Text

July-August Exam 50-325, 324/2007301 Final JPMs (3 of 4)
	ML072960573
Person / Time
Site:	Brunswick
Issue date:	01/31/2007
From:	; - No Known Affiliation
To:	; Office of Nuclear Reactor Regulation
References
	50-324/07-301, 50-325/07-301 50-324/07-301, 50-325/07-301
	Download: ML072960573 (190)
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NRC 81M JPM 8-2 1 of 10 PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION JOB PERFORMANCE MEASURE NRC 51M JPM 5-2 TITLE: RCIC SYSTEM OPERATION NRC SIM JPM S-2 2 of 10 SAFETY CONSIDERATIONS:

None.

EVALUATOR NOTES: (Do not read to trainee)

1. The applicable procedure section WILL be provided to the trainee.

2. This is an ALTERNATE PATH JPM

3. Validation time is 20 minutes.

TASK CONDITIONS:

1. Unit Two (2) is in Mode 1.

2. OPT-1 0.1.1, RCIC System Operability Test, is in progress.

3. Personnel are in the field in support of the RCIC surveillance.

4. All pre-job and ALARA briefs have been completed.

5. The HP Window has been notified of the anticipated rad level changes when steam is admitted to the RCIC turbine.

6. Brunswick Security personnel have been notified of restricted access to the Unit Two (2) -17 foot elevation during the RCIC operation.

7. Standby Gas has been started per OP-1 0 to support testing.

8. OPT-10.1.1 has been completed up to, and including, Step 7.9.4.

9. A second operator is available to monitor Suppression Pool level and temperature.

10. Drywell to Torus Vacuum Breaker monitoring equipment is installed.

INITIATING CUE:

You are directed by the Unit Two (2) SeQ to continue with the performance of OPT-10.1.1 beginning with Step 7.10.1.

NRC SIM JPM S-2 3 of 10 Step 1 - Obtain and Review OPT-1 0.1.1.

Obtains and reviews OPT-1 0.1.1, begins at step 7.10.1 SAT/UNSAT Step 2 - OPEN COND PUMP DISCH INBD DRAIN VALVE, E51-F004.

2-E51-F004 is Opened. SAT/UNSAT Step 3 - CONFIRM RCIC SYSTEM PRESS LOW (A-02, 2-6) annunciator is clear.

SYSTEM PRESS LOW (A-02, 2-6) annunciator is clear. SAT/UNSAT PROMPT: When oil level is requested, report that it is normal Step 4 - ENSURE the RCIC lubricant oil level is normal.

RCIC lubricant oil level is normal. SAT/UNSAT PROMPT: When local suction pressure indication is requested, inform the candidate that suction pressure is 52 psig.

Step 5 - RECORD RCIC pump suction pressure (stopped) indicated on E51-PI-R002 (local) on Attachment 2.

RCIC pump suction pressure (52 psig) recorded on Attachment 2, page 34 of 43 ..

SAT/UNSAT NRC SIM JPM S-2 4 of 10 Step 6 - IF RCIC pump suction pressure is' greater than or equal to 29 psig, THEN RECORD RCIC CONDENSATE CHECK VALVE TO PUMP, E51-F011 and RCIC CONDENSATE PUMP DISCHARGE LINE CHECK VALVE, E51-F047 are closed on Attachment 3.

E51-F011 recorded on Attachment 3, page 37 of 43.

SAT/UNSAT E51-F047 recorded on Attachment 3. SAT/UNSAT Step 7 - Step 7.10.5 determined to be not applicable.

Step 7.10.5 determined to be not applicable. SAT/UNSAT PROMPT: WHEN requested, inform the candidate that suppression chamber to drywell vacuum breaker monitoring has been established and that all of the vacuum breakers indicate CLOSED.

Step 8 -IF desired, THEN ESTABLISH MONITORING of the suppression chamber to drywell vacuum breakers.

Suppression chamber to drywell vacuum breaker monitoring established.

SAT/UNSAT Step 9 - CLOSE COND PUMP DISCH INBD DRAIN VLV, E51-F004.

E51-F004 CLOSED. SAT/UNSAT NRC SIM JPM S-2 5 of 10 Step 10 - OPEN REDUNDANT ISOL TO CST VLV, E41-F011.

E41-F011 OPENED.

- CRITICAL STEP** SAT/UNSAT Step 11 - START BAROMETRIC CNDSR VACUUM PUMP.

Barometric Condsr Vacuum Pump started. SAT/UNSAT Step 12 - OPEN COOLING WATER SUPPLY VLV, E51-F046.

E51-F046 Opened.

- CRITICAL STEP** SAT/UNSAT Step 13 - THROTTLE OPEN BYPASS TO CST VLV, E51-F022, 2 to 4 seconds, unless otherwise directed by the Unit SCO.

E51-F022 throttled open approximately 3 seconds.

- CRITICAL STEP** SAT/UNSAT Step 14 - DISPATCH an auxiliary operator to observe the system discharge piping for excessive motion and water hammer during startup of the RCIC System.

Auxiliary operator dispatched. SAT/UNSAT NRC SIM JPM S-2 6 of 10 Step 15 - EVACUATE all personnel below the Reactor Building 20' Elevation east half.

Announces that personnel evacuate from Reactor Building below the 20' Elevation east half.

SAT/UNSAT PROMPT: WHEN requested, inform the candidate that suppression pool monitoring has been established.

Step 16 - MONITOR suppression pool temperature at intervals less than or equal to 5 minutes to ensure the average suppression pool temperature is less than 104°F.

Suppression Pool temperature monitoring is established.

SAT/UNSAT NOTE: Twenty seconds after the 2-E51-F045 is opened, indications of an Exhaust Diaphragm Failure will be present. This should result in an Automatic RCIC Steam Line isolation and RCIC Turbine trip.

However, these functions will fail to automatically occur.

Step 17 - Open the RCIC Turbine Steam Supply Valve, 2-E51-F045.

2-E51-F045 is opened.

- CRITICAL STEP** SAT/UNSAT NRC SIM JPM S-2 7 of 10 NOTE: The recognition of a failure of the E51-F007 and E51-F008 to close and the candidate's actions to close them may be performed in either order.

Step 18 - Recognize RCIC Isolation Signal "A" light is lit and the 2-E51-F007 not closing.

2-E51-F007 failure to isolate is recognized.

SAT/UNSAT Step 19 E51-F007 CLOSED by taking the control switch to the CLOSE position.

2-E51-F007 closed using the control switch. **CRITICAL STEP**

SAT/UNSAT Step 20 - Recognize RelC Isolation Signal "8" light is lit and the 2-E51-F008 not closing.

2-E51-F008 failure to isolate is recognized.

SAT/UNSAT Step 21 E51-F008 CLOSED by taking the control switch to the CLOSE position.

2-E51-F008 closed using the control switch. **CRITICAL STEP**

SAT/UNSAT Step 22 - Recognize RCIC TURBINE TRIP failed to actuate.

RCIC TURBINE TRIP failure recognized. SAT/UNSAT NRC 81M JPM S-2 8 of 10 NOTE: Tripping the RCIC Turbine is not critical because closure of either the E51-F007 or E51-F008 will isolate steam to the RCIC turbine.

Step 23 - RCIC Turbine tripped using the trip pushbutton on the RTGS.

RCIC turbine tripped using the manual pushbutton. SAT/UNSAT Step 24 - Notify the SCQ that RCIC had failed to isolate automatically on a valid signal and that RCte has been isolated and tripped by operator action.

SCQ notified of RCtC status. SAT/UNSAT TERMINATING CUE: When the 2-E51-F007 and 2-E51-F008 areCLQSED and the SCQ is informed of the status, this JPM is complete.

NRC SIM JPM S-2 9 of 10 RCIC EXHAUST DIAPHRAGM FAILURE WITH A RCIC FAILURE TO ISOLATE RELATED TASKS:

217000 K1.07 3.1/3.2 Knowledge of the physical connections and lor cause-effect relationships between REACTOR CORE ISOLATION COOLING SYSTEM (RCle) and Leak Detection.

217000 A2.14 3.3/3.4 Ability to (a) predict the impact of a rupture disc failure: Exhaust-Diaphragm on the Reactor Core Isolation System ,

(RCIC); and (b) based on those predictions, mitigate the consequences of the abnormal condition.

REFERENCES:

OPT-10.1.1, Rev. 89 TOOLS AND EQUIPMENT:

None.

SAFETY FUNCTION (from NUREG 1123, Rev 2.):

5 - Containment Integrity Time Required for Completion: 20 Minutes (approximate).

APPLICABLE METHOD OF TESTING Performance: Simulate Actual X Unit: 2 Setting: Control Room Simulator X Time Critical: Yes No X Time Limit NIA Alternate Path: Yes L No EVALUATION Trainee:

JPM: Pass Fail Comments:

TASK CONDITIONS:

1. Unit Two (2) is in Mode 1.

2. OPT-1 0.1.1, RCIC System Operability Test, is in progress.

3. Personnel are in the field in support of the RCIC surveillance.

4. All pre-job and ALARA briefs have been completed.

5. The HP Window has been notified of the anticipated rad level changes when steam is admitted to the RCIC turbine.

6. Brunswick Security personnel have been notified of restricted access to the Unit Two (2) -17 foot elevation during the RCIC operation.

7. Standby Gas has been started per OP-1 0 to support testing.

8. OPT-10.1.1 has been completed up to, and including, Step 7.9.4.

9. A second operator is available to monitor Suppression Pool level and temperature.

10. Drywell to Torus Vacuum Breaker monitoring equipment is installed.

INITIATING CUE:

You are directed by the Unit Two (2) SeQ to continue with the performance of OPT-10.1.1 beginning with Step 7.10,1.

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~

~ Progress Energy BRUNSWICK NUCLEAR PLANT Continuous Use DATE COMPLETED _ FREQUENCY:

UNIT _ _ % PWR GMWE _

SUPERVISOR. _ ~. Once every 92 days in Modes 1,2, and 3.

REASON FOR TEST (check one or more): B. Leakage 'Walkdown - at least once per 24 Routine surveillance months.

WO # _

__ Other,(explain) _

PLANT OPERATING MANUAL' VOLUME X PERIODIC TEST UNIT o

OPT-10.1.1 RCIC SYSTEM OPERABILITY TEST REVISION 89 IOPT-10.1.1 Rev. 89 Page 1 of43 I

7.0 PROCEDURAL STEPS Initials

[ill 7.1 7.2 OBTAIN permission from the Unit sca to perform this test.

CONFIRM reactor pressure is between 945 psig and 1045 psig.

+-

7.2.1 IF reactor pressure is less than 945 psig, THEN JljL SLOWLY INCREASE the setpoint of the pressure regulator to attain at least 945 psig.

NOTE: Fire watch inspections in the 20' EGGS room should be coordinated with Security to ensure they are completed as required while performing this test.

OFPP-005 requires a fire watch inspection in the 20' ECGS Room once every clock hour. Additionally, 30 minutes should elapse between fire watch inspections in an area. Fire watch inspections established for impairments in areas that could be affected by this test should be coordinated also.

7.3 CONTACT Security AND COORDINATE fire watch inspections. +-

7.4 PERFORM the following notifications:

7.4.1 NOTIFY E&RC of the estimated time of RCIC turbine operation.

L 7.4.2 WHEN available, THEN NOTIFY I&C and Maintenance Supervisors of RetC turbine and pump

-l-run so they can observe operation, if desired.

7.5 ENSURE prerequisites listed in Section 4.0 are met. --L 7.6 ENSURE the required data has been recorded in Section 5.0. L 7.7 ENSURE RHR is in the suppression pool cooling mode, in y

accordance with 1(2)OP-17.

7.8 PERFORM the following to place the SBGT in service:

7.8.1 IF HPCI is NOT in standby, THEN ENSURE HPCI VACUUM PUMP DISCHARGE TO SBGT SYSTEM 4

VALVE, E41-V30, is open.

IOPT-10.1.1 Rev. 89 Page 13 of 431

7s0 PROCEDURAL STEPS Initials 7.8.2 START SBGT in accordance with 1(2)OP-10. L 7.8.3 ENSURE the following valves are open:

1. POST LOCA VENT, SGT-V8.

L

2. POST LOCA VENT, SGT-V9.

-L-7.9 Verification of Filled Discharge Piping 7.9.1 IF required, THEN CONNECT a vent and drain rig to RCIC PUMP DISCHARGE HEADER VENT VALVE, JJ/L E51-V33.

7.9.2 THROTTLE OPEN RCIC PUMP DISCHARGE HEADER VENT VALVE, E51-V33.

L 7.9.3 WHEN a solid stream of water issues from the vent, THEN CLOSE RCIC PUMP DISCHARGE HEADER l

VENT VALVE, E51-V33.

7.9.4 IF desired, THEN REMOVE the vent and drain rig. .Jl/L IOPT-1 0.1.1 Rev. 89 Page 14 of 431

7.0 PROCEDURAL STEPS Initials IR291 7.10 Pump Operability Testing 7.10.1 OPEN COND PUMP DISCH INBD DRAIN VL V, E51-F004.

1. CONFIRM RCIC SYSTEM PRESS LOW (A-02 2-6) annunciator is clear.

7.10.2 ENSURE the RCIC lubricant oil level is normal.

7.10.3 RECORD RCIC pump suction pressure (stopped) indicated on E51-PI-R002 (local) on Attachment 2.

NOTE: A suction pressure of greater than or equal to 29 psig confirms RCIC CONDENSATE CHECK VALVE TO PUMP, E51-F011, and RCIC CONDENSATE PUMP DISCHARGE LINE CHECK VALVE, E51-F047, are closed.

7.10.4 IF RCIC pump suction pressure is greater than or equal to 29 psig, THEN RECORD RCtC CONDENSATE CHECK VALVE TO PUMP, E51-F011 and RCIC CONDENSA TE PUMP DISCHARGE LINE CHECK VALVE, E51-F047 are closed on Attachment 3.

7.10.5 IF RCIC suction pressure is NOT greater than or equal to 29 psig, THEN PERFORM the following:

1. RECORD RCIC suction pressure and CST level in the Comments Section of Attachment 1.

2. SLOWLY THROTTLE OPEN RCIC KEEPFILL STATION BYPASS VALVE, E51-V70, while monitoring RCle suction pressure.

IOPT-10.1.1 Rev. 89 Page 15 of 431

7.0 PROCEDURAL STEPS Initials

3. IF RCIC suction pressure increases to greater than or equal to 29 psig THEN PERFORM the following:

a. IMMEDIATELY CLOSE RCIC KEEPFILL STATION BYPASS VALVE, E51-V70.

b. RECORD RCIC CONDENSATE CHECK VALVE TO PUMP, E51-F011 and RCIC CONDENSATE PUMP DISCHARGE LINE CHECK VALVE, E51-F047 are closed on Attachment 3.

4. IF RCIC suction pressure does NOT increase to greater than or equal to 29 psig AND flow is evident through the keepfill bypass line, THEN PERFORM the following:

a. CLOSE RCIC KEEPFILL STATION BYPASS VALVE, E51-V70.

b. NOTIFY the Unit sca that the E51-F011 and E51-F047 valve positions could NOT be confirmed closed.

c. NOTIFY Engineering for determination.

NOTE: Technical Specifications 3.6.1.6.2 (Modes 1, 2, or 3) requires completion of OPT-02.3.1 Suppression Chamber To Drywell Vacuum Breakers Operability J

Test, within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months following an operation that causes any of the vacuum breakers to open. The test is NOT required if vacuum breakers are monitored and determined to remain closed.

7.10.6 IF desired, THEN ESTABLISH MONITORING of the suppression chamber to drywell vacuum breakers.

7.10.7 CLOSE COND PUMP DISCH INBD DRAIN VL~

E51-F004.

7.10.8 OPEN REDUNDANT ISOL TO CST VL V, E41-FO 11.

7.10.9 START BAROMETRIC CNDSR VACUUM PUMP.

7.10.10 OPEN COOLING WATER SUPPLY VL~ E51-F046.

IOPT-10.1.1 Rev. 89 Page 16 of 431

7BO PROCEDURAL STEPS Initials NOTE: The System Engineer may have trend data that will assist in positioning BYPASS TO CST VLV, E51-F022, as needed (ESR 99-00507).

7.10.11 THROTTLE OPEN BYPASS TO CST VL V, E51-F022, 2 to 4 seconds, unless otherwise directed by the Unit SCQ.

7.10.12 DISPATCH an auxiliary operator to observe the system discharge piping for excessive motion and water hammer during startup of the RCIC System.

7.10.13 EVACUATE all personnel below the Reactor Building 20' elevation east half.

7.10.14 MONITOR suppression pool temperature at intervals less than or equal to 5 minute to ensure the average suppression pool temperature is less than 104°F.

NOTE: WHEN evolutions are in progress with the potential to change suppression pool level, THEN a second operator is necessary to monitor suppression pool level.

T.5 J"tr-o~

fJ 7.10.15 OPEN TURBINE STEAM SUPPLY VLV, E51-F045. _r/rl ",!

fJ)/1 II c....c-... r

- - - - - - - - - - - , , . . - - - - - - - - - r - o - - - - - - _ P-.t/#..>.,o.j IIJ~

IOPT-10.1.1 I Rev. 89 I Page 17 of43 I /

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780 PROCEDURAL STEPS Initials 7.10.16 CONFIRM RCIC turbine starts and develops a flow of greater than or equal to 400 gpm AND RECORD the start time below:

NOTE: Depending upon the number of valve motor starts required in the following step, consideration may be given to manually'throttling the valve.

NOTE: The required test flow/pressure condition can usually be obtained by increasing the flow controller setpoint to between 480 and 500 gpm, and then throttling E51-F022 in 0.5 to 1.0 second increments.

7.10.17 ADJUST RCtC FLOW CONTROL, E51-FIC~R600, and BYPASS TO CST VL V, E51-F022, as necessary, to obtain a pump discharge pressure of greater than or equal to 1130 psig with a pump flow rate of greater than or equal to 400 gpm.

7.10.18 RECORD the following AND CIRCLE the indicator used when appropriate:

1. Pump discharge pressure on E51-PI-R601.

_ _ _ _ _ _ _psig

2. Pump flow rate on E51-FIC-R600.

_ _ _ _ _ _ _,gpm

3. Reactor pressure on C32-R609 OR C32-R60B.

- - - - - - -psig

!OPT-10.1.1 Rev. 89 Page 18 of 431

TASK CONDITIONS:

1. Unit Two (2) is in Mode 1.

2. OPT-10.1.1, RCIC System Operability Test, is in progress.

3. Personnel are in the field in support of the RCIC surveillance.

4. All pre-job and ALARA briefs have been completed.

5. The HP Window has been notified of the anticipated rad level changes when steam is admitted to the RCIC turbine.

6. Brunswick Security 'personnel have been notified of restricted access to the Unit Two (2) -17 foot elevation during the RCIC operation.

7. Standby Gas has been started per QP-1 0 to support testing.

8. OPT-10.1.1 has been completed up to, and including, Step 7.9.4.

9. A second operator is available to monitor Suppression PoolleveJ and temperature.

10. Drywell to Torus Vacuum Breaker monitoring equipment is installed.

INITIATING CUE:

You are directed by the Unit Two (2) SCQ to continue with the performance of OPT-10.1.1 beginning with Step 7.10.1.

c ti Progress Energy BRUNSWICK NUCLEAR PLANT Continuous Use DATE COMPLETED _ FREQUENCY:

UNIT _ _ % PWR GMWE _

SUPERVISOR - - . - - - - - - - - - - - - - - ~. Once every 92 days in Modes 1 2, and 3.

t REASON FOR TEST (check one or more): B. leakage Walkdown - at teast once per 24 Routine surveillance months.

WO # _

__ Other (explain) _

PLANT OPERATING MANUAL VOLUME X PERIODIC TEST UNIT o

OPT-10.1.1 RCIC SYSTEM OPERABILITY TEST REVISION 89 IOPT-10.1.1 Rev. 89 Page 1 of 43 I

,U 1.0 PURPOSE 1.1 This test is performed to determine the 'operability of the Rele System in confb"rmance.with the requirem.ents specified in the ASMEBoHer and Pressure Vessel Code, Section Xl, ASME/ANSI-OM-CODE, and, Technical Specifications 5.5.6, TRM*3.14 andSR3.5,~'3.3t SR3.6.1.6.1, and SR* ,3.'6.1.6.2. Ital50 satisfies Technical Specification SR 3.6.2.1.1 to monitor suppression, pool temp.erature at least every five minutes while addi.ng heat and**TechnicaISpecification:5.5.2'for leakti:ghtnessinspectj'onevery 24 months.

1.2 The following test quantities shall be measured, observed, or calculated as applicable:

1.2.1 Valve stem* travel or disk movement 1.2.2 Pump discharge pressure 1.2.3 Pump flow rate 1.2.4 Reactor pressure 1.2.5 Turbine speed (rpm) 1.2.6 Pump suction pressure (stopped and running) 1.2.7 Pump vibration velocity 1.2.8 Pump lubricant level/pressure 1.2.9 Pump differential pressure (calculated) 2.0 REFE'RENCES I R11 2.1 Technical Specifications 3.5.3.3, 3.6.1.6.1, 3.6.1.6.2, 3.6.2.1.1, 5.5.2a & b, 5.5.6, TRM' 3.14 2.2 FSAR, Section 7.4.1 2.3 1(2)OP'-1 0, Standby Gas Treatment System Operating Procedure 2.4 1(2)OP- 16, Reactor Core Isolation Cooling System Operating Procedure

[ OPT-10.1.1 Rev. 89 Page 2 of 43 I

1;.1

t: J

2.0 REFERENCES

2.5 1(2)OP-17, Residual Heat Removal System Operating Procedure 2.6 t(2)OP-51, D,C ElectricaISystemOperating--Procedure 2.7 1(2)OP-59 Hydrogen Water Che-mistry System Operating Procedure l

2.8 OOI-65,'Operation-ofIR-DMo-del 890 Data Collector 2.9 8D-16, Reactor Core Isolation Cooling System Description 2.10 ASME Boiler and Pressure Vessel Code, Section Xl~ 1989 Edition 2.11 AN-SI/AS-ME, OM:-1987, nOperationand-M*aintenance of Nuclear" Power Plants," w/OMa-1988 Add-enda 2.12 OPT-02.3.1 ,Suppression -Chamber-To Drywell Vacuum Breakers Operability Test 2.13 OPT~02.3. tb; Suppression Pool to Drywell Vacuum* Breaker Position Indication Check 2.14 OENP-16.1, 1ST Pump and Valve Data 2.15 OENP--17, Pump and-Valve Inservice Testing (1ST) 2.16 NU-REG-0737, Item III.D.1.1, Integrity ofSystamsOutside Containment Likely to Contain Radie>active Material for Pressurized Water Reactors and Boiling Water Reactors I R17 1 2.17 CP&L Response to NRC Bulletin 88-04, Potential Safety--Related Pump Loss IRIS I 2.18 GE- SIL No. 106 Rev. 2, Suppression -Pool Tem-p_erature Monitoring and Control IR19 1 2~19 SOER 89-1, Testing of Steam Turbine/Pump Overspeed.Trip Devices 2.20 GE SI~-623)RCIC Pump Discharge Pressure 2.21 EGR-NGGC-0010, System & Component Trending Program and System Libraries 2.22 OE-NP-23, Predictive Maintenance Program

!OPT-10.t.1 Rev. 89 I Page 3 of43 I

,) 1

"_1 P 2.. 0 REFERENCES 2.23 Pipin"g Diagram, D-02529, "SH.1, Reactor Core Isolation CoolingSystem J U"nit2 2.24 Pi"ping Diagram, D-02529, SH.2, Reactor Core Isolation Cooling System, Unit2 2.25 Pi"ping Diagram, 0-25029, SH.1,ReactorCore Isolation Cooling System, Unit 1 2.26 Piping Diagram, 0-25029, SH.2, Reactor Core Isolation Cooling System, U"nit 1 2~27 NUREG1482,Guidelines For Inservice Testing at Nuclear Power PI;ants 2.28 OFPP-005, Fire Watch Program IR291 2.29 SOER01-01, Unplanned Radiation Exposure, Recommendation 6d 3..0 PRECAUTiONS" AND LIMITATI"ONS 3.1 The following annunciators may alarm during the performance of this test

3~ 1.1 RCle TURBINE TRIPPED (A-03 5-3) 3.1.2 RCIC VACUUM TANK PRlZSS HI (A-03 6-4) 3.1.3 RCle TURa OIL PRESS LO (A-03 5-4) 3.1.4 ROle PUMP DISCH FLOW LO (A-03 3-4) 3.2 Tesflnform"ati:on Attachments 2 and 3 shall be reviewed by the 1ST group.

3. 3 Suppression pool water shall not be injected into the. reactor vessel during the performance of this* test.

IOPT-10.1.1 R'ev.89 page40f43!

"1:\ }l 3.0 PRECAUTIONS AND LIMITATIONS

[]I] 3.4 Confirm s.uppression pool average temperature less than 105°F every 5 minutes 'whenadd"ingh-eatto the suppression pool as required by SR 3.6.2.1.1.

3.4.1 When suppression pool average water temperature is. greater than 95°F, then suppression pool temperature shall be logged at 30 minute intervals.

IRisl 3.5 When the RCIC System is discharging steam into the suppression pool, then suppression po~1 cooling should be in service to insure proper mixing. for the best possible indication of average*water tem.perature.

3.6 Suppression pool'-cooHng>should be pl'aced in. service prior to .starting RCle turbine*op'eration. Both RHR Loops may be' required for suppression pool cooling if a*verage cooling water inlet temperature is greater than 80°F.

3.7 Suppression:pool'averagewater temperature may be monitored using Process Computer points G050 an'd G051 for operator convenience.

However,Technical Specifications function must-.be*,verified using, the S PTMS temperature, recorders CAC-TR-4426-1A(2A) and CAC- TR~4426-1B(2B).

JD 3.8 If average suppression pool temperature reaches 104°Pt then RCle System should ..be shut down. The maximum aliowabJesuppression pool temperature duri.ngte~tingwhichaddsheat to the suppression pool is r05°F.(LCO 3.6.2~1 Action C).

[]I] 3.9 If average'suppression pool temperature exceeds 110°F) then the 'reactor must be scrammed in accordance* with Tech Spec 3~6.2.1.

3.10 When' evolution*s are in progress that have the potential to chang,e suppression pool level, then a*secondoperator is necessary to monitor suppression poo.I*leveL Ri7 1 3.11 Operation of the RCIC System under minimum flow conditions with MIN I

FLOW BYPASS to -TORUS VLV':E5*1-F019 open should be minimized to J

reduce.suppression pool level increases. .

3.12' The stea.m I*ine to the turbine must be completely drained prior to any turbine operation.

3.13 To ensuFeaclequateoilpressure and to preventexhaustvalve chattering, operation* of.tl,-e* RC.IC. turbine below 2000 rpm should ba kept to a minimum.

[OPT-10.1.t. Rev: 89 . Page 5 of4$ I

)1 1.:;;1 3.0 PRECAUTIONS AND LIMITATIONS 3.14 DC Limitorque valves are limited to a duty cycle of 3 starts in 5 minutes followed by a 50-minute cooldown period'except:

3.14.1 Valves 1(2)E51-F013, 1(2)E51-F019, 1(2)E51-F045, and 1(2)E51-V8 have a duty cycle of 6 starts and, 3.14.2 1(2)E5'1-F022 is allowed 9 actuations with an average duration of 3 seconds (or less) with at least*15 seconds*between* actuations in accordance with guidelines estCilblish'e'd by ESR 94-00802.

Any valve actuation, whether in the form of a throttle action, a continuous stroke, or any auto-actuated movement, is considered a.motor,start Adherence to the duty cycle requirements win minimize DC valve motor failures.

3.15 The Rele turbine has the* potential for failures that could causepersohnel injuries. The potential is most significant when the system is initially started after control system maintenance or after an extende'dperiod of bei'ng idle.

An'nouncing turbine starts and clearing of anpersonnel,below*the R'eact6r .

Buildi'ng 20' el'evation east half are require'dduring' this,.period,-*of risk.

Permission to access this area during initial RCIC' turbine roll, requires>the approval* of the Unit SeQ.

)

lli!J 3.16 Failure to ensure each suppression chamber to'dryweUYCicuum'breakeris cfosed(OPT-02.3.1b forSR 3.6.1.6.1) and functionaL(OPT~02..3.1*.or observing valve position for SR3.6.1.6.2) win violate Technica',

Sp'ecifications.

3.17 The vibration velocity readings shall be taken at the test positions .specifi'ed on the Data Sheet Ensure the probe is located on thecorrectbe'aring in, accordance with Attachment 6.and in the correct direction as specified on Attachment '2.

3.18 When taklngvibratio.n rea~ingst then the accelerometer-probeshall'be'used with the magnetic holder for each test p*osition*and,the*J)robe**must**be infirm contact with the bearing housing.

3.19 When ta'king pressure readings to be recorded on Attachment 2, th'e indicator/pointer fI.uctuation*should beredu.ced to*a.minimum. A'valve' upstream. of theg*aug.e. maybe throttled' loreaiJcefl.uctu¢.)lipn.*Care* srrould be taken to ensure 'propet communication, be1'Neen gauge. and .main* flaw path.

IOPT-1 0.1.1 R.ev.89 I Page 6 of43.1

11 3.0 PRECAUTIONS AND LIMITATIONS 3.20 The HPCI System should be operable prior to and during the performance of this test, for Mode 1, 2, and 3 testing.

jR291 3.21 During RCIC turbine operation using react~r steam, caution should be used when entering the south RHR area and the mini-steam tunneL A portabr.e radiation monitor should be carried to check for high radiation levels and to prevent in'advertent exposure~to*personnel.

3.22 Hydrogen injection rateshoufd be minimized,in .accordance with 1(2)OP-59 and Chemistry concurrence, during performance of this test to reduce personnel radiation exposure.

3.23 If RetC System automatic initiation'shouldoccur while the' RelC FLOW CONTROL, E51..;FIC-R600, is in manual(M), then. the controller ~haltbe immediately returned to automatic (A}to'allowprQpero'peration .ofthe system. Depressing thePF pushbutton on the controller win immediately place the controller in automatic (A) at400.9pm.

3.24 The RCICSystem will be inoperable while the mechanical'oversfJeed. device is in the tripped position. Therefore, all efforts: to quiCkly reset the device .

should be made.

3.25 When using temporary test gauges, then the full scale range of each instrument shaH be three times the reference value or less, with ad:equate low range to prevent damage duriQ9 use.

3.26 If an overspeed event occurs and pump discharge pressure 'ofgreaterthan .

1500psig is noted, then a routine walk down of the SRHR roomfC).r leakag.e-should be performed. Engineering .should be contacted' for estimcttion'of maximum*discharge pressure above*1*SOO psig, in*accordancewith ESR 99-00507. If no significant Joint leak-age. is' noted and the estimated pressure is .less than 2000 psig, an' Operatio'ns' LO'g entry shouldbe'made documenting the overpressure event and walkdown. For discharge pressures estimated greater than 2000 psig, Engi.neeriJlgwUI.provi.de, analysis of the piping equipment prior to declaring the* system operable fonowing the event.

3~27 During'system.venting, air is not expected in the system. If air is found, then a W/O* should be initiated and tnesystem engineer notified olthe condition.

The presenceofaJr in the system does not mean' the -system' isinoperabl*e.

but can imply component degradation that mustbeadores.sedats.p:m*epoint.

Thetas,! may be continued provided the air in the system i*sTemoved by.the normal venting process.

[ OPT-10.l.1. Rev. 89 .*. Page 7 of43 I

3.0 PRECAUTIONS AND LIMITATIONS 3.28 The locar lube oil sight glass has a scale that indicates a norrnallevel range.

TheoH Jevel should be in the normal range when the turbine lubeoil'system has been shutdown for a while (up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ma*y be needed for the level tostabilize*after a turbine run). When the turbine lube*oil system is in operation) oil level will norma-lly drop and take* time to return to the Ustandstill" normal level in the sight glass, this is not-a*problem as lo-ng as there is visible oil in the sight glass.

4.0 PREREQUISITES 4.1 No other testing or maintenance is in progress that wiUadversely affect.the performance-of this test 4.2 The SBGT System is in standby in accordance with l(2).OP-tO.

4.3 Rete System is in standby in accordance 'with 1(2)O*P:16.

4.4 The *station battery chargers are in operation in accordance with 1(2)OP-51.

lli!J 4.5 The suppression pool level is between -27 inches and' -31 inch'es.

4.6 Ensure maintenance is available to take oil samples when. the. run is complete.

IOPT-tO.1.1 Rev. 89 I Page 8 of43 1

5.0 SPECIAL TOOLS AN,DEQUIPM'ENT 5.1 C'onfirm no, active corrective maintenance WOexists on the following l

installed instru'ments. IF any active WO exists, THEN operability of the instrument mustbe resolved and recorded in the General Comments and Recommend,ationssection before the instrument may be used.

Instrument WO wo#

5.1.1 E51-FT-N003 yes~

5.1.2 E51-F/C-R600 yes@

5.1.3 E51-PT-N004 yesAfiW 5.1.4 E51-P/~R'601 yestfig) 5.1.5 E51'-Pi-ROOt yes@

5.1.6 E51~PI-R004 ye~

,5.1.7 E51-PT-N007 yes~

5.1.8 E51-PI-R602 yes~

5.1.9 E51-PT-N008 yes~

5.1.10 E51-P/-R603 ye~

5.1.11 E51-PI-3005 yeS@

5.1.12 C32-PT-N008 yes.{@)

5.1.13 C32-PR~R609 yes>c 5.1.14 E51-PJ;-R002 ye~

5.1.15 E51-P/...R003 yes@

5.'1.'16 C32~PT:..N005A yes~

5.1.17 C32-PT-N005B yes~

5.1.18' C32-LPR~R608 ye~

5.1.19 E51-C002-2 yes@

, 5.1~20 E51-C002-EGM yesAtiQ) 5.1.21 E51-C002-MAG-PU yes{

IOPT~10.1.1 .

I Rev. 89 Page 90r4-3!

5.0 SPECIAL TOOLS AND EQUIPMENT 5'~2 Suitable test gauges maybe'used to obtain data in place of any instaned instrument If us'ed, then record the following. information,:

ID N o . . J/4

~:~d.g:t:f, instrument Cal due date .

1------

~

Parameter bein,gmeasured --~tI,~/4~' _

ID No.

R, Cal 9

a.,.ndate

.eo.f. in.strument Cal,duedate - ~ - - - - - -- - - -

NjA

. _~ _

Parameter being' 'measured tl/4' 5~3 Tubing', valves,and fittings to' install test gauges (as required).

5~4 Predictive Maintenance personnel'will provide the vibration monitoring e,q,uip,ment th'ey will use to coneet vibration data. ,Record the required, data

'be'low: '

Data Collector ID No. f) e.-.l' ~ J 3 ~

Transducer ID No. D <:- r, ?..t 2 Data Collector/transducer cal date / .. J . . () 2 Data*, Collector/transducer oal'due date I -I - () R 5.5 Portable'speed ind'icator~ If used, then record the following information:

ID No. N/I; Cal date .J Cal' due date 14 5~6 Vent and drain rig~

[OPT-10.1.1 I Rev. 89 Page 10 of 431

6.0 ACCEPTANC'E CRITERIA This procedure may be considered satisfactory when the following criteria are met:

6.1 'Pump Tests j R1 I 6.1.1 r,he Rete Systemdevel,ops a flow rate of greater than or equal to 400 gpmwith' a pump discharge pressure of greater than or equal to 1125 psig when the ste'am supply pressure is between 945 psig and 1045 psig.

6.1.2 The pum'p test'data shall be compared, to the allowable ranges idehtified'onTestlnformation Attachment 2.

6.1.3 If.d'eviationsfaU witt:tin the ALE'RT RANGE of Attachment 2., then the frequency of testing shall be doubled untilthe cause of the deviation is determined and corrected and either the existing reference values reverified, or a new set of reference values established per OMa-1988, Paragraph 6.1.

6.1.4 Ifthe ,deviations fall within the REQUIRED ACTION RANGE of Attachment 2, ,the. pump shall' be declared inoperable and not returned to service until th'econdition has been corrected.

6.1.5 Ifcompletedtest resultssh,owdeviationsoutside thealtowable ACCEPTANCE, VALUE, the instrometlt(s) involved may be re-calibrated'an'dlhe test rerun. This'shall not'preclude declaring the pumpino'perable.

6.1.6 Deviations from the standard m,ethods of testing will be specified in the procedure.

6.2 Check Valve' Exercising 6.2.1 Valve 'exercising to'the'full open position shall be satisfied by demonstrating the a*bHity to pass maximum accident condition flow.

F:tow rates less than maximum accident flow are considered partial

-e,xercise tests.

6.2.2 VaJveex~rcising,to' theclosedpositionshaU be consIdered satisfactt>ryby ,dem<;instratirlg'the ,ability to' establish, a differenti'al pressure,8cross the "vaJve,seat'or'by, open'ing an upstream drain conoeeti,QR'"andcQ,nfirtnln'gtne:<absence* of pressurized flow,with

'pressure >oh the downstream 'side'. '

IOPT-10.1.1 [ Rev~89' Page 11 of43 I

6.0 ACCEPTA*NCE CRITERIA 6.3 Le*ak Tig,hlnessExamillation 6.3.1 Identified leakage is recorded on Attachment 4, Leak: Identification Datq*Sheet, and a Work Request (WR) is initiated for any leakage with* the exception of packin~and gasket leakage" less than 5.drops per minute (dpm). TheWRshali state that identified leakage is required to be corrected or minImized as required* byTS 5.5.2.

t 6.3.2 For 'through-wall or 'through-weld' leakage, a Nuclear Condition Rep*ort (NCR) is initiated to assess structural integrity of the affected component

[ OPt-10.1.1 . Rev. 89 Page 12 Of43!

~ ~

d

-1 7.0 PROCEDURAL STEPS Initials 7.1 OBTAIN permission from the Unit SeQ to perform this test.

+-

I R1 I 7.2 CON'FIRM*reactor pressure is between 945 psig and 10.45 psig. -f-7 ~2.1 IF reactor pressure is less than 945 psig, THEN SLOWLY INCREASE the setp*oint of the pressure

..J#-

regulator to attain at least 945 psig.

t NOTE: Fire watch inspections in the 20* ECCS room should be coordinated with Security to*ensure they are completed as required while performing this test.

OFPP~005 requires a fire watch inspection in the 20' ECCSR()o:m*onceevery clock hour. AdditionaJly, 30 minutes should elapse between.fire watch i"nspectionsin an area. Fire watchinspeetions*established for irnpairments. in areas* that could be affected by this test should be coordinated also.

7.3 CO'NTACT Security AND COOR*DINATE fire watch inspections.

-J-7.4 PERFORM the following notifications:

7.4.1 NOTIFY E&RC of the estimated time of Rele turbine operation.

L 7.4.2 W*HEN available, THEN NOTI.FY I&C and Maintenance Supervisors of Rele turbine and pump

-i-run so they can* observe operation, if desired.

7.5 EN,SURE prerequisitesiisted in Section 4.0 are met. -L 7.6 ENSURE the required data has been recorded in Section 5.0. L 7.7 ENSURERHR is in the suppression pool cooling mode, in y

accordance with 1(2}OP-17.

7.8 PERFORM the following to place the SBGT in service:

7.8.1 . IF HPCI is NOT in standby, THENENSUREHPCI .,tJ..

VACUUM PUMP DISCHARGE TO SBGT SYSTEM*

VALVE, E41- V30,is open.

IOPT~10.1.1 Rev. 89 I Page 13 of43 I

i,t

(*f 7.0 PROCEDURAL STEPS Initials 7.8.2 STARTSBGT in accordance with 1(2)OP-10. L 7'.8.3 ENSURE the following. valves.are open:

1. P'OST LOGA VENTt SGT-V8.

~

2. POST LOGA VENT,SGT-V9. -L-7.9 Verification of Filled. Discharge Piping

7.9.1 7.9.2 7.9.3 7.9.4 rOPt~10.t.1 . Rev. 89 I Page 14 Of~~_1

J' ~

7..0 PROCEDURAL STEPS Initials 7.10 Pump Operability Testing 7.10.1 OPEN COND PUMP DISCH INBD DRAIN VLV:

E51-F004.

1. CONFIRM Rele SYSTEM PRESSLOW(A~022-6) annunciator is clear.

7.10.,2 EN*SURE the RCIC lubricant oil level isnorrnal.

7.10~3 R,'ECORD RCle pump sucti,onpressure (stopped) indicated, on E51-PI-R002 (local) on Attach-rnent2.

,NOTE: As.uction pressure of greater than or equal to 29 psig co,nfirms~C,IC CONDENSA TE CHECK VAL VE TO 'PU,MP, ES-1-F011;'and ROIG CONDENSA TEPU'MP DISCHARGE LINE CHECK,VALVE, E51~F047, are closed.

7.10.4 IF RCICpump suction pressure is greaterthan or equal to 29 psig, THEN RECORD Rele CONDENSA TE CHECK VAL V£ TO PUMP, E51-F011 and RCle CONDENSA TE PUMP DISCHARGE LINE CHECK VALVE, E51-F047 are closed on Attachment 3.

,7.10.5 IF RCle suction pressure is NOT greater than or equal to,29 psig THEN PERFORM the follow,ing:

t

1. 'RECORD RCle suction pressure'and CST level,in the Comments Section ofAttachment 1.

2. S:LOWLY THROTTLEOP,ENRC/C KEEPFILL STATION BYPASS VALVE, E51~V70t while monitoring *RCIC.'suction,pressure.

l.oPT-10.1.1 Rev. 89 Page 15 of43 I

{ -

7.0 PROC'EDURALSTEPS Initials

3. I'FRCICsuction *pressure in'creasestogreater than or.

equal to 29: psig'THEN PERFO*RM the following:

a. IM*MEDIATELY CLO-SE RCle KEEPFILL STATIONB:YPASSVALVE, E51- V70.

b. R*E'CQRDRClCCONDENSATEGHeCK*VALVE TOPUMP,-E51~F011-andRCIC CONDENSATE PUMP D1SCHARGE LINE CHECK VAL VE, E51-F047 are closed on Attachment 3.

4. . IF.*RCIC.suction*.press.t.Jre d.oesNQT increase to,.

greater than - or equal' to 2*9' -psig:ANDflowjSevide'ht through thekeepfillbypass HnetTH:E*NPERF*OR*M:fhe following:

a. CLOSE RCIC KEEPFILL STATIONB.YPASS VALVE, E51-V70.

b. N()'TIFY th'eUnit SeQ thatthes5:1~F01*1a*nd.

E5:1~F047valve:positio'ns c*ould*NOT.be confirmed closed.

c. NOTIFY Engineering- for determination.

NQTE': Technical Specifications' '3.6.1.'6.2 -(Modes 1, 2,. or 3) re:quires:.completion:of, ....

OPT-02.3.1 ,Suppression Chamber To DryweU VacuumBreakfifsOperab!lity

Test, within 12-hours following an operation -that.causes,,'a'nyof thevaeu**um* .

breakers to -open. The testis* NOT required if v*acuum*:breakers are monitored and determined to remain closed.

7.10.6 IF, desired, THEN ESTABLISH* MONITORING*.ofthe suppression chamber todryweUvacuumb'reakers~ .

7.10.7 CLOSECOND PUMP DISCH INBD*DRAIN VLV:

E51-F004._

7.10.8 OPE'N ReDUNDANT ISOL TO CST VL V, E41-F011.

7'.10.9 START :BAROMETRIC CNDSR VACUUM PUMP.

7.1-0.10 OPE'NC'-OOLING WATER 'SUPPL'Y-VL v: E51~F046.

I~PT -11l1.1. Rev. 89 Page 160f4$*1

7.. 0 PROCEDURAL STEPS Initials NOT*E: The System En9ineer.m~y ha*ve trendd.ata* that will assist in positioning BYPASS TO CST VL V,~51-F022,as ne'eded (ESR 99-00507).

7.1"0.11 THROTTLE OPEN* BYPASS TOCSTVLV, E51-F022, 2 to 4 seconds, unlessotherwi:se directed by the Unit SeQ.

7.10.12 DISPATCH an auxiliary operator to observe the system discharge*piping for excessive'motion and water hammer during starlupofthe*RCICSystem.

7*.10.13 EVACUATEalipersonne'l below the Reactor Building 20' ""elevation *east h*alf.

7.10.14 MONITOR suppression pool' temperature at intervals less*than or equal to 5: minute to*; ensure the. averClge sLJppressionpool temperature'is less than 104C>F.

NOTE: WHENevotution*s*are in progress with the potential to change suppres'sion pool level, THEN a second operator is ne'cessary to' monitor suppression pool level.

7.10.'1<5 O*P*E*N TURBLNES TEAA/r*S.tlPPLY~VLV, E51-F045.

IOPT-10; 1.1 I Rev.'S'g* Page 17 of 431

\)

7.0 PROCEDURAL STEPS Initials 7.10.16 CONFIRM RCICturbin'e'starts'and'developsa flow of greater than or equal to 400 gpmAND RECORD the start time below:

NOTE: Depending upon the number of valVe'motOf starts required' in the following step,consideration maybe given t6manually throttling the*valve.

NOTE: The required test flow/pres'sure condition can usually be o'bfained by increasing the flow controller setpoint-to b'etween 480:and 500 gpm, and then throttling'E51-F022 in 0.'5 to 1.0 second incre*ments.

7.10.1-7 ADJUST RCICFLOW CONTROL, E51-FIC-R"600, and BYPASS TO CSTVL.~ :E51-F022, as nece.s:sary, to obtain a pump discharge>pressur~"ofgrealerthan or equal to 113.0 psigwith apumpfl'owrateofgreater than or equal to 400 gpm.

7.10.18 RECORD the following AND* CIRCLE the indicator used when appropriate:

1. Pump discharge* press:ure :o:n E51-Pf-'R601.

__________________ . psig'

2. Pump flow rate onE51-FJC~R600~

_ _ _ _"",,,-- 9pm

3. Reactor pressure.on"C32-Ro090RC32~R.608.

_________~~psig.

IOPT-10.1.1 Rev.* 89 Page 18 of 4~1

~ ')

7.0 PROCEDURAL STEPS Initials

4. Steam inlet pressure on E51-PI-R602 O.R E51-PI-R003 (local).

_________psig

5. Steam exhaust pressure on E51-PI-R603 OR E51-PI-R004 (local).

_ _ _ _ _ _-apsig NOTE: Aturbine steam e:X'haust pre.ssure of I.ess*than or e.qualto30 psig on E51-PI-R6030rE51 ~PI-ROC?4{I:ocal))confirmsTURBJNg EXHA:US*T CHECK VAL VE, E51-F040, and TURBINE EXHAUST STOP CHECK VALVE, E51-FOOt ,:are open.

7.10.19 CON*FIRM turbine $team exhaust pressure is less than or equal to 30 psig AND RECORD TURBINE EXHAUST CHECK. VAL.VE,E51-F04*O.and TURBINE EXHAUST STOP CHECK VAL VE,E51-FOO,1' are open on Attachment 3.

NOTE: Pump operation should remain as s~able'as possible 'during the examination.

NOTE: A leakage walkdown is required to be performed .every 24 months in accordance with TS. 5.5.2..

7.10.20 IF required, THEN PERFORM a leak tightness examination of components Identified on Attachment 7, AND RECORD*any*leal<age observed on Attachment 4.

7.10.21 WHEN leak tightness examination is complete OR -

determined NOT needed, THEN PERFORM the following':

1. PLACE Rele FLOW CONTROL, E51-FIC-R600, in ma~lual (M) .

NOTE: Locar speed. verification using thep()rta*blesp*eed indicator is preferred.

2. AQ.,JUST RCICFLOWCONTROL, E51-FIC-R600;as necessary,' to ootainapproximafelY'2500 rpm.

[ OPT-10.1.1 I Rev. 89 Page 190f 431

1. L r\ ).

7.0 PROCEDURAL STEPS Initials

3. OPEN BYPASS TO CST VLV: E51-F022.

4. SLOWLY OPEN E51-PI-R001 INSTRUMENT ISOLA T10N VALVE, E51-PI-R001-3.

5. ADJUST RCIC FLOW CONTROL, E51-FIC-R600 OR B'YPASS TO CSTVLV,. E51~F022, as necessary, to attain the- reference values given on Attachment 2 in accordance with the following:

a. Turbine speed of 2500 rpm on E51-C002-2 OR 2485 to 2515 rpm on po.rtable**sp:eed indicator.

.b. Systemttowof 465 gpm for Unit 1 (480 gpm for Unit 2).

NOTE: To minImize the potential'for d.elays, it i-s *allowable to che'ck that the pump"dP is in theacceptabterange shown on Attachment 2 prior to the 2-minutehold period.

NOTE: TheRCICSyst~m shall operate for at least 2 minutes under conditions. as stable as -the system' permits prior to' recording test data.

7.10.22 RECOR[) the fbU~winglnf()rm:ationon Attachment 2 AND CIRCLE the indicator used:

1. RC1Csuction pressure (runnirtlg)on E51-PI-R002 (local).

2. RCICdischarge pressureonE51-PI-R001 (local).

3. RCIC. turbine speed onE51-G002-2 OR strobe tach (local).

4. RetC system flow on E51-FIC-R600.

5. RCle pump vibration velocity (in/sec peak) at the test positions* designated Q'n ,Attachment 2.

7.1 0.23 CL()SE*E5*1-P/~ROO.1 INSTRUMENT ISOLA TION I VALVE, E5:1-PI-ROO*1..3. Ind.Ver.

!OPT-10.1.1 I . Rev. 89 Page 206f43!

ti"'t L"-

7.0 PROCEDURAL STEPS Initials NOTE: Steps 7.10.24 throug'h 7.10.. 28 may be performed at anytime after Rele is running:and may be performed in any sequence, as appro'priate'j with concurrence ,from' the Unit seQ.

7.10'.24 ENSURE the RCIC lubricant oil level is normal AND RECORD on Attachment 2.

NOTE: Operability of the keep-fill check val,ves are performed asapair.

"NOTE: A press'ure indication onE51-PI..R6'01greaterthan E51-P/~3005,cohfirms RCIC KEEPFILL STATION OUTLET CHECK,E51-V72'and'RCIC' KEEPFILL STATION OUTLET CHECK VAL VE, E51-V73~areclosed.

7.10.25 IF pressure indicationonE51-PJ-R601i$'~greater than E51-PI-3005 t THEN RECQRD RCIC KEEPFILL STATJONOU,TLE'T CHECK, E51-V72':andRCIC KEEPFILLSTA TIONOUTLET CHECK VALVE, E51~V73,are closed on Attacnment3.

7.10.26 IF pressure indication on E51-PI-300S'isgre,aterthan E51-P/~R601 or ES1-PI-3005 is off~scale high, THEN PER:FORM the following:

1. CONNECT a drain hose at E51-PI-3005 INSTRUMENT DRAIN VALVE, E51-PI-3005-6, AND ROUTE to floor drain.

2. CLOS'ERCIC KEEPFILL STATION INLE,T ISOLATION VALVE, E51-V66.

3. OPEN E51-PI-3005/NSTRUMEN'T DRAIN VALVE, E51-PI-3005-6, an:d drain for at least 3 minutes.

(OPT-10.1.1 Rev~'89 Page 21 of 431

II 7.0 PROCEDURAL STEPS Initials NOTE:: The abse'nce of flow under pressure during the following venting sequence confirms one or both of the keep fiJI check valve(s) (ROle KEEPFILL STATION OUTLET CHECK, E51-V72t RCICKEEPFILL STATION OUTLET

, CHECK VALVE, E51-V73) go to the closed position and satisfies reverse exercise requirements. It is acceptable that some drainage will be present NOTE: IF the check valve can NOT be determined to be closed THEN a W/R shall J

be written.

4. CONFIRM KEEPFILL STA TION OUTLET CHECK, E51~V72,and RCle KEEPFILL STATION OUTLET CHECK VALVE, E51-V73 are closedtANDREC'ORD on Attachment 3.

5. CLOSEE51-PI-3005INSTRUMENT DRAIN VALVE, I E51-PI-3005-6. Ind.Ver.

6. OPEN RCIC KEEPFILL STATION INLET1S0LA,TJON L VALVE, E51-V66. Ind.Ver.

NOTE: RelC System flow of greater than or -equal to -400 gpni confirms CONDENSATE STORAGE TANK SUCTION CHECK VALVE, E51~F011, and PUMP DISCHARGE CHECK VALVE, E51-F014, are open.

7.10.27 CONFIRM RCIC System flow is greaterthan or equ8'1 to 400 gpm AND RECORD CONDENSA TE STORAGE TANK SUCTION CHECK VAL VE, E51~F011 and PUMP DISCHARGE CHECK VALVE, E51~F014 are open on Attachment 3.

7.10.28 IF the Unit sca deems it appropriate for current plant conditions, THEN CONTINUE Rele system operation AND ADJUST parameters, as needed to obtain additional data or confirm proper system operation 'as required within the following:

1- . Within vendors rated speed range of approximately 2000 rpm to 4600 rpm.

2. - Within-the flow and pressure limits of the control room

-flow ,and discharge pressure indicators, unless specifi'cally aUlhorizedby the Unit SCO.

IOPT-tO.1.1 Rev. 89 Page 22 of43 I

t I

\:t 7.0 PROCEDURAL STEPS Initials

3. Sfab:le system operation ifflow is below. 120 gpm.

4. Minimize time with MIN FLOW B"YPASS TO TORUS VLV;E51-F019,open*on low flow.

7.10.29 WHEN RCIC run is Gomplete't"THEN PE"RFORMthe foUoWin*g* to* trip*tt1eRCIC"" turbine:

1. ENSURE RCtC FLOW CONTROL, E51~FIC.;.R600in Manual (M).

2. IF"ROIC turbine. speed is above 2600 rpm,TH:EN" AD:JUStRCIC FLqW"CONTROL,* E51"i.FIC-R600, as necessary, to obtain 240.0 to 2600' rpm.

3. DEPRI;SS TURBINETRIP,E51-S17, push button to trip the RCIC turbine.

7.10.30 CLOSE TURBINE STEAM'*S.UPPL Y VLVt: E51-F045.

7.10.31 CLOSE TURBINE. TRIP &THROTTLEVLV, E51~V8, motor operator AND HO.LD*fhe control switch in CLOSEfor approximately 5 seconds after full closed indication to ensure latch mechanism engagement.

7.10'.32" OPEN TURBINE TRIP & THROTTLE VLVt:E51-V8.

7.10.33 OPEN TORUSSUC"TJON VLV, E51-F031.

7.10.34 OPEN' TORUS SUCTION VLVt: E51-F029.

7.10.35 CONFIRM CSTSUCT/ON VLV,E51-F010, closes.

7.10.36 CONFIRM BYPASS TO CST VLV, E51-F022, closes.

7.10.37 OPEN TURBINE STEAM SUPPLY VLVt:"E51-F045.

7.10.38 cO"NFIRM RCle turbine starts and accelerates.

7.10.39 ADJUST RCJCFLOWCONTROL, E51-FIC-R600, as necessary, to.. obtain 2400 to 2600 rpm.

7.10.4.0 CO.NFIRM'*MJNFLOWBYPASS TO TORUS VLV, E51-F019, .opens.

IOPT-10,1.1 Rev. 89 Page 23 of43 I

y;.

7.0 PROCEDURAL STEPS Initials

,NOTE: PUMP SUCTION CHECK VALVE, ,E51~F030, a,nd MINIMUM FLOW CHECK VALVE, E51-F021~a{eCOhfirmed to 9Qtothe partially open position when RCICflow changes are heard when stroking MINFLOWBYPASS TO TORUS'VL~ E51~F019.

7.10.41 CLOSE MINFLOWB,YPASSTO TO'RUSVLV, E51,-F019~

7.10.42 ENSURE MIN FLOW BYPASS TO TORUS VLV, E51-F019" re-opens.

7.10.43 CONFIRM PUMP SUCTION CHECK VALVE, E51-F030and MINIMUM FLOW CHECK VA'LVE, E51-F021 partially open AND'RECORD on Attachment 3.

NOTE: For purposes of this proce,dure',the tripping 0fthe Rele turbinewilld¢note "completion of steamdischarg,e,to the Suppr~ssion,Chamber" for purpos'e's of Tech 'Spec s'urveillances SR3.6.1.6.1 (OPT-02.3.1 b) and SR 3.6.1.6.2 (OPT-02.3.1).

R19 1 7.10.44 DEPRESS the local meehanical ;overspeed device trip I

lever to trip theReTO, turbine AN"Ir) ,RECORD the time below.

7~10.45 CLOSE TURBINE'STEAMSUPPLYVL~E51-F045.

7.10.46 CLOSE TURBltyE TRIP & THROTTLE VLV,E51-V8, motor operator~NDHOLI)the control switch in CLOSE for* approximaotely 'Sse'concis "after fuU'closed indicati.on to. ensurelatchmechanismeng,ageme:nt

7. 1'0.47 RE*$ETthe.rllech(lnic~r,tripoverspeedd'evice in accord'anCl~'with t{2)OP~t6~

IOPT -10.1.1 'Rev. 89, Page 24 of4~J

~)< )'

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7.0 PROCEDURAL'STEPS Initials 7.10.4'8' OPEN',TURBINE TRJP&'THROTTLE VLV, E51-VB.

7'.10.49'" IF'<N~T~neededfor HPCI'op'eration,' THEN CLOSE REDUNDANT'J80L TOCST'VL V, E41-F011.

7.10.50 PLACE, Rele' FLOW CONTROL, E51-FIC-R600, in automatic (A).-

NOTE: Technical,Specification 3.6.1.6.1 (Modes 1, 2, or3) requires completion of OPT-02.3.1b, Suppression PoOl to DrywellVacuum Breaker Position Check, within 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months s~fter a'nydischarge,of'steamto the suppression ch'amber from any source.

NOTE: Step 7. 10.51documents"'CCimpliance ,with Technical ,Specifications and may be' completed as orequired' during,the performa'nceof the proced~ure.

[BD 7.10.51 IF in MOd~s,t, 2, or 3, THEN,'ENSUREOPT-02.3.1b, SUPPf~$:sion Pool:to 'D'f:YWe\~;IVacuum Breaker Po~ition Chec~,jsc()mpletedwithih,6 h'ours, after any,discharge of stearn to the' sUJDpressi:on.'chamber from any source.

NOTE: Technical Specification 3,6.1.6.2 (M()tfes t, 2,0[3) requires the suppression chamb'er todryweU-vacuum':breakers:>'toremainclosed',OR completion of OPT~02.3.1, SUPJ:>ression Chamber to Drywell Vacuum Breakers Operability Test,*within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months following an ,operation th,at caused, any of the vacuum, breakers to open.

NOTE: Step 7.10.52 documents compUamce 'with Technical Sp.ecifications and may be completed as* required'during the,:performanceQf the procedure.

I R1*' 7.10,.52 IF j'n Modes 1, 2,or3,THEN'PERFOR'Mone of the .

following:

1. .CONFIRM suppression chamber todrywell vacuum breakers remained, closed.

'OR

2. OPT-02.3.1, Suppression' Ch'amberto'Drywell Vacuum Brea,kers ,O~p~'FabUityTest}ls, com'pleted'; Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 'f()no\IVing:;~n':operationtliatcause,s,*.anY'9f'*the vacuum.*bre,al<erslo'opert '

!OPT-10.t.1 Rev.* 89 Page 25 ;f43 I*

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7.0 PROCEDURAL STEPS Initials 7.10.53 NOTIFY M:ainten~nce'to,sampleRCICturoine oil as J follows,. within 2' hours:'

1. UN'CAP,ANO'ClPE,N RCIC TURBINE OIL SAMPLE VALVE,E51;"TQ$V-1, to collectapproximately 1 cup ofoilto'purgeth'e'sampleHne.

2. OBTAIN oil sample.

3. CLOSE AND CAP RCIC TURBINE OIL SAMPLE L VALVE~, E51-TO$V~1~ Ihd.Ver.

7.10.54 CLOSE'.COOLING WA*TER SUPPL Y VL v:

ES1"'F046.

7.10.55 CLOSE TORUS SUCTION VLV: E51-F031.

7.10.56 CLOSE TORUS S:U.CTION VLV: E51-F029.

7 .1.0~57 0p**EN CST SUCTION VL v: ES*1-F010.

7.10.58 IF'desired',',TH'EN SECURE'R-HR from the Suppre~sion Pool C.oolingm.ode* in accordance With1{2JOP~17.

7.10~'59 WHEN 15 mInutes have elapsed a,fier se*curing the R.CIC Turbine, THEN PERFORM ,the following:

1. stop BAROMETRIC CNDSR VACUUM PUMP.

2. PLACE BAROMETRIC CND,SR VACUUM PUMP control switch in AUTO.

7.10.60 IF desired, THEN, RETURN SSGT to standby in accordance with 1(2)OP-10.

IOPT~lf11.1 .* Rev. ,89 I Page 26 Of43*1

f: ; '1) 7.0 PROCEDURAL STEPS Initials NOTE: ERFI*Scornputer pointsEHCPA002 andEHCPA003, in Group Point Display

38, may"be ,accessed to more pre'cisely adjustthe pressure regulator setpoint .

7.10.6*1 I'Fthepressure regulat()rsetpoint was increased to supp'ortR'CIC testing,~AND surveillance testing requiring a reactor pressure of945psig is complete, THE*N*SLOWLYD.ECREAS*E the pressure regulator setpoint to 928 psig.

7.11 RCIC.System"Restoration*

NOTE:C:ompletion of this section' will return the RCICSystem to standby in accordance with 1(2)OP-16.

7.11.1 ST()P suppression p.ool temperature monitoring AND REC(>.Rp.the maximuin.*avera~e temperature achieved* during this test.

- - - - - - -of 7.11.2 ENSURE proper oil revel is;maintained at the RCle turbine (viSible in s'ight glass per Precaution and Limitation 3.29).

lOPT-10.1.1 I Rev. 89 Page 27 Of~~

7..0 PROCEDURAL STEPS Initials 7.11.3 ENSURE the valves listed below are in the position as indicated:

Valve No. Valve Description I Position I Checked I Verified E51~V9 . Turbine-GovernorValve I OPE.N E51-F01'9 Min Flow B'ypass To Torus Vlv I CLOSED E51~F022 Bypa.ss To CST Vlv I CLOSED E51-F066 Turbine' Exh VacBkrVlv I OPEN ES'l-F062 Turbio'e Exh VacBkr Vlv f OPEN E51'-F010 CST Suction Vlv I OPEN E51-F031 TOfUS SuctionVlv t CLOSED E51 ..F02*9 Torus Suction Vlv I CLOSED E51-FOt2 Pump Discharge Vlv I a'PEN Est-Fooa' Steam Su.pply Outboardlsol Vlv I OPE'N Eq,1,*F007 Steam 'Supply Inboard rsol :Vlv I OPEN E51~F045 Turbine Steam Supply Vlv ICLO,SED E51-F01'3 RCIC InJe~tion Vlv I CLOSE.D E51-F025 Supply 'Drain Potlnbd DrainVlv I OPEN fI51-F026 Supply Drain Pot Otbd DrainVlv I OPEN E51 ...F054 Supply Drain PotDra,inByp Vlv t CLO.SED, E5:t-F046 eooUng Water Supply Vlv I CLOSE'D E5t-F004 CondPu'mp*D.isch InbdDrainVlv I CLOSED E5t-FODS Cond Pump'Disc~ Otbd Drain Vlv I OPE*N E41 ...F011 Redundant Isol To CST Vlv I CLOSED E51:...V33 RelC Pump Discharge Header I CLOSED Vent Valve E51-V70 RCIC. Keepfill Station Bypass Valve f CLOSED JOPT-tO.l.t Rev. 89 Page 28 of 431

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7.0 PROCEDURAL STEPS Initi'als 7.11.4 ENSURE TURBINE TRIP AND THROTTLE VL V L (Actuator Position), E51-VB, is open. Ind.Ver.

7.11.5 ENSURE TURBINE TRIP AND THRO TTLE VL V L (Valve Position), E51-VB, is open. Ind.Ver.

7.11.6 IF installed, THEN REMOVE the drain hose at E51-PI-3005 INSTRUMENT DRAIN VAL VE, E51-PI-3005-6.

7.11.7 ENSURE the following for Rete FLOW CON"TROL, E51-FIC-R600:

1. In automatic (A) position. L Ind.Ver.

2. Setpoint .set at 400 gpm. 1 Ind~Ver.

3. Yellow ALM light off. L Ind.Ver.

4. Red FAIL light off. ...L Ind~Ver.

) 7.11.8 ENSU*RE TURBINE SPEED TEST SELECTOR switch --.l J

in NORMAL. Ind.Ver.

7.11.9 EN.SURE TURBINE 'TEST POWER switch is OFF. L Ind.Ver.*

7.11.10 ENSURE BAROMETRIC CNDSR VACUUM PUMP is L NOT running. Ind.Ver:

7.11.11 ENSU.REBAROMETRIC CNDSR VACUUM PUMP L control switch in AUTO. Ind.Ver.

7.11.12 EN'SURE BAROMETRIC CNDSR CONDENSA TE l PUMP is .NOT running. Ind.Ver.

7.11.13 ENSURE BAROMETRIC CNDSRCONDENSA TE L PUMP control switch in AUTO. Ind.Ver.

7.11.14 IF ERFISis available, THEN' REQUEST STAor other knowledgeable individual to obtain ER'FIS 'datain accordance with Attachment 5.

IOPl-10.1.1 I Rev. 89 Pag.e 29 of 431

't>l.l

'10- _'1 7.0 PROCEDURAL STEPS Initials 7.11.15 EN;~l.lR;Ethe reCJuired information has been record'ed on the coyer page.

7.11. t6 N()TIFY'IST grou'pwt)endata has b.een.recorded on Test Inform.ati.on Atta:chme'nts* 2 and3AND DOCUMENT**the following informcation:

1ST Date Time _

Name 7.11.17 N:OTIF*Y Unit SeQ when this*test is complete or found to be unsatisfactory.

I.OPT-l0.1.1 I Rev. 89 [ .** Page 30 of 43 I

\,)

},:j ATTACHMENT1 Page 1 of1 Certification, 8,nd" Revlew Form General Comments and Recommendations

--~-----------------

Initials Name'{Print)

Test procedure performed by: y l.It~'u~Z Exceptions~satisfucto~pe~rmance ~ ~_~ ~

Correctiveaction~quired~~~~~~~~~~~~~~~~~~~~~~~~

NOTE: Pump test datashaUt)e analy,~ed with'in96, hours after completion of this PT.

Unit seo' review/approva I of the, P;T satisfies this ASM'E" Code requirement Test procedure has been satisfactorily compJeted Unit SeQ: ----............------.---------_............_ ....................-.----.

Signature Date Test procedure has NOT bee:nsatisfactorHy completed UnitSCO: ,

..........---------------------------------------~

Signature Date Test procedure h,:as be~nTevjewed,by:

Shift Superintendent:,.----... ~...........----.- --__--~..........-

"""SigRature 'Date IOPT -1 0.1.1 Rev~89 Page 31* of43 .,

1£> **

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ATTACHMENT 2 Page 1 of4 Rele Pump Data Sheet UNIT 1 Discharge pressure - suction pressure (running) =delta P (dP)

Lubricant level normal _

NOTES: 1. Pump vibration is measured at the test point marked on the pump for the correct bearing number and direction as indicated by the Test Position number as follows:

the number indicates the bearing number from Attachment 6

for direction, A = Axial, H = Horizontal, V = Vertical

2. The magnetic holder is to be used with the accelerometer probe for all vibration readings.

TEST ACTUAL REFERENCE ACCEPTANCE ALERT RANGE REQUIRED ACTION RANGE PARAMETER VALUE VALUE VALUE LOW HIGH LOW HIGH Suction Press. N/A ~8 N/A N/A <8 N/A (Stopped) psig Suction Press. N/A N/A N/A N/A N/A N/A (Running) psig Discharge N/A N/A N/A N/A N/A N/A Press. psig Pump DP 275 247.5 to N/A N/A < 247~5 > 302.5 psid 302.5 Flow Rate 465 N/A N/A N/A N/A N/A gpm Pump Speed 2500 2485-2515* N/A N/A N/A N/A rpm Vibration-vel 0.114 o to 0.285 N/A > 0.285 N/A > 0.684 (in/sec peak) to 0.684 Position 3 H Vibration-vel 0~074 o to 0.185 N/A > 0.185 N/A > 0.444 (in/sec peak) to 0.444 Position 3 V Vibration-vel 0.105 o to 0.262 N/A > 0.262 N/A > 0.630 (in/sec peak) to 0.630 Position 4 A Vibration-vel 0.138 o to 0.325 N/A > 0.325 N/A > 0.700 (in/sec peak) to 0.700 Position 4 H Vibration-vel 0.089 o to 0.222 N/A > 0.222 N/A > 0.534 (in/sec peak) to 0.534 Position 4 V

Range given in Acceptance Value only applicable when using a portable speed indicator.

IOPT-10.1.1 Rev. 89 Page 32 of 431

ATTACHMENT 2 Page 2 of4 RCtC Pump Data Sheet UNIT 1 Performed by:

(Signature) Date Time 1ST Group:

(Signature) Date Time CORRECTIVE ACTION

1. Any required corrective action shall be performed in accordance with Section 6.0, Acceptance Criteria.

IOPT-10.1.1 Rev. 89 Page 33 of 43]

1 4

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ATTACHMENT 2 Page 30f 4 Rele Pump Data Sheet UN:IT2 Discharge pressure...2suction pressure (running)=: delta P (dP)

-lu-b--n-~ca""';*""';rit""';,-ev';"';;'e-f:-n--ormaf*-. --

NOTES:1. Pump* vibration is 'measured at the test point marked on the pump for the correct bearing number and direction :as indl~ted by:the Test Position number as follows:

.the nu-mt>¢rindicates the bearing numberfrotTl Attachment 6

.or'dtrection, -A = Axial, -H-= Horizontal, V= Vertical

2. The magnetic holder is to be used with the accelerometer probe for all vibration readings.

PARAMETER TEST ACTUAL VALUE REFERENCE VALUE I ACCEPTANCE VALUE I

I ALERT RANGE REQUIRED ACTION RANGE

, LOW HIGH LOW HIGH Suctionpress.- N/A ~8 N/A N/A <8 N/A

- (Stopped) pSig

-SUCtlonPres_s. N/A N/A N/A N/A N/A :N/A (RunJiing) psig Discharge Press. N/A N/A N/A N/A N/A N/A psig PumpDP 283 I 254.7 to 311.3 I N/A I N/A < 254.7 > 31f3 psid Flow--Rate - 480 I N/A I N/A N/A NIA N/A gpn) -

Pump Speed- 2500 I 2485-2515* I N/A N/A NJA N/A rpm Vibration.:vel 0.083 oto 0.207 N/A > 0.207 I N/A >0.498 (in/sec peak) to 0.498 Position3H

-Vibration:-v~I_ 0.070 oto 0.175 N/A > 0.175 I N/A I > 0.420 (in/se-c-peak) -to 0.420 Position-3 V Vibra-tion-vel 0.063 oto 0.157 N/A > 0.157 I N/A I >.O~378 (in/~ec peak} to 0.378 Position 4A Vibrati()n-vel - 0.091 I oto 0.227 I N/A > 0.227 NJA :> 0.546 (in/secpeak) to 0.546 Position4H Vibration..vel 0.104 I oto 0.260 t N/A I > 0.260 N/A- >- 0.624

- (in/sec peak) to 0.624 Position 4 V

Range given ill Acceptance Value only applicable when using a portable speed indicator.

lOPT~10.t.1 *. I Rev.*8-9 Page 34 of 431

t 1 ATTACHMENT 2 Page 4 of4 Rele Pump Data Sheet UNIT 2 Perfo'rmed by:

(Sign'ature) Date Time ISTGro~p:

(Signature) Date Time CORRECTIVE ACTION

1. Any required corrective action shall be perfurmed in accordance with Section 6.0, Acceptance Criteria.

IOPT~10.1.1 I Rev. 89 Page 35 of 431

J.,r, ATTACHMENT 3 Page 1 of 2 Unit 1 RCIC Valve Test Information Sheet STROKE TIME ACCEPTANCE VALVE STROKE REMOTE STROKE CRITERIA (SECONDS) FAIL- FULL- CHECK NUMBER DIRECTION POSITION TIME ACCEPTABLE RANGE REF. SAFE STROKE VALVE VALVE INDICATION (INITIALS) TEST MINIMUM MAXIMUM LIMITING STROKE TEST EXERCISE EXERCISE SATI STEM IND. LIGHTS (SEC) (2) (~) (5) TIME (INITIALS) (INITIALS) (INITIALS) UNSAT 1-E51 ..F040 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1-E51-FOO1 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1..E51-V721 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A V73 1-E51-F011 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1..E51-F014 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1-E51-F030 PART OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1*E51 ..F021 PART OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 1..E51-F011 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A 1-E51-F047 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A NOTES: Spaces next to valve number shall be filled in with an appropriate entry, initials, or N/A.

Performed by (Signature) Date _

Reviewed, 1ST group (Signature) Date _

IOPT-10.1.1 I Rev. 89 I Page 36 Of43!

ATTACHMENT 3 Page 2 of2 Unit 2 RelC*Valve Test Information Sheet STROKE TIME ACCEPTANCE VALVE STROKE REMOTE STROKE CRITERIA (SECONDS) FAIL.. FULl- CHECK NUMBER DIRECTION POSITION TIME ACCEPTABLE RANGE REF. SAFE STROKE VALVE VALVE INDICATION (INITIALS) TEST MINIMUM MAXIMUM LIMITING STROKE TEST EXERCISE EXERCISE SATI STEM. IND. LIGHTS (SEC) (~) (:::;) (~) TIME (INITIALS) (INITIALS) (INITIALS) UNSAT 2~E51 ...F040 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2-E51 ..FOO1 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2.. E51 ..V721 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A V73 2-E51 ..F011 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2-E51-F014 OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2-E51*F030 PART OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2...E51 ..F021* PART OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A 2..E51 ..F011 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A 2.. E51 ...F047 CLOSE N/A N/A N/A N/A N/A N/A N/A N/A N/A NOTE: Spaces next to valve number shall be filled in with.an appropriate entry, initials, or N/A.

Performed*by (Signature) Date _

Perf.ormed by (Signature) Date _

Reviewed, 1ST group (S'ignature) Date _

IOPT-10.1.1 I Rev. 89 I Page 37 of43 I

1 \ II J ~ i ATTACHMENT 4 Page 1 of1 leak Identification Data Sheet NOTE: For packing and gaskets. a WR is required to be initiated and documented if leakage exceeds 5 dpm.

NOTE: Each WRIWO listed is required to state that identified leakage is to be corrected or minimized as required by TS 5.5.2.

LeakaQe Component "Nature of leak R""atel I WRIWO#

1 Leakage identified from components shown in Attachment 7.

Examination Performed by: I Date _

(Signature) (Print Name)

IOPT-10.1.1 Rev.B9 Page 38 of 431

1 ~ '\

1 -;1 ATTACHMENT 5 Page 1 of1 .

ERFI'S Trace 'Setup a,nd Notes NOTE: The. parameters shown below in theexampJeqispJayare normally. saved as S11T10.. IF*the setup has been lo~tJTHEN the.. parameters*should be entered again and saved as 811T10.

NOTE: The ROIC System Engineer should be contacted if any un~xpected trips or other significant problems are n:oted. Otherwise, the* RCrC data should be forwarded to' the RelC Sy~tern Eng.ine.erfor.ttendihg::purposes.:.

EXAMPLE DISPLAY:*

NO. POINT 10 ORIGIN F.lTER .1*(HZ) FILTERZ (HZ) SCALING UNITSI NUMBER (A OR M) .Y*GRID OFFSET

1. E51SA014 1 M 500.000 0.000

2. E51DD042 2 M 4~000 -1.000

3. E51PA006 3 M 200.000 0.000

4. E51FAOO4 7 M 100.000 0.000

5. B21LA001 5 M 20.000 140.000

6. B21PA104 6 M 100.000 600.000 7.

Total number of Y grids: 12 Initials

1. Makea' trace of the entire run at 120 seconds per grid and *t~Oj, grids.

2. . Make additional traces at 10 seconds per grid and 1.0'" g'rids to show the first 1 to2minutes of each Rele fun. Tab trendsat"O.5 second intervals may also be used.

[OPT-10.1.1 Rev~ 89 Page 39 of 4~ I

ATTACHMENT 6 Page 1 of 1 Pump Vibration Test Position Numbers (Bearing Numbers)

RCIC TURBINE ROle,PUMP IOPT-10.1.1 I Rev. 89 I Page 40 of43 I

ATTACHMENT 7 Page 1 of 2 Leakage Inspection Boundary NOTE: Because of drawing limitations, instrumentation lines and turbine casing piping are not shown. The leakage inspection boundary for instrumentation lines extend to and include the last instrument root valve before the instrument. Turbine casing piping to the drain pot is included the leakage Inspection boundary.

NOTE: The Suppression Chamber and Barometric Condenser are NOT reqUired to be examined. They are shown for clarification only.

V104 F010 F023 F017 V9 B.Q1Q fUMe

.QQ.Q.1 V4 DETAIL HA" F019 F021 F020 FOP7 V3 FO~7

~=J

- PSI:

f().41 0001 IOPT-10.1.1 I Re\!.89 I Page 41 of43 I

-9 '\

-I" d ATTAC.HMENT 7 Page 1 of2 Leakage Inspection Guideline When performing Jeakage inspections for TS 5.*5.2, the fbllowing guidance shou.ld be foHowed to the .extent practical.

1. The leakage inspection should be*c.onductedby* examining* theaccessibleex'posed surfaces for .evidence of leakage.

2. For insulated components or components whose external surfaces are inaccessible for direct inspection, the leak~ge inspection should bepertormed on surrounding areas (i.e~ floors 'or equipment-surfa'ces located under the component) for evidence'of:leakage:or other areas to.which*leakagemay be channeled.

3. For vertical surfaces"the inspectjon of the lowest elevation where leakage*maybe detected should be performed.

4. For ALARA, a* leakage inspection using remote visual equipment or tne use of an installed leakage detection system to identify'Jeakage is acceptat)le.

I*OPT-10.1.1 Rev. 89 Page 42 of 431

1 rr I h 1 REVISION

SUMMARY

'Revision 89 incorporatesprogramcha:ngesto perforrrraLeal<ageWalkdown in accordance withTS 5.5.2 (NCR 20757S}. Acceptance ,criteria added for pump values in the Alert Range to perform increased'testing to conform tootherPTs for the same type of testing~ Editorial change to remove Desd,emona font from place keeping aids.

Revision 88 incorporates Tech Spec Ch:angeTSC-2004-04, for suppression chamberto drywell vacuum breakers, Sections 3.16,7.10, and*7.11.

Revision 87 incorporates EC 50554 which returns Unit 2 pressure set to 928 following testing.

Revision 86 adds step to confirm reactor pressure greater tM'a,n 945psi,gand adjust the pressure regulator as needed to attain 945 psig. Likewise, steps are added to return the press.ure regulator setpoint to 928 psig for Unit 1 when testing.iS complete.

Revision 85 incorporated EC 46907, AST Implementation for Unit 2 Operation, which changed the normal valve position for 2-SGT-Va*& V9*fromctosed,to open.

Revision 84 is an editorial correction, which updated the title page, addedSOER 01-01 to the references, and annotated theassociatedP/L Step 3.29 and Caution 'prior to Step 7.10to'reflect response to recommendation 6d of the'S'OER. (AR 49693--26-04)

)

R,evision 83 deleted ,two. precaution and limitation steps stating the RCIC*bearing oil telJ1perature I,imits. These steps were delete'd to eliminate ,confusio"n'since,th,e "local temperature indicating switches were previously replaced with just temperature switches (DRs 86-0177' & 86..;0124)} which actuate high temperature alarms in the main control room.

Revision 82 incorporated TSC-2001-08, which cha,nged Step 7.10.50 to perform OPT-02.3.1b, Suppression Pool to Drywell Vacuum Breaker JDositron Indication Check within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months afterdi.s'charging' steam to the suppression, and* converted the procedure' to*Word 2000 software/format.

Revision 8:1 incorporated EC 478'10, ASTtmplementatio'nfor Unit 1 Operation, which changed the normal valve positi,onfor 1-8GT-VB ,& V9 from closed to open.

Revision 80 added Precaution/Limitations Step 3.30 and 3.31 concerning RetC pre/post run ,oil levels venting of air from system, deleted specific references to vibration data collectors, and transducers, and updated PassPortWork'Ma'nagement references as weUas TIS 5.5.2 reference. (AR 00021660; PAR 00-537). '

I'OPT-10.1.1 Rev. 89 Page 43 of 431

NRC 81M JPM 8-3 Page 1 of 13 PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION JOB PERFORMANCE MEASURE NRC 81M JPM 8-3 TITLE: CORE SPRAY SURVEILLANCE

NRC SIM JPM S-3 Page 2 of 13 SIMULATOR OPERATOR NOTES:

Copy Batch File NRC JPM S-3.bat from memory stick E Drive to F Drive on bsimpcOO Provide calibrated stopwatch and calculator Provide set of vibration data when requested EVALUATOR NOTES: (Do not read to trainee)

1. The applicable procedure section WILL be provided to the trainee.

2. Validation Time 20 minutes

3. This is an Alternate Path JPM TASK CONDITIONS:

1. No other testing or maintenance is in progress that will adversely affect the performance of this test.

2. The station battery chargers are in operation per 20P-51.

3. OPT-07.2.4a, Core Spray Operability Test - Loop "A" is in progress.

4. All pre-job briefs have been completed

5. OPT-07.2.4a has been completed up to, and including, Step 7.7.4.

6. All required personnel are in the field to support performance of the surveillance.

7. Unit Two (2) is at 75% power.

INITIATING CUE:

You are directed by the unit SCO to continue with the performance of OPT-07.2.4a beginning with Step 7.8.1 and notify him when the surveillance is completed.

NRC SIM JPM S-3 Page 3 of 13 Step 1 - Obtain OPT-07.2.4a and reviews precautions and limitations. Begins at with Step 7.8.1 Procedure obtained and reviewed. Begins at step 7.8. 1 SAT/UNSAT PROMPT: WHEN contacted as the Reactor Building AO, report that suction pressure is 5 psig Step 2 OBSERVE CORE SPRA Y PUMP A suction pressure (stopped) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

Suction pressure recorded on Attachment 2 (page 26 of 33)

SAT/UNSAT Step 3 ENSURE one of the following valves is open:

NUC SW TO VITAL HEADER VLV, SW-V117 or CONV SW TO VITAL HEADER VLV, SW-V111 Opened either the SW-V117 or SW- V111.

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-3 Page 4 of 13 Step 4 ENSURE VITAL HEADER XTIE VLV, SW-V118, IS OPEN sw- V118 verified open.

SAT/UNSAT Step 5 ENSURE WELL WATER TO VITAL HEADER VALVE, SW-V141 IS CLOSED.

sw- V141 verified closed. SAT/UNSAT Step 6 STATION an operator to monitor system piping for excessive motion and water hammer when a Core Spray Pump is started.

Operator stationed to monitor for vibration. SAT/UNSAT PROMPT: WHEN contacted as the Reactor Building AO, report that Core Spray Pump "A" oil level is SAT.

Step 7 ENSURE proper CORE SPRAY PUMP A lubricant level.

Proper lubricant level verified. SAT/UNSAT Step 8 START CORE SPRAY PUMP A while monitoring Pump discharge pressure on E21-PI-R600A AND CONFIRM pressure increases to greater than or Equal to 300 psig in less than or equal to 5.0 seconds.

Core Spray Pump started and pressure increase verified.

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-3 Page 5 of 13 Step 9 RECORD the time that CORE SPRAY PUMP A was started.

Core Spray Pump A start time recorded. SAT/UNSAT Step 10.a ENSURE the following:

CORE SPRAY DIVISION 1 ROOM COOLER FAN has Started.

CORE SPRA Y DIVISION 1 ROOM COOLER FAN verified Started.

SAT/UNSAT PROMPT: WHEN contacted as the Reactor Builidng AO, report that SW-V128 is open.

Step 10.b. SERVICE WATER OUTLET VALVE, SW-V128, is open.

sw- V128 verified open by contacting the building Auxiliary operator.

SAT/UNSAT Step 11 THROTTLE OPEN Core Spray FULL FLOW TEST BYP VLV, E21-F015A, to obtain greater than or Equal to 4700 gpm as indicated on E21-FI-R601A.

E21-F015A Throttled Open and flow achieved.

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-3 Page 6 of 13 Step 12 WHEN flow is greater than 603 gpm, CONFIRM that the Core Spray MIN FLOW BYPASS VLV, E21-F031A, closes.

E21-F031A verified closed.

SAT/UNSAT Step 13 CONFIRM CORE SPRAY PUMP A discharge pressure is greater than or equal to 260 psig, as indicated on E21-PI-R600A.

Core Spray Pump A discharge pressure confirmed to be > 260 psig SAT/UNSAT PROMPT: WHEN contacted as the Reactor Building AO, report that E21-PI-2651 is reading 65 psig.

Step 14 CONFIRM KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A, go to the closed Position, and record on Atl. 3 E21-F030A and/or E21-F029A confirmed to have gone to the closed position and recorded on Attachment 3.

SAT/UNSAT Step 15 If test conditions in Step 7.8.13 cannot be met, then perform Step 7.8.14.

Candidate determines Step 7.8.14 is not required.

SAT/UNSAT

NRC SIM JPM S-3 Page 7 of 13 Step 16 SLOWLY OPEN E21-PI-7119A INSTRUMENT ISOLATION VALVE, E21-V5000.

Contacts AD to open E21-V5000 PROMPT: When contacted by the candidate, acknowledge direction to open the E21-V5000 and report that the valve is open.

- CRITICAL STEP**

SAT/UNSAT Step 17 THROTTLE Core Spray FULL FLOW TEST BYP VLV, E21-F015A, to obtain 4700 gpm as indicated on E21-FI-R601A.

Flow established at 4700 gpm.

- CRITICAL STEP**

SAT/UNSAT Step 18 OBSERVE CORE SPRAY PUMP A suction pressure (running) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

Suction pressure obtained and recorded on Att.2 PROMPT: WHEN contacted as the Reactor Building AO, report that suction pressure is 4.5 psig SAT/UNSAT PROMPT: WHEN contacted as the Reactor Building AO, report that discharge pressure is 290 psig.

NRC SIM JPM S-3 Page 8 of 13 NOTE: IF the instrument root valve, E21-V5000, was not opened, report "0" psig discharge pressure.

Step 19 OBSERVE CORE SPRAY PUMP A discharge pressure as indicated on E21-PI-7119A AND RECORD on Att.2 Core Spray Pump A discharge pressure obtained and recorded on Attachment 2.

SAT/UNSAT Step 20 OBSERVE CORE SPRAY PUMP A system flow as Indicated on FLOW INDICATOR E21-FI-R601A and record on Att.2 Pump flow obtained and recorded on Attachment 2.

SAT/UNSAT PROMPT: WHEN requested as the Reactor Building AO, report lubricant level SAT Step 21 ENSURE proper lubricant level AND RECORD on Att.2 Lubricant level verified by contacting auxiliary operator In the reactor building.

SAT/UNSAT

NRC SIM J*PM S-3 Page 9 of 13 PROMPT: WHEN contacted as vibration analyses personnel, provide vibration data as follows:

Vibration Vel Position 1S H =0.215 Vibration Vel Position 1W A =0.204 Vibration Vel Position 1W H =0.145 Step 22 OBTAIN vibration data and record on Attachment 2 Vibration Data recorded SAT/UNSAT.

Step 23 THROTTLE Core Spray FULL FLOW TEST BYP VLV E21-F015A, to obtain 5000 gpm as indicated on E21-FI-R601A.

E21-F015A throttled open and 5000 gpm Flow obtained.

- CRITICAL STEP**

SAT/UNSAT Step 24 CONFIRM CORE SPRA Y PUMP A DISCHARGE CHECK VALVE, E21-F003A, fully opens AND RECORD on Attachment 3.

E21-F003A confirmed to be fully open and recorded On Attachment 3.

SAT/UNSAT

NRC SIM JPM S-3 Page 10 of 13 PROMPT: Inform the candidate that a leakage walkdown is not required For this performance of the surveillance.

Step 25 CLOSE E21-PI-7119A INSTRUMENT ISOLATION VALVE, E21-V5000.

PROMPT: When contacted by the candidate, acknowledge direction to Close the E21-V5000 and report that the valve is closed.

SAT/UNSAT Step 26 CLOSE Core Spray FULL FLOW TEST BYP VLV, E21-F015A.

E21-F015A closed.

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-3 Page 11 of 13 EXAMINER NOTE: The next critical step will be a failure of E21-F031A to open automatically, requiring candidate action to open the valve.

Step 27 WHEN CORE SPRA Y LOOP A flow is less than 603 gpm, ENSURE that Core Spray MIN FLOW BYPASS VLV, E21-F031A, opens.

Operator recognizes E21-F031A does not open Automatically and opens the valve by manipulating The E21-F031A to the Open position. **CRITICAL STEP**

SAT/UNSAT EXAMINER NOTE: If applicant fails to identify valve does not open and trips the pump use followup questions to determine why the pump was secured at the time it was secured.

Step 28 STOP CORE SPRA Y PUMP A AND RECORD the time.

Core Spray Pump 2A secured and time recorded.

SAT/UNSAT Termination Note: When the Core Spray Pump 2A has been secured and The candidate has informed the SCO of the failure of The E21-F031A, the JPM is complete.

NRC SIM JPM S-3 Page 12 of 13 RELATED TASKS:

209001 A4.04 2.9/2.9 Ability to manually operate and/or monitor in the control room: minimum flow valve

REFERENCES:

OPT-07.2.4a Rev. 57 TOOLS AND EQUIPMENT:

None SAFETY FUNCTION (from NUREG 1123, Rev 2.):

2 - Reactor Water Inventory Control Time Required for Completion: 20 Minutes (approximate).

APPLICABLE METHOD OF TESTING Performance: Simulate Actual X Unit: 2 Setting: Control Room Simulator L Time Critical: Yes No X Time Limit N/A Alternate Path: Yes L No EVALUATION JPM: Pass Fail Comments:

TASK CONDITIONS:

1. No other testing or maintenance is in progress that will adversely affect the performance of this test.

2. The station battery chargers are in operation per 20P-51.

3. OPT-07.2.4a, Core Spray Operability Test - Loop "A" is in progress.

4. All pre-job briefs have been completed

5. OPT-07.2.4a has been completed up to, and including, Step 7.7.4.

6. All required personnel are in the field to support performance of the surveillance.

7. Unit Two (2) is at 75% power.

INITIATING CUE:

You are directed by the unit SCO to continue with the performance of OPT-07.2.4a beginning with Step 7.8.1 and notify him when the surveillance is completed.

c

~ progress Energy BRUNSWICK NUCLEAR PLANT Continuous Use DATE COMPLETED " _ FREQUENCY:

UNIT % PWR GMWE _ A. Once every 92 days SUPERVISOR _ B. Stem verification - each refueling NOT to REASON FOR TEST (check one or more): exceed two years Routine surveillance c. Leakage walkdown - at least once per 24 W/O # _ months

__ Other (explain) _ D. Stroking/timing E21-F015A- each refueling outage PLANT OPERATING MANUAL VOLUME X PERIODIC TEST UNIT o

OPT-07.2.4a CORE SPRA Y SYSTEM OPERABILITY TEST .. LOOP A REVISION 57 IOPT-07.2.4a Rev. 57 Page 1 of 331

7.0 PROCEDURAL STEPS Initials

7. SLOWLY OPEN KEEPFILL STATION ,Ill I lIM E21-PCV-F026A DOWNSTREAM ISOLATION Ind.Ver.

VALVE, E21-F027A.

7.7.3 IF required REMOVE the vent and drain rig from the t

CORE SPRAY DIVISION I LINE VENT VALVE, "LA E21-V23.

7.7.4 CONFIRM CORE SPRA Y LOOP A SYS PRESS LOW 'I (A-01 2-10) is cleared.

7.8 Pump Testing 7.8.1 OBSERVE CORE SPRA Y PUMP A suction pressure (stopped) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

7.8.2 ENSURE one of the following valves is open:

1. NUC SW TO VITAL HEADER VLV, SW-V117 OR

2. CONV SWTO VITAL HEADERVLV, SW-V111.

7.8.3 ENSURE VITAL HEADER XTJE VLV, SW-V118, is open.

7.8.4 ENSURE WELL WATER TO VITAL HEADER VALVE, SW-V141, is closed.

7.8.5 STATION an operator to monitor system piping for excessive motion and water hammer when a Core Spray pump is started.

IOPT-07.2.4a Rev. 57 Page 17 of 331

7.0 PROCEDURAL STEPS Initials 7.8.6 ENSURE proper CORE SPRAY PUMP A lubricant level.

NOTE: The following step requires that the time interval from pump start to discharge pressure at 300 psig be measured with a stopwatch. It may be advisable to place a temporary non-destructive mark on the pressure indicator at 300 psig to assist in timing.

IR1 5 1 7.8.7 START CORE SPRAY PUMP A while monitoring pump discharge pressure on E21-PI-R600A, AND CONFIRM pressure increases to greater than or equal to 300 psig in less than or equal to 5.0 seconds.

Response Time _ _ sec.

7.8.8 RECORD the time that CORE SPRAY PUMP A was started.

Time _

7.8.9 ENSURE the following:

1. CORE SPRA Y DIVISION I ROOM COOLER FAN has started.

2. SERVICE WA TER OUTLET VAL VE, SW- V128, is open.

7.8.10 THROTTLE OPEN Core Spray FULL FLOW TEST BYP VLV, E21-F015A, to obtain greater than or equal to 4700 gpm as indicated on E21-FI-R601A.

IOPT-07.2.4a Rev. 57 Page 18 of 331

7.0 PROCEDURAL STEPS Initials 7.8.11 WHEN flow is greater than 603 gpm, CONFIRM that the Core Spray MIN FLOW BYPASS VL V, "E21-F031A, closes~

IR131 7.8~12 CONFIRM CORE SPRA Y PUMP A discharge pressure is greater than or equal to 260 psig, as indicated on E21-PI-R600A.

NOTE: A higher pressure indication on E21-PI-R600A than on E21-PI-2651 verifies KEEPFILL STA TION CHECK VAL VES, E21-F030A and/or E21-F029A, go to the closed position. If indication on E21-PI-2651 is "pegged", then proceed to Step 7.8.14. If test is satisfactory, then N/A Step 7.8.14.

NOTE: Operability of the keep-fill check valves is performed as a pair. If the check valves cannot be determined to be closed, then a W/R shall be written to repair or replace both E21-F030A and E21-F029A.

7.8.13 CONFIRM KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A, go to the closed position, AND RECORD on Attachment 3.

NOTE: Verifying the absence of flow under pressure while venting at E21-PI-2651 INSTRUMENT DRAIN VALVE, E21-IV-786, satisfies reverse exercising requirements for KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A. This does NOT imply that drainage will not be present.

IRIS I 7.8.14 IF test conditions in Step 7.8.13 cannot be met, THEN PERFORM the following steps to satisfy exercising KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A, to the closed position:

1. CONNECT hose at E21-PI-2651 INSTRUMENT DRAIN VALVE, E21-IV-786, AND ROUTE to floor drain.

2. CLOSE KEEPFILL STATION E21-PCV-F026A UPSTREAM ISOLATION VALVE, E21-F025A.

IOPT-07.2.4a Rev. 57 Page 19 of 331

7.0 PROCEDURAL STEPS Initials

3. ENSURE CORE SPRA Y LOOP A KEEPFILL ISOLATION VALVE, TD-V13, is closed .

4. OPEN E21-PI-2651 INSTRUMENT DRAIN VALVE, E21-IV-786, AND ALLOW piping to drain for a minimum of three minutes.

5. CONFIRM the absence of pressurized flow from drain hose AND RECORD KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A go to the closed position on Attachment 3.

6. CLOSE E21-PI-2651 INSTRUMENT DRAIN _I VALVE, E21-IV-786. Ind.Ver.

7. SLOWLY OPEN KEEPFILL STATION l E21-PCV-F026A UPSTREAM ISOLA TION Ind.Ver.

VALVE, E21-F025A.

7.8.15 SLOWLY OPEN E21-PI-7119A INSTRUMENT ISOLATION VALVE, E21-V5000.

NOTE: The Core Spray Pump shall be operated for at least 2 minutes under conditions as stable as the system permits prior to recording test data.

7.8.16 THROTTLE Core Spray FULL FLOW TEST BYP VL V, E21-F015A, to obtain 4700 gpm as indicated on E21-FI-R601A.

7.8.17 OBSERVE CORE SPRAY PUMP A suction pressure (running) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

IOPT-07.2.4a Rev. 57 Page 20 of 331

7.0 PROCEDURAL STEPS Initials 7.8.18 OBSERVE CORE SPRA Y PUMP A discharge pressure as indicated on E21-PI-7119A AND RECORD on Attachment 2.

7.8.19 OBSERVE CORE SPRAY PUMP A System flow as indicated on FLOW INDICATOR E21-FI-R601A AND RECORD on Attachment 2.

7.8.20 ENSURE proper lubricant level AND RECORD on Attachment 2.

7.8.21 MEASURE CORE SPRAY PUMP A vibration velocity (in/sec peak) at the test positions indicated on Attachment 2.

7.8.22 RECORD the measured vibration velocities in the ACTUAL VALUE column on Attachment 2.

NOTE: Flow indication of at least 5000 gpm on FLOW INDICA TOR E21-FI-R601A confirms CORE SPRAY PUMP A DISCHARGE CHECK VALVE, E21-F003A, goes to the full open position.

7.8.23 THROTTLE Core Spray FULL FLOW TEST BYP VL V, E21-F015A, to obtain 5000 gpm as indicated on E21-FJ-R601A.

7.8.24 CONFIRM CORE SPRA Y PUMP A DISCHARGE CHECK VALVE, E21-F003A, fully opens AND RECORD on Attachment 3.

NOTE: A leakage walkdown is required to be performed at least once per 24 months per TS 5.5.2.

7.8.25 IF required, PERFORM a leakage walkdown of the components identified on Attachment 6, AND RECORD leakage on Attachment 4, Leak Identification Data Sheet.

7.8.26 CLOSE E21-PI-7119A INSTRUMENT ISOLATION l VALVE, E21-V5000. Ind.Ver.

7.8.27 CLOSE Core Spray FULL FLOW TEST BYP VLV, E21-F015A.

IOPT-07.2.4a Rev. 57 Page 21 of 331

7.0 PROCEDURAL STEPS Initials 7.8.28 WHEN CORE SPRA Y LOOP A flow is less than 603 gpm, ENSU~E that Core Spray MIN FLOW BYPASS VLV, E21-F031A, opens.

7.8.29 STOP CORE SPRA Y PUMP A AND RECORD the time.

Time 7.8.30 CONFIRM the following:

1. CORESPRA Y DIVISION I ROOM COOLER FAN is off.

2. SERVICE WATER OUTLET VALVE, SW-V128, is closed.

7.8.31 IF required, ENSURE the following valves are closed:

1. NUC SW TO VITAL HEADER VLV, SW-V117

2. CONV SW TO VITAL HEADER VL V, SW- V111 ,

Ind.Ver.

7.8.32 CALCULATE CORE SPRA Y PUMP A run time.

=

7.8.29 7.8.8 7.8.33 IF required to relieve high system pressure condition or ensure the system is filled and vented, THEN PERFORM the following

1. ENSURE a vent and drain rig is attached to CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23.

2. THROTTLE OPEN CORE SPRA Y DIVISION I LINE VENT VALVE, E21-V23, until a solid stream of water issues from the vent line, THEN CLOSE E21-V23.

3. IF required, REMOVE the vent and drain rig from CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23.

IOPT-07.2.4a Rev. 57 Page 22 of 331

ATTACHMENT 2 Page 2 of2 Unit 2 Core Spray Pump A Test Information Data Sheet

1. The lubricant level (pump running) is normal.

2. Calculate pump dP as follows:

Pump discharge pressure - suction pressure (run) = pump dP

=

NOTE: Pump vibration is measured at the test point marked on the pump for the correct bearing number and direction as indicated by the Test Position number as follows:

the number indicates the bearing number from Attachment 5 for position, N=North, S=South, E=East, W=West for direction, A=Axial, H=Horizontal, V=Vertical NOTE: Reference values for pump suction and discharge pressures are provided for determining the suitability of alternate test gauges, if used.

UNIT 2 CORE SPRAY PUMP A TEST DATA REQUIRED ACTION ACTUAL REFERENCE ACCEPTANCE ALERT RANGE RANGE TEST PARAMETER VALUE VALUE VALUE RANGE LOW HIGH LOW HIGH Suction Press. 6.0 4 to 8 N/A N/A <4 >8 (Stopped) psig Suction Press. 4.0 N/A N/A N/A N/A N/A (Running) psig Discharge Press. Psig 290.0 N/A N/A N/A N/A N/A Pump DP psid 283.1 260.0 to 311.4 N/A N/A < 260.0 > 311.4 Flow Rate gpm 4,700 N/A N/A N/A N/A N/A Vibration-vel (in/s 0.230 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1S H to 0.700 Vibration-vel (in/s 0.212 oto 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W A to 0.700 Vibration-vel (in/s 0.156 oto 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W H to 0.700 Performed By (Signature) Date Time _

Reviewed, 1ST Group (Signature) Date _

IOPT-07.2.4a Rev. 57 Page 26 of 331

ATTACHMENT 3 Page 2 of 2 Unit 2 Core Spray System (Loop A) Valve Test Information Sheet Valve Number Stroke Remote Position Stroke Stroke Time Acceptance Direction Indication (Initials) Time Test Criteria (Seconds) Fail- Full- Check Stem Ind. (sec) Acceptable Range Ref. Safe Stroke Valve Valve Lights Minimum Maximum Limiting Stroke Test Exercise Exercise SATI

(~) (~) C:<J Time (Initials) (Initials) (Initials) UNSAT 2-E21 ...F015A OPEN J/A ,l!A N/A N/A N/A N/A N/A N/A N/A N/A JIA 2-E21-F015A CLOSED

"/A 36.30 49.10 53.30 42.70 N/A JIA N/A II/A 2-E21-F004A CLOSED 11.,0 9.38 12.70 13.80 11.04 N/A N/A N/A SA'-

2-E21 ...F005A OPEN II. , 10.20 13.80 15.00 12.00 N/A N/A N/A SAl' 2...E21-F005A CLOSED II *., 10.30 13.94 15.15 12.12 N/A r N/A SAT 2-E21-F004A 2-E21-F001A OPEN CLOSED

". ).

9.61 70.00 13.01 94.60 14.14 102.90 11.31 82.34 N/A N/A Y

N/A N/A N/A SAT 10.' 'AT 2-E21-F001A OPEN , fa~ 67.20 90.80 98.70 79.03 N/A f N/A SAJ 2-E21-F031 A CLOSED , ~ 13. 7 12.20 16.40 17.90 14.33 N/A N/A N/A SAT 2...E21 ...F031A OPEN ilIA tin '<.2 13.10 17.70 19.20 15.41 N/A r N/A SA"'-

2...E21-F029A CLOSED N/A N/A N/A N/A N/A N/A N/A N/A N/A 2-E21 ...F030A CLOSED N/A N/A N/A N/A N/A N/A N/A N/A N/A 2-E21-F003A OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A NOTE: Spaces next to valve numbers shall be filled in with an appropriate entry, initials, or N/A.

Performed by (signature) rt.ic.. f o .Ie. r bJ Date _

Performed by (signature) _ Date _

Revie~d, 1ST Group (s~natu~)~_~ ~ Date _

I OPT-07.2.4a I Rev. 57 I Page 28 of 331

TASK CONDITIONS:

1. No other testing or maintenance is in progress that will adversely affect the performance of this test.

2. The station battery chargers are in operation per 20P-51.

3. OPT-07.2.4a, Core Spray Operability Test - Loop "A" is in progress.

4. All pre-job briefs have been completed

5. OPT-07.2.4a has been completed up to, and including, Step 7.7.4.

6. All required personnel are in the field to support performance of the surveillance.

7. Unit Two (2) is at 75°A, power.

INITIAliNG CUE:

You are directed by the unit SCO to continue with the performance of OPT-07.2.4a beginning with Step 7.8.1 and notify him when the surveillance is completed.

'1 7',1 f C

~ Progress Energy BRUNSWICK NUCLEAR PLANT Continuous Use DATE COMPLETED* _ FREQUENCY:

UNIT % PWR GMWE _ A. Once every 92 days SUPERVISOR _ B. Stem verification - each refueling NOT to REASON FOR TEST (check one or more): exceed two years Routine surveillance C. Leakage walkdown - at least once per 24 WIO # _ months

__ Other (explain) ~ _ D. Stroking/timing E21-F015A- each refueling outage PLANT OPERATING MANUAL VOLUME X PERIODIC TEST UNIT o

. OPT-07.2.4a CORE SPRA Y SYSTEM OPERABILITY TEST - LOOP A REVISION 57 IOPT-07.2.4a Rev. 57 Page 1 of 331

1.0 PURPOSE 1.1 This test is performed to determine the operability of the Core Spray System A Loop. The test conforms to the requirements specified in Technical Specifications 5.5.6 to perform testing in accordance with ASME Boiler and Pressure Code,Section XI ASME/ANSI OM-Code. This test satisfies Technical Specification surveillance's SR 3.5.1.6 and 3.5.2.5 (for the Core Spray Pump). Performance of Valve Remote Position indicator Verification satisfies the requirements ofSR 3.3.3.1.3. This test satisfies a portion of SRs 3.5.1.12 and 3.5.2.7 related to response time testing for Core Spray Pump A and E21-F005A.

1.2 This test also satisfies Technical Specification 5.5.2 for leak tightness inspection every 24 months.

1.3 The following test quantities shall be measured, calculated, or observed and recorded as applicable:

1.3.1 Valve stem travel or disk movement 1.3.2 Proper operation of the valve remote position indicator (RPI) 1.3.3 Time required for valve stroke 1.3.4 Pump inlet pressure 1.3.5 Pump discharge pressure 1.3.6 Pump vibration velocity 1.3.7 Pump flow rate 1.3.8 Pump lubricant level 1.3.9 Pump differential pressure (calculated)

IOPT-07.2.4a Rev. 57 Page 2 of 331

4. i 1

2.0 REFERENCES

2.1 Technical Specifications 2.2 FSAR, Section 6.3 2.3 1(2)OP-18, Core Spray System Operating Procedure 2.4 1(2)OP-51, DC Electrical System Operating Procedure 2.5 001-01.08, Control of Equipment and System Status 2.6 Technical Requirements Manual (TRM) 2.7 OSO-18, Core Spray System Description 2.8 ASME Boiler and.Pressure Vessel Code,Section XI, 1989 Edition 2.9 ANSI/ASME, OM-1987, "Operation and Maintenance of Nuclear Power Plant," w/0Ma-1988 Addenda, Part 6 and Part 10 2.10 NRC Generic Letter 89-04, Guidance on Developing Acceptable Inservice Testing Programs

)

2.11 OENP-17, Pump and Valve Inservice Testing (1ST) 2.12 OENP-16.1, 1ST Pump and Valve Data IR131 2.13 EC 46949, 2-E21-F004A/B and F005A/B Motor Pinion Gear Ratio Change &

Compiling Core Spray Surveillance Requirements 2.14 EER 90-0315, Vibration Program for 1A and 2A Core Spray Pumps IRISI 2.15 Response to NRC Bulletin 88-04, Potential Safety Related Pump Loss 2.16 0-25024, Sheet 2, Core Spray System, Unit 1 2.17 D-02524, Sheet 2, Core Spray System, Unit 2 2.18 NUREG-1482, Guidelines for Jnservice Testing at Nuclear Power Plants IOPT-07.2.4a . Rev. 57 Page 3 of 331

2.0 REFERENCES

2.19 ESR 97-00508, EGGS Response Time Testing Methods IR201 2.20 Second Request for Additional Information, Brunswick Steam Electric Plant, Units 1 and 2 Response to Generic Letter 95-07, "Pressure Locking and Thermal Binding of Safety-Related Power Operated Gate Valves" 2.21 EGR-NGGG-0010, System and Component Trending Program and System Libraries 2.22 OENP-23, Predictive Maintenance Program 2.23 RFJ-24, Refueling Justification for Stroking E21-F015A/B.

2.24 OAP-54, Plant Leak Management IR251 2.25 Brunswick Steam Electric Plant Units 1 and 2, Issuance of Amendment RE:

Alternative Source Term (License Amendments 221 and 246, dated May 30, 2002) 2.26 10 GFR 50.67, Accident Source Term 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Attachments 2 and 3 must be reviewed by the 1ST group.

3.2 Water from the suppression pool should not be injected into the reactor vessel during the performance of this test.

3.3 The following annunciators may alarm during the performance of this test:

3.3.1 CORE SPRAY OR RHR PUMPS RUNNING (A-03 2-1).

3.3.2 CORE SPRAY LOOP A SYS PRESS LOW (A-01 2-10).

3.4 The vibration velocity readings shall be taken at the test positions specified on the data sheet. Since there are multiple test points, ensure that the probe is located on the correct bearing (see Attachment 5) and in the correct direction as specified in the test position number.

IOPT-07.2.4a Rev. 57 Page 4 of 331

3.0 PRECAUTIONS AND LIMITATIONS 3.5 For taking vibration readings} the probe shall be securely mounted at each test position. The probe must be in firm contact with the bearing housing when taking data.

3.6 When taking readings to be recorded on Attachment 2, the indicator/pointer fluctuation should be reduced to a minimum. A valve upstream of the gauge may be throttled to reduce fluctuation. Care should be taken to ensure proper communication between the gauge and main flow path.

3.7 Suitable test gauges may be used in place of any installed instrument. If used, the full-scale range of each instrument should be three times the reference value or less, with adequate range to prevent damage during use.

Use of alternate test gauges requires recording the test gauge identification number, test gauge calibration date} and test gauge calibration due date.

3.8 Some steps of this test require independent verification.

3.9 An Operator should be stationed to monitor system piping for excessive motion and/or water hammer when a core spray pump is started. The susceptible piping includes core spray discharge piping located in the overhead of the 50' elevation of the Reactor Building.

3.10 When opening system drain/vent valves, proper radiological control procedures shall be observed.

3.11 Core Spray Loop A shall be declared inoperable from the beginning of Valve Testing, Section 7.6, to when valve stroking is complete AND the CORE SPRAY LOOP A SYS PRESS LOW (A-01 2-10) is cleared.

3.12 During system venting, air is not expected in the system. Should air be found, initiate a WIO and notify the System Engineer. Presence of air in the system does not make the system inoperable but does imply component degradation at some point that must be addressed. The test may continue provided air can be removed from the*system via the normal venting process.

IOPT-07.2.4a Rev. 57 Page 5 of 33 I

'7 1 4.0 PREREQUISITES 4.1 No other testing or maintenance is in progress that will adversely affect the performance of this test 4.2 The Core Spray System (Loop A) is in standby per 1(2)OP-18.

4.3 The station battery chargers are in operation per 1(2)OP-51.

4.4 IF a leakage walkdown is required, THEN OAP-054 Alternative Source Term (AST) Combined Leakage Log value has been recorded on Attachment 4.

5.0 SPECIAL TOOLS AND EQUIPMENT 5.1 Confirm that no active corrective maintenance W/O exists on the following installed instruments. If any active W/O exists, operability of the instrument must be resolved and recorded in the General Comments and Recommendations section before the instrument may be used.

Instrument W/R-W/O W/R-W/O#

5.1.1 E21-PT-NOO1A yes/@ ----N/A-5.1.2 E21-FT-NOO3A yes@

5.1.3 E21-PI-R600A yes@

5.1.4 E21-FI-R601A yes@

5.1.5 E21-PI-2651 yes@

5.1.6 E21-PI-7119A yes (5§)

~

5.1.7 E21-PI-ROO1A yes (fiY tl/A

[ OPT-07.2.4a Rev. 57 Page 6 of 331

5.0 SPECIAL TOOLS AND EQUIPMENT 5.2 Suitable test gauges may be used to obtain data in place of any installed instrument. If used, note:

5.2.1 10 number J/A.

5.2.2 Range of instrument 5.2.3 Calibration date 5.2.4 Calibration due date 5.2.5 Parameter measured

~

5.3 A stopwatch with the following data recorded below:

5.3.1 Stopwatch identification number. 7 KLo(J/3 5.3.2 Stopwatch calibration" date. ,. J.C)?

5.3.3 Stopwatch calibration due date. 12- 3/-o?

5.4 Predictive Maintenance personnel will provide the vibration monitoring instrument used for data collection. Record the required data below:

5.4.1 Vibration monitor identification number. 3 C.£L tL 'I 5.4.2 Transducer identification number. B R lf18 5.4.3 Vibration monitor/transducer calibration date. '- 0' 5.4.4 Vibration monitor/transducer calibration due date. .1

2 ,. 0 t 5.5 Vent and drain rig 5.6 Tubing, valves, and fittings to install test gauges (as required).

5.7 Ladder for vibration readings

[ OPT-07.2.4a Rev. 57 Page 7 of 331

6.0 ACCEPTANCE CRITERIA This test may be considered satisfactory when the following criteria are met:

6.1 Pump Tests NOTE: Acceptance Criteria 6.1.1 includes allowances for a number of items (such as flow diversion through the minimum flow valve, cracks, and the vent hole).

Meeting the values shown assure that CS can provide 4100 gpm to the vessel with 113 psid between the Suppression Pool and the vessel as required by Technical Specifications.

IR131 6.1.1 CORE SPRA Y PUMP A operation develops a recirculation flow rate

.of 4700 gpm or greater against a system head of greater than or equal to 260 psig. (SR 3.5.1.6, SR 3.5.2.5) 6.1.2 CORE SPRA Y PUMP A discharge pressure increases to greater than or equal to 300 psig within 5 seconds of control switch operation.

(SR 3.5.1.12, SR 3.5.2.7) 6.1.3 The pump test data shall be compared to the allowable ranges identified in Test Information Attachment 2.

6.1.4 If deviations fall within the ALERT RANGE of Attachment 2, the frequency of testing shall be doubled until the cause of the deviation is determined and corrected and either the existing reference values reverified or a new set of reference values established per OMa-1988, Paragraph 6.1.

6.1.5 If the deviations fall within the REQUIRED ACTION RANGE of Attachment 2, the pump shall be declared inoperable and not returned to service until the condition has been corrected.

6.1.6 When completed test results show deviations greater than the allowable ACCEPTANCE VALUE RANGE, the instruments involved may be recalibrated and the test rerun. However, this shalf not preclude declaring the pump inoperable as required.

IOPT-07.2.4a Rev. 57 Page 8 of 331

6..0 ACCEPTANCE CRITERIA 6.2 Valve Tests NOTE: Stroke time shall be measured from the time the control switch is repositioned to the time the valve is fully stroked by light indication.

Deviations from this standard method of testing will be specified in the procedure.

6.2.1 Valve Stroke Time

1. Measured stroke times shall be within the ACCEPTABLE RANGE as specified by the minimum and maximum stroke times shown on Attachment 3.

2. For tests where the measured stroke time of a valve exceeds the maximum ACCEPTABLE stroke time but does not exceed the LIMITING stroke time, the valve shall be immediately retested or declared INOPERABLE.

a. If a valve is retested, and the measured stroke time is within the ACCEPTABLE RANGE, the valve may be declared OPERABLE. A Condition Report (CR) shall be generated to ensure the OM Code requirement associated with the evaluation is completed by Engineering.

b. If a valve is retested and the measured stroke time falls outside the ACCEPTABLE RANGE, a Tracking LCO shall be generated to track the time agreed upon by the Shift Superintendent and BESS in accordance with 001-01.08.

Otherwise, declare the valve INOPERABLE and meet the requirements of all applicable Technical Specifications.

3. For tests where the measured stroke time of the valve is less than the minimum ACCEPTABLE stroke time, exceeds the LIMITING stroke time or the valve disc or stem fail to exhibit the required change of position, the valve shall immediately be declared INOPERABLE.

4. For Core Spray Injection Valves, E21-F004A and E21-F005A, the measured opening stroke time shall be less than or equal to 23.8 seconds to satisfy Core Spray Loop A response time requirements. (SR 3.5.1.12, SR 3.5.2.7).

IOPT-07.2Aa I Rev. 57 Page 9 of 331

6.0 ACCEPTANCECRITERIA 6.2.2 Valve Full-Stroke Exercise Full-stroke exercise requirements shall be satisfied by completely cycling a valve from the closed position to the open position and back to the closed position or from the open position to the closed position and back to the open position.

6.2.3 Valve Remote Position Indicator (RPI) Verification At a refueling frequency (not to exceed 2 years), each RPI Verification identified on Attachment 3 shall be observed to verify that the valve position is accurately indicated in both the open and closed positions by the indicating lights on the RTGS when the valve stem or mechanical position indicator has stopped moving. RPI verification satisfies the requirements of SR 3.3.3.1.3.

6.2.4 Check Valve Exercising

1. Check valve exercising to the fun open position shall be satisfied by demonstrating the ability to pass maximum accident condition flow.

2. Check valve exercising to the closed position shall be considered satisfactory by demonstrating the ability to establish a differential pressure across the valve seat, or by verifying the absence of flow under pressure while venting the upstream side of the valve seat with pressure on the downstream side.

6.3 Leak Tightness Examination 6.3.1 Identified leakage is recorded on Attachment 4, Leak Identification Data Sheet, and a Work Request (WR) is initiated for any leakage with the exception of packing and gasket leakage less than 5 drops per minute (dpm). The WR shaH state that identified leakage is required to be corrected or minimized as required by TS 5.5.2.

6.3.2 For 'through-wall' or 'through-weld' leakage, a Nuclear Condition Report (NCR) is initiated -to assess structural integrity of the affected component.

IOPT-07.2.4a Rev. 57 Page 10 of 331

6.0 ACCEPTANCE CRITERIA IR251 6.3.3 The following applicable actions are taken when the combined leakage total (AST Combined Leakage Log value plus leakage from components shown on Attachment 6) is greater than 0 gpm:

1. If the combined leakage is determined to be less than or equal to 1 gallon per minute (gpm)t the normal work management process (PRI 3) for correcting leakage is implemented.

2. If the combined leakage is determined to be greater than 1 gpm and less than or equal to 20 gpm, the initiated WR should be identified as PRI 2 to expedite corrective actions to eliminate or reduce identified .

leakage as soon as plant conditions allow.

3. If the combined leakage is greater than 20 gpm, the initiated WR should be identified as PR12*to expedite corrective actions to eliminate or reduce identified leakage as soon as plant conditions allow. A Nuclear Condition Report (NCR) is initiated to have Engineering assess the impact to the AST (10CFR50.67) analysis.

1 OPT-07.2.4a Rev. 57 Page 11 of 331

1 I t 7.0 PROCEDURAL STEPS Initials 7.1 OBTAIN permission from the Unit sea to perform this test, ~

AND ENSURE LeO requirements have been reviewed in Unit sca accordance with 001-01.08.

7.2 ENSURE all prerequisites listed in Section 4.0 are met. '(

7.3 CONFIRM required data has been recorded in Section 5.0. L 7.4 NOTIFY Maintenance the pumps are being tested so they can observe the pump run, if desired.

L NOTE: A leakage walkdown is required to be performed each 24 months per TS 5.5.2.b.

7.5 IF a leakage walkdown is required of CORE SPRA Y LOOP A during the performance of this procedure, THEN PREPARE

--!./L to perform a system walkdown to identify system leaks.

7.6 Valve Testing NOTE: Those steps associated with valve remote position indicator (RPI) verification are performed each refueling, not to exceed 2 years, or after maintenance which affects RPI performance. IF RPI verification is NOT required for this test, THEN N/A may be entered in the Initials.

NOTE: Steps 7.6.1 through 7.6.3.2 are required to be performed only during refueling outages in an effort to prevent voiding Core Spray piping during power operations. IF these steps are NOT required for this test, THEN NA may be entered where appropriate.

IR201 7.6.1 IF performing during a refueling outage, THEN ..l!/tL ENSURE Core Spray FULL FLOW TEST BYP VL V, .

E21-F015A, is closed.

IOPT-07.2.4a Rev, 57 I Page 12 of 331

f I /0 t 7.0 PROCEDURAL STEPS Initials 7.6.2 1.

IF performing during a refueling outage, THEN OPEN Core Spray FULL FLOW TEST BYP VLV, E21-F015A.

CONFIRM Core Spray FULL FLOW TEST BYP VL V, J1/L E21-F015A, valve stem travels to the open position when indicating lights indicate open, AND RECORD remote position indicator results on Attachment 3.

7.6.3 IF performing during a refueling outage, THEN CLOSE Core Spray FULL FLOW TEST BYP VL v:

J!/L E21-F015A, AND RECORD valve stroke time and full-stroke exercise on Attachment 3.

1. CONFIRM Core Spray FULL FLOW TEST BYP VL v: ---'/L E21-F015A, valve stem travels to the closed position when indicating lights indicate closed, AND RECORD remote position indicator results on Attachment 3.

2. IF entrance into this procedure was necessary only to perform stroking and timing of E21-F015A, THEN GO

~

TO AND PERFORM Section 7.7 AND applicable steps of Section 7.9.

7.6.4 ENSURE Core Spray OUTBOARD INJECTIONVL V, Y E21-F004A, is open.

7.6.5 CLOSE Core Spray OUTBOARD INJECTION VL V, E21-F004A, AND RECORD valve stroke time on L

Attachment 3.

1. CONFIRM Core Spray OUTBOARD INJECTION VL V, E21-F004A, valve stem travels to the closed position

-J/L when indicating lights indicate closed, AND RECORD remote position indicator results on Attachment 3.

7.6.6 ENSURE Core Spray INBOARD INJECTION VL V, L E21-F005A, is closed.

7.6.7 OPEN Core Spray INBOARD INJECTION VL v: 'I E21-F005A, AND RECORD valve stroke time on Attachment 3.

1. CONFIRM Core Spray INBOARD INJECTION VL V, JlIA E21-F-005A, valve stem travels to the open position when indicating-lights indicate open, AND RECORD remote position indicator results on Attachment 3.

IOPT~07 .2.4a I Rev. 57 I Page 13 of 331

IOPT~07.2.4a Rev. 57 Page 14 of 331

~ 1 "

7.0 PROCEDURAL STEPS Initials 7.6.12 OPEN Core Spray TORUS SUCTION VL V, '(

E21-F001A, AND RECORD the valve stroke time and full-stroke exercise on Attachment 3.

1. CONFIRM Core Spray TORUS SUCTION VL V, E21-F001A, valve stem travels to the open position

~'--

J1/A-when indicating lights indicate open, AND RECORD remote position indicator results on Attachment 3.

7.6.13 ENSURE Core Spray MIN FLOW BYPASS VL V, E21-F031A, is open.

L 7.6.14 CLOSE Core Spray MIN FLOW BYPASS VL ~

E21-F031A, AND RECORD valve stroke time on L

Attachment 3.

1. CONFIRM Core Spray MIN FLOW BYPASS VL V, E21-F031A, valve stem travels to the closed position

.J/L when indicating lights indicate closed, AND RECORD remote position indicator results on Attachment 3.

7.6.15 OPEN Core Spray MIN FLOW BYPASS VL V, E21-F031A, AND RECORD valve stroke time and L

full-stroke exercise on Attachment 3.

1. CONFIRM Core Spray MIN FLOW BYPASS VL V, E21-F031A, valve stem travels to the open position

~

when indicating lights indicate open, AND RECORD remote position indicator results on Attachment 3.

7.7 Filling and Venting Core Spray Loop A NOTE: IF air is observed in the discharge piping, a W/R should be prepared to correct any problems.

7.7.1 IF the keepfilt station for CORE SPRAY LOOP A is available, THEN PERFORM the following:

1. ENSURE that a vent and drain rig is attached to y CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23.

IOPT-07.2.4a Rev. 57 Page 15 of 331

t \ I 7.0 PROCEDURAL STEPS Initials

2. THROTTLE OPEN CORE SPRA Y DIVISION I LINE VENT VALVE, E21-V23, until a solid stream of water L

issues from the vent line, THEN CLOSE E21-V23.

7.7.2 IF it is desired to use the KEEPFILL STATION E21-PCV-F026A BYPASS VALVE, E21-F028A, OR the valve is already open, THEN PERFORM the following:

1. ENSURE that a vent and drain rig is attached to CORE SPRA Y DIVISION I LINE VENT VAL VE,

.J1/L E21-V23.

2. ENSURE KEEPFILL STATION E21-PCV-F026A DOWNSTREAM ISOLATION VALVE, E21-F027A, is

.r1A-closed.

3. IF necessary, THROTTLE OPEN KEEPFILL STATION E21-PCV-F026A BYPASS VALVE,

--JM-E21-F028A.

4. THROTTLE OPEN CORE SPRA Y DIVISION I LINE

~

VENT VALVE, E21-V23, until a solid stream of water ~/

issues from the vent line, THEN CLOSE E21-V23.

5. CLOSE KEEPFILL STATION E21-PCV-F026A tip I J/A BYPASS VALVE,E21-F028A. Ind.Ver.

6. THROTTLE OPEN CORE SPRA Y DIVISION I LINE J!A-VENT VALVE, E21-V23, until CORE SPRAY PUMP A DISCHARGE PRESSURE INDICA TOR, E21-PI-R600A (Panel H12-P601), indicates 40 to 70 psig, THEN CLOSE E21-V23.

IOPT-07.2.4a Rev. 57 I Page 16 of 331

t I {

7.0 PROCEDURAL STEPS Initials

7. SLOWLY OPEN KEEPFILL STATION E21-PCV-F026A DOWNSTREAM ISOLA TION ilp I~

Ind.Ver.

VALVE, E21-F027A.

7.7.3 IF required, REMOVE the vent and drain rig from the ,//A CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23.

7.7.4 CONFIRM CORE SPRA Y LOOP A SYS PRESS LOW 'I (A-01 2-10) is cleared.

7.8 Pump Testing 7.8.1 OBSERVE CORE SPRA Y PUMP A suction pressure (stopped) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

7.8.2 ENSURE one of the following valves is open:

1. NUC SW TO VITAL HEADER VLV, SW-V117 OR

2. CONV SWTO VITAL HEADERVLV, SW-V111.

7.8.3 ENSURE VITAL HEADER XTJE VLV, SW-V118, is open.

7.8.4 ENSURE WELL WATER TO VITAL HEADER VALVE, SW-V"141, is closed.

7.8.5 STATION an operator to monitor system piping for excessive motion and water hammer when a Core Spray pump is started.

[ OPT-07.2.4a Rev. 57 Page 17 of 331

1 7.0 PROCEDURAL STEPS Initials 7.8.6 ENSURE proper CORE SPRA Y PUMP A lubricant level.

NOTE: The following step requires that the time interval from pump start to discharge pressure at 300 psig be measured with a stopwatch. It may be advisable to place a temporary non-destructive mark on the pressure indicator at 300 psig to assist in timing.

IRIS I 7.8.7 START CORE SPRAY PUMP A while monitoring pump discharge pressure on E21-PI-R600A, AND CONFIRM pressure increases to greater than or equal to 300 psig in less than or equal to 5.0 seconds.

Response Time _ _ sec.

7.8.8 RECORD the time that CORE SPRA Y PUMP A was started.

Time _

7.8.9 ENSURE the following:

1. CORE SPRA Y DIVISION I ROOM COOLER FAN has started.

2. SERVICE WATER OUTLET VALVE, SW-V128, is open.

7.8.10 THROTTLE OPEN Core Spray FULL FLOW TEST BYP VL ~ E21-F015A, to obtain greater than or equal to 4700 gpm as indicated on E21-FI-R601A.

[ OPT-07.2.4a Rev. 57 Page 18 of 331

7.0 PROCEDURAL STEPS Initials 7.8.11 WHEN flow is greater than 603 gpm, CONFIRM that the Core Spray MIN FLOW BYPASS VL v:

E21'-F031A, closes.

IR13 1 7.8.12 CONFIRM CORE SPRA Y PUMP A discharge pressure is greater than or equal to 260 psig, as indicated on E21-PI-R600A.

NOTE: A higher pressure indication on E21-PI-R600A than on E21-PI-2651 verifies KEEPFILL STA TION CHECK VALVES, E21-F030A and/or E21-F029A, go to the closed po~ition. If indication on E21-PI-2651 is "pegged", then proceed to Step 7.8.14. If test is satisfactory, then N/A Step 7.8.14.

NOTE: Operability of the keep-fill check valves is performed as a pair. If the check valves cannot be determined to be closed, then a W/R shall be written to repair or replace both E21-F030A and E21-F029A.

7.8.13 CONFIRM KEEPFILL STATION CHECK VAL VES, E21-F030A and/or E21-F029A, go to the closed position, AND RECORD on Attachment 3.

NOTE: Verifying the absence of flow under pressure while venting at E21-PI-2651 INSTRUMENT DRAIN VAL VE, E21-IV-786, satisfies reverse exercising requirements for KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A. This does NOT imply that drainage will not be present.

IRISI 7.8.14 IF test conditions in Step 7.8.13 cannot be met, THEN PERFORM the following steps to satisfy exercising KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A, to the closed position:

1. CONNECT hose at E21-PI-2651 INSTRUMENT DRAIN VALVE, E21-IV-786, AND ROUTE to floor drain.

2. CLOSE KEEPFILL STATION E21-PGV-F026A UPSTREAM ISOLATION VALVE, E21-F025A.

IOPT-07.2.4a Rev. 57 Page 19 of 331

7.0 PROCEDURAL STEPS Initials

3. ENSURE CORE SPRA Y LOOP A KEEPFILL ISOLATION VALVE, TD-V13, is closed .

4. OPEN E21-PI-2651 INSTRUMENT DRAIN VALVE, E21-IV-786, AND ALLOW piping to drain for a minimum of three minutes.

5. CONFIRM the absence of pressurized flow from drain hose AND RECORD KEEPFILL STATION CHECK VALVES, E21-F030A and/or E21-F029A go to the closed position on Attachment 3.

6. CLOSE E21-PI-2651 INSTRUMENT DRAIN _/

VALVE, E21-IV-786. Ind.Ver.

7. SLOWLY OPEN KEEPFILL STA TION L E21-PCV-F026A UPSTREAM ISOLATION Ind.Ver.

VALVE, E21-F025A.

7.8.15 SLOWLY OPEN E21-PI-7119A INSTRUMENT ISOLATION VALVE, E21-V5000.

NOTE: The Core Spray Pump shall be operated for at least 2 minutes under conditions as stable as the system permits prior to recording test data.

7.8.16 THROTTLE Core Spray FULL FLOW TEST BYP VL V, E21-F015A, to obtain 4700 gpm as indicated on E21-FI-R601A.

7.8.17 OBSERVE CORE SPRAY PUMP A suction pressure (running) as indicated on E21-PI-R001A AND RECORD on Attachment 2.

IOPT-07.2.4a Rev. 57 Page 20 of 331

7.0 PROCEDURAL STEPS Initials 7.8.18 OBSERVE CORE SPRA Y PUMP A discharge pressure as indicated on E21-PI-7119A AND RECORD on Attachment 2.

7.8.19 OBSERVE CORE SPRA Y PUMP A System flow as indicated on FLOW INDICA TOR E21-FI-R601A AND RECORD on Attachment 2.

7.8.20 ENSURE proper lubricant level AND RECORD on Attachment 2.

7.8.21 MEASURE CORE SPRA Y PUMP A vibration velocity (in/sec peak) at the test positions indicated on Attachment 2.

7.8.22 RECORD the measured vibration velocities in the ACTUAL VALUE column on Attachment 2.

NOTE: Flow indication of at least 5000 gpm on FLOW INDICATOR E21-FI-R601A confirms CORE SPRA Y PUMP A DISCHARGE CHECK VALVE, E21-F003A, goes to the full open position.

7.8.23 THROTTLE Core Spray FULL FLOW TEST BYP VL V, E21-F015A, to obtain 5000 gpm as indicated on E21-FI-R601A.

7.8.24 CONFIRM CORE SPRA Y PUMP A DISCHARGE CHECK VALVE, E21-F003A, fully opens AND RECORD on Attachment 3.

NOTE: A leakage walkdown is required to be performed at feast once per 24 months per TS 5.5.2.

7.8.25 IF required, PERFORM a leakage walkdown of the components identified on Attachment 6, AND RECORD leakage on Attachment 4, Leak Identification Data Sheet.

7.8.26 CLOSE E21-PI-7119A INSTRUMENT ISOLATION l VALVE, E21-V5000. Ind.Ver.

7.8.27 CLOSE Core Spray FULL FLOW TEST BYP VLV, E21-F015A.

IOPT~07.2.4a Rev. 57 Page 21 of 331

)r I 7.0 PROCEDURAL STEPS Initials 7.8.28 WHEN CORE SPRA Y LOOP A flow is less than 603 gpm, ENSU~E that Core Spray MIN FLOW BYPASS VLV, E21-F031A, opens.

7.8.29 STOP CORE SPRA Y PUMP A AND RECORD the time.

Time -

7.8.30 CONFIRM the following:

1. CORESPRA Y DIVISION I ROOM COOLER FAN is off.

2. SERVICE WATER OUTLET VALVE, SW-V128, is closed.

7.8.31 IF required, ENSURE the following valves are closed:

1. NUC SW TO VITAL HEADER VL V, SW- V117

2. CONV SWTO VITAL HEADER VLV: SW-V111 ,

Ind.Ver.

7.8.32 CALCULATE CORE SPRAY PUMP A run time.

- =

7.8.29 7.8.8 7.8.33 IF required to relieve high system pressure condition or ensure the system is filled and vented, THEN PERFORM the following

1. ENSURE a vent and drain rig is attached to CORE SPRA Y DIVISION I LINE VENT VALVE, E21-V23.

2. THROTTLE OPEN CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23, until a solid stream of water issues from the vent line, THEN CLOSE E21-V23.

3. IF required, REMOVE the vent and drain rig from CORE SPRA Y DIVISION I LINE VENT VAL VE, E21-V23.

IOPT-07.2.4a Rev. 57 Page 22 of 331

7.0 PROCEDURAL STEPS Initials 7.9 System Restoration 7.9.1 ALIGN valves as specified in Table 1.

NOTE: Independent verification is required for valve lineup.

TABLE 1 SYSTEM VERIFICATION LINEUP SHEET REQUIRED INITIALS VALVE NO. DESCRIPTION POSITION IND. VER.

E21-FOO1A Core Spray Pump A Suppression Pool Suction Valve OPEN I E21-FOO4A Core Spray Outboard Injection Valve OPEN I E21-FOO5A Core Spray Inboard Injection Valve CLOSED I E21-F031A Core Spray Minimum Flow Bypass Valve OPEN I E21-F015A Core Spray Test Bypass Valve CLOSED I E21-V23 Core Spray Division I Line Vent Valve CLOSED I 7.9.2 IF installed, REMOVE drain hose installed at E21-PI-2651, INSTRUMENT DRAIN VALVE, E21-IV-786.

7.9.3 IF necessary, REMOVE the temporary mark on pressure indicator E21-PI-R600A.

7.9.4 ENSURE the required information has been recorded on the cover page.

7.9.5 NOTIFY the 1ST Engineer when data has been recorded on Attachments 2 and 3 AND RECORD the following information.

1ST Engineer _

Name Da~ Time 7.9.6 NOTIFY the Unit sea when this test is complete or found to be unsatisfactory.

!OPT-07 .2.4a Rev. 57 Page 23 of 331

ATIACHMENT 1 Page 1 of 1 Certification and Review Form General Comments and Recommendations Initials Name (Print)

Performed by: s $ .. m B,:"el ~.t' t --.PJ,. En J~ r /

Exceptionstosatisfucto~pe~rmance~~~~~~~~~~~~~~~~_

Corrective action required _~~~~~~~~~~~~~~~~~~~ __

NOTE: Pump test data shall be analyzed within 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after completion of this PT.

sca review/approval of the PT satisfies this ASME Code requirement.

Test procedure has been satisfactorily completed:

Unit SCQ: _

Signature Date Test procedure has NOT been satisfactorily completed:

Unit SCQ:

Signature Date Test has been reviewed by:

Shift Superintendent _

Signature Date IOPT-07.2.4a Rev. 57 Page 24 of 331

ATTACHMENT 2 Page 1 of2 Unit 1 Core Spray Pump A Test Information Data Sheet

1. The lubricant level (pump running) is normal.

2. Calculate pump dP as follows:

Pump discharge pressure - suction pressure (run) = pump dP

=

NOTE: Pump vibration is measured at the test point marked on the pump for the correct bearing number and direction as indicated by the Test Position number as follows:

the number indicates the bearing number from Attachment 5 for position, N=North, S=South, E=East, W=West for direction, A=Axial, H=Horizontal, V=Vertical NOTE: Reference values for pump suction and discharge pressures are provided for determining the suitability of alternate test gauges, if used.

UNIT 1 CORE SPRAY PUMP A TEST DATA REQUIRED ACTUAL REFERENCE ACCEPTANCE ALERT RANGE ACTION RANGE TEST PARAMETER VALUE VALUE VALUE RANGE LOW HIGH LOW HIGH Suction Press. 6.0 4 to 8 N/A N/A <4 >8 (Stopped) psig Suction Press. 4.0 N/A N/A N/A N/A N/A (Running) psig Discharge Press. Psig 290.0 N/A N/A N/A N/A N/A Pump DP psid 290.9 261.9 to 319.9 N/A N/A < 261.9 > 319.9-Flow Rate gpm 4,700 N/A N/A N/A N/A N/A Vibration-vel (in/s 0.133 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1S H to 0.700 Vibration-vel (in/s 0.195 o fo 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W A to 0.700 Vibration-vel (in/s 0.144 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W H to 0.700 Performed By (Signature) Date Time _

Reviewed, 1ST Group (Signature) Date _

I OPT-07.2.4a Rev. 57 Page 25 of 331

ATTACHMENT 2 Page 2 of 2 Unit 2 Core Spray Pump A Test Information Data Sheet

1. The lubricant level (pump running) is normal.

2. Calculate pump dP as follows:

Pump discharge pressure - suction pressure (run) = pump dP

=

NOTE: Pump vibration is measured at the test point marked on the pump for the correct bearing number and direction as indicated by the Test Position number as follows:

the number indicates the bearing number from Attachment 5 for position, N=North, S=South, E=East, W=West for direction, A=Axial, H=Horizontal, V=Vertical NOTE: Reference values for pump suction and discharge pressures are provided for determining the suitability of alternate test gauges, if used.

UNIT 2 CORE SPRAY PUMP A TEST DATA REQUIRED ACTION ACTUAL REFERENCE ACCEPTANCE ALERT RANGE RANGE TEST PARAMETER VALUE VALUE VALUE RANGE LOW HIGH LOW HIGH Suction Press. 6.0 4 to 8 N/A N/A <4 >8 (Stopped) psig Suction Press. 4.0 N/A N/A N/A N/A N/A (Running) psig Discharge Press. Psig 290.0 N/A N/A N/A N/A N/A Pump DP psid 283.1 260.0 to 311.4 N/A N/A < 260.0 > 311.4 Flow Rate gpm 4,700 N/A N/A N/A N/A N/A Vibration-vel (in/s 0.230 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1S H to 0.700 Vibration-vel (in/s 0.212 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W A to 0.700 Vibration-vel (in/s 0.156 o to 0.325 N/A > 0.325 N/A > 0.700 peak) Position 1W H to 0.700 Performed By (Signature) Date Time _

Reviewed, 1ST Group (Signature) Date _

IOPT-07.2.4a Rev. 57 Page 26 of 331

~;;..

ATTACHMENT 3 Page 1 of 2 Unit 1 Core Spray System (Loop A) Valve Test Information Sheet Valve Number Stroke Remote Position Stroke Stroke Time Acceptance Direction Indication (Initials) Time Test Criteria (Seconds) Fail- Full- Check Stem Ind. (sec) Acceptable Range Ref. Safe Stroke Valve Valve Lights Minimum Maximum Limiting Stroke Test Exercise Exercise SATI

(?:) (~) <<) Time (Initials) (Initials) (Initials) UNSAT

,r ,

1-E21-F015A OPEN IJ/~ ilIA N/A N/A N/A N/A N/A N/A N/A N/A ,J/A 1...E21*F015A CLOSED tllA 35.90 48.50 52.70 42.20 N/A J/A N/A 1-E21-F004A CLOSED 9.85 13.33 14.49 11.59 N/A N/A N/A 1-E21-F005A OPEN 10.01 13.55 14.73 11.78 N/A N/A N/A 1...E21 ...F005A CLOSED 9.88 13.36 14.53 11.62 N/A N/A "IA 1-E21-F004A OPEN 9.99 13.51 14.69 11.75 N/A lilA N/A 1-E21-F001A CLOSED 68.51 92.69 100.75 80.60 N/A N/A N/A 1-E21...FOO1A OPEN 72.73 98.39 106.95 85.56 N/A JIA N/A N/A N/A N/A 1-E21-F031A CLOSED I

.j V 11.00 14.80 16.10 12.90 1-E21-F031A OPEN J/~

r JIA

, ~!J 12.30 16.50 18.00 14.40 N/A J/A

~

N/A 1-E21 ...F029A CLOSED N/A N/A N/A N/A N/A N/A N/A N/A N/A JIA 1..E21-F030A CLOSED N/A N/A N/A N/A N/A N/A N/A N/A N/A I v

1-E21-FOO3A OPEN N/A N/A N/A N/A N/A N/A N/A N/A N/A JJ'~rA lilA NOTE: Spaces next to valve numbers shall be filled in with an appropriate entry, initials, or N/A.

Performed by (signature) JjA Date N/A Perfonned by (signature) J/A Date J/A Revie~d, 1ST Group (~gnatu~)~~~~~~~~~~~~~~~~~~~~~~ Date J/A IOPT-07.2.4a , I Rev. 57 I Page 27 of 331

ATTACHMENT 3 Page 2 of 2 Unit 2 Core Spray System (Loop A) Valve Test Information* Sheet Valve Number I Stroke Remote Position Stroke Stroke Time Acceptance Direction Indication (Initials) Time Test Criteria (Seconds) Fail- Full- Check Stem I Ind. (sec) Acceptable RanQe Ref. Safe Stroke Valve Valve Lights Minimum Maximum Limiting Stroke Test Exercise Exercise SATI

(>> (<;) (~) Time (Initials) (Initials) *(Initials) UNSAT 2-E41 ~FO 15A OPEN lilA '/J~ N/A N/A N/A N/A N/A N/A N/A N/A Jh 2-E2.1-F9'1SA CLOSED "fA 36.30 49.10 53.30 42.70 N/A ,II,. NlA Jlff 2-E21-F004A CLOSED 11*,,0 9.38 12.70 13.80 11.04 N/A N/A. N/A SA"-

2-E2.1-F00"5A OPEN II. , 10.20 13.80 15.00 12.00 N/A N/A N/A S,Ar-2-E2t-FOO5A CLOS.lED IJ .7 10.30 13.94 15.15 12.12 N/A Y N/A SAT 2.. E21-F004A OPEN II. 1 9.61 13.01 14.14 11.31 N/A Y N/A SAT 2-E21-F'OOtA CLOSED to.' 70.*00 94.60 102.90 82.34 N/A N/A N/A JAT 2-E21-POO1A OPl:N , I .. ~ 67.20 90.80 98.70 79.03. N/A r N/A SAT 2*E2t-F031A CLOSED , I 13. 7 12.20 16.40 17.90 14.33 N/A N/A N/A SAT 2-E21-F031A OPEN lilA riIJ ,('.:2 13.10 17.70 19.20 15.41 N/A r N/A SA-r-2-E21*F029A CLOSED N/A NlA N/A N/A N/A NIA N/A N/A N/A 2... E21 ...F030A CLOSED NIA N/A N/A N/A N/A N/A N/A N/A N/A 2..E21-FOO3A OPEN NIA N/A N/A N/A N/A N/A N/A N/A N/A I

NOTE: Sp.aces next to valve numbers shall be filled in with an appropriate entry, initials, or N/A.

Performedl:)y (signature) _ T' ~i,- (9 -I.e.( '" Date D LtJ..i Performed by (signature) ~ ..-.-.. _ Date - _

Rev~~d,lSTG~up{~gnature)~~_~~~~~~~~~~~~~~~~_ Date _ - _ - - _

IOPT- 0 7 . 2 0 4 a \ Rev. 57 I Page 28 of 331

~

AITACHMENT 4 Page 1 of 1 IR2S1 Leak Identification Data Sheet NOTE: For packing and gaskets, a WR is required to be initiated and documented if leakage exceeds 5 dpm.

NOTE: Each WRIWO listed is required to state that identified leakage is to be corrected or minimized as required by TS 5.5.2.

SYSTEM: Core Spray System A Loop Unit - - - - -

Leaka~e Component Nature of Leak Rate WRlWO#

Sum of Identified Leakage:

AST Combined Leakage Log value from OAP-054: +

Total: =

1 Conversion Factor: (dpm x 1.6 x 10- 3

) + 60 =gpm Examination Performed by: / Date _

(Signature) (Print Name)

Examination Performed by: / Date _

(Signature) (Print Name)

IOPT-07.2.4a Rev. 57 Page 29 of 331

"t 1 4' f:

ATTACHMENT 5 Page 1 of 1 Core Spray Pump Pump Vibration Test Position Numbers (Bearing Numbers)

< I 1 I I <-----",I 2 IOPT-07.2.4a Rev. 57 Page 30 of 331

ATTACHMENT 6 Page 1 of 2 Leakage Inspection Boundary NOTE: Because of drawing limitations, instrumentation lines connected to boundaries are not shown. The leakage inspection boundary for instrumentation lines extends to and includes the last instrument root valve before the instrument.

NOTE: The Suppression Chamber is NOT required to be examined. It is shown for clarification only 6:J Go:J..: F012A

?

F004A

?

F015A F020A V41 Pump

>lA,.

f032.A FOO V1 FOOOA Vf13 IOPT-07.2.4a I Rev. 57 I Page 31 of 331

-) "t ~, 1 r ATIACHMENT6 Page 2 of 2 Leakage Inspection Guidance When performing leakage inspections for TS 5.5.2, the following guidance should be followed to the extent practical.

1. The leakage inspection should be conducted by examining the accessible exposed surfaces for evidence of leakage.

2. For insulated components or components whose external surfaces are inaccessible for direct inspection, the leakage inspection should be performed on surrounding areas (Le. floors or equipment surfaces located under the component) for evidence of leakage or other areas to which leakage may be channeled.

3. For vertical surfaces, the inspection of the lowest elevation where leakage may be detected should be performed.

4. For ALARA, a leakage inspection using remote visual equipment or the use of an installed leakage detection system to identify leakage is acceptable.

I OPT-07.2.4a Rev. 57 Page 32 of 331

~~j \1" REVISION

SUMMARY

Revision 57 incorporates PRR214582 (CORR 207570-14) and PRR20653 (CORR 207575-16) program changes to perform a Leakage Walkdown in accordance with TS 5.5.2. Changes include documenting leakage as required for Alternate Source Term (License Amendments 221 and 246 dated May 30,2002).

Revision 56 adds Step 7.8.33 to vent system as required.

Revision 55 incorporated EC63657 by changing pump flow rate from 4626 to 4700 gpm (steps 6.1.1 and 7.8.10), adding a new step (7.8.23) to increase flow to 5000 gpm, changing Note prior to new step (7.8.23) to 5000 gpm, remove the statement inside the

"( )" in Step 2.13, and changed the 1ST pump psid value to 260.

Revision 54 makes an editorial correction to add the Tech Spec reference to Section 6.3 per NAS Observation 69604 (This reference is already listed in the Purpose Section).

Revision 53 revises the stroke time acceptance criteria for 1-E21-F004A and 1-E21-F005A to reflect the gear ratio change incorporated lAW EC 51210/54126.

Revision 52 makes editorial corrections to update the cover page and word processing format and makes changes to reflect EC 46949, Rev 2, re-evaluation of CS injection valve and pump performance requirements.

Revision 51 revises the stroke time acceptance criteria for 2-E21-F004A and 2-E21-F005A to reflect the gear ratio change incorporated lAW EC 46949/EC 50010.

Revision 50 adds "if performing during a refueling outage" to clarify required testing associated with stroking E21-F015A.

Revision 49 updates stroke time data for 2-E21-F005A iaw the 1ST program; added frequency of each refueling outage for stroking/timing E21-F015A; added NOTES/step informing operators E21-F015A is required to be stroked/timed during refuel outages only and routes procedure users to applicable sections if test is being performed only to test E21-F015A Revision 48 removes reference to specific vibration instrument, IRD Model 890, and replaces with generic reference; AddP&L and caution identifying Core Spray Loop A is inop during valve stroking and until the Loop A low pressure alarm clears.

Revision 47 revises purpose to include Tech Spec Section 5.5.2.a and adds Precaution and Limitations regarding actions if air is found in the system during testing.

Revision 46 revises gear ratio thus stroke times for 1-E21-F004A in accordance with ESR 98-00285. This revision also incorporates new stroke times for 1-E21-F001A in accordance with ESR 98-00284.

IOPT-07.2.4a Rev. 57 Page 33 of 331

NRC 81M JPM 8-4 Page 1 of 9 PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION JOB PERFORMANCE MEASURE NRC 81M JPM 8-4 TITLE: Restore Shutdown Cooling following a spurious isolation

NRC SIM JPM S-4 Page 2 of 9 SAFETY CONSIDERATIONS:

None.

EVALUATOR NOTES: (Do not read to trainee)

1. The applicable procedure section WILL be provided to the trainee.

2. This is an ALTERNATE PATH JPM

3. Validation Time 20 minutes

- FE DIB. r**r 11 'IIInm* *rn. n 8111_

- .f'I. 1111£ Read the following to applicant.

TASK CONDITIONS:

Unit (2) has been shutdown for maintenance for 5 days.

A spurious Group 8 isolation(High Steam Dome Pressure) caused a loss of the B loop of shutdown cooling.

RHR flow prior to the loss was =:5000 gpm The cause of the isolation was found and repaired and the isolation has been reset.

RPS is energized Reactor Water Level band is 200" to 220" Reactor pressure is 0 psig RHR system cooldown and draindown are not a concern A 2nd licensed operator will be conducting 2PT-01.7 and will notify you of any unexpected trends.

INITIATING CUE:

You are directed by the Unit SCO to return the B loop of RHR to Shutdown Cooling lAW AOP-15 (Start the "B" RHR pump).

NRC SIM JPM S-4 Page 3 of 9 STEP 1- Enters AOP-15.0 and determines step 3.2.11 is the appropriate starting point.

Enters AOP-15 at step 3.2.11.

SAT/UNSAT NOTE: If asked, all precautions are met Step 2 - CLOSE Loop "B" OUTBOARD INJECTION VALVE, E11-F017B.

n Closes Loop "B OUTBOARD INJECTION VALVE, E11-F017B.

- CRITICAL STEP**

SAT/UNSAT EXAMINER NOTE: Applicant will hold switch to 'Close' position approximately 5 seconds after valve indicates full closed to ensure full closure.

Step 3 - ENSURE Loop "B" INBOARD INJECTION VALVE, E11-F015B is OPEN ENSURES Loop "B" INBOARD INJECTION VALVE, E11-F015B, is OPEN.

SAT/UNSAT

NRC SIM JPM S-4 Page 4 of 9 Step 4 - Unit 2 Only: OPEN RHR SHUTDOWN COOLING INBOARD SOLATION VALVE, E11-F009.

Opens valve E11-F009

- CRITICAL STEP**

SAT/UNSAT EXAMINER NOTE: Per OP-17, Precaution and Limitation 3.1, Valve movement for the E11-F008 is limited to 3 duty cycles in a 5 minute period followed by a 50 minute cooldown.

Step 5 - Unit 2 Only: SLOWLY OPEN RHR SHUTDOWN COOLING OUTBOARD ISOLATION VALVE, E11-F008.

Slowly Opens valve E11-F008

- CRITICAL STEP**

SAT/UNSAT CAUTION Failure to minimize RHR Pump operation while deadheaded may cause pump damage.

Step 6 - START an RHR Pump in the loop being used for Shutdown Cooling.

Starts the "B" RHR pump.

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-4 Page 5 of 9 Step 7 - SLOWLY THROTTLE OPEN Loop "B" OUTBOARD INJECTION VALVE, E11-F017B to re-establish RHR loop conditions prior to the event.

Throttles Open E11-F017B to approx. 5000 gpm

- CRITICAL STEP**

SAT/UNSAT EXAMINER NOTE: When the E11-F017B is FULL OPEN, the running RHRSW Booster Pump will trip. The following annunciator will alarm.

2-A-3 1-8, " RHRSW Pump 2B TRIP This is AOP-15 Symptom 1.2. The following actions must be taken to maintain a Shutdown Cooling alignment.

Step 8 - WHEN RHR loop conditions have stabilized, FULLY OPEN Loop "B" OUTBOARD INJECTION VALVE, E11-F017B.

Fully Opens E11-F017B SAT/UNSAT NOTE: If notified as the Unit SCO that RHRSW Pump 2B has tripped, then direct the candidate to take appropriate actions lAW plant procedures.

NRC SIM JPM S-4 Page 6 of 9 Step 9 - RHRSW Booster Pump 2B Trips Determines RHRSW Booster Pump 2B trips and references AOP-15 and annunciator response for 2-A-3 1-8, " RHRSW Pump 2B TRIP.

Determines that actions per A OP -15, step 3.2.9 are applicable

- CRITICAL STEP** SAT/UNSAT EXAMINER NOTE:

AOP-15 Procedure step 3.2.9.1 is not applicable. The applicant will continue at step 3.2.9.2.

Step 10 -IF available, THEN START the idle RHRSW Booster Pump in the RHRSW loop being used for Shutdown Cooling.

Places RHRSW Booster Pump "0" in service.

- CRITICALSTEP** SAT/UNSAT Step 11 - Re-opens E11-F068B , Heat Exh 2B Discharge Valve Recognizes that the E11-F068B auto closed when the 2B RHRSW pump tripped and re-opens valve to establish flowpath

- CRITICAL STEP** SAT/UNSAT

NRC 81M JPM 8-4 Page 7 of 9 TERMINATING CUE: When the candidate has informed you that the "8" Loop of RHR and RHRSW are in service in Shutdown Cooling, the JPM may be terminated.

COMMENTS:

NRC SIM JPM S-4 Page 8 of 9

REFERENCES:

OAOP-15.0, Rev.20 section 3.2.11 KA

Reference:

205000 A4.01, A4.02, A4.03 Ability to monitor and/or manually in the control room SDC/RHR pumps and valves TOOLS AND EQUIPMENT:

None SAFETY FUNCTION (from NUREG 1123, Rev 2.):

4 - Heat removal From the Core Time Required for Completion: 20 Minutes (approximate).

APPLICABLE METHOD OF TESTING Performance: Simulate Actual X Unit: ~

Setting: Control Room Simulator X Time Critical: Yes No L Time Limit N/A Alternate Path: Yes No EVALUATION JPM: Pass Fail

TASK CONDITIONS:

Unit (2) has been shutdown for maintenance for 5 days.

A spurious Group 8 isolation(High Steam Dome Pressure) caused a loss of the B loop of shutdown cooling.

RHR flow prior to the loss was ~5000 gpm The cause of the isolation was found and repaired and the isolation has been reset.

RPS is energized Reactor Water Level band is 200" to 220" Reactor pressure is 0 psig RHR system cooldown and draindown are not a concern A 2 nd licensed operator will be conducting 2PT-01.7 and will notify you of any unexpected trends.

INITIATING CUE:

You are directed by the Unit SCQ to return the B loop of RHR to Shutdown Cooling lAW AQP-15 (Start the "B" RHR pump).

BRUNSWICK NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME XXI ABNORMAL OPERATING PROCEDURE UNIT o

OAOP-15.0 LOSS OF SHUTDOWN COOLING REVISION 20 IOAOP-15.0 Rev. 20 Page 1 of 191

3.0 OPERATOR ACTIONS

3. CLOSE the following valves:

- INBOARD RX HEAD VENT VLV, B21-FOO3 D

- OUTBOARD RX HEAD VENT VL V, B21-FOO4. D

4. ENSURE the following valves are closed:

- REACTOR INBOARD HIGH POINT MANUAL VENT D VALVE, B21-FOO1

- REACTOR OUTBOARD HIGH POINT MANUAL D VENT VALVE, B21-FOO2.

5. NOTIFY the WCC to evaluate ongoing work which D requires the unit to be in Mode 4 for safety clearances.

3.2.9 IF the operating RHRSW loop has been lost, THEN PERFORM the following:

I R17 1 1. IF unexplained changes in flow or pump discharge D pressure are observed in the running RHRSW loop, AND NSW or CSW header pressure approaches pump shutoff head (approximately 90 psig), THEN ENSURE UNIT 1(2) SERVICE WATER DISCHARGE OUTLET VALVE, SW-V442, is open.

2. IF available, THEN START the idle RHRSW Booster D Pump in the RHRSW loop being used for Shutdown Cooling.

3. IF the NSW or CSW Service Water Header has been D lost, THEN PLACE the RHRSW loop in operation using the other Service Water header in accordance with 1(2)OP-43.

4. IF NO RHRSW Booster Pumps can be placed in D operation, THEN PLACE RHRSW in operation with NO RHRSW Booster Pumps available in accordance with 1(2)OP-43.

5. IF Service Water is unavailable, THEN PLACE Fire D Protection Water in operation to the Service Water Header in accordance with OAOP-18.0.

IOAOP-15.0 Rev. 20 Page 7 of 191

3.0 OPERATOR ACTIONS IR211 CAUTION 3.2.10 IF the RHR loop operating in Shutdown Cooling has D been lost AND the following conditions exist, THEN SHIFT Shutdown Cooling loops in accordance with 1(2)OP-17:

- NO Group 8 Isolation Signal

- NEITHER RHR Pump in the RHR loop being used for Shutdown Cooling can be started.

3.2.11 IF the RHR loop operating in Shutdown Cooling has been lost AND a Group 8 Isolation Signal is present, THEN PERFORM the following:

1. RESTORE AND MAINTAIN reactor water level in the D previously established band in accordance with direction of the Shift Superintendent.

2. REDUCE reactor pressure below 125 psig in accordance D with OGP-05.

3. ENSURE RPS is energized. D

4. WHEN Group 8 Isolation signals have cleared, THEN D RESET the Group 8 Isolation.

5. IF RHR System piping cool down or drain down are NOT a concern, THEN PERFORM the following to restore the RHR loop that was operating in Shutdown Cooling:

a. CLOSE Loop A(B) OUTBOARD INJECTION D VALVE, E11-F017A(B).

b. OPEN Loop A (B) INBOARD INJECTION VALVE, D E11-F015A(B).

[ OAOP-15.0 Rev. 20 Page 8 of 191

3.0 OPERATOR ACTIONS

c. Unit 1 Only: OPEN RHR SHUTDOWN COOLING D OUTBOARD ISOLATION VALVE, E11-FOOB.

d. Unit 1 Only: SLOWLY OPEN RHR SHUTDOWN D COOLING INBOARD ISOLA TION VAL VE, E11-F009.

e. Unit 2 Only: OPEN RHR SHUTDOWN COOLING D INBOARD ISOLATION VALVE, E11-F009.

f. Unit 2 Only: SLOWLY OPEN RHR SHUTDOWN D COOLING OUTBOARD ISOLA TION VALVE, E11-FOOB.

CAUTION

g. START an RH R Pump in the loop being used for D Shutdown Cooling.

h. SLOWLY THROTTLE OPEN Loop A(B) D OUTBOARD INJECTION VALVE, E11-F017A(B) to re-establish RH R loop conditions prior to the event.

i. WHEN RHR loop conditions have stabilized, D FULLY OPEN Loop A(B) OUTBOARD INJECTION VALVE, E11-F017A(B).

j. IF the reactor coolant temperature is less than 212°F, THEN ENSURE the following valves are open:

- INBOARD RX HEAD VENT VLV, B21-FOO3 D

- OUTBOARQ RX HEAD VENT VLV, B21-FOO4. D

k. MAINTAIN RHR in Shutdown Cooling in D accordance with 1(2)OP-17.

IOAOP-15.0 Rev. 20 Page 9 of 191

Unit 2 APP A-03 1-8 Page 1 of 2 RHR SW PUMP 2B TRIP AUTO ACTIONS

1. If RHR SW Pump 2D is not operating, RHR Heat Exchanger 2B Service Water Discharge Valve, EII-F068B, will close.

CAUSE

1. RHR SW booster pump suction header pressure low (15.5 psig with five-second time delay) .

2. Instantaneous overcurrent on Phase A, B, or C.

3. Time overcurrent on Phase A or C.

4. Circuit malfunction.

OBSERVATIONS

1. RHR SW Booster Pump 2B is off.

2. RHR SW Booster Pump 2B discharge pressure decreasing (SW-PI-1155-1).

3. RHR SW Booster Pump 2B motor breaker, Compartment AK4 on 4160V Emergency Bus E4, is in the OPEN position.

4. RHR SW PMP II SUCT HDR PRESS LOW (A-02 2-9) alarm if both RHR SW Pumps 2B and 2D have tripped on low suction pressure.

5. RHR SW PUMP 2B OVERLOAD (A-03 2-8) alarm.

ACTIONS

1. If the RHR service water header is being supplied from the service water nuclear header, check that the service water nuclear header pressure, as indicated on SW-PI-143-1 on RTGB Panel XU2, is reading a normal pressure of 55 to 65 psig and, if necessary, start the standby pump to the service water nuclear header.

2. If the RHR service water header is being supplied from the service water conventional header, check that the service water conventional header pressure, as indicated on SW-PI-131-1 on RTGB Panel XU2, is reading a normal pressure of 55 to 65 psig and, if necessary, start the standby conventional service water pump.

3. Verify that the proper bus voltage is on Emergency Bus E3.

4. Perform a visual inspection of Compartment AK4 on 4160V Emergency Bus E4 to determine the cause.

5. Perform a visual inspection of RHR SW Booster Pump 2B to verify that the pump is free of mechanical trouble ..

6. If a circuit malfunction is suspected, ensure that a WR/JO is prepared.

12APP-A-03 Rev. 44 Page 17 of 100 I

Unit 2 APP A-03 1-8 Page 2 of 2 DEVICE/SETPOINTS Alarm Relay 74: Energized Pressure Switch SW-PS-1176B 15.5 psig with a five-second time delay Instantaneous/Time Overcurrent Relay 50/51 on 0A Instantaneous Overcurrent Relay 50 on 0B Instantaneous/Time Overcurrent Relay 50/51 on 0c POSSIBLE PLANT EFFECTS

1. Reduced cooling capability of the RHR System.

2. If RHR SW Booster Pump 2B is inoperable, a Technical Specification LCO may result.

REFERENCES

1. LL-9364 - 54

2. Technical Specification 3.6.2.1, 3.7.1

3. PM 89-051 12APP-A-03 Rev. 44 Page 18 of 100 I

TASK CONDITIONS:

Unit (2) has been shutdown for maintenance for 5 days.

A spurious Group 8 isolation(High Steam Dome Pressure) caused a loss of the B loop of shutdown cooling.

RHR flow prior to the loss was ~5000 gpm The cause of the isolation was found and repaired and the isolation has been reset.

RPS is energized Reactor Water Level band is 200" to 220" Reactor pressure is 0 psig RHR system cooldown and draindown are not a concern A 2nd licensed operator will be conducting 2PT-01.7 and will notify you of any unexpected trends.

INITIATING CUE:

You are directed by the Unit sca to return the B loop of RHR to Shutdown Cooling lAW AOP-15 (Start the "8" RHR pump).

~ Progress Energy BRUNSWICK NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME XXI ABNORMAL OPERATING PROCEDURE UNIT o

OAOP-15.0 LOSS OF SHUTDOWN COOLING REVISION 20 IOAOP-15.0 Rev. 20 Page 1 of 191

1.0 SYMPTOMS 1.1 RHR SW PUMP 1A(2A) TRIP (A-01 1-9) or RHR SW PUMP 1C (2C) TRIP (A-01 3-9) is in alarm.

1.2 RHR SW PUMP 1B(2B) TRIP (A-03 1-8) or RHR SW PUMP to (20) TRIP (A-03 3-8) is in alarm.

1.3 RHR PUMP 1A(2A) TRIP (A-01 3-8) or RHR PUMP 1C(2C) TRIP (A-01 5-8) is in alarm.

1.4 RHR PUMP 1B(2B) TRIP (A-03 3-7) or RHR PUMP 10(20) TRIP (A-03 5-7) is in alarm.

1.5 RHR HX AlB DISCH CLG WTR TEMP HI (A-03 2-9) is in alarm.

1.6 RHR AlB DISCH & SUCT HDR PRESS HI (A-03 3-9) is in alarm.

1.7 REACTOR VESS LO LEVEL TRIP (A-05 2-6) is in alarm.

1.8 CORE SPRA Y OR RHR PUMPS RUNNING (A-03 2-1) is flashing.

)

1.9 ERFIS valve monitoring al'arming on RHR valve closure 1.10 Group 8 Isolation Valves close.

1.11 Increasing Reactor Coolant Temperature and/or Pressure.

IR1 7 1 1.12 High NSW or CSW header pressure approaching pump shutoff head (approximately 90 psig).

IR171 1.13 Unexplained changes in running RHRSW loop flow or pump discharge pressure.

2.0 AUTOMATIC ACTIONS 2.1 IF a Group 8 Isolation Signal exists (Low Level One or High Steam Dome Pressure), THEN the following will occur:

RHR SHUTDOWN COOLING OUTBOARD ISOLA TION D VAL VE, E11-FOOB, will close RHR SHUTDOWN COOLING INBOARD ISOLA TION D VAL VE, E1t-FOG9, will close

[ OAOP-15.0 Rev. 20 Page 2 of 191

2.0 AUTOMATIC ACTIONS Loop A(B) INBOARD INJECTION VALVE, D E11-F015A(B), will close (Low Level One Only)

The RHR Pump in service for Shutdown Cooling will trip D on a loss of suction path.

3.0 OPERATOR ACTIONS 3.1 Immediate Actions None 3.2 Supplementary Actions IR211 3.2.1 IF Shutdown Cooling has been lost due to a tripped RHR D Pump, THEN START an RHR Pump in the loop being used for Shutdown Cooling.

NOTE: During conditions in which there is no circulation, the reactor vessel water level, as read on 821-LI-R605A(B), should be maintained between 200" and 220", or as directed by the Shift Superintendent based on plant conditions, until forced circulation is restored.

3.2.2 IF forced circulation has been lost, AND natural D circulation has NOT been established, THEN RESTORE AND MAINTAIN reactor vessel water level.

IOAOP-15.0 Rev. 20 I Page 3 of 191

3.0 OPERATOR ACTIONS NOTE: A Group 10 Isolation Signal will isolate the air supply to Reactor Head Vent Valves, B21-F003 and B21-F004~ These valves fail closed on a loss of air supply or power.

3~2.3 IF vessel coolant temperature is greater than 212°F, OR is indeterminate, THEN ENSURE the following valves are closed:

- INBOARD RX HEAD VENT VLV, 821-F003 D

- OUTBOARD RX HEAD VENT VL V, B21-F004 D IR221 3.2.4 MONITOR reactor coolant heatup/cooldown in accordance with 1(2)PT-01.7 for any unexpected trends.

o NOTE: If the time to boiling in the reactor vessel can NOT be determined, it must be assumed that 212°F will be exceeded.

3.2.5 OBTAIN the approximate time to boiling in the reactor D vessel based on current plant conditions (values should be in Daily Schedule Report).

3~2.6 REFERENCE Technical Specifications 3.4~7, 3.4.8, D 3.9.7, and 3.9~8 for actions required for loss of RHR shutdown cooling.

IOAOP-15.0 Rev. 20 I Page 4 of 191

3.0 OPERATOR ACTIONS 3.2.7 PERFORM the following to ensure undervoltage trip is restored to Reactor Building Temp Power Panels 1-LOX (2-LOX) and 1-1R117A (2-2R117A):

NOTE: Keys for Mode Selector Switch 1-LOX-XFER-SW (2-LOX-XFER-SW) and 1-1R117A-XFER-SW (2-2R117A-XFER-SW) remain in the switches in Modes 4 & 5. The keys should be removed and controlled when in Modes 1, 2, &3.

NOTE: 480V Maintenance & Construction Power Distribution Panel 1-LOX (2-LOX),

breaker 1-AC-OFFSITE-LOX-1 (2-AC-OFFSITE-LOX-1)J and breaker 1-AC-OFFSITE-LOX-2 (2-AC-OFFSITE-LOX-2) are located at Reactor Building 20' elevation SW.

NOTE: Temporary Power Panel 1-1 R117A (2-2R117A) is located at Reactor Building 117' elevation SW.

1. PRIOR TO the plant entering Mode 3, PERFORM the following:

a. ENSURE mode selector switch 1-LOX-XFER-SW D (2-LOX-XFER-SW) is in the MODES 1, 2 & 3 position.

b. ENSURE breaker 1-AC-OFFSITE-LOX-1 D (2-AC-OFFSITE-LOX-1) is reset

c. ENSURE breaker 1-AC-OFFSITE-LOX-2 D (2-AC-OFFSITE-LOX-2) is reset.

d. ENSURE mode selector switch D 1-1R117A-XFER-SW (2-2R117A-XFER-SW) in the MODES 1,2 & 3 position.

e. ENSURE breaker 1-R117A-52 (2-R117A-52) is D reset IOAOP-15.0 Rev. 20 I Page 5 of 191

3.0 OPERATOR ACTIONS

2. IF the plant is returned to Mode 4 AND going to Mode 5, THEN PERFORM the following:

a. OSTAIN keys for the following mode selector switches:

1-LOX~XFER-SW(2-LOX-XFER-SW) D 1-1R117A-XFER-SW (2-2R117A-XFER-SW). D

b. ENSURE mode selector switch 1-LOX-XFER-SW D (2-LOX-XFER-SW) is in the MODES 4 & 5 position.

c. ENSURE breaker 1-AC-OFFSITE-LOX-1 D (2-AC-OFFSITE-LOX-1) is reset.

d. ENSURE breaker 1-AC-OFFSITE-LOX-2 D (2-AC-OFFSITE-LOX-2) is reset.

e. ENSURE mode selector switch D 1-1R117A-XFER-SW (2-2R117A-XFER-SW) in the MODES 4 & 5 position.

f. ENSURE breaker 1-R117A-52 (2-R117A-52) is D reset.

NOTE: Secondary Containment Pressure Seal Work Permits are tracked in accordance with OENP-54.

3.2.8 IF it becomes apparent that Shutdown Cooling can NOT be reestablished OR it has been determined that 212°F will be exceeded, THEN PERFORM the following:

1. DIRECT Engineering to restore Secondary Containment D prior to exceeding 212°F.

2. RESTORE Primary Containment prior to exceeding D 212°F.

IOAOP-15.0 Rev. 20 I Page 6 of 191

3.0 OPERATOR ACTIONS

3. CLOSE the following valves:

- INBOARD RX HEAD VENT VL V, B21-FOO3 D

- OUTBOARD RX HEAD VENT VL V, 821-FOO4. D

4. ENSURE the following valves are closed:

- REACTOR INBOARD HIGH POINT MANUAL VENT D VALVE, 821-FOO1

- REACTOR OUTBOARD HIGH POINT MANUAL D VENT VAL VE, B21-FOO2.

5. NOTIFY the wec to evaluate ongoing work which D requires the unit to be in Mode 4 for safety clearances.

3.2.9 IF the operating RHRSW loop has been lost, THEN PERFORM the following:

IR171 1. IF unexplained changes in flow or pump discharge pressure are observed in the running RHRSW loop, AND 0

)

NSW or CSW header pressure approaches pump shutoff head (approximately 90 psig), THEN ENSURE UNIT 1(2) SERVICE WA TER DISCHARGE OUTLET VALVE, SW-V442, is open.

2. IF available, THEN START the idle RHRSW Booster D Pump in the RHRSW loop being used for Shutdown Cooling.

3. IF the NSW or esw Service Water Header has been D lost, THEN PLACE the RHRSW loop in operation using the other Service Water header in accordance with 1(2)OP-43.

4. IF NO RHRSW Booster Pumps can be placed in D operation, THEN PLACE RHRSW in operation with NO RHRSW Booster Pumps available in accordance with 1(2)OP-43.

5. IF Service Water is unavailable, THEN PLACE Fire D Protection Water in operation to the Service Water Header in accordance with OAOP-18.0.

IOAOP-15.0 Rev. 20 Page 7 of 191

3.0 OPERATOR ACTIONS IR211 3.2.10 IF the RHR loop operating in Shutdown Cooling has D been lost AND the following conditions exist, THEN SHIFT Shutdown Cooling loops in accordance with 1(2)OP-17:

- NO Group 8 Isolation Signal

- NEITHER RHR Pump in the RHR loop being used for Shutdown Cooling can be started.

3.2.11 IF the RHR loop operating in Shutdown Cooling has been lost AND a Group 8 Isolation Signal is present,

) THEN PERFORM the following:

1. RESTORE AND MAINTAIN reactor water level in the D previously*established band in accordance with direction of the Shift Superintendent.

2. REDUCE reactor pressure below 125 psig in accordance D with OGP-05.

3. ENSURE RPS is energized. D

4. WHEN Group 8 Isolation signals have cleared, THEN D

-RESET the Group 8 Isolation.

5. IF RHR System piping cool down or drain down are NOT a concern, THEN PERFORM the following to restore the RHR loop that was operating in Shutdown Cooling:

a. CLOSE Loop A(B) OUTBOARD INJECTION D VALVE, E11-F017A(B).

b. OPEN Loop A (B) INBOARD INJECTION VALVE, D E11-F015A(B).

[ OAOP-15.0 Rev. 20 Page 8 of 191

3.0 OPERATOR ACTIONS

c. Unit 1 Only: OPEN RHR SHUTDOWN COOLING 0 OUTBOARD ISOLA TION VALVE, E11-FOOB.

d. Unit 1 Only: SLOWLY OPEN RHR SHUTDOWN 0 COOLING INBOARD ISOLA TION VALVE, E11-F009.

e. Unit 2 Only: OPEN RHR SHUTDOWN COOLING 0 INBOARD ISOLATION VALVE, E11-F009.

f. Unit 2 Only: SLOWLY OPEN RHR SHUTDOWN 0 COOLING OUTBOARD ISOLA TION VAL VE, E11-FOOB.

g. START an RHR Pump in the loop being used for 0 Shutdown Cooling.

h. SLOWLY THROTTLE OPEN Loop A(B) 0 OUTBOARD INJECTION VALVE, E11-F017A(B) to re-establish RHR loop conditions prior to the event.

i. WHEN RHR loop conditions have stabilized, 0 FULLY OPEN Loop A(B) OUTBOARD INJECTION VALVE, E11-F017A(B).

j. IF the reactor coolant temperature is less than 212°F, THEN ENSURE the following valves are open:

- INBOARD RX HEAD VENT VLV, B21-FOO3 0

- OUTBOARD RX HEAD VENT VL ~ B21-FOO4. 0

k. MAINTAIN RHR in Shutdown Cooling in 0 accordance with 1(2)OP-17.

IOAOP-15.0 Rev. 20 I Page 9 of 191

3.0 OPERATOR ACTIONS

6. IF RHR has NOT been restored in accordance with Step 3.2.11.5, THEN PLACE the RHR loop that was operating o

in Shutdown Cooling back in service in accordance with 1(2)OP-17 as soon as conditions permit.

3.2.12 IF necessary to minimize reactor coolant temperature. o rise, THEN PERFORM one of the following feed and bleed combinations:

FEED BLEED COND/FW in accordance with RWCU Reject in accordance 1(2)OP-32 with 1(2)OP-14 CRD in accordance with Reactor Water Level Control 1(2)OP-08 using Main Steam Lines in Core Spray in accordance accordance with 1(2)OP-32 with 1(2)OP-18 LPCI in accordance with 1(2)OP-17 3.2.13 IF NEITHER RHR loop can be placed in Shutdown Cooling, THEN PLACE the Condensate System in o

Condenser Cooling in accordance with 1(2)OP-32.

3.2.14 IF ALL of the above methods can NOT maintain reactor vessel coolant temperature below 212°F, THEN INITIATE alternate Shutdown Cooling with the SRVs as follows:

1. ENSURE ALL control rods are fully inserted. o

2. CONFIRM reactor vessel head is installed and o tensioned.

3. IF the Reactor Recirculation Pumps are running, THEN PERFORM the following:

a. RAISE AND MAINTAIN reactor water level between 200" and 220" as read on o

821-LI-R605A(B), or as directed by Shift Superintendent based on plant conditions.

b. STOP the running Reactor Recirculation Pumps in o accordance with 1(2)OP-02.

[ OAOP-15.0 Rev. 20 Page 10 of 191

3.0 OPERATOR ACTIONS

4. SHUT DOWN the RHR loop that was operating in D Shutdown Cooling in accordance with 1(2)OP-17.

5. PLACE one RHR loop in the Suppression Pool Cooling D mode in accordance with 1(2)OP-17.

6. IF Suppression Pool temperature rises above 95°F, D THEN GO TO OEOP-02-PCCP, Primary Containment Control Procedure AND PERFORM CONCURRENTLY with this procedure.

7. EONSURE the following valves are closed:

a. INBOARD MS/V A VLV, B21-F022A D

b. INBOARD MS/V B VLV, B21-F0228 D

c. INBOARD MS/V C VL V, B21-F022C D

d. INBOARD MSIV D VLV, B21-F022D D

e. OUTBOARD MSIV A VLV, B21-F02BA D

f. OUTBOARD MS/V B VLV, B21-F02BB D

g. OUTBOARD MSIV C VL V, B?1-F02BC D

h. OUTBOARD MSIV D VL V, B21-F02BD D

i. STEAM SUPPL Y INBOARD ISOL VLV, E41-FOO2 D

j. STEAM SUPPL Y OUTBOARD ISOL VL V, D E41-FOO3

k. STEAM SUPPL Y INBOARD ISOL VL V, E51-FOO7 D I. STEAM SUPPL Y OUTBOARD ISOL VL V, D E51-FOGB

m. INBOARD RX HEAD VENT VL V, B21-FOO3 D

n. OUTBOARD RX HEAD VENT VLV, B21-FOO4 D IOAOP-15.0 Rev. 20 Page 11 of 191

3.0 OPERATOR ACTIONS

o. REACTOR INBOARD HIGH POINT MANUAL D VENT VALVE, 821-FOO1

p. REACTOR OUTBOARD HIGH POINT MANUAL D VENT VALVE, B21-FOO2

q. MAIN STEAM LINE DRAIN INBO ISOL VL V, D 821-F016

r. MAIN STEAM LINE DRAIN OUTBO ISOL VL V, D 821-F019~

8. SELECT one SRV based upon the desired cool down rate using the following table:

NOTE: All SRVs within the same block on the table will produce a similar cooldown rate; therefore, to effect a change in cooldown rate, an SRV in a different box must be used.

RHR RHR CS CS Ale BID A B HIGHEST B21-F013F B21-F013A B21-F013K B21-F013E COOLDOWN B21-F013H B21-F013B B21-F013L 821-F013G B21-F013C B21-F013G B21-F013C B21-F013J B21-F013D B21-F013J B21-F013D B21-F013A B21-F013E B21-F013E B21-F013A B21-F013B B21-F013F B21-F013F B21-F013B B21-F013K B21-F013H B21-F013H B21-F013K B21-F013L B21-F013L B21-F013C B21-F013G B21-F013C B21-F013G B21-F013D B21-F013J B21-F013D B21-F013J LOWEST B21-F013E B21-F013K B21-F013A B21-F013F COOLDOWN B21-F013L B21-F013B B21-F013H

9. PLACE the control switch for the desired SRV to OPEN. D IOAOP-15.0 Rev. 20 Page 12 of 191

3.0 OPERATOR ACTIONS NOTE: Raising RPV water level slowly using CRD is preferred to reduce stresses induced in the RPV vessel and piping when injecting cold water. RHR and CS may be used if necessary, but should be considered only after determining other methods are not effective.

10. RAISE AND MAINTAIN reactor water level greater than D 254 inches.

NOTE: The RHR pumps are preferred for injection.

NOTE: Monitoring TSAT in accordance with 1(2)PT-01.7 may NOT be valid under these special conditions due to reactor pressure NOT necessarily relating to TSAT . Therefore, SRV tailpipe temperature recorder 821- TR-R614 on Panel H12-P614, and/or ERFIS trending should be utilized for monitoring reactor coolant cool down rate.

11. IF any low pressure injection system, other than the RHR Loop operating in Suppression Pool Cooling, is available, THEN PERFORM the following:

a. IF an RHR Pump is to be started, THEN PERFORM the following:

- CLOSE the applicable OUTBOARD D INJECTION VLV, E11-F017A(B).

- START an available RHR Pump. D

- OPEN the applicable INBOARD INJECTION D VLV, E11-F015A(B).

- THROTTLE OPEN the applicable OUTBOARD D INJECTION VL V, E11-F017A(B), until the SRV opens.

b. IF a Core Spray Pump is to be started, THEN PERFORM the following:

- START the available Core Spray Pump. D

- THROTTLE OPEN the applicable INBOARD D INJECTION VALVE, E21-F005A(B), until the SRVopens.

IOAOP-15.0 Rev. 20 Page 13 of 191

3.0 OPERATOR ACTIONS

12. IF the only low pressure injection system available is the RHR Loop in Suppression Pool Cooling, THEN PERFORM the following:

a. CLOSE the applicable OUTBOARD INJECTION D VLV, E11-F017A(B)~

b. CLOSE TORUS COOLING ISOL VL V, D E11-F024A(B.

c. OPEN the applicable INBOARD INJECTION VL V, D E11-F015A(B).

d. THROTTLE OPEN OUTBOARD INJECTION VL V, D E11-F017A(B), until the selected SRV opens.

13. IF reactor pressure can NOT be maintained less than D 164 psig above Suppression Chamber pressure, THEN PLACE another SRV control switch to OPEN.

14. PERFORM the following as necessary to maintain cool down rate less than 100°F per hour:

a. THROTTLE CLOSE the injection valve on the D affected pump until the desired SRV closes.

b. RECORD reactor pressure at which the SRV D closes.

_ _ _ _ psig

c. THROTTLE OPEN the injection valve on the D affected pump until the SRV reopens.

d. THROTTLE CLOSE the injection valve on the D affected pump until reactor pressure is 10 to 20 psig greater than the pressure at which the SRV closed in Step 3.2.14.14.b.

e. IF it is desired to adjust the cool down rate, THEN D CLOSE the open SRV AND OPEN the next SRV that will adjust the cool down rate in the desired direction.

IOAOP-15.0 Rev. 20 Page 14 of 191

3.0 OPERATOR ACTIONS

15. REPEAT Step 3.2.14.14 until vessel coolant and D Suppression Pool temperature are within 100°F.

16. CONTROL Suppression Pool temperature as necessary D to maintain vessel coolant temperature above 75°F.

17. WHEN a normal method of Shutdown Cooling can be established, THEN SHUT DOWN alternate Shutdown Cooling as follows:

a. STOP the ECCS pump(s) used for vessel D injection.

b. WHEN the SRV(s) that were opened have closed, D THEN PLACE the control switch for the SRV(s) to CLOSE OR AUTO.

c. IF the reactor coolant temperature is less than 212°F, THEN OPEN the following valves:

- INBOARD RX HEAD VENT VL V, B21-F003 D

- OUTBOARD RX HEAD VENT VL V, B21-F004. D IR211

d. RESTORE AND MAINTAIN reactor water level tl ft D

between 200 and 220 or as directed by the Shift Superintendent, based on plant conditions.

e. WHEN directed by the Shift Superintendent, . D THEN SHUT DOWN the RHR loop used for Suppression Pool Cooling in accordance with 1(2)OP-17.

IOAOP-15.0 Rev. 20 Page 15 of 191

4.0 GENERAL DISCUSSION An extended loss of the decay heat removal function can lead to elevated vessel coolant temperatures, localized or bulk coolant boiling and potentially result in a depletion of reactor coolant and eventual uncovering of the core. If no forced circulation exists during a Loss of Shutdown Cooling event, natural circulation must be established. Natural circulation however, cannot be depended on to provide adequate flow through the bottom head region or the recirculation loops. The recirculation loop suction temperatures and bottom head temperatures therefore cannot be utilized for vessel coolant temperature monitoring for heatup rate determination or indication of boiling.

In addition, if RWCU is not in service with suction from the bottom head, vessel bottom head drain temperature cannot be used for verification of Tech Spec 3.4.9 (PressurelTemperature Curves) compliance for cooldowns.

IR221 Under natural circulation conditions, reactor vessel pressure must be monitored for vessel coolant temperature determination. If vessel coolant temperature is less than 212°F, pressure must be closely monitored for indications of a trend of increasing pressure. If this trend is established, it must be assumed that 212°F has been exceeded, boiling is occurring, and a mode change has taken place.

)R21 I If reactor coolant temperature is greater than 212°F, and reactor water level has been raised to greater than 218 inches for 10 minutes or more, then a false RPV low level signal could result when the reference leg condensing pot N12A(B) nozzle is uncovered as level is subsequently lowered below 218 inches. This false signal is the result of water exiting the nozzle and condensing pots at the same time steam is re-entering the reference leg. This counter flow condition sets up the conditions conducive to steam bubble creation and collapse. This causes a momentary upward pressure spike in the reference leg, which gives a momentary indicated false signal to the transmitters involved.

While irradiated fuel remains in the reactor vessel during an outage, maintaining the decay heat removal function remains a key to shutdown safety. The risk associated with a loss of decay heat removal event is dependent on a number of factors, including the decay heat load present and the existing plant configuration. Outage risk assessment will ensure that adequate contingency plans are in place prior to reducing decay heat removal capability.

IOAOP-15.0 Rev. 20 Page 16 of 191

4.0 GENERAL DISCUSSION This procedure addresses a loss of normal decay heat removal capability during shutdown conditions. The procedure provides contingencies for the following methods of decay heat removal:

RHRSW Loop Failure RHR Loop Failure Condenser Cooling Failure Feed and Bleed Combinations Alternate Shutdown Cooling with SRVs This procedure also provides contingencies for restoring primary and secondary containment, and initial emergency actions for a Joss of Shutdown Cooling.

Industry events have occurred which demonstrate that use of the SRVs to steam to the Suppression Pool is a viable method of decay heat removal. Makeup requirements can be supplied by a single CRD Pump in this mode of cooling.

Outage risk assessment should prevent the need for ever using this mode of cooling.

IOAOP-15.0 Rev. 20 Page 17 of 191

5.0 REFERENCES

5~ 1 Regulatory Guide 1~33J Quality Assurance Program Requirements (Operations) (November 1972), Appendix A, Item F~8 5.2 ANSI Standard N18.7-1976, Administrative Controls and Quality Assurance for the Operational Phase of Nuclear Power Plants, Section 5~3~9~2, Item (3) 5~3 Technical Specifications 3.4.7, 3~4.8, 3.4~9, 3.6.1.1, 3.6.4~ 1, 3~9~7, and 3~9.8 5.4 FSAR Section 5~4.7, 7~4.3, 15~2~7 5.5 NUMARC 91-06, Guidelines for Industry Actions to Assess Shutdown Management 5.6 1(2)APP-A-01 , Annunciator Panel Procedure For Panel A-01 5~7 1(2)APP-A-03, Annunciator Panel Procedure For Panel A-03 5.8 1(2)APP-A-05, Annunciator Panel Procedure For Panel A-OS 5~9 OAOP-18.0, Nuclear Service Water System Failure 5.10 1(2)OP-02, Reactor Recirculation System Operating Procedure 5.11 1(2)OP-08, Control Rod Drive Hydraulic System Operating Procedure 5~ 12 1(2)OP-14, RWCU System Operating Procedure 5~13 1(2)OP-17, RHR System Operating Procedure 5~ 14 1(2)OP-18, Core Spray System Operating Procedure 5~ 15 1(2)OP-32, Condensate and Feedwater System Operating Procedure 5.16 1(2)OP-43, Service Water System Operating Procedure IR171 5.17 IER #92-21-03 (IFI); FACTS #9389034 5.18 OEOP-02-PCCP, Primary Containment Control Procedure 5~ 19 OENP-54, Building Ventilation Pressure Control Program 5~20 1(2)PT-01 ~ 7, Heatup/Cooldown Monitoring IR211 5.21 CR 95-01883, False RPV Water Level Low Level 1 Signals IR221 5.22 AI 95-02283,1995 INPO Response 6.0 ATTACHMENTS None IOAOP-15.0 Rev. 20 Page 18 of 191

REVISION

SUMMARY

Revision 20: As requested by PRR 222219, added additional symptoms to Section 1.0.

Revision 19 closes the RHR outboard injection valve F017, opens F015, and then throttles F017 when in alternate shutdown cooling to utilize throttle capability of F017; directs bleed portion of feed and bleed approach in step 3.2.12 to be performed in accordance with reactor water level control using main steam lines Revision 18 incorporates PRR209334 which adds Step 3.2.8.5 to notify the weco Revision 17 - Editorial Correction to change font of place keeping check boxes.

Revision 16 - Format changes to meet the requirements of OAP-OOS, changed word processing software to Microsoft Word XP, added place keeping aids, and changed wording to accommodate the difference between Unit 1 and 2 Shutdown Cooling suction valves.

)

IOAOP-15.0 Rev. 20 Page 19 of 191

-,1 NRC SIM JPM S-5 Page 1 of 9 PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION JOB PERFORMANCE MEASURE NRC 81M JPM 8-5 TITLE: Primary Containment Ventilation During Personnel Entry

NRC SIM JPM S-5 Page 2 of 9 SAFETY CONSIDERATIONS:

None.

EVALUATOR NOTES: (Do not read to trainee)

1. The applicable procedure section WILL be provided to the trainee.

2. Validation time 20 minutes TASK CONDITIONS:

1. Unit Two (2) is in Mode 4.

2. Primary Containment purging is complete lAW 20P-24, Section 5.3.

3. Primary Containment oxygen concentration is >18%.

4. An E&RC air sample has determined radioactive gases are less than 1 DAC.

5. Five drywell volumes have been purged.

6. The Reactor Building Ventilation System is in operation per 20P-37.1 and SBGT is in STANDBY per 2QP-10.

7. Personnel entry into primary containment is necessary.

8. The requirements for isolation of all nitrogen sources to the containment and TIP System have been met.

9. E&RC has been notified of changing ventilation in primary containment.

INITIATING CUE:

You are directed by the Unit SCQ to startup Primary Containment Ventilation During Personnel Entry, per 20P-24 using both purge exhaust fans and inform the Unit SCO when the actions are complete.

NRC SIM JPM S-5 Page 3 of 9 Step 1 - Obtain a current revision of 20P-24, Section 5.4.

Current Revision of 20P-24, Section 5.4 obtained.

SAT/UNSAT Step 2 - WHEN the unit is in Mode 4, THEN STOP PURGE EXHAUST FAN, 2A-PS-EF-RB AND 2B-PS-EF-RB, if running.

Ensures Purge Exhaust Fans are not running SAT/UNSAT Step 3 - Ensure the following valves are OPEN (Procedure Steps 5.4.2.3 thru 5.4.2.10)

OPENS the following are valves: **ALL ARE CRITICAL STEPS**

1. ENSURE DIW N2 INLET VLV, CAC-V6. SATI UNSAT

2. ENSURE TORUS N2 INLET VLV, CAC-V5. SATI UNSAT

3. ENSURE TORUS PURGE EXH VLV, CAC-V7. SATI UNSAT

4. ENSURE TORUS PURGE EXH VLV, CAC-V8. SATI UNSAT

5. ENSURE DRYWELL PURGE EXH VLV, CAC-V9. SATI UNSAT

6. ENSURE DRYWELL PURGE EXH VLV, CAC-V10. SATI UNSAT

7. ENSURE DW HEAD PURGE EXH VLV, CAC-V49. SATI UNSAT

8. ENSURE DW HEAD PURGE EXH VLV, CAC-V50. SATI UNSAT

NRC SIM JPM S-5 Page 4 of 9 Step 4 - IF running, THEN STOP SBGT A and B.

Ensures SBGT A & B are not running SAT/UNSAT Step 5 - ENSURE SBGT OW SUCT DAMPER, 2F-BFV-RB, is closed.

Ensures SBGT OW SUCT DAMPER, 2F-BFV-RB, is closed SAT/UNSAT Step 6 - OPEN PURGE SUCTION & INBO EXHAUST ISOL, 21-BFV-RB AND 2N-BFV-RB.

Opens PURGE SUCTION & INBD EXHAUST ISOL, 21-BFV-RB AND 2N-BFV-RB.

- CRITICAL STEP**

SAT/UNSAT Step 7 - OPEN PURGE OTBO EXHAUST ISOL, 2A-BFV-RB.

OPENs PURGE OTBD EXHAUST ISOL, 2A-BFV-RB

- CRITICAL STEP**

SAT/UNSAT

NRC SIM JPM S-5 Page 5 of 9 Step 8 - ENSURE DW PURGE AIR INLET VLV, CAC-V15, is open.

Ensures OW PURGE AIR INLET VLV, CAC-V15, is open.

- CRITICAL STEP**

SAT/UNSAT Step 9 - PLACE DW/TORUS PURGE DAMPER, 2C-TPD-RB, in MAX.

Places DW/TORUS PURGE DAMPER, 2C-TPD-RB, in MAX.

SAT/UNSAT NOTE: The following caution is prior to the next step CAUTION Starting a second fan when one is already running causes excessive thermal stress to the motor. This is due to the reverse rotation of the non-running fan while the suction and discharge dampers are opening. Starting of fan(s) should be in the slow mode of operation until system pressure stabilizes and then shifted to the fast mode of operation as desired.

NRC SIM JPM S-5 Page 6 of 9 EXAMINER NOTE: A dual fan start was specified in the initiating cue. Slow speed is required by the caution noted above.

NOTE: Even if the following step is performed correctly the fan may shift to

'Fast', If so, it should be placed back to 'Slow' and is not considered incorrect.

If asked, 2-hand operation is permitted for the next step.

Step 10- PERFORM the following to start Purge Exhaust Fan(s).

a. IF a single fan start is desired, THEN START 2A-PS-EF-RB or 2B-PS-EF-RB.

b. IF dual fan starts are desired, THEN SIMULTANEOUSLY START 2A-PS-EF-RB and 2B-PS-EF-RB.

c. IF a second fan start is desired AND one fan is already running, THEN PERFORM the following:

- STOP the running fan.

- WHEN the suction and discharge dampers indicate full closure, THEN SIMULTANEOUSLY START 2A& 2B-PS-EF-RB Performs a dual fan start in slow speed (step b. above)

- CRITICAL STEP**

SAT/UNSAT Step 11 - ENSURE SBGT TRAIN 2A REACTOR BUILDING SUCTION VALVE, 2D-BFV-RB, is open.

Ensures SBGT TRAIN 2A REACTOR BUILDING SUCTION VALVE, 2D-BFV-RB, is open SAT/UNSAT

NRC SIM JPM S-5 Page 7 of 9 Step 12 - ENSURE SBGT TRAIN 2B REACTOR BUILDING SUCTION VALVE, 2H-BFV-RB, is open.

Ensures SBGT TRAIN 2B REACTOR BUILDING SUCTION VALVE, 2H-BFV-RB, is open.

SAT/UNSAT TERMINATING CUE/NOTE: The JPM is complete when the next step is addressed. Another operator will perform that step.

COMMENTS:

NRC SIM JPM S-5 Page 8 of 9 KA Reference 288000 A4.01 3.1/2.9: Ability to manually operate and/or monitor in the control room: Start and stop fans.

REFERENCES:

20P-24, Rev.139 TOOLS AND EQUIPMENT:

None.

SAFETY FUNCTION (from NUREG 1123, Rev 2.):

9 - Rad Release - Plant ventilation Time Required for Completion: 20 Minutes (approximate).

APPLICABLE METHOD OF TESTING Performance: Simulate Actual X Unit: 2 Setting: Control Room Simulator X Time Critical: Yes No Time Limit N/A Alternate Path: Yes No X EVALUATION JPM: Pass Fail

1. Unit Two (2) is in Mode 4.

2. Primary Containment purging is complete lAW 20P-24, Section 5.3.

3. Primary Containment oxygen concentration is >18%.

4. An E&RC air sample has determined radioactive gases are less than 1 DAC.

5. Five drywell volumes have been purged.

6. The Reactor Building Ventilation System is in operation per 20P-37.1 and SBGT is in STANDBY per 2QP-10.

7. Personnel entry into primary containment is necessary.

8. The requirements for isolation of all nitrogen sources to the containment and TIP System have been met.

9. E&RC has been notified of changing ventilation in primary containment.

INITIATING CUE:

You are directed by the Unit SCO to startup Primary Containment Ventilation During Personnel Entry, per 20P-24 using both purge exhaust fans and inform the Unit SCQ when the actions are complete.

5.4 Primary Containment Ventilating During Personnel Entry C Continuous Use 5.4.1 Initial Conditions

1. Primary containment purging is complete in accordance D with Section 5.3 or 8.13.

2. IF the unit is in Mode 1, 2, or 3, THEN drywelJ purge is in D service in accordance with Section 5.3.

3. Primary containment oxygen concentration is greater D than 180/0.

4. An E&RC air sample determined radioactive gases are D less than 1 DAC.

5. Five drywell volumes have been purged. D

6. The Reactor Building Ventilation System is in operation D in accordance with 20P-37.1.

7. Personnel entry into primary containment is necessary. D 5.4.2 Procedural Steps NOTE: The performance of Step 5.4.2.1 completes the conditions necessary to make drywell entry in Modes 1, 2, or 3 and the remainder of this section is not applicable. This step must also be completed to satisfy personnel entry requirements for Modes 4 and 5.

IR271

1. ENSURE the requirements for isolation of all nitrogen D sources to containment AND TIP System have been met as specified by 001-01.02 for drywell entry.

!20P-24 Rev. 139 Page 35 of 196 ]

5.4.2 Procedural Steps NOTE: E&RC should be notified prior to changing ventilation through primary containment..

2. WHEN the unit is in Mode 4, THEN STOP PURGE D EXHAUST FAN, 2A-PS-EF-RB AND 2B-PS-EF-RB, if running.

3. ENSURE D/W N2 /NLET VLV, CAC-V6, is open. D

4. ENSURE TORUS N2/NLET VLV, CAC-V5, is open. D

5. ENSURE TORUS PURGE EXH VLV, GAG-V?, is open. D

6. ENSURE TORUS PURGE EXH VLV, CAC-VB, is open. D

7. ENSURE DRYWELL PURGE EXH VLV, GAC-V9, is D open.

8. ENSURE DRYWELL PURGE EXH VLV, CAC-V10, is D open.

9. ENSURE OW HEAD PURGE EXH VLV, CAG-V49, is D open.

10. ENSURE OW HEAD PURGE EXH VLV, CAC-V50, is D open.

11. IF running, THEN STOP SBGT A and B. D

12. ENSURE SBGT OW SUGT DAMPER, 2F-BFV-RB, is D closed.

13. OPEN PURGE SUCTION & /NBD EXHAUST /SOL, D 2/-BFV-RB AND 2N-BFV-RB.

14. OPEN PURGE OTBD EXHAUST /SOL, 2A-BFV-RB. D

!20P-24 Rev. 139 Page 36 of 1961

5.4.2 Procedural Steps

15. ENSURE OW PURGE AIR INLET VLV, CAC-V15, is D open.

16. PLACE OWITORUS PURGE DAMPER, 2C-TPD-RB, in D MAX.

17. PERFORM the following to start Purge Exhaust Fan(s).

a. IF a single fan start is desired, THEN START D 2A-PS-EF-RB or 2B-PS-EF-RB.

b. IF dual fan starts are desired, THEN D SIMULTANEOUSLY START 2A-PS-EF-RB and 2B-PS-EF-RB.

c. IF a second fan start is desired AND one fan is already running, THEN PERFORM the following:

STOP the running fan. D WHEN the suction and discharge dampers D indicate full closure, THEN SIMULTANEOUSLY START 2A-PS-EF-RB and 2B-PS-EF-RB.

18. ENSURE SBGT TRAIN 2A REACTOR BUILDING D SUCTION VAL VE, 2D-BFV-RB, is open.

120P-24 Rev. 139 Page 37 of 196]

5.4.2 Procedural Steps

19. ENSURE SBGT TRAIN 28 REACTOR BUILDING D SUCTION VAL VE, 2H-8FV-RB, is open.

20. IF Section 7.3 was NOT performed prior to this section, D THEN ENSURE SBGT System in standby in accordance with 20P-10.

NOTE: The Control Operator may adjust primary containment flow as specific activities in the primary containment require.

!20P-24 Rev. 139 Page 38 of 1961

1. Unit Two (2) is in Mode 4.

2. Primary Containment purging is complete lAW 20P-24, Section 5.3.

3. Primary Containm*ent oxygen concentration is >18%.

4. An E&RC air sample has determined radioactive gases are less than 1 DAC.

5. Five drywell volumes have been purged.

6~ The Reactor Building Ventilation System is in operation per 20P-37 ~ 1 and SBGT is in STANDBY per 20P-10.

7. Personnel entry into primary containment is necessary.

8. The requirements for isolation of all nitrogen sources to the containment and TIP System have been met.

9. E&RC has been notified of changing ventilation in primary containment.

INITIATING CUE:

You are directed by the Unit SCQ to startup Primary Containment Ventilation During Personnel Entry, per 2QP-24 using both purge exhaust fans and inform the Unit SCQ when the actions are complete.

5.4 Primary Containment Ventilating During Personnel Entry C Continuous Use 5.4.1 Initial Conditions

1. Primary containment purging is complete in accordance D with Section 5.3 or 8.13.

2. IF the unit is in Mode 1, 2, or 3, THEN drywell purge is in D service in accordance with S~ction 5.3.

3. Primary containment oxygen concentration is greater D than 18%.

4. An E&RC air sample determined radioactive gases are D less than 1 DAC.

5. Five drywell volumes have been purged. D

6. The Reactor Building Ventilation System is in operation D in accordance with 20P-37.1.

7. Personnel entry into primary containment is necessary. D 5.4.2 Procedural Steps NOTE: The performance of Step 5.4.2.1 completes the conditions necessary to make drywell entry in Modes 1, 2, or 3 and the remainder of this section is not applicable. This step must also be completed to 'satisfy personnel entry requirements for Modes 4 and 5..

IR271

1. ENSURE the requirements for isolation of all nitrogen D sources to containment AND TIP System have been met as specified by 001-01.02 for drywell entry..

120P-24 Rev. 139 Page 35 of 1961

5.4.2 Procedural Steps NOTE: E&RC should be notified prior to changing ventilation through primary containment..

2.. WHEN the unit is in Mode 4, THEN STOP PURGE D EXHAUST FAN, 2A-PS-EF-RB AND 2B-PS-EF-RB, if running .

3.. ENSURE D/W N 2 1NLET VLV, GAG-V6, is open.. D 4.. ENSURE TORUS N 2 INLET VL V, GAG-V5, is open. D 5.. ENSURE TORUS PURGE EXH VLV, GAG-V?, is open.. D

6. ENSURE TORUS PURGE EXH VLV, GAG-VB, is open.. D 7.. ENSURE DRYWELL PURGE EXH VLV, CAC-V9, is D open .

8.. ENSURE DRYWELL PURGE EXH VLV, GAC-V10, is D open.

9.. ENSURE OW HEAD PURGE EXH VLV, GAC-V49, is D open.

10.. ENSURE OW HEAD PURGE EXH VLV, CAC-V50, is D open.

11.. IF running, THEN STOP SBGT A and B.. D 12.. ENSURE SBGT OW SUCT DAMPER, 2F-BFV-RB, is D closed .

13.. OPEN PURGE SUCTION & INBO EXHAUST ISOL, D 21-BFV-RB AND 2N-BFV-RB..

14.. OPEN PURGE OTBO EXHAUST ISOL, 2A-BFV-RB.. D 120P-24 Rev. 139 Page 36 of 1961

5.4.2 Procedural Steps

15. ENSURE OW PURGE AIR INLET VLV, CAC-V15, is D open.

16. PLACE DWITORUS PURGE DAMPER, 2C-TPD-RB, in D MAX.

17. PERFORM the following to start Purge Exhaust Fan(s).

a. IF a single fan start is desired, THEN START D 2A-PS-EF-RB or 2B-PS-EF-RB.

b. IF dual fan starts are desired, THEN D SIMULTANEOUSLY START 2A-PS-EF-RB and 2B-PS-EF-RB.

c. IF a second fan start is desired AND one fan is already running, THEN PERFORM the following:

STOP the running fan. D WHEN the suction and discharge dampers D indicate full closure, THEN SIMULTANEOUSLY START 2A-PS-EF-RB and 2B-PS-EF-RB.

18. ENSURE SBGT TRAIN 2A REACTOR BUILDING D SUCTION VALVE, 20-BFV-RB, is open.

120P-24 Rev. 139 Page 37 of 196/

5.4.2 Procedural Steps

19. ENSURE SBGT TRAIN 28 REACTOR BUILDING D SUCTION VAL VE, 2H-BFV-RB, is open.

20. IF Section 7.3 was NOT performed priorto this section, D THEN ENSURE SBGT System in standby in accordance with 20P-10.

NOTE: The Control Operator may adjust primary containment flow as specific activities in the primary containment require.

120P-24 Rev. 139 Page 38 of 1961

NRC SIM JPM *S-6 Page 1 of 8 PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION JOB PERFORMANCE MEASURE NRC 81M JPM 8-6 TITLE: Manual Transfer of 4160 Emergency Bus Supply from the DG to the Normal Feeder lAW OOP-50.1

NRC SIM JPM S-6 Page 2 of 8 SAFETY CONSIDERATIONS:

None.

SIMULATOR SETUP: IC-196 EVALUATOR NOTES: (Do not read to trainee)

1. The applicable procedure section WILL NOT be provided to the trainee.

2. Validation time was 20 minutes TASK CONDITIONS:

1. Unit Two (2) is operating at 1000/0 power.

2. Emergency Bus E3 is being carried by the #3 EDG due to a relay trip of the E3 Bus feeder breaker.

3. The Unit 2 alignment (Isolations and Actuations) has been restored to normal configuration following the restoration of power to Bus E3 from DG-3.

4. Repairs have been completed to the E-3 feeder breaker relay.

5. Normal feeder bus for emergency bus is energized.

6. The Load Dispatcher has been notified that the 4160V E-3 Bus power supply is being shifted to the Normal Feeder.

INITIATING CUE:

You are directed by the Unit sea to manually transfer the 4160 Emergency Bus Supply for Emergency Bus E-3 from the DG to the Normal Feeder lAW OOP-50.1.

NRC SIM JPM S-6 Page 3 of 8 EXAMINER NOTE: The following note and caution must be noted prior to performing step 1 of JPM (End of Procedure Step 8.6.1)

NOTE:

WHEN transferring the diesel generator from Auto Mode to Control Room Manual, diesel generator frequency is expected to drop approximately 3 Hz at rated load. Since the range of frequency drop to diesel generator load is linear (e.g., transfer to Control Room Manual at half load results in a frequency drop of 1.5 Hz), adjustments to lower diesel generator load or raise diesel frequency can be made to compensate for frequency drop prior to the transfer. See Figure 1.

CAUTION:

Failure to reduce load or raise frequency on the diesel generator as necessary, prior to transferring to Control Room Manual may result in trip of the RPS EPA breakers on underfrequency (57.7 Hz decreasing).

Step 1- Obtain and Review procedure OOP-50.1. and begin at step 8.6.1 Procedure OOP-50.1. obtained and reviewed.

SAT/UNSAT Step 2- PERFORM one or more of the following as necessary to prevent RPS EPA breaker trip.

- RAISE diesel generator frequency (limiter set at 61 Hz)

- REDUCE diesel generator load Raises frequency and/or reduces load to maintain 60 hertz SAT/UNSAT

NRC SIM JPM S-6 Page 4 of 8 Step 3 - PLACE the appropriate diesel generator control in control room manual mode by depressing applicable push button on Panel XU-2.

Depresses PB and places the #3 EDG control in control room manual

CRITICAL STEP**

SAT/UNSAT Step 4 - PLACE appropriate synchroscope switch in ON for normal feed to emergency bus: E3 BUS 20 TO BUS E3 (2A01).

Places E3 BUS 20 TO BUS E3 (2A01) synchroscope switch in ON

- CRITICAL STEP**

SAT/UNSAT NOTE: Procedure Caution Prior to next step CAUTION Incoming voltage is from the grid and running voltage is from the diesel generator.

Step 5 - ENSURE incoming and running voltages are matched.

Ensures incoming and running voltages are matched.

SAT/UNSAT

NRC SIM JPM S-6 Page 5 of 8 NOTE: Procedure Caution Prior to next step CAUTION WHEN the synchroscope is rotating slowly in the fast direction during this method of transfer, it will be necessary to raise DG frequency to obtain rotation in the slow direction. Failure to follow this guidance could result in an RPS MG set trip on low frequency at 57.7 Hz decreasing.

Step 6 - ADJUST diesel generator GOVERNOR motor control switch as necessary so the synchroscope is rotating slowly in the SLOW direction (counterclockwise).

ADJUST diesel generator GOVERNOR motor control switch as necessary so the synchroscope is rotating slowly in the SLOW direction (counterclockwise).

- CRITICAL STEP**

SAT/UNSAT Step 7 - WHEN synchroscope is at "12 o'clock", THEN PLACE AND HOLD control switch for appropriate normal feed to emergency bus in CLOSE until both MSTR and SLAVE breakers indicate closed:

BUS 20 TO BUS E3 Master - 2AD1 Slave - A12.

Places AND Holds control switch for appropriate normal feed to emergency bus in CLOSE until both MSTR (2AD1) and SLAVE (AI2) breakers indicate closed:

- CRITICAL STEP**

SAT/UNSAT Step 8 - CONFIRM synchroscope remains at "12 o'clock".

Confirms synch scope remains at 12 oJclock.

SAT/UNSAT

NRC SIM JPM S-6 Page 6 of 8 Step 9- PLACE synchroscope used in Step 8.6.2.3 in OFF.

PLACES synchroscope E3 BUS 20 TO BUS E3 (2AD1) in OFF.

SAT/UNSAT NOTE: Procedure Caution Prior to next step CAUTION To prevent a diesel generator from tripping on reverse power, do NOT reduce DG load below 450KW.

Step 10 - MAINTAIN generator vars with voltage adjusting rheostat while lowering diesel generator load.

Maintains vars with voltage by adjusting rheostat while lowering load SAT/UNSAT Step 11 - LOWER diesel generator load to between 450 and 550 KW by momentarily placing the GOVERNOR motor control switch in LOWER.

Lowers load to between 450 and 550 KW (not <450KW)

- CRITICAL STEP**

SAT/UNSAT EXAMINER NOTE: The critical aspect of step 11 is to not get a reverse power trip of the DG if load is <450KW

NRC 81M JPM S-6 Page 7 of 8 Step 12 - OPEN the appropriate diesel generator output breaker:

D/ESEL GEN 3 TO BUS E3 (AI5)

Opens output breaker DIESEL GEN 3 TO BUS E3 (A/5)

- CRITICAL STEP**

SAT/UNSAT Step 13 - OBSERVE the following indications:

a. Breaker open in accordance with indicating lights.

b. Emergency bus voltage remains constant.

c. Diesel generator load and amps are zero.

d. NO LOAD and AVAIL lights are illuminated on the diesel generator control module.

Obsetves indications noted above SAT/UNSAT TERMINATING CUE/PROMPT: The diesel generator will be shutdown by another operator. The JPM is complete.

COMMENTS:

NRC 81M JPM 8-6 Page 8 of 8 KIA REFERENCE AND IMPORTANCE RATING:

264000 A4.05 3.6/3.7 Ability to manually operate and/or monitor in the control room: Transfer of the EDG with load to grid

REFERENCES:

OOP-50.1, Revision 67 TOOLS AND EQUIPMENT:

None.

SAFETY FUNCTION (from NUREG 1123, Rev 2.):

6 - Electrical APPLICABLE METHOD OF TESTING Performance: Simulate Actual X Unit-.-l Setting: Control Room Simulator X In-Plant:

Time Critical: Yes No X Time Limit Alternate Path: Yes No X EVALUATION Performer:

JPM: Pass Fail _

TASK CONDITIONS:

1. Unit Two (2) is operating at 1000/0 power.

2. Emergency Bus E3 is being carried by the #3 EDG due to a relay trip of the E3 Bus feeder breaker.

3. The Unit 2 alignment (Isolations and Actuations) has been restored to normal configuration following the restoration of power to Bus E3 from OG-3.

4. Repairs have been completed to the E-3 feeder breaker relay.

5. Normal feeder bus for emergency bus is energized.

6. The Load Dispatcher has been notified that the 4160V E-3 Bus power supply is being shifted to the Normal Feeder.

INITIATING CUE:

You are directed by the Unit SeQ to manually transfer the 4160 Emergency Bus Supply for Emergency Bus E-3 from the DG to the Normal Feeder lAW OOP-50.1.

. ~

(~361 8.6 Control Room Manual Transfer of 4160V Emergency Bus Supply from C Continuous Diesel Generator to Normal Feeder Use 8.6.1 Initial Conditions NOTE: IF this procedure is being used to recover from a loss of grid event (such as IR3S1 OAOP-36.1 or OAOP-36.2), THEN the Shift Superintendent and Operations Manager should be included during consultation with the Load Dispatcher to obtain assurance that Off-site power is reliable enough to support reconnection of the Emergency Buses.

1. Diesel generator is supplying the associated emergency o bus.

2. Normal feeder bus for emergency bus is energized. o

3. Notify the Load Dispatcher that the 4160V E Bus power o supply is being shifted to the Normal Feeder.

8.6.2 Procedural Steps NOTE: WHEN transferring the diesel generator from Auto Mode to Control Room Manual, diesel generator frequency is expected to d-rop approximately 3 Hz at rated load. Since the range of frequency drop to diesel generator load is IR3S1 linear (e.g., transfer to Control Room Manual at half load results in a frequency drop of 1.5 Hz), adjustments to lower diesel generator load or raise diesel frequency can be made to compensate for frequency drop prior to the transfer. See Figure 1.

IR3S1 IOOP-50.1 Rev. 67 Page 112 of 1641

8.6.2 Procedural Steps IR3S1 1. PERFORM one or more of the following as necessary to prevent RPS EPA breaker trip.

(See Figure 1.)

- RAISE diesel generator frequency (limiter set at D 61 Hz)

- REDUCE diesel generator load D

2. PLACE the appropriate diesel generator control in D control room manual mode by depressing applicable push button on Panel XU-2.

3. PLACE appropriate synchroscope switch in ON for normal feed to emergency bus:

Emergency Bus Synchroscope

a. E1 BUS 10 TO BUS E1 (1A01). D

b. E2 BUS 1G TO BUS E2 (1AG8). D

c. E3 BUS 20 TO BUS E3 (2A01). D

d. E4 BUS 2G TO BUS E4 (2AGB). D

4. ENSURE incoming and running voltages are matched. D

5. ADJUST diesel generator GOVERNOR motor control D switch as necessary so the synchroscope is rotating slowly in the SLOW direction (counterclockwise).

IOOP-50.1 Rev. 67 Page 113 of 1641

8.6.2 Procedural Steps

6. WHEN synchroscope is at "12 o'clock", THEN PLACE D AND HOLD control switch for appropriate normal feed to emergency bus in CLOSE until both MSTR and SLA VE breakers indicate closed:

Breaker Feed Master Slave Breaker Breaker 8 .. BUS 10 TO BUS E1 1AD1 AE6. D b.. BUS 1C TO BUS E2 1AC8 AG4 . D

c. BUS 20 TO BUS E3 2AD1 A12. D

d. BUS 2C TO BUS E4 2AC8 AJ9. D

7. CONFIRM synchroscope remains at "12 o'clock". D

8. PLACE synchroscope used in Step 8.6.2.3 in OFF. D

9. MAINTAIN generator vars with voltage adjusting rheostat D while lowering diesel generator load.

10. LOWER diesel generator load to between 450 and D 550 KW by momentarily placing the GOVERNOR motor control switch in LOWER.

[ OOP-50.1 Rev. 67 Page 114 of 1641

I" r 8.6.2 Procedural Steps

11. OPEN the appropriate diesel generator output breaker: D Diesel Generator Breaker No.1 DIESEL GEN 1 TO BUS E1 (AE9) D No.2 DIESEL GEN 2 TO BUS E2 (AG?) D No.3 DIESEL GEN 3 TO BUS E3 (AI5) D No.4 DIESEL GEN 4 TO BUS E4 (AK2) D

12. OBSERVE the following indications: D

a. Breaker open in accordance with indicating lights. D

b. Emergency bus voltage remains constant. D

c. Diesel generator load and amps are zero. D

d. NO LOAD and A VAIL lights are illuminated on the D diesel generator control module.

13. SHUT DOWN the diesel in accordance with OOP-39. D NOTE: The emergency bus is now energized from normal feeder and the diesel generator is returned to standby automatic upon completion of shutdown section.

IOOP-50.1 Rev. 67 Page 115 of 1641

TASK CONDITIONS:

1. Unit Two (2) is operating at 100% power.

2. Emergency Bus E3 is being carried by the #3 EDG due to a relay trip of the E3 Bus feeder breaker.

3. The Unit 2 alignment (Isolations and Actuations) has been restored to normal configuration following the restoration of power to Bus E3 from OG-3.

4. Repairs have been completed to the E-3 feeder breaker relay.

5. Normal feeder bus for emergency bus is energized.

6. The Load Dispatcher has been notified that the 4160V E-3 Bus power supply is being shifted to the Normal Feeder.

INITIATING CUE:

You are directed by the Unit SeQ to manually transfer the 4160 Emergency Bus Supply for Emergency Bus E-3 from the OG to the Normal Feeder lAW OOP-50.1.

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