Q 2Y ! G33F133 4 M-1079 A 13 I I ____ [ G A Fs I C ! O Q Q 2Y !

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M.139.1 GRAND GULF NUCLEAR STATION REVISION NO.8 FUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - FACE NO. G33 -2 SYSTEM: G33 -' Reactor Water Cleanup System VALVE ra in isT l REQUIRED TESTS AND FREQUENCY j RELIEF YALVE SIZE 0m) No. , 15T CODE N- SAFETY OTHER REFEST MO. TYPE ACT. G M MtD. FASS GA55 M, . M F5 PS LT IJ 5T FT FI RV EX CD OM) AMAVT) NOTF5: G33F2l30 6 M-3079 1 B C3-G3M2

G M GS C C C 2Y il G33F231 6 M 1079 .B cm3w2 3 !

l l o u o4 C iC C 2Y I il c33F258 6 u-3079 : A y j j cmjw G M ES lI C IC 3 C 2Y i-03n353 6 u 307, 2 B C3mw2 H l f G M E4 C ji C i C 2Y ! i 4

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS.M-189.1 GRAP'D GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. G36 -I SYSTEM: G36 - RWCU Filter /Demmeraluer S3 stem t VALVE F A ID IST REQUIRED TESTS AND FREQUENCY l-. RELIEF VALVF. StIE k) NO. , 15T CODE CODE lsryyyg I OTHER

                                                  ,                                                  ;   REQUE5T CAT.

NO- Tyre Acr. tuomD. FASS IA55 lN rs f rs l LT IJ ST FT F1 RV EX CD l OM) A M A%T) NOTE & 4 G MFl28 M-los08 2 A l } l G A G3 h{ C 1Q J Q Q 2Y ll GMF106 4 M-1080H 2 A ! H l G A G2 i C Il Q lJ Q Q 2Y G% FIDS 4 M-1080B A B l l Q G A G3 C lQ Q Q 2Y II I GMF109 4 M-1080B A B l l} l l G A G4 I C il Q Q Q 2Y ji f

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. G41 -I SYSTEM: G41 - Fuel Pool Coolmg and Cleanup System vat.vE ra ID REuEF WDE.}%AIETY[REQUIRED TESTS AND FREQUENCY isi VAISE IST l f SIZE 0m) MO. , EUDE 1 Rif)CEST OTHER SO. TYPE ACT. G)ORD. FASS CLu$ CAT. j pog F3 ) PS l 1.T ) W ( ST ) FT l FI l RV EX l O h (VRR) (CJ181A%T) MDTE5: G4tF002 3 M-1088E A B i !! I l. O A OS C II Q hQ 2Y I G4:F010A 8 u.108E A C j O gQ ] C sA C3 i C if O ! ;! G41F01013 8 M.IO*SE A C j O I Q i l C SA A$ ! C i Q } l G41FDl7 8 l M-1083E A B l O l} Q { l g B 11 I 11 4 - C il V I i li G41F039 10 M.lostE A 11 ! y l B A D3 i C ll Q Q 2Y I G4lFUd! 10 M.10g3E A O ! Q Q 2Y j B l l GL M ES ! i ! ! 10 M.loggE A C y G4tF022 [ l l l %se $ iC sA DI I C il Q l I GelFO:s ( 8 [ M-1083E 2 A Il y 8 l l , l GL M l Il 6 h C Il Q l J lQ 2Y j G4 t FU29 8 M-10 8E 2 A i y ! l G M As I C if Q l J Q 2Y I G41FU.32 12 M-1088E 3 B y ll G A El C II Q Q Q 2Y li G41F033 12 M-lostE 3 B l l } i l 0 A El l C IQ l Q Q l 2Y h G41F035 12 M-1055E A B O ll Q ! O 31 G4 il , l G4 t t'040 8 M-1088C 2 C.A jl l g C SA II ) C !! Q j 1 J H GOLF 04) 10 M 1088E A II Q ' Q 2Y j l O l GL M D$ il I l ! G4tt004 5 M-lossC 2 A I j l l j U M 11 6 l C ll Q 3 J lQ 2Y { IO M-10g3E j G4tF045 It A D3 A B 4 [ ] { Q { l C t! Q l l 2Y I

ENTERGY OPERATIONS,1NC. PROGRAM PLAN NO. GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. G41 -2 SYSTEM: G41 - Fuel Pool Coolmg and Cleanup S)sicm VAX.VE F A ID 15T VALVE SIZE (ist) NO. , 15T WDF WM !,5AHTYl U I l REQUIRED TEST 3 AND FREQUENCY ij Rn 1EF REQUEST OTHER l g MA TYFE ACT. CUORD- FA55 CLA55 N

O POS fl,54 FPS 1.T IJ ST ST FI J RV EX CD (VRR) ' (CA RJ'AVT) M7TE5:

G41HM7 3 M-1088C 3 Bh il l Il G A G3 !I C I! Q I Q Q 2Y l G4IfD48 10 M-1088E A I C

                                                          }                          l                 y             &

Nac 3 C sA DI l l{t C nQ 1 9 ! G4:re23 f 12 u-1088C F 2 A j jj l l l ! y } jG II B8 ! C li iJ l 1 ! li l j G41705? B 18 n M-1088E A B i[h O lln Q { j E6 i i i G4tF201 12 M-1088C F 2 A ll il l j {l C II B8 0 C h J l l l1 G4lD26 B 18 11 M-1088E F5 A B[ ' O lj Q il g il G41F268 3 M-1088C 3 C j ll { ft y C SA r4 } C li Q i il G41D00A 17 M-1088E 3 C y O p l 10Y y RV SA C6 (I C ij j 10Y ll G4tD000 IG M-1088E 3 C O lj 5 10Y j l1, *l RV SA A6 il C 11 I IOY I l d G4tD01A 3/4 M 1088E 3 C 1 0 y 10Y : RV SA C3 I C d ICY - G4tD01B 14 M-1088E 3 C ll 0 l 10f [ RV SA A3 i II C l 10Y l G41D40 1- 4 M-1088C F 2 A i

                                                            @                    l                      l],

GE 'I 11 2 i C U J l N

i G41 H48 18 M-1088E A O jQ B }} B 11 F5 II 'l D

ENTERGY OPERATIONS,INC. PROGRAM FLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. GM -1 SYSTEM: G46 - FPCCU Filter /Demineralizer System VALVE F A ID IST l REQUIRED TESTS AND FREQUENCY ar_t.tEr VALVE SIZE (la) .No, . 15T G)DE CODE iSAFEn' CAT. MF F NO. TYPE ACT. uxMtIA Pass class jm l , g , G 4F253 3 M-sc89 A B j

                                                            !l                                g                 g               ,

o ^ i E4 C l} Q j Q Q 2Y N l k l I i i

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS.M.189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. M23 - 1 SYSTEM: M23 - Contamment ard Drywell Airlock VAI,VE ' F A ID 15 7 l' REQUIRED TESI3 AND FREQUENCY Mrt Er Vas_VE s ZE On) Nn. IST CODE (UDE 1;MITTY OTHER REQCEST Na TYPF, ACT, CVONn FASS CLAS5 CAI-l FOS. F5fF5l1T U ST F'r l FI { KV l EX l O Olut) [ 63RAAVT) WM M23F017A i 2 M-II24B 2 C, A [ O j l IoY g ; { RV SA G7 ! C I- l J toy ji l M23tul/D 2 A 3324C 2 CA i O {j 30Y l av sA o, ; C y 3 ioy s k

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO.GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. M41 -1 SYSTEM: M41 - Containment Cooling Sysem VALVE F e ID 15T I l REQUIRED TESTS AND FR2QUENCY RELitr VALVE IST Q)DE ON l SII.E (In) No. . liAFED] : REQ 0EST OTHER No. TYPE ACT. GM O. FASS CLA55 CAT. l POS. l M f M f IT f IJ f ST f FT F1 RV EX (D f OltR) (C2111A%T) N)TE5: M4t FC27 20 ~ M-in00A A B I! l l

II A D2 I C lQ Q Q 2Y O M41F003 } 20 M-Il00A A B ! g l [

lB A C2 . C i Q Q Q 2Y I il M4tFOII B 20 A M-Il00A B6 2 A 1 j l l j 1 C il Q l J Q Q 2Y I d M41!Cl2 20 M-Il00A 2 A l C A lI l { { $ B6 i C 11 Q l J Q Q 2Y l l l !! 20 M-Il01 M41F013 B A DI 2 B { C ii J Q Q 2Y MelF;IS 20 M-Il01 2 11 j H B A D2 C ij Q Q Q 2Y l 20 M-Il01 M4 t F216 B A 2 B llil H [ $ G3 C ll Q Q Q ' 2Y N i M41Fol7 20 M-Il01 2 Bl 4 __ ; It A ll a , l C hQ Q Q 2( M41F034 20 M.IIDOA 2 A _ g B A FI C O J Q Q 2Y il M411035 20 M-IIDOA 2 A !i j l . j B A FI lj C lQ J Q Q 2Y I: M41F036 20 M 1100A A B 'lj l i l 15 A G2 lI C lQ Q Q 2Y I } M4tF037 20 M IIOOA A B l{ l B A 02 p C i O Q Q 2Y 1 M21F042 3/4 M-Il00A P 2 A y l }{ ul- B B6 C il J j 11 M4 tF031 3/4 M-Il00A P 2 A I l ut B on c i J } MilF054

                  ' ~61.

14 11 M-Ilooll F6 P 2 A i i C II 11 1 [ j~l

                                                                                             ! J i                            {

I{t

ENTERGY OPERATIONS,INC. PROGRAM FLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. M61 - 1 SYSTEM: M61 - Contailu nent leak Rate Test Sisem VALVE P t. !' 15T l REQUIRED TESTS AND FREQUENCY RELIEF VALVE MIZE (Im) X- 15T (DDE EN MFETY [ M REQtT5T OTHER NO- TYPE ACT. COGt.4. PA55 CLAS5 N- M ts PS f LT 1J ST FT Pt RV EX CD lI 0 114 QUAVT) WTER h21F009 14 M-Illl A P 2 A {

l GL 31 D4 i C } J EfotfDI) 14 M-Illl A P 2 A l GL 11 E4 C J l bl61Fol4 1 M-Illl A P 2 A y } g I GL II E7 C ll l J d MellVIS I M-Illl A P 2 A l GL 81 E7 ! C 3 M6tF016 i M-Illl A P 2 A l l

GL li D7 i C J $ kulFol7 i M-Illl A P 2 A ll GL Il D7 C }l J kl68Folt 3 M-IllI A P 2 A j j j GL 11 C7 'I C i J f At6tFol9 I A M-Illl A P 2 ll l l l GL 13 C7 C ll Jl N l [ 1

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNEM-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. M71 -I SYSTEM: M71 - Containment and Drywell Instrumentaten and Control Sysicm VAut raid Isr ! l REQUIRED TESTS AND FREQUENCY RnJEF VALVE SIZE (Ist) NO. . 15T (TM N ti4f1TY OTHER REQUEST No. TYPE ACF. (UORD. PAS 5 CLASS N-fN F5 F5lLT LJ ST FTlFIlRV EX f CD (VRR} (CARSAVT) M)TE5: M71F391A F4 M-Ill0A 2 A i O I l 2Y j % p posen, - GL M C7 l C l Qj J Q 2Y I M7lF59tB F4 M-Ill0A 2 A O l 2Y Opeu pmatzs peenve l' GL M C3 C 't Q J Q 2Y l M71F*93A 3/4 M-Il10A 2 A 2Y openpwn p mane l 0 l GL M C7 i C IQ J Q 2Y M73 F392!1 F4 M-Ill0A 2 A O jl l 2Y Open postun yannwe GL M C3 C II Q l J Q 2Y M?tFD) F4 M-Ill0A 2 A l l GL M D3 I C !O J Q R M7tF594 3 '8 M-Ill0A 2 j A [ GL M E3 ! C iQ J Q 2Y M71F395 I M.ll10A 2 A i GL M E3 C i O J Q 2Y I l

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO.GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P11 - 1 SYSTEM: PIi - Condensate and Refueling Water Stuage and Transfer System VALVE P&ID IST RELIEF

                                                            ; SAFETY REQUIRED TESTS AND FREQUENCY l                                              i VALVE          MZE (ba.)       No. ,  IST  CUDE   WDE               l                                  j      REQUL5T     OTHER No.        TYPE ACT.       WORD    FA55 C1.A55 CAT. ljposIF5lF5   LT IJ ST FT F1          RV EX CD !        (VRR)   (C11U/A%T)   N,sTE5:

PilD004 10 M-1065 P A D I l j l Reptm.e curv

years RD SA D6 ! C i i l PIIFOO4 6 M.1065 2 C.A l H i g

C 5A Es I C ii O J II PillV47 12 M-l%S A B i ll l { l G A US ! C li Q QIQ 2Y l PillMI 12 M.:%S A B l O A ( !, B4 i C !O Q Q 2Y l Pf ifTJ63 s ! M-1065 A B { H f G A l G6 l C II O O Q 2Y ! Pil106'l s 1 M-1065 A B y l

l G A G6 C 0Q t OlQ 2Y 11 P11FM4 12 M-1065 A B 1 l M G A D5 C II'Q Q Q ! 2Y li

> Pi tf%9 12 l M-lO65 A B l! f l O A l D4 lI C ih Q Q Q 2Y j PIIF066 i 12 M.IO65 A B l l fG A C5 C iO Q Q N i l Pilic7 12 M-IO65 A B 1 h l , O A C4 C II Q Q Q 2Y l I PilF079 6 M.106 2 A j

              ,_                                          g         i           l G       A        D7                      d   C    lQ        J IQ    Q    2Y               l Pitt095             3'4          M-1065   P     2     A          li                                        ;                         j UL       II       DS                          C              J                             i                         }

j PIIFIED B 12 A M.IO65 2 A g_ l l . A7 C ll Q 3 Q Q '2Y l ! PilFI3I 82 M-1065 2 A l ll l 4 [_ _ H

            )             A         A6                       i C }l Q         J   Q   Q    2Y               i PilFl32             34           M-1065   P     2     A                                               l UL       II        A7                     ,   C              J                        l PilF429             34           M-1065   P     2     A          y UL                 A7 II                                   C li           J f

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 - GRAND GULF NUCLEAR S78.T10N REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING- PAGE NO. P21 -1 , SYSTEM: P21 - Makeup Water Treatment S} stem VAR.VE F & ID IST REQUIRED TESTS AND FREQUENCY I RELIEF VALVE SIZE (im) NO. , IST (X)DE CN llMFETY!! : I REQt'EST OTIIER NO. TYPE ACT. Ec onD. PASS class N- h; M ! p3 l F5 f LT IJ f ST FT FI RV EX CD fi ORR) (CMM WEs: 2 Mm330 2 A j P31F217 { [ l l GL M E2 ! C ! O 3 Q 2Y l P21Fols 2 3;m33B 2 A l_ l i l GL M E2 i C I Q 3 Q 2Y Il P21F034 4 l M@330 A B ll H { j' G A I F2 Il C il Q l Q Q 2Y L

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M.139.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE ENSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -1 SYSTEM: P41 - Stanen Semcc Water Sysicm VALvt 15T H r a lD WM! I! MFETY; REC *ED TESTS AND FREQUENCY ! Rn.IEF VALVE MZE (in) .%O. . IST CUDE ,

                                                                                                                -    ;    REQl'EST    OT11FR MD-      TYFE ACT. COORR       FA55   CutSS   CAT.ffPOS l M f P$ f LT l U l 5T l FT l FI                           Omt)     (CNAVT) Mn u:

KV EX f CD ! P4 t f 001 A 24 M-ID6I A 3 B g O !! Q l l Q 2Y l l p D M 11 2 H C 0Q i i n 2Y j l h P4tfDolB 24 3 O }; Q Q M-1061 A { 8 jj { l 2Y { g B M C4 l h C tl Q ! Q { 2Y 1 il 24 O P4tF003A M-106t A 3 B j! HQ} l Ql TV 1 l p i B M Og h C h Q l' j Qj Wi l !j l P415V05B 28 M-106t A 3 B y O gQt l l Q [Y l g H M C7 4 C ll O I l I Qi i 2Y I II 20 O pQ 2Y P41FD06A El-106tA 3 B Q j l [ B M G2 ! C ri Q Q i 2Y I ! H NIFEI3 20 M-1061 A 3 B O jj Qj l Q 2Y l l g Il M A5 i C D QI ( O 2Y I l 11 i 4 P4!fM7A i 1G M M-106 t A G4 P 3 8 (

                                                           !!    C I!

lt i I j i l l l l 2Y } { Q P4tlN07B 4 M-106t A P 3 B p 5 { } g G M A4 II C ! ( 2Y i il P4If005A C 24 SA M-IO6 t A F4 3 CQ 0 O {l! Q]l

i l i l g wI

P41F0esB 24 M-1061 A 3 C l O jQ j l [ J gg, 3 C 5A 13 3 i i i !- f P61Foll to M-1061 A 3 B O jj Q { j j Q ?Y j gj l B M E6 h C ff Q t i ! Q 2Y i j il P411V12 30 M-1061 A 3 C it O UQl l l l %ee l C sA Fs U E 1 71 )l P43 fD14A 18 M-106tC 3 B ji O "Q l Q 2Y l} 13 M CS , h 9 i II I P41FVl4H 18 1 M 106tD 3 8 g O l1 Q{ { }Q l 2Y p B M ) F4 i! ti f I l l D P4 t F015 A 4 _] M-106f A 3 B j! y { l l [ G M l F2 }i C il Q i I Q 2Y I I il P4ticl5tl l 4 M-106t A 3 l

                                                            }  '

q j j j j l 0 M C4 i C il Q l ( Q 2Y I i !

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO.GGNS-M-Is9.1 GRAND GULF NUCLEAR ST/.! ION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -2 SYSTEM: P41 - Standby Service Water Sysicm VALVE F A ID 15T NE ll [ REQUIRED TESTS AND FREQUENCY REUFJ

    . VALVE So.

MZE (in) TYPE ACT. NO. . 15T FASS (X)DE C1A55 N' 9FETY} ]i REQUEST OTHER (X)ORD. ]M l 53 f F5 IT IJ ' 5T IT F1 RV EX CD l ORR) (CJUAVT) WTE5: P41FDi&A 4 M-1061 A ' 3 ji B l N O M G2 i C II Q Q 2Y A P41FV16B 4 i M-106t A 3 8 t

                                                                      ;      ll                       l           l   g G           M        C4                             i  C UQ                    Q    j 2Y        I   Il relFol"A.           30           M-106 t B           3       B j      O ij Q                  Q      2Y            g B          M        c5                           I        O                                        y P4tFolgB             10 M-106tB {           3       B     l  0       Q               Q      2Y l

B M 03 l ! l P4tIVl9 IIG M-1061B 3 C 3 { l SC ILSA G6 4 C li Q t P4 t F024A IG M-10618 3 C j O g 10Y

})

RV SA II S l C !! 10Y il P41F02til !!2 M-106t B 3 C l O l 10Y l l RV SA F4 I C i i 10Y l P4tF03 t A I/2 l M.IO6tB 3 C O y 10Y l RV SA l F5 = C N 10Y l P41F03113 1/2 ' M-1061B 3 C { O g 10Y RV SA F7 .I C 11 10Y 2 P41F036 t /2 M-106t B 3 C ; O j 10Y d RV SA 94 l C i IOY ll l P4tF041 1/2 M-IO613 3 C 0 l 10Y t RV SA i E4 C I 10Y i P41F046 I!2 l M-1061B 3 C i Ol l 10Y RV SA_l F1 i C l 10Y P4tFD49 IG M-106Ill 3 C ll 0 l 10Y RV SA El I C i IOY P411V53 IG M-1061B 3 C l 0 l 10Y RV SA GS , l C l '30Y P4tt061 172 M.IO61 D 3 C I 10Y RV SA F. 2 b{ O C ! IOY P411064A 3 l M-1061C 3 B l 0 Q Q 2Y j Valve No gwens "$- 0 M l E2 I l

ENTERGY OPERATIONS,1NC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -3 SYSTEM: P41 - Standby Semce Water Syuem val.YE ist REQUIRED TESTS AND FREQUENCY VALVE MlZE (ht) ra lD So. , thT (UDE WDE J MPETY ( REtatr RFQUEST OTilER NO. TYPE A(T. COORD. PAS 5 (1.A55 A T. (Pos.,lF5 PS LT I3 ST FT FI RV EX CD (VER) (C.LIL3/.OT) SOTE5: P4 t F%4tl 3 M-1061D 3 Bp O gQ{l } Q 2Y ll y.gw g ,,g gin . y G M G8 II il l Il P4 tit 15A i 1/2 M-1061C C 10Y j RV SA 3 {OC l j

10y l G3 t l P4 t F0638 l t l'2 M-1061D 3 C 0 y : 10Y RV SA F7 C ll ' 50Y P4 tiV66A 3 M-106 tC 3 B ll l Valw h prefim s* G M F2 i C II Q Q 2Y I ; P41F066B 3 M-106 t D 3 B Valw % gwern .*s* l G M (; 7 C i Q Q 2Y NIF064A 18 M-1061C 3 B j O yQl Q 2Y j B M C8 I ll j ! P4 t fD68B 18 M 106tD 3 8 ! O ll Q Q 2Y { g Il M F6 l II j 6 P4 t F074A 3 M 1061C 3 B l l lValw % gwcfim.*S* l G M II 2 l C fQ Q 2Y I P41F074tt 3 M-1061D 3 B l i I j Valw % gwefis- T G M D7 i C g! I O Q j 2Y ! P4 tICI A 3 M-1061C 3 D I O lQ Q 2Y l y.gw g ,,,g; . .$- G M 11 2 f I l P4tF08tli 3 M-1061D 3 D 0 l Q 2Y Valw M gwefis.*5* - G M D6 il Q_I P111V84n 1/2 M-1061C 3 C 0 l 10Y ! RV SA D4 C ! 10Y P4'J 08411 I/2 M-lo6t D 3 CQ O y ] l 10Y l l RV SA (12 lI C ll l l 10Y I NilV97A l '2 M-106tC 3 C O l IOY l Nl RV SA C4 C I, 101 1 P41tV#78 t /2 M-1061D 3 C O I ! 10Y ; l 1 RV SA E2 C I lbY P4:ricsA L 3'4SA _ u io6tc C7 3 Cl 0 l 10Y l

             ! Rv                                              i     C j                                        10Y           l

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUC' EAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -4 SYSTEM: P41 - Standby Senice Water System vAtvE ra ID ist } REQUIRED TESTS AND FREQUENCY I REurF VALVE MIZE(in) NO. , lit (UDE 0)DEll;gogTY I OTilER CAT. 3 RE@'EST NO. TYPE ACT. PASS CLASS pos UM)RD. F5 F5 LT IJ ST FTlP1 RV EX CD (VRR) (CJlu/AvT) ' NOTES: P4 t FIDOB 3/4 M-106t D 3 C 0 ll ' 30Y g lll RV SA r3 i C iI 10Y H PCIF104 Il M-1061C 3 C ll 0 1 10Y j RV SA E3 lI C l 10Y f

P43 Fill A 2 M-10618 3 C l j ll l SC IL3A 11 7 C }l Q l i l P41FillB 2 M-1061D 3 C j f l ji

, SC ll3A G$ C Il Q l l ll P4tFil3 2 M-1061D 3 B l } l GL M C6 C _l Q Q l 2Y $ P41Fl23 6 M-106 tC 3 11 (Valve % pefis."5" _ l G M El C Q Q 2Y 3 l P41F127A I/2 M-1061C 3 C O ll 10Yl l RV SA F4 C ll 10Y I l FCIFl27B I/2 M-1061D C O 10Y RV SA D6 3 C { IDY P4 t F13RA I/2 M-106 t C 3 C O 10Y g RV 5A F$ f C l 10Y P4lFl3811 1/2 M-106 t D 3 C O 10Y RV SA H5 C IOY PCIFl51 A I/2 M-106tC 3 C O l l 10Y j RV SA F7 C I f l0Y l } P4tFl$lli _ l/2 M-106 t D 3 C Ol 10Y RV SA I? 3 C l _[ 10Y P41F194 3 M-1061D 3 B i ll Valve % pefis-T l G M 11 2 t fC ll Q Q 2Y r4 F199A 3 u-iosiD 3 II l 1 van = w p.e . s-G M GI l C iO Q 2Y PCIFIS911 3 M-106 t D 3 B j Valve Na priin s* O M O2 C Q Q 2Y l P4 t FI97A I/2 M-106tC 3 C O ll 10Y ! RV SA F6 C f 10Y [

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO.GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -5 SYSTEM: P41 - Standby Senice Water System VALVE F A ID 15T ! I REQUIRED TESTS AND FREQUENCY RnJEF VALVE SIZE (im) No. . IST CY)DE UN ;5AFETY! REQt'EST ()THER No. TYPE ACT. (Y) Oft!L FASS CW UAI-lMl F5 PS LT IJ ST FT FI RV EX CD (VRR) , (CJ.1tJ/AVT) NOTES: P41Fl57B l'2 M-lG61D 3 C O l l 10Y RV 5A B4 ] C 1 IOY P41Fl59A 2 M-IO610 l 2 A e O Q Q 2Y g OL M E4 l C Q J Q 2Y P41F159B 2 M-1061D 2 8 A 0 Q Q 2Y l GL M D2 C Q J Q 2Y l f PCIFI60A 2 M-1061B 2 A O jQ Q 2Y l GL M D2 C iQ J Q 2Y l P41FI600 2 M-1061D 2 A j O Q Q 2Y GL M { D4 l C Q { J Q 2Y PCIF103A 3/4 M.IO6t B F 2 A [ GL 11 E4 C l J P4IFlalu 14 M-l%3 D F 2 A y i GL 11 D2 C 11 J l P41Fl68A 2 M-106111 2 A O Q Q 2Y j GL M E3 C Q J Q 2Y l ; P41F16sB 2 M-106t D 2 A O Q Q 2Y ' GL M E3 C O J Q 2Y 2 O P4 t FI69A SC ll3A M-106111 E4 2 C.A C l Q]

                                                                        !Q                 J P41Fl69B         2          M.106t D             2      C.A       O      Q SC       ll,3A     D2                                 C      Q                3 P4tFl?4           3         M-106 t D             3      C I          f                                                                   RJ-P4141   l'    - % cwy refucimg eutage C        SA       ll )                         l     C i                                                R PCIFis9          6          M-1061D               3      B                                                                                           Valw No prefis ."5"

{ O M C3 , C l Q Q 2Y P41Fl94A t r2 M.1061C 3 C l 0 g 10Y ] kV SA F3 I C !! 10Y P41FINil If2 M-1061D 3 C l 0 l l , a l10Y l RV SA Il 2 ! C i j '80Y P4 tl236 3 M-1061C 3 C l -l QF

                                                                                  -~-~

C sA t4 C 1

ENTERGY OPERATIONS,INC PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P41 -6 SYSTEM: P41 - Standby Service Water Sysicm VALVE F & ID IST l lMFETY REQUIRED TESTS AND FREQUENCY l REU EF val.VE 5tZE(im) NO. , IST Coog CODE OTHER RE(KEST NO. Tyre Act. ux>un- FAss CIAss CAT. l yos, < g l ,, l L l u l si l FT l Pt l av l EX CD (VER) (C11U/AVT) MJTES: P4tF237 3 M-1061C 3 B O ll Q Q 2Y g - 0- M ES II W P41F2D 3 M-1061C 3 B .l 0 lQ Q 2Y g G M G3 { l N P4tf239 3 M-IO6tC 3 D G A F3 C Q Q Q 2Y P4fF240 3 M-1061C 3 B ll G A II ) C ll Q Q Q 2Y P4tF2OI G 3 M M-1061C 3 Bl l 11 3 i C i Q Q 2Y P4 t F293A 1 M-IO6t B 3 C i O l 10Y l RV SA C4 C I 10Y i PCIF29311 3 M-IO61B 3 C O 10Y RV SA G1 C 30Y P4iF299A 6 M.1061 A 3 C 1 O 80Y RV SA G3 i C 10Y 6 0 P4IF2993 [ SA M-106tA C5 3 Cl C j IGY l RV l- I 10Y !

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P42 -1 SYSTEM: P42 - Component Coolmg Water System VAs.vE F a IB ! IsT 4 li REQUIRED TESTS AND FREQUENCY {! Rttarr VAttE stIIth) so. , IST (T)DE N ; ILEQUEST OTHEst l CAI-MA TYPE # "T. CXM MtD. FAS5 CLASS l:5AFETYblD3fF5fI.TfIJfhe POS l fFTlFIlRV EX CD h (VRR) ; KW'AVT) f MJTEk P42F02sA = M-1063A F 3 B (( O ij l l 2Y l @ B M 11 6 il il i i i li F42101sa 8 M-1063A 3 fj j B j{ l l l l 1 B M o4 il C OQ l } jQ } 2Y j { P43FU29A 14 M-1063A 3 C .] O H g l 10Y l RV SA 11 7 i C si i 10Y } S P41NB 3/4 M-1063A 3 C [j O l l 10Y l j ll l RV SA FS !i C ti ( ) 10Y j e I P457038A 8 M-1063 A P 3 B y 0 y 2Y g [ l B M 07 h il I { $ P42F033D [ 8 MMA 3 B h _l l l h iB M E7 !( C fi Q l l l Q 2Y W P42FD33 y 10 M-10638 2 C.A h 9 l l l h Cs F4241 lC SA l17 fi C I! C I l J } h P42F066 10 M-1063B 2 A ll ll l l l CJ-P4242 G M 11 7 h C 11 C I J iC I 2Y P42F067 ) 10 M-1063B 2 A {O M E8 y d j! C 11 C f { J C { 2Y l l jj CJ.F4242 ( ll P42F064 10 M-1063B 2 A j CJ-P4242

                                                                   !!  l                    l               l Q O        M          Ds                         l  C tl C l           J      CI     2Y          l  j!

P4SF103 B IO M

M-1063A 3 B l {

C {j Q i l 2Y g 11 3 i Q Q P42Fil4 O 8 M M-IO638 11 5 2 B { i f C 11 C C 2Y ll si CJ-P4244 P42Fil9 C 8 j M-10638 sr 1 n5 2 C ;l 4 { C it C l i l i Q CJ-P4243 W P42Fil6 8 i M-1063B 2 B i !l l I CJ-P4244 il G M l CS C lC i C 2Y i h P42Fil7 G 8 M M-1063B C5 2 B {il { C !! C { lC 2Y j{ CJ-P4244 P42FIGI _,_3 4 GL M-1063B P 2 A l( { l l ll 31 11 7 !! C il l J i 4 1 c..

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM YALVE

SUMMARY

LISTING - PAGE NO. P42 -2 SYSTEM: P42 - Component Cooling Water Sysem VALVE } F AID IST REtJEr CODE l l- REQUIRED TESTS AND FREQUENCY VALVE sizz <ia) x3. , IST cvsDE REQUEST OTHER NO. TYF#, ACT. (1)ORD. FAS5 CLASS, CAT. ,)(SAFETYIpos, 73 l F5 l jLT IJ ST FTlFIiRV EXlCD O RR) (CJTJtAVT) MJTE5: P42FI23 3/4 M-1063B F 2 A GL l l l l < 11 DE C i J l @ P42F200A 8 M-1063A 3 B j O lQ Q 2Y g n u os 1 C iQ Q 2Y g I'42F200D 8 M-1063A 3 B O { Q Q { 2Y B M F4 C i. Q lQ l 2Y P42F201A 8 M-IO63A 3 B 0 yQ Q 2Y l 3 M FE i C li O Q 2Y P42F2018 8 B M M-1063A E7 3 8 QO il C IQ jQ Q 2Y 2Y p Q Il P42F203 3 M-1063A 3 B jj H l l D M 04 il C ij O Q 2Y ! ! P42F204 8 M-1063A 3 B {j ; W D M Es C 11 Q I Q 2Y Il P42F20$ to M-1063A 3 D l l { 11 M Es C I Q Q 2Y l I l 1

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P44 -1 1 SYSTEM: P44 - Plant Semcc Water S3Mem VALVE F a ID IST l RLt_IEF NE.l$rygryll! REQUIRED TESTS AND FREQUENCY VALVE- $1ZE (in) NO. , 15T 00DE ; , REQt'EST OTilER No. TYPE ACT. WORD. FASS C1. Ass CAT. j, pos l! FS l FS l LT IJ ST FT FI RVlEX (D OltR) (CIRAA%T) NOTES: P44F042 8 M-1072F 3 8 ' l $ 11 M G4 C Q iQ 2Y N P44 FOS 2 8 M-1072A 3 C !! IU-Pe tal C SA A6- CO ' R P44F054 8 M-1072F 3 B ! (( D M

G3 t C il O Q 2Y 11 P44F067 8 M-1072A 3 B l CLP4441 Il M A6 'gl l C C C 2Y P44Fil& 24 M-1072A A D j AVT-P44-02 ll } } B A H5 .l C il C C C } 2Y l P44Fil7 24 M.1072A A B i lj A\T-P4442 [ H A D6 C lj C C C 2Y I P44Fil8 24 M-1072A A B i} l A%T-P4448 B A as !l C I C C C 2Y P44Fil9 24 M-1072A A B j j AVT-P444I l , H A As l C i C C C 2Y I I P44F120 % M-1072A A B j li AVT-P4441 II A Fs C IC C C 2Y Il P44F121 l M M-1072A A D l A%T.P4441 ! l _

            ; D           A       Os                               !   C l      C               C C    2Y                                                                !

P44FI22 30 j A D lj ll A%T P4442 n A } M-1072A n6 h C li C C C 2Y P44F123 30 M-1072A A B j A%T.P4442 l ll n A u. C li C C C 2Y I P44F495A 3'4 M-1072tl 3 C i O IOY i { , RV SA E3 ! C i 10Y P44F49311 3/4 M-IO7211 3 C l 0 ! 10Y RV SA E4 l C l 10Y

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P45 -I SYSTEM: P45 - Floor and Equipment Drains System

          !     VAI.VE        F A ID           IST         j        l    REQUIRED TESTS AND FREQUENCY           EFLIEF VALVE       SIZE (Is.)      NO. .  .IST    CODE   WM    iMFETY   !

OTHER

                                                                                    ,                          REQt:EST No.      TYPE ACT.      WORD. FASS          CAT. yos C*.A55                l F5   PS LT IJ l ST FT FI RV   EX CD  i     (VltR)  (CallSA%T) NOTES:

P43Fooi 3 M-1394A 2 8 CJf4341

ll G A 18 6 C l} C C C 2Y P43F004 3 M-1094A 2 B j G A 11 3 C Q Q Q 2Y f P4?f009 3 M-1094A 2 B l CJ-P4341 O A D6 C I C C C 2Y P45FV10 3 M-1094A 2 B !

G A D3 C IQ Q Q 2Y P43F061 6 M-1094Il 2 A { } G A D3 C l Q J Q Q 2Y ! P45FC3 6 M.109413 2 A l { G A D2 l C Q J Q Q 2Y l 6 ' P4SF067 M_lo9413 2 A G A F3 C Q J O Q 2Y P43F063 6 M.10948 2 A G A F2 C Q J Q Q 21 P43FU96 81/2 M.1094E 2 B GL M If 6 i C Q Q 2Y I 81/2 M-1094E B P45F097 2 l GL u n3 C Q Q 2Y il P45F098 3 M-109*E 2 A l l l G A G2 i C i Q J Q Q 2Y P43F099 3 M-1094E 2 A y { ~{ G A GI C Q J Q Q 2Y t Il P45F158 8 i M-1094C A II l ll G A I FI C iQ Q Q 2Y H P4SF199 8 M-1094C A B j j _ l [ G A G1 l C lQ l Q Q 2Y l P43F160 8 M-109 C A II l G A C2 C !Q Q Q 2Y P49F161 8 M-1094C A B ll l -l G A C2 il C lQ Q Q 2Y i

ENTERGV OPERATIONS,1NC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 l PUMP AND VALVE INSERVICE TESTING PROCRAM VALVE

SUMMARY

LISTING - PAGE NO. P45 -2 SYSTEM: P45 - Floor and Equipment Drains 5)*cm VAISE Fa 30 15T l REQUIRED TESIS AND FREQUENCY j RE1JEF VALVE sizr(in.) so_ , 15T CW N. ! SAFETY OTHER CAT. REQUEST

30. TYPE ACT. (m FASS C1.Asg j po3L FS F5 LT IJ ST ET FI RV EX CD OM @ MAW' M)TE5:

P45F103 3 M-1094C A B ' ll O A E6 C HQ Q Q 2Y t F45F273 4 M-1094C F 2 A 'I l G M Bt C ' 3 2Y _i P45F374 4 M-1094C F 2 A l l [ G M Cl C J $ 2Y i i P49f273 14 M-1094C F 2 A ll GL II DI C Il J P45F290 3 '4 M-1094C F 2 A l l { GL 11 Dt I C l_ J l

ENTERGY OPERAYIONS,INC. PROGRAM PLAN NO. GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. PS2 -1 SYSTEM: P52 - Service Air System VALVE F A ID 15T [ REUEF vatvg stir <w) 30. . Ist CODE "2DE ijSAFETYll 'tEQUIRED TESTS AND FREQUENCY 3 NEQtT_ST OTHER NO. - T)PE ACT. G)ORD FA55 CLASS CAT. j pos l F5 P4 1T IJ ST FT Ff RV EX CD k O'kR) CMAW 30TE5: N F305 } 3 41068A 2 AO ] l iG A F6 II C HQ J Q Q 2Y l r$2Fl4 3 M-106EA 2 C.A ' l [ ] }} C sA ES I C 'o s i tl r$2Fl60A. 4 M-1068A A si l l } l [ G A r IC iQi iQ Q 2Y' l ! r$2F160B 4 j M-106BC D j A { j' G A l D3 } [ C Q Q Q 2Y ! rssFies 2 u-1068A r 2 a } I GL M D4 C l 2Y I r$2Fl96 2 M-1068A 2 C ll l l CJ-r$241 sC nsA D3 C ii C i ti r52F22nA 4 M-106sA A B y I G A HS C l} Q Q Q r 2Y r52mlB 4 M-1068C A B ll l f G A A3 lI C I' Q Q Q 2Y h r$2f255 3/4 M-1068A P 2 A tj y l l l l Ut u n6 i li C ii i is i

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.G PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. PS3 - 1 SYSTEM: P53 - Instrument Air System V M .Y E F A ID IST REQUIRED TESTS AND FREQUENCY RELIEF VALVE SI2O(isL) NO. , { IST CY)DE CUDE MFETY g REQUEST OTHER NO. TYPE ACT. COOkD. I PASS CLASS N- N FS FS l LT LJ ST FT FI !RV EX CD OltR) (C11UiAVT) NOTE.4: PS3FCDI 21/2 M-1067M 2 A O ll 2Y j CAF53-01 Open posision ymssew G A F5 C , C 1 _C C 2Y j P51F002 21/2 M-1067A 2 C.A O C l CAP 5342 l C SA B6 C C J { P93F003 1 M-1067M 2 A O 2Y 1 Open p pensive GL M E4 C Q J Q 2Y , PS3FC36 3/4 M-1067A 2 C,A O C CJ-P5343

C SA A3 C C J i PS3F007 2 M-1067A 2 B O 2Y CJ-PS344 Open ematum passeve Gl. M 11 4 C C C 2Y PS3fT)CO 2 M-1067A 2 C O j C l CJ-PS345 sC lisA B3 C i C ! P531026A 21/2 M-1067M A B Ol 2Y j A%T.PS341 W posaxm pesssvc G A 05 C l C C C 2Y l PS3F026B 2 112 M-1067E A B O l 2Y AST-r5341 open posiekm p.s.w G A Os C 1C C C 2Y PS3}D36 3/4 M-1067M P 2 A GL II F5 C J PS3F043 3/4 M-1067M 2 A 0 Q l _ GL li E4 i C Q J P93FA01 3/4 M-1067M 2 B o Q l GL 11 D4

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROCRAM YALVE

SUMMARY

LISTING - PAGE NO. P60 -I SYSTEM: P60 - Suppression Pool Cleanup System VAI.YE F& 3D IST 1 ji VALVE FO. , IST mDE ! REQUIRED TESTS AND FREQUENCY RELIEF l SIZE (la) CODE REQt'EST OTilER No. TYPE ACT. mostD. FASS (uss CAT. l SAFETY.kpoi1.Th FSIJ l ST F5l FT P1 RV EX CD i OTR) (CNAW) WTES: P60Fty 3 12 M-1099 2 B l l l O A D4 [ C jQ Q Q 2Y j P601D 3 12 M-1099 B l A j G A D3 C Q Q Q 2Y i P607004 12 M 1099 A D 11 ; W G A E3 l} C Q l Q Q 2Y !! P60F007 32 M-1099 A 3 i G A F6 { C lQ Q Q 2Y P60tu s 12 M-1099 A B l-O A k F6 C { Q- Q Q 2Y ll PtC 009 12 M-1099 2 A A f l f G F6 I C l Q J Q Q 2Y l P60F010 12 M-1099 2 A j G A F7 C l Q J Q Q 2Y P60lVII 3/4 M-1099 P 2 A GL 11 E6 C J P60F03I 12 M-1099 2 B j G A D5 C Q Q Q 2Y i P601D34 l'4 M.1099 P 2 A GL 11 F7 {i C J I

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION h0. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P64 - 1 SYSTEM: P64 - Fire Protection Sysem VALVE F A ID IST REQUIRED TESTS AND FREQUENCY REl_IEF VALYK SIZE (in) NO. , IST CODE 0)DE SAFETY , REQUEST OTitER NO. TYPsC ACT. G)ORD. PASS CLASS CAT. poi FS PS LT IJ ST FT F1 RVl'EX CD VRR) (CSRJ/AYT) NOTES: M40350 A 1%4F282A 10 B O A C4 C Q Q Q 2Y I%4F2828 to M_0033n A B l[ O A C4 C Q Q Q 2Y (( P64F183A 10 M4035B A B f l l G A C7 i C lQ Q Q 2Y l P64F233fl 10 M403513 A B O A C7 C Q Q Q 2Y P64F332A 3 M4035E A B O A E6 C O Q Q 2Y 1%4F3328 3 M4035E A D G A E6 C Q Q Q 2Y P60FA10A 4 M4035B P A B O M B4 C 2Y P64FA108 4 M 0035B P A B ( O M 11 7 C , 2Y l r e

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GCNS.M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8

                    MP AND VALVE INSERVICE TESTING PROGRAM                                   VALVE

SUMMARY

LISTING - PACE NO. ~ P66 -I SYSTEM: P66 - Domestic Water Sysicm . VAISE F A ID IST REQUIRED TESTS AND FREQUENCY REIJFF I IST CY)DE UN l5AFETY - REQUEST OTHER VALVE MIZE (ht) NO. , . NO. TYPE ALT. COORD. FASS CLAS5 CAT. lpos F5 l F5 LT LJ NT FT FI RV EX CD (VRR) (CJ1tJ/AVT) M)TES: 3 MM34D A B l Vahe No prenz.T Pe4F029A O A 'E3 C Q- l O Q 2Y I

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P71 -1 SYSTEM: P71 - Plant Chilled Water System VALVE P A ID IST l . REQUIRED TESTS AND FREQUENCY REuEr IST 01)DE CODE %*JETY REQUEST . OT1tER VALVE SIZE (In) 50. , FASS CIASS CAT. pos- FI RV EX CD (Villt) (CJ10/AVT) NOTES: NO. TYPE ACT. (X)ORD. FSlPS 1.T IJ ST IT Replace every 7 years P71tI211 6 M-I109A P A D RD SA Fa l C 4 M-Il09D 2 A { { MIF145 { ll lG A Fs il C .I Q J Q}Q 2Y P71F149 4 M-Il09D 2 A G A F7 tl C Q J Q Q 2Y P71Fl50 4 M-Il09D 2 A l l G A E. 7 , C jQ[ J Q Q 2Y C,A jj CJ-P7101 P71F151 4 M-Il09D 2 l , C SA E6 C 1 Cl J li P7tF232 3/4 M-1109D P 2 A { GL II E7 i C{ J P71F246 (l GI. 34 11 M-Il09D Fs P 2 A C ii l} J P71F3C 2IG M-Il09D A B l l G A Cs l C O Q Q 2Y , P7tF301 21/2 M. llc 9D A B ! l G A C7 C IQ Q Q 2Y l P7tF302 G 2IG A M-Il09D Cs A B { C !} Q Q Q 2Y P7tF303 21/2 j H.I109D A 11 l l G A C7 i C IQ Q Q 2Y P7tF304 _ s M-Il09F A B{ f _ j AVT-P71-01 O A A3 l C !C C C 2Y l s M Il09F A B AVT-P7141 P7tF305 l 'l

                        ]G                                                                                                          C  2Y                                                                           -

A A3 ! C C C I 8 M.ll09F A B lj !! A%T-P5

P7tF3G l C C C C 2Y ll IG A A4 l}

M0ll09F A B !'

l AVT P71-01 F7:F307 G A A4 C f C f C C 2Y

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P72 -I SYSTEM: P72 - Drywell Chillco Wa: r Sysicm VALVE F A ID IST *l REQUIRED TESTS AND FREQUENCY RELIEF IST CODE CODE iMETY REQUEST OTHER VALVE SITE (in) N(L . PASS . CLAS5 CAT. ( pog- 1J RV EX (VRR) (CARJ/AVT) NOTES: NUL TYPE ACT. (VORD. F5 F5 LT ST FT f FI CD n 4 M-1072B 2 A i l cam 48 P72F121 G M !! 5 i C C J C 2Y _ 4 M-1072B 2 A I CAF7241 P72F122 O M Il s l- C C J C 2Y , M FI23 4 M-1072B 2 A , cam 41 O M Os C C J C 2Y P72F124 4 M-1072D 2 B l j cam 42 l O M F5 C t 0 C _ 2Y .i 4 M-107211 2 B } l CAP 7242 P72Ft25 O M Es C l C C 2Y J 4 2 H CAP 72-02 P72F126 M-1072B l l O M Fs C i C C 2Y I 4 M-1072B 2 C CAF7243 m FIA7 l C SA ES , C !C j' i CA m 44 P72F165 4 M-10720 2 CA ll C sA as n C i C J l P72Ft47 3 '4 M-1072B P 2 A OL ll G4 C J _ __.-, A

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 9 RAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P7S - 1 SYSTEM: P75 - Standby Diesel Generator System VALVE F A ID IST RELIEF l SAFETYREQUIRED TES13 AND FREQUENCY l VALVE filZE(IsL) NO. , IST CUDE CODE CAT. l - REQUEST (ITilF.R NO. TYPE ACT. COORD. FASS CIASS pos- FS FS LT IJ ST FT FI RV EX CD (VMR) (OHAVT) NO1E5: P75F003A 2 M-1070A 3 C O IQ SC ILSA 11 7 i P75F003B 2 M-1070B 3 C 0 Q .1 SC IL5A 11 T l P75F006A 2 M 1070A ' 3 Cl 0 Q SC llSA G6 t P79fD611 2 M-1070B 3 C O Q SC IISA G6 P75F007A 8 M-1070A A C II O Q AYT-F7541 C SA 11 4 l P79F00711 8 M-1070B A C O Q AVT-F75-01 C SA 13 4 P75Fe39A 3 M-1070A 3 C C SA F6 C Q P75F00911 3 M-1070A 3 C l. C SA AB C ll Q P79Fe39C 3 M-10708 3 C A C SA F6 C Q P75F009D 3 M-10709 3 C l C SA As C Q P75F0ll A 3 M-1070A 3 C l 0 Q C SA E6 [

                                                           '   O P75Follll          3         M 1070A           3    C               Q C         SA      Il s P79F01IC           3         M-1070ll          3     C        O     Q C         SA       E6 3         M-1070B           3     C        O     Q P7510llD [                                                                                               _

C SA Il s P79tD25A I M-1070A 3 C O 10Y RV SA E$ C 10Y P751'02511 i M 1070A 3 C O 10Y RV SA As C , twY

ENTERGY OPERAT!ONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P75 -2 SYSTEM: P75 - Standby Diesel Generator Sysicm

                                                                            '                                                         REUEF VAIAE                  P A ID   .

15T (1)DE ! REQUIRED TEST 3 AND FREQUENCY VAI,VE IST CY)DE REQUEST OTHER

SIZE (Im) No. ,

CAT.

50. TYPE A(T. COORD. FASS CtASS l SAFETY N FS Ps LT IJ ST PT FI RV EX CD OltR) (CJ/ILI/A%T) NOTES:

I M-1070B I 3 C O 10Y P79F025C RV SA E5 C 10Y I 3 C 0 10Y M51025D M-10708 l l RV SA A8 f C I 10Y j i 1/2 C i O i 10Y P75F026A M-1070A 3 RV SA 11 7 fC I 10Y P75F026B l !!2 M-1070ll 3 C Ol 10Y j j RV SA 11 7 C i 10Y I M-1070A 3 C O g 10Y P751028A RV SA G3 CH 10Y 1 M-107011 3 C O l 10Y l P79F02811 RV SA G3 C l 10Y 4 3 C O 10Y - P75F031A M-1070A RV SA F3 C 10Y f P79F03111 4 M-1070fl 3 C O 10Y g RV SA F2 C 10Y It 8 M-1070A A C A%T-P75-01

    '751034 A C             SA            B4                           C      Q P75fM4Il                   8               M-1070B            A      C          l                   l                                    AVT-P7541 C             SA            11 4                         C      O PFSIO38A                 I 1/2             M-1070A            A      C                                                                   AST-P7541 C             SA            C3                           C      Q P79F01811               I 1/2              M-1070B            A      C                                                                   AVT-P75-01 C             SA            C3                           C      Q Pbr050A                    6               M-1070A            A      C     0    lQ                                                       AgT-P7344 C             SA            F3                           C    lQ                               '

P7SF050il 6 M-1070B A C 0 l Q l AVT-P7544 j C SA F3 C l Q P7SF059A 6 M-1070A A C 0 Q A%T-F7544 3 C SA ES Ag7.P7544 P'79F059tl 6 M-1070!! A C O lQ C SA , t5 l __ _ = ___ _ . _ = _-_ _ _ ___ _ .

                                                                                                                                    ~                   - _ -

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 CRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P75 -3 SYSTEM: P75 - Standby Diesel Generator S 3stem IST REQUIRED TESTS AND FREQUENCY RELIEF WDE l' SAFETY' VALVE P A ID l IST CODE REQUEST OTilER VALVE Sm:0m) No. , N-CIASS Poi CD (VRR) (CLitJ/A%T) NOTES: NO- TYPE ACT. WORD. FASS ,3 PSlLT IJ ST FT Pt RV EX C 10Y P73F066A 2 M-104A 3 C l ] RV SA F4 l C 10Y l C 0 10Y P75106613 2 M-1070!! 3 l RV SA F3 C 10Y I I/2 C 0 10Y P75t067A M-1070A 3 l RV SA F4 j C 10Y 10Y P75F06711 RV 11/2 _ SA M-107t*13 F4 3 C (OC i 10Y I M 1370C A C O jQ AVT-P7543 P73F077A C SA 05 l I M 1070D A C O Q A%T-P75-03 P79107713 C SA 05 3 M-1070C A C O Q AVT-P754 !%ft)79A C SA D6 C R P73F07911 3 M 1070C A C O ll Q j Ayr-P75m C SA D6 C f[ R I 3 M-IO70C A C O Q AVT.P75-06 P75F079C C SA D6 C R AST-P7546 P79t079D 3 M-1070C A C O l Q C SA D5 C l R P75F079E 3 M-1070D A C D lQ AVT-P7546 C SA D6 C l R 3 M-1070D A C O } Q A%T-P75-06 P75F079F C SA D6 C f R P75tV790 3 M-1070D A C O Q A%T-P 75-06 C SA D6 C R 3 M-1070D A C i O lQ AVT-P75-06 P75F07911 C SA D5 I C l k 6 M 1970C A C O Q ANT-P75-05 P75FOC3A C SA E2 C Q O Q AgT-P7545 P79FOSoll _ _. 6 M-1070D A C C SA F4 f C Q

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. P75 -4 SYSTEM: P75 - Standby Diesel Generator System

                              % AIXE        P & ID          IST             l              REQUIRED TESTS AND FREQUENCY               RELIEF IST    (Y)DE   CY)DE    :SAFF.TY                                                 REQUEST    OTilLR VAIXE       $1ZE (in)       .NO. ,

(CJ,1tJ/A%T) TYPE ACT. PASS CIASS PO5. LJ P1 RV EX CD l OltR) NOIE5: SO., (UORD. FS f PS f LT VT FT AVT-P7MS P75F095A 6 M-1070C A Cl 0 lQ [ C SA DS l C lQ [ 6 M-1070D A C O l Q AVT-P7545 P75F0958 C SA DS C i Q A%T-r75-05 P7SfV96A 2 M-1070C A C O lQ C SA E4 l P75F0968 2 M-1070D A C Ol Q AVT-P75-05 C SA E4 , I 2 M-1070C A C O Q Av7-P7545 P75F097A C SA ES 2 M.1070D A C O l Q AVT-P7545 F75F0979 C SA D5 l I l#4 3 C O 10Y P7SF09sA M-1070C RV SA G6 C 10Y i 1/4 3 C O 10Y P75F09sil M-1070D [ l RV SA G6 l C l 10Y 3 M-1070C A B O Q Q AVT-P7542 P75F507A GL 5 DS C Q Q 3 M-1070C A n O Q Q AVT-P7542 P75F507B GL S D6 C Q Q 3 M-1070D A B O l Q Q AVT-P7542 F75F507C GL S D5 C I Q Q j Q AgT-r7542 P75F507D 3 M-1070D A B O lQ UL S D6 C l Q Q O Q AgT-r75 02 P79F503A 3 M-1070C A 11 lQ GL S C5 C iQ Q P75F50Sil 3 M 1070C A B Ol Q Q 4%T-P7542 GL S D6 C l Q Q 3 M 1070D A Il l O Q Q AVT-P7542 P75F508C GL S C5 fC Q Q 3 M 1070D A 11 O lQ Q j A%T-P75-02 P75F50P' { Gr. S D6 i C li Q Q f

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. Pal -I

SYSTEM: PSI - HPCS Diesel Generator System I IST 'I REQUIRED TES13 AND FREQUENCY RELIEF VALVE F a ID l IST CUDE CODE l SAFETY REQt'MT OTilER VALVE NIZE(la) NO. . CAT.

                  $0. TYPE ACT. (VORD.            PASS   CIA 5S           l pos        53  PS LT   IJ ST l IT Ft   RV    EX CD .        (VRR)   (Calt.B/AVT) SOTES:

PRIF007 2 El-IO93A 3 C _ O jQ l l ILSA ! { SC B4 ! I hi1093fl A C 0 Q j l PS1F03 t A l C SA C4 l l 3J4 Af-1093C A C i O Q l P31F031B C u C5 i i Ag7.pgl43 PtifD34A 2 511093D A C O lQ C SA C4 C tQ AVT-PSI 43 P3tt034H 2 ki-1091C A C O lQ j l C SA C6 C fQ AVT-P5143 P81F035A 2 kl.1093B A C O Q '_ C SA C4 C Q AVT-Pal 43 PSifU15B 2 kf-1093C i A Cp O ll Q C SA CT fl C li Q A C 10Y P*lF047A M-109313 j O l C i 10Y I RV SA D5 f A C O 10Y I ElID471) M-1093C g [ l C i 10Y RV SA D5 l ! 3/4 3 C O j 10Y PSIF04R A M-1093B RV SA G5 C l 10Y O j 10Y j j P81F048B 3/4 M-1093C 3 C I C 10Y l RV SA i 05 l 3 '4 3 C O 10Y l PS!F049A M-109311 C 10Y j RV SA F4 3/4 C 0 l l 10Y - PSI 104911 M IO93C 3 RV SA G6 : C i 10Y 10Y P31F052A M-1093B A C Ol } j SA C i 10Y l RV II S A C l O I 10Y PtifD328 M-1093C b SA C5 fC f 10Y Ayr.pgla4 Pall 053A M 109311 A B i O Q Q [ T' A D4 l C Q Q l

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. PSI -2 SYSTEM: P81 - IIPCS Diesel Generator System VALVE P & ID l IST REQUIRED TESTS AND FREQUENCY MEUFJ IST CODE NE SAFETY -- REQUEST OTHER VALVE NIZE(la.) No. , CM-g N EX CD OltR) (CJ/RJiA%T) NOTES: NO. TYPE ACT. COORD. PASS class F5 PS LT IJ ST FT FI l RV PSIF05311 T A M-1093C D6 A B {O { C Q Q Q Q AVT-PSlot A B O Q Q AVT-PS144 Palfo94A M-1093B T A C4 C Q Q l M-1093C A B U jQ Q AVT-P5104 Pal 10$411 T A C6 C }Q Q O Q Ay; pgla2 P8tF059A ' I M-1093B A C l C Q ! C SA D2 3/4 A C O Q { AVT-P31-02 P811V5911 _ _ _ M-1093C C SA C Q I D3 I A C A%T-P81-02 PSIID60A M-1093B C SA D2 C Q 3/4 M-1093C A C AVT-Psl42 PalF060Il C SA og C Q A C O Q AVT-P8845 PSIFD64 _ M-1093C C SA B7 C Q P33F067A 3/4 M-109311 A C ~' l C SA G5 C Q ( PSil067B 3/4 M 1093C A C C SA G5 C Q PS11'D68A 3/4 M-1093fl A C l C dA F4 C j Q PSIF06sfl 3/4 M-1093C A C i C SA F6 l C Q A C 0 10Y P3 t Fl03A , later , RV SA C 10) A C O 10Y PSIF103tl later RV SA C 10Y 1/2 A B O Q Q, A yr.pgl at P3 t F303A l M-1093'.! GL S D4 C O Q 1/2 M-1093C A B O Q Q AVT .l-01 PalF90311 GL S D6 C Q Q n

e : ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 CRAND GULF NUCLEAR STATION RSVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROCRAM , VALVE

SUMMARY

LISTING - PAGE NO. Ps1 -3 SYSTEM: P81 - IIPCS Diesel Generator System VALVE F a ID IST l REQUIRED TESTS AND FREQUENCY RELIEF VA1.YE NO. , IST WDE WDE : REQUEST OTHER SIZ"(Am) f* NO. TYPE ACT. COORD. FASS CIA 5S CAT. m l SAFETY 5 T U M a F1 RV EX CD O RR) (ClRJ/AVT) NOTES: 13 M-1093B A D 0 Q Q AVT#stal P8tF504A GL S n4 C Q Q ! IG M-1093C A B O Q Q AVT.Psl41 P8tF504D _ GL S C6 C Q Q i 1

- N

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO.GGNS-M-189.1-GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. T41 -1 SYSTEM: T41 - Auxiliary Building Ventilation Syvem VA1.VE F A ID IST REQUIRED TESTS AND FREQUENC( RFifEF vAs.VE IST CODE CDDE JFETY REQUEST OTifER SIZE Om) No. . - NO. T) PE ACT. COORD. FASS CLAS$ CA I- .FOi FS f PS LT IJ ST FT FI R*.* EX CD M R) , @ MAW NOTES: { T41F006 24 ki-1103 A A B B A 11 2 C Q Q Q 2Y T4tF007 24 kg.Il03A .l A B e q g g B A 2y 02 , l l

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ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. T42 -1 SYSTEM: T42 - Fuelllandling Area Ventilation System YA1AE F A ID 15T REQUIRED TESTS AND FREQUENCY l mEutr VAISE !$T CODE CODF. MFETY

            $1ZE 0m)      Nn . .                                                                              REQUEST  OTHER sm    mE Acr.      mom      em   cuss         -
                                                       !        ., ,, I l.s i.1Iuisiin    ,1 l ov   e.m.        o->   ==Avr> softs =

T42mn a u.ii-A A o :: 4 _t y! a A re l{ c iQ Q Q 2Y l ! T4sroo4 44 u.uo4A A e l l g H A Es l C Q l QlQ 2Y !! T42foll M-Il04A A B l j B A D2 C i O Q Q 2Y ! T42Fol2 ju.IIG4A A B l [ j n A ! 02 i C i Q Q Q 2r i T42F019 M M.ll04A A B ! { n A as e iO Q Q 1 2v i M st-4104A A B l j T42fC20 L l iB A 02 l C i Q Q Q 2f I f

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 : GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. T48 - 1

SYSTEM: T48 - Standby Gas Treatment Sysicm VA1.VE P & ID IST REQUIRED TESTS AND FREQUENCY RELIEF VALVE SIZE Um) IST - CODE CVDE SAFETY No. , REQUEST ' OTHER NO. TYPE ACT.- COORD. PASS CLOS CAT. POS. i L FSfPS LT IJ ST FT FI RV EX CD OllR) (CARJ/A%T) NOTES: T48F005 6 M-Il02B 2 B O }Q Q 2Y B M E3 { T4sfoos 6 u.iio2B 2 B O lQ Q , .T B M D3 i T48F02) 18 M-Il02 A B O Q Q 2Y 2 l. B M E6 C Q Q 2Y , l T48F034 IS M 1102A 2 B l 0 Q Q 2Y B M B6 l C Q Q 2Y T48F025 18 M.Il02A 2 B o j Q Q 2Y B M E2 C i Q Q 2Y T48F026 38 M-Il02A 2 B O Q Ql 2Y B M B2 C Q Qj 2Y

                                                                                                          . y                     - ,.

ENTERGY OPERATIONS, INC. PROGRAM PLAN NO.GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM VALVE

SUMMARY

LISTING - PAGE NO. Z51 -1 N SYSTEM: Z51 - Control Room IIVAC System VALVE P A ID Isf REQUIRED TESTS AND FREQUENCY RELIEF VALVE SIZE (la) NO. , IST (X)DE CODE SAFETY - REQUEST 01HER NO. TYPE ACT. WORD. PASS CLASS N- M Fs PS LT IJ ST FT FI RV EX CD ~ (VRR) (CJ/RJ/AST) NOTES: 29tF001 24 M4049 3 D l l Valve No pefiz-T B A F7 C !Q Q Q 2Y Z91F002 24 M4049 3 D i talve Na pefim -T II A F7 l C Q Q Q 2Y ZS1F003 18 M 4049 3 D Valve Na pelis-T B A B7 C Q Q Q 2Y ZStFO4 38 M4049 l-3 Il l Valve Na pefit -T 11 A Il7 C Q Q Q 2Y j Z51FQ7 20 M M4049 3 Bl 0 C C 2Y J CJJ.$l41 Valve No gefix-T 11 !! 3 I C C C 2Y l Z$1FE38 20 M 4049 3 B O lQ Q 2Y Valve No pcfis *S* - Il M G3 C lQ Q 2Y Z$1F010 I 18 M 4049 3 H y Valve No pefix-T 15 A D2 C Q Q Q 2Y h Z3iF0I1 !8 M4049 3 D Valve Na gefiz-T 11 A D2 C Q Q Q 2Y Z5tF014 20 M 4049 3 B O Q Q 2Y Valve No pefis *S* U M H3 C ] Q Q 2Y a Z$IF016 20 M 4049 3 B O C C 2Y CJJ5141 Valve Na pefix -T 11 M A3 C C C 2Y Z3t F073A 3 M-106 tC 3 B O Q Q Q Valve No petiz.T GL A F2 Z3tF07311 3 M-1061D 3 H O Q Q O Valve No gefiz-T l Gl. A E8 I

ENTERGY OPERATIONS, INC. - PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLF.AR STATION REVISION NO. 8

       ' PUMP AND VALVE INSERVICE TESTING PROGRAM                                                                  VALVE

SUMMARY

LISTING - PAGE NO. I - OF 1 Wlve Summary Listing Notes No. I To meet the requirements ofIE Bulletin 83-03, vahrs P41-F008A/B and F012 will be disassembled and inspected during the first refueling outage following installation of saht, and every 5 years thereafter. 2 Valves E12F094 and E12F096 are closed during all modes of plant operation. liowoct, these vahrs hast switches on the remote shutdown panel, and the circuits are required to be demonstrated OPERABLE at least once per 18 months, by Technical Specifications. Ren.ote vahe poshion indicators will be verified to accurately reflect vahr disc position at least once every two years. 3 Testing personnel manually mme the external arm (with counterweight) of check vahr E51F040 to the fully-closed position. Then steam is , passed through the check valve at approximately 85% ofdesign accident flow. With steam flowing and the vahe almost fully open, the

           ' testing personnel mme the arm to the fully-open position.

4 When the steam pot reaches the full mark, a drain sahr automatically opens putting flow through check sahr E51F047 and the downstream restricting orifice (0.1 gpm). During a design basis accident, the drain pot and the check vahe perform exactly the same function as during . normal operation; tigrefore verification of the proper operation of the drain pot produces a full-stroke test of the check vahe. 5 These check valves are tested closed a" a pair per NUREG-1482,4.1.1, " Closure Verification for Senes Check Vahts without Intermediate Test Connections". 6 Valves in system Cl 1, " Control Rod Drive flydraulic System", are tested as required by GGNS Technical Specifications. 7 Exercising valves E12F066A and F066B to the open position is an " Augmented" function associated with the Spent Fuel Pool Cooling System, which is considered an " Augmented" system. The closed position of F066A and F066B is associated with the E12 (RilR) System.

                                                                                                                                                           --w T

PROGRAM PLAN NO GGNS-M-189.1 REVISION NO 8 PAGE: 1 of 3 PUMP PROGRAM GENERAL The pump test requirements are presented on the Pump Summary Listing form, along with pertinent pump, system, and plant information. The form organized by systems / component, is to be used in conjunction with Piping and instrument Diagrams (P&lDs). The P&lDs for each system are listed in the Applicab!s Systems section of this document. The following pages contain instructional information to aid in the use of the Pump Summary Listing and are keyed to the various heading categories. INSTRUCTIONS FOR USE OF PUMP

SUMMARY

LISTING PUMP NO. Indicates pump number, including system number. PUMP DESCRIPTION Brief description of each pump. PUMP TYPE Reciprocating, centrifugal or vertical line shaft. DRIVER Driver type: AC motor or steam turbine. P&lD NO . COORD. P&lD number and coordinate of the P&lD at which each pump is located. IST CODE CLASS Designated as "2", or "3" for ASME Code Class 2 or 3 within the scope of OMa-1988 Part 6. Designated as "A" (Augmented) for safety related non-ASME components. Also designated as "A" for ASME components that are not within the scope cf OMa-1988 Part 6. REQUIRED TESTS AND FREQUENCY Required tests for each pump are indicated by an entry for the , associated test frequency in the Summary Listing column for the tests described below (OMa-1988 Part 6 Table 2). mt 89-t rV'textp.ru

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 2 of 3 PUMP PROGRAM l S Rotational speed measurement (required for variable speed pumps only; pumps directly coupled to synchronous or induction motors are exempt) (OMa-1988 Part 6,4.6.3). dP Differential pressure across the centrifugal or vertical line shift pump, either by direct measurement or by calculating the difference between the pressure at a point in the inlet pipe and the pressure at a point in the discharge pipe (OMa-1988 Part 6, 4.6.2.2). FR Flow rate (Q) measurement (OMa-1988 Part 6, 4.6.5). Pd Pump discharge pressure; required for positive displacement pumps only (OMa-1988 Part 6,4.6.2.2). V Broad band (unfiltered) measurement of pump vibration (velocity or displacement). If velocity measurements are used they shall be peak; if displacement measurements are used, they shall be peak-to-peak (OMa-1988 Part 6,4.6.4 and Table 2). TEST FREQUENCY Frequency of performance for the required tests. O Test performed once every 92 days (3 months). For a pump in a system declared inoperable or not required to be operable, the test schedule need not be followed. Within 3 months of placing the system in an operable status, the pump shall be tested, and the test schedule of once very 3 months followed. If any pump can not be tested during plant shutdown, it shall be tested within 1 week following plant startup (OMa-1988 Part 6,5.4). Pumps that are operated more frequently than every 92 days (3 months) need not be run or stopped for a special test, provided the plant records show each such pump was operated at least once every 92 days (3 months) at the reference conditions and the quantities specified on the Pump Summary Listing were measured, observed, recorded, and analyzed (OMa-1988 Part 6, 5 3). l m189 irV4extp-tu

PROGRAM PLAN NO. GGNS M-189.1 REVISION NO. 8 PAGE. 3 of 3 PUMP FROGRAM PRR Alternative testing and/or frequency as defined in applicable o Pump Relief Request. RELIEF REQUESTS Relief Requests for pumps that cannot be tested per Code requirements are provided in the Relief Requests section. The appropriate Relief Request number is provided in the Pump Summary Listing. NOTES Any explanatory notes required are provided or are referenced. Notes for the Pump _ Summary Listing are included at the end of the Summary Listing. SCOPE OF TESTS < Each inservice test shall include the measurement and observation of all quantities at the freq jency indicated on the Pump Summary Listing forms. / m1EtrV4ewtp4U

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 1 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR E12 01 System E12 Residual Heat Removal System Component: r12C003A E12C003B E12C003C Type: Centnfugal Class: 2 Function These jockey pumps operate continuously during normal operation to keep the main Residual Heat Removal (RHR) pump discharge piping full of water. Impractical Test Reaulrements: OMa-1988 Part 6, para 5.2: An inservice test shall be conducted with the pump operating at specified test reference conditions. The test parameters shown in Table 2 shall be determined and recorded as directed in this paragraph. OMa-1988 Part 6, para 5.2(b): The resistance of the syster., si:all be varied until the flow rate equals the reference value. The pressure shall then be determined and compared to its reference value. Attemately, the flow rate can be varied until the pressure equals the reference value and the flow rate shall be determined and compared to the reference flow rate value. OMa-1988 Part 6 Table 2: Differential Pressure is a required test parameter f; mntrifugal pumps. OMa 1988 Part 6, Table 2: Flow Rate is a required test parameter for pumps. Basis For Relief: These jockey pumps are required to operate whenever their respective RHR trains are in the operable condition. As such, the pumps perfrsrm continuous duty on a recirculation line and provide makeup as needed. There is no practical means of measuring the flow rate of these pumps, nor have attempts with ultrasonic flow measurement been successful. As such, flow rate can not be measured with the current system configuration. Even though pressure taps exist where pump suction and discharge pressure can be measured, ) the pump-differential-pressure information provided would be of little use for analyzing the hydraulic condition of the jockey pump without being able to establish a known flow condition. Additionally, jockey pump pressure is continuousiy monitored, and an annunciator alarms in the Control Room if the respective discharge header pressure drops below a preset value. Also GGNS Technical Specification Section SR 3.5.1.1 requires venfication every 31 days that the respective header is filled with water by venting the piping at the high point vents. Such continuous monitoring and monthly venting will provide waming if a jockey pump has failed, et that system leakage has exceeded the capacity of the jockey pump. Since failure of the pump to produce adequate f. eau would be identified by an annunciator in the Control Room, measurement of the actual pump differential pressure will not provide any additional benefit to warrant the

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 2 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR-E12-01 system manipulation necessary to measure the pump differential pressure directly. Finally, such actions are occurring at a periodicity more freq":. i than the quarterly periodicity mandated by OMa 1988 Part 10. Since these pumps perform continuous duty, any physical degradation of the pumps will be more readdy identified by the measurement and evaluation of the quarterly vibration data. As such, GGNS believes that adeq'Jate means exist to assess the hydraulic condition and operational readiness of these pumps without necessitating the measurement of flow rate or differential pressure. Attornative Testina: No altemative testing is considered necessary. Vibration will continue to be measured on these pumps as required by ASME OMa 1988, Part 6.

PROGRAM PLAN NO. GGNS-M-189.1-

REVISION HO 8 - PAGE NO. 3 OF 16 . PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR E21 $g313m .- E21 Low Pressure Core Spray System Component: E21C002 Igatt : Centrifugal fr. lath 2 Function ' L This jockey pump operates continuously during normal operation to keep the main Low

                    ' Pressure Core Spray (LPCS) pump discharge piping full of water.

Imoractical Test Reauirements: OMa-1988 Part 6, para 5.2: An inservice test shall be conducted with the pump operating at specified test reference conditions. The test parameters shown in Table 2 shall be determined and recorded as directed in this paragraph. OMa-1988 Part 6, para 5.2(b): The resistance of the system shall be varied until the flow rate equals the reference value. The pressure shall then be determined cnd compared to its reference - value.-- Altomately, the flow rate can be varied until the pressure equals the reference value and the flow rate shall bo determined and compared to the reference flow rate value. OMa-1988 Part 6, Table 2: Differential Pressure is a required test parameter for centrifugal 7 pumps. OMa-1988 Part 6, Tabla 2: Flow Rate is a required test parameter for pumps. Basis For Relief: This jocney pump is required to operate _whenever the LPCS system is in the operable condition. As such, the pump performs continuous duty on a recirculation line and provides makeup as needed There is no practical means of measuring the flow rate of this pump, nor have attempts with ultrasonic flow measurement been successful. As such, flow rate can not be measured with the current system configuration. Even though pressure taps exist where pump suction and discharge pressure can be measured, the pump-differential-pressure informatir.,n provided would be of little use for analyzing the hydraulic condition of the jockey pump without being able to establish a known flow condition, i Additionally, jockey pump pressure is continuously monitored, and an annunciator alarms in the Control Room if the discharge header pressure drops below a preset value.. Also, GGNS Technical Specification Section SR 3.5.1.1 requires verification every 31 days that the header is filled with water by venting the piping at the high point vents. _Such continuous monitoring and

        - monthly venting will provide waming if the jockey pump has failed, or that system leakage has s         exceeded the capacity of the jockey pump. Since failure of the pump to produce adequate head would be identified by an annunciator in the Control Room, measurement of the actual pump differential precsure will not provide any additional benefit to warrant the system manj.pulation

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 4 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR E21-01 necessary to measure the pump differential pressure directly. Finally, such actions are occurring at a periodicity more frequent than the quarterly periodicity mandated by OMa-1988 Part 10. Since this pump performs continuous duty, any physical degradation of the pump will be more readily identified by the measurement and evaluation of the quarterly vibration data. As such, GGNS believes that adequate means exist to assess the hydraulic condition and operational readiness of this pump without necessitating the measurement of flow rate or differential pressure. Alternative Testina: No attemative testing is considered necessary, Vibration will continue to be measured on this pump as required by ASME OMa-1988, Part 6.

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 5 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR-E22-01 System E22 High Pressure Core Spray System Component: E22C003 Tygpl Centrifugal gig 31;, 2 Function This jockey pump operates continuously during normal operation to keep the main High Pressure Core Spray (HPCS) pump discharge piping full of water. Imoractical Test Reauirements: OMa 1988 Part 6, para 5.2: An inservice test shall be conducted with the pump operating at specified test reference conditions. The test parameters shown in Table 2 shall be determined and recorded as directed in this paragraph. OMa-1988 Part 6, para 5.2(b): The resistance of the system shall be varied until the flow rate equals the reference value. The pressure shall then be determined and compared to its reference value. Altemately, the flow rate can be varied until the pressure equals the reference value and the flow rate shall be determined and compared to the reference flow rate value. OMa-1988 Part 6, Table 2: Differential Pressure is a required test parameter for centrifugal pumps. OMa 1988 Part 6 Table 2: Flow Rate is a required test parameter for pumps. Basis For Relief: This jockey pump is required to operate whenever the HPCS system is in the operable condition, As such, the pump performs continuous duty on a recirculation line and provides makeup as needed. There is no practical means of measuring the flow rate of this pump, nor have attempts with ultrasonic flow measurement been successful. As such, flow rate can not be measured with the current system configuration. Even though pressure taps exist where pump suction and discharge pressure can be measured, the pump-differential-pressure information provided v<ould be of little use for analyzing the hydraulic condition of the jcekey pump without being able to establish a known flow condition. Additionally, jockey pump pressure is continuously monitored, and an annunciator alarms in the Control Room if the discharge header pressure drops below a preset value. Also, GGNS Technical Specification Section SR 3.5.1.1 :equires verification every 31 days that the header is filled witn water by venting the piping at the high point vents. Such continuous monitoring and monthly venting will provide waming if the jockey pump has failed, or that system leakage has exceeded tiie capacity of the jockey pump. Since failure of the pump to produce adequate head would be identified by an annunciator in the Control Room, measurement of the actual pump differential pressure will not provide any additional benefit to v. arrant the system manipulation

PROGRAM PLAN NO. GGNS-M-189.1 REVie:ON NO. 8 PAGE NO. 6 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR E22-01 necessary to measure the pump differential pressure directly. Finally, such actions are occumng at a periodicity more frequent than the quarterly periodicity mandated by OMa 1988 Part 10. Since this pump performs continuous duty, any physical degradation of the pump will be more readily identified by the measurement and evaluation of the quarterly vibration data. As such, GGNS believes that adequate means exist to assess the hydraulic condition and operational readiness of this pump without necessitating the measurement of flow rate or differential pressure. Alternative Testino: No attemative testing is considered necessary. Vibration will continue to be measured on this pump as required by ASME OMa-1988, Part 6.

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE NO. 7 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P75-01 System P75 Standby Diesel Generator System Component: P75C002A P75C002B TyRf1 Centrifugal Class: 3 Function Transfer fuel oil from the storage tank to the day tank to satisfy the seven day fuel oil supply requirement for the standby diesel generators. Imoractical Test Requirements: OMa-1988 Part 6, para 5.2: An inservice test shall be conducted with the pump operating at specified test reference conditions. The test parameters shown in Table 2 shall be determined and recorded as directed in this paragraph. OMa 1988 Part 6, para 5.2(b): The resistance of the system shall be varied until the flow rate equals the reference value. The pressure shall then be determined and compared to its reference value. Altemately, the flow rate can be varied until the pressure equals the reference value and the flow rate shall be determined and compared to the reference flow rate value. OMa-1988 Part 6, Table 2: Differential Pressure is a required test parameter for centrifugal pumps. OMa-1988 Part 6, Table 2: Vibration is a required test parameter for pumps. Basis For Relief: Fuel Oil Transfer System Arrangement The physical locations of the Standby Diesel Generator (SDG) fuel oil transfer pumps are at the bottoms of the respective SDG fuel oil storage tanks, which are buried in the ground outside the diesel generator bays. The pump design specifies each pump to be submerged in the fuel oil with the 3/4-inch discharge piping rising from the pump, through the fuel oil, and out the top of the tank approximately 13 feet above the pump discharge. Approximately 1 foot above the tank, the 3/4-inch piping widens to 2 inch diameter pipe. A 2-inch check valve near the expansion fitting prevents fuel oilin the transfer piping from draining back into the storage tank. The 2-inch piping nses approximately 15 to 16 inches, elbows twice during the next 29-inch run, and then flanges 20 inches later prior to entering the ground. Since good engineering design requires a minimum of 5 pipe diameters both upstream and downstream for source pressure measurement, the only adequate location for a pressure instrument tap within this exposed piping between the top of the storage tank and the ground entry point is the 29-inch run. However, as the following justification will identify, locating a pressure tap in this exposed pipe run will not provide a significant increase in the usefulness of a discharge pressure measurement. The 2 inch piping then runs underground to the respective SDG room, and rises above ground level enroute to the day tank. Shortly after the 2-inch piping exits the ground in the respective SDG room, but pnor to the SDG fuel oil strainer, is the pressure instrument tap used to measure

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 8 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR.P75-01 the transfer pump discharge pressure. This pressure instrument tap is the current location for measurement of the pump discharge pressure, and is located approximately 12 feet above the 3/4 to 2-inch expansion fitting (24 feet above the actual pump discharge), and approximately 10 feet below the highest piping elevation to the day tank. As noted above, the 3/4 inch diameter discharge pip;ng run and elevation rise are both approximately 13 feet. The 2 inch diameter fuel oil transfer piping run is approximatch 295 feet ('B' DG) and 360 feet ('A' DG), and a total nse of 22 feet before entering the top of the respective SDG day tank. For both trains of the SDG fuel oil transfer piping, the only isolation valve is located in the highest elevation run of the 2 inch pipe shortly upstream of where the pipe enters the day tank. Difforential Pressure Discus: ion Between August 1994 and July 1997,15 inst.rvice tests were performed and docut.1ented for trending purposes for the 1P75C002A pump. [For brevity, only test data from the 'A' pump is given. The 'P' pump exhibits similar resu!ts.) For these 15 tests, the pressure readings at the current instrument location ranged from 3.96 to 5.51 psig, which obviously does not reflect the frue discharge pressure of the pump. The suction pressure, which is calculated utilizing the level of the storage tank, has ranged from 3.43 to 3.67 psig during these tests. The calculated differential pressure utilizing only the discharge instrument and suction pressure has ranged from 0.34 to 2.04 psid. This calculated differential pressure ir, clearly nnt representa'.ive of the actual pump differential pressure. Based on a system resistance cal:,ulation, these pumps experience approximately 68% to 70% of the total head loss in the 3/4 inch piping. Thus, only approximately 30% of the actual pump discharge pressure is measurable at the 3/4 to-2 inch reducer. From the reducer to the pressure instrument tap location, another 5 psi drop is experienced due to the elevation difference alone. Although the actual pressure readings documented during the test period analyzcc nave been in the range expected, the information has provided very little velue as a pump-degradation tool. The average measured discharge pressure over the analyzed tests is approximately 5.30 psig, with the average cuction pressure being approximately 3.57 prig, thus the average differential pressure has been around 173 psid. As an attempt to make the differential pressure measurem9nt e more practical pump performance indicator, a correction factor was calculated based on the respective SDG fuel oil system resistances. However, testing expenence has indicated that even the uf;e of a correction factor has not increased the usefulness of the differential-pressure determinations for these pumps, as the following discussion will establish. The system resistance is based on the flow ratc, and therefore the correction factor utilized would need to be based on the system flow rate during the test. This would necessitate setting the flow rate at a fixed value (32.75 gpm being the current reference value), and determining the pump differential pressure, OR setting the differential pressure and determining the flow rate. Both of I these test methods are considered to be impractical for the following reasons: (1) Flow rate is determined by measuring the day tank level changc from the low-level alarm to the pump shutoff level, and dividing the change by the pump run time. As such, instantaneous I

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO. 9 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P75-01 flow measurement is not available to allow simple adjustment to establish a fixed flow. There are no installed flowmeters or taps for measuring flow rate directly. Ultrasonic flow measurement attempts have proven to be inconsistent when compared to the level change method. The current method for determination of flow rate meets the loop accuracy requirements mandated per Table 1 of OMa 1988 Part 6. Modification to install a flow meter solely for the purpose of providing instantaneous flow indication to allow establishment of a fixed flow rate is clearly not the intent of OM&1988 Part 6. (2) Differential pressure is determined by a calculation of the measured discharge pressure plus the correction factor minus the suction pressure. The suction pressure is from a real time calculation based on the storage tank level measurement during pump run. To ensure full loop accuracy. a Barton tube gauge (0-200 inches of water)is utilized to measure the discharge pressure, and thus requires a real time calculation to convert inches of water to psi. Thus, three calculations are required for each valve adjustment to establish a differential pressure. To utilize differential pressure as the fixed parameter, each system adjustment to set the differential pressure to the reference velue would necessitate the performance of these three calculations Each performance of these calculations adds time to the pump run duration and unnecessarily increases the potential for calculational error. (3) The pump run is typically 8-10 minutes which, as noted above, will not allow for a fixed parameter adjustment during the pump run. Thus, the day tank would need to be drained to the low level for another pump run once the differential pressure is correctly adjusted. Tne breaker for the pump must be opened in order to drain the day tank to the low level alarm. Unnecessary cycling of component breakers solely for the purpose of performance testing is not desirable. (4) The globe valve is the only available means of adjusting the system resistance to set either flow rate or differential pressure equal to its reference value; however, adjusting the globe valve will change the system resistance upon which the differential pressure correction factor is based. The corresponding resis'ance factor for the position of the globe valve would need to be determined to re-perform the system resistance calculation, and could necessitate the performance of the system resistance calculation during each pump test depending upon the sensitivity of the valve's resistance factor versus valve position. In either case, valve adjustment would add additional uncertainty to the correction factor applied to the differential pressure measurements, which would further reduce the usefulness of the differential pressure as a pump performance parameter. (5) Evaluation of the inservice testing results for these pumps has shown that differential pressure measureme at is not provioing any substantial benefit as a diagnostic tool for pump hydraulic performanci The current differential pressure reference values for these pumps are 28,11 ('A') and 28.29 ('B') psid. These reference values are based on a correction factors from the syt!em resistance at an average flow rate of approximately 33.0 gpm. Even thcugh a different reference flow rate (32.75 Cpm) has been established since the original differential pressure reference value was determined, there has been absolutely no change in the average differential pressure results for the tests at the new flow reference value. If a new reference value is established based on a currection factor at 32.75 gpm, the same test results would be averaged around the new correction factor because of the vury little variation between the measured suction and discharge

PROGRAM PLAN NO. GGNS M-189.1 REVISION NC. 8 PAGE NO.10 OF 16 PUMP REllEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P75-01 pressures. However, establishing new correction factors or reference vales would provide no additional benefit as noted below. Per Tab!e 3b of OMa 1988 Part 6, the acceptance enteria can deviate from the reference value by as much as 10% (2.8 psi) before corrective action is necessary. In order to nchieve a 2.8 psi drop in differential pressure, the measured discharge pressure would have to drop to approximately 1.2 to 2.4 psig since suction pressure remains fairly constant. The pressure drop due solely to the elevation difference between the pressure instrument location and the maximum elevation experienced enroute to the day tank is approximately 4 psi. As such, flow would have to drop dramatically, and even cease, before the differential pressure ever came close to the lower required action value. Therefore, it has become clear that the only parameter which is currently providing any true reprcsentation of the pump hydraulic condition is the flow rate. To make the measurement of the pump differential pressure a uceful parameter for pump perforrnance evaluation, it would be necessary to perform a modification to install the pump discharge pressure gage closer to the pump discharge. Such a modification is considered to represvnt an unusual hardship without a compensating increase in the level of quality and safety for the following reasons: (a) Any modification wr:uld require romoval of the fuel oil transfer pump from the associated fuel oil storage tank to make the necessary modification. (b) A direct sensing instrument at the discharge penetration elevation would be submerged in the fuel oil with the pump. For this application, a pressure transducer would be required in lieu of a pressure gage. Such an arrangement would necessitate the removal of the pump assembly from the storage tank every time the pressure transducer required calibration. (c) If a pressure gage option were used with the tap location at the discharge of the pump, the least impact would be caused by routing the gage line along with the fuel discharge piping. However, this option would require an additional modification to the existing discharge flange arrangement at the top of the sf) rage tank to allow the sensing line to penetrate the tank (any other penetration location would necessitate an entry into the tank to disconnect the sensing line whenever the pump is required to be pulled for planned or corrective maintenance.) Once this modification was performed, a correction factor will still need to be calculated to account for the elevation 6fference between the gage and the pump. (d) The current test configuration allows the fuel oil transfer system to be treated as a fixed-resistance system due to the negligible head loss between the current discharge measurement location and the day tank. If a modification were performed to allow for more practical discharge pressure measurement, the system may no longer qualify as a fixed-resistance *ystem depending upon the modification performed, if such were the case, resistance adjustment would necessitate at least two pump runs per quarter as discussed above. The option does exist to keep the drain opun on the day tank while the adjustment is made, and then the drain would be shut for the level measurement. This option, however, could significantly reduce the accuracy of the flow rate measurement due to the shorter pump run time and due to the need to measure the initial tank level while the pump is actually filling the tank instead of during a stable, no-flow condition. (e) Safety related maintenance activities, such as the removal of this pump for any reason, are

l l PROGRAM PLAN NO. GGNS M 169.1 j REVISION NO. 8 PAGE NO.11 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P75-01 expensive undertakings and ;nvolve risks associated with the disassembly of any piping system. Performance of a modification requiring such activities will significantly increase the cost burden, l 1 (f) Working with fuel oil systems involves additional personnel and equipment safety hazards, which should be minimized whenever possible. (g) If the transducer option were installed, removal and reir'stallation of the pump assembly would be necessary for calibration purposes. This would require additional testing to be performed on the system to ensure that the maintenance activity did not impact the h)draulic performance capability of the fuel oil transfer system. Such testing would require vt rification that the reference values of the pump hydraulic parameters were not affected. If a transducer arrangement were usea, then revalidation of the reference values would be required at the same periodicity as the instrument calibration. This is clearly not the intent of Part 6. (h) Finally, diesel-generator operability and availability could be adversely affected by an installation of any modification that would require multiple test runs of the fuel oil transfer pump or frequent storage tank entries for calibration purposes should se;h instnJmentation be installed. Vibration Discussion The physicallocation of each pump is at the bottom of the respective SDG fuel oil storage tank, which is buried in the ground outside the diesel generator bay. Due to the pumps being submerged, vibration measurements cannot be performed. Additionally, installation of permanently-mounted transducers are considered impractical for the same reasons as discussed for pressure transducer installation impracticality. It should be noted that OMa 1988 Part 6, paragraph 4.6.4(a), requires vibration measurements to be performed on centrifugal pumps only if they have " accessible" pump bearing housings. Alternative Testina: As noted in the preceding discussion, the existing means of meaturing pump differential pressure does not provide iny usefulinformation regarding the pump hydraulic condition that would not be readily apparent by a corresponding decrease in pump flow. For the fuel oil transfer system pumps, the measurement of flow alone, with the following additional requirements, will provide an acceptable level of quality and safety while having minimal negative impact on diesel generator operability and availability. Before starting the pumps, adequate storage tank level will be ensured for pump NPSH requiremen3. The systems will be left in their normal alignment with no valves throttled. The day tanks will be 6,5ned to a low level and then refilled using the associated fuel )il transfer pump. An average flow rate will be calculated and compared to its referenco value in order to determine if any pump degradation is occurnng. A lower " alert value"(not presently required per 1able 3b of Part 6 for centrifugal pumps) of 93% of the reference flow value will be established for each of the pumps. If the measured flow rate falls beluw this " alert value", then the analyses and evaluation actions required by Section 6 of OMa 1988 Part 6 will be performed. Vibration measurements will not be performed due to the inaccessibility of these pumps.

l PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 l PAGE NO.12 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P81-01 Sy11tm P81 HPCS Diesel Generator System Component, 001C001 Irmi Centnfugal Clasa: 3 Function Transfer fuel oil from the storage tank to the day tank to satist 'he rieven day fuel oil supply requirement for the HPCS ciesel generator. impractical Test Reauirements_1 OMa 1988 Part 6, para 5.2: An inservice test shall be conducted with the pump operating at specified test reference conditions. The test parameters shown in Table 2 shall be determined and recorded as directed in this paragraph. OMa 1988 Part 6, para 5.2(b); The resistance of the system shall be varied until the flow rate equals the reference value. The pressure shall then be determined and compared to its reference value. Alternately, the flow rate can be varied until the pressure equals the reference value and the flow rate shall be determined and compared to the reference flow rate value. OMa 1988 Part 6, Table 2: Differential Pressure is a required test parameter for centnfugal pumps. OMa 1988 Part 6, Table 2: Vibration is a required test parameter for pumps. Basis For Relief: Fuel Oil Transfer System ArrangemeW. The physicallocation of the High Pressure Core Spray Diesel Generator (HPCS DG) fuel oil transfer pump is at the bottom of the HPCS DG fuel oil storage tank, which is buried in the ground outside the diesel generator bay. The pump design specifies the pump to be submerged in the fuel oil with the 3/4 inch discharge piping rising from the pump, through the fuel oil, and out the top of the tank appioximately 11 feet above the pump discharge. Less than 1 foot above the tank, the 3/4 inch piping widens to 2 inch diameter pipe. A 2-inch check valve near the expansion fitting prevents fuel oilin the transfer piping from draining back into the storage tank. The 2 inch piping rises approximately 4 inches, elbows twice during the next 14 inch run, and then flanges 9 inches la;er prior to entering the ground. Since good engineering design requires a minimum of 5 pipe diameters both upstream and downstream for source pressure measurement, there is no adequate location for a pressure instrument tap wnhin this exposed piping between the top of the sto. age tank and the ground entry point. The 2 inch piping then runs underground to the HPCS DG room, and rises above ground level enroute to the day tank. Shortly after the 2 inch piping exits the ground in the HPCS DG room, but prior to the DG fuel oil strainer, is the pressure instrument tap used to measure the transfer pump discharge pressure. This pressure instrument tap is the closest practical point for measurement of the pump discharge pressure, and is located approximately 11.5 feet above the

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.13 OF 10 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P8101 3/4 to-2 inch expansion fitting (23.5 feet above the actual pump discharge), and 6.5 feet below the highest pipino elevation to the day tank. As noted above, the 3/4-inch diameter discharge piping run and elevation rise are approximately 11 feet. The 2 inch diameter fuel oil transfer piping run and total rise is approximately 177.5 feet and 19 feet respectively before entering the top of the HPCS DG day tank. The onfy isolation valve in the HPCS DG fuel oil transfer piping is located in the highest elevation run of the 2 inch pipe shortly upstream of where the pipe enters the day tank. Differential Pressure Discussion Between August 1994 and July 1997,20 inservice tests were performed and documented for trending purposes. For these 20 tests, the pressure readings at this instrument location ranged from 2.95 to 3.80 psig, which obviously does not reflect the true discharge pressure of the pump. The suction pressure, which is calculated utilizing the level of the storage tank, has ranged from 3.51 to 3.80 psig during these tests. The calculated differential pressure utilizing only the discharge instrument and suction pressure has ranged from -0.71 to 0.17 psid. This calculated differential pressure is clearly not representative of the actual pump differential pressure. Based on a system resistance calculation for the HPCS DG fuel oil transfer system, the expected pump discharge pressure for the current reference flow rate (36.7 gpm)is 35 4 psig. Also, based on the same resistance calculation, the pump experiences approximately 75% of the total head loss in the 3/4 inch piping. This would yield an approximate pressure measurement of 8.8 psig at the 3/4 to-2 inch reducer. From the reducer to the pressure instrument tan location, another 5 psi drop is experienced due to the elevation difference alone. Although the actual pressure readings documented during the test penod analyzed have been in the range expected, the information has provided very little value as a pump-degradation tool. The average measured discharge pressure over the analyzed tests is approximately 3.65 psig, with the average suction pressure being approximately 3.68 psig, thus the average differential pressure has been around 0.03 psid. As an ettempt to make the differential pressure measurement a more practical pump performance indicator, a correction factor was calculated based on the HPCS DG fuel oil system resistance. However, testing experience has indicated that even the use of a correction factor has not increased the usefulness of the dPerential-pressure determinations for this pump, as the following discussion will establish. The system resistance is based on the flow rate, and therefore the correction factor utilized would need to be based or the system flow rate during the test. This would necessitate setting the flow rate at a fixed value (36.7 gpm being the current reference value), and determining the pump ddferential pressure, OR setting the differential pressure and determining the flow rate. Both of these test methods are considered to be impactical for the following reasons: (1) Flow rate is determined by measuring the day tank level change frum the low level alarm to the pump shutoff level,9nd dividing the change by the pump run time. As such, instantaneous flow measurement is not available to allow simple adjustment to establish a fixed flow. There are no installed flowmeters or taps for meauring flow rate directly. Ultrasonic flow measurement

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.14 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR.P81-01 attempts have proven to be inconsistent when compared to the level change method. The current method for determination of flow rate meets tne loop accuracy requirements mandated per Table 1 of OMa 1988 Part 6. Modificat'on to install a flow meter solely for the purpose of providing instantaneous flow indication to allow establishment of a fixed flow rate is clearly not the intent of OMa 1988 Part 6. (2) Differential pressure is determined by a calculation of the measured discharge pressure plus tiie correction factor minus the suction pressure. The suction pressure is from a real time calculation based on the storage tank level measurement during pump run. To ensure fullloop acenracy, a Barton tube gauge (0 200 inches of water)is utilized to measure the discharge pressure, and thus requires a real time calculation to convert inches of v.mter to psi. Thus, three calculations are required for each valve adjustment to establish a diffeicntial pressure. To utilize differential pressure as the fixed parameter, each system adjustment to set the differential pressure to the reference value would necessitate the performance of these three calculations. Each performance of these calculations adds time to the pump run duration and unnecessarily increases the potenti Al for calculational error. (3) The pump run is typically 9-10 minutes which, as noted above, will not allow for a fixed parameter adjustment during the pump run. Thus, the day tank would need to be drained to the low level for another pump run once the differential pressure is correctly adjusted. The breaker for the pump must be opened in order to drain the day tank to the low level alarm. Unnecessary cycling component breakers solely for the purpose of performance 'esting is not desirable. (4) The globe valve is the only available means of adjusting i ,ystem resistance to set either flow rate or differential pressure equal to its reference value; ih vever, adjusting the globe valve will change the system resistance upon which the differential pressure correction factor is based. The corresponding resistance factor for the position of the globe valve would need to be determined to re-perform the system resistance calculation, and could necessitate the performance of the system resistance calculation during each pump test depending upon the sensitivity of the valve's resistance factor versus valve position. In either case, valve adjustment would add additional uncertainty to the correction factor applied to the differential pressure measurements, which would further reduce the usefulness of the differential pressure as a pump performance parameter. (5) Evaluation of the inservice testing results for this pump has shown that differential pressure measurement is not providing any substantial benefit as a diagnostic tool for pump hydraulic performance. The current differential pressure reference value for this pump is 33.7 psid which was based on a system resistance at the old reference flow rate of approximately 35 gpm. Even though a different reference flow rate (36.7 gpm) has been established since the original differential pressure reference value was determined, there has been absolutely no change in the average differential pressure results for the tests at the new flow reference value. If a new reference value is established based on a correction factor at 36.7 gpm, the same test results would be averged around the new correction factor because of the very little variation between the measured suction and discharge pressures. However, establishing a new correction factor or reference value would provide no additional benefit as noted below.

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE NO.15 OF 16 PUMP RELIEF REQUESTS PUMP RELIEF REQUEST NO.: PRR P81-01 Per Table 3b of OMa 1988 Pcrt 6, the acceptance enteria can deviate from the reference value by as much as 10% (3.3 psi) before corrective action is necessary. In order to achieve a 3.3 psi drop in differential prescure, the measured discharge pressure would have to drop to approximately 0.4 to 0.5 psig since suction pressure remains fairly constant. The pressure drop due solely to the elevation difference between the pressure instrument location and the maximum elevation experienced enroute to the day tank is approximately 2.5 psi. As such, flow would have to drop dramatically, and even cease, before the differential pressure ever came close to the lower required action value. Themfore, it has become clear that the only parameter which is currently providing any true representation of the pump hydraulic condition is the flow rate. To mal.e the measurement of the pump differential pressure a useful parameter for pump performance evaluation, it would be necessary to perform a modification to install the pump discharge pressure gage closer to the pump discharge. Such a modification is considered to represent an unusual hardship without a compensating increase in the level of quality and safety for the following reasons: (a) Any modificadon would require removal of the fuel oil transfer pump from the associated fuel oil storage tank to make the necessary modification. (b) A direct sensing instrument at the discharge penetration elevation would be submerged in the fuel oil with the pump. For this application, a pressure transducer would be required in lieu of a pressure gage. Such an arrangement would necessitate the removal of the pump assembly from the storage tank every time the pressure transducer required calibration. (c) If a pressure gage option were used with the tap location at the discharge of the pump, the least impact would be caused by routing the gage line along with the fuel discharge piping. However, this option would require an additional modification to the existing discharge flange arrangement at the top of the storage tank to allow the sensing line to penetrate the tank (any other penetration location would necessitate an entry into the tank to disconnect the sensing line whenever the pump is required to be pulled for planrsed or corrective maintenance.) Once this modification was performed, a correction factor will still need to be calculated to account for the elevation difference between thG gage and the pump. (d) The current test configuration allows the fuel oil transfer system to be treated as a fixed-resistance system due to the negligible head loss between the current discharge measurement location and the day tank. If a modification were performed to allow for more practical discharge pressure measurement, the system may no longer quahfy as a fixed-resistance system depending upon the modification performed. If such were the case, resistance adjustment would necessitate at least two pump runs per quarter as discussed above. The option does exist to keep the drain open on the day tank while the adjustment is made, and then the drain would be shut for the level measurement. This option, however, could significantly reduce the accuracy of the flow rate measurement due to the shorter pump run time and due to the nead to measure the initial tank level while the pump is actually filling the tank instead of dunng a stable, no-flow condition. (e) Safety related maintenance activities, such as the removal of this pump fer any reason, are expensive undertakings and involve risks associated with the disassemb'y of any piping system. Performance of a modification requiring such activities will significantly increase the cost burden.

PROGRAM PLAN NO. GGNS M-189.1 REVISION NO. 8 - PAGE NO.16 OF 16 , PUMP RELIEF REQUESTS i PUMP RELIEF REQUEST NO.: PRR P81-01 (f) Working with fuel oil systems involves additional personnel and equipment safety hazards, which snould be minimized whenever possible. t (g) If the transducer option were installed, removal and reinstallation of the pump assembly would be necessary for calibration purposes. This would require additional testing to be performed on 4 the system to ensure that the maintenance activity did not impact the hydraulic performance capability of the fuel oil transfer Jystem. Such testing would require verification that the reference values of the pump hydraulic parameters were not affected. If a transducer arrangemert were used, then revalidation of the reference values would be required at the same periodicity as the instrument calibration. This is clearly not the intent of Part 6. (h) Finally, diesel generator operability and availability could be adversely affected by installation of any modificatiori that would require multiple test runs of the fuel oil transfer pump or frequent storage tank entries for calibration purposes should such instrumentation be installed, Vibration Discussion The pnysical location of tne pump is at the bottom of the HPCS DG fuel oil storage tank, which is : buried in the ground outside the diesel generator bay Due to the pump being submerged, ! vibration measurements cannot be pe. formed. Additionally, installation of permanently mounted transducers are considered impractical for the same reasons as discussed for pressure transducer installation impracticality, it should be noted that OMa 1988 Par 16, paragraph 4.6.4(a), requires vibration measurements to be performed on centrifugal pumps only if they have " accessible" pump bearing housings.

      &lternative Testino:

As noted in the preceding discussion, the existing means of measuring pump differential pressure does not provide any aseful information regarding the pump hydraulic condition that would not be readily apparent by a corresponding decrease in pump flow. For the fuel oil transfer system pump, the measurement of flow alone, with the following additional requirements, will provide an acceptable level of quality and safety while having minimal negative impact on diesel-generator operability and availability. Before starting the pump, adequate storage tank level will be ensured for pump NPSH requirements. The system will be left in its normal alignment with no valves throttled. The day tank will be drained to a low level and then refilled using the fuel oil transfer pump. An average flow rate will be calculated and compared to its reference value in order to determine if any pump degradation is occurring. A lower " alert value"(not presently required per Table 3b of Part 6 for centrifugal pump,,) of 93% of the reference flow value will be established for the pump. If the measured flow rate fdis below this " alert value", then the analyses and evaluation actions required by Sectiot 6 of OMa 1988 Part 6 will be performed. Vibretion measurements will not be perforrned due to the inaccessblity of the pump.

ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS.M.189.1 GRAND GULF NUCLEAR STATION REVISION NO. 8 PUMP AND VALVE INSERVICE TESTING PROGRAM PUMP

SUMMARY

LISTING -PAGE NO. 1 OF 2 I l F A ID So, IST REQCIRED TE5T5 A3D FREQtm'

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ENTERGY OPERATIONS,INC. PROGRAM PLAN NO. GGNS-M-189.1 GRAND GULF NUCLEAR STATION REVISION NO.8 PUMP AND VALVE INSERV!CE TESTING PROGRAM PUMP SUk1 MARY LISTING-PAGE NO. 2 OF 2 F & ID No, IST l REQt1 RED TESTS AND FitEQtM" FtJMr CUORD. CUDE I f

39. FUMP DESCRIPTION FUMP TYPE DRIVER Gass.f S dJ FR V l l Pd f. l RELIEF REOt ESTS: SOTES:.

P4IO)0!B SSW BILOP VertzaI Une Shat Mcaer I M-1061 A 3 Q Q l Q G5 P48C002 HPCE SW Vertzal Une ShmA Mdar M-106I A 3 Q Q Q F4 F75CIM)2A ILT10lLTR ANSFER - DIV. I Cenerdugal Makr M-IO70A 3 PRR Q FRR FRR-F7541 , G7 F75C002B FUE10!L TRANStut - DIV. 2 Ceardugal Me M-10703 3 FER Q PRR ; PRR-F7341 l 07 } t l rslC001 FUEL OIL TRANSFER -ItPCS DG Centringal Ektor M-1093A 3 81 FRR Q PRR !PRX-r5841 B4 9j l

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t Entergy Operoflons, Inc. PROGRAM PLAN NO. GGNS-M 189.1 Grand Gulf Nuclear Station REVISION NO. 8 Pump And Vulve Inservice Testing Program PAGE: COVER SHEET , i i APPENDIX A BASES FOR MAXIMUM STROKE TIMES OF POWER ACTUATED VALVES m1941r$wa.t$ y-,. w- m - - - , , . -y -,-,my . 37-y-.- -y., ---g- g e .-.--y- -gw-< -9,---,-- 3

PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 8 PAGE: 1 OF 18 APPENDlX A 1.0 PURPOSE IST Maximum Stroke Times are required, by ASME Section XI, Paragraph IWV 3413 for all power actuated valves in the Pump and Valve Inservice Testing Program. The purpose of this appendix is to identify those valves for which a bases for the IST , Maximorn Stroke Times exists in plant documentation. Bases for IST Maximum Stroke Times provide the maximum allowable valve stroke times required for safety system operation. The IST Maximum Stroke Time shall not exceed these values. 2.0 SCOPE This appendix provides bases (e.g., Calculations, Technical Specifications or other safety analysis limits) for IST Maximum Stroke Times of power actaated valves. , NOTE:The stroke times provided by this appendix may not be the limiting values of full-stroke times for IST (i.e., IST Maximum Stroke Times). The IST Maximum Stroke Time shall be compared to the values in this appendix, and the lesser of the two shall be used. IST Ma mum Stroke Times are controlled by this appendix and Aroendix C and are contained in Plant Staff Procedures. 3.0 RESPONSIBILITY 3.1 Performance and Systems Engineering (P&SE) 3.1.1 Uses this appendix for comparison of calculated stroke times with , bases stroke times 3.2 Nuclear Plant Engineering (NPE) 3.2.1 Develops bases for IST Maximum Stroke Times 4 3.2.2 Provides bases for IST Maximum Stroke Times in this appendix

4.0 REFERENCES

4.1 USNRC Generic Letter No. 89-04, Guidance on Developing Acceptable Inservice Testing Programs, dated April 3,1989. 4.2 ASME Boiler and Pressure Vessel Code, Section XI, Paragraph IWV 3413. 5.0 ATTACHMENTS None mwt w o

l l l PROGRAM PLAN NO. GGNS M 189.1 REVISION NO. 0 1 PAGE: 2 OF 18 l APPENDIX A 6.0 DEFINITIONJ None 7.0 DETAILS 7.1 IST Maximum Stroke Times should, per the guidance of USNRC Generic Letter 89-04, be the lesser of the following:

a. A calculated value based on the valve reference or average stroke time when it is known to be in good condition and operating properly, or,

b. A Technical Specification, safety analysis or analytical limit listed in this Appendix.

7.2 Appendix C provides methods for calculation of IST Maximum Stroke Times. 7.3 Descriptions of Columns in Appendix A 7.3.1 The first column lists valves in numerical order by system / valve number. 7.3.2 The second column lists the Safety Position of the valve. This is the position the valve should be in to perform its safety function. 7.3.3 The third column lists the stroke time value (unless otherwise noted, stroke times are in seconds). 7.3.4 The fourth column lists the reference document containing the stroke time value. 7.3.5 The fifth column lists specific notes regarding the ectries (notes are listed on the last page). m141the4

t SPECIFICATION NO. GGNS M 189.1 REVISION NO. 8 PAGE: 3 OF 18 - APPENDIX A SAFETY STROKE TIME , VALVE NO. POSITION STROKE TIME REFERENCE NOTES ! 821F016 C 20 TRM Table TR3.6.1.31 821F019 C 20 TRM Table TR3.6.1.3-1 B21F022A, C 5 SR3.6.1.3.6 C 5 TRM Table TR3.6.1.3-1 C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.0-4 C 5 UFSAR Table 15.412 C 5 UFSAR Table 15.61 C 5 'JFSAR Table 15.6-2 C 5 UFSAR Table 5.2 5 - C 5 UFSAR Table 6.2-44 L B21F022B C 5 SR3.6.1.3.6 C 5 TRM Table TR3.6.1.3-1 C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.0-4 C 5 UFSAR Table 15.412 C 5 UFSAR Table 15.6-1 C 5 UFSAR Table 15.6 2 C 5 UFSAR Table 5.2 5 C 5 UFSAR Table 6.2-44 -,- ~- - <c-s. ~ , , - , . . . . . . - - --

SPECIFICATION NO. GGNS-M 189.1 REVISION NO. 8 i PAGE: 4 OF 18 APPENDIX A SAFETY STROKE TIME ! VA.VE NO. PQSITION STROKE TIME REFERENCE NOTES B21F022C C 5 SR3.6.1.3.6 ; C 5 TRM Table TR3.6.1.3-1 C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f t C- 5 UFSAR Table 15.0-4 ! C 5 UFSAR Table 15.412 C 5 UFSAR Table 15.61 C 5 UFSAR Table 15.6 2 C 5 UFSAR Table 5.2 5 C 5 UFSAR T Oie 6.2 4 i 821F022D C 5 SR3.6.1.3.6 C 5 TRM Table TR3.6.1.31 , C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15.2.4.3.2 : C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.0-4 C 5 UFGAR Table 15.4-12 C 5 UFSAR Table 15.61 C 5 UFSAR Table 15.6-2 C 5 UFSAR Table 5.2 5 C 5 UFSAR Table 6.2 44 821F028A C 5 SR3.6.1.3.6 ; C 5 TRM Table TR3.6.1.3-1 C 5 UFSAR 15.1.3.3.2 , C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f ; C 5 UFSAR Table 15.0-4 C 5 UFSAR Table 15.4-12 C 5 UFSAR Table 15.6-1 C 5 UFSAR Table 15.6-2 C 5 UFSAR Table 5.2 5 C 5 UFSAR Table 6.2 44 l-

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SPECIFICATION NO. GGNS-M 189.1 REVISION NO. 8 ! PAGE: 5 OF 18 APPENDlX A SAFETY STROKE TIME , VALVE NO. POSIT!ON STROKE TIME REFER _ENCE NOTES 821F0288 C 5 SR3.6.1.3.6 ; C 5 TRM Table TR3.6.1.3-1 C 5 UFSAR 15.1.3.3.2 ! C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.0-4 C 5 UFSAR Table 15.412 C 5 UFSAR Table 15.61 , C 5 UFSAR Table 15.6 2 C 5 UFSAR Table 5.2 5 + C 5 UFSAR Table 6.2-44 B21F028C C 5 SR3.6.1.3.6 C 5 TRM Table TR3.6.1.3-1 , C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15 2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.04 C 5 UFSAR Table 15.412 C 5 UFSAR Table 15.61 C 5 UFSAR Table 15.6-2 C 5 UFSAR Table 5.2 5 C 5 UFSAR Table 6.2-44 B21F023D C 5 SR3.6.1.3.6 , C 5 TRM Table TR3.6.1.01 C 5 UFSAR 15.1.3.3.2 C 5 UFSAR 15.2.4.3.2 C 5 UFSAR 6.2.1.1.3.3.1.1.f C 5 UFSAR Table 15.0-4 , C 5 UFSAR Table 15.4-12 C 5 UFSAR Table 15.6-1 C 5 UFSAR Table 15.6-2 C 5 UFSAR Table 5.2 5 C 5 UFSAR Table 6.2 44 , m~ , - . .. . , , , - - , , - . , -

l l SPECIFICATION NO. GGNS.M 189.1 REVISION NO,8 ' PAGE: 6 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. - POS!IlOL4 STROKE TIME REFERE_NCE NOTES ; B21F067A C 9 TRM Table TR3.6.3.1 1 B21F0678 C 9 TRM Table TR3.6.3.1 1 821F067C C 9 TRM Table TR3.6.3.1 1 B21F067C C 9 TRM Table TR3.6.3.1 1 B21F113 C 120 TRM Table TR3.6.4.21 D21F114 C 120 TRM Table TR3.6.4.21 l B33F019 C 36 TRM Table TR3.6.5.3-1 833F020 C 36 TRM Table TR3.6.5.31 C11F010 C 30 SR3.1.8.3 C11F011 C 30 SR3.1.8.3 . : C11F180 C 30 SR3.1.8.3 C11F181 C 30 SR3.1.8.3 D23F591 C 60 TRM Table TR3.6.1.3-1 : D23F592 C 60 TRM Table TR3.6.1.31 D23F593 C 60 TRM Table TR3.6.1.3-1 D23F594 C 60 TRM Table TR3.6.1.31 E12F008 C 40 TRM Table TR3.6.1.3-1 C 40 UFSAR Table 5.2 5 C 40 UFSAR Table 6.2-44 E12F009 C 40 TRM Table TR3.6.1.31 C 40 UFSAR Table 5.2 5 C 40 UFSAR Table 6.2 44 -

          - E12F011A                   C              60                           TRM Table TR3.6.1.31 E12F0118                  C              60                           TRM Table TR3.6,1.31 E12F021               -C                144                          TRM Table TR3.6.1.3-1 E12F023                   C-             94                          TRM Table TR3.6.1.3-1 h

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i SPECIFICATION NO. GGNS M 989.9 REVISION NO. 8 PAGE: 7 OF 18 APPENDIX A - SAFETY STROKE TIME VALVE NO. STROKE TIME . REFERENCE NOTES POSITION E12F024A C 144 TRM Table TR3.6.1.3-1 C 144 UFSAR Table 6.2 44 E12F024B C 144 TRM Table TR3.6.1.3-1 C 144 UFSAR Table 6.2 44 E12F028A, C 90 TRM Table TR3.6.1.31 E12F026B C 90 TRM Table TR3.6.1.3-1 E12F037A C 74 TRM Table TRS.6.1.31 E12F0378 C 74 TRM Table TR3.6.1.31 E12F042A O 29 SR TR3.5.1.1 0 30 UFSAR 5.4.7.1.1.2 0 30 UFSAR 7.3.1.1.1.6.7 0 30 UFSAR Table 15.0-4 0 30 UFSAR Table 6.31a 0 30 UFSA R Table 6.3 2 0 30 UFSAR Table 6.3 2a O 30 UFSAR Table 6.3-8 C 30 UFSAR 6.2.1.1.5.8 l E12F042B O 29 SR TR3.5.1.1 0 30 UFSAR 5.4.7.1.1.2 0 30 UFSAR 7.3.1.1.1.6.7 0 30 UFSAR Table 15.0-4 0 30 UFSAR Table 6.31a O 30 UFSAR Table 6.3-2 0 30 UFSAR Table 6.3 2a 0 30 UFSAR Table 6.3-8 C 30 UFSAR 6.2.1.1.5.8

l SPECIFICATION NO. GGNS M 189.1 . REVISION NO. 8 I PAGE: 8 OF 18 APPENDlX A ! I SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REFER _ENCE NOTES E12F042C O 29 SR TR3.5.1.1 0 30 UFSAR 5.4.7.1.1.2 , O 30 UFSAR 7.3.1.1.1.6.7 O 30 UFSAR Table 15.0-4 0 30 UFSAR Table 6.31a O 30 UFSAR Table 6.3 2 l O 30 UFSAR Table 6.3-2a O 30 UFSAR Table 6.3 8 i E12F203 C 120 TRM Table TR3.6.4.21 E12F394 C 60 TRM Table TR3.6.1.3-1 E21F005 0 29 SR TR3.5.1.1 0 30 UFSAR Table 6.313 - 0 30 UFSAR Table 6.3-2 O 30 UFSAR Table 6.3 2a O 30 UFSAR Table 6.3 8 E21F012 C 144 TRM Table TR3.6.1.31 E22r004 0 17 UFSAR Table 15.0-4 0 16 UFSAR Table 6.3-1 ER 96-0078 O 16 UFSAR Table 6.3.2 ER 96-0078 E22F012 0 5.5 MC-Q1E22 92019. RO C 5.5 MC-Q1E22 92019, RO E22F023 C 75 TRM Table TR3.6.1.3-1 E30F001A O 79.2 Calc.1.6.8Q O- 79.2 UFSAR 6.2.7.3.2 E30F001B O 79.2 Calc.1.6.8Q O 79.2 UFSAR 6.2.7.3.2 E30F002A- O 79.2 Calc.1.6.8Q 0 79.2 UFSAR 6.2.7.3.2 E30F002B O 79.2 Calc.1.6.8Q O 79.2 UFSAR 6.2,7.3.2 , 1 , . _ - - - , . . _re.- ._ _ ,._,4-- ~ . - , . _ ,,m.m. , , _ ,__,.-..,,.._ ., m

_ . . _ . _ . . . _ . _ _ _ . . - _ . _ . _ _ _ _ _ . .= _ __ _ _ _ . _ _ _ _ _ . . _ _ . _ _ _ . _ _ _ _ _ _ _ _ SPECIFICATION NO. GGNS-M-189.1 REVISION NO. 8 PA'3E: 9 OF 18 APPENDlX A SAFETY STROKE TIME f VA_LVE NO. POSITION STROKE TIME REFER 1tiCE _ NOTES j E32F001A O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F001E O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F001J' O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F001N O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b , E32F002A O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F002E O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F002) 0 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F602N O 15 UFSAR 6.7.1.3.1.b C 15 UFSAR 6.7.1.3.1.b E32F006 O 30 UFSAR 6.7.1.3.1.b C 30 UFSAR 6.7.1.31.b E32F007 0 30 UFSAR 6.7.1.3.1.b C 30 UFSAR 6.7.1.3.1.b E32F008 0 30 UFSAR 6.7.1.3.1.b C 30 UFSAR 6.7.1.3.1.b E32F009 O 30 UFSAR 6.7.1.3.1.b C 30 UFSAR 6.7.1.3.1.b E51F013 0 15 UFSAR 5.4.6.2.2.2 0 15 UFSAR 7.4.1.1.3.6 C 15 UFSAR 5.4.6.2.2.2 r C 15 UFSAR 7.4.1.1.3.6

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i SPECIFICATION NO. GGNS-M 189.1 REVISION NO. 8 r PAGE: 10 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REFERENCE NOTES E51F019 O 5 UFSAR 5.4.6.2.2.2 0 5 UFSAR 7.4.1.1.3.6 C 5 UFSAR 5.4.6.2.2.2 C 5 UFSAR 7.4.1.1.3.6 E51F031 C 60 TRM Table TR3.6.1.31 E51F045 0 15 UFSAR 5.4.6.2.2.2 O 15 UFSAR 7.4.1.1.3.6 C 15 UFSAR 5.4.6.2.2.2 C 15 UFSAR 7.4.1.1.3.6 E51F063 C 60 TRM Table TR3.6.1.31 C 60 UFSAR Table 5.2 5 C 60 UFSAR Table 6.2-44 E51F064 C 60 TRM Table TR3.6.1.3-1 C 60 UFSAR Table 5.2-5 C 60 UFSAR Table 6.2-44 E51F076 C 60 TRM Table TR3.6.1.3-1 E51F077 C 60 TRM Table TR3.6.1.3-1 E51F078 C 60 TRM Table TR3.6.1.3-1 E51F095 0 5 UFSAR 5.4.6.2.2.2 0 5 UFSAR 7,4.1.1.3.6 C 5 UFSAR 5.4.6.2.2.2 C 5 UFSAR 7.4.1'.1.3.6 E61F003A C 84 TRM Table TR3.6.5.31 . E61F0038 C 84 TRM Table TR3.6.5.3-1 E61F005A C 84 TRM Table TR3.6.5.3-1 E61F005B C 84 TRM Table TR3.6.5.3-1 E61F007 C 9 TRM Table TR3.6.5.3-1

i SPECIFICATION NO. GGNS M 189.1 REVISION NO. 8 PAGE: 11 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REFERENCE NOTES E61F009 C 4 TRM Table TR3.6.1.31 C 4 UFSAR 6.2.4.3.3 , C 4 UFSAR 9.4.7.3 E61F010 C 4 TRM Table TR3.6.1.31

i C 4 UFSAR 6.2.4.3 3 C 4 UFSAR 9.4.7.3 E61F020 C 18 TRM Table TR3.6.5.31 E61F056 C 4_ TRM Table TR3.6.1.3 1 ; C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.7.3 E61F057 C 4 TRM Table TR3.6.1.3-1 i C 4 UFSAR 6.2.4.3.3 . C 4 UFSAR 9.4.7.3 G33F001 C 35 TRM Table TR3.6.1.31 C 35 UFSAR Table 5.2 5 C 35 UFSAR Table 0.2 44 G33F004 C 35 TRM Table TR3.6.1.3-1 C 35 UFSAA Table 5.2 5 C 35- UFSAR Table 6.2-44 G33F 028 C 35 TRM Table TR3.6.1.3-1 C 35 UFSAR Table 6.2-44 G33F034 C 35 TRM Table TR3.6.1.3-1 C 35 UFSAR Table 6.2 44 G33F039 C 35 TRM Table TR3.6.1.31 C 35 UFSAR Table 6.2 44 G33F040 C 35 TRM Table TR3.6.1.3-1 C 35 UFSAR Table 6.2-44 G33F053 - C 35 TRM Table TR3.6.1.3-1 C 35 - UFSAR Table 6.2-44 '

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                                                                                           ., , - - -         ,,,3-v--,~m-,        .- r,, . , . ,                 s        _   . . , ,- , ,

i i SPECIFICATION NO. GGNS-M 189.1 REVISION NO. 8 : PAGE: 12 OF 18 i' APPENDIX A SAFETY STROKE TIME . VALVE NO. POSITION - STROKE TIME REFERENCE NOTES l G33F054 C 35 TRM Table TR3 6.1.3-1 C 35 UFSAR Table 6.2-44 l G33F234 C 120 TRM Table TR3.6.4.2-1 i G33F235 C 120 TRM Table TR3.6.4.21 l G33F250 ' C 35 TRM Tsbie TR3.6.5.3-1 C 35 UFSAR Table 5.2 5 G33F251 C 35 TRM Table TR3.6.5.3-1 C 35 UFSAR Table 5.2 5 G33F252 C 35 TRM Table TR3.6.1.31 C- 35 UFSAR Table 6.2-44 G33F253- C 35 TRM Table TR3.6.5.3-1 , G36F101 C 60 TRM Table TR3.6.1.3-1 G36F106 C 60 TRM Table TR3.6.1.3-1 G36F108 C 120 TRM Table TR3.6.4.21 G36F109 C 120 TRM Table TR3.6.4.2-1 G41F028 C 60 TRM Table TR3.6.1.3-1 G41F029' C 60 TRM Table TR3.6.1.3-1 G41F044 C 60 TRM Table TR3.6.1.3-1

               -G46F253                     C               120                                  TRM Table TR3.6.4.21 M41F007                     C               120                                  TRM Table TR3.6.4.21 M41F008                     C               120                                  TRM Table TR3.6.4.21                                           ,.

M41F011. C 4 TRM Table TR3.6.1.3-1 C 4 UFSAR 15.7.6.2.2.2 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.7.3 C 4 UFSAR Table 6.2-44 t

SPECIFICATION NO. GGNS M>189.1 REVISION NO. 8 PAGE: 13 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REFERENCE NOTES M41F012 C 4 TRM Table TR3.6.1.3-1 C 4 UFSAR 15.7.6.2.2.2 C 4 UFSAR 6.2.4.3.3 C 4 UFSA R 9.4.7.3 C 4 UFSAR Table 6.2-44 1 M41F013 C 4 TRM Table TR3.6.5.3-1 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.8.2.2 M41F015 C 4 TRM Table TR3.6.5.31 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.8.2.2 M41F016 C 4 TRM Table TR3.6.5.31 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.8.2.2 M41F017 C 4 TRM Table TR3.6.5.3-1 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.8.2.2 M41F034 C 4 TRM Table TR3.6.1.3-1 C 4 UFSAR 15.7.6.2.2.2 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.7.3 C 4 UFSAR Table 6.2-44 M41F035 C 4 TRM Table TR3.6.1.31 C 4 UFSAR 15.7.6.2.2.2 C 4 UFSAR 6.2.4.3.3 C 4 UFSAR 9.4.7.3 C 4 UFSAR Table 6.2-44 M41F036 C 120 TRM Table TR3.6.4.2-1 M41F037 C 120 TRM Table TR3.6.4.21 M71F594 C 60 TRM Table TR3.6.1.3-1

SPECIFICATION NO. GGNS M-189.1 REVISION NO. 8 PAGE: 14 OF 18 APPENDlX A SAFETY STROKE TIME VALVE NO. POSITLON STROKE TIME REFERENCE NOTES M71F595 C 60 TRM Table TR3.6.1.3-1 P11F047- C 120 TRM Table TR3.6.4.21 P11F061 C 120 TRM Table TR3.6.4.21 s P11F062 C 120 TRM Table TR3.6.4.2-1 4 P11F063 C 120 TRM Table TR3.6.4.2-1 P11F064 C 120 TRM Table TR3.6.4.2-1 P11F065 C 120 TRM Table TR3.6.4.2-1 P11F066 C 120 TRM Table TR3.6.4.21 P11F067 C 120 TRM Table TR3.6.4.21 P11F075 C 60 TRM Table TR3.6.1.3-1 , P11F130 C 60 TRM Table TR3.6.1.3-1 P11F131 C 60 TRM Table TR3.6.1.31 P21F017 C 60 TRM Table TR3.6.1.3-1 P21F018 C SO TRM Table TR3.6.1.3-1 P21F024 C 120 TRM Table TR3.6.4.21 , P44F116 C ;20 TRM Table TR3.6.4.21 P44F117 C 120 TRM Table TR3.6.4.2-1 P44F118 C '120 TRM Table TR3.6.4.21 P44F119 C 120 TRM Table TR3.6.4.2-1 P44F120 C 120 TRM Table TR3.6.4.2-1 P44F121 C 120 TRM Table TR3.6.4.21 P44F122 C 120 TRM Table TR3.6.4.2-1 P44F123 C 120 TRM Table TR3.6.4.2-1 P45F003 C 6 TRM Table TR3.6.5.3-1

SPECIFICATION NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 15 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REF_ER_ENCE NOTES P45F004 C 6 TRM Table TR3.6.5.3-1 P45F009 C 6 TRM Tabte TR3.6.5.3-1 P45F010 C 6 TRM Table TR3.6.5.31 P45F061 , C 7 TRM Table TR3.6.1.31 P45F062 C 7 TRM Table TR3.6.1.3-1 P45F067 C 7- TRM Table TR3.6.1.31 P45F068 C 7 TRM Table TR3.6.1.3-1 P45F090 C 9 TRM Table TR3.6.5.3-1 P45F007 C 9 TRM Table TR3.6.5.31 P45F098 C 8 TRM Table TR3.6.1.3-1 . P45F099 C 8 TRM Table TR3.6.1.31 P45F158 C 120 TRM Table TR3.6.4.21 P45F159 C 120 TRM Table TR3.6.4.2-1 P45F160 C 120 TRM Table TR3.6.4.2 1 P45F161 C 120 TRM Table TR3.6,4.2-1 P45F163 C 120 TRM Table TR3.6.4.2-1 P45F273 C 32. TRM Table TR3.6.1.3-1 P45F274 C 32 TRM Table TR3.6.1.3-1 PS2F105 C 60 TRM Table TR3.6.1.3-1 I PS2F160A C 120 TRM Tabla TR3.6.4.21 PS2F160B C 120 TRM Table TR3.6.4.21 PS2F195 C 16 TRM Table TR3.6.5.3-1 PS2F221A C 120 TRM Table TR3.6.4.21 PS2F221B C 120 TRM Table TR3.6 4.21 9

f SPECIFICATION NO. GGNS M 189.1 REVISION NO. 8 PAGE: 16 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSillON STROKE TIME REFERENQE NOTES PS3F001 C 60 TRM Table TR3.6.1.31 PS3F003 C 60 TRM Table TR3.6.1.31 P53F007 C 7 TRM Table TR3.6.5.3-1 P53F026A, C 120 TRM Table TR3.6.4.2-1 P53F026B C 120 TRM Table TR3.6.4.21 P60F003 C 120 TRM Table TR3.6.4.2-1 P60F004 C 120 TRM Table TR3.6.4.2-1 P60F007 C 120 TRM Table TR3.6.4.21 P60F008 C 120 TRM Table TR3.6.4.21 P60F009 C 60 TRM Table TR3.6.1.31 P60F010 C 60 TRM Table TR3.6.1.3-1 P64F282A C 120 TRM Table TR3.6.4.2-1 P64F2828 C 120 TRM Table TR3.6.4.2-1 P64F283A C 120 TRM Tabte TR3.6.4.21 P64F283Bt C 120 TRM Table TR3.6.4.2-1 P64F332A C 120 TRM Table 1R3.6.4.2-1 P64F332B C 120 TRM Table TR3.6.4.21 P66F029A C 120 TRM Table TR3.6.4.21 P71F148 C 60 TRM Table TR3.6.1.3-1 P71F149 C 60 TRM Table TR3.6.1.3-1 P71F150 C 60 TRM Table TR5.6.1.3-1 P71F300 C 120 TRM Table TR3.6.4.21 P71F301 C 120 TRM Table TR3.6.4.2-1 P71F302 C 120 TRM Table TR3.6.4.21

SPECIFICATION NO. GGNS M-189.1 REVISION NO. 8 PAGE: 17 OF 18 APPENDIX A SAFETY STROKE TIME VALVE NO. POSITION STROKE TIME REFERENCE NOTES P71F303 C 120 TRM Table TR3.6.4.2-1 P71F304 C 120 TRM Table TP3.6.4.2-1 P71F305 C 120 TRM Table TR3.6.4.2-1 P71F306 C 120 TRM Table TR3.6.4.21 P71F307 C 120 TRM Table TR3.6.4.2-1 P72F121 C 60 TRM Table TR3.6.1.31 P72F122 ) C 60 TRM Table TR3.6.1.31 P72F123 C 60 TRM Table TR3.6.1.3-1 P7i'F124 C 31 TRM Table TR3.6.5.31 , t P72F125 C 32 TRM Table TR3.6.5.3-1 P72F126 C 32 TRM Table TR3.6.5.3-1 T41F006 C 120 TRM Table TR3.6.4.2-1 r T41F007 C 120 TRM Table TR3.6.4.2-1 T42F003 C 4 TRM Table TR3.6.4.2-1 b C 4 UFSAR 15.7.4.5.2 T42F004 C 4 TRM Table TR3.6.4.2-1 C 4 UFSAR 15.7.4.5.2 1 T42F011 C 120 TRM Table TR3.6.4.2-1 T42F012 C 120 TRM Table TR3.6.4.2-1 [ T42F019 C 4 TRM Table TR3.6.4.2-1 C 4 UFSAR 15.7.4.5.2 T42F020 C 4 TRM Table TR3.6.4.2-1 C 4 UFSAR 15.7.4.5.2 Z51F001 C 4 SR 2.7.3.3 Bases C 4 UFSAR Table 18.1-2 1

I SPECIFICATION NO. GGNS M-189,1 - REVISION NO,8 PAGE: 18 OF 18 APPENDIX A JAFETY STRCKE TIME VALVE NO. POSITION STROKE TIME REFERENCE NOTES ) I 251F002 C 4 SR 3.7.3.3 Bases

                   .C             4               UFSAR Table 18.12 Z51F003         C             4               SR 3.7.3.3 Bases                             !

C 4 - UFSAR Table 18.12 l Z51F004 ' C 4 SR 3.7.3.3 Bases C 4 UFSAR Table 18.12 Z51F010 C 4 SR 3.7.3.3 Bases C 4 UFSAR Table 18.1-2

  - 251F011         C             4               SR 3.7.3.3 Bases C            .4               UFSAR Table 18.1-2 r
                ,     ,  , . . .    ._      ~ - .                  . , - .

Enfergy' Operations, Inc. . PROGRAM PLAN NO. GGNS-M-189.1-Grand Gulf Nuclear Station REVISION NO. 8 Pump And Valve Inservice Testing Program PAGE: COVER SHEET n APPENDIX B , L PROGRAM PLAN - CHANGE REQUEST / NOTICE m100t h D-r4

l PROGRAM PLAN NC,. GGNS-M-1C3,1 REVISION NO. 8 PAGE: 1 of 4 APPENDIX B 1.0 PURPOSE To provide an avenue for the initiation of change requests to Program Plan No. GGNS-M-189.1, Pump and Valve Inservice Testing Program (M-189.1). 2.0 SCOPE This appendix provides instruction to GGNS organizations on inception, documentation, sLbmittal, review, Control, and incorporation of an M-189.1 Program Change Request / Notice (PCR/PCN). Any change within the Inservice Inspection (ISI) boundary affecting M-189.1 shall be evaluated for impact to this document. 3.0 RESPONSIBILITY 3.1 GGNS Organizations 3.1.1 Perform review Jf plant documents that could affect M-189.1 and initi. ate an M-189.1 PCR/PCN if applicable. 3.1.2 Submit M 189.1 PCR/PCNs to NPE for review and approval. 3.2 Nuclear Plant Engineering (NPE) 3.2.1 Performs review of documents that could affect M-189.1 (e.g., new ASME Code requirements, Technical Specification, NRC Documents, UFSAR, etc.) and initiates an M-189.1 PCR/PCN, if app.licable. 3.2.2 Approves or disapproves submitted M-189.1 PCR/PCNs. 3.2.3 Incorporates approved M-189.1 PCR/PCNs into M-189.1. 3.2.4 Maintains the M 189.1 PCR/PCN Log and Fila. 4.0 R.EFERENCES 4.1 Specification No. GGNS-M-489.1, Technical Spedfication for the Ten-Year Inservice Inspection PLin. 4.2 Nuclear Plant Engineering Administration Procedure (NPEAP) 343, Program Plans. m

 ,  . m t 89-irV4 app-b48

PROGRAM f LAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 2 of 4 APPENDIX B r 5.0 ATTACHMENT' 5.1 - M-189.1 Program Change Request / Notice (Form) 6.0 QEFINITIONS 6.1 M-189.1 Program Change Request / Notice (M-189.1 PCR/PCN) - A form originated by any GGNS organization to request and make changes to M-189.1. 6.2 M 189.1 PCR/PCN Leg - A record of M-189.1 PCR/PCN's processed by NPE. 7.0 DETAILS 7.1 General 7.1.1 M 189.1 PCR/PCNs must be processed in accordance with this appendix. , 7.1.2 An M 189.1 PCR/PCN may be initiated by any GGNS organization to request an addition or modification to testing information for components within the Inservice Inspection (ISI) boundary as depicted on ISI Boundary Diagrams (See Reference 4.1 for ISI Boundary Diagram Index). 7.1.3 Once approved, an M-189.1 PCR/PCN must not be revised. However, it may be canceled, superseded, or voided and ane'her issued. 7.1.4 Examples of changes to be documented via an M-189.1 PCR/PCN:

a. The ad6ition, dew a,i, or modification of valve or pump information provided by M-189.1.

b. Incorporation of changes to Engineering Markups as a result of Design Change Packages (DCPs) or Change Notices (CNs).

c. Editorial corrections.

d

d. Changes to reference drawing information provided by M-189.1.

e. Modification, deletion, or addition of testing requirements as a result of dccument reviews.

m1801ru8epp tw8

PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 3 of 4 APPENDIX B 7.1.5 Upon completion of activities within the ISI Boundary and the subject component retumed to operation, originating organizations should submit any necessary M-189.1 PCR/PCNs within thirty (30) days. 7.2 M 189.1 PCR/PCN Initiation 7.2.1 PART I of M-189.1 PCR/PCN Form: / a. Indicate current revision of M-189.1.

b. Thorcughly describe the change and provide marked-up pages when applicable.

c. List all reference documents researched and provide reason for the change request.

, d. Initiator signs and dates the form and enters initiating organization. 7.3 M-189.1 PCR/PCN Submittal (GGNS Organizations Other than NPE) 7.3.1 The responsible originating organization supervisor or superintendent - must review the M-189.1 PCR/PCN prior to submittal to NPE. 7.3.2 Once initiator has obtained supervisor review signature, NPE's inservice Testing (IST) Responsible Engine,r (RE) must be contacted for an M-189.1 "CR/PCN number. The number is entered on the M-189.1

PCR/PCN form and the form is submitted to NPE.

7.4 M-189.1 PCR/PCN Processing (NPE Organization) 7.4.1 When a NPE section submits an M-189.1 PCR/PCN, it must first be reviewed / signed by the initiators supervisor or. designee, and then submitted to NPE's inservice Testing (IST) Responsible Engineer (RE) for a number and processing. Y.4.2 NPE must process cil M-189.1 PCR/PCNs submitted. 7.4.3 An M-189.1 PCR/PCN Log must be maintained by NPE for all M-189.1 PCR/PCNs received. m1801rO8epg>t>r8

l 1 PROGRAM PLAN NO. GGNS M-189.1 REVISION NO. 8 PAGE: 4 of 4 APPENDIX B 7.4.4 The NPE IST RE provides the disposition and justification on the M-189.1 PCR/PCN and obtains appropriate reviews for those dispositioned as approved. Disapproved requests should be retumed to initiator with an explanation. A copy must be maintained in the M-189.1 PCR/PCN file. A copy must be submitted to Document Control for microfilming (Record Type J2.08). 7.4.5 After review, requests approved by NPE must be forwarded to NPE ' Responsible Supervisor, Authorized Nuclear Inservice inspector (ANil), and the Responsible Manager for approval prior to incorporation into M-189.1. 7.4.6 Requests obtaining Responsible Manager approval must be incorporated into the next revision of M-189.1 in accordance vith Reference 4.2. Revisions to M-189.1 must be scheduled for completion ninety (90) days, or sooner, prior to the next scheduled refueling outege,if time allows. 7.5 issuance of M-189.1 PCR/PCNs 7.5.1 Approved M-189.1 PCR/PCNs must be submitted to Document Control for controlled distribution. 7.6 Outstanding Specification Change Requests / Notices (SCR/SCN) against M-189.1, Revision 7 7.6.1 Previously issued SCR/SCNs that are pending on the issue date of M-189.1. Revision 8, shall be processed in accordance with 7.4.4 through 7.5.1 of this Appendix. m159 IrV8ap1>b r4

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 APPENDIX B - PCR/PCN FORM M-189.1 PROGRAM PLAN CHANGE REQUEST / NOTICE (M189.1 PCR/PCN) PART I -Initiation Section PCR/PCN NUMBER: PROGRAM PLAN REV. NO,: PCR/PCN PAGE OF PROPOSED CHANGE TO PROGRAM PLAN: (List Section, Page No., etc; Attach markup) REASON FOR CHANGE INITIATOR: DATE: GGNS ORGANIZATION: ' INITIATOR'S SUPERVISOR: DATC _ PART 11 - Disposition Section DISPOS 1 HON JUSTIFICATION: DISPOSITION:

                                                           /                                    /

DISPOSITIONER DATE CHECKER DATE (__ i RESPONISBLE SUPERVISOR DATE REVIEWER /ORG DATE

                                                           /                                    /

REVIEWER /ORG DATE ANil DATE APPROVED: / RESPONSIBLE MANAGER DATE m1841rfhepptw8

Entergy Operations, Inc. PROGR M PLAN NO GGNS-M-189,1 Grand Gulf Nuclear Station REVISION NO. 8 Pump And Volve Inservice Testing Program. PAGE: COVER SHEET APPENDIX C CALCULATION OF - IST MAXIMUM STROKE TIME

  . 4, l

                                                               -- PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE:1 of 6 APPENDlX C 1.0         PURPOSE To provide the methodology for calculating inservice Testing Maximum Stroke Times and to provide instructions for controlling their use.

2.0 SCOPE This appendix provides instruction to Grand Gulf Nuclear Station (GGNS) organizations for calculating IST Maximum Stroke Times used in testing procedures. 3.0 RESPONSIBILITY 3.1 Performance & System Engineering (P&SE) . 3.1.1 Performs determinations that existing IST Maximum Stroke Times are no lunger applicable. 3.1.2 Develops new IST Maximum Stroke Times in accordance with this appendix. 3.2 Nuclear Plant Engineering (NPE) 3 2.1 Develops bases for IST Maxirrc;m Stroke Times. 3.2.2 Provides bsses for IST Maximum Stroke Times in Appendix A.

4.0 REFERENCES

4.1 USNRC Generic Letter No. 89-04, Guidance on Developing Acceptsble Inservice Testing Programs, dated April 3,1989. 4.2 - Code for Operation and Maintenance of Nuclear Power Plants, ASME OM Code-1990 (hereafter referred to as the Code). m100-tr0 % te'

F r-PROGRAfM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 2 of 6 APPENDIX C 4.3 AECM-85/0149 from L. F. Dale (SERI) to Harold R. Denton (USNRC), "lST Pump.and. Valve Program - Maximum Stroke Times and Additional Relief Requests" dated June 28,1985. 4.4 ASTM Recommended Practice E 29 90, Standard Practice for Using Significant Digits in Test Data to Determine Conformance with Specifications. 5.0 ATTACHMENTS None i l 6.0 DEFINITIONS , 4 None. 7.0 DETAILS 7.1 Generai 7.1.1 The purpose of establishing IST Maximum Stroke Times is to provide values at which corrective action is to be takJn to er$sure that valves will perform their intended safety functions. 7.1.2 Any calculation or recalculation of IST M;ximum Stroke Times shall include the following: j

a. Any references, known values, vendor information, or assumptions.

b. The results of comparisons to limits listed in Appendix A.

c. The stroke times used in the calculation (obtained from the test data sheets), the calculation method used, and the calculated IST Ma.tmum Stroke Time.

d. Justification explaining why the calculation is required.

m1Eirtapg>c-r8 -

PROGRAM PLAN NO. GGNS NI-189.1 REVISION N0. 8 - PAGE: 3 of 6-APPENDIX C 1

                       '7.1.3     IST Maximum Stroke Times should, per the gGJance of Reference 4.1, be the lesser of the following:

a. A calculated value based on the reference or average stroke time of a valve when it is known to % in good condition and operating property, or,

b. A Technical Specifiestion, safety analysis or other analytical limit (these limi'.s are listed in Appendix A).

7.1.4 The Code rules and requirements (Reference 4.2) goveming GGNS IST require that a limiting value of full-stroke time (i.e., IST Maximum Stroke Time) be established for testing purposes. However, the Code' does not provide a calculation methodology to be used for establishing IST Maximum Stroke Times. This appendix, describes two methodologies utilized in calculating IST Maximum Stroke Times. 7.2 Valves With Stroke Time Basis 7.2.1 Appendix A identifies those valves that have a basis .for IST Maximum Stroke Times. 7.2.2 The IST Maximum Stroke Tims calculated in accordance with this Appendix shall be compared to the limit in Appendix A, and the lesser of the two shall be used. 7.3 Valves Without Stroke Time Basis 7.3.1 For valves with no bases listed in-Appendix A, the IST Maximum Stroke Time will be the value calculated in accordance with this 4

                                 ' Appendix.

mihirtapec-t$ b

   .-        -.        -         .        _ - . =              .     - - .         . . - .         .   .. - - -

P

                                                                  ' PROGRAM PLAN NO. GGNS-M 189.1 REVISION NO. 8 PAGE: 4 of 6                                j APPENDIX C 7.4    Calculation of IST Maximum Stroke Time e
                         '7.4.1     Reference 4.3 describes the two methodologies (Method 1 and
                ,                   Method 2) developed by GGNS for use 'in calculating maximum allowable stroke time values. Method 1 is applied where a valid statistical data base is available for analysis. Method 2 is used where there is not sufficient data for statistical analysis.

7.4.2 CHOOSING CALCULATION METHOD - When performing a recalculacion, a dctabase is generally considered large enough for application of Method 1 when 30 or more data points are available for analysis. Method 2 !s generally used when less than 30 data points are available. If a valve is classified as a rapid acting valve , only the average stroke time needs to be calculated. 7.4.3 METHOD 1 (Reference 4.3)- For groups of valves where sufficient data exists to ensure a valid statistical base, the maximum (stroke time) is computed by the areater of adding 3 standai.: deviations to the mean te define the normal range and then adding 10% to that normal range, or a 10% increase beyond the Code " Alert" value (1.35 times mean for stroke times exceeding 10 seconds and 1.6 times ! mean for stroke times less than or equal to 10 seconds). These computations are referred to as Method iA and Method 18 and are restated below. For- recalculations, valves are analyzed on an individual basis rather than by groups as implied by Reference 4.3. METHOD 1: Maximum Stroke Time = the greater of Method 1 A or Method 1B , METnCD 1 A: Maximum Stroke Time = (mean + 3 standard

,                                                            deviations) times 1.1 METHOD 18:         Maximum Stroke Time = mean times 1.35,
;                                                            when the mean is greater than 10 seconds Qfl Maximum Stroke Time = mean times 1.6, l

when the mean is less than or equal to 10 seconds m189-trSapp.c-r8

n v PROGRAM PLAN NO. GGNS-M-189.1-REVISION NO.- 8 < PAGE: 5 of 6 - APPENDIX C NOTE: -When calculating standard deviations, a population ~ standard deviation or sample standard deviation is used based on the number of data points. A population standard deviation calculation is used when 50 or more data points are used. r Sample standard deviation calculations are used when less than 50 data points are used. 7.4.4 METHOD 2 (Reference 4.3)- The " normal" range of Method 1 cannot always be determined for a valve for which a large database is not available. _ Additionally, a " normal" range cannot - always be determined for a valve that does not follow a trend. In such cases, a slightly larger margin is added to the aversge stroke time by use of the following formula. METHOD 2: Maximum Stroke Tiri.e = (mean times 2.058) - (0.027 times the mean squared), when the mean is less than or equal to 26 seconde QB Maximum Stroke Tima = mean times 1.35, when the mean is greater than 26 seconds 7.4.5 RAPID _ ACTING VALVES - Valves cre classified as rapid acting-valves if they have stroke time averages less thar* 1.6 seconds and no stroke times greater than or equal to 2.0 seconds. When valves are classified as rapid acting valves a 2.0 second IST Maximum Stroke Time shall be specified along with the following Note: NOTE: Rapid-acting valve. Refer to Generic Relief Request 2. The 2 second limit specified in Generic Letter 89-04 (Reference 4.1) for rapid acting valves will allow a measured suoke time' of up to 2.5 seconds (per ISTB 4.2.4(b)). Measured values for rapid-acting valves are to be rounded to the nearest second in acccrdance with th? rounding-off method of ASTM Recommended Practice E 29-90. A , i k mies.1rsapp.c es '- _j

PROGRAM PLAN NO. GGNS-M-189.1 REVISION NO. 8 PAGE: 6 of 6 APPENDIX C 7.4.6 TECHNICAL SPECIFICATION OR SAFETY ANALYSIS < COMPARISON

a. As stated in the USNRC position regarding limiting stroke times

          ,                                                              for power operated- valves (Reference 4.1), those Technical Specificaticn or safety analysis limits that are less than the calculated IST Maximum Stroke Times should be used as the IST Maximum Stroke Times. The calculated IST Maximum Stroke Times are compared to stroke times specified in Appendix A.

1 1 m1841tSapsH:-r8

l Attachment I to: Program PI:n No. GGNS-M 189.1 Revision No. 8 Page 1 of 2 GRAND GUI,F NUCl. EAR STATION UNIT 1 SAfEIY EVALUATION APPLICABILITY REVIEW FORM 1 A) Document Evaluated: Program Plan GGNS-M-1891. Revision 8 B) Description of the Proposed Change: Revision 8 represents an update frorn the requirements of the AShtE Section XI,1980 Code to the ASME Sectiori XI,1989 Code. The ASME Sechon XI-1989 Code references ASME/ ANSI Standard OM-1987 with 1988a Addenda, Parts 6 and 10 for Inservice Testing of Pumps and Valves, respectively. (OMa-1988 Part 10 references OM-1987 Part 1 for inservice testing of relief salves) Editorial / format changes convert former .IST Specification GGNS-M-189.1, Revision 7, into IST Program Plan GGNS-M-189.1, Revision 8 and also incorporates previously-approved specification changes. PRE-SCREENING Check the applicable boxes below. If any of the following boxes are checked, neither a safety evaluation applicability review nor a safety evaluation is necessay and steps C, D and E may be skipped. The preparer and reviewer must sign at the bottom of the form. _ The change is editorial as defined in Section 6.2.1 of PAP 01-S-06-24. _ 10CFR50.59 does not apply per Section 6.2.2 of PAP 01-S-06-24. Reference . _ An approved safety evaluation covering all aspects of this subject already exists. Reference SE #

          /              The change, in its entirety, has been approved by the NRC.

Referencc GNRI-96/00184 , _ The change is an FSAR change that meets the exclusion criteria outlined in the 10CFR50.59 Safety Evaluation Guidelines and the change does not represent a change to the Technical

 ,                        Specifications or the Technical Requirements Manual.

Safety Evaluation Applicability Review If any of the following questions in steps C and D are answered "yes", then a full 50.59 Safety Evaluation must be completed. C) Does the proposed change or activity represent a change to the Technical Specifications? , YES _ Explain: NO __ _ Form 316.2, Revision 8 Page t j

h$ Attachtnent I to: Program Plan No. GGNS-M 189.1 Revision No. 8 Page - 2 of 2 D) = Does the proposed change or activity represent: (1) A change to the facility which alters, or has the potential to aher, the information, operation, function or ability to perform the function of a system, structure or component described in the SAR7 YES Explain: NO - (2) A change to a procedure which alters, or has the potential to alter, a procedure described, outlined or summarized in the SAR? YES Explain: NO (3) .A test or experiment not described in the S AR or which requires that a system be operated in an abnormal manner that is not described or previously analyzed in the SAR? YES Explain: f No 4 E)~ Is a TRM change required? ( )YES - [ ] NO PREPARER: )/ r 4,a o/ t 5 /t?

                        /         /"               Name                           Job Title      Date REVIEWER:               11.                                                50PFJN isofL         11-t5 'i7 6~                       Name                           Job Title      Date 4-If the preparer penbrmed an applicability review (screening' the reviewer should check below to indicate by which means the independent review reached the same conclusions.

[ Reviewed the applicability review documentatioa. Completed an independent applicability review. Performed a verbal review with the preparer. i Form 316.2, Revision 8 Page 2

)}}

ML20199L571

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