ML042530535

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Emergency Operating Procedures
ML042530535
Person / Time
Site: Ginna Constellation icon.png
Issue date: 09/01/2004
From: Widay J
Constellation Energy Group
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
Download: ML042530535 (45)
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Text

1503 Lake Road Ontario, New York 14519-9364 585.771.3000 Constellation Energy R.E. Ginna Nuclear Power Plant, LLC September 1, 2004 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, JAW/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 ATT-16.1, Rev3 ATT Index ATT--17.0, Rev 17 AP-SW.1, Rev 20 ATT--17.1,Rev7 AP-SW.2, Rev 5 ATT-20.0, Rev 4 ATT-1 1.0, Rev 4 ATT-14.1, Rev 7

(. C (

NPSP0200 Ginna Nuclear Power Plant Wed 9/1/2004 12:47:02 pm E66429 PROCEDURE INDE) Page 1 of 2 INPUT PARAMETERS: TYPE. PRAP STATUS VALUE(S): EF. aU 5 YEARS ONLY:

PRAP ABNORMAL PROCEDURE rAuu .UcE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REV0EW ST AP-CCW.1 LEAKAGE INTO THE COMPONENT COOLUNG LOOP 017 06130/2004 06/26f2002 06126/2007 EF AP-CCW.2 LOSS OF CCW DURING POWER OPERATION 019 06830/2004 06/26t2002 06/26/2007 EF AP-CCW.3 LOSS OF CCW- PLANT SHUTDOWN 016 06/30/2004 06/26/2002 06/26/2007 EF AP-CR.1 CONTROL ROOM INACCESSIBIULY 020 06t30/2004 06126/2002 OM6282007 EF AP-CVCS.1 CVCS LEAK 014 06/30/2004 06/03/2002 06/03t2007 EF AP-CVCS.3 LOSS OF ALL CHARGING FLOW 004 08/26/2003 02/27/2004 02/27/2009 Er AP-CW.1 LOSS OF A CIRC WATER PUMP 011 06/26/2002 04/16/2003 04/16/2008 EF AP-ELEC.1 LOSS OF 12A AND/OR 12B BUSSES 027 06/30/2004 06/6/2002 06/26/2007 EF AP-ELEC2 SAFEGUARD BUSSES LOWVOLTAGE OR SYSTEM LOW FREQUENCY 011 06/10/2004 06/26/2002 06/26/2007 EF AP-ELEC.3 LOSS OF 12A AND/OR 12B TRANSFORMER (BELOW 350 F) 012 05/30/2003 06/26/2002 06/26/2007 EF AP-ELEC.13t15 LOSS OF BUS 13115 001 06/30/2004 09/24/2003 09/24/2008 EF AP-ELEC.14116 LOSS OF SAFEGUARDS BUS 14116 008 06/30/2004 06/26/2002 06/26/2007 EF AP-ELEC.17/18 LOSS OF SAFEGUARDS BUS 17/18 007 06/30/2004 06826/2002 06/26/2007 EF AP-FW.1 ABNORMAL MAIN FEEDWATER FLOW 016 06/30/2004 0682612002 06/26/2007 EF AP-IA.1 LOSS OF INSTRUMENT AIR 018 0661/2002 04/16/2003 04/16/2005 EF AP-PRZR.1 ABNORMAL PRESSURIZER PRESSURE 015 06/30/2004 06/26/2002 06/26/2007 EF AP-RCC.1 CONTINUOUS CONTROL ROD WITHDRAWALJNSERTION 009 06/30/2004 04/16/2003 04/16/2008 Ea AP-RCC.2 RCCIRPI MALFUNCTION 011 06/30/2004 2/120/51/2 01122/2007 EF AP-RCC.3 DROPPED ROD RECOVERY 006 02125/2003 02/25/2003 02/25/2008 EF AP-RCP.1 RCP SEAL MALFUNCTION 017 06/30/2004 04/24/2003 04/24/2008 EF AP-RCS.1 REACTOR COOLANT LEAK 017 06/30/2004 04/16/2003 04116/2008 EF AP-RCS.2 LOSS OF REACTOR COOLANT FLOW 012 06/30/2004 04/16/2003 04/16/2008 EF AP-RCS.3 HIGH REACTOR COOLANT ACTIVITY 011 06/30/2004 04/01/2002 01/22/2007 EF AP-RCS.4 SHUTDOWN LOCA 015 06/30/2004 04/30/2003 04/30/2008 EF AP-RHR.1 LOSS OF RHR 019 04/30/2003 04/30/2003 04/30/2008 EF AP-RHR.2 LOSS OF RHR WMILE OPERATING AT RCS REDUCED INVENTORY CONDITIONS 014 06/3012004 04/30/2003 04/30/2008 EF AP-SG.1 STEAM GENERATOR TUBE LEAK 003 11/21/2002 06/26/2002 06/26/2007 EF AP-SW.1 SERVICE WATER LEAK 020 09/01/2004 04121/2003 04/21/2008 EF AP-SW.2 LOSS OF SERVICE WATER 005 09/01/2004 10/31/2001 10/31/2006 EF AP-TURB.1 TURBINE TRIP VWTHOUT RX TRIP REQUIRED 013 06/30/2004 06/26/2002 06/26/2007 EF

C (. ('

NPSP0200 Ginna Nuclear Power Plant Wed 9/1/2004 12:47:02 pm E66429 PROCEDURE INDE) Page 2 of 2 INPUTPARAMETERS: TYPE PRAP STATUSVALUE(S): EF,QU 5 YEARS ONLY:

PRAP ABNORMAL PROCEDURE PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVIEW ST AP-TURB2 TURBINE LOAD REJECTION 019 06/3012004 06/26/2002 06/2612007 E6 AP-TURB.3 lURBINEVIBRATION 012 06/30/2004 06/26/2002 06/2612007 EF AP-TURB.4 LOSS OF CONDENSER VACUUM 017 04/30/2003 04130/2003 04/30/2008 E AP-TURB.5 RAPID LOAD REDUCTION 007 06/30/2004 06/26/2002 06/26/2007 EF PRAP TOTAL 34 GRAND TOTAL 34

(. (7 NPSP0200 Ginna Nuclear Power Plant Wed 9/1/2004 12:46:38 pm E66429 PROCEDURE INDE) Page 1 of 2 INPUT PARAMETERS: TYPE: PRATT STATUSVALUE(S): EF.,QU 5 YEARS ONLY:

PRATT EOP A1TACHMENTS PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVIEW ST ATT-1 .0 ATTACHMENT AT POWER CCWALIGNMENT 003 021212003 0211212003 0211212008 EF ATT-1.1 ATTACHMENT NORMAL CCW FLOW o00 0511812000 05/182000 05/1812005 EF ATT-2.1 ATTACHMENT MIN SW 005 0210112001 0210312003 0210312008 EF ATT-2.2 ATTACHMENT SW ISOLATION 008 0301002 03/27/2003 0312712008 EF ATT-2.3 ATTACHMENT SW LOADS INCNMT 004 0310612002 04/0612004 0410612009 ATT-2.4 ATTACHMENT NO SW PUMPS D02 05/3012003 10/3112001 10/3112008 ATT-2.5 ATTACHMENT SPLIT SW HEADERS 000 0612612002 0612612002 06126/2007 ATT-3.0 ATTACHMENT CUCV1 007 0211712004 0211712004 0211712009 E:

ATT-3.1 ATTACHMENT CNMT CLOSURE 005 0211712004 0211712004 0211712009 E:

ATT-4.0 ATTACHMENT CNMT RECIRC FANS 003 0712611994 0312712003 0312712008 EF ATT-5.0 ATTACHMENT COND TO SIG 006 10110/2003 04/0612004 04/0612009 EF ATT-5.1 ATTACHMENT SAFW *008 05/3012002 04/0612004 0402009 E:

.E.

ATT-5.2 ATTACHMENT FIRE WATER COOLING TO TDAFW PUMP 003 01/14/1999 0112812004 0112812009 E:

ATT-e.o ATTACHMENT COND VACUUM 003 12/18/1996 02103/2003 0210312008 6:

ATT-7.0 ATTACHMENT CR EVAC 006 03/062002 0210312003 0210312008 E:

ATT-8.0 ATTACHMENT DC LOADS 007 02/0412004 0142004 02104/2009 EF EF ATT-s.1 ATTACHMENT D/G STOP Co05 03062002 02/03/2003 0210312008 EF EF ATT-8.2 ATTACHMENT GEN DEGAS 008 06/2012002 o5n812004 0.51282009 EF 6:

ATT-8.3 ATTACHMENT NONVITAL 004 03M6/2002 0210312003 02103/2008 EF E:

ATT-8.4 ATTACHMENT SLW 005 03/062002 0210312003 0210312008 EF ATT-8.5 ATTACHMENT LOSS OF OFFSITE POWER 001 0812612003 0510212002 05/0212007 E:

EF ATT-9.0 ATTACHMENT LETDOWN 009 01/0712C04 03/0G/2002 03/0612007 6:

EF EF ATT-9.1 ATTACHMENT EXCESS L/D 006 0712812004 10/3112001 10/3112006 6:

EF ATT-10.0 ATTACHMENT FAULTED SIG 006 03/06/2002 03/2712003 03127/2008 6:

ATT-11.0 ATTACHMENT IA CONCERNS 04 09/0112004 0312712003 03/2712008 ATT- 1.1 ATTACHMENT LA SUPPLY 003 03/0612002 03127/2003 03127/2008 ATT-11.2 ATTACHMENT DIESEL AIR COMPRESSOR 004 11/18/2002 03/1012003 03/1012008 ATT-12.0 ATTACHMENT N2 PORVS 005 0211212003 02112/2003 0211212008 ATT-13.0 ATTACHMENT NC 003 0211212003 0211212003 0211212008 ATT-14.0 ATTACHMENT NORMAL RHR COOLING 003 03/0612002 0462004 04/0612009

C C.

NPSP0200 Ginna Nuclear Power Plant Wed 9/1/2004 12:46:38 pm E66429 PROCEDURE INDE> Page 2 of 2 INPUT PARAMETERS: TYPE., PRATT STATUS VALUE(S): EF. QU 5 YEARS ONLY:

PRATT EOP ATTACHMENTS PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TITLE REV DATE REVIEW REVEW ST ATT-14.1 ATTACHMENT RHR COOL 007 09/0112004 01/0812002 01108/2007 EF ATT-14.2 ATTACHMENT RHR ISOL 003 02/12/2003 02V12/2003 02/12/2008 EF ATT-14.3 ATTACHMENT RHR NPSH 003 03/06)2002 01/28/2004 01/28/2009 EF ATT-14.5 ATTACHMENT RHR SYSTEM 003 03/20/2003 02/03/2003 02/03/2008 EF ATT.14.6 ATTACHMENT RHR PRESS REDUCTION 002 03/06/2002 01/28/2004 01/28/2009 EF ATT-14.7 ATTACHMENTADJUSTRHR FLOW 000 02/17/2004 02/17/2004 02/17/2009 EF ATT-15.0 ATTACHMENT RCP START 009 03/06/2002 03/17/2000 03/17/2005 EF ATT-15.1 ATTACHMENT RCP DIAGNOSTICS 003 04124/1997 02/03/2003 02/03/2008 EF ATT-15.2 ATTACHMENT SEAL COOUNG 005 03106/2002 02/03/2003 02/03/2008 EF ATT-16.0 ATTACHMENT RUPTURED SIG 012 04129/2004 01111/2000 01/11/2005 EF ATT-16.1 ATTACHMENT SGTL 003 09/01/2004 09/08/2000 09/08/2005 EF ATT-15.2 ATTACHMENT RCS BORON FOR SGTL 003 11/28003 09/08/2000 09/08/2005 EF ATT-17.0 ATTACHMENT SD-1 017 09101/2004 02/29/2000 02/28/2005 EF ATT-17.1 ATTACHMENT SD-2 007 09/01/2004 01/30/2001 01/30/2006 EF ATT-1 8.0 ATTACHMENT SFP - RWST 005 03106/2002 02/03/2003 02/03/2008 EF ATT-20.0 ATTACHMENT VENT TIME 004 09/01/2004 02/03/2003 02ov3/2008 EF ATT-21.0 ATTACHMENT RCS ISOLATION 002 0310n/2002 02/03/2003 02/03/2008 EF ATT-22.0 ATTACHMENT RESTORING FEED FLOW ou3 05o02/2002 01/22/2002 01/22/2007 EF ATT-23.0 ATTACHMENT TRANSFER 4160V LOADS c00 0212611999 01/28/2004 01/28/2009 EF ATT-24.0 ATTACHMENT TRANSFER BATTERY TO TSC 000 09/08/2000 09/08/2000 09/08/2005 EF ATT-26.0 ATTACHMENT RETURN TO NORMAL OPERATIONS 000 10/31/2001 10/31/2001 10/31/2006 EF PRATT TOTAL 51 GRAND TOTAL 51

EOP: TITLE:

REV: 2 0 AP-SW.1 SERVICE WATER LEAK PAGE 1 of 12 GINNA STATION CONTROLLED COPY NUMBER 232 RESPONSIBLO MANAGER EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 2 of 12 A. PURPOSE - This procedure provides the necessary instructions to respond to a service water system leak.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:
a. N/A
2. SYMPTOMS - The symptoms of SERVICE WATER LEAK are:.
a. AR-PPCS-P2160, SERVICE WATER PUMPS A & B HEADER, or
b. AR-PPCS-P2161, SERVICE WATER PUMPS C & D HEADER, or
c. Sump pump activity increases in containment, the AUX BLDG, or INT BLDG, or
d. Unexplained increase in the waste hold-up tank, or
e. Visual observation of a SW leak, or
f. Annunciator C-2, CONTAINMENT RECIRC CLRS WATER OUTLET HI TEMP 2170F, lit, or
g. Annunciator C-10, CONTAINMENT RECIRC CLRS WATER OUTLET LO FLOW 1050 GPM, lit, or
h. Annunciator E-31, CONTAINMENT RECIRC FAN CONDENSATE HI-HI LEVEL alarm, exhibits an unexplained increase in frequency, or
i. Annunciator H-6, CCW SERVICE WATER LO FLOW 1000 GPM, lit.

EOP: TITLE:

. . .REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 3 of 12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1 Verify 480V AC Emergency Ensure associated DIG(s) running Busses 17 and 18 - ENERGIZED and attempt to manually load busses 17 and/or 18 onto the D/G(s) if necessary.

IF neither bus 17 nor bus 18 can be energized. THEN perform the following:

a. Trip the reactor
b. WHEN all E-O Immediate Actions done, THEN trip both RCPs
c. Close letdown isol. AOV-427
d. Close excess letdown. HCV-123
e. Go to E-O, REACTOR TRIP OR SAFETY INJECTION IF either bus 17 OR bus 18 is deenergized. THEN refer to AP-ELEC.17/18. LOSS OF SAFEGUARDS BUS 17/18.

[EOP: TITLE:

REV: 2 01 AP-SW.1 SERVICE WATER LEAK I PAGE 4 of 12 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 2 Verify At Least One SW Pump Perform the following:

Running In Each Loop:

a. Manually start SW pumps as
  • A or B pump in loop A necessary (257 kw each).
  • C or D pump in loop B
b. IF adequate cooling can NOT be supplied to a running D/G. THEN perform the following:
1) Pull stop affected D/G
2) Immediately depress voltage shutdown pushbutton
3) Refer to ER-D/G.2. ALTERNATE COOLING FOR EMERGENCY D/Gs
c. IF no SW pumps can be operated.

THEN perform the following:

1) Trip the reactor
2) WHEN all E-O Immediate Actions done, THEN trip BOTH RCPs
3) Close letdown isol. AOV-427
4) Close excess letdown. HCV-123.
5) Go to E-O. REACTOR TRIP OR SAFETY INJECTION
d. IF only one SW pump can be operated.-THEN refer to AP-SW.2, LOSS OF SERVICE WATER.

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 5 of 12 NOTE: Abnormally low pressure in either SW loop may indicate that the idle pump check valve is open. This may be corrected by restarting or isolating the idle pump.

3 Check SW System Status:

a. Check SW loop header pressures: a. IF three SW pumps operating and either loop pressure less than o Pressure in both loops - 40 psig. THEN trip the reactor APPROXIMATELY EQUAL and go to E-0. REACTOR TRIP OR SAFETY INJECTION.

o PPCS SW low pressure alarm status - NOT LOW IF only two SW pumps operating and either loop pressure less

  • PPCS point ID P2160 than 45 psig. THEN start one
  • PPCS point ID P2161 additional SW pump (257 kw each pump).

o Pressure in both loops -

STABLE OR INCREASING

b. Check SW loop header pressures - b. IF either SW loop pressure is GREATER THAN 55 PSIG less than 55 PSIG with three SW pumps running AND cause can NOT be corrected. THEN initiate a controlled shutdown while continuing with this procedure (Refer to AP-TURB.5, RAPID LOAD REDUCTION).

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 6 of 12 ACTION/EXPECTED RESPONSE lRESPONSE STEP NOT OBTAINED NOTE: o If SW is lost to any safeguards equipment. the affected component should be declared inoperable and appropriate actions taken as required by ITS. Section 3.

o CNMT sump A level of 10 feet is approximately 6 feet 6 inches below the bottom of the reactor vessel.

4 Check For SW Leakage In CNMT:

a. Check Sump A indication a. IF the SW leak is NOT in the CNMT. THEN go to Step 6.

o Sump A level - INCREASING

-OR-o Sump A pump start frequency -

INCREASING (Refer to RCS Daily Leakage Log)

b. Evaluate Sump A conditions: b. Plant shutdown should be considered, consult plant staff.
1) Verify Leakage within capacity of one Sump A pump (50 gpm)
2) Check Sump A level - LESS THAN 10 FEET
c. Direct RP to establish conditions for CNMT entry

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK I PAGE 7 of 12 ACTION/EXPECTED RESPONSE STP lRESPONSE NOT OBTAINED NOTE: o One Reactor Compartment cooling fan should be running whenever RCS temperature is greater than 1350F.

o CNMT recirc fan condensate collector level indicators may be helpful in identifying a leaking fan cooler.

5 Check CNMT fan indications: Dispatch AO with locked valve key to perform ATT-2.3, ATTACHMENT SW o CNMT recirc fan collector dump LOADS IN CNMT to determine leak frequency - NORMAL (Refer to RCS location. WHEN CNMT SW leak Daily Leakage Log) location identified. THEN go to Step 9.

o CNMT recirc fan SW flows -

APPROXIMATELY EQUAL (INTER BLDG basement by IBELIP) o Reactor compartment cooler SW outlet pressures - APPROXIMATELY EQUAL (INTER BLDG SAMPLE HOOD AREA)

  • Cooler A - PI 2232
  • Cooler B - PI 2141

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 6 Dispatch AO To Screenhouse To Perform The Following:

a. Verify idle SW pump check valve a. Notify Control Room of any closed indication of check valve failure.

o Idle pump shaft stopped o Idle pump discharge pressure

- ZERO (unisolate and check local pressure indicator)

b. Investigate for SW leak in b. Perform the following:

Screenhouse - NO EXCESSIVE LEAKAGE INDICATED 1) Identify leak location.

IF increase in leakage from underground header indicated.

THEN isolation of header should be considered (Refer to ATT-2.2. ATTACHMENT SW ISOLATION)

2) Notify Control Room of leak location.

NOTE: Refer to ATT-2.2. ATTACHMENT SW ISOLATION for a list of the major non-safeguards loads supplied by each service water header.

7 Check Indications For Leak Dispatch AO to the specific area to Location: investigate for leakage.

o AUX BLDG sump pump start frequency - NORMAL (Refer to RCS Daily Leakage Log) o Annunciator L-9, AUX BLDG SUMP HI LEVEL - EXTINGUISHED o Annunciator L-17. INTER BLDG SUMP HI LEVEL - EXTINGUISHED

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 9 of 12 ACTION/EXPECTED RESPONSE SP [RESPONSE NOT OBTAINED]

8 Dispatch AO To Locally Investigate For SW Leakage And To Monitor Operating Equipment

  • Turbine BLDG
  • SAFW pump room NOTE: If SW is lost to either D/G. refer to ER-D/G.2. ALTERNATE COOLING FOR EMERGENCY D/Gs, if cooling is required.

9 Evaluate SW Leak Concerns

a. Check SW pump status - AT LEAST a. IF either SW header pressure THREE PUMPS RUNNING less than 45 psig. THEN start third SW pump.
b. Check SW loop header pressure - b. Perform the following:

BOTH LOOPS GREATER THAN 45 PSIG

1) Dispatch AO to split A and B SW headers (refer to ATT-2.5.

ATTACHMENT SPLIT SW HEADERS)

2) IF plant at power. THEN initiate a controlled shutdown (Refer to AP-TURB.5.

RAPID LOAD REDUCTION).

3) Go to Step 10.
c. Verify leak location - IDENTIFIED c. Return to Step 3.
d. Verify plant operating at power d. Verify SW system conditions appropriate for plant mode (Refer to ITS Section 3.7.8) and go to Step 10.
e. Leak isolation at power - e. IF plant shutdown required. THEN ACCEPTABLE refer to 0-2.1. NORMAL SHUTDOWN TO HOT SHUTDOWN or AP-TURB.5.

RAPID LOAD REDUCTION.

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 10 of 12 SACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 10 Dispatch AO(s) To Locally Isolate SW Leak As Necessary

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 11 of 12 ACTION/EXPECTED RESPONSE ilRESPONSE SP NOT OBTAINED 11 Verify SW Leak Isolated

a. Monitor SW System Operation a. IF SW leak can NOT be isolated within the affected loop. THEN o SW loop header pressure - stop SW pumps in the affected RESTORED TO PRE-EVENT VALUE loop.

Archive PPCS point ID loop A P2160 OR loop B P2161) o Both SW loop header pressures

- STABLE

b. Verify At Least One SW Pump b. Perform the following:

Running In Each Loop:

1) Ensure two SW pumps running
  • A or B pump in loop A (257 kw each).
  • C or D pump in loop B
2) IF adequate cooling can NOT be supplied to a running D7G.

THEN perform the following:

a) Pull stop affected D/G b) Immediately depress voltage shutdown pushbutton c) Refer to ER-D/G.2.

ALTERNATE COOLING FOR EMERGENCY D/Gs.

3) IF no SW pumps can be operated. THEN perform the following:

a) Trip the reactor b) WHEN all E-0 Immediate Actions done. THEN trip BOTH RCPs c) Close letdown isol. AOV-427 d) Go to E-0. REACTOR TRIP OR SAFETY INJECTION

4) IF only one SW pump can be operated. THEN refer to AP-SW.2, LOSS OF SERVICE WATER.
c. Restore to normal position all valves repositioned during leak investigation EXCEPT leak isolation boundary.

EOP: TITLE:

REV: 2 0 AP-SW.1 SERVICE WATER LEAK PAGE 12 of 12 ACTIN/EXECTE REPONS l lRESPNSENOT OBTAINEDl 12 Evaluate MCB Annunciator Status (Refer to AR procedures)

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

13 Notify Higher Supervision

-END-

EOP: TITLE:

REV: 20 AP-SW.1 SERVICE WATER LEAK PAGE 1 of 1 AP-SW.1 APPENDIX LIST TITLE

1) ATTACHMENT SW ISOLATION (ATT-2.2)
2) ATTACHMENT SW LOADS IN CNMT (ATT-2.3)
3) ATTACHMENT SPLIT SW HEADERS (ATT-2.5)

EOP: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 1 of 8 GINNA STATION CONTROLLED COPY NUMBER 3.

RESPONSIBL ",NAGER

- i/-_ oo EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

EOP: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 2 of 8 A. PURPOSE - This procedure provides the necessary instructions to respond to a loss of service water pumps.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:
a. AP-ELEC.17/18, LOSS OF SAFEGUARDS BUS 17/18.
b. Any of several EOPs, when only one SW pump can be operated.
2. SYMPTOMS - The symptoms of LOSS OF SERVICE WATER PUMPS are:
a. AR-PPCS-P2160, SERVICE WATER PUMPS A & B HEADER, or I
b. AR-PPCS-P2161, SERVICE WATER PUMPS C & D HEADER, or I
c. Annunciator C-2, CONTAINMENT RECIRC CLRS WATER OUTLET HI TEMP 2170F, lit, or
d. Annunciator C-10, CONTAINMENT RECIRC CLRS WATER OUTLET LO FLOW 1050 GPM, lit, or
e. Annunciator H-6, CCW SERVICE WATER LOW FLOW 1000 GPM, lit, or
f. Annunciator H-9, AUXILIARY FEED PUMP CLG WTR FLTR HI DIFF PRESS, lit, or
g. Annunciator I-10, CW PUMP SEAL WATER LO FLOW, lit, or
h. Annunciator J-4, GENERATOR ISOPHASE BUS COOLING SYSTEM, lit, or
i. Annunciator J-9, SAFEGUARD BREAKER-TRIP, lit, or
j. Annunciator K-30, TURBINE PLANT SAMPLING RACK TROUBLE, lit.

EOP: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 3 of 8 ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED l 1 Verify 480V AC Emergency Ensure associated DIG(s) running Busses 17 and 18 - ENERGIZED and attempt to manually load busses 17 and/or 18 onto their respective D/G(s).

IF neither bus 17 nor bus 18 can be energized. THEN perform the following:

a. Trip the reactor
b. WHEN all E-O Immediate Actions done. THEN trip both RCPs
c. Close letdown isol. AOV-427
d. Close excess letdown. HCV-123
e. Go to E-O. REACTOR TRIP OR SAFETY INJECTION

rEOP: TITLE:

REV: 5 *1 AP-SW.2 - LOSS OF SERVICE WATER PAGE 4 of 8

  • 2 Verify SW Pump Alignment:
a. Check at least one SW pump a. Perform the following:

running in each loop

1) Manually start SW pumps as
  • A or B pump in loop A necessary (257 kw each).
  • C or D pump in loop B
2) IF adequate cooling can NOT be supplied to a running D/G.

THEN perform the following:

a) Pull stop affected D/G b) Immediately depress voltage shutdown pushbutton

3) IF no SW pumps can be operated. THEN perform the following:

a) Trip the reactor b) WHEN all E-O Immediate Actions done. THEN trip BOTH RCPs c) Close letdown isol, AOV-427 d) Close excess letdown.

HCV-123 e) Go to E-O. REACTOR TRIP OR SAFETY INJECTION

4) IF only one SW pump can be operated. THEN go to step 3..
5) IF at least two SW pumps can be operated. THEN go to step 8.
b. Return to procedure or guidance in effect

EOP: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER

. . s.

PAGE 5 of 8 ACTION/EXPECTED RESPONSE RSOS O BAN 3 Align Alternate Cooling To One D/G (Refer to ER-D/G.2, ALTERNATE COOLING EMERGENCY D/Gs):

o IF A or C SW Pump is operating, THEN align alternate cooling to D/G B

-OR-o IF B or D SW Pump is operating.

THEN align alternate cooling to DIG A 4 Isolate SW To Non-Essential Loads

a. Close screenhouse SW isolation K) valves
  • MOV-4609
  • MOV-4780
b. Close air conditioning SW isolation valves
  • MOV-4663
  • MOV-4733
c. Direct AO to perform Part C of ATT-2.2. ATTACHMENT SW ISOLATION

EOP: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 6 of 8 ACTION/EXPECTED RESPONSE STP lRESPONSE NOT OBTAINEDl 5 Monitor Plant Equipment IF required. THEN reduce load as Cooled By SW - TEMPERATURES necessary to stabilize equipment STABLE temperatures (Refer to 0-5.1. LOAD REDUCTIONS, or AP-TURB.5. RAPID

  • MFP oil coolers
  • Instrument air compressors
  • Bus duct coolers
  • Seal Oil unit
  • AEPs
  • Condensate Pumps
  • Secondary sample coolers 6 Notify Higher Supervision

ACTION/EXPECTED RESPONSE P lRESPONSE NOT OBTAINED 7 Check SW System Status:

a. Check SW loop header pressures: a. Locally isolate selected SW loads as desired (Refer to o PPCS SW low pressure alarm ATT-2.2. ATTACHMENT SW ISOLATION) status - NOT LOW
  • PPCS point ID P2161 o Pressure in both loops -

STABLE OR INCREASING o Check SW loop header pressures - GREATER THAN 40 PSIG

b. Check at least one SW pump b. Perform the following:

running in each loop:

1) Continue efforts to start at
  • A or B pump in loop A least one SW pump in each
  • C or D pump in loop B loop.
2) IF at least two SW pumps can be operated. THEN go to Step 8. IF NOT. THEN return to step 3.

8 Notify Higher Supervision 9 Select Operable SW Pumps For Refer to ITS LCO 3.7.8 Auto Start

EOP: TIRE: REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 8 of *8 ACTION/EXPECTED RESPONSE P lRESPONSE NOT OBTAINED l 10 Evaluate MCB Annunciator Status (Refer to AR Procedures) 11 Return To Procedure or Guidance In Effect

-END-

EON: TITLE:

REV: 5 AP-SW.2 LOSS OF SERVICE WATER PAGE 1 of 1 AP-SW.2 APPENDIX LIST TITLE

1) ATTACHMENT SW ISOLATION (ATT-2.2)

o?73 EOP: TITLE:

REV: 4 ATT-11.0 ATTACHMENT IA CONCERNS PAGE 1 of 2 Responsible Manager Date ________

CNMT IA LOSS AND FAILURE MODE

1) P&ID #33013-1887 o Letdown AOV-427 (FO) o Excess Letdown AOV-310 (FC) o RCP Seal Return Valves AOV-270A, AOV-270B (FO) o RCP Thermal Barrier CCW AOV-754B (FO)
2) P&ID #33013-1888 o Letdown Orifices AOV-200A, AOV-200B, AOV-202 (FC) o Charging AOV-294, AOV-392A (FC) o Aux. Spray AOV-296 (FC) o PRZR Spray PCV-431A, PCV-431B (FC) o PRZR PORV PCV-430, PCV-431C (FC) o RCP Thermal Barrier CCW AOV-754A (FO) o Charging AOV-392B (FC) o RCP Seal Bypass Valve, AOV-386 (FC) o PRZR Sample Valves AOV-951, AOV-953 (FC) o Post Accident Filter Dampers AOV-5871, 5872, 5874, 5876 (FO)

(Log filters in service on run time log)

AUX BLDG IA LOADS AND FAILURE MODE

1) P&ID #33013-1889 o Letdown Valve LCV-112A (Fail to VCT)
2) P&ID #33013-1890 o Letdown Valve AOV-371 (FC) o Charging Line Valve HCV-142 (FO) o RHR Flow Valves HCV-624, HCV-625 (FO) o RHR Hx Bypass Flow Valve FCV-626 (FC) o CCW From Excess Letdown HX AOV-745 (FC)
3) P&ID #33013-1891 o VCT Makeup Valves AOV-11OB, AOV-110C, AOV-111 (FC) o Charging Pump Suction AOV-112B (FC) AOV-112C (FO) o Charging Pump Speed Control Fails to Mimimum o NaOH Tank Outlet Valves AOV-836A, AOV-836B (FO).

o Letdown Valve TCV-145 (Fail to VCT) o Letdown Valve PCV-135 (FO)

4) P&ID #33013-1892 o VCT Makeup Valve AOV-11OA (FO)

EOP: TITLE:

REV: 4 ATT-11.0 ATTACHMENT IA CONCERNS PAGE 2 of 2 TURBINE BLDG IA LOADS AND FAILURE MODE

1) P&ID #33013-1894 o Heater Drain Pump Recirc Vlv AOV-3365 (FO) HDT pumps trip if recirc vlv full open 1 minute o Condensate Trim Valves AOV-9508D, AOV-9508G (FC) o Steam Dump Valves AOV-3349, AOV-3351, AOV-3353, AOV-3355 (FC) o H2 Cooler Inlet Vlv AOV-4230 (FO) o Condensate Makeup Valve AOV-4315 (FC) o Condensate Quench Temp Control AOV to HDT, AOV-3359 (FO)
2) P&ID #33013-1895 o MFW Regulating Valves and Bypass Valves AOV-4269, AOV-4270, AOV-4271 and AOV-4272 (FC)
3) P&ID #33013-1896 o Condensate Bypass Valve AOV-3959 (FO) o Steam Dump Valves AOV-3350, AOV-3352, AOV-3354, AOV-3356 (FC) o H2 Cooler Bypass Valve AOV-4229 (FO)

INTERMEDIATE BLDG IA LOADS AND FAILURE MODE

1) P&ID #33013-1893 o S/G Blowdown Vlvs AOV-5737, AOV-5738 (FC)
2) Ventilation Print #33013-1874 o Int Bldg outside air dampers, east wall (FC)
  • AID 05A
  • AID 05B
  • AID 05C
  • AID 05D
  • AID 05E
  • AID 05F
  • AID 05G IA COMPRESSORS, FILTERS, AND AIR DRYERS
1) P&ID #33013-1900, Sheets 1 & 2

EOP: TITLE:

REV: 7 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 < 3500 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
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: 7 ATT-14.1 ATTACHMEN 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 10M).
17. Close RHR PUMP SUCTION FROM CNMT SUMP B MOV-851B breaker (MCC D Pos 10M).
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 10M).
20. Open RHR PUMP SUCTION FROM CNMT SUMP B MOV-851B breaker (MCC D Pos 10M).
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 as follows:

25.1 Replace annunciator window F-29 with LTOP RCS pressure alarm window.

25.2 On.PPCS, substitute a value of one (1) for point ID KPLTOP.

25.3 Substitute a value for P0420 or P0420A greater than 390 psig.

25.4 Verify that annunciator F-29 alarms.

25.5 Restore selected point to processing.

25.6 Verify that annunciator F-29 clears.

25.7 Substitute a value for P0420 or P0420A less than 300 psig.

25.8 Verify that annunciator F-29 alarms.

25.9 Restore selected point to processing.

25.10 Verify that annunciator F-29 clears.

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, verify 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.

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.

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.

Responsible Manager Date _________

This Attachment describes the stepQ to be taken up to and including a normal plant shutdown in the event of a Steam Generator (SIG) tube leak.

NOTE: ITS LCO 3.4.13 limit on S/G leakage of .1 gpm is equivalent to 378 cc/min (144 GPD).

This Attachment is organized in the following subsections:

A. Primary to secondary leakage in at least one S/G 2 5 GPD B. Primary to secondary leakage in at least one S/G 2 75 gpd A. Primary to secondary leakage in at least one SIG 2 5 cmd

1. Request RP perform a second sample to confirm the leak rate.
2. Notify RP to implement procedure CH-SAMP-SG-LEAKRATE.
3. Refer to ITS LCO 3.7.14 for secondary specific activity limit.
4. Notify Chemistry to determine desired S/G blowdown flowpath.
5. Check operability of the following monitors.
  • R-15
  • R-15A
  • R-19
  • R-31
  • R-32
6. IF any monitor in Step 5 is NOT operable, THEN elevate monitor repair efforts to the highest priority.
7. Dispatch an AO to perform T-35H, Nuclear House Heating Steam To Boiler Steam Supply Change Over.
8. IF the leaking S/G has NOT been identified, THEN perform the following to identify the leaking S/G. (Valves located in IB hot side, outside sample room) 8.1 Direct an AO to close V-996A, inlet block valve to FI-2027 (S/G blowdown Hx A outlet flow)

8.2 Monitor R-19 for approximately two (2) minutes.

o IF R-19 decreases, THEN leakage is in S/G A.

o IF R-19 increases, THEN leakage is in S/G B.

o IF R-19 does not change, THEN request RP perform CH-SAMP-SG-BLOWDOWN to identify leaking S/G.

8.3 Open V-996A, inlet block valve to FI-2027 (S/G blowdown Hx A outlet flow)

B. Primary to secondary leakage in at least one S/G 2 75 qpd NOTE: Refer to ITS LCO 3.4.13 for RCS leakage limits.

NOTE: Refer to ITS LCO 3.7.14 for secondary specific activity limit.

NOTE: Refer to EPIP-1.0, Ginna Station Event Evaluation and Classification.

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

NOTE: AFTER the Turbine is off line, IMMEDIATELY perform step B.12 THEN return to any section or steps NOT performed.

1. Place Hotwell level controller in Manual at 50% position to minimize reject.
2. Start the A and B CNMT Auxiliary Charcoal Filter Fans.
3. Consult with RP/Chemistry section. If desired, perform the following:
a. Bypass the AVT Condensate DIs. Refer to T-6.9C, Condensate Demineralizer Bypass Operation.
b. Notify RP/Chemistry that the AVT Condensate DIs are bypassed AND isolated.
4. Shift Support Heating Steam Trap Outlet Valves from the trap header to Blowdown Tank by performing the following (6 ft east of S/G B FRV, 2 ft high):
a. Close support orifice system isolation valve, V-3684
b. Open support system to S/G blowdown tank isolation valve, V-3683.
5. Request identification of leaking S/G from the Control Room.
6. Close trap drain isolation valve upstream of MSIV on the leaking SIG.
  • S/G A, V-3521 Closed (south of S/G B FRV, 8 ft high)

OR

  • S/G B, V-3520 Closed (30 feet east of S/G B FRV, 8 ft high)
7. Verify Blowdown Tank discharge valve V-5714 is closed (at S/G Blowdown Tank.
8. Isolate Blowdown from the leaking S/G.
  • S/G A, AOV-5738 OR V-5701 Closed OR
  • S/G B, AOV-5737 OR V-5702 Closed NOTE: Annunciator H-15 will light when this step is performed.

NOTE: Refer to ITS LCO 3.7.5 for TDAFW train flowpath operability.

NOTE: Refer to TRM 3.4.3 for ATWS mitigation operability.

9. PULL STOP the TDAFW Pump Steam Admission valve from the leaking S/G.
  • S/G A, MOV-3505A PULL STOP OR
  • S/G B, MOV-3504A PULL STOP
10. Notify RP to survey the following areas:
  • Blowdown Tank
  • Turbine Bldg Wall Fan
  • Turbine Plant Sample Rack
11. Notify RPs to verify that airborne contaminants that may be discharging from steam reliefs OR the Air Ejector are NOT being pulled into the supply air handling units. The most likely areas affected are:
  • Auxiliary Bldg
  • Intermediate Bldg
  • Service Bldg
12. WHEN the Turbine is off line, THEN perform the following:
a. Place leaking S/G ARV controller to AUTO, set for 1050 psig,and verify ARV is closed.
  • Leaking S/G ARV in AUTO
  • Leaking S/G ARV Set for 1050 psig
  • Leaking S/G ARV Closed
b. Close the MSIV on the leaking S/G.

o S/G A, AOV-3517 Closed OR o S/G B, AOV-3516 Closed NOTE: IF 0-2.1, NORMAL SHUTDOWN TO HOT SHUTDOWN, was used to perform the shutdown, THEN do steps 13 and 14. IF NOT, THEN do step 15.

13. WHEN 0-2.1 is completed, THEN continue cooldown to MODE 5 per 0-2.2.
14. When directed by 0-2.1 or 0-2.2, remove the RCP associated with the leaking S/G from service.
15. Review 0-2.1 and 0-2.2 as necessary to secure equipment and establish shutdown alignments.

Responsible Manager + _ Date i-/-A f Perform the following local actions to complete normal secondary system shutdown:

o Close reheater 4th pass temperature control valves:

o V-2432 (SW corner IA MSR) o V-2433 (SW corner lB 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 lB MSR) o V-3551 (SW of 1B MSR) o V-3552 (NW of IA MSR) o V-3553 (NW of IA 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 o Secure all 5 secondary chemical addition pumps on TURB BLDG middle floor by #5 heaters.

o Secure all 3 ammonia pumps, TURB BLDG basement by MCC A.

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 o IF HDT Pump A seal injection primary filter (FGSOlA) 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 (FGS0lB) 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

!\

k _ _ __ __

Perform the following to complete secondary system shutdown:

1. Align S/G blowdowns as follows:
a. Secure blowdowns to the condenser per T-14G, STEAM GENERATOR BLOWDOWN HEAT RECOVERY SYSTEM SHUTDOWN.
b. IF restoration of blowdowns is desired, THEN ensure releases are in effect before performing the next step.

IF restoration of blowdowns is NOT desired, THEN go to Step 2.

c. Align Steam Generator Blowdown Flash Tank drains to the discharge canal per T-14F.1, SG BLOWDOWN ALIGNMENT TO DISCHARGE CANAL.
2. Transfer main steam header upstream traps from condenser to Blowdown Tank (TB, middle lvl, East of MFW Reg Vlvs).

o Open support trap outlet to blowdown tank (V-3683).

o Close support trap outlet to condenser (V-3684).

o Open A steam header trap to blowdown tank (V-3617).

o Close A steam header trap to condenser (V-3605).

o Open B steam header trap to blowdown tank (V-3604).

o Close B steam header trap to condenser (V-3616).

3. Close steam supply to air ejector (V-3583) (TB, middle lvl, East of AE unit).
4. Open vacuum breaker (V-3164) (TB, top floor, North of L.P.

turbines, inside Turb skirting).

5. WHEN condenser vacuum at 0 inches Hg, THEN secure gland steam regulator isolation (V-3872) and stop gland steam vapor extractor (TB, middle lvl, North of main condensers).

Responsible Manager Date q /12O)LC VENT TIME CALCULATIONS

1. Record H2 Concentration and RCS pressure.
a. H2 Concentration _
b. RCS pressure psig
2. Determine Containment Volume at standard conditions (V).
a. V = (5.1X108) = cu ft (CNMT temperature in OF + 460)
b. V = cu ft
3. Determine the maximum H2 volume that can be vented (H).
a. H = (3% - H2 Concentration) x V = cu ft 100%
b. H = cu ft
4. Determine H2 flow rate (F) from curve on Figure CNMT HYDROGEN and RCS pressure recorded in step lb.
a. F = SCFM I
5. Calculate the maximum venting time (T).
a. T = H (from step 3) / F (from step 4)
b. T = minutes
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