Text

Letter Transmitting Ginna Station Emergency Operating Procedures
	ML051090405
Person / Time
Site:	Ginna
Issue date:	04/10/2005
From:	Marlow T; Constellation Energy Group
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	Download: ML051090405 (161)
	v • d • e

1503 Lake Road Ontario, New York 14519-9364 585.771.3000 Constellation Energy R.E. Ginna Nuclear Power Plant, LLC April 10, 2005 U.S. Nuclear Regulatory Commission Document Control Desk Washington, D.C. 20555

Subject:

Emergency Operating Procedures R.E. Ginna Nuclear Power Plant Docket No. 50-244 As requested, enclosed are Ginna Station Emergency Operating Procedures.

Very truly yours, Thomas A. Marlow TAM/jdw xc: U.S. Nuclear Regulatory Commission Region I 475 Allendale Road King of Prussia, PA 19406-1415 Ginna USNRC Senior Resident Inspector Enclosure(s):

AP Index FIG-2.0, Rev 5 AP-TURB.4, Rev 18 ATT Index AP-CVCS.3, Rev 5 AP-TURB.5, Rev 8 FIG Index AP-RCC.2, Rev 12 ATT-14.1, Rev 8 AP-SG. I, Rev 4 ATT-16.2, Rev 4 ATT- 17.0, Rev 20 AP-TURB.1, Rev 14 AP-TURB.2, Rev 21 DE)a

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/ NPSP0200 Ginna Nuclear Power Plant Sun 4/10/2005 9:42:59 am

, E66429 PROCEDURE INDE) Page 1 of 2 INPUT PARAMETERS: TYPE: PRAP STATUS VALUE(S): EF, QU 5 YEARS ONLY:

PRAP A~ IORMAL PROCEDURE PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVIEW ST AP-CCW.1 LEAKAGE INTO THE COMPONENT COOLING LOOP 017 063012004 0612612002 06/26/2007 AP-CCW.2 LOSS OF CCW DURING POWER OPERATION 019 06/30/2004 08/25/2002 06/26/2007 EF AP-CCW.3 LOSS OF CCW- PLANT SHUTDOWN 016 06/30/2004 06/26/2002 06/2612007 EF AP-CR.1 CONTROL ROOM INACCESSIBnJTY 020 06/30)2004 06n26/2002 06/2612007 EF AP-CVCS.1 CVCS LEAK 014 06130)2004 06103/2002 06/03/2007 EF AP-CVCS.3 LOSS OF ALL CHARGING FLOW 005 04110)2005 02127/2004 02/27/2009 EF AP-CW.1 LOSS OF A CIRC WATER PUMP 012 09117/2004 04116/2003 04/16/2008 EF AP-ELEC.1 LOSS OF 12A AND/OR 12B BUSSES 028 01/21/2005 06)26/2002 06/26/2007 EF AP-ELEC2 SAFEGUARD BUSSES LOW VOLTAGE OR SYSTEM LOW FREQUENCY O11 06/10)2004 06)26/2002 06/26/2007 EF AP-ELEC.3 LOSS OF 12A AND/OR 12B TRANSFORMER (BELOW35O F) 013 01/21/2005 06/26/2002 06/6/2007 EF AP-ELEC.13115 LOSS OF BUS 13115 001 0630/2004 09/24/2003 09/24/2008 EF AP-ELEC.14/16 LOSS OF SAFEGUARDS BUS 14116 009 01/21/2005 08/26/2002 06/26/2007 EF AP-ELEC.17/18 LOSS OF SAFEGUARDS BUS 17118 008 01/21/2005 06/26/2002 0612812007 E:

AP-FW.1 ABNORMAL MAIN FEEDWATER FLOW 016 06/30/2004 06126/2002 06/26/2007 E:

AP-IA.1 LOSS OF INSTRUMENTAIR 018 06/26/2002 04/16/2003 04/16/2008 E:

AP-PRZR.1 ABNORMAL PRESSURIZER PRESSURE 015 06/30/2004 06/26/2002 06/26/2007 E:

AP-RCC.1 CONTINUOUS CONTROL ROD IMTHDRAWALAJNSERTION 009 06130/2004 04/16/2003 0411612008 E:

AP-RCC2 RCCtRP MALFUNCTION 012 04)10/2005 2V12015112 01/22/2007 E:

AP-RCC.3 DROPPED ROD RECOVERY 006 02125/2003 02/25/2003 02/25/2008 E:

AP-RCP.1 RCP SEAL MALFUNCTION 017 0613012004 04/24/2003 04/24/2008 E:

AP-RCS.1 REACTOR COOLANT LEAK 017 06/30/2004 04116/2003 04/16/2008 6:

AP-RCS.2 LOSS OF REACTOR COOLANT FLOW 012 06/30/2004 04/16/2003 04/16/2008 EF E:

AP-RCS.3 HIGH REACTOR COOLANT ACTMvnY O11 06/30/2004 04/01/2002 01/22/2007 EF E:

AP-RCS.4 SHUTDOWN LOCA 017 03118/2005 04130/2003 04/30/2008 EF E:

AP-RHR.1 LOSS OF RHR 019 04/30/2003 04/30/2003 04/30/2008 E:

AP-RHR2 LOSS OF RHR WHLE OPERATING AT RCS REDUCED INVENTORY CONDmONS 015 04/05/2005 04)3012003 04/30/2008 EF E:

AP-SG.1 STEAM GENERATOR TUBE LEAK 004 04/10/2005 06/26/2002 06/26/2007 EF AP-SW.1 SERVICE WATER LEAK 021 09/17/2004 04/21/2003 04/21/2008 AP-SW.2 LOSS OF SERVICE WATER 007 01121/2005 11/20/50/3 10/31/2006 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUPRED 014 04110/2005 06/26/2002 06/26/2007

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. NPSP0200 Ginna Nuclear Power Plant Sun 4/10/2005 9:43:00 am E66429 PROCEDURE INDE) Page 2 of 2 11 INPUT PARAMETERS: TYPE' PRAP STATUS VALUE(S): EF. QU 5 YEARS ONLY:

PRAP ABNORALMPROCEDURE PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVIEW ST AP-TURB.2 TURBINE LOAD REJECTION 021 0411012005 06126/2002 06/28/2007 E6 AP-TURB.3 TURBINEVIBRATION 012 0613012004 06126/2002 06/2612007 F AP-TURB.4 LOSS OF CONDENSER VACUUM 018 0411012005 04/3012003 04/30/2008 E:

AP-TURB.5 RAPID LOAD REDUCTION 008 04110/2005 08126/2002 06126/2007 F PRAP TOTAL 34 GRAND TOTAl 34

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NPSP0200 Ginna Nuclear Power Plant Sun 4/1012005 9:40:59 am E66429 PROCEDURE INDE) Page 1 of 2 INPUT PARAMETERS: TYPE. PRATT STATUS VALUE(S): EF, QU 5 YEARS ONLY:

PRATT EOP ATTACHMENTS PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE lTME REV DATE REVIEW REVIEW ST ATT-1.0 ATTACHMENT AT POWER CCWALIGNMENT 003 0211212003 02V12/2003 02V12/2008 ATT-1.1 ATTACHMENT NORMAL CCW FLOW 000 05118/2000 03/2512005 03/25/2010 EF ATT-2.1 ATTACHMENT MIN SW 005 0210112001 02103/2003 02/03/2008 EF ATT-2.2 ATTACHMENT SW ISOLATION 008 03/0612002 0312712003 0312712008 EF ATT-2.3 ATTACHMENT SW LOADS IN CNMT 004 03106/2002 0410612004 04/06/2009 EF ATT-2.4 ATTACHMENT NO SW PUMPS 002 05/30/2003 10/3112001 1013112006 EF ATT-2.5 ATTACHMENT SPLIT SW HEADERS 000 0612612002 06/26/2002 06/2612007 EF ATT-3.0 ATTACHMENT CUCV 008 12101/2004 02/17/2004 02/1712009 EF ATT-3.1 ATTACHMENT CNMT CLOSURE 005 02117/2004 02117/2004 02/1712009 EF ATT-4.0 ATTACHMENT CNMT RECIRC FANS 003 07126/1994 03127/2003 03/27/2008 EF ATT-5.0 ATTACHMENT COND TO SIG 006 10/10/2003 04106/2004 04/0612009 EF ATT-5.1 ATTACHMENT SAFW 008 0513012002 04/2004 04/0612009 EF ATT-5.2 ATTACHMENT FIRE WATER COOLING TO TDAFW PUMP 004 10/07/2004 8/12015112 0112812009 EF ATT-6.0 ATTACHMENT COND VACUUM 003 12118/1996 02/03/2003 02103/2008 EF ATT-7.0 ATTACHMENT CR EVAC 008 03/0612002 02/0312003 02/03/2008 EF ATT-8.0 ATTACHMENT DC LOADS 007 02104/2004 02/04/2004 02/04/2009 EF ATT-8.1 ATTACHMENT DIG STOP 005 03/06/2002 02/03/2003 021032008 EF ATT-8.2 ATTACHMENT GEN DEGAS 008 0612012002 05128/2004 05/28/2009 EF ATT-8.3 ATTACHMENT NON?'TAL 004 03/0612002 02/03/2003 02/03/2008 EF ATT-8.4 ATTACHMENT SWVU 005 03/06/2002 0210312003 02/03/2008 EF ATT-8.5 ATTACHMENT LOSS OF OFFSITE POWER 001 08/26/2003 05/0212002 05/0212007 EF ATT-9.0 ATTACHMENT LETDOWN 009 01/07/2004 03(06/2002 03/0612007 EF ATT-9.1 ATTACHMENT EXCESS LID 006 0712812004 10/3112001 10/31/2006 EF ATT-10.0 ATTACHMENT FAULTED S/G 006 03/0612002 03/27/2003 03/27/2008 EF ATT-1 1.0 ATTACHMENT LA CONCERNS 004 09/0112004 03127/2003 03/27/2008 EF EF ATT-1 1.1 ATTACHMENT IA SUPPLY 003 03/0612002 0312712003 03/27/2008 EF ATT-11.2 ATTACHMENT DIESEL AIR COMPRESSOR 004 11/1182002 03/1012003 03110/2008 EF ATT-12.0 ATTACHMENT N2 PORVS 005 02/12V2003 02/12/2003 02112008 EF ATT-13.0 ATTACHMENT NC 003 02112/2003 02/12/2003 02/1212008 EF ATT-14.0 ATTACHMENT NORMAL RHR COOLING 003 03106/2002 04/06/2004 0410612009

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NPSP0200 Ginna Nuclear Power Plant Sun 411012005 9:40:59 am E66429 PROCEDURE INDE> Page 2 of 2 INPUT PARAMETERS: TYPE. PRATT STATUSVALUE(S): EFQU 5 YEARS ONLY:

PRATT EOP ATTACHMENTS PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TTlE REV DATE REVIEW REVIEW ST ATT-14.1 ATTACHMENT RHR COOL 008 0411012005 0110812002 01/0812007 EF ATT-14.2 ATTACHMENT RHR ISOL 003 0211212003 021212003 02112/2008 EF ATT-14.3 ATTACHMENT RHR NPSH 003 03106/2002 01/2812004 01128/2009 EF ATT-14.5 ATTACHMENT RHR SYSTEM 003 0312012003 0210312003 021032008 EF ATT-14.6 ATTACHMENT RHR PRESS REDUCTION 002 030612002 01128/2004 012812009 EF ATT-14.7 ATTACHMENT ADJUST RHR FLOW 001 0211712005 02117/2004 0211712009 EF ATT-15.0 ATTACHMENT RCP START 010 01/11/2005 01111/2005 01/1112010 EF ATT-1s.1 ATTACHMENT RCP DIAGNOS11CS 003 0412411997 02/03/2003 0210312008 EF ATT-15.2 ATTACHMENT SEAL COOUNG 005 03/0612002 0210312003 02103/2008 EF ATT-16.0 ATTACHMENT RUPTURED SIG 013 01/11/2005 0111112005 01/1112010 EF ATT-16.1 ATTACHMENT SGTL 003 09l01/2004 0910812000 091082005 EF ATT-16.2 ATTACHMENT RCS BORON FOR SGTL 004 04/1012005 0910512000 09/082005 EF ATT-17.0 ATTACHMENT SD-1 020 04110/2005 0112112005 01/21/2010 EF ATT-17.1 ATTACHMENT SD-2 007 0910112004 01/3012001 01/302006 EF ATT-18.0 ATTACHMENT SFP - RWST 005 0310612002 0210312003 0210312008 EF ATT-20.0 ATTACHMENT VENT TIME 004 09101/2004 02103/2003 02103/2008 EF ATT-21.0 ATTACHMENT RCS ISOLATION 002 03/06/2002 0210312oo3 02103/2008 EF ATT-22.0 ATTACHMENT RESTORING FEED FLOW 004 1111712004 01/22002 01/2212007 EF ATT-23.0 ATTACHMENT TRANSFER 4160V!LOADS 000 02/26/1999 01/28/2004 01/2812009 EF ATT-24.0 ATTACHMENT TRANSFER BATTERY TO TSC 001 1210112004 09/0812000 09/08/2005 EF ATT-26.0 ATTACHMENT RETURN TO NORMAL OPERATIONS 000 10/3112001 10/3112001 10/3112006 EF PRATT TOTAL: 51 GRAND TOTAL: 51

( (, C NPSP0200 Ginna Nuclear Power Plant Sun 411012005 9:42:14 am E66429 PROCEDURE INDE) Page 1 of I INPUT PARAMETERS: TYPE: PRFIG STATUS VALUE(S): EF, QU 5 YEARS ONLY:

PRFIG EOP FIGURE PROCEDURES PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVIEW ST I

FIG-1.0 FIGURE MIN SUBCOOLING 000 05(01/1998 03/27/2003 03J27/2008 EF FIG-2.0 FIGURE SDM 005 04/10/2005 03/27/2003 03/2712008 EF FIG-3.0 FIGURE NAT CIRC CID MTH SHROUD FANS 000 05/0111998 0312712003 03/27/2008 EF FIG-3.1 FIGURE NAT CIRC CID WITHCIUT SHROUD FANS 001 0210812001 03127/2003 03/27/2008 EF FIG-3.2 FIGURE NC CID MT VOID INNUPPER HEAD 000 0510111998 03/27/2003 03/27/2008 EF FIG-4.0 FIGURE RCP SEAL LEAKOFF 002 02/28/2001 03127/2003 03/2712008 EF FIG-5.0 FIGURE RHR INJECTION 000 05101/1998 03/27/2003 03127/2008 EF FIG-6.0 FIGURE MIN RCS INIECTION 000 05101/1998 03/2712003 0312712008 EF FIG-7.0 FIGURE INTACT SIG PRESSU RE 001 05118t1998 03t2712003 03/27/2008 EF FIG-8.0 FIGURE TSAT 000 0510111998 03/27/2003 03/27/2008 EF FIG-9.0 FIGURE TECH SPEC CD4 001 02115/2001 0312712003 03127/2008 EF FIG-9.1 FIGURE CID UMITS 000 0510111998 0312712003 03/2712008 EF FIG-10.0 FIGURE UMITA 000 0510111998 03/2712003 03/27/2008 EF FIG-1 1.0 FIGURE SOAK UMITS 000 05101/1998 03/27/2003 03127/2008 EF FIG-12.0 FIGURE CNMT HYDROGEN 000 05101/1998 03/27/2003 03/2712008 EF FIG-13.0 FIGURE BACK PRESSURE 000 05/01/1998 03/27/2003 03/27/2008 EF FIG-14.0 FIGURE LA ISOL 002 10/10/2003 03/2712003 03127/2008 EF PRFIG TOTAI 17 GRAND TOTAL: 17

EOP: TITLE:

REV: 8 ATT-14.1 ATTACHMENT RHR COOL PAGE 1 of 6 Responsible Manager Date ________

NOTE: Maintain operating RCP #1 seal DP greater than 220 psid.

1. Maintain RCS Temp < 350'F AND align the RHR system for shutdown operations as follows:

2. Open RHR Heat Exchanger bypass (HCV-626) isolation valves:

V-712A

V-712B

3. Ensure closed the following valves:

RHR PUMP DISCHARGE TO RX VESSEL DELUGE MOV-852A

RHR PUMP DISCHARGE TO RX VESSEL DELUGE MOV-852B

4. Open RHR Pump discharge crosstie valves

V-709C

V-709D K> 5. Open RHR PUMP DISCHARGE TO SI PUMP SUCTION MOV-857C

6. Verify RHR PUMP SUCTION FROM RWST MOV-856 open.

NOTE: WHEN the next step is performed, THEN Annunciator A-20 will light.

7. Start one RHR Pump AND locally throttle open RHR PUMP DISCHARGE TO SI PUMP SUCTION valves MOV-857A and 857B to maintain combined flow of < 1500 GPM as read on FI-931A and 931B.

RHR Pump Started

MOV-857A Throttled

MOV-857B Throttled

8. Throttle RHR Flow control valves to 50% open

HCV-624 Throttled

HCV-625 Throttled

HCV-626 Throttled

9. AFTER the RHR Pump has run 10 minutes, THEN obtain a sample of RHR System to verify Boron Concentration is greater than RCS Boron Concentration. If not, continue running RHR Pump until RHR Boron Concentration is acceptable.

EOP: TITLE:

REV: 8.

ATT-14.1 ATTACHMENT RHR COOL PAGE 2 of 6 NOTE: WHEN the next step is performed, THEN Annunciator A-20 will extinguish.

10. Stop the running RHR PUMP.

11. Place RHR suction from RWST MOV-856 Key Switch to ON.

12. Close RHR PUMP SUCTION FROM RWST MOV-856.

13. Close RHR PUMP DISCHARGE TO SI PUMP SUCTION MOVs

MOV-857A

MOV-857B

MOV-857C NOTE: DO NOT remove fuses.

14. Open the following breakers (Bkr):

MOV-857A (MCC C Pos 7M) Bkr

MOV-857B (MCC D Pos 7M) Bkr

MOV-857C (MCC C Pos 15J) Bkr

15. Close RHR Flow control valves

HCV-624

HCV-625

HCV-626

16. Close RHR PUMP SUCTION FROM CNMT SUMP B MOV-851A breaker (MCC C Pos 1OM).

17. Close RHR PUMP SUCTION FROM CNMT SUMP B MOV-851B breaker (MCC D Pos 1OM).

18. Close RHR PUMP SUCTION FROM CNMT SUMP B MOVs. IF MOV-851A and/or MOV-851B will NOT close, THEN consult Plant Staff to determine if MOV-850A and/or MOV-850B should be closed.

MOV-851A

MOV-851B NOTE: DO NOT remove fuses.

19. Open RHR PUMP SUCTION FROM CNMT SUMP B MOV-851A breaker (MCC C Pos 1OM).

EOP: TITLE:

REV: 8 ATT-14.1 ATTACHMENT RHR COOL PAGE 3 of 6

20. Open RHR PUMP SUCTION FROM CNMT SUMP B MOV-851B breaker (MCC D Pos 1OM).

21. WHEN Primary System pressure reaches 350 to 360 psig, THEN perform the following:

22. To prevent flashing in the CCW System, start a second Component Cooling Water Pump and put a second Component Cooling Water Heat Exchanger into service.

NOTE: IF FI-619 (PPCS point F0619) is > 4900 gpm, THEN notify the Shift Supervisor (Flow induced vibration concern).

23. With two CCW HX's in service, ensure CCW flow is < 4900 gpm.

24. Control RCS pressure using PRZR heaters and spray as follows:

24.1 IF at least one RCP is running, THEN reduce RCS pressure to approximately 325 psig and stabilize pressure, unless otherwise directed by procedure in effect.

24.2 IF NO RCP running, THEN stabilize RCS pressure between 350 and 360 psig, unless otherwise directed by procedure in effect.

25. Enable LTOP RCS pressure alarms associated with Annunciator F-29 and perform MCB alarm checks per S-26.1, COMPUTER PROGRAM CHECK.

26. Open CCW to RHR HX A MOV-738A.

27. Open CCW to RHR HX B MOV-738B.

NOTE: IF FI-619 (PPCS point F0619) is > 4900 gpm, THEN notify the Shift Supervisor (Flow induced vibration concern).

28. AFTER MOV-738A and MOV-738B are open, ensure CCW flow is

< 4900 gpm on FI-619.

29. Verify LOW PRESS LTDN PRESS PI-135 PCV-135 setpoint set to 300 psig.

30. Open RHR HX BYPASS HCV-626 to 25% to ensure RHR System pressure equalization.

31. Station an Auxiliary Operator at RHR pressure indicator PIC-629 (South of Spent Fuel Pool Pump A).

32. IF letdown NOT in service, THEN perform the following:

a. Place switches for AOV-200A, 200B, 202 to CLOSE

b. Open AOV-427 (reset XY relays, if necessary)

c. Open AOV-200A

d. Go to Step 34

33. Ensure CVCS letdown aligned up to PCV-135.

34. SLOWLY open RHR LETDOWN TO CVCS HCV-133 to 100% to fill AND pressurize the RHR system.

35. Verify RHR pressure (PIC-629) is within 200 psig of RCS pressure (P-420 or P-420A). Additional letdown orifice valves may be opened to help equalize pressure.

36. Remove AND reinsert control power fuses for RHR PUMP SUCTION FROM LOOP A HOT LEG MOV-700. (MCC C Pos 7F)

37. Close MOV-700 breaker (MCC C Pos 7F).

38. Remove AND reinsert control power fuses for RHR PUMP SUCTION FROM LOOP A HOT LEG MOV-701. (MCC D Pos 7F)

39. Close MOV-701 breaker (MCC D Pos 7F).

40. Open RHR PUMP SUCTION FROM LOOP A HOT LEG MOVs.

MOV-701

MOV-700

41. Verify closed RHR HX flow control valves.

HCV-626

HCV-625

HCV-624 NOTE: IF letdown in service, THEN it may be necessary to close down PCV-135 following RHR Pump start to maintain < 70 gpm Letdown flow. This can be done by raising PCV-135 AUTO setpoint OR taking MANUAL control of PCV-135 AND closing.

NOTE: IF letdown in service, THEN PI-135 may read 100 psi greater than PI-420 due to RHR Pump shutoff head.

NOTE: Annunciator A-20 will light.

42. Start one RHR PUMP.

EOP: TITLE:

REV: 8 ATT-14.1 ATTACHMENT RHR COOL PAGE 5 of 6 NOTE: DO NOT run two (2) RHR pumps with the discharge crossties open AND flow < 1200 gpm.

43. IF letdown in service, THEN adjust Low Press LTDN Press PCV-135 to establish desired Letdown flow (FI-134).

NOTE: PCV-135 (Letdown flow) determines the amount of flow during this temperature equalization.

44. Maintain flow at a minimum through HCV-624 and HCV-625 for 5 minutes to equalize the temperature of the RHR Loops.

45. Perform the following to establish the RHR System as a heat sink and secure the Steam Generators as heat sinks:

NOTE: To prevent flashing in the CCW System, ensure 2 CCW Pumps and 2 CCW Heat Exchangers are in service.

45.1 Remove AND reinsert control power fuses for RHR PUMP DISCHARGE TO LOOP B COLD LEG MOV-720.

45.2 Close MOV-720 breaker (MCC C Pos 7C).

45.3 Remove AND reinsert control power fuses for RHR PUMP DISCHARGE TO LOOP B COLD LEG MOV-721.

45.4 Close MOV-721 breaker (MCC D Pos 7C).

45.5 Open RHR PUMP DISCHARGE TO LOOP B COLD LEG.

MOV-720

MOV-721 45.6 Manually increase RHR flow and adjust HCV-624, HCV-625, and HCV-626; while simultaneously reducing Steam Generator feeding AND steaming rate to control RCS temperature.

NOTE: Maximizing feeding and steaming during subsequent cooldown on RHR will assist in SG cooling, and allow access as soon as possible.

45.7 WHEN Steam Generator feeding AND steaming has been reduced to the desired rate or secured, THEN continue increasing RHR flow AND/OR adjust HCV-624, HCV-625, and HCV-626 as necessary to establish the desired cooldown rate.

45.8 IF letdown in service, THEN readjust Low Press LTDN Press PCV-135 to re-establish desired letdown flow.

EOP: TITLE:

REV: 8 ATT-14.1 ATTACHMENT RHR COOL PAGE 6 of 6 NOTE: FI-626 flow indication will be lost during reset of flow alarm.

45.9 Notify I&C to reset RHR flow alarm to 400 gpm.

45.10 WHILE I&C resets the RHR flow alarm, THEN place RHR HX BYPASS HCV-626 in MANUAL.

45.11 Open RHR LETDOWN TO CVCS HCV-133.

EOP: TITLE:

REV: 4 ATT-16.2 ATTACHMENT RCS BORON FOR SGTL PAGE 1 of 2 Responsible Manager _ _ _ _ _ Date _________

NOTE: Boron calculations below assume most conservative values for temperature coefficient and boron worth.

Determine desired RCS boron concentration using attached figure as follows:

1. Find boron concentration for current cycle burnup. ppm

2. Add 140 ppm to the value of step 1. +140 ppml

3. Total is desired RCS boron concentration for cooldown from 547°F to 5000 F.

Total (5000 F)

4. Add 150 ppm to the value of step 3. +150 ppml

5. Total is desired RCS boron concentration for cooldown from 5000 F to 4500 F.

Total (4500 F)

I EOP: TITLE: REV: 4 ATT-16.2 ATTACHMENT RCS BORON FOR SGTL PAGE 2 of 2 Ginna Cycle 32 Required Boron Concentration to Maintain SDM at HZP Xenon-Free Conditions a-r_

V 0

U 0

r_

a) 0 0rD C

0*

V 0

a):

0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 Cycle Burnup (MWDIMTU)

EOP: TITLE:

REV: 20 ATT-17.0 ATTACHMENT SD-i PAGE 1 of 4 Responsible Manager Date ______°_

Perform the following local acti ns to complete normal secondary system shutdown:.

o Close reheater 4th pass temperature control valves:

o V-2432 (SW corner 1A MSR) o V-2433 (SW corner 1B MSR) o V-2434 (SW corner 2A MSR) o V-2435 (SW corner 2B MSR) o Close reheater steam chain valves:

o V-3550 (SW of 1B MSR) o V-3551 (SW of 1B MSR) o V-3552 (NW of 1A MSR) o V-3553 (NW of 1A MSR) o Open Reheater steamline vents (SW corner of condenser, middle floor):

o V-8500 o V-8501 o V-8502 o V-8504 o V-8505 o Open Reheater steamline vents (SW corner of condenser, above walkway):

o V-8506 o V-8507 o V-8508 o V-8509 o Locally close flange heating isolation valves:

o MOV-3601A (TB Middle Lvl East of TURB Lube Oil Reservoir) o MOV-3602A o Open the following valves to align for condensate feed system cooldown RECIRC:

o V-3982B (at #5 heater outlet header) o V-3983B (at #5 heater outlet header) o V-4363 (at #5 heater outlet header) o V-4365 (by MFW regulating valves) o V-4361 (southwest corner of condenser, middle floor) o V-3976A MFP A discharge valve bypass valve o V-3977A MFP B discharge valve bypass valve

EOP: TITLE:

REV: 20 ATT-17.0 ATTACHMENT SD-i PAGE 2 of 4 o Secure secondary chemical addition pumps on TURB BLDG middle floor by #5 heaters.

o Secondary Chem Add Pump A o Secondary Chem Add Pump B o Secondary Chem Add Pump C o Secondary Chem Add Pump D o Secondary Chem Add Pump E o Secure ammonia injection pumps, TURB BLDG basement by MCC A.

o Ammonia Inj Pump 1 o Ammonia Inj Pump 2 o Ammonia Inj Pump 3 o' Secure the Ethanolamine (ETA) injection pump, TURB BLDG basement by turbine lube oil purifier.

o Close SW valves from the following coolers:

o MFW Pump Oil Coolers (MFW pump room) o V-4703 o V-4704 o Exciter Air Cooler:

o V-4679B (chain valves next to condensate transfer pump) o V-4679 o Bus Duct Air Cooler (TURB BLDG basement East of bus duct cooler) o V-4674 o V-4674C (mini bypass around V-4674) o Throttle SW as necessary from following coolers:

o Generator Seal Oil Unit Coolers (H2 side and air side):

o V-4676A (mini bypass disch valve inside seal oil enclosure Bldg. NW corner) o V-4677A (mini bypass disch valve inside seal oil enclosure Bldg. NW corner) o Main Lube Oil Coolers (SW corner of Turb Oil Reservoir) o V-4691 o V-4692

EOP: TITLE:

REV: 20 ATT-17.0 ATTACHMENT SD-1 PAGE 3 of 4 o IF HDT Pump A seal injection primary filter (FGS0lA) is in service, THEN perform the following to place the HDT Pump A seal injection bypass line (and filter FGS02A) in service and isolate the primary filter as follows (north side of HDT Pump A):

1. Ensure closed HDT Pump A bypass filter outlet valve, V-3709C.

2. Slowly open HDT Pump A bypass filter inlet isolation, V-3907F.

3. Slowly throttle open HDT Pump A bypass filter outlet valve, V-3709C WHILE concurrently closing HDT Pump A primary filter outlet valve, V-3709B to maintain approximately 5 - 8 gpm seal injection flow (FAL-3799A).

o IF HDT Pump B seal injection primary filter (FGS01B) is in service, THEN perform the following to place the HDT Pump B seal injection bypass line (and filter FGS02B) in service and isolate the primary filter as follows (south side of HDT Pump B):

1. Ensure closed HDT Pump B bypass filter outlet valve, V-3710C.

2. Slowly open HDT Pump B bypass filter inlet isolation, V-3910F.

3. Slowly throttle open HDT Pump B bypass filter outlet valve, V-3710C WHILE concurrently closing HDT Pump B primary filter outlet valve, V-3710B to maintain approximately 5 - 8 gpm seal injection flow (FAL-3799B).

o WHEN the turbine shaft stops, THEN notify Control Room. Control Room personnel will determine if adequate power (36 KW) available to start turning gear.

o Transfer house heating steam to house heating boiler if necessary (refer to T-35H, NUCLEAR HOUSE HEATING STEAM TO BOILER STEAM SUPPLY CHANGE).

o Align S/G blowdowns as follows:

1. Secure blowdown to the condenser per T-14G, STEAM GENERATOR BLOWDOWN HEAT RECOVERY SYSTEM SHUTDOWN.

2. IF restoration of blowdowns is desired, THEN ensure releases are in effect before performing the following step. IF restoration of blowdowns is NOT desired, skip the following step.

3. Align Steam Generator Blowdown Flash Tank drains to the discharge canal per T-14F.1, SG BLOWDOWN ALIGNMENT TO DISCHARGE CANAL.

o Restore MAKEUP to CSTs as directed by Control Room.

Responsible Manager _ _ _ _ _ _ _ Date -/6)

- 66S FIGURE SDM NOTE: o Curve includes allowance for one stuck rod. Add 100 ppm for each additional stuck rod.

o To obtain core burnup, use PPCS point ID BURNUP.

BORON CONCENTRATION (PPM) 1800 1600 -

1400 -

E 1200 -

1000 -

800 -

600 -

400 -

200 -

0 I- -I I I Il I I .I l 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 CYCLE 32 BURNUP (MWD/MTU)

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW l ~PAGE I of 32.

GINNA STATION CONTROLLED COPY NUMBER C06)

RESPONSIBLE ( NAGER 04- -a 66as EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 5 qP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 2 of 32 A. PURPOSE - This procedure provides the necessary instructions to mitigate the consequences of a loss of all charging flow or gas binding of charging pumps.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. AP-CVCS.1, CVCS LEAK, when no charging flow paths are available for inventory control.

b. AP-ELEC.14/16, LOSS OF SAFEGUARDS BUS 14/16, when no charging pumps are available.

2. SYMPTOMS - The symptoms of a loss of all charging or gas binding charging of pumps are;

a. Annunciator B-9 (B-10), RCP A(B) LABYR SEAL LO DIFF PRESS 15" H20, lit, or

b. Seal injection flow low or erratic, or

c. Charging line flow low or erratic, or

d. Charging pump discharge pressure low or erratic, or

e. Annunciator F-14, CHARGING PUMP SPEED, lit, or

f. Annunciator A-2, VCT LEVEL 14%86, if gas intrusion to charging pumps is indicated, or

g. Annunciator A-4, REGEN HX LETDOWN OUT HI TEMP 3950F, lit, or

h. Annunciator A-10, VCT PRESSURE 15PSI65, if gas intrusion to charging pumps is indicated, or

i. Annunciator G-25, MOTOR OFF CTR SECT PUMPS EXCEPT MAIN &

AUX FEED PUMPS

OP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 3 of 32

< ACTION/EXPECTEDERESPONSE 1 Check Charging Pumps - ANY Start two charging pumps. IF at RUNNING least one pump cannot be started, THEN go to step 4.

2 Check Charging Pump Evaluate System Conditions Conditions:

o AO Reports o Check charging pump discharge pressure - GREATER THAN RCS

Indications of CVCS leakage PRESSURE AND STABLE

Increased sump pump operation

Abnormal indications for o Check charging flow - NORMAL operating charging pumps o Check RCP labyrinth seal dp - o Rad Monitors GREATER THAN 15 INCHES AND STABLE o VCT Indications o Aux Bldg Sump Indication

Frequency of level alarms

Increased sump pump operation IF AP-CVCS.1. CVCS LEAK directed this procedure be entered, THEN go to Step 4.

IF NOT and a charging system leak is suspected. THEN go to AP-CVCS.1.

CVCS LEAK.

IF NOT. THEN stop all charging pumps and go to step 4.

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 4 of 32 STEPACTI N/EX ECTE RES ONS RESPONSE NOT OBTAINED 3 Return To Guidance In Effect 4 Isolate Letdown

a. Close letdown isolation valve.

AOV-427

b. Close letdown orifice valves (AOV-200A. AOV-200B. and AOV-202)

c. Close excess letdown flow control valve. HCV-123.

d. Close excess letdown isolation valve, AOV-310.

e. Close charging flow control valve. HCV-142.

5 Check CCW To RCP Thermal IF CCW lost to RCP(s). THEN perform Barriers the following:

o Annunciator A-7. RCP 1A CCW a. Trip the Reactor. I RETURN HI TEMP OR LOW FLOW-EXTINGUISHED b. Trip affected RCP(s) o Annunciator A-15. RCP 1B CCW c. Close seal return AOV for RETURN HI TEMP OR LOW FLOW - affected RCP(s)

EXTINGUISHED

. RCP A - AOV-270A

RCP B - AOV-270B

d. Go to E-O, REACTOR TRIP OR SAFETY INJECTION.

EOP: TITLE: REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 5 of 32 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED I I

6 Monitor PRZR Level - GREATER IF reactor trip breakers are THAN 5% closed, THEN trip the reactor and go to E-0, REACTOR TRIP OR SAFETY INJECTION.

7 Check VCT Makeup System:

a. Ensure the following:

1) RMW mode selector switch in AUTO

2) RMW control armed - RED LIGHT LIT

b. Check VCT level: b. Check letdown divert valve.

LCV-112A. aligned to VCT.

o Level - GREATER THAN 20%

1) Manually increase VCT makeup

-OR- flow as follows:

o Level - STABLE OR INCREASING a) Ensure BA transfer pumps and RMW pumps running.

b) Adjust RMW flow control valve. HCV-l1l. to increase flow.

c) Adjust boric acid flow to maintain required concentration.

IF VCT level can NOT be maintained, THEN refer to ER-CVCS.1. REACTOR MAKEUP CONTROL MALFUNCTION, if necessary.

.EOP: TITLE:V: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 6 of 32 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl NOTE: A load reduction may be required if charging pump suction is aligned to the RWST.

8 Check Charging Pump Suction Aligned To VCT:

a. VCT level - GREATER THAN 20% a. IF VCT level can NOT be maintained greater than 5%. THEN perform the following:

1) Ensure charging pump suction aligned to RWST o LCV-112B open o LCV-112C closed IF LCV-112B and/or LCV-112C CAN NOT be operated THEN perform the following:

a) Stop charging pump A and place in PULL STOP.

b) Dispatch AO to locally open V-358. manual charging pump suction from RWST (charging pump room).

c) WHEN V-358 open, THEN direct AO to close V-268 to isolate charging pumps B and C from VCT (charging pump room).

2) Direct AO to isolate H2 and N2 to the VCT.

Close V-261

. Close V-262

3) Close seal return. MOV-313.

4) Continue with step 9.

b. Align charging pumps to VCT o LCV-112C open o LCV-112B closed

TIThE:

EOP EOP: TITIE: RV REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 7 of 32 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl NOTE: A load reduction may be required if charging pump suction is aligned to the RWST.

9 Try To Restore Charging Pumnp A

a. Check charging pump isolation. a. Go to Step 10.

V-268 - OPEN

b. Charging pump A is to be started b. Go to Step 10.

c. Gas binding of charging pump A c. Vent and fill charging pump A as NOT suspected follows:

1) Close discharge isolation.

V-287.

2) Throttle open discharge drain, V-292C.

3) WHEN sump tank level increase is noted, THEN close discharge drain, V-292C.

4) Open discharge isolation.

V-287.

d. Start charging pump A. d. IF charging pump A will not start. THEN go to Step 10.

e. Check charging pump conditions: e. Perform the following:

o Charging pump discharge 1) Stop charging pump A.

pressure - ABOVE RCS PRESSURE AND STABLE 2) Go to Step 10.

o Charging flow normal

EOP: TITLE: 5 REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

, PAGE 8 of 32 NOTE: A load reduction may be required if charging pump suction is aligned to the RWST.

10 Try To Restore Charging Pump B

a. Charging pump B is to be started a. Go to Step 11.

b. Gas binding of charging pump B b. Vent and fill charging pump B as NOT suspected follows:

1) Close discharge isolation.

V-288.

2) Throttle open discharge drain, V-292D.

3) WHEN sump tank level increase is noted, THEN close discharge drain, V-292D.

4) Open discharge isolation.

V-288.

c. Start charging pump B c. IF charging pump B will not start, THEN go to Step 11.

d. Check charging pump conditions: d. Perform the following:

o Charging pump discharge 1) Stop charging pump B.

pressure - ABOVE RCS PRESSURE AND STABLE 2) Go to Step 11.

o Charging flow normal

EOP TITLE:

EOP: TIRLE:

REV: 5 MK-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 9 of 32 NOTE: A load reduction may be required if charging pump suction is aligned to the RWST.

11 Try To Restore Charging Pump C

a. Gas binding of charging pump C a. Vent and fill charging pump C as NOT suspected follows:

1) Close discharge isolation.

V-291.

2) Throttle open discharge drain. V-292E.

3) WHEN sump tank level increase is noted. THEN close discharge drain, V-292E.

4) Open discharge isolation.

V-291.

b. Check charging pumps A and B - b. Perform the following:

BOTH RUNNING

1) IF desired. THEN start charging pump C.

IF charging pump C can not be started, THEN go to Step 12.

2) Go to Step lid.

c. Go to Step 12.

d. Check charging pump conditions: d. Perform the following:

o Charging pump discharge 1) Stop charging pump C.

pressure - ABOVE RCS PRESSURE AND STABLE 2) Go to Step 12.

o Charging flow normal

FEON: TITLE:

IIT REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

.I PAGE 10 of 32 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE: A load reduction may be required-if charging pump suction is aligned to the RWST.

12 Check Charging Pumps

a. At least one charging pump a. Continue efforts to restore running charging capability AND go to Step 17.

b. Check charging pump conditions: b. Perform the following:

o Charging pumps discharge 1) Stop charging pump(s).

pressure - ABOVE RCS PRESSURE AND STABLE 2) Continue efforts to restore charging capability AND go to o Charging flow - NORMAL step 17.

c. Adjust charging pump speed and HCV-142 to:

Restore PRZR level to program

Maintain labyrinth seal D/P between 15 inches and 80 inches 13 Check PRZR Level

a. Check PRZR level - INCREASING a. IF'Tavg is stable or increasing, THEN go to AP-RCS.1, REACTOR COOLANT LEAK. -

b. Check PRZR level - GREATER THAN b. WHEN PRZR level increases to 13% greater than 13%. THEN do step 14.

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 11 of 32 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

. 14 Establish Normal Letdown IF normal letdown can NOT be (Refer to ATT-9.0, ATTACHMENT established, THEN establish excess LETDOWN) letdown. (Refer to ATT-9.1, ATTACHMENT EXCESS L/D) 15 Evaluate MCB Annunciator Status (Refer to AR Procedures) 16 Return To Procedure Or Guidance In Effect

EOP: TITLE:

REV: 5 H

AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 12 of 32 CAUTION IF CHARGING CAPABILITY IS RESTORED DURING SUBSEQUENT STEPS THE OPERATOR SHOULD STOP THE LOAD DECREASE AND RETURN TO STEP 7 FOR RECOVERY ACTIONS.

17 Initiate Load Reduction

a. Verify rode in AUTO a. Perform the following:

1) Place rods to MANUAL.

2) Insert rods as necessary to match Tavg and Tref.

b. Reduce turbine load in AUTO as b. IF Auto Control is inoperable.

follows: THEN reduce turbine load in manual at 5%/min.

1) Place Turbine EH Control in OPER PAN.. IMP PRESS IN. if desired

2) Select rate of 5%/min on thumbwheel

3) Reduce the cetter to zero

4) Depress the GO button

c. Transfer 4160V Auxiliary load from #11 Transformer (Refer to ATT-23.0, ATTACHMENT TRANSFER 4160V LOADS)

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW P

. . PAGE 13 of 32 ACTIN/EXECTE ORESOBNSE I CAUTION EXTREME AND RAPID ROD MOTION TO MITIGATE TAVG SWINGS MAY RESULT IN LARGE POWER EXCURSIONS AND SHOULD BE AVOIDED.

U *

U * * * * * * * * *

U * * * * * * * * * * * * * *

U * * * * * * *

U

18 Monitor RCS Tavg Verify control rods responding in AUTO. IF NOT. THEN place rods to o Tavg - GREATER THAN 5451E MANUAL and adjust rods to restore Tavg within limits.

o Tavg - LESS THAN 5661F IF Tavg is outside limits AND can NOT be controlled. THEN trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

19 Check IA Available To CNMT Control PRZR level and pressure as follows:

o IA pressure - > 60 psig o Adjust load reduction rate o Instr Air to CNMT Isol Valve.

AOV-5392 - OPEN I o Ensure control rods are moving to control Tavg o Operate proportional and backup heaters as required NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3)

20 Monitor PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

. 431K in MANUAL

Manual control of PRZR heaters and sprays IF PRZR pressure can NOT be controlled manually. THEN refer to AP-PRZR.I. ABNORMAL PRESSURIZER PRESSURE.

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

. ~PAGE 14 of 32.

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

21 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected SIG(s) MEW regulating valve in MANUAL

b. Restore S/G level to 52%.

IF SIG level can NOT be controlled manually. THEN refer to AP-EW.1, ABNORMAL MAIN FEEDWATER FLOW.

22 Check Steam Dump Status I IF steam dump required but NOT operating. THEN perform the o Annunciator G-15. STEAM DUMP I following:

ARMED - LIT I

a. Place STEAM DUMP MODE SELECTOR o Steam dump operating properly in Switch to MANUAL. I AUTO I

b. Place steam dump controller.

SC-484. to MANUAL. I

c. Operate steam dump valves manually as necessary. I

<-/

EOP: TITLE: -REV: 5 H

AP-CVCS.3 LOSS OF ALL CHARGING FLOW

.PAGE 15 of 32 ACTION/EXPECTED RESPONSE TAINE CAUTION IF CONDENSATE BOOSTER PUMP "A" IS OPERATING IN PARALLEL WITH EITHER CONDENSATE BOOSTER PUMP "B" OR "C" THEN CONDENSATE BOOSTER PUMP "B" OR "C" SHOULD BE SECURED FIRST IN ORDER TO MINIMIZE OPERATING AT MINIMUM FLOW CONDITIONS.

NOTE: The load reduction should not be delayed to perform the remaining steps.

23 Check If Condensate Booster Pumps Should Be Secured

a. Power < 65% OR Trim Valve a. WHEN power < 65% OR Trim Valve V-9508G indicates > 80% open V-9508G indicates > 80% open.

THEN continue with Step 23b.

b. Place the auto condensate booster pump to the trip position

c. Stop one condensate booster pump

d. WHEN condensate system pressures stabilize, THEN stop the remaining condensate booster pump

. LOP:REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW R PAGE 16 of 32 24 Check If One MFW Pump Should Be Secured

a. Power < 50% a. WHEN power < 50%, THEN continue with Step 24b.

b. Verify at least one MEWP Seal b. Notify AO to start one MFWP Seal Booster pump in service Booster pump

c. Two MEW Pumps running c. Go to Step 25.

d. Close discharge valve for the pump to be secured

MEW Pump A - MOV-3977

MEW Pump B - NOV-3976

e. Stop the desired MEW Pump

f. Close the secured MEW pump recirc valve by placing the control switch in pull stop

g. Close the service water block valve to the secured MEW pump oil cooler

MEW Pump A - V-4701

MFW Pump B - V-4702 25 Verify Trim Valves Place controller in manual and Controlling Condensate System control pressure between Pressure In Auto 300-375 psig (300-375 PSIG) 0

EOP . TITLE:

K AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 17 of 32

_ STP _ACTON/EPECED ESPOSE ESPNSENOT OBTAINEDI

* * * * * *

z* *

a* * * * * * * * * * * * * * * *

lt * * * * * * * * * * *

CAUTION IF MAIN FEEDWATER FLOW SHOULD DECREASE TO 25% OF FULL POWER VALUE

(.825 E+6 LBM/HR) PRIOR TO THE AMSAC SYSTEM AUTOMATICALLY BLOCKING, THEN A TURBINE TRIP AND AUX FEED PUMPS START COULD RESULT.

26 Check ANSAC System Status

a. Power < 35% (-150 psig first a. Continue with Step 27. WHEN stage pressure) power < 35% (-150 psig first stage pressure). THEN do Step 26b.

b. Verify AMSAC Auto Block Status b. Place AMSAC Manual Block switch Light is ON to the BLOCK position 27 Check Heater Drain Tank Pump Status

a. Generator load < 175 MWe a. WHEN generator load < 175 MWe.

THEN continue with Step 27b.

b. Stop one Heater Drain Tank Pump

c. WHEN Heater Drain Tank level control is stable, THEN stop the second Heater Drain Tank Pump

TIRE:

EOP E°P: TITLE lREV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW P PAGE 18 of 321 28 Check MFW Regulating Bypass Vlv Status

a. Power < 30% a. WHEN power is < 30%. THEN continue with Step 28b.

b. MFW Regulating Bypass Vlvs in b. Perform the following:

AUTO

1) Slowly open the MEW

HCV-480 Regulating Bypacs Vlvs while

HCV-481 verifying the associated MFW Regulating Vlv compensates by closing slightly

2) Place MEW Regulating Bypass Vlvc in AUTO 29 Align Systems For Low Power Operation

a. Place AOV-3959. CNDST Bypaos Vlv to CLOSE

b. Place LC-107. Hotwell Level Control, to MANUAL at 50%

c. Generator load < 100 MWe c. WHEN generator load < 100 MWe.

THEN continue with Step 29d.

d. Open turbine drain valves

TITLE:

EOP

.EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 19 of 32 30 Check If Turbine Should Be Tripped:

a. Check turbine load -

15 MW a. WHEN turbine load is

15 MW.

THEN continue with Step 30b.

b. Trip the turbine

c. Check turbine stop valves - c. Direct an AO to locally trip the CLOSED I turbine by placing the red TRIP lever to TRIP (west end of turbine).

IF the turbine will NOT trip.

THEN close both MSIVM. I

EOP TITLE: 1 REV: 5 H.

AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 20 of 32 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 31 Verify Proper Operation Of Steam Dump:

a. Verify annunciator G-15, STEAM a. Place steam dump mode selector DUMP ARMED - LIT switch to MANUAL.

b. Condenser steam dump operating b. IF steam dump NOT available.

in AUTO THEN perform the following:

1) IF power is greater than 8%.

THEN ensure reactor trip and go to E-O, REACTOR TRIP OR SAFETY INJECTION.

2) Adjust SIG ARV setpoints to 1005 psig and verify proper operation.

c. Tavg - TRENDING TO PROGRAM c. IF temperature less than 547 0F and decreasing, THEN perform the following:

1) Stop dumping steam

2) IF cooling continues, THEN close both MSIVs.

IF temperature greater than 547 0F and increasing, THEN dump steam to stabilize and slowly decrease temperature to 547 F.

IF Tavg can NOT be controlled, THEN manually trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

EOP TITLE EOP: TITLE: - REV:

. REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

. PAGE 21 of 32 NOTE: Transition to E-O is NOT required when the reactor trip breakers are opened in the following step.

32 Shutdown The Reactor

a. Place rod control in MANUAL

b. Drive control rods until

1% RTP

c. Press Rx trip pushbutton

d. Verify Rx trip breakers open d. Dispatch AO to locally open reactor trip breakers.

e. Verify MRPI indicates all control and shutdown rods on bottom

TIRE:

EOP EOP: TITLE: RV REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

. ~PAGE 22 of 32.

STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl t * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *

CAUTION IF ANY S/G LEVEL ABOVE 52%. THEN AFW FLOW MAY BE THROTTLED IMMEDIATELY TO PREVENT S/G ISOLATION.

33 Check S/G Feed Flow Status:

a. Manually start both MDAFW pumps

b. Verify MDAFW Pump flow - b. Perform the following:

SUFFICIENT FLOW TO MAINTAIN SIG LEVELS 1) Establish MEW flow using MEW regulating valve bypass valves.

IF MEW NOT available. THEN perform the following: I a) Manually start TDAFW pump and establish flow. I b) Adjust feed flow to restore S/G level to 52%. I c) Go to Step 33c. I

2) Adjust feed flow to restore S/G level to 52%.

3) Go to Step 35.

c. Verify MEW flow control valves - c. Place A and B MFW regulating and CLOSED bypass valve controllers in manual at 0% demand.

. MFW regulating valves

. MEW bypass valves

d. Close pump discharge valve for the MFP to be secured:

MOV-3977, A MEW pump

. MOV-3976, B MEW pump This Step continued on the next page

Thu:

EOP

.EOP: TITLE: R V REV: 5 AP.-CVCS.3 LOSS OF ALL CHARGING FLOW

. PAGE 23 of 32

_STEP _ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 33 continued from previous page)

e. Stop the running MFW pump

f. Close the secured MEW pump recirc valve by placing the control switch in PULL STOP

g. Place A and B MEW regulating and bypass valve controllers in manual at 0% demand.

h. Adjust AEW pump flow to restore SIG level to 52%

34 Establish Normal AFW Pump Shutdown Alignment:

a. Place AFW bypass switches to DEE

b. Close MDAFW pump discharge valves

. MOV-4007

. MOV-4008

c. Open AEW bypass valves as necessary to control S/G levels

. AOV-4480

AOV-4481

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 24 of 32 STP ACTION/EXPECTED RESPONSE REPNENTOTIE NOTE: Loss of forced air cooling may result in failure of NIS detectors.

35 Check If Sourcze Range Detectors Should Be Energized:

a. Source range channels - a. Go to Step 35e.

DEENERGIZED

b. Check intermediate range flux - b. Continue with Step 36. WHEN EITHER CHANNEL LESS THAN flux is less than 10-10 amps on 10-10 AMPS any operable channel. THEN do Steps 35c. d and e.

c. Check the following: c. Continue with Step 36. When either condition met, THEN do o Both intermediate range Steps 35d and e.

channels - LESS THAN 10-10 AMPS

-OR-o Greater than 20 minutes since reactor trip

d. Verify source range detectors - d. Manually energize source range ENERGIZED detectors by depressing P-6 permissive defeat pushbuttons (2 of 2).

IF source ranges can NOT be restored, THEN refer to ER-NIS.1. SR MALFUNCTION, and go to Step 36.

e. Transfer Rk-45 recorder to one source range and one intermediate range channel

. EOP: TITLE:REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

. PAGE 25 of 32 ACTION/EXPECTED RESPONSE STEP RESPONSE NOT OBTAINED 36 Check RCPs - BOTH RUNNING IF only one RCP is running. THEN go to step 38.

IF no RCPs are running, THEN perform the following:

a. Ensure 2 control rod shroud fans running.

b. Go to ES-0.2, NATURAL CIRCULATION COOLDOWN, step 1.

NOTE: The temperature limit of 530 0 F is based on two loop SDM requirements.

37 Initiate RCS Cooldown To 5400 F

a. Place Steam Dump Mode Selector Switch to MANUAL

b. Dump steam to condenser from b. Manually or locally dump steam intact S/G(s) using intact S/Gs ARV.

c. Establish and maintain cooldown rate in RCS cold legs - LESS THAN 1000F/HR

d. RCS T cold - LESS THAN 540'F d. Continue with Step 39. WHEN RCS T cold less than 5401F THEN do step 37e.

e. Stop RCS cooldown and stabilize T cold between 530 0E and 5401E

f. Go to step 39

lEOP: TITLE:

I REV: 5 1

AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 26 of 32 38 Maintain RCS TAVG - STABLE AT 5470F

a. Dump steam to condenser from a. Manually or locally dump steam intact SIG(s) using intact S/Gs ARV.

b. Establish and maintain TAVG -

STABLE AT 5470F NOTE: WHEN using a PRZR PORV, THEN select one with an operable block valve.

39 Depressurize RCS To Less Than IF normal spray not available. THEN 1950 PSIG Using Normal Spray use one PRZR PORV.

.EOP: TITLE: REV:

R V 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 27 of 32 ACTI~ON/XETE RESPONSE I

. CAUTION SI ACTUATION CIRCUITS WILL AUTOMATICALLY UNBLOCK IF PRZR PRESSURE INCREASES TO GREATER THAN 1992 PSIG.

40 Monitor SI Block Criteria:

a. Check the following: a. Return to Step 39.

o PRZR pressure - LESS THAN 1950 PSIG

-OR-o LOW PRZR PRESS BLOCK SAF INJEC status light - LIT

b. Stop RCS depressurization AND maintain RCS pressure less than 1950 pcig and stable

c. Place SI block switches to BLOCK

Train A

Train B

d. Verify SAFETY INJECTION BLOCKED d. Maintain PRZR pressure greater status light - LIT than 1750 psig and S/G pressure greater than 514 peig until SI blocked.

EOP: TITLE: REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 28 of 32 ACTIN/EXNCTE RE S P O N S E I NOTE: o Refer to 0-9.3. IMMEDIATE NOTIFICATION, for reporting requirements.

o. WHEN using a PRZR PORV. THEN select one with an operable block valve.

41 Restore PRZR Level

a. Verify RCS T cold - LESS THAN a. Perform the following:

5400F(stable at 547 0F for one RCP) o IF both RCPs running, THEN return to step 37.

-OR-o IF only one RCP running, THEN return to step 38.

b. Ensure at least one SI pump suction valve from RWST open

MOV-825A

MOV-825B

c. Start one SI Pump

d. Depressurize RCS to between d. IF normal spray not available.

1350 psig and 1450 psig using THEN use one PRZR PORV.

normal spray

e. Verify injection flow to RCS

f. Verify PRZR level greater than f. Continue with step 42. WHEN 13% PRZR level is greater than 13%.

THEN do step 4 1g.

g. Energize PRZR heaters as necessary to return PRZR to ,

saturation conditions

.EOP

TITLE:

REV: 5 AP-CVCS.3 LOSS OF .ALL CHARGING FLOW R PAGE 29 of 32 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

* * * * * * *r * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *

CAUTION OBSERVE SAFETY INJECTION PUMP STARTING DUTY LIMITS PER P-7. SAFETY INJECTION AND CONTAINMENT SPRAY SYSTEMS.

NOTE: Adjust RCS pressure, if required, between 1350 psig and 1450 peig as necessary to obtain SI flow.

42 Maintain Stable Plant Conditions

a. Maintain RCS pressure between . a. IF normal spray not available, 1350 psig and 1450 psig using THEN maintain RCS pressure PRZR heaters and normal PRZR between 1350 psig and 1450 psig spray using PRZR heaters.

b. Maintain PRZR level between 35%

and 50% by starting and stopping one SI pump as needed

c. Maintain RCS T cold between c. IF condenser not available. THEN 530'F and 540 0F (stable at 547 0F maintain RCS T cold between for one RCP) using steam dump to 530'F and 540'F (stable at 547 0F condenser for one RCP) using intact S/G(s)

ARV.

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

. PAGE 30 of 32 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 43 Establish Normal Shutdown Alignment:

a. Check condenser - AVAILABLE a. Dispatch AO to perform ATT-17.1.

ATTACHMENT SD-2.

b. Perform the following as necessary:

o Open generator disconnects

1G13A71

9X13A73 o Place voltage regulator to OFF o Rotate reheater steam supply controller cam to close valves o Place reheater dump valve switches to HAND o Stop all but one condensate pump (Refer to T-5F.

STARTING OR STOPPING THE CONDENSATE PUMPS)

c. Verify Bus 11A and Bus liB c. IF either bus NOT energized, energized - BOTH BUSSES GREATER THEN refer to 0-6.9.2.

THAN 4 KV ESTABLISHING AND/OR TRANSFERRING OFESITE POWER TO BUS 12A/

BUS 12B.

d. Dispatch AO to perform ATT-17.0.

ATTACHMENT SD-1

EOP: TITLE:

REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW PAGE 31 of 32 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 44 Notify RP .To Obtain Primary Samples Required By ITS LCO 3.4.16 (Load Reduction > 15%

in one hour)

. EOP: TITLE: REV: 5 AP-CVCS.3 LOSS OF ALL CHARGING FLOW

.I PAGE 32 of 32 STEP ACTION/EXPECTED RESPONSE lRESPONSE NOT OBTAINED 45 Consult Plant Staff For Long Term Recovery o Determine method of VCT level control o Drain VCT to Aux Bldg Sump Tank through one charging pump drain valve

-OR-o Divert RCP seal return to PRT by closing MOV-313 o Refer to O-2.1,NORMAL SHUTDOWN TO HOT SHUTDOWN o Refer to 0-2.2. PLANT SHUTDOWN FROM HOT SHUTDOWN TO COLD CONDITIONS o Review ITS LCOs (3.1.1. 3.4.5, 3.5.1. 3.5.2. 3.5.4, TRM 3.1.1) o Review SDM requirements (Refer to 0-2.1. 0-3.1) o Determine preferred water source to SI pumps

RWST

BAST o Review SI Accumulator isolation criteria (refer to 0-2.2) o Determine if excess letdown should be placed in service (Refer to ATT-9.1. ATTACHMENT EXCESS L/D) o Determine how long RCPs should be run without seal injection (generally less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ) o Determine method to increase RCP seal cooling, if necessary

-END-

VP-CVCS.3 EOP: TITLE:

J LOSS OF ALL CHARGING FLOW REV: 5 PAGE 1 of.1 AP-CVCS.3 APPENDIX LIST TITLES

1) ATTACHMENT SD-1 (ATT-17.0)

2) ATTACHMENT EXCESS L/D (ATT-9.1)

3) ATTACHMENT TRANSFER 4160V LOADS (ATT-23.0)

4) ATTACHMENT SD-2 (ATT-17.1)

5) ATTACHMENT LETDOWN (ATT-9.0)

EOP: TIRE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 1 of 10 GINNA STATION CONTROLLED COPY NUMBER X__ _

RESPONSIBLE AGER E-/E- DATE EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 2 of 10 A. PURPOSE - This procedure provides the steps necessary to continue plant operation while investigating an RCC/RPI malfunction.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. N/A

2. SYMPTOMS - The symptoms of RCC/RPI MALFUNCTION are;

a. Power range NIS indicate a flux tilt, or

b. Group step counters for any individual bank are not within 1 step of each other, or

c. Incore flux map indicates abnormal flux tilt, or

d. Incore thermocouples indicate abnormal power tilt, or

e. Individual rods are not within +/- 12 steps of their respective step counters as indicated on MRPI, or

f. Annunciator C-5, PPCS ROD SEQUENCE OR ROD DEVIATION lit, or

g. Annunciator C-29, MRPI SYSTEM FAILURE, lit, or

h. Annunciator E-26, POWER RANGE CHANNEL DEV +/- 2%, lit, or

i. Annunciator F-29, PPCS AXIAL OR QUADRANT POWER TILT, lit.

EOP: TITLE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 3 of 10 ACTIN/EPECED ESPOSE l ESPNSENOT OBTAINED I 1 Place Rods To Manual CAUTION o BANK ROD WITHDRAWAL SHOULD NOT BE PERFORMED UNTIL DIRECTED PER APPLICABLE RECOVERY PROCEDURE.

o UNTIL THE MRPI SYSTEM IS KNOWN TO BE AT FAULT, A ROD INDICATING GREATER THAN +/- 12 STEPS FROM ITS GROUP STEP COUNTER SHOULD BE CONSIDERED A MISALIGNED ROD.

2 Check Dropped Rod Indication: IF the following conditions exist.

THEN go to AP-RCC.3. DROPPED ROD o Annunciator E-28, POWER RANGE RECOVERY.

ROD DROP ROD STOP 5%/5 SECONDS -

EXTINGUISHED o Reactor Power - decreasing o Annunciator C-14, ROD BOTTOM ROD o Tavg - decreasing STOP - EXTINGUISHED IF NOT. THEN go to Step 3.

3 Check Tavg - STABLE AT PROGRAM Perform the following:

a. Place EH control in MANUAL.

b. Manually adjust turbine load to match Tavg and Tref.

EOP: TITLE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 4 of 10 ACTION/EXPECTED RESPONSE STP lRESPONSE NOT OBTAINED 4 Verify Annunciator G-15, Verify steam dump valves closed.

STEAM DUMP ARMED - IF NOT. THEN place STEAM DUMP MODE EXTINGUISHED SELECTOR switch to MANUAL and-close valves.

5 Check Main Generator Load - IF load can NOT be stabilized above GREATER THAN 15 MW 15 MW, THEN trip the turbine and go to AP-TURB.1, TURBINE TRIP WITHOUT RX TRIP REQUIRED.

EOP: TITLE: i REV: 12 . I AP-RCC.2 RCC/RPI MALFUNCTION PAGE 5 of 10 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE: With PRZR pressure controller 431K in manual. PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3) 6 Establish Stable Plant Conditions:

a. Tavg - TRENDING TO TREE a. IF Tavg greater than Tref. THEN restore Tavg to Tref by RCS boration.

IF Tavg less than Tref, THEN restore Tavg to Tref by one or more of the following:

. Reduce turbine load

Dilution of RCS

b. PRZR pressure - TRENDING TO b. Control PRZR pressure by one of 2235 PSIG IN AUTO the following:

a 431K in MANUAL

. Manual control of PRZR heaters and spray IF pressure can NOT be controlled manually. THEN refer to AP-PRZR.1. ABNORMAL PRESSURIZER PRESSURE.

c. PRZR level - TRENDING TO PROGRAM c. Perform the following:

IN AUTO CONTROL

1) Place affected charging pumps in MANUAL

2) Adjust charging pump speed to restore PRZR level to program IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1, REACTOR COOLANT LEAK.

d. MEW Regulating Valves - d. Perform the following:

RESTORING S/G LEVEL TO 52% IN AUTO 1) Place affected S/G(s) MEW regulating valve in MANUAL

2) Restore S/G level to 52%

IF S/G level can NOT be controlled manually. THEN refer to AP-FW.1. ABNORMAL MAIN FEEDWATER FLOW.

EOP: TITLE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 6 of 10 7 Check Control Rod Alignment:

a. Verify all rods in affected a. Refer to ITS Section 3.1.4.

group - WITHIN i 12 STEPS OF ASSOCIATED GROUP STEP COUNTER NOTE: Step 8 is an attempt to determine whether a rod is misaligned or whether the MRPI System is malfunctioning.

8 Check QPTR - LESS THAN 1.02 Refer Ito ITS Section 3.2.4. I NOTE: IF the MRPI CRT fails, THEN the PPCS can be used for rod position indication until the CRT is made operable. Rod position indication can be retrieved from the PPCS by selecting the "CBAW" display button.

9 Verify All Individual Rod Perforim the following:

Position Indication Per Bank Operable: a. Refiar to ITS section 3.1.7 for reqiLuired action.

o MRPI system - NO MRPI SYSTEM ALARMS b. Con:cult Reactor Engineer and plaint staff to evaluate MRPI.

o MRPI system - NO KNOWN PROBLEMS WITH MRPI SYSTEM THAT COULD c. Go to Step 11.

RENDER ROD POSITION INDICATION INOPERABLE

[EOP: TITLE:

AP-RCC.2 RCC/RPI MALFUNCTION

. PAGE 7 of 10

_ SEP ACIONEXPCTE REPONE RSPOSENOT OBTAINEDI NOTE: The incore flux mapping system may aid in evaluating rod alignment depending on rod location.

10 Evaluate Control Rod Operability:

a. Verify less than two misaligned a. IF two or more rods are rods misaligned. THEN initiate plant shutdown. (Refer to 0-2.1, NORMAL SHUTDOWN TO HOT SHUTDOWN)

b. Direct I&C to locally investigate rod failure

c. Refer to ER-RCC.2. RESTORING A MISALIGNED RCC

d. Rod failure identified d. Perform the following:

1) Consult Reactor Engineer and ITS section 3.1.4 for operational concerns.

2) Return to step 2.

e. Rod failure corrected e. WHEN rod failure corrected, THEN continue with Step lOf.

IF rod failure can NOT be corrected at power, THEN go to ER-RCC.2. RESTORING A MISALIGNED RCC.

f. Restore misaligned rod (Refer to ER-RCC.2. RESTORING A MISALIGNED ROD)

EOP: TIRE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 8 of 10 ACTION/EXPECTED RESPONSE l[RESPONSE STP NOT OBTAINED 11 Verify Affected Group Step Refer to ITS section 3.1.7 for Counters Operable: required actions.

a. Affected bank group step counter movement - CONSISTENT WITH MRPI TRANSITIONS (Evaluate affected bank using PT-1, ROD CONTROL SYSTEM)

b. Group step counters for affected bank - WITHIN 1 STEP OF EACH OTHER 12 Check Reactor Conditions:

a. Rod insertion limit alarms - a. Reduce load and borate and EXTINGUISHED withdraw control rods to clear insertion limit alarms (refer to affected rod bank alarm response procedures if necessary).

b. NIS PR AI - WITHIN i 5% OF b. Perform one or more of the TARGET VALUE following to restore AI to within limits:

Borate RCS

Dilute RCS

Restore control rods to desired position 13 Evaluate Plant Conditions:

a. Rod/MRPI malfunction - REPAIRED a. Return to Step 8.

b. Verify control rod operability - b. Refer to ITS section 3.1.4 and OPERABILITY RESTORED (Refer to consult plant staff for further PT-1. ROD CONTROL SYSTEM) guidance.

EOP: TITLE:

REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION PAGE 9 of 10 14 Establish Control Systems In Auto

a. Verify 431K in AUTO a. Place 431K in AUTO, if desired.

b. Verify PRZR spray valves in AUTO b. Place PRZR spray valves in AUTO, if desired.

c. Verify PRZR heaters restored: c. Restore PRZR heaters, if desired.

o PRZR proportional heaters breaker - CLOSED o PRZR backup heaters breaker -

RESET. IN AUTO

d. Verify one charging pump in AUTO d. Place one charging pump in AUTO.

if desired.

e. Verify MFW regulating valves in e. Place MEW regulating valves in AUTO AUTO, if desired.

f. Restore EH controls

1) Place in OP PAN. IMP OUT

2) Place load rate thumbwheel to 10%/hr

3) Match setter and reference

g. Verify annunciator G-15, STEAM g. WHEN Tavg within 5 0F of Tref, DUMP ARMED - EXTINGUISHED THEN perform the following:

1) Ensure steam dump valves closed

2) Reset steam dump

h. Verify rods in AUTO h. Place rods in AUTO. if desired.

EOP: TIRE: REV: 12 AP-RCC.2 RCC/RPI MALFUNCTION

, PAGE 10 of 10 15 Evaluate MCB Annunciator Status (Refer to AR Procedures) %

NOTE: Refer to 0-9.3. NRC IMMEDIATE NOTIFICATION, for reporting requirements.

16 Notify Higher Supervision 17 Return To Procedure Or Guidance In Effect

-END -

EOP: TITLE:

REV: 4 AP-SG.1 STEA~M GENERATOR TUBE LEAK PAGE 1 of 33 GINNA STATION CONTROLLED COPY NUMBER QS3 V

RESPONSIBLq AGER EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 2 of 33 A. PURPOSE - This procedure provides the necessary instructions to be taken in the event of a Steam Generator tube leak within the capacity of the charging pumps.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITION - This procedure is entered from:

a. AP-RCS.1, REACTOR COOLANT LEAK,-if S/G tube leak is indicated.

b. AR-PPCS-1, SGTL INDICATED, when R-15A-5 is increasing for greater than one minute.

c. AR-RMS-15, R15 AIR EJECTOR, AR-RMS-19, R-19 STEAM GEN BLOWDOWN, when SG sample indicates a tube leakrate of greater than 5 gpd.

d. AR-EMS-31, R31 STEAM LINE A and AR-RMS-32, R32 STEAM LINE B when other indications of SG tube leakage exist.

e. Shift Supervisor discretion.

2. SYMPTOMS - Symptoms of STEAM GENERATOR TUBE LEAK are:

a. Primary to secondary tube leak rate in one S/G has been verified by sampling to be greater than or equal to 5 gpd.

b. Either of the following indicating a leak rate of greater than or equal to 5 gpd AND increasing for greater than one minute:

o R15A5G OR o Sping (using R15A5 conversion table, Curve Book #06-004)

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 3 of 33 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

1 Monitor PRZR Level - STABLE IF PRZR level decreasing. THEN AT PROGRAM LEVEL start additional charging pumps and increase speed as necessary to stabilize PRZR level.

IF PRZR level continues to decrease. THEN close letdown isolation. AOV-427 and excess letdown AOV-310.

IF available charging pumps are running at maximum speed with letdown isolated. AND PRZR level is decreasing. THEN trip the reactor and go to E-O, REACTOR TRIP OR SAFETY INJECTION.

2 Monitor S/G Tube Leak Rate:

a. Estimate SIG tube leak rate:

o Charging/Letdown mismatch o A VCT o PPCS Point R15A5G o SPING (using R15A5 conversion table. Curve Book #06-004)

b. Check total RCS to secondary b. Go to Step 8.

leak rate - LESS THAN 1 GALLON PER MINUTE (1440 GPD)

EOP: TITLE: REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 4 of 33 3 Trend SIG Leak Rate:

a. While continuing with this procedure, perform Part A of ATT-16.1, ATTACHMENT SGTL

b. Determine S/G leak rate:

o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table. Curve Book #06-004)

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 5 of 33 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 4 Determine If Shutdown Required:

a. SIG tube leak rate - GREATER a. Perform the following:

THAN OR EQUAL TO 5 GPD

1) Notify higher supervision

2) Return to guidance in effect

b. S/G tube leak rate - GREATER b. Perform the following:

THAN OR EQUAL TO 30 GPD

1) Notify higher supervision

2) Determine S/G tube leak rate at least once per hour o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table, Curve Book #06-004)

3) IF leak rate is stable OR decreasing for 4 consecutive hours. THEN reduce leak rate trending to at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table, Curve Book #06-004)

4) Return to Step 1.

This Step continued on the next page.

EOP: TITLE: REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK

.. PAGE 6 of 33 ACTION/EXPECTED RESPONSE STEP RESPONSE NOT OBTAINED (Step 4 continued from previous page)

c. S/G tube leak rate - GREATER c. Perform the following:

THAN OR EQUAL TO 75 GPD

1) Notify higher supervision

2) Determine S/G leak rate every 15 minutes (IF performing a procedural loop, THEN use trending rates previously determined in Step 5) o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table, Curve Book #06-004)

3) Go to Step 5.

d. S/G tube leak rate - STABLE OR d. Perform the following:

INCREASING

1) Notify higher supervision

2) IF the leak rate spiked to greater than 144 gpd. THEN go to Step 6.

IF the leak rate spiked to less than 144 gpd but has remained greater than 75 gpd for at least one hour. THEN go to Step 6.

IF the leak rate spiked to less than 144 gpd AND has decreased to less than 75 gpd within one hour. THEN return to Step 4b.

e. Go to Step 6.

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 7 of 33 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED 5 Determine Trending Requirements:

a. S/G leak rate - INCREASES LESS a. Return to Step 1.

THAN 10% DURING A ONE HOUR PERIOD o PPCS point R15A5G o SPING (using R15A5 conversion table. Curve Book #06-004) o Grab sample

b. Trend SIG leak rate at least once per hour.

o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table. Curve Book #06-004)

c. Review E-3. STEAM GENERATOR TUBE RUPTURE.

d. At least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months since one-hour d. Return to Step 1.

leak rate trending began.

e. S/G leak rate - INCREASES LESS e. Return to Step 1.

THAN 10% DURING the last 24 HOURS

f. Trend S/G leak rate at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table, Curve Book #06-004)

g. Return to Step 1.

EOP: TITRE:

REV: 4 AP-SG. 1 STEAM GENERATOR TUBE LEAK PAGE 8 of 33 6ACTOEETRSENOTR OBTAINEk 6 Confirm~ S/G Leak Rate:

a. At least two independent a. IF an instrument failure can be indications - TREND IN THE SAME confirmed. THEN return to DIRECTION guidance in effect. Otherwise return to Step 4.

o R-31 o R-32 o PPCS point R15A5G OR SPING (using R15A5 conversion table. Curve Book #06-004) o R-15 o R-19 o Grab samples (only allowed for confirming leaks less than 144 gpd which increase at less than 30 gpd/hr)

b. Notify higher supervision

c. While continuing with this procedure, perform Parts A AND B of ATT-16.1. ATTACHMENT SGTL

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 9 of 33 STP ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINEDl CAUTION MAINTAIN PRZR LEVEL AT 50% TO ACCOMMODATE RCS SHRINKING DURING PLANT SHUTDOWN AND COOLDOWN NOTE: Measured leakrate depends on RCS activity level, which may increase or decrease during power reduction, depending on fuel condition.

Therefore, once the power reduction has begun. R-15A should NOT be used to determine if the rate of power reduction should be changed.

7 Initiate Plant Shutdown

a. Determine S/G leakrate every 15 minutes o PPCS point R15A5G

-OR-o SPING (using R15A5 conversion table, Curve Book #06-004)

b. Check S/G leak rate - INCREASING b. Perform the following:

LESS THAN 30 GPD/HR

1) Reduce power to less than 50%

o Leak increases less than 15 RTP within 1 hour of gpd in 30 minutes (R15A5G or exceeding 30 gpd/hr. (Refer SPING) to AP-TURB.5. RAPID LOAD REDUCTION) o Grab samples indicate less than 30 GPD increase in 60 2) Be in Mode 3 within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months minutes of exceeding 30 gpd/hr.

(Refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN)

3) Go to Step 7g.

This Step continued on the next page.

EOP: TITIE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 10 of 33 (Step 7 continued from previous page)

c. Check R15A5 - OPERABLE c. Perform the following:

1) Be in Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months of exceeding 75 gpd. (Refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN)

2) Go to Step 7g.

d. Check SIG leak rate - HAS d. Perform the following:

REMAINED LESS THAN 144 GPD SINCE LEAK INITIATION 1) Be in Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months of exceeding 144 gpd. (Refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN)

2) Go to Step 7g.

e. Check S/G leak rate - REMAINED e. Return to Step 1.

GREATER THAN 75 GPD FOR GREATER THAN ONE HOUR

f. Be in Mode 3 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of exceeding 75 gpd (Refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN)

g. Refer to ITS o LCO 3.4.13 o LCO 3.4.16 o LCO 3.7.14

h. Check reactor - IN MODE 3 h. Return to Step 7a.

i. Go to Step 28.

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 11 of 33 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 8 Initiate Load Reduction

- a. Notify higher supervision.

b. Verify rode in AUTOMATIC b. Perform the following:

1) Place rods to MANUAL.

2) Adjust rode to match Tavg and Tref.

c. Reduce turbine load in Auto as c. IF Auto Control is inoperable, follows: THEN reduce turbine load in manual at 3%/min.

1) Place Turbine EH Control in OPER PAN., IMP PRESS IN, if desired.

2) Select rate of 3%/min on thumbwheel.

3) Reduce the setter to zero.

4) Depress the GO button.

d. Initiate boration at -2 gal/%

load reduction. I

e. Place PRZR backup heaters switch to ON.

f. Transfer 4160V Auxiliary load from #11 Transformer. (Refer to ATT-23.0. ATTACHMENT TRANSFER 4160V LOADS)

EOP: TITLE: R AP-SG.1 STEAM GENERATOR TUBE LEAK 4

. lPAGE 12 of 33 ACTION/EXPECTE D RESPONSE NED

* * * * * * * * * * * * * * *

C * * * * * * * * * * * * * * * * * * * * * *

CAUTION EXTREME AND RAPID ROD MOTION TO MITIGATE TAVG SWINGS MAY RESULT IN LARGE POWER EXCURSIONS AND SHOULD BE AVOIDED.

a * * * * * * * * * * * * * * * * * * * * * * * *

a * *

a * * * * * * * * * *

9 Monitor RCS Tavg Verify control rode responding in AUTO. IF NOT. THEN place rode to o Tavg - GREATER THAN 545 0F MANUAL and adjust control rods to restore Tavg within limits.

o Tavg - LESS THAN 566 0F IF Tavg is outside limits AND can NOT be controlled, THEN trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

10 While Continuing With This Procedure, Perform The Following:

a. Perform parts A AND B of ATT-16.1, ATTACHMENT SGTL

b. Dispatch an AO to perform T-35H, NUCLEAR HOUSE HEATING STEAM TO BOILER STEAM SUPPLY CHANGE OVER 11 Request RP to obtain the following samples:

RCS boron

RCS activity (ITS 3.4.16)

EOP: TITE:

AP-SG.1 STEAM GENERATOR TUBE LEAK l .PAGE 13 of 33 STP ACTION/EXPECTED RESPONSE lRESPONSE NOT OBTAINED NOTE: It is permissible to operate RCPs for limited periods without seal injection, provided CCW is being supplied to the thermal barriers.

12 Check IA Available To CNMT Control PRZR level and pressure as follows:

o IA pressure - > 60 psig o Adjust load reduction rate o Instr Air to CNMT Isol Valve, AOV-5392 - OPEN o Ensure control rods are moving to control Tavg o IF CCW supplied to BOTH RCP thermal barrier heat exchangers, THEN start/stop charging pumps as necessary to control PRZR level o Operate proportional and backup heaters to control PRZR pressure NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3)

13 Monitor PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

431K in MANUAL

- Manual control of PRZR heaters and sprays IF PRZR pressure can NOT be controlled manually. THEN refer to AP-PRZR.1. ABNORMAL PRESSURIZER PRESSURE.

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK

. .PAGE 14 of 33 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

14 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected S/G(s) MEW regulating valve in MANUAL

b. Restore S/G level to 52%

IF SIG level can NOT be controlled manually, THEN refer to AP-FW.1, ABNORMAL MAIN FEEDWATER FLOW.

15 Monitor PRZR Level - TRENDING Perform the following: I TO PROGRAM IN AUTO CONTROL I a. Place affected charging pumps in MANUAL I

b. Adjust charging pump speed to restore PRZR level to program I IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1.

REACTOR COOLANT LEAK.

16 Check Steam Dump Status: IF steam dump required but NOT operating, THEN perform the o Annunciator G-15. STEAM DUMP following:

ARMED - LIT

a. Place STEAM DUMP MODE SELECTOR I.

o Steam dump operating properly in I Switch to MANUAL.

AUTO

b. Place steam dump controller.

HC-484, to MANUAL. I

c. Operate steam dump valves manually as necessary. I

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 15 of 33 STP ACTION/EXPECTED RESPONSE lRESPONSE NOT OBTAINEDl 17 Adjust Boric Acid Addition Rate As Necessary To (refer to OPG-REACTIVITY-CALC):

o Maintain or return A Flux to the target band l o Maintain control rods above insertion limits o Match Tavg and Tref o Compensate for Xenon .

CAUTION IF CONDENSATE BOOSTER PUMP "A" IS OPERATING IN PARALLEL WITH EITHER CONDENSATE BOOSTER PUMP "B" OR "C" THEN CONDENSATE BOOSTER PUMP "B" OR "C" SHOULD BE SECURED FIRST IN ORDER TO MINIMIZE OPERATING AT MINIMUM FLOW CONDITIONS.

NOTE: The load reduction should not be delayed to perform the remaining steps.

18 Check If Condensate Booster Pumps Should Be Secured

a. Power < 65% OR Trim Valve a. WHEN power < 65% OR Trim Valve V-9508G indicates > 80% open V-9508G indicates 80% open, THEN continue with Step 18b.

b. Place the auto condensate booster pump to the trip position

c. Stop one condensate booster pump

d. WHEN condensate system pressures stabilize, THEN stop the remaining condensate booster pump

. EOP: TITLE:

. RE:V: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK I. PAGE 16 of 33 ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED STP 19 Check If One MFW Pump Should Be Secured

a. Power < 50% a. WHEN power < 50%. THEN continue with step 19b.

b. Verify at least one MFWP Seal b. Notify AO to start one MFWP Seal Booster pump in service Booster pump

c. Two MEW Pumps running c. Go to Step 20.

d. Close discharge valve for the pump to be secured

MEW Pump A - MOV-3977

. MEW Pump B - MOV-3976

e. Stop the desired MEW Pump

f. Close the secured MEW pump recirc valve by placing the control switch in pull stop

g. Close the service water block valve to the secured MEW pump oil cooler

MEW Pump A - V-4701

. MEW Pump B - V-4702 20 Verify Trim Valves Place controller in manual and Controlling Condensate System control pressure between Pressure In Auto 300-375 psig (300-375 PSIG)

EOP: TITIE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 17 of 33 ACTIN/EXECTE ORESOBNSE I

* * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *t * * *t *

CAUTION IF MAIN FEEDWATER FLOW SHOULD DECREASE TO 25% OF FULL POWER VALUE

(.825 E+6 LBM/HR) PRIOR TO THE AMSAC SYSTEM AUTOMATICALLY BLOCKING, THEN A TURBINE TRIP AND AUX FEED PUMPS START COULD RESULT.

* * * * * * * * * * * * *

a * * * * * * * * * * * * * * * * * * * * * * * *

21 Check ANSAC System Status

a. Power < 35% (-150 psig first a. Continue with Step 22. WHEN stage pressure) power < 35% (-150 psig first stage pressure). THEN do Step 21b.

b.. Verify AMSAC Auto Block Status b. Place AMSAC Manual Block switch Light is ON to the BLOCK position 22 Check Heater Drain Tank Pump Status

a. Generator load < 175 MWe a. WHEN generator load < 175 MWe.

THEN continue with Step 22b.

b. Stop one Heater Drain Tank Pump

c. WHEN Heater Drain Tank level control is stable, THEN stop the second Heater Drain Tank Pump

EOP: TIRE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 18 of 33 ACTION/EXPECTED RESPONSE lRESPONSE STEP NOT OBTAINED 23 Check MFW Regulating Bypass Vlv Status

a. Power < 30% a. WHEN power < 30%. THEN continue with Step 23b.

b. MFW Regulating Bypass Vlvs in b. Perform the following:

AUTO

1) Slowly open the MFW

HCV-480 Regulating Bypass Vlvs while

HCV-481 verifying the associated MEW Regulating Vlv compensates by closing slightly

2) Place MFW Regulating Bypass Vlvs in AUTO 24 Align Systems for Low Power Operation

a. Place AOV-3959. CNDST Bypass Vlv to CLOSE

b. Place LC-107, Hotwell Level Control, to MANUAL at 50%

c. Generator load < 100 MWe c. WHEN generator load < 100 MWe, THEN continue with step 24d.

d. Open turbine drain valves

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REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 19 of 33 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED 25 Check If Turbine Should Be Tripped:

a. Check turbine load -

15 MW a. WHEN turbine load is

15 MW, THEN continue with Step 25b.

b. Trip the turbine.

c. Check turbine stop valves - c. Direct an AO to locally trip the CLOSED I turbine by placing the red TRIP lever to TRIP (west end of turbine).

IF the turbine will NOT trip.

THEN close both MSIVs. I

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 20 of 33 26 Verify Proper Operation Of Steam Dump: I

a. Verify annunciator G-15, STEAM a. Place steam dump mode selector

'DUMP ARMED - LIT I switch to MANUAL. I

b. Condenser steam dump operating b. IF steam dump NOT available.

in AUTO I THEN perform the following:

1) IF power is greater than 8%.

THEN ensure reactor trip and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

2) Adjust intact SIG ARV setpoint to 1005 psig and verify proper operation.

c. Tavg - TRENDING TO PROGRAM I c. IF temperature less than 5470 F and decreasing. THEN perform the following:

1) Stop dumping steam

2) IF cooldown continues, THEN l close both MSIVs.

IF temperature greater than 5470 and increasing. THEN dump steam to stabilize and slowly decrease temperature to 547E.

IF Tavg can NOT be controlled.

THEN manually trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

K>

EOP:

AP-SG.1 TITLE:

STEAM GENERATOR TUBE LEAK REV: 4 PAGE 21 of 33 I

ACTIN/EXECTE REPONS 1 lRESPNSENOT OBTAINED NOTE: Transition to E-O is NOT required when the reactor trip breakers are opened in the following step.

27 Shutdown The Reactor

a. Place rods in MANUAL

b. Drive control rods until

1% RTP

c. Press Rx trip pushbutton

d. Verify Rx Trip breakers open d. Dispatch AO to locally open reactor trip breakers

e. Verify MRPI indicates all control and shutdown rods on bottom NOTE: The following step is intended to start an RCS boration at the earliest opportunity. The boration endpoint is determined in Step 34.

28 Initiate RCS Boration At IF normal boration can NOT be Maximum Rate Using FCV-11OA performed, THEN align charging pump suction to RWST

a. Start BOTH BAST pumps o LCV-112B - OPEN

b. Place FCV-1lOA controller to MANUAL AND adjust to full open. o LCV-112C - CLOSED

EOP: TITLE:

REV: 4 AP-SG. 1 STEAM GENERATOR TUBE LEAK PAGE 22 of 33 CAUTION IF ANY S/G LEVEL ABOVE 52%. THEN AEW FLOW MAY BE THROTTLED IMMEDIATELY TO PREVENT S/G ISOLATION.

29 Check S/G Feed Flow Status:

a. Manually start both MDAFW pumps

b. Verify MDAFW Pump flow - b. Perform the following:

SUFFICIENT FLOW TO MAINTAIN SIG LEVELS 1) Establish MEW flow using MEW regulating valve bypass valves.

IF MEW NOT available. THEN perform the following: I a) Manually start TDAFW pump from the non-leaking S/G and establish flow.

b) Adjust feed flow to restore S/G level to 52%. I c) Go to Step 29c.

2) Adjust feed flow to restore S/G level to 52%.

3) Go to Step 31.

c. Verify MEW flow,control valves - c. Place A and B MEW regulating and CLOSED bypass valve controllers in manual at 0% demand.

. MEW regulating valves

MEW bypass valves

d. Close pump discharge valve for the MEP to be secured: I

MOV-3977, A MEW pump

. MOV-3976. B MEW pump This Step continued on the next page.

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 23 of 33 ACTION/EXPECTED RESPONSE STEP RESPONSE NOT OBTAINED (Step 29 continued from previous page)

e. Stop the running MFW pump

f. Close the secured MFW pump recirc valve by placing the control switch in PULL STOP

g. Place A and B MFW regulating and bypass valve controllers in manual at 0% demand

h. Adjust AEW pump flow to restore S/G level to 52%.

30 Establish Normal AFW Pump Shutdown Alignment:

a. Place AEW bypass switches to DEF

b. Close MDAFW pump discharge valves

MOV-4007

MOV-4008

c. Adjust AEW bypass valves to control S/G levels at 52%

AOV-4480

AOV-4481

STP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINEDl 31 Complete Leaking S/G Isolation:

a. Close leaking S/G MSIV - LEAKING a. Perform the following:

S/G MSIV CLOSED

1) Close intact SIG MSIV.

2) Place intact S/G ARV controller at 1005 psig in AUTO.

3) Adjust condenser steam dump controller to 1050 psig in AUTO.

4) Place condenser steam dump mode selector switch to MANUAL.

5) Adjust reheat steam supply controller cam to close reheat steam supply valves.

6) Ensure turbine stop valves -

CLOSED.

7) Dispatch AO to complete leaking SIG isolation (Refer to ATT-16.0. ATTACHMENT RUPTURED S/G, parts A for the leaking S/G AND B).

b. Dispatch AO to complete leaking S/G isolation (Refer to ATT-16.0, ATTACHMENT RUPTURED S/G part A for the leaking S/G)

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REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 25 of 33 32 Check Leaking S/G Level:

a. Narrow range level - GREATER a. Perform the following:

THAN 17%

1) Maintain feed flow to leaking S/G until level greater than 17%.

2) Continue with Step 33. WHEN leaking S/G level greater than 17%. THEN do Steps 32b through f.

b. Close MDAFW pump discharge valve b. Dispatch AO to locally close to leaking S/G valve.

S/G A. MOV-4007

S/G B. MOV-4008

c. Close MDAFW pump bypass valve for leaking S/G

S/G A. AOV-4480

. S/G B. AOV-4481

d. Pull stop MDAFW pump for leaking S/G

e. Close TDAFW pump flow control e. Dispatch AO with locked valve valve to leaking S/G key to locally close TDAFW pump manual feedwater isolation valve

SIG A. AOV-4297 to leaking S/G.

. S/G B. AOV-4298

S/G A. V-4005

. S/G B, V-4006

f. Verify MDAFW pump crosstie f. Manually close valves.

valves - CLOSED

^ MOV-4000A

MOV-4000B

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 26 of 33 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

33 Reduce RCS Pressure To Minimize Tube Leak:

a. Maintain RCS pressure low in the desired operating range (Refer to 0-2.2. PLANT SHUTDOWN FROM HOT SHUTDOWN TO COLD CONDITIONS)

b. WHEN RCS pressure is less than 1950 psig. THEN place SI block switches to BLOCK

Train A

Train B

c. Verify SAFETY INJECTION BLOCKED status light - LIT

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 27 of 33 ACTION/EXPECTED RESPONSE OT OBTAINED J CAUTION OPERATION OF BOTH RCPS IS PREFERRED TO MINIMIZE REQUIRED BORON ADDITION FOR SUBSEQUENT COOLDOWN.

34 Increase RCS Boron

a. Determine desired RCS boron concentration for subsequent cooldown (Refer to ATT-16.2.

ATTACHMENT RCS BORON FOR SGTL)

b. Borate RCS to desired b. IF normal boration can NOT be concentration using FCV-1lOA performed. THEN align charging pump suction to RWST o LCV-112B - OPEN o LCV-112C - CLOSED

c. If desired. request Reactor Engineer evaluate an alternate desired RCS boron concentration to maintain SDM during subsequent cooldown

EOP: TITLE:

REV: 4 AP-SG.1 . STEAM GENERATOR TUBE LEAK PAGE 28 of 33 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 35 Establish Normal Shutdown Alignment:

a. Check condenser - AVAILABLE a. Dispatch AO to perform ATT-17.1.

ATTACHMENT SD-2.

b. Perform the following as necessary:

o Open generator disconnects

1G13A71

. 9X13A73 o Place voltage regulator to OFF o Open turbine drain valves o Rotate reheater steam supply controller cam to close valves o Place reheater dump valve switches to HAND o Stop all but one condensate pump and place in PULL STOP (Refer to T-5F. STARTING OR STOPPING THE CONDENSATE PUMPS)

c. Verify Bus 11A and Bus lB c. IF either bus NOT energized.

energized - BOTH BUSSES GREATER THEN refer to 0-6.9.2.

THAN 4 KV ESTABLISHING AND/OR TRANSFERRING OFESITE POWER TO BUS 12A/BUS 12B.

d. Dispatch AO to perform ATT-17.0.

ATTACHMENT SD-1

. EOP: TITLE:

I REV: 4 AP-SG.1 STE-AM GENERATOR TUBE LEAK

. PAGE 29 of 33 ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED STP 36 Check If Source Range Detectors Should Be Energized:

a. Source range channels - a. Go to Step 36e.

DEENERGIZED

b. Check intermediate range flux - b. Continue with Step 37. WHEN EITHER CHANNEL LESS THAN flux is less than 10-10 amps on 10-10 AMPS any operable channel. THEN do Steps 36c. d and e.

c. Check the following: c. Continue with Step 37. WHEN either condition met. THEN do o Both intermediate range Steps 36d and e.

channels - LESS THAN 10-10 AMPS

-OR-o Greater than 20 minutes since reactor trip

d. Verify source range detectors - d. Manually energize source range ENERGIZED detectors by depressing P-6 permissive defeat pushbuttons (2 of 2).

IF source ranges can NOT be restored. THEN refer to ER-NIS.1. SR MALFUNCTION. and go to Step 37.

e. Transfer RK-45 recorder to one source range and one intermediate range channel

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 30 of 33 ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED I 37 Check Rx Trip Breakers - OPEN DO NOT continue until Rx trip breakers open.

38 Check RCS Boron Concentration

a. RCS Boron Concentration - equal a. Continue boration. WHEN RCS to or greater than required for boron equal to or greater than cooldown to 500 degrees per required value. THEN go to step 34 step 38b.

b. Verify MRPI indicates all b. Borate an additional 650 gallons control and shutdown rods on of boric acid for each rod not bottom fully inserted. WHEN boration complete. THEN continue with Step 39.

39 Initiate RCS Cooldown To 500 degrees:

a. Check leaking S/G MSIV - CLOSED a. Perform the following:

1) Manually or locally initiate steam dump from intact S/G using S/G ARV

2) Go to step 39d

b. Place Steam Dump Mode Selector switch to MANUAL

c. Initiate dumping steam to c. IF condenser steam dumps not condenser from intact S/G available. THEN manually or locally initiate steam dump from intact S/G using S/G ARV

d. Establish and maintain cooldown rate in RCS cold legs - LESS THAN 500F/HR

e. Maintain RCS pressure low in the desired operating range (Refer to 0-2.2. PLANT SHUTDOWN FROM HOT SHUTDOWN TO COLD CONDITIONS)

EOP: TITLE:

AP-SG.1 STEAM GENERATOR TUBE LEAK

. 'PAGE 31 of 33 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 40 Notify RP To Obtain Primary Samples Required By ITS LCO 3.4.16 (load reduction >'15%

in one hour) 41 Check RCS Boron Concentration

a. RCS boron - equal to or greater a. Perform the following:

than required for cooldown to 450 degrees per step 34 1) Stop cooldown AND maintain stable RCS temperature above 500 degrees and stable.

2) Continue boration. WHEN RCS boron equal to or greater than required value, THEN go to step 41b.

b. Verify MRPI indicates all b. Request Rx Engineer determine control and shutdown rods on amount of boration required due bottom to rods not fully inserted.

c. Borate to 2.45% CSD Curve per 0-3.1. BORON CONCENTRATION FOR THE XENON FREE ALL RODS IN -

MOST REACTIVE ROD STUCK OUT SHUTDOWN MARGIN

EOP: TITLE:

REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 32 of 33 42 Cooldown RCS To 450 Degrees

a. Initiate dumping steam

b. Establish and maintain cooldown rate in RCS cold legs - LESS THAN 50OF/HR

c. Maintain RCS pressure low in the desired operating range

d. WHEN RCS pressure is less than 1500 psig, THEN isolate SI ACCUMs as follows:

1) Dispatch AO with locked valve key to locally close breakers for SI ACCUM discharge valves

. MOV-841. MCC C position 12F

MOV-865, MCC D position 12C

2) Close SI ACCUM outlet valves

ACCUM A. MOV-841

ACCUM B. MOV-865

3) Locally reopen breakers for MOV-841 and MOV-865

e. Check RCS temperature - LESS e. Continue RCS cooldown THAN 460 DEGREES

f. Stop the cooldown AND maintain ROS between 450 and 460 degrees

g. WHEN RCS pressure equals leaking S/G pressure, THEN maintain stable RCS pressure

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REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 33 of 33 ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED l 43 Check Normal Or Excess IF normal letdown desired, THEN Letdown - IN SERVICE establish normal letdown (Refer to ATT-9.0. ATTACHMENT LETDOWN)

IF normal letdown NOT available, THEN establish excess letdown if desired (Refer to ATT-9.1, ATTACHMENT EXCESS L/D).

44 Evaluate Long Term Plant Status:

a. Consult the following groups:

Operations Staff

. Plant Engineering Staff

. Chemistry

b. RCS boron - MEETS 2.45% CSD b. Perform the following:

CURVE PER 0-3.1. BORON CONCENTRATION FOR THE XENON FREE 1) Continue RCS boration to CSD ALL RODS IN - MOST REACTIVE ROD concentration. (Refer to STUCK OUT SHUTDOWN MARGIN 0-3.1, BORON CONCENTRATION FOR THE XENON FREE ALL RODS IN - MOST REACTIVE ROD STUCK OUT SHUTDOWN MARGIN)

2) Continue with Step 44e. WHEN RCS boron meets 2.45% CSD curve requirement. THEN do steps 44c and d.

c. Stop RCS boration

d. Restore RCS makeup to desired alignment

e. Determine if condensate cleanup is desired

f. Determine appropriate cooldown method

-END-

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REV: 4 AP-SG.1 STEAM GENERATOR TUBE LEAK PAGE 1 of 1 AP-SG.1 APPENDIX LIST TITLE

1) ATTACHMENT TRANSFER 4160V LOADS (ATT-23.0)

2) ATTACHMENT SD-1 (ATT-17.0)

3) ATTACHMENT SD-2 (ATT-17.1)

4) ATTACHMENT RUPTURED S/G (ATT-16.0)

5) ATTACHMENT SGTL (ATT-16.1)

6) ATTACHMENT RCS BORON FOR SGTL (ATT-16.2)

7) ATTACHMENT EXCESS LID (ATT-9.1)

8) ATTACHMENT LETDOWN (ATT-9.0)

GINNA STATION CONTROLLED COPY NUMBER 0X__

RESPONSIBLE ()NAGER EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

A. PURPOSE - This procedure provides the necessary instructions to control the plant following a turbine trip without a reactor trip required.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. AR-G-32, EMERGENCY DC LUBE OIL PUMP, if turbine tripped.

b. AR-I-8, EH RESERVOIR HI-LO LEVEL, if level is decreasing and cannot be stabilized.

c. AR-I-16, EH RESERVOIR LO LEVEL PUMP LOCKOUT, if level is decreasing and cannot be stabilized.

d. AR-J-2, GENERATOR STATOR WINDING HI TEMP, if generator conditions warrant turbine trip.

e. AR-VOLT-REG-3, LOSS OF BOTH FIRING CIRCUITS, if voltage regulator will'not control voltage.

f. AP-CW.1, LOSS OF A CIRC WATER PUMP, or,

g. AP-FW.1, ABNORMAL FEED FLOW, or,

h. AP-TURB.2, TURBINE LOAD REJECTION, or,

i. AP-TURB.3, TURBINE VIBRATION, or,

j. AP-TURB.4, LOSS OF CONDENSER VACUUM, when power is less than P-9 and the turbine trips without a Rx trip.

k. AP-TURB.5, RAPID LOAD REDUCTION, when Rx is to be maintained critical.

2. SYMPTOMS - The symptoms of TURBINE TRIP WITHOUT RX TRIP REQUIRED are:

a. Annunciator F-21, COND HI PRESS 20" HG OR LOSS OF BOTH CIRC WTR PMPS, lit, or

b. Annunciator G-15, STEAM DUMP ARMED, lit, or

c. Annunciator J-11, GENERATOR REVERSE POWER, lit, or

d. Annunciator J-26, GENERATOR EXCITER FIELD BREAKER TRIP, lit, or

e. Annunciator K-1, THRUST BEARING FAILURE, lit, or

f. Annunciator K-3, AMSAC ACTUATED, lit.

g. Annunciator K-9, TURBINE BEARING OIL LO PRESS TRIP 6 psi, lit, or

h. Annunciator K-10, TURBINE HIGH VIBRATION TRIP, lit, or

i. Annunciator K-17, TURBINE LOW VACUUM TRIP 20" HG, lit, or

j. Annunciator K-25, TURBINE OVERSPEED ALERT 1980 RPM, lit, or

k. Annunciator K-26, GENERATOR LOCKOUT RELAY, lit, or

1. Annunciator L-12, CONDENSER PIT OR SCREENHOUSE HI LEVEL 6.5", lit, or

m. Annunciator VOLT-REG-12, LOSS OF BOTH PWR SUPPLY, lit.

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1 Verify Turbine Stop Valves - Manually trip turbine.

CLOSED IF turbine stop valves can NOT be closed. THEN perform the following:

a. Trip the reactor

b. WHEN all E-O Immediate Actions done, THEN ensure both MSIVs closed

c. Go to E-O. REACTOR TRIP OR SAFETY INJECTION NOTE: o Automatic rod control is desired, if available.

o Transition to E-O is NOT required if the reactor trip breakers are opened in the following step.

2 Check Reactor Power:

a. NIS power ranges - ABOVE 1% a. Perform the following:

1) IF the reactor is subcritical. THEN shut down the reactor using manual trip pushbutton.

2) Go to Step 3.

b. Verify control rods driving in b. Perform the following:

to reduce reactor power in AUTO

1) Place rods in MANUAL

2) Adjust rods to control reactor power between 1% and 2%.

c. Borate to maintain control rods above rod insertion limits

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I REV: 14 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 5 of 16 ACTION/EXPECTED RESPONSE STEP RESPONSE NOT OBTAINED

3 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected S/G(s) MEW regulating valve in MANUAL

b. Restore SIG level to 52%

IF SIG level can NOT be controlled manually. THEN refer to AP-FW.1.

ABNORMAL MAIN FEEDWATER FLOW.

4 Verify Proper Operation Of Steam Dump:

a. Verify annunciator G-15, STEAM a. Place steam dump mode selector DUMP ARMED - LIT switch to MANUAL.

b. Condenser steam dump operating b. IF steam dump NOT available.

in AUTO THEN perform the following:

1) Adjust S/G ARV setpoints to 1005 psig and verify ARV operating to control Tavg to approximately 5470F.

2) IF power is greater than 8%.

THEN ensure reactor trip and go to E-O, REACTOR TRIP OR SAFETY INJECTION.

c. Check RCS Tavg: c. Verify control rods responding in AUTO. IF NOT, THEN place

Tavg - GREATER THAN 5451F rods to MANUAL and adjust

Tavg - LESS THAN 5661f control rods to restore Tavg within limits.

IF Tavg is outside limits and can NOT be controlled. THEN trip the reactor and go to E-O.

REACTOR TRIP OR SAFETY INJECTION.

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REV: 14 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 6 of 16 STP ACTION/EXPECTED RESPONSE lRESPONSE NOT OBTAINEDl NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3) 5 Check PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

431K in MANUAL

Manual control of heaters and sprays IF PRZR pressure can NOT be controlled manually. THEN refer to AP-PRZR.l. ABNORMAL PRESSURIZER PRESSURE.

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REV: 14 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 7 of 16 ACTION/EXPECTED RESPONSE STEP lRESPONSE NOT OBTAINED 6 Check PRZR Level:

a. Level - GREATER THAN 13% a. Perform the following:

1) Place letdown isolation valve AOV-427 switch to CLOSE.

2) Place letdown orifice valve switches to CLOSE CAOV-200A.

AOV-200B. and AOV-202).

3) Close excess letdown isolation valve. AOV-310.

4) Ensure PRZR heaters off.

5) Close letdown isolation AOV-371 WHILE adjusting charging pump speed to maintain:

o RCP labyrinth seal D/P between 15 inches and 80 inches o PRZR level at program

6) WHEN PRZR level greater than 13%. THEN restore letdown.

(Refer to ATT-9.0, ATTACHMENT LETDOWN)

b. Level - TRENDING TO PROGRAM IN b. Perform the following:

AUTO CONTROL

1) Place affected charging pumps in MANUAL

2) Adjust charging pump speed to restore PRZR level to program.

IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1. REACTOR COOLANT LEAK.

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REV: 14 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED

. PAGE 8 of 16 ACTION/EXPECTED RESPONSE IRESPONSE NOT OBTAINED 7 Check MFW System:

a. MEW pumps - BOTH RUNNING a. Perform the following:

1) Verify one MEW pump running.

IF NOT. THEN establish sufficient AEW flow to maintain S/G levels

. MDAFW pump(s)

TDAFW pump

2) Go to Step 8.

b. Close one MEW pump discharge valve

c. Stop selected MEW pump

EOP: TILE, REV: 14 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 9 of 16 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

* * * * * * * * * * * * * * * *

A* * * * * * * * * * * * * * * * * * * * * *

CAUTION IF AT ANY TIME IT IS SUSPECTED THAT THE REACTOR IS SUBCRITICAL. THEN MANUALLY TRIP THE REACTOR.

NOTE: o With PRZR pressure controller 431K in manual. PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3) o Transition to E-O is NOT required if the reactor trip breakers are opened in the following step.

8 Establish Stable Plant Conditions:

a. NIS power ranges - LESS THAN 2% a. Return to Step 2.

b. Place rods in MANUAL

c. Check reactor power - GREATER c. IF the reactor is subcritical, THAN 1% THEN perform the following:

1) Shut down the reactor using manual trip pushbutton.

2) Go to Step 8e.

d. Maintain reactor power between 1% and 2%

e. PRZR pressure - BETWEEN e. Control PRZR pressure between 2220 PSIG AND 2260 PSIG 2220 psig and 2260 psig by one of the following:

. 431K in AUTO

431K in MANUAL

Manual control of heaters and spray

f. RCS Tavg - GREATER THAN 545 0F f. Control dumping steam to control Tavg. IF cooldown continues.

THEN close both MSIVs.

IF MSIVs closed AND Tavg still decreasing, THEN trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

ACTI~ON/XETE RESPONSE I CAUTION IF ANY S/G LEVEL ABOVE 52%. THEN AEW FLOW MAY BE THROTTLED IMMEDIATELY TO PREVENT S/G ISOLATION.

NOTE: Maintaining reactor power less than 2% is within the capacity of MDAFW pumps.

9 Check S/G Feed Flow Status:

a. Manually start both MDAFW pumps

b. Verify MDAFW pump flow - b. Perform the following:

SUFFICIENT FLOW TO MAINTAIN S/G LEVELS 1) Establish MEW flow using MEW regulating valve bypass valves.

IF MEW NOT available. THEN perform the following: I a) Manually start TDAFW pump and establish flow. I b) Adjust feed flow to restore SIG level to 52%. I c) Go to Step 9c. I

2) Adjust feed flow to restore S/G level to 52%.

3) Go to Step 11.

c. Verify MEW flow control valves - c. Place A and B MEW regulating and CLOSED bypass valve controllers in manual at 0% demand.

MFW regulating valves

MFW bypass valves This Step continued on the next page.

(Step 9 continued from previous page)

d. Close MEW pump discharge valves

MOV-3977, A MFW pump

MOV-3976, B MFW pump

e. Stop any running MEW pump

f. Close MEW pump recirc valves by placing BOTH MEPs in PULL STOP.

g. Place A and B MEW regulating and bypass valve controllers in manual at 0% demand.

h. Adjust AFW pump flow to restore S/G level to 52%.

10 Verify TDAFW Pump Aligned For AUTO Start:

a. Any MDAFW pump - AVAILABLE I a. Verify TDAFW pump operating to maintain required S/G level and go to Step 12.

b. Verify AMSAC TRIPPED status l b. Reset AMSAC. I light - EXTINGUISHED

c. Verify both S/G levels - GREATER c. Continue with Step 12. WHEN S/G THAN 17% 1 level greater than 17%, THEN do Steps lOd. e and 11.

d. Verify Bus 11A and Bus 11B - AT d. Perform the following: I LEAST ONE ENERGIZED

1) IF TDAFW pump NOT required to maintain S/G level. THEN pull stop TDAFW pump steam supply valves:

MOV-3504A

MOV-3505A I

2) Go to Step 11. I

e. Verify the following:

1) TDAFW pump - OFF I 1) Perform the following: I a) IF TDAFW pump required to maintain S/G level. THEN go to Step 12.

b) Stop TDAFW pump. I

2) TDAFW pump steam supply valve 2) Place TDAFW pump steam supply l switches in AUTO I valve switches in AUTO. I

3) Verify TDAFW flow control 3) Open TDAFW flow control valves - OPEN. DEMAND AT 0 I valves.

AOV-4297

AOV-4298

STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl 11 Establish Normal AFW Pump Shutdown Alignment:

a. Place AFW bypass switches to DEF

b. Verify the following: b. Continue with Step 12. WHEN conditions met. THEN do Steps o Both S/G levels - STABLE OR lic through d.

INCREASING o Total AEW flow - LESS THAN 200 GPM

c. Close MDAFW pump discharge valves

MOV-4007

. MOV-4008

d. Adjust AFW bypass valves to control SIG levels at 52%

AOV-4480

. AOV-4481

12 Establish Normal Shutdown Alignment:

a. Check condenser - AVAILABLE a. Dispatch AO to perform ATT-17.1.

ATTACHMENT SD-2.

b. Perform the following:

o Open generator disconnects

. 1G13A71

9X13A73 o Place voltage regulator to OFF o Open turbine drain valves o Rotate reheater steam supply controller cam to close valves o Place reheater dump valve switches to HAND o Stop all but one condensate pump (Refer to T-5F.

STARTING OR STOPPING THE CONDENSATE PUMPS)

c. Verify Bus 11A and Bus 11B c. IF either bus NOT energized, energized - BOTH BUSSES GREATER THEN refer to 0-6.9.2.

THAN 4 KV ESTABLISHING AND/OR TRANSFERRING OFFSITE POWER TO BUS 12A/

BUS 12B.

d. Dispatch AO to perform ATT-17.0.

ATTACHMENT SD-1

13 Establish Control Systems In 13 Establish Control Systems In Auto:

a. Verify 431K in AUTO a. Place 431K in AUT(). if desired.

b. Verify PRZR spray valves in AUTO b. Place PRZR spray iialves in AUTO.

if desired.

c. Verify one charging pump in AUTO c. Place one charginjg pump in AUTO.

if desired.

d. Verify PRZR heaters restored: d. Restore PRZR heat4ars. if desired.

o PRZR proportional heaters breaker - CLOSED o PRZR backup heaters breaker -

RESET. IN AUTO 14 Evaluate MCB Annunciator Status (Refer to AR Procedures) 15 Notify RP To Obtain Primary Samples Required By ITS LCO 3.4.16 (Load Reduction > 15%

In One Hour)

NOTE: Refer to 0-9.3. NRC IMMEDIATE NOTIFICATION, for reporting requirements.

16 Notify Higher Supervision

ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED STE 17 Establish Desired Plant Conditions:

a. Reactor shutdown - DESIRED a. IF turbine is to be restored to service. THEN maintain reactor critical and refer to 0-1.2.

PLANT STARTUP FROM HOT SHUTDOWN TO FULL LOAD.

b. Refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN

-END-

AP-TURB.1 APPENDIX LIST TITLE

1) ATTACHMENT SD-1 (ATT-17.0)

2) ATTACHMENT SD-2 (ATT-17.1)

3) ATTACHMENT LETDOWN (ATT-9.0)

EOP: TITLE:

REV: 21 U-TURB.2 TURBINE LOAD REJECTION PAGE 1 of 12 GINNA STATION CONTROLLED COPY NUMBER Z3 RESPONSIBLO MANAGER EFFE-/C0TIV DA EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

TIRE:

EOP:

KP-TURB.2 TURBINE LOAD REJECTION REV:

A 21 PAGE 2 of 12 A. PURPOSE - This procedure provides the guidance necessary to control the plant during a transient resulting from an unanticipated turbine/secondary plant load decrease.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. N/A

2. SYMPTOMS - The symptoms of TURBINE LOAD REJECTION are;

a. Unexplained decrease in main generator output, lit, or

b. Annunciator F-10, PRESSURIZER LO PRESS 2205 PSI, lit, or c.- Annunciator F-15, RCS TAVG DEV 40 F, lit, or

d. Annunciator F-30, OPAT TURBINE RUNBACK, lit, or

e. Annunciator F-31, OTAT TURBINE RUNBACK, lit, or

f. Annunciator G-15, STEAM DUMP ARMED, lit, or

g. Annunciator I-30, TURBINE VALVES CHANNEL ALERT, lit, or

h. Annunciator L-27, 34 KV BREAKER TRIP, lit.

EOP TITLE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION

. PAGE 3 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED CAUTION ANY AT RUNBACK SIGNAL WILL BLOCK AUTO AND MANUAL OUT MOTION OF ROD CONTROL SYSTEM.

NOTE: The thumb rule for initial boron addition is -2 gal/% load reduction.

1 Monitor RCS Tavg Verify control rods responding in AUTO. IF NOT. THEN place rods to o Tavg - GREATER THAN 5450F MANUAL and adjust rods to restore Tavg within limits.

o Tavg - LESS THAN 566 0F IF Tavg is outside limits AND can NOT be controlled, THEN trip the reactor and go to E-0. REACTOR TRIP OR SAFETY INJECTION.

2 Check Steam Dump Status: IF steam dump required but NOT operating. THEN perform the o Annunciator G-15. STEAM DUMP following:

ARMED - LIT

a. Place STEAM DUMP MODE SELECTOR o Steam dump operating properly in Switch to MANUAL.

AUTO

b. Place steam dump controller.

HC-484. to MANUAL.

c.Operate steam dump valves manually as necessary.

. EOP: TITLE:

I REV: 21 AP-TURB.2 TURBINE LOAD REJECTION PAGE 4 of 12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3 Verify Tavg - TRENDING TO TREF Place control rods to MANUAL and adjust control rods to restore Tavg to Tref.

NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3)

4 Monitor PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

. 431K in MANUAL

. Manual control of PRZR heaters and sprays IF PRZR pressure can NOT be controlled manually. THEN refer to AP-PRZR.1, ABNORMAL PRESSURIZER PRESSURE.

5 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected S/G(s) MEW regulating valve in MANUAL

b. Restore S/G level to 52%

IF S/G level can NOT be controlled manually. THEN refer to AP-FW.1, ABNORMAL MAIN FEEDWATER FLOW.

EOP: TITLE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION

. . PAGE 5 of 12.

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

6 Monitor PRZR Level - TRENDING Perform the following:

TO PROGRAM IN AUTO CONTROL

a. Place affected charging pumps in MANUAL

b. Adjust charging pump speed to restore PRZR level to program IF PRZR level can NOT be controlled manually, THEN refer to AP-RCS.1.

REACTOR COOLANT LEAK.

7 Check Turbine Runback Criteria:

a. Any AT annunciator - LIT a. Go to Step 8.

F-30. OPAT TURBINE RUNBACK

F-31, OTAT TURBINE RUNBACK

b. AT runback occurring as required b. Place EH in MANUAL and reduce turbine load by 5% RTP every 30 seconds.

8 Check Turbine Power - STABLE Determine cause of continued power reduction and stabilize load if

. Setter possible.

. Control valve position

. Generator load IF a loss of condenser vacuum is

PBACK (PPCS Point ID PBACKA or indicated. THEN go to AP-TURB.4, PBACKB) I LOSS OF CONDENSER VACUUM.

EOP: TITLE: REV: 21 AP-TURB.2 TURBINE LOAD REJECTION PAGE 6 of 12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 9 Check Main Generator Load - IF load can NOT be stabilized above GREATER THAN 15 MW 15 MW. THEN trip turbine and go to AP-TURB.1. TURBINE TRIP WITHOUT RX TRIP REQUIRED, Step 1.

EOP: TITLE:

REV: 21 AP-TURB. 2 TURBINE LOAD REJECTION PAGE 7 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3) 10 Establish Stable Plant Conditions:

a. Tavg - TRENDING TO TREE a. IF Tavg greater than Tref, THEN restore Tavg to Tref by one or more of the following:

Insert control rods

RCS boration IF Tavg less than Tref. THEN restore Tavg to Tref by one or more of the following:

. Withdraw control rods

Reduce Turbine Load

Dilution of RCS

b. PRZR pressure - TRENDING TO b. Control PRZR pressure by one of 2235 PSIG IN AUTO the following:

431K in MANUAL

Manual control of PRZR heaters and sprays IF pressure can NOT be controlled manually, THEN refer to AP-PRZR.1, ABNORMAL PRESSURIZER PRESSURE.

c. PRZR level - TRENDING TO PROGRAM c. Perform the following:

IN AUTO CONTROL

1) Place affected charging pumps in MANUAL

2) Adjust charging pump speed to restore PRZR level to program IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1. REACTOR-COOLANT LEAK.

This Step continued on the next page.

EOP: TITLE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION PAGE 8 of 12 (Step 10 continued from previous page)

d. MFW regulating valves - d. Perform the following:

RESTORING S/G LEVEL TO 52% IN AUTO 1) Place affected S/G(s) MFW regulating valve in MANUAL

2) Restore S/G level to 52%

IF S/G level can NOT be controlled manually. THEN refer to AP-FW.1. ABNORMAL MAIN FEEDWATER FLOW.

e. Steam dump valves - CLOSED e. Perform the following:

1) Ensure proper operation of steam dump control system.

2) If either of the following occurs, THEN refer to AP-TURB.4, LOSS OF CONDENSER VACUUM o Condensate Temperature greater than 100'F (PPCS Point ID T2053)

-OR-o Condenser vacuum degrading (PPCS top menu condenser backpressure)

EOP: TITLE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION PAGE 9 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 11 Verify Cause Of Turbine Load Attempt to determine and correct Rejection - IDENTIFIED cause of turbine load rejection.

EOP: TITLE: 1 REV: 21 AP-TURB. 2 TURBINE LOAD REJECTION PAGE 10 of 12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 12 Establish Normal Plant Conditions:

a. Verify 431K in AUTO a. Place 431K in AUTO, if desired.

b. Verify PRZR spray valves in AUTO b. Place PRZR spray valves in AUTO, if desired.

c. Verify PRZR heaters restored: c. Restore PRZR heaters, if desired.

o PRZR proportional heaters breaker - CLOSED o PRZR backup heaters breaker -

RESET, IN AUTO

d. Verify one charging pump in AUTO d. Place one charging pump in AUTO.

if desired.

e. Verify MEW regulating valves in e. Place MEW regulating valves in AUTO AUTO, if desired.

f. Restore EH controls

1) Place in OP PAN, IMP OUT

2) Place load rate thumbwheel to 10%/hour

3) Match setter and reference

g. Verify steam dump controller, HC-484, in AUTO at 1005 psig

h. Verify annunciator G-15, STEAM h. WHEN Tavg within 5 0F of Tref, DUMP ARMED - EXTINGUISHED THEN perform the following:

1) Ensure steam dump valves closed.

2) Reset steam dump.

i. Verify Rods in AUTO i. Place Rods in AUTO, if desired.

This Step continued on the next page.

EOP: TIRE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION P

. PAGE 11 of 12 ACTION/EXPECTED RESPONSE SP lRESPONSE NOT OBTAINED I (Step 12 continued from previous page)

j. Rod insertion limit alarms - j. IF any AT channel failed. THEN EXTINGUISHED determine actual RIL from the COLR. IF alarm valid. THEN borate as necessary and withdraw control rods to clear insertion limit alarms (refer to affected rod bank alarm response procedures if necessary).

k. NIS PR AI - WITHIN +/- 5% OF k. Perform one or more of the TARGET VALUE following to restore AI to within limits:

a Borate RCS

. Dilute RCS

. Restore control rods to desired position 13 Check If PRZR Boron Should Be Mixed:

a. Boration performed for load a. Go to Step 14.

rejection I

b. Place PRZR backup heaters switch to ON 14 Evaluate MCB Annunciator Status (Refer to AR Procedures)

EOP: TITLE:

REV: 21 AP-TURB.2 TURBINE LOAD REJECTION PAGE 12 of 12 STEP ACTION/EXPECTED RESPONSEREPNE OT BAIE NOTE: Refer to 0-9.3. NRC IMMEDIATE NOTIFICATION, for reporting requirements.

15 Notify Higher Supervision 16 IF Load Was Reduced More Than 15% In One Hour, THEN Notify RP To Obtain Primary Samples Required By ITS LCO 3.4.16.

17 Return To Procedure Or Guidance In Effect

-END -

EOP: TITLE:RE :2

.,P-TURB.2 TURBINE LOAD REJECTION PAGE 1 of 1 AP-TURB.2 APPENDIX LIST TITLE

1) ATTACHMENT EXCESS L/D (ATT-9.1)

EOP: TITLE: REV: 18 P-TURB.4 LOSS OF CONDENSER VACUUM PAGE 1 of 12 GINNA STATION CONTROLLED COPY NUMBER __3 RESPONSIBLE 3 NAGER EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EDP: TITLE:

REV: 18

,P-TURB.4 LOSS OF CONDENSER VACUUM PAGE 2 of 12 A. PURPOSE - This procedure provides the necessary actions to control the plant with decreasing condenser vacuum.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. AP-TURB.2, TURBINE LOAD REJECTION if a loss of vacuum is indicated.

2. SYMPTOMS - The symptoms of LOSS OF CONDENSER VACUUM are;

a. Low or decreasing condenser vacuum, or

b. Annunciator H-7, CONDENSER HI PRESSURE 25.5" HG, lit, or

c. PPCS high condenser backpressure alarm, or

d. Unexplained decreasing generator output, or

e. Annunciator I-18, CONDENSER EXP JOINT A LO LEVEL, or

f. Annunciator I-19, CONDENSER EXP JOINT B LO LEVEL.

EOP: TITLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM PAGE 3 of.12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1 Check Condenser Circulating IF a loss of circulating water has Water System occurred, THEN go to AP-CW.1, LOSS OF A CIRC WATER PUMP.

o CW pump discharge valves - BOTH OPEN o CW pumps - BOTH RUNNING

EOP: TITLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM l . PAGE 4 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED CAUTION o TURBINE LOAD DECREASE SHOULD BE COMPLETED AS QUICKLY AS POSSIBLE WHILE MINIMIZING THE AMOUNT OF STEAM DUMP OPERATION.

o EXCESSIVE BACK PRESSURE MAY RESULT IN SEVERE TURBINE BLADE VIBRATION.

MINIMIZE TIME OUTSIDE THE SATISFACTORY OPERATION REGION.

2 Check Condenser Indications:

a. Turbine back pressure - EACH a. IF back pressure is in the DO CONDENSER WITHIN THE NOT OPERATE region for SATISFACTORY OPERATING REGION OF > 5 minutes, THEN perform the FIG-13.0. FIGURE BACK PRESSURE following:

o IF power > P-9, THEN trip the reactor and go to E-O, REACTOR TRIP OR SAFETY INJECTION.

o IF power < P-9. THEN trip the turbine and go to AP-TURB.1.

TURBINE TRIP WITHOUT RX TRIP REQUIRED.

IF in the AVOID region. THEN adjust turbine load to return to the SATISFACTORY OPERATING REGION.

b. Condenser vacuum - STABLE OR b. WHILE continuing with this IMPROVING procedure. decrease turbine load to stabilize condenser vacuum.

(Refer to AP-TURB.5. RAPID LOAD REDUCTION)

IF condenser vacuum can NOT be stabilized, THEN perform the following:

1) Decrease turbine load to less than 15 MW.

2) Trip turbine.

3) Go to AP-TURB.1, TURBINE TRIP WITHOUT RX TRIP REQUIRED.

EOP: TITLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM

. ~PAGE 5 of 12.

ATO/XPECTED RESPONSE RSOS NTOTIE 3 Dispatch AO To Perform Local Actions To Attempt To Restore Condenser Vacuum (Refer to ATT-6.0, ATTACHMENT COND VACUUM)

EOP: TITLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM V. PAGE 6 of 12 ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED STP CAUTION CLOSELY MONITOR FEED PUMP SUCTION PRESSURE WHEN ADJUSTING CONDENSATE COOLING VALVES.

4 Check Condensate Temperature

- GREATER THAN 1000F (PPCS point ID T2053)

a. IF S/G blowdowne are aligned to the hotwello. THEN place S/G blowdown and sample valve master isolation switch to CLOSE.

b. Check condensate cooler - b. Place condensate cooler in INSERVICE I service per T-29B WHILE continuing with Step 5. WHEN condensate cooler is in service.

THEN do Step 4c.

c. Perform the following to cool air ejector cooling medium:

1) Place generator hydrogen temperature controller in MANUAL at 50%.

2) Dispatch AO to throttle closed V-3928. condensate cooler bypass valve to control condensate temperature.

3) Adjust hydrogen temperature controller and condensate cooler manual bypass valve to establish maximum condensate cooling.

4) Check hydrogen cooler AP less 4) Place generator hydrogen than 5.2 psid (back of MCB). I temperature controller in manual to control AP less than 5.2 psid.

5) Check condensate cooler AP 5) Adjust condensate cooler less than 10.0 psid (back of bypass valve to less than MCB). 10.0 psid.

EOP: TITLE:

REV: 1 8 AP-TURB.4 LOSS OF CONDENSER VACUUM PAGE 7 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 5 Dispatch AO To Check IF condenser inleakage is detected.

Condenser For Air Inleakage - THEN isolate if possible.

NO INLEAKAGE DETECTED a Vacuum breaker

Condenser boot area

Condenser areas

Blowdown Tank area 6 Determine If Load Reduction Can Be Stopped:

a. Monitor condenser indications: a. Return to Step 2.

o Condenser back pressure -

EACH CONDENSER WITHIN THE SATISFACTORY OPERATING REGION OF FIG-13.0. FIGURE BACK PRESSURE o Vacuum - STABLE OR IMPROVING

b. Stop the load reduction

EOP: TITE: REV: 18 MP-TUBA LOSS OF CONDENSER VACUUM K B PAGE 8 of 12 NOTE: With PRZR pressure controller 431K in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3)

7 Establish Stable Plant Conditions:

a. Tavg - TRENDING TO TREE a. IF Tavg greater than Tref, THEN restore Tavg to Tref by one or more of the following:

Insert control rods

RCS boration IF Tavg less than Tref. THEN restore Tavg to Tref by one or more of the following:

Withdraw control rods

Reduce turbine load

Dilution of RCS

b. PRZR pressure - TRENDING TO b. Control PRZR pressure by one of 2235 PSIG IN AUTO the following:

431K in MANUAL

Manual control of PRZR heaters and sprays IF pressure can NOT be controlled manually, THEN refer to AP-PRZR.1. ABNORMAL PRESSURIZER PRESSURE.

c. PRZR level - TRENDING TO PROGRAM c. Perform the following:

IN AUTO CONTROL

1) Place affected charging pumps in MANUAL

2) Adjust charging pump speed to restore PRZR level to program IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1. REACTOR COOLANT LEAK.

This Step continued on the next page.

EOP: TITLE:

REV: 18 1

AP-TURB.4 LOSS OF CONDENSER VACUUM U. PAGE 9 of 12 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED (Step 7 continued from previous page)

d. HFW regulating valves - d. Perform the following:

RESTORING S/G LEVEL TO 52% IN AUTO 1) Place affected S/G(s) MFW regulating valve in MANUAL

2) Restore S/G level to 52%

IF S/G level can NOT be controlled manually. THEN refer to AP-FW.l. ABNORMAL MAIN FEEDWATER FLOW.

K>

EOP: TIRLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM

. PAGE 10 of 12 CAUTION IF CONDENSATE BOOSTER PUMP "A" IS OPERATING IN PARALLEL WITH EITHER CONDENSATE BOOSTER PUMP "B" RO "C". THEN CONDENSATE BOOSTER PUMP "B" OR "C" SHOULD BE SECURED FIRST IN ORDER TO MINIMIZE OPERATING AT MINIMUM FLOW CONDITIONS.

8 Establish Normal Plant Operation:

a. Check condenser indications a. Return to Step 2.

o Condenser pressure - EACH CONDENSER WITHIN THE SATISFACTORY OPERATING REGION OF FIG-13.0. FIGURE BACK PRESSURE o Vacuum - STABLE OR IMPROVING

b. Restore EH controls

1) Place in OP PAN. IMP OUT

2) Place load rate thumbwheel to 10%/hour

3) Match setter and reference

c. Verify annunciator G-15, STEAM c. WHEN Tavg within 5 0F of Tref.

DUMP ARMED - EXTINGUISHED THEN perform the following:

1) Ensure steam dump valves closed.

2) Reset steam dump.

d. Verify one charging pump in AUTO d. Place one charging pump in AUTO.

if desired.

e. Verify Rods in AUTO e. Place rods AUTO, if desired.

f. Verify 431K in AUTO f. Place 431K in AUTO, if desired.

This Step continued on the next page.

(Step 8 continued from previous page)

g. Verify PRZR spray valves in AUTO g. Place PRZR spray valves in AUTO.

if desired.

h. Verify PRZR heaters restored: h. Restore PRZR heaters, if desired.

o PRZR proportional heaters breaker - CLOSED o PRZR backup heaters breaker -

RESET. IN AUTO

i. Verify MFW regulating valves in i. Place MFW regulating valves in AUTO AUTO, if desired.

j. Dispatch AO to remove priming ejector from service if desired

k. Verify S/G blowdown and sample k. Perform the following:

valve master isolation switch in REMOTE 1) Dispatch AO to locally isolate blowdown.

2) WHEN blowdown locally isolated. THEN place blowdown and sample valve master switch to REMOTE.

3) Direct AO to restore blowdown flow (Refer to T-14N, BLOWDOWN SYSTEM FLOW CHANGES).

EOP: TITLE:

REV: 18 AP-TURB.4 LOSS OF CONDENSER VACUUM

. . PAGE 12 of 12 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl 9 Evaluate MCB Annunciator Status (Refer to AR Procedures) 10 Perform Notifications:

a. Notify higher supervision

b. Request Turbine System Engineer evaluate effect of back pressure transient on the turbine.

11 IF Load Was Reduced More Than 15% In One Hour, THEN Notify RP To Obtain Primary Samples Required By ITS LCO 3.4.16.

12 Return To Procedure Or Guidance In Effect

-END-

EOP: TITLE:

REV: 18 P-TURB.4 LOSS OF CONDENSER VACUUM PAGE 1 of 1 AP-TURB.4 APPENDIX LIST TITLE

1) FIGURE BACK PRESSURE (FIG-13.0)

2) ATTACHMENT COND VACUUM (ATT-6.0)

EOP: TITLE:

REV: 8 P-TURB.5 RAPID LOAD REDUCTION PAGE 1 of 21 GINNA STATION CONTROLLED COPY NUMBER ____3 RESPONSIBL X AGER

/EF-/FEC-TI ODT EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 8 P-TURB.5 RAPID LOAD REDUCTION PAGE 2 of 21 A. PURPOSE - This procedure provides the necessary actions when turbine load is to be reduced 2 1%/minute.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from

a. The SS has determined that a load reduction rate 2 1%/min is desired.

b. AR-J-4, GENERATOR ISO PHASE BUS COOLING SYS, if fan and SW conditions require a load reduction, or

c. AR-J-12, GENERATOR MAIN TRANSFORMER ANNUNCIATOR, if top oil temperature is outside limits, or winding temperature is outside limits, or cooler/fan combination requires load reduction, or

d. AR-L-21, MAIN FEEDWATER PUMP OIL SUMP HI-LO LEVEL, if SW in-leakage to MFP oil sump is apparent, or

e. AR-VOLT-REG-3, LOSS OF BOTH FIRING CIRCUITS, if generator did not trip.

SP ACTION/EXPECTED RESPONSE l lRESPONSE NOT OBTAINED CAUTION IF MAIN FEEDWATER FLOW SHOULD DECREASE TO 25% OF FULL POWER VALUE

(.825 E+6 LBM/HR) PRIOR TO THE AMSAC SYSTEM AUTOMATICALLY BLOCKING, THEN A TURBINE TRIP AND AUX FEED PUMPS START COULD RESULT.

NOTE: o IF the turbine is to be taken offline, THEN transfer of 4160V loads may be performed at any time. Refer to ATT-23.0. ATTACHMENT TRANSFER 4160V LOADS.

o A maximum continuous load reduction rate of > 5%/min should not be used unless directed by the Shift Supervisor.

1 Initiate Load Reduction

a. Verify rods in AUTO a. Perform the following:

1) Place rods to MANUAL.

2) Adjust Rods to match Tavg and Tref.

b. Reduce turbine load in Auto as b. IF Auto Control is inoperable, follows: THEN reduce turbine load in manual at the desired rate.

1) Place Turbine EH Control in OPER PAN.. IMP PRESS IN. if desired.

2) Select desired rate on thumbwheel

3) Reduce the setter to the desired load

4) Depress the GO button

c. Initiate boration at 2 gal/%

load reduction.

d. Place PRZR backup heaters switch to ON

EOP: TITLE:

REV: 8 1

K AP-TURB.5 RAPID LOAD REDUCTION

.PAGE 4 of 21 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl CAUTION EXTREME AND RAPID ROD MOTION TO MITIGATE TAVG SWINGS MAY RESULT IN LARGE POWER EXCURSIONS AND SHOULD BE AVOIDED.

2 Monitor RCS Tavg Verify control rods responding in AUTO. IF NOT, THEN place rods to o Tavg - GREATER THAN 545 0F MANUAL and adjust rods to restore Tavg within limits.

o Tavg - LESS THAN 566 0F IF Tavg is outside limits AND can NOT be controlled. THEN trip the reactor and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

NOTE: It is permissible to operate RCPs for limited periods without seal injection, provided CCW is being supplied to the thermal barriers.

3 Check IA Available To CNMT Control PRZR level and pressure as follows:

o IA pressure - > 60 psig o Adjust load reduction rate o Instr Air to CNMT Isol Valve.

AOV-5392 - OPEN o Ensure control rods are moving to control Tavg o IF CCW supplied to BOTH RCP thermal barrier heat exchangers.

THEN start/stop charging pumps as necessary to control PRZR level o Operate proportional and backup heaters to control PRZR pressure

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 5 of 21.

ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED NOTE: With PRZR pressure controller in manual, PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3)

4 Monitor PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

431K in MANUAL

. Manual control of PRZR heaters and sprays IF PRZR pressure can NOT be controlled manually, THEN refer to AP-PRZR.1, ABNORMAL PRESSURIZER PRESSURE.

5 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected S/G(s) MEW regulating valve in MANUAL

b. Restore S/G level to 52%

IF S/G level can NOT be controlled manually, THEN refer to AP-EW.1.

ABNORMAL MAIN FEEDWATER FLOW.

6 Monitor PRZR Level - TRENDING Perform the following:

TO PROGRAM IN AUTO CONTROL

a. Place affected charging pumps in MANUAL.

b. Adjust charging pump speed to restore PRZR level to program.

IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1, REACTOR COOLANT LEAK.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION V.. .PAGE 6 of 21 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

7 Check Steam Dump Status: IF steam dump required but NOT operating, THEN perform the o Annunciator G-15. STEAM DUMP following:

ARMED - LIT

a. Place STEAM DUMP MODE SELECTOR o Steam dump operating properly in Switch to MANUAL. I auto

b. Place steam dump controller, HC-484. to MANUAL. I

c. Operate steam dump valves as necessary. I 8 Adjust Boric Acid Addition Rate As Necessary To (refer to OPG-REACTIVITY-CALC):

o Maintain or return AElux to the target band o Maintain rods above the insertion limit o Match Tavg and Tref o Compensate for Xenon

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION h PAGE 7 of 21 SP ACTION/EXPECTED RESPONSE l lRESPONSE NOT OBTAINEDl CAUTION IF CONDENSATE BOOSTER PUMP "A" IS OPERATING IN PARALLEL WITH EITHER CONDENSATE BOOSTER PUMP "B" OR "C". THEN CONDENSATE BOOSTER PUMP "B" OR toCH SHOULD BE SECURED FIRST IN ORDER TO MINIMIZE OPERATING AT MINIMUM FLOW CONDITIONS.

NOTE: The load reduction should not be delayed to perform the remaining steps.

9 Check If Condensate Booster Pumps Should Be Secured

a. Power < 65% OR Trim Valve a. Go to Step 16.

V-9508G indicates > 80% open

b. Place the auto condensate booster pump to the trip position

c. Stop one condensate booster pump

d. WHEN condensate system pressures stabilize. THEN stop the remaining condensate booster pump

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. PAGE 8 of 21 STP ACTION/EXPECTED RESPONSE lRESPONSE NOT OBTAINEDl 10 Check If One MFW Pump Should Be Secured

a. Power < 50% a. Go to Step 16.

b. Verify at least one MEWP Seal b. Notify AO to start one MEWP Seal Booster pump in service Booster pump

c. Two MEW Pumps running c. Go to Step 11.

d. Close discharge valve for the pump to be secured

MEW Pump A - MOV-3977

MEW Pump B - MOV-3976

e. Stop the desired MEW Pump

f. Close the secured MEW pump recirc valve by placing the control switch in pull stop

g. Close the service water block valve to the secured MEW pump oil cooler

MEW Pump A - V-4701

MEW Pump B - V-4702 11 Verify Trim Valves Place controller in manual and Controlling Condensate System control pressure between Pressure in Auto 300-375 psig.

(300-375 PSIG)

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. . PAGE 9 of 21.

TE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 12 Check ANSAC System Status

a. Power < 35% (-150 psig first a. Go to Step 16.

stage pressure)

b. Verify AMSAC Auto Block Status b. Place AMSAC Manual Block switch Light is ON to the BLOCK position 13 Check Heater Drain Tank Pump Status

a. Generator load < 175 MWe a. Go to Step 16.

b. Stop one Heater Drain Tank Pump

c. WHEN Heater Drain Tank level control is stable, THEN stop the second Heater Drain Tank Pump 14 Check MFW Regulating Bypass Vlv Status

a. Power < 30% a. Go to Step 16.

b. MFW Regulating Bypass Vlvs in b. Perform the following:

AUTO

1) Slowly open the MEW

HCV-480 Regulating Bypass Vlvs while a HCV-481 verifying the associated MEW Regulating Vlv compensates by closing slightly

2) Place MEW Regulating Bypass Vlvs in AUTO

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 10 of 21 STP ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINEDl 15 Align Systems For Low Power Operation

a. Power at 30% a. Go to Step 16.

b. Place AOV-3959, CNDST Bypass Vlv to CLOSE

c. Place LC-107, Hotwell Level Control, to MANUAL at 50%

d. Generator load < 100 MWe d. Go to Step 16.

e. Open turbine drain valves 16 Evaluate Plant Status

a. IF load was reduced more than 15% RTP in one hour, THEN notify RP to obtain primary samples required by ITS LCO 3.4.16

b. Power stable at desired level b. IF power > 20% and further reduction is required. THEN continue load reduction and return to Step 9.

IF power < 20% and further reduction is required. THEN go to Step 23.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 11 of 21 ESPNSE ACTIN/EPECED 1 ESPNSENOTOBTAINED I NOTE: With PRZR pressure controller 431K in manual. PORV-431C will not operate in the automatic mode. (Refer to TR 3.4.3) 17 Establish Stable Plant Conditions:

a. Tavg - TRENDING TO TREE a. IF Tavg greater than Tref, THEN restore Tavg to Tref by one or more of the following:

Insert control rode

RCS boration IF Tavg less than Tref. THEN restore Tavg to Tref by one or more of the following:

Withdraw control rode

Reduce turbine load

. Dilution of RCS

b. PRZR pressure - TRENDING TO b. Control PRZR pressure by one of 2235 PSIG IN AUTO the following:

431K in MANUAL

. Manual control of PRZR heaters and sprays IF PRZR pressure can NOT be controlled manually, THEN refer to AP-PRZR.1. ABNORMAL PRESSURIZER PRESSURE.

c. PRZR level - TRENDING TO PROGRAM c. Perform the following:

IN AUTO CONTROL

1) Place affected charging pumps in MANUAL.

2) Adjust charging pump speed to restore PRZR level to program.

IF PRZR level can NOT be controlled manually. THEN refer to AP-RCS.1. REACTOR COOLANT LEAK.

This Step continued on the next page.

ACTION/EXPECTED RESPONSE OBTAINE (Step 17 continued from previous page)

d. Rod insertion limit alarms - d. Borate and withdraw control rods EXTINGUISHED to clear insertion limit alarms (refer to affected rod bank alarm response procedures if necessary).

e. Check MFW regulating valves - e. Perform the following:

RESTORING SIG LEVEL TO 52% IN AUTO 1) Place affected S/G(s) MEW regulating valve in MANUAL

2) Restore S/G level to 52%

IF S/G level can NOT be controlled manually. THEN refer to AP-FW.1, ABNORMAL MAIN FEEDWATER FLOW.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 13 of 21 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 18 Establish Normal Plant Conditions:

a. Restore EH controls

1) Place in OP PAN. IMP OUT

2) Place load rate thumbwheel to 10%/hour

3) Match setter and reference

b. Verify steam dump controller.

HC-484. in AUTO at 1005 psig

c. Verify annunciator G-15, STEAM c. WHEN Tavg within 5 0F of Tref.

DUMP ARMED - EXTINGUISHED THEN perform the following:

1) Ensure steam dump valves closed.

2) Reset steam dump.

d. Verify Rods in AUTO d. Place Rods in AUTO if desired.

e. Verify 431K in AUTO e. Place 431K in AUTO, if desired.

f. Verify PRZR spray valves in AUTO f. Place PRZR spray valves in AUTO, if desired.

g. Ensure PRZR Heaters restored:

o PRZR proportional heater breaker - CLOSED o WHEN PRZR mixing complete, THEN place PRZR backup heater breaker to RESET. THEN AUTO

h. Verify one charging pump in AUTO h. Place one charging pump in AUTO, if desired.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. PAGE 14 of 21 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 19 Evaluate MCB Annunciator Status (Refer to AR Procedures)

NOTE: Refer to 0-9.3. NRC IMMEDIATE NOTIFICATION. for reporting requirements.

20 Notify Higher Supervision 21 Refer to 0-5.1, LOAD REDUCTIONS, for additional guidance 22 Return To Procedure Or Guidance In Effect 23 Transfer 4160V Auxiliary load from #11 Transformer (Refer to ATT-23.0, ATTACHMENT TRANSFER 4160V LOADS) 24 Check If Turbine Should Be Tripped

a. Check turbine load -

15 MW a. Return to Step 16. WHEN turbine load is

15 MW, THEN continue with Step 24b.

b. Trip the turbine

c. Check turbine stop valves - c. Direct an AO to locally trip the CLOSED I turbine by placing the red TRIP lever to TRIP (west end of turbine).

IF the turbine will NOT trip.

THEN close both MSIVs. I

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 15 of 21 25 Verify Proper Operation Of Steam Dump:

a. Verify annunciator G-15, STEAM a. Place steam dump mode selector DUMP ARMED - LIT switch to MANUAL.

b. Condenser steam dump operating b. IF steam dump NOT available, in AUTO THEN perform the following:

1) IF power is greater than 8%.

THEN ensure reactor trip and go to E-O. REACTOR TRIP OR SAFETY INJECTION.

2) Adjust S/G ARV setpoints to 1005 psig and verify proper operation.

c. Tavg - TRENDING TO PROGRAM c. IF temperature less than 5471F and decreasing. THEN perform the following:

1) Stop dumping steam

2) IF cooldown continues. THEN close both MSIVs.

IF temperature greater than 547 0F and increasing, THEN dump steam to stabilize and slowly decrease temperature to 547 F.

IF Tavg can NOT be controlled, THEN manually trip the reactor and go to E-O, REACTOR TRIP OR SAFETY INJECTION.

EOP: TITLE: lREV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. .. PAGE 16 of 21.

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 26 Reactor Is To Be Shutdown IF reactor is to be maintained (Consult Plant Staff If critical, THEN go to AP-TURB.1.

Necessary) TURBINE TRIP WITHOUT RX TRIP REQUIRED.

NOTE: Transition to E-0 is NOT required when the reactor trip breakers are opened in the following step.

27 Shutdown the Reactor

a. Place rods in MANUAL

b. Drive control rods until

1%

RTP.

c. Press reactor trip pushbutton.

d. Verify reactor trip breakers d. Dispatch AO to locally open open. reactor trip breakers.

e. Verify MRPI indicates all e. IF one or more control rods NOT control and shutdown rods on fully inserted, THEN perform the bottom following:

1) Place RMW mode selector switch to BORATE.

2) Adjust boric acid flow control valve. FCV-l1OA. for desired flowrate.

3) Set boric acid integrator to desired amount (650 gallons for each control rod not fully inserted).

4) Place RMW control to start and verify flow. IF flow can NOT be established. THEN refer to ER-CVCS.I. REACTOR MAKEUP CONTROL MALFUNCTION.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. PAGE 17 of 21 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED CAUTION IF ANY S/G LEVEL ABOVE 52%. THEN AFW FLOW MAY BE THROTTLED IMMEDIATELY TO PREVENT S/G ISOLATION.

28 Check SIG Feed Flow Status:

a. Manually start both MDAFW pumps

b. Verify MDAEW pump flow - b. Perform the following:

SUFFICIENT FLOW TO MAINTAIN S/G LEVELS 1) Establish MFW flow using MFW regulating valve bypass valves.

IF MEW NOT available. THEN perform the following:

a) Manually start TDAFW pump and establish flow. I b) Adjust feed flow to restore S/G level to 52%. I c) Go to Step 28c. I

2) Adjust feed flow to restore S/G to 52%.

3) Go to Step 29.

c. Verify MFW flow control valves - c. Place A and B MFW regulating and CLOSED bypass valve controllers in manual at 0% demand.

MFW regulating valves

MFW bypass valves

d. Close discharge valves for the MEP to be secured: I

MOV-3977. A MFW pump

. MOV-3976. B MFW pump This Step continued on the next page.

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION

. PAGE 18 of 21 ACTION/EXPECTED RESPONSE 1RESPONSE STEP NOT OBTAINED (Step 28 continued from previous page)

e. Stop the running MEW pump

f. Close the secured MEW pump recirc valve by placing the control switch in PULL STOP.

g. Place A and B MEW regulating and bypass valve controllers in manual at 0% demand

h. Adjust AEW flow to restore SI/G level to 52%

29 Establish Normal AFW Pump Shutdown Alignment:

a. Place AEW bypass switches to DEE

b. Close MDAFW pump discharge valves

. MOV-4007

MOV-4008

c. Adjust AEW bypass valves to control S/G levels at 52%

. AOV-4480

AOV-4481

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 19 of 21 STEP ACTION/EXPECTED RESPONSEREP SENT O AI D 30 Establish Normal Shutdown Alignment:

a. Check condenser - AVAILABLE a. Dispatch AO to perform ATT-17.1, ATTACHMENT SD-2.

b. Perform the following as necessary:

o Open generator disconnects

1G13A71

9X13A73 o Place voltage regulator to OFF o Open turbine drain valves o Rotate reheater steam supply controller cam to close valves o Place reheater dump valve switches to HAND o Stop all but one condensate pump (Refer to T-5F, STARTING OR STOPPING THE CONDENSATE PUMPS)

c. Verify Bus 11A and Bus 11B c. IF either bus NOT energized.

energized - BOTH BUSSES GREATER THEN refer to 0-6.9.2.

THAN 4 KV ESTABLISHING AND/OR TRANSFERRING OFFSITE POWER TO BUS 12A/BUS 12B.

d. Dispatch AO to perform ATT-17.0, ATTACHMENT SD-1

EOP: TIT:REV:8 AP-TURB.5 RAPID LOAD REDUCTION PAGE 20 of 21 ACTION/EXPECTED RESPONSE STP lRESPONSE NOT OBTAINEDI NOTE: Loss of forced air cooling may result in failure of NIS detectors.

31 Check If Source Range Detectors Should Be Energized:

a. Source range channels - a. Go to Step 31e.

DEENERGIZED

b. Check intermediate range flux - b. Continue with Step 32. WHEN EITHER CHANNEL LESS THAN flux is less than 10-10 amps on 10-10 AMPS any operable channel, THEN do Steps 31c. d and e.

c. Check the following: c. Continue with Step 32. WHEN either condition met, THEN do o Both intermediate range Steps 31d and e.

channels - LESS THAN 10-10 AMPS

-OR-o Greater than 20 minutes since reactor trip

d. Verify source range detectors - d. Manually energize source range ENERGIZED detectors by depressing P-6 permissive defeat pushbuttons (2 of 2).

IF source ranges can NOT be restored, THEN refer to ER-NIS.1, SR MALFUNCTION, and go to Step 32.

e. Transfer Rk-45 recorder to one source range and one intermediate range channel

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REV: 8 AP-TURB.5 RAPID LOAD REDUCTION l l . PAGE 21 of 21.

ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 32 Go to 0-2.1, NORMAL SHUTDOWN TO HOT SHUTDOWN

-END-

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REV: 8 FP-TURB.5 RAPID LOAD REDUCTION P

. ~PAGE 1 of 1 AP-TURB.5 APPENDIX LIST TITLE

1) ATTACHMENT TRANSFER 4160V LOADS (ATT-2 3.0)

2) ATTACHMENT SD-1 (ATT-17.0)

3) ATTACHMENT SD-2 (ATT-17.1)

ML051090405

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