ML051730536

Emergency Operating Procedures

ML051730536
Person / Time
Site:	Ginna
Issue date:	06/10/2005
From:	Marlow T Constellation Energy Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
Download: ML051730536 (29)

Text

1503 Lake Road Ontario, New York 14519-9364 585.771.3000 Constellation Energy R.E. Ginna Nuclear Power Plant, LLC June 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 AP-TURB.1, Rev 15 AP-TURB.3, Rev 13 c6\o;

(7 ( C NPSP0200 Ginna Nuclear Power Plant Fri 6/10/2005 10:15:55 am I E66429 PROCEDURE INDE) Page 1 of 2 INPUT PARAMETERS: TYPE. PRAP STATUSVALUE(S): EF.QU s YEARS ONLY:

!,?

PRAP ABNORMAL PROCEDURE PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE TlTLE REV DATE REVIEW REVIEW ST AP-CCW.1 LEAKAGE INTO THE COMPONENT COOLiNG LOOP 017 06/30/2004 06/26/2002 06/26/2007 EF AP-CCW2 LOSS OF CCW DURING POWER OPERATION 020 04128/2005 06/26/2002 06/26/2007 EF AP-CCW.3 LOSS OF CCW- PLANT SHUTDOWN 017 04/28/2005 06/26/2002 06/26/2007 EF AP-CR.1 CONTROL ROOM INACCESSIBILITY 021 04/26/2005 06/2612002 06/26/2007 EF AP-CVCS.1 CVCS LEAK 014 06130/2004 06/03/2002 06/03/2007 EF AP-CVCS.3 LOSS OF ALL CHARGING FLOW 005 04/1012005 02/27/2004 02/27/2009 EF AP-CW.1 LOSS OF A CIRC WATER PUMP 012 09/17l2004 04/16/2003 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-ELEC.2 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 (BELOW350 F) 013 01121/2005 0812612002 06/26/2007 EF AP-ELEC.13Y15 LOSS OF BUS 13i15 001 08130/2004 09/24/2003 09/24/2008 EF AP-ELEC.14/16 LOSS OF SAFEGUARDS BUS 14116 009 01/21/2005 06/26/2002 06/26/2007 EF AP-ELEC.17/18 LOSS OF SAFEGUARDS BUS 17/18 008 01/21/2005 06/26/2002 06/2612007 EF AP-FW.1 ABNORMAL MAIN FEEDWATER FLOW 016 06/30/2004 06/26/2002 06/26/2007 EF AP-IA.1 LOSS OF INSTRUMENT AIR 018 06/26/2002 04116/2003 04/16/2008 EF AP-PRZR.1 ABNORMAL PRESSURIZER PRESSURE 015 06/30/2004 06/26/2002 06/26/2007 EF AP-RCC.1 CONlINUOUS CONTROL ROD WITHDRAWALJINSERTION 009 06130/2004 04/16/2003 04/16/2008 EF AP-RCC.2 RCC/RPI MALFUNCTION 012 04/10/2005 2/120/51/2 01/22/2007 AP-RCC.3 DROPPED ROD RECOVERY 007 04/28/2005. 02/25/2003 02/25/2008 AP-RCP.1 RCP SEAL MALFUNCTION 017 06130/2004 04/24/2003 04/24/2008 AP-RCS.1 REACTOR COOLANT LEAK 017 06/30/2004 04/16/2003 04/16/2008 AP-RCS.2 LOSS OF REACTOR COOLANT FLOW 012 06/30/2004 "04/16/2003 04/16/2008 AP-RCS.3 HIGH REACTOR COOLANT ACTMITY O11 06130/2004 04/01/2002 01/22/2007 AP-RCS.4 SHUTDOWN LOCA O17 03/18/2005 04/30/2003 04/30/2008 AP-RHR.1 LOSS OF RHR 019 04130/2003 04130/2003 04/30/2008 AP-RHR.2 LOSS OF RHR WHILE OPERATING AT RCS REDUCED INVENTORY CONDmONS 015 04/05/2005 04/3012003 04/3012008 AP-SG.1 STEAM GENERATOR TUBE LEAK 004 04/10/2005 06/26/2002 06/26/2007 AP-SW.1 SERVICE WATER LEAK 021 09/17/2004 04121/2003 04/21/2008 AP-SW.2 LOSS OF SERVICE WATER 007 01/21/2005 1//20/5013 10/31/2006 EF AP-TURB.1 TURBINE TRIP WITHIIJT RX TRIP REQUIRED 015 06/10/2005 06/26/2002 06/26/2007 EF

( C C(

NPSP0200 Ginna Nuclear Power Plant Fri 6/10/2005 10:15:55 am FrA9Q nonnrani I0C lKlnC - D-n 7) nf 73 INPUT PARAMETERS: TYPE, PRAP STATUS VALUE(S): EF. QU 5 YEARS ONLY:

PRAP ABNORMAL PROCEDURE PROCEDURE EFFECT LAST NEXT NUMBER PROCEDURE llTLE REV DATE REVIEW REVIEW ST AP-TURB.2 TURBINE LOAD REJECTION 021 04110/2005 06/20/2002 06/26/2007 EF AP-TURB.3 TURBINEMBRATION 013 0611012005 06/26/2002 06/26/2007 EF AP-TURB.4 LOSS OF CONDENSER VACUUM 018 04110/2005 04/30/2003 04/3012008 EF AP-TURB.5 RAPID LOAD REDUCTION 008 04110/2005 06/26/2002 06/2612007 EF PRAP TOTAL 34 GRAND TOTAL 34

. GINNA STATION CONTROLLED COPY NUMBER -_______

RESPONSIBLE MANAGER k-/l-z, a s 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 HIGH VIBRATION, 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.

ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED l 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

ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED I

• 3 Monitor MFW Regulating Valves Perform the following:

- RESTORING S/G LEVEL TO 52%

IN AUTO a. Place affected S/G(s) MFW 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.l.

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 SIG 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 545 0 F rods to MANUAL and adjust

• Tavg - LESS THAN 5660 f 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.

EOP: TITLE: REV: 15 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 6 of 16 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) 5 Check PRZR Pressure - Control PRZR pressure by one of the TRENDING TO 2235 PSIG IN AUTO following:

• 431K in MANUAL

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

TIE EOP~

.EDP: TLE:

TI -

REV: 15 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PE 7o 1 6

. PAGE 7 of 16 STE ACTION/EXPECTED RESPONSE RESPONSE 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 (AOV-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.

ACTION/EXPECTED RESPONSE lRESPONSE STEP NOT OBTAINED 7 Check MFW System:

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

1) Verify one MFW pump running.

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

• MDAFW pump(s)

• TDAFW pump

2) Go to Step 8.

b. Close one MFW pump discharge valve

c. Stop selected MFW pump

P ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED w * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * *r

• 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-0 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 prig 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 0 F 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.

S P ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED 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 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.

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

c) Go to Step 9c.

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.

• MEW regulating valves

• MEW bypass valves This Step continued on the next page.

EOP: TITE:- REV: 15 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED

. . PAGE 11 of 16 ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED (Step 9 continued from previous page)

d. Close MEW pump discharge valves

• MOV-3977, A MEW pump

. MOV-3976, B MEW 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%.

I I EOP: TITLE:

REV: 15

-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED PAGE 12 of 16 I,

STE ..

ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINED 10 Verify TDAFW Pump Aligned For AUTO Start:

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

b. Verify AMSAC TRIPPED status b. Reset AMSAC.

light - EXTINGUISHED

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

d. Verify Bus 11A and Bus 11B - AT d. Perform the following:

LEAST ONE ENERGIZED

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

\K>

• MOV-3504A

• MOV-3505A

2) Go to Step 11.

e. Verify the following:

1) TDAFW pump - OFF 1) Perform the following:

a) IF TDAFW pump required to maintain S/G level. THEN go to Step 12.

b) Stop TDAFW pump.

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

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

• AOV-4297

• AOV-4298

EOP: TITLE:

I REV: 15 AP-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED I .PAGE 13 of 16 STP ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINEDI 11 Establish Normal AFW Pump Shutdown Alignment:

a. Place AEW bypass switches to DEE

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 MDAEW pump discharge valves

. MOV-4007

• MOV-4008

d. Adjust AFW bypass valves to control S/G levels at 52%

• AOV-4480

• AOV-4481

ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINED 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

STP ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINED 13 Etabish Sstes ontol I

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 valves 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 heat4arc, 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

IEOP: TITLE:

REV: 15

[P-TURB.1 TURBINE TRIP WITHOUT RX TRIP REQUIRED

. . PAGE 16 of 16 STP ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINEDl 17 Establish Desired Plant Conditions:

a. Reactor shutdown - DESIRED a. IF turbine is to be restored to cservice. 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: 13 KP-TURB.3 TURBINE VIBRATION PAE 1 I9 PAG f l GINNA STATION CONTROLLED COPY NUMBER ____

CQCC6.Laj RESPONSIBLE MANAGER 6_ M c S EFFECTIVE DATE CATEGORY 1.0 REVIEWED BY:

A

.EOP: lTITLE:RE: 1 TLP-TURB.E3 TURBINE VIBRATION PAGE 2 of 9 A. PURPOSE - This procedure provides the necessary actions to be taken in the event of increasing turbine vibrations.

B. ENTRY CONDITIONS/SYMPTOMS

1. ENTRY CONDITIONS - This procedure is entered from:

a. N/A

2. SYMPTOMS - The symptoms of TURBINE VIBRATION are;

a. Increasing or High Turbine Vibration detected, or

b. Annunciator I-27, Rotor Eccentricity or Vibration alarm is lit, or

c. Annunciator K-10, Turbine High High Vibration alarm lit.

EOP: TITLE:

REV: 13 AP-TURB.3 TURBINE VIBRATION

. . PAGE 3 of 9.

ACTION/EXPECTED RESPONSE llRESPONSE NOT OBTAINED STE

• 1 Verify Turbine Vibration - Perform the following:

ALL BEARINGS LESS THAN 14 MILS IF power greater than P-9, THEN trip the reactor and go to E-O.

REACTOR TRIP OR SAFETY INJECTION.

IF power less than P-9, THEN trip the turbine and go to AP-TURB.1.

TURBINE TRIP WITHOUT RX TRIP REQUIRED.

A.

EOP: TITLE: REV: 13 AP-TURB.3 TURBINE VIBRATION PAGE 4 of 9 STEP ACTION/EXPECTED RESPONSE 1RESPONSE NOT OBTAINED NOTE: IF power reduction is required the thumb rule for initial boron addition is -2 gal/% load reduction.

2 Check Turbine Vibration:

a. Bearings No. 1 through No. 8 - a. Attempt to stabilize vibration LESS THAN 7 MILS as follows:

o IF increasing turbine speed, THEN stop speed increase and evaluate. Evaluate reducing speed to a non-resonance region. (Refer to 0-1.2) o IF generator on line. THEN begin reducing load to stabilize vibrations. (Refer to AP-TURB.5. RAPID LOAD REDUCTION)

b. Bearing No. 9 - LESS THAN b. Attempt to stabilize vibrations 8.5 MILS as follows:

o Adjust generator hydrogen temperature.

-OR-o Adjust turbine lube oil temperature,

-OR-o Adjust exciter cooling,

-OR-o Adjust generator seal oil cooling.

A.

EDP: TITLE:

1 REV: 13 AP-TURB.3 TURBINE VIBRATION

. . PAGE 5 of 9.

STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 3 Evaluate Plant Conditions:

a. Check turbine vibrations - a. Reduce turbine load until STABLE OR DECREASING turbine vibrations stabilize.

IF vibrations can NOT be stabilized with the plant at power. THEN take unit off line (refer to AP-TURB.5, RAPID LOAD REDUCTION)

b. Stop load reduction

EOP: TITLE:

REV: 13 AP-TURB.3 TURBINE VIBRATION PAGE 6 of 9 ACTION/EXPECTED RESPONSE l RESPONSE NOT OBTAINED I 4 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.

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.

ACTION/EXPECTED RESPONSE llRESPONSE SP NOT OBTAINED 5 Evaluate Turbine Operation:

a. Verify no unusual noises exist a. IF unusual noises detected, THEN locally at turbine generator notify the Maintenance Manager.

b. Monitor turbine supervisory instrumentation to ensure conditions stable o Turbine Vibration Recorder (Front of MCB) o Turbine Vibration Monitor (Back of MCB)

K>1-

VF EOP: TITLE:

REV: 13 AP-TURB.3 TURBINE VIBRATION P

. . lPAGE 8 of 9 STEP ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 6 Establish Control Systems In Auto:

a. Restore EH controls

1) Place in OP PAN. IMP OUT

2) Place load rate thumbwheel to 10%/hr

3) Match setter and reference

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

1) Ensure steam dump valves cloned.

2) Reset steam dump.

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

if desired.

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 spray valves in AUTO f. Place spray valves in AUTO, if desired.

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

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

RESET, IN AUTO

h. Verify MEW regulating valves in h. Place MEW regulating valves in AUTO AUTO, if desired.

ACTION/EXPECTED RESPONSE llRESPONSE STP NOT OBTAINEDl 7 Evaluate MCB Annunciator Status (Refer to AR Procedures) 8 Notify Higher Supervision

-END-