ML18057B518

V.C. Summer 05000395/2011301 Exam Final Items 2B

ML18057B518
Person / Time
Site:	Summer
Issue date:	07/30/2011
From:	NRC/RGN-II
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Download: ML18057B518 (372)

See also: IR 05000395/2011301

Text

2011 NRC Admin A1-a RO & SRO: OPERATIONAL LEAK RATE TEST (STP-114.002) W/O IPCS LEAK

RATE PROGRAM AVAILABLE

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-081AAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:5THIS JPM IS APPROVEDSaturday, September 03, 2011Page 1 of 10

TASK:002-001-02-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

20TIME CRITICAL

NoTASK STANDARD:Unidentified leak rate determined to be outside Technical Specification limits.PREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:41(b)10PERFORM REACTOR COOLANT SYSTEM WATER INVENTORY BALANCETOOLS:STP-114.002

CURVE BOOK Figure V-7

CURVE BOOK Figure VI-22

T.S. 3.4.6.2

CALCULATORREFERENCES:TERMINATING CUE:Unidentified leakage calculated.STP-114.002OPERATIONAL LEAK TESTINDEX NO.ROSROK/A NO.002000A401RCS leakage calculation program using the computer3.53.8A4.01002000K405Detection of RCS leakage3.84.2K4.05002000A301Reactor coolant leak detection system3.73.9A3.01Saturday, September 03, 2011Page 2 of 10

INITIATING CUES:Perform the manual leak rate calculation, using STP-114.002.INITIAL DATA, TIME START 0345:T0499A, RCL MEDIAN TAVG = 587.4°FL0480A, PRESSURIZER LEVEL-LT459 = 60.6%

L0112A, VOLUME CONTROL TANK LEVEL-LT-115 = 57.1%

L0485A, PRESSURIZER RELIEF TANK L-LT470 = 75.0%L1028, REACTOR COOL DR TNK LEV = 60.0%FINAL DATA, TIME STOP 0445:T0499A, RCL MEDIAN TAVG = 587.1°FL0480A, PRESSURIZER LEVEL-LT459 = 59.4%L0112A, VOLUME CONTROL TANK LEVEL-LT-115 = 53.5%

L0485A, PRESSURIZER RELIEF TANK L-LT470 = 75.0%L1028, REACTOR COOL DR TNK LEV = 61.0%Current Primary-to-Secondary Leakage = 0.0 gpmStart with step 6.4.b. Another operator will complete 6.4.cINITIAL CONDITION:The plant is operating at 100%. STP-114.002, OPERATIONAL LEAKAGE CALCULATION, is due. The IPCS Leak Rate Program is unavailable; but the IPCS is available for data calculation.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORSaturday, September 03, 2011Page 3 of 10

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Saturday, September 03, 2011Page 4 of 10

INITIATING CUES:Perform the manual leak rate calculation, using STP-114.002.INITIAL DATA, TIME START 0345:T0499A, RCL MEDIAN TAVG = 587.4°FL0480A, PRESSURIZER LEVEL-LT459 = 60.6%L0112A, VOLUME CONTROL TANK LEVEL-LT-115 = 57.1%

L0485A, PRESSURIZER RELIEF TANK L-LT470 = 75.0%L1028, REACTOR COOL DR TNK LEV = 60.0%FINAL DATA, TIME STOP 0445:T0499A, RCL MEDIAN TAVG = 587.1°FL0480A, PRESSURIZER LEVEL-LT459 = 59.4%L0112A, VOLUME CONTROL TANK LEVEL-LT-115 = 53.5%

L0485A, PRESSURIZER RELIEF TANK L-LT470 = 75.0%

L1028, REACTOR COOL DR TNK LEV = 61.0%Current Primary-to-Secondary Leakage = 0.0 gpm

Start with step 6.4.b. Another operator will complete 6.4.cINITIAL CONDITION:The plant is operating at 100%. STP-114.002, OPERATIONAL LEAKAGE CALCULATION, is due. The IPCS Leak Rate Program is unavailable; but the IPCS is available for data calculation.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TSaturday, September 03, 2011

Saturday, September 03, 2011Page 6 of 10

STEPSInputs data into TEST DATA SHEETYesStudent inputs data, initial and finalCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Calculates change in test dataYesStudent subtracts initial data from final t

odetermine change in Tavg, Pressurizer level, VCT level, PRT level and RCDT

levelCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Inputs factor for leakage parametersYesStudent inputs data from References identified at the bottom of leakrate form.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Saturday, September 03, 2011Page 7 of 10

Calculates TOTAL LEAKAGEYesStudent calculates Total leakage per STP-114.002 between 1.5514 and

1.5664 gpm. Tolerance given for reading Figure V-7: 1/2 the smallest increment, which is 5 DEGF. Since

TAVG~587F, tolerance allowed for reading 585-590 DEGF, which yields a range of 81.5-84 gallons/1 DEGF

change. This, in turn, yields the range o

fcalculated TOTAL Leakage of 1.5514 and 1.5664 gpm.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Calculates IDENTIFIED LEAKAGEYesStudent calculates IDENTIFIED LEAKAGE per STP-114.002 between 0 and 0.15 gpm.. Tolerance given to allo

wusing a range of 0 to 9 for using FIGURE VI-22. Considering the

tolerance given for calculating TOTAL Leakage, this tolerance will have no bearing on the final calculated value for

UNIDENTIFIED Leakage.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Saturday, September 03, 2011Page 8 of 10

Examiner ends JPM at this point.Calculates UNIDENTIFIED LEAKAGEYesStudent calculates UNIDENTIFIED LEAKAGE per STP-114.002 between

1.4014 and 1.5664 gpm. Tolerance allowed as described in the Step for calculating TOTAL Leakage.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Student identifies Tech Spec LCO not satisfied.

May prompt operator to report findin

gs.YesStudent reports to CRS that UNIDENTIFIED LEAKAGE is in excess

of T.S. 3.4.6.2.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Saturday, September 03, 2011Page 9 of 10

JPM NO:JPA-081ADESCRIPTION:2011 NRC Admin A1-a RO & SRO: OPERATIONAL LEAK RATE TEST (STP-114.002) W/O IPCS LEAK RATE PROGRAM AVAILABLEIC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETSaturday, September 03, 2011Page 10 of 10

2011 NRC Admin A1-b RO: CALCULATE REACTIVITY CONTROL PARAMETERS (Base on new core at MOL)

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-006BAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:5THIS JPM IS APPROVEDWednesday, September 07, 2011Page 1 of 11

TASK:004-006-01-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

15TIME CRITICAL

NOTASK STANDARD:OAP-100.6, Attachment IA, Reactivity Control Parameters, completed.PREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)12PERFORM BORON CHANGE CALCULATIONSTOOLS:OAP-100.6 ATTACHMENT IA

CALCULATOR

VC SUMMER CURVE BOOK (sections)OAP-100.6, Attachment IA Answer Key (Examiner Copy)REFERENCES:TERMINATING CUE:Examinee provides OAP-100.06, Attachment 1A to the Examiner.SAP-155REACTIVITY MANAGEMENTOAP-100.6CONTROL ROOM CONDUCT AND CONTROL OF ACTIVITIESINDEX NO.ROSROK/A NO.1940012118Ability to make accurate, clear and concise logs, records, status boards,

and reports.3.63.82.1.18Wednesday, September 07, 2011Page 2 of 11

INITIATING CUES:The CRS directs the NROATC to complete OAP-100.6, Attachment IA, Reactivity Control Parameters.PARAMETER DATA:RCS Boron Concentration = 1050 ppmBURNUP = 10,000 MWD/MTU

BAT in Service = BAT "A"BAT "A" Boron Concentration = 7000 ppmBAT "B" Boron Concentration = 7581 ppmINITIAL CONDITION:The plant is operating at 100%, steady-state power. It is Sunday day

shift.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Wednesday, September 07, 2011Page 3 of 11

INITIATING CUES:The CRS directs the NROATC to complete OAP-100.6, Attachment IA, Reactivity Control Parameters.PARAMETER DATA:RCS Boron Concentration = 1050 ppmBURNUP = 10,000 MWD/MTU

BAT in Service = BAT "A"BAT "A" Boron Concentration = 7000 ppmBAT "B" Boron Concentration = 7581 ppmINITIAL CONDITION:The plant is operating at 100%, steady-state power. It is Sunday day

shift.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TWednesday, September 07, 2011

STEPSRCS Boron Concentration _______ ppmNOTE: Provide Examinee with blank copy of OAP-100.6, Attachment 1A, Reactivity Control Parameter Data Sheet and Station Curve Book. NOTE: Value obtained from Initiatin

g Cues.YesEnters 1050 ppm.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Burnup _________ MWD/MTUNOTE: Value obtained from Initiatin

g Cues.YesEnters 10,000 MWD/MTU.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2(Check BAT in Service)NOTE: Value obtained from Initiatin

g Cues.YesChecks BAT "A" inservice.Enters BAT "A" Boron Concentration =

7000 ppm.Enters BAT "B" Boron Concentration =

7581 ppm.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Wednesday, September 07, 2011Page 5 of 11

Moderator Temperature Coefficient (MTC) (Fig. II-3.7, HFP) ______ pcm/ppmNOTE: Value obtained from Table on Fi

g. II-3.7 for 10,000 MWD/MTU.YesEnters (-)16.6 - (-)17.6.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Differential Boron Worth (DBW) (Fig. II-7.2, HFP) _______ pcm/ppmNOTE: Value obtained from Table on Fi

g. II-7.2 for 1050 ppm.YesEnters - 6.83 to -6.96 pcm/ppm. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Gallons of Boric Acid or Reactor Makeup Water required to change RCS average temperature by one (1) degree:MTC/DBW = _____/______ = ________ ppm Boron Change/°FYesEnters 2.385 to 2.577 for ppm Boron Change/°F. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Wednesday, September 07, 2011Page 6 of 11

(Fig. III-2) ______ gal. Acid/°FYesEnters 19.79-21.65 for gal. Acid/°F. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7(Fig. III-3) _________ gal. RMW/°FYesEnters 108.04-128.59 for gal. RMW/°F. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:8Power Defect (PD) for 10% power change (100% to 90%) (Fig. II-2).

_____ PD @ 100% RTP - _____ PD @ 90% = _____ Power Defect, ppmNOTE: Values from Fi

g. II-2: 1717 PD

@ 100% RTP - 1549 PD

@ 90% RTP = 168YesEnters 168 Power Defect, ppm.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:9Wednesday, September 07, 2011Page 7 of 11

Gallons of Boric Acid only to reduce reactor power from 100% to 90%: Power Defect/DBW = _____ / _____ = _______ ppm BoronYesEnters 24.1 to 24.6 ppm Boron. (see ke

yfor derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:10(Figure III-2) ________ gal. Boric Acid/10%

RTPYesEnters 200.27-207.64 for gal. Boric Acid/10% RTP. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:11Final rod height using rods only to reduce reactor power from 100% to 90%: Power Defect = Integrated Rod Worth (IRW) = _____ pcmNOTE: Examinee determines value is taken from Step 9.YesEnters 168 pcm.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:12Wednesday, September 07, 2011Page 8 of 11

(Fig. II-10) ___________ final rod height

Bank DYesEnters 178 to 185 final rod height Bank D. (see key for derivation)CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:13For a 100% to 90% load reduction:Use ______ gallons boric acid (1/2 the gallons calculated above), and expect the rods to be at approximately ______ steps on

bank D (Fig. II.10 series, 1/2 the IRW, NOT

1/2 the steps).YesEnters 100 - 104 for gallons boric acid and 193 - 200 for steps on bank D.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:14Copies data from page 1 to page 2.YesRight values are transposed from page 1and placed on page 2.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:15Wednesday, September 07, 2011Page 9 of 11

Examiner ends JPM at this point.FCV 113 A&B, pot setting for current RCS boron concentration.

NoEnters 4.50.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:16Expected Boric Acid flowrate for VCT makeup _____YesEnters 18.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:17Expected Boric Acid total gallons on an Auto Makeup based on current BAT in service:

_______YesEnters 40-41.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:18Wednesday, September 07, 2011Page 10 of 11

JPM NO:JPA-006BDESCRIPTION:2011 NRC Admin A1-b RO: CALCULATE REACTIVITY CONTROL PARAMETERS (Base on new core at MOL)IC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETWednesday, September 07, 2011Page 11 of 11

2011 NRC Admin A1-b SRO: DETERMINE SHIFT MANNING REQUIREMENTS

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-009APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:5THIS JPM IS APPROVEDSRO ONLYWednesday, September 07, 2011Page 1 of 7

TASK:341-050-01-03PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

15TIME CRITICAL

NOTASK STANDARD:Determines personnel to hold over that will meet the full crew complement and completes FEP MANNING SHEET.PREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:41b10SS RELIEF CHECKLIST REVIEW (SAP-200)TOOLS:OAP-100.2, Operating Personnel Expectations and ResponsibilitiesSAP-152, Fatigue Management and Work Hour LimitsSAP-200, Conduct of OperationsREFERENCES:TERMINATING CUE:Completes FEP MANNING SHEET.SAP-152FATIGUE MANAGEMENT AND WORK HOUR LIMIOAP-100.2OPERATIONS PERSONNEL EXPECTATIONS AN

DRESPONSIBILITIESSAP-200CONDUCT OF OPERATIONSINDEX NO.ROSROK/A NO.1940012103Knowledge of shift or short-term relief

turnover practices.3.73.92.1.3Wednesday, September 07, 2011Page 2 of 7

INITIATING CUES:As the oncoming Shift Supervisor review the shift manning for the next four hours. Determine what actions, if any, must be taken to meet the normal full crew complement and complete OAP-100.6, Attachment VIIA, FEP MANNING SHEET.No extensions/deviations are to be granted. Operations management is coming in within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to assist with a long term manning plan.INITIAL CONDITION:Plant is at 100% power. Shift turnover is being conducted to start Thursday 08/25 Night Shift and the STS requests assistance

determining what to do because B. Earle, K. Raymond, and M. O'Connell have been admitted to the hospital and will not be able to work the upcoming shift. No extra personnel are available on either shift. The entire Admin shift is on a benchmarking trip at Diablo Canyon.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Wednesday, September 07, 2011Page 3 of 7

Wednesday, September 07, 2011Page 4 of 7

INITIATING CUES:As the oncoming Shift Supervisor review the shift manning for the next four hours. Determine what actions, if any, must be taken to meet the normal full crew complement and complete OAP-100.6, Attachment VIIA, FEP MANNING SHEET.No extensions/deviations are to be granted. Operations management is coming in within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to assist with a long term manning plan.INITIAL CONDITION:Plant is at 100% power. Shift turnover is being conducted to start Thursday 08/25 Night Shift and the STS requests assistance

determining what to do because B. Earle, K. Raymond, and M. O'Connell have been admitted to the hospital and will not be able to work the upcoming shift. No extra personnel are available on either shift. The entire Admin shift is on a benchmarking trip at Diablo Canyon.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TWednesday, September 07, 2011

STEPSExaminer ends JPM at this point.Review the shift manning to determine actions for normal full complement and completes FEP MANNING SHEET.If asked to call in another building operator ask what their qualifications must be and then respond that no operators are available for call in within the next 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.YesDetermine that an ABUL, ABLL, and CBAO is needed. For the first 4 hrs, the

following is required. C. Haley must be

kept to be the control building operator. D. Stewart must be kept to be the ABLL. Either S. Williams or E. Cary ma

ybe held over to be ABUL.See key for how FEP MANNING SHEE

Tmust be completed.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1Wednesday, September 07, 2011Page 6 of 7

JPM NO:JPA-009DESCRIPTION:2011 NRC Admin A1-b SRO: DETERMINE SHIFT MANNING REQUIREMENTSIC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETWednesday, September 07, 2011Page 7 of 7

2011 NRC A2 RO: TAGOUT "B" MDEFP

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-025APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:3THIS JPM IS APPROVEDWednesday, September 07, 2011Page 1 of 8

TASK:119-012-03-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

45TIME CRITICAL

NOTASK STANDARD:'B' MDEFP is tagged out in accordance with SAP-201, EQUIPMENT TAGGING AND LOCKOUT-TAGOUT. The suction and discharge valves are tagged closed, pump casing drains and vents

are tagged open, the motor is tagged out, and the correct sequence is identified for tagging.One of the following two (2) valves should be tagged open to provide a vent path for draining (either one or both are acceptable).1. XVT11006, MTR DR EF PUMP B SUCT HDR TEST ISOL VLV2. XVT11007, MOTOR DRIVEN EF PUMP B VENT VALVEPREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45.13CONDUCT EQUIPMENT TAGOUTS (EQUIPMENT CLEARANCE AND SWITCHING)TOOLS:SAP-201 and OAP-100.5 (or computer access)

SAP-201, ATTACHMENT VIC (4 copies)SAP-201, ATTACHMENT VIA (partially completed)D-302-085, EMERGENCY FEEDWATER

ELECTRICAL FEEDER LIST FOR XSW1DB AND XMC1DB2X

SOP-211, ATTACHMENTS I - IV (or computer access)Highlighters for each student (pink, blue, yellow, green).REFERENCES:TERMINATING CUE:SAP-201DANGER TAGGINGINDEX NO.ROSROK/A NO.1940012213Knowledge of tagging and clearance procedures.4.14.32.2.13Wednesday, September 07, 2011Page 2 of 8

INITIATING CUES:The SS, Todd Price, directs you to prepare a tagout for the 'B' MDEFW pump. Complete SAP-201, Attachment VIC. Only tagged positions and sequence are required at this time. You do not have to fill out restoration positions, individual danger tags or Locked Valve Tracking

sheets.INITIAL CONDITION:The plant is in MODE 1. Mechanical maintenance has requested a

tagout to replace pump seals on 'B' MDEFW pump. This is emergent

work, and no isolation points have been recommended at this time.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Wednesday, September 07, 2011Page 3 of 8

INITIATING CUES:The SS, Todd Price, directs you to prepare a tagout for the 'B' MDEFW pump. Complete SAP-201, Attachment VIC. Only tagged positions

and sequence are required at this time. You do not have to fill out

restoration positions, individual danger tags or Locked Valve Tracking

sheets.INITIAL CONDITION:The plant is in MODE 1. Mechanical maintenance has requested a

tagout to replace pump seals on 'B' MDEFW pump. This is emergent

work, and no isolation points have been recommended at this time.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TWednesday, September 07, 2011

STEPSTAG - Enter the sequential tag number.

Tag number is not critical, onl

y the sequence is.

NoSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1ISSUED TO - Check blocks for which discipline each component is tagged.

NoSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2HOLD TAG INST - Enter a check mark if a Hold Tag is to be placed on a control panel component.

NoSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Wednesday, September 07, 2011Page 5 of 8

COMPONENT I.D. - Enter the complete CHAMPS identification number of the component being tagged.

NoSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4PLANT LOC - Enter the specific plant location of the component being tagged.YesSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5REQ'D TAG POSIT - Enter the position in which the component is to be tagged.YesSee completed Attachment VIC.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Wednesday, September 07, 2011Page 6 of 8

Examiner ends JPM at this point.INST SEQ - Enter sequence that tags are to be installed.YesSee completed Attachment VIC. Components must be sequenced as

notated on attachment or in an equivalent sequence. Components of a smaller sequence number on the key

must be listed before components of a larger sequence number.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Wednesday, September 07, 2011Page 7 of 8

JPM NO:JPA-025DESCRIPTION:2011 NRC A2 RO: TAGOUT "B" MDEFPIC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETWednesday, September 07, 2011Page 8 of 8

2011 NRC Admin A2 SRO: REVIEW TAGOUT FOR "B" MDEFP

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-025AAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:5THIS JPM IS APPROVED

Thursday, September 08, 2011Page 1 of 10

TASK:342-005-03-02PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

30TIME CRITICAL

NOTASK STANDARD:'B' MDEFP is tagged out in accordance with SAP-201, EQUIPMENT TAGGING AND LOCKOUT-TAGOUT. The suction and discharge valves are tagged closed, pump casing drains and vents are tagged open, the motor is tagged out, and the correct sequence is identified for tagging. Identifies that tagout cannot be authorized as written.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45.13AUTHORIZE HANGING OF TAGS ON PLANT EQUIPMENTTOOLS:SAP-201, OAP-100.5, OAP-102.1 (or computer access)SAP-201, ATTACHMENT VIC (Completed with errors)

OAP-102.1 ATTACHMENT I EQUIPMENT LINEUP REQUEST (Completed)OAP-102.1, ATTACHMENT VI SCHEDULING TAGOUT PACKAGE CHECKLIST (with signature stamp, first SRO review initialed)D-302-085, EMERGENCY FEEDWATER (NUCLEAR), (Boundaries indicated with error)

ELECTRICAL FEEDER LIST FOR 1DB AND 1DB2X

SOP-211, ATTACHMENTS I - IVREFERENCES:TERMINATING CUE:SAP-201DANGER TAGGINGINDEX NO.ROSROK/A NO.1940012213Knowledge of tagging and clearance procedures.4.14.32.2.13Thursday, September 08, 2011Page 2 of 10

INITIATING CUES:As an SRO, you are to review the work package prior to allowing the tagout to be hung and the work to begin. Positions for restoration are not required at this time. Limit your review to the Tagout Preparation Section of OAP-102.1, Attachment VI, SCHEDULING TAGOUT

PACKAGE CHECKLIST. Write down all discrepancies noted, if any,

and determine if tagout may be authorized as written.INITIAL CONDITION:The plant is in Mode 1. B1 Maintenance Work Week. Emergent work for pump seal replacement on 'B' Motor-Driven EFW Pump is to be

performed. A work package has been completed. LOTO is

unavailable.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Thursday, September 08, 2011Page 3 of 10

INITIATING CUES:As an SRO, you are to review the work package prior to allowing the tagout to be hung and the work to begin. Positions for restoration are

not required at this time. Limit your review to the Tagout Preparation Section of OAP-102.1, Attachment VI, SCHEDULING TAGOUT PACKAGE CHECKLIST. Write down all discrepancies noted, if any,

and determine if tagout may be authorized as written.INITIAL CONDITION:The plant is in Mode 1. B1 Maintenance Work Week. Emergent work for pump seal replacement on 'B' Motor-Driven EFW Pump is to be performed. A work package has been completed. LOTO is

unavailable.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TThursday, September 08, 2011

STEPSChecks correct train work week.If required during this JPM, remind examinee to limit review to the preparation section of OAP-102.1, Attachment VI.YesNotes that B1 train work week is indicated.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Scope of all work requiring tags within the tagout boundary.YesMust note the following errors in the specified isolation during this review:- XVT01028B missing from boundary- XVG1001A incorrectly specified, should be XVG1001BMay note the following errors in the specified isolation during this review (NOT critical):- XVT11006 vent valve position specifie

das CLOSED incorrectlyCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:2Thursday, September 08, 2011Page 5 of 10

All power sources are tagged as required per job scopeYesMust note the following error:- XMC1DB2X 03 AD (isolation of power to XVG1001B MOV) is missing.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Install sequence logicalYesNotes that install sequence meets requirements.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Are hold tags needed and identified for switches, MCB gages, or status lights?YesNotes pump breaker indicates HOLD ta

grequired.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Restoration position in a Clear Tag Enclosure has been verified per SOP.YesNot requiredCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Thursday, September 08, 2011Page 6 of 10

Component worked has a "NO TAG" assigned to it and sequence in the Clear Tag Enclosure.If required, remind examinee that this is not required for this review.YesNot requiredCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:7Conflict check performed and warning flags are evaluated and understood?Remind student that since the package has to be done manually the conflict check provided by the computer s

ystem is not available.

NoN/ACUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Electrical Feeder list review and included, if necessary.YesDetermines that electrical feeder list is included in package.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Thursday, September 08, 2011Page 7 of 10

System/ Electrical drawing utilized are marked up with tagout boundaries and tagout index#YesNotes that drawing is correctly marked.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:10Vent and Drain information Sheet included if necessary?YesNotes Vent and Drain Information sheet included.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:11Thursday, September 08, 2011Page 8 of 10

Examiner ends JPM at this point.All errors foundYesMust note the following errors in the specified isolation during this review:- XMC1DB2X 03 AD (isolation of power to XVG1001B MOV) is missing.

- XVT01028B missing- XVG1001A incorrectly specified, should be XVG1001BMay note the following errors in the specified isolation during this review:(NOT critical):- XVT11006 vent valve position CLOSED incorrectlyDetermines that tagout cannot be authorized as written.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:12Work Document numbers on WPO?YesDetermines that WPO is not required with only one work request for the tagou

tCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:13Thursday, September 08, 2011Page 9 of 10

JPM NO:JPA-025ADESCRIPTION:2011 NRC Admin A2 SRO: REVIEW TAGOUT FOR "B" MDEFPIC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEET

Thursday, September 08, 2011Page 10 of 10

2011 NRC Admin A3 RO & SRO: APPLY FACILITY ALARA PRINCIPLES TO A SPECIFIC TASK AND DETERMINE OVERALL DOSE

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-083A(R

1)APPROVAL:

RJAPPROVAL DATE:8/11/2011REV NO:2THIS JPM IS APPROVEDWednesday, August 24, 2011Page 1 of 7

TASK:000-061-05-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

15TIME CRITICAL

NOTASK STANDARD:All critical tasks evaluated as SAT.PREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45.B.10RESPOND TO AREA RADIATION MONITORING SYSTEM ALARMSTOOLS:HPP-0153, HPP-0155CalculatorREFERENCES:TERMINATING CUE:All options have been prioritized and provided to the Examiner.INDEX NO.ROSROK/A NO.1940012312Knowledge of radiological safety principles pertaining to licensed operator duties, such as containment entry

requirements, fuel handling responsibilities, access to locked high-radiation areas, aligning filters, etc.3.23.72.3.12Wednesday, August 24, 2011Page 2 of 7

INITIATING CUES:You have been assigned to calculate the expected dose for the two options and prioritize them according to the VC Summer ALARA

philosophy. For the purposes of the JPM, assume that no dose is

received in transit.INITIAL CONDITION:A hydrogen explosion in the waste gas system has resulted in a

radioactive leak of a gas decay tank. The operating crew is performing the actions of ARP-019 XCP-644 Point 2-1, GAS DECAY TK AREA RM-G10 HI RAD. Several manual valves must be manipulated to isolate the leak. The general area radiation level where the work will

be performed is 1000 mR/hour. Airborne iodine activity is estimated at 30 DAC (assumed to be I-131 only)There are two options for performing the work:

- One person without a respirator = 30 minutes or

- One person with a respirator will take 10% longer (33 min).READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Wednesday, August 24, 2011Page 3 of 7

INITIATING CUES:You have been assigned to calculate the expected dose for the two options and prioritize them according to the VC Summer ALARA

philosophy. For the purposes of the JPM, assume that no dose is

received in transit.INITIAL CONDITION:A hydrogen explosion in the waste gas system has resulted in a

radioactive leak of a gas decay tank. The operating crew is performing the actions of ARP-019 XCP-644 Point 2-1, GAS DECAY TK AREA RM-G10 HI RAD. Several manual valves must be manipulated to isolate the leak. The general area radiation level where the work will

be performed is 1000 mR/hour. Airborne iodine activity is estimated at 30 DAC (assumed to be I-131 only)There are two options for performing the work:

- One person without a respirator = 30 minutes or

- One person with a respirator will take 10% longer (33 min).SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TWednesday, August 24, 2011

STEPSCalculate dose for each option.YesReviews conditions.May refer to facility/corporate procedures for respirator factors and

DAC conversion.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Calculate dose for each option.- One person without respirator.Acceptable ran

ge is 537 to 538 mR.Yes(1000 mr/hr) (1 hr/60 minutes) (30 minutes) + (30 DAC) (30 minutes) (1 hr/60 minutes) (2.5 mr/DAC-hr) = 537.5

mR.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:2Calculate dose for each option.- One person with a respirator.The candidate may not use the protection factor because the difference is negligable. Acceptable range is 550 - 551 mR.Yes(1000 mr/hr) (1 hr/60 minutes) (30 minutes) (1.1)+ (30 DAC) (30 minutes) (1 hr/60 minutes) (2.5 mr/DAC-hr) (1.1) /

(1000 protection factor)= 550.04125 m

RCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Wednesday, August 24, 2011Page 5 of 7

Examiner ends JPM at this point.Prioritize options IAW the lowest total dose.Yes1. One person without respirator.2. One person with a repirator.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Wednesday, August 24, 2011Page 6 of 7

JPM NO:JPA-083A(R 1)DESCRIPTION:2011 NRC Admin A3 RO & SRO: APPLY FACILITY ALARA PRINCIPLES TO A SPECIFIC TASK AND DETERMINE OVERALL DOSEIC SET:N/AINSTRUCTIONS:COMMENTS:

JPM SETUP SHEETWednesday, August 24, 2011Page 7 of 7

2011 NRC Admin A4 SRO: CLASSIFY EMERGENCY PLAN EVENT

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPA-020APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:7THIS JPM IS APPROVEDSRO ONLYTIME CRITICAL JPM

Thursday, September 08, 2011Page 1 of 11

TASK:344-019-03-02PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

30TIME CRITICAL

YESTASK STANDARD:Event properly classified as a SITE AREA EMERGENCY due to FS 1.1 Loss or potential loss of any two barriers (Table F-1). This is a time critical JPM and the declaration must be made within 15 minutes after the emergency condition exists and the NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM (ENF) form must be completed within 15 minutes of the

declaration.PREFERRED EVALUATION LOCATIONCLASSROOMTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)11CLASSIFY EMERGENCY EVENTS REQUIRING EMERGENCY PLAN IMPLEMENTATIONTOOLS:EPP-001- Attachment I.

EPP-001 Full.

EPP-002 FullAccess to a computer for other potential references. Technical Specifications, EPP-108 act.REFERENCES:TERMINATING CUE:Classification has been made and NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM (ENF) form has been completed.EPP-001ACTIVATION AND IMPLEMENTATION OF THE E

MINDEX NO.ROSROK/A NO.1940012106Ability to manage the control room crew during plant transients.3.84.82.1.6Thursday, September 08, 2011Page 2 of 11

INITIAL CONDITION:THIS IS A DRILL.The plant was initially at 100% power, when a plant S/D was commenced per AOP-112.2, STEAM GENERATOR TUBE LEAK NOT

REQUIRING SI, for a significant S/G Tube Leak. The reactor trip breakers were opened 10 minutes ago.The 'A' steam generator has been isolated in accordance with AOP-112.2 and the crew is performing step 22 to determine the target temperature for cooldown.Chemistry was directed to sample the RCS and S/Gs for activity. Results are as follows:

RCS - 417 Ci/gm DE I-131 S/G 'A': Tube leak indicated.S/G 'B': No indication of tube leak.S/G 'C': No indication of tube leak.Current steam generator pressures:S/G 'A': 850 psig and lowering.S/G 'B': 1090 psig and stable.

S/G 'C': 1090 psig and stable.Current steamline power relief indicators:PCV-2000, A SD/PWR RELIEF, green light lit red light dim.

PCV-2010, B SD/PWR RELIEF, green light lit red light dim.PCV-2020, C SD/PWR RELIEF, green light lit red light dim.A security officer reports that steam is issuing from the Auxiliary Building (AB) roof.RB pressure is 0.5 psig and stable.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATOR

Thursday, September 08, 2011Page 3 of 11

INITIATING CUES:1. Classify the plant event and write down your declaration on this sheet. Notify an examiner when this is done. You will be provided a package from the examiner at that time.2. Complete a NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM (ENF) for the plant event.RCS conditions are stable and net charging indicates 70 gpm.Meteorological data is not available.THIS IS A DRILL.THIS IS A TIME CRITICAL JPM!HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Thursday, September 08, 2011Page 4 of 11

Thursday, September 08, 2011Page 5 of 11

INITIAL CONDITION:THIS IS A DRILL.The plant was initially at 100% power, when a plant S/D was commenced per AOP-112.2, STEAM GENERATOR TUBE LEAK NOT

REQUIRING SI, for a significant S/G Tube Leak. The reactor trip breakers were opened 10 minutes ago.The 'A' steam generator has been isolated in accordance with AOP-112.2 and the crew is performing step 22 to determine the target temperature for cooldown.Chemistry was directed to sample the RCS and S/Gs for activity. Results are as follows:

RCS - 417 Ci/gm DE I-131 S/G 'A': Tube leak indicated.S/G 'B': No indication of tube leak.S/G 'C': No indication of tube leak.Current steam generator pressures:S/G 'A': 850 psig and lowering.S/G 'B': 1090 psig and stable.

S/G 'C': 1090 psig and stable.Current steamline power relief indicators:PCV-2000, A SD/PWR RELIEF, green light lit red light dim.

PCV-2010, B SD/PWR RELIEF, green light lit red light dim.PCV-2020, C SD/PWR RELIEF, green light lit red light dim.A security officer reports that steam is issuing from the Auxiliary Building (AB) roof.RB pressure is 0.5 psig and stable.RCS conditions are stable and net charging indicates 70 gpm.Meteorological data is not available.

THIS IS A DRILL.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:

JPM BRIEFING SHEE

TThursday, September 08, 2011

INITIATING CUES:1. Classify the plant event and write down your declaration on this sheet. Notify an examiner when this is done. You will be provided a package from the examiner at that time.2. Complete a NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM (ENF) for the plant event.HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Thursday, September 08, 2011

STEPSEvaluate plant conditions and classify event per EPP-001.If student does not explain basis for the classification, the evaluator must ask him to describe the basis. If the basis is not justified, this constitutes failure, even if the classification is correct.When student has classified the event, then provide the student with handout materials (Full EPP-001 and EPP-002

).YesClassifies event, per EPP-001 as a SITEAREA EMERGENCY due to FS 1.1: Loss or potential loss of any two barriers

(Table F-1)

Detection Method:E.4- Loss of Fuel Clad Barrier based on Dose equivalent I-131 coolant activity

>300 microCi/gm.No loss of Reactor Coolant System Barrier since using AOP-112.2 to

combat accident (still on normal

charging and SI not required.D.4 Loss of Containment Barrier based on Primary-to-secondary leakrate>10

gpm AND Unisolable steam release

from affected SG to the environment.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1Completes line 1 of NUCLEAR POWER PLANT EMERGENCY NOTIFICATION

FORM (ENF).YesChecks "Drill" and writes message number as "1".CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Thursday, September 08, 2011Page 8 of 11

Completes line 2 of ENF.YesChecks "Initial".CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Completes line 4 of ENF.YesChecks "Site Area Emergency" writes in "FS 1.1" and "Loss or potential loss of any two barriers" or the equivalent.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Completes line 5 of ENF.YesChecks "Is Occurring"CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Completes line 7.This step is not critical.YesChecks "Above normal operating limits"CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Thursday, September 08, 2011Page 9 of 11

Completes line 8.This step is not critical.YesChecks "Stable"CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:7Completes line 10YesChecks "Declaration" and includes

declaration time.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:8Completes line 12.YesWrites % Power as 0 and indicates time of trip (10 minutes prior to start of JPM).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:9Thursday, September 08, 2011Page 10 of 11

Examiner ends JPM at this point.Completes line 13.This step is not critical.YesWrites summary of occurrence at the plant. To include failed fuel, a steam

generator tube leak, and an uncontrolledrelease of steam from the steam generator with a tube leak.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:10Thursday, September 08, 2011Page 11 of 11

JPM NO:JPA-020DESCRIPTION:2011 NRC Admin A4 SRO: CLASSIFY EMERGENCY PLAN EVENTIC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEET

Thursday, September 08, 2011Page 12 of 11

Appendix D 1 NUREG 1021 Revision 9 Facility: VC SUMMER Scenario No.:1 Op Test No.:

2011 NRC Examiners: Operators: CRS RO BOP

Initial Conditions: IC-10, 100% Power, MOL (IC-301 or 305 for 2011) "B" EDG is OOS to clean the lube oil strainer "B" RB spray pump is out of service for bearing replacement National Weather Service has issued a severe weather alert due to a line of heavy thunderstorms moving into the area Turnover: Maintain current conditions

Critical Task: Transfer rods to MANUAL before going below Rod Insertion Limit Establish feed to Steam Generators or initiate feed and bleed prior to SG dryout as indicated by a loss of subcooling (alarm at 0°F)

Event No. Malf. No. Event Type* Event Description

1. NIS007G

I-RO, N-BOP TS- CRS Power Range upper detector NI-44A fails high RO1, BOP1 2. FWM009A

C- BOP, CRS HP heater tube leak BOP2 3. N/A R-RO Reduce power to isolate HP FW heater string

4. EPS018A&B

and EPS-006A IND ES071 &

073=>0 C - RO,BOP TS-CRS 115KV offsite power is lost, the "A" EDG rolls but trips: 1DA is deenergized. RO Must start "B" train CCW pump and charging pump. BOP will start restoration of 1DA. RO2 5. N/A N-RO, CRS Restore letdown 6. PCS013B M-ALL Inadvertent FW Isolation Signal, Train B

7. FWM003B

C- BOP, CRS "B" MDEFW pump fails to start 8. VLV-MS001F

C- BOP, CRS FCV-2030 fails as is; TDEFW Pump fails to start, no EFW

available Terminate when Main Feedwater is restored OR Feed and Bleed has been initiated * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D 2 NUREG 1021 Revision 9

VC Summer NRC Scenario #1 Summary

The crew will assume the watch having pre-briefed on the Initial Conditions (stable full power, middle of life, A1 Maintenance week). The plan for this shift is to maintain present conditions and continue work on the "B" EDG and "B" RB Spray Pump.

Power Range N44 upper detector A fails high as indicated by channel and delta I deviations. Power mismatch

will result in inward rod motion. The RO will place control rods in MANUAL to avoid exceeding the Rod Insertion Limit and the CRS will enter AOP-401.10 POWER RANGE CHANNEL FAILURE to bypass the failed channel and identify Tech Spec Table 3.3-1 items 2,3,19 which requires actions 2 and 7 required monitoring of

Quadrant Power Tilt Ratio. The BOP will take the channel out of service at the NIS panels.

When control room actions for the failed NI are complete, the Lead Evaluator can cue a tube leak in HP Feedwater Heater 1A. The leak is large enough to cause automatic shell-side isolation of the "A" string of HP feedwater heaters by the DCS. The crew will enter AOP-204.1, LOSS OF HIGH PRESSURE FEEDWATER HEATERS, and reduce power to 925MWe (approx. 92% RTP) at 3% per minute. The BOP will start the

standby condensate pump to compensate for the FW heater dumping to the condenser (Deaerator Storage

Tank level will drop, which would eventually lead to loss of all Feedwater pumps.)

When isolation of the tube side of the leaking HP heater string is directed, the Lead Evaluator can cue the

booth operator to insert the loss of 115KV power. Due to the unavailability of the "A" DG, power is lost to 1DA

("A" train ESF power) and all running essential equipment. The crew will enter AOP-304.1 LOSS OF BUS 1DA

WITH THE DIESEL NOT AVAILABLE. CRS will evaluate Techni

cal Specification 3.8.1.1.a for availability of Offsite Sources. Restoration of 1DA from

the Emergency Aux Transformer (230KV) will be prevented by an inoperable alternate incoming breaker (this forces more observable actions in EOP-15.0/H.1)

.

When the evaluation of the loss of "A" Train ESF power is complete and Component Cooling Water and

Charging restored, the Lead Evaluator can cue the booth operator to insert the Inadvertent Feedwater Isolation

Signal. This isolates Main Feedwater with no EFW pumps available. Crew will progress through EOP-1.0 REACTOR TRIP/SAFETY INJECTION ACTUATION and EOP-15.0 RESPONSE TO LOSS OF SECONDARY HEAT SINK . SG heat sink will then be restored

by bypassing the FWIS and using the Feedwater Booster Pumps. The scenario can be terminated either 1) after feed is restored or 2) after PORVs are closed and SI

flow reduced at Lead Evaluator discretion. Failure to restore heat removal will by indicated by an RCS heatup

to saturation (alarm at zero degrees subcooled, simulator has no instrument error inserted) which is when a

steam void starts to form in the Reactor Vessel, threatening eventual core uncovery below 51% narrow range

RVLIS.

Appendix D 3 NUREG 1021 Revision 9

VCS 2011 NRC Scenario 1 Simulator Setup

Initial Conditions:

IC-10, 100% power, MOL. Reactivity Management Plan/Turnover sheet for IC "B" EDG and "B" RB Spray pump are OOS Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires.

VCS 2011 NRC Scenario 1 Simulator Setup (SNAP 301 or 305)

Conduct two-minute drill Mark up procedures in use with "Circle and slash" as applicable (N/A for this 100% snap)

Pre-Exercise:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)

TQP-801 Booth Operator checklist, has been completed

Hang red tags and Removal and Restoration tags on "B" RB Spray Pump and "B" EDG control switches.

Make extra copies of EOP-1.1 Att. 16

PRE-LOAD

MAL EPS006A = Fail "A" EDG fails to autostart, will not start manually or locally VLV MS001F FCV-2030 fails as-is (closed) LOA AUX118 = RACK OUT ("B" RB Spray pump OOS) LOA-EPS114 = MAINTENANCE ("B" EDG OOS) MAL FWM003B "B" MDEFW Pp fails to start Override STL-ES007 (86 XTF-4) to OFF Override STL-ES008 (86 XTF-5) to OFF LOA-AUX050, SFP HX 1B DISCH ISOL VLV Set=0.9 LOA-AUX048, CROSS-TIE ISOL VLV Set=1 LOA-AUX073, SPENT FUEL POOL PUMP B SWITCH Set=ON MAL-EPS005B, Failure of 1DA alternate feeder breaker to close

Appendix D 4 NUREG 1021 Revision 9

EVENT 1: Power Range Detector NI-44A fails high

Trigger 1 Malfunction NIS007G = 5 ma, 2 minute ramp No local actions, circuit will not be repaired

EVENT 2: Leak on 1A High Pressure feedwater heater

Trigger 2 Malfunction FWM009A=3E6 (3 million pounds mass/hour) ramp over 5 minutes HP heater tube leak "A" heater string will auto-isolate on high level Damage will not be repaired

EVENT 4: 115KV offsite power is lost

Trigger 4 Currently Malfunctions EPS018A&B Parr switchyard is impacted by tornado, will not be restored during scenario Bus 1DA is lost due to failure of "A" Emergency Diesel Generator to start CCW non-essential supply valves powered by "A" train must be locally operated (Trigger 6)

EVENT 5: Inadvertent Train B Feedwater Isolation

Trigger 5 Malfunction PCS013B = INDAVERTANT INIT Signal may be bypassed per EOP-15.0 using trigger 7

TRIGGER 6: local transfer of non-essential CCW loads to "B" train

Trigger 6 VLV CC006P = 0% 45 sec. ramp (MVB-9524A and 9526A closed using Limitorque local handwheel) VLV CC009P = 100% 45 sec. ramp, 45 sec TD (MVB-9687B and 9525B opened using Limitorque local

handwheel)

TRIGGER 7: local bypass of feedwater isolation

LOAs FWM-040,041, and 042 = BYPASS

Appendix D 5 NUREG 1021 Revision 9

Trigger 8: Deenergize Train A Loading Sequencer

ANN-SG012 ESFLS (A) DOOR OPEN XCP 636 LOA-EPS136, LOAD SEQUENCER A:CONTROL POWER SWITCH Set=OPEN 30 second TD

Trigger 9: Transfer 1FC1 to 1FB

LOA-EPS171 APN-1FC1 to Power Selector switch for DRPI when requested Set = 1FB

Trigger 10; HVAC annunciator/horn acknowledge LOA-AUX078 to OFF

Trigger 11; Bypass and isolate "A" HP heater string (announce time compression) LOA-FWM031 = 1.0, 1 minute ramp

LOA FWM029 = 0.0, 1 minute ramp 1 minute time delay

Trigger 12; Transfer "C" Charging pump to "B" train LOA-CVC043 CHARGING PUMP C SUPPLY BRKR TRAIN A = RACK OUT 2 minute TD

LOA-CVC044 CHARGING PUMP C SUPPLY BRKR TRAIN B = RACK IN 5 minute TD

LOA-CVC045 CHARGING PUMP C DISCONNECT SWITCH = TRAIN B 8 minute TD

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 6 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 6 NUREG 1021 Revision 9

Booth Instructor:

When directed, insert Trigger 1.

Indications available: Uncontrolled Rod Motion XCP-620 1-1, PR HI SETPT FLUX HI

XCP-620 2-2, PR FLUX HI RATE SINGLE CHAN ALERT

XCP-621 2-4, PR FLUX HI ROD STP Evaluator's Note: The crew could enter the ARPs but it is more likely that they will

recognize the entry condition for AOP-401.10, POWER RANGE CHANNEL FAILURE.

CRS Enters AOP-401.10, PO

WER RANGE CHA

NNEL FAILURE

Enters AOP-401.10

IOA RO Verify normal indication on Power Range Channel N-44. (NO) AOP IOA & CRITICAL

TASK RO If Power Range Channel N-44 has failed, THEN place the ROD CNTRL BANK SEL Switch in MAN (Prior to rods going below the RIL)

AOP IOA Crew Stabilize any plant transients in progress.

AOP * Crew Maintain stable plant conditions.

AOP Crew Verify no testing is in progress on the operable Power Range channels

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 7 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 7 NUREG 1021 Revision 9

RO Place ROD STOP BYPASS Switch (on the MISCELLANEOUS CONTROL

AND INDICATION PANEL) for the failed Power Range channel

(N-44) in BYPASS. AOP RO Verify the appropriate Rod Stop Bypass status light is bright: For N-41, A1 OP ROD STOP BYP (XCP-6111 4-1). For N-42, B1 OP ROD STOP BYP (XCP-6111 4-2). For N-43, A2 OP ROD STOP BYP(XCP-6111 4-3). For N-44, B2 OP ROD STOP BYP (XCP-6111 4-4).

AOP RO Adjust Control Rods to maintain Tavg within 1.0 °F of Tref

AOP Crew Notify the I&C Department to record detector currents and status lights on POWER RANGE A and POWER RANGE B drawers

AOP Booth Operator Instructions: When called as I&C to record detector currents and status lights report that the necessary data for N44 has been collected.

Evaluator Note: The recording of data by I&C would be done in the control room so the booth operator is compressing time and the operators will not see an individual record data (it may be necessary to cue the crew as to these facts).

CAUTION - Step 9

The empty fuse holders should NOT be reinstalled as this will allow a small amount of current flow through the blown fuse indicator.

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 8 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 8 NUREG 1021 Revision 9

BOP Deenergize the failed Power Range channel:

(N-44) a. Remove the CONTROL POWER fuses from the POWER RANGE A

drawer. b. Remove the INSTR POWER fuses from the POWER RANGE B

drawer. AOP BOP Align the Power Range channel comparator circuits: a. Place the following switches to the failed Power Range channel

position: (N-44) 1) COMPARATOR CHANNEL DEFEAT Switch (on the

COMPARATOR AND RATE drawer). 2) UPPER SECTION Switch (on the DETECTOR CURRENT

COMPARATOR drawer). 3) LOWER SECTION Switch (on the DETECTOR CURRENT

COMPARATOR drawer).

AOP RO Ensure NR-45 is selected to the appropriate operable channels.

AOP Crew Check if Reactor power is LESS THAN 75% (NO) AOP Crew Initiate GTP-702, Attachment IV.F.

AOP Evaluator Note: GTP-702 Attachment IV.F requires that STP0108.001 be performed every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Since the scenario will not last that long it is assumed that STP0108.001 will not be performed.

Crew Check if Reactor power is LESS THAN 50% (NO) AOP Crew Initiate GTP-702, Attachment IV.D

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 9 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 9 NUREG 1021 Revision 9

Evaluator Note: GTP-702 Attachment IV. D requires that STP0133.001 be performed once per hour. Since

the scenario will not maintain power above 50% for the next hour it is assumed that STP0133.001 will not be performed.

CRS Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a tripped

condition: (N/A) AOP Evaluator Note: The other three channels would require tripping of additional bistables. The only bistables

for N-44 are in the NIS Racks and are already tripped.

CRS Refer to Tech Spec 3.3.1

AOP CRS From Table 3.3-1 Functional Units 2 & 3 require action 2# and Function Unit 19 requires action 7

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 10 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 10 NUREG 1021 Revision 9 Action 2

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied: a. The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. DONE b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels per Specification 4.3.1.1. c. Either, THERMAL POWER is restricted to less than or equal to 75% of RATED THERMAL POWER and the Power Range Neutron Flux trip setpoint is reduced to less

than or equal to 85% of RATED THERMAL POWER within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />; or, the

QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> per Specification 4.2.4.2.

4.2.4.1 The QUADRANT POWER TILT RATIO shall be determined to be within the limit above

50% of RATED THERMAL POWER by:

a. Calculating the ratio at least once per 7 days when the alarm is OPERABLE.

b. Calculating the ratio at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during steady state operation when the alarm is

inoperable.

4.2.4,2 The QUADRANT POWER TILT RATIO shall be determined to be within the limit when

above 75 percent RATED THERMAL POWER with one Power Range Channel inoperable at

least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by using the PDMS or movable incore detectors to confirm that the normalized symmetric power distribution is consistent with the indicated QUADRANT POWER TILT RATIO. The incore detector monitoring shall be done with 2 sets of 4 symmetric thimbles or a full incore flux map.

GTP-702 Attachment IV.F Tech Specs Action 7

With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window(s) that the interlock is in its

required state for the existing plant condition, or apply Specification 3.0.3.

P-7, P-8, P-10, P-9 Tech Specs Crew Verify proper status of P-7, P-8, P-10, & P-9 Tech Specs

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1 Op Test No.: 2011 NRC Scenario # 1 Event # 1 Page 11 of 43 Event Description: Power Range upper detector NI-44A fails high

Time Position Applicant's Actions or Behavior

Appendix D 11 NUREG 1021 Revision 9 4.2.1.1 The indicated AFD shall be determined to be within its limits during POWER. OPERATION above 50% of RATED THERMAL POWER by:

a. Monitoring the indicated AFD -for each OPERABLE excore channel at least once per 7 days when the AFD Monitor Alarm is OPERABLE: b. Monitoring and logging the indicated AFD for each OPERABLE excore channel at least once

per hour for the first 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and at least once per 30 minutes thereafter, when the AFD Monitor

Alarm is inoperable. The logged values of the indicated AFD shall be assumed to exist during the

interval preceding each logging. GTP-702 Attachment IV.D Tech Specs Crew Conducts post-event brief and notifies SS.

Once TS implications are identified, proceed to the next event.

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-2

Op Test No.: 2011 NRC Scenario # 1 Event # 2 & 3 Page 12 of 43 Event Description: HP heater tube leak, Reduce power to isolate HP FW heater string

Time Position Applicant's Actions or Behavior

Appendix D 12 NUREG 1021 Revision 9

Booth Operator Instructions:

When directed, insert Trigger 2

Indications available:

XCP-627 2-3, FW HTR 1,2,4 ISOLATE/LVL HI-HI

BOP Responds to alarm XCP-627 2-3, FW HTR 1,2,4 ISOLATE/LVL HI-HI.

BOP Enters ARP-001-627 2-3.

ARP XCP-627 2-3

PROBABLE CAUSE: 1. Failure of the heater level control system(s).

2. Any HTR 1(A or B), 2(A or B) or 4(A or B) in ISOLAT (manually or automatic).

ARP AUTOMATIC ACTIONS: 1. The following will occur to the heater with the High-High level: a. The extraction steam check valve and isolation valve close.

(YES) b. The emergency drain valve to the Condenser opens fully.

c. For Heaters 1A(B) only, the drain from the Reheater Drain Tank closes.

(YES) d. For Heaters 2A(B) only, the drain from the Moisture Sep Drain Tank closes.

(NO) e. For Heaters 2A(B) only, the drain from Heater 1A(B) closes.

(NO) ARP NOTE This alarm has reflash capabilities.

ARP CORRECTIVE ACTIONS: 1. Determine which heater is ISOLATED using DCS screens 101 thru 110.

2. For Heaters 1A(B) or 2A(B) go to AOP-204.1 (YES). ARP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-2

Op Test No.: 2011 NRC Scenario # 1 Event # 2 & 3 Page 13 of 43 Event Description: HP heater tube leak, Reduce power to isolate HP FW heater string

Time Position Applicant's Actions or Behavior

Appendix D 13 NUREG 1021 Revision 9 CRS Go to AOP-204.1, LOSS OF HIGH PRESSURE FEEDWATER HEATERS

Transitions to AOP-204.1 NOTE - Step 1

Entering CNTRL-ALT-S on the EHC keyboard

is the preferred method to accomplish a rapid load reduction during FW Heater transients.

AOP IOA BOP Verify Turbine Load is LESS THAN 950 MWe (NO) AOP IOA BOP Using any method available, reduce Turbine Load by 40 MWe to 50 MWe

AOP BOP Verify Turbine Load is GREATER THAN 700 MWe (YES) AOP * CREW Monitor DELTA T PWR on ZZMENU (Screens 1 and 2) on the IPCS

AOP Evaluator note; manual trip is required at 102% delta T.

BOP Verify the following are NOT ISOLATED: HEATER #2A. HEATER #2B MS DRN TANK A. MS DRN TANK B. (YES) AOP BOP Verify the following are NOT ISOLATED: HEATER #1A. HEATER #1B RH DRN TANK A. RH DRN TANK B.

(NO) AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-2

Op Test No.: 2011 NRC Scenario # 1 Event # 2 & 3 Page 14 of 43 Event Description: HP heater tube leak, Reduce power to isolate HP FW heater string

Time Position Applicant's Actions or Behavior

Appendix D 14 NUREG 1021 Revision 9

Booth Operator Instructions: If contacted as Turbine Operator, report High level in the #2 heater sightglass, Normal and

Emergency Drain valves (3763A & 3763B) are fully open.

BOP Reduce Turbine Load at 3%/MIN until one of the following has been met: If only one #1 Heater or RHDT is ISOLATED, THEN reduce load to LESS THAN 925 MWe

(YES) OR If two or more #1 heaters or RHDTs are ISOLATED, THEN reduce load to

LESS THAN 850 MWe

(NO) AOP 204.1 RNO Evaluator note; 925MWe is approximately 80% valve position.

RO Maintains Tavg within 1°F of Tref; Operates Control rods in MANUAL Borates through the blender or MVG-8104 (8104 expected)

AOP 410.10 BOP Verify DA level is stable at or trending to normal operating band. (NO) AOP 204.1 BOP Start the remaining Condensate Pump per the following: a) Ensure XVB-614A(B)(C), A(B)(C) DISCH ISOL, is closed for the pump to be

started. b) Start the remaining Condensate Pump. c) Open XVB-614A(B)(C), A(B)(C) DISCH ISOL, for the remaining Condensate Pump. AOP 204.1 NOTE - Step 7

Following the Turbine Power Reduction, Xenon levels may increase. Tavg should be maintained at T

ref by Control Rod movement or RCS dilution. Reactor Engineering should be contacted for a long term reactivity

management plan.

AOP 204.1

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-2

Op Test No.: 2011 NRC Scenario # 1 Event # 2 & 3 Page 15 of 43 Event Description: HP heater tube leak, Reduce power to isolate HP FW heater string

Time Position Applicant's Actions or Behavior

Appendix D 15 NUREG 1021 Revision 9

Booth Operator Instructions: When called as Reactor Engineering for a long term reactivity management plan report that a

reactivity management plan is being developed.

If contacted as Unit 5 (TBAO) report that FW Pump seal cooling is responding normally.

RO Maintain the following operating limits: a. Axial Flux Difference within the ta

rget band. Check the RAOC or BASELOAD display on the IPCS.

b. Control Rods above RIL:

Check the RIL display on the IPCS. Verify CRB INSERT LMT LO-LO (XCP-621 1-1), annunciator is NOT lit. ' c. Steady state power level. REFER TO GOP-4B, POWER OPERATION (MODE 1 - DESCENDING).

d. Main Generator reactive load LESS THAN 325 MVAR.

AOP 204.1 BOP When no longer required to maintain DA level, secure Condensate Pumps as necessary per SOP-208.

AOP 204.1 Booth Operator Instructions: when notified of event

as SS direct isolation of leaking heater per SOP-

204. Booth Operator Instructions: SOP-204 IV.A may be used to isolate the leaking heater. If contacted as Turbine Operator to open XVT01609 bypass and close XVK01626A and XVK01608

isolations, use Trigger 11 to do so.

SOP-204 IV.A Crew Conducts post-event brief, contacts SS and may contact Mechanical Maintenance.

At the discretion of the lead examiner, proceed to the next event.

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 16 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 16 NUREG 1021 Revision 9

Booth Instructor:

When directed, insert Trigger 4

Indications available: Buss potential lights on 1DA are out Trip alarm for A charging pump

DG A AUTOSTART NOT READY alarm

CRS Enters AOP-304.1(A), LOSS OF BUS IDA WITH THE DIESEL NOT AVAILABLE

AOP-304.1(A) NOTE This procedure assumes a loss of XSW1DA has occurred due to one of the following reasons: A loss of the offsite power source occurred. An XSW1DA Bus lockout has occurred.

AOP NOTE - Steps 1 through 5

The installed spare components (C Pumps or Chillers) may be aligned and started for Train B operation if

the Train B components are NOT available.

AOP RO Ensure a Train B Component Cooling Pump is running: XPP-0001B, PUMP B. (STARTS) OR XPP-0001C, PUMP C TRAIN B.

AOP RO Ensure a Train B Charging Pump is running: XPP-0043B, PUMP B. (STARTS) OR XPP-0043C, PUMP C TRAIN B.

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 17 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 17 NUREG 1021 Revision 9 NOTE - Step 3

On a loss of power to MVG-9600, TO THERM BARR ISOL, from XSW1DA2X, the Component Cooling

Water Booster Pumps will not start due to an open contact in the start circuit. (This applies here)

AOP RO Verify Component Cooling Water Loop B is the Active Loop. (NO) AOP RO Close the following Charging and Letdown Valves: a) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

b) LCV-459 and LCV-460, LTDN LINE ISOL. c) FCV-122, CHG FLOW. d) HCV-142, LTDN FROM RHR (low pressure letdown, N/A in this MODE)

. AOP RO Establish Component Cooling Water Loop B as the Active Loop. REFER TO SOP-118, COMPONENT COOLING WATER.

Uses SOP-118 section V.A

RO Ensure MVB-9503B, CC TO RHR HX B, is open

SOP NOTE 2.3.a

On a loss of power to MVG-9600, TO

THERM BARR ISOL, from XSW1DA2X, the Component Cooling Water Booster Pumps will

not start due to an open contact in the

start circuit.

SOP RO Ensures MVB-9503B, CC TO RHR HX B is open

SOP RO Starts XPP-001B, PUMP B

SOP RO Closes MVB-9687A/9525A, LP A NON-ESSENTIAL LOAD ISOL

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 18 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 18 NUREG 1021 Revision 9

SOP RO Open MVB-9524B/(%26B, LP B NON-ESSEN LOAD ISOL

SOP Booth Operator Instructions: Use SOP-118 section V.A; When called to close MVB-9524A and 9526A, A NON-ESSEN LOAD ISOL, and open MVB-9687B and 9525B, LP B NON-ESSEN LOAD ISOL, use Trigger 6 to do so.

SOP RO Directs locally opening XVB-9525B and 9687B, supply and return header cross-

connects

SOP RO Closes MVB-9503B, CC TO RHR HX B.

SOP RO Directs locally opening XVB-9503A and closing XVB-9524A and 9526A.

RO Ensure the following valves have not automatically closed due to high flow: 1) MVG-9625, CC TO RB. 2) MVG-9626, CC TO RB.

3) MVG-9583, FROM XS LTDN HX.

4) MVT-9593A(B)(C), FROM RCP A(B)(C) THERM BARR.

SOP RO Locally verify greater than 1 gpm sample flow on RML0002B, LIQUID RAD MON COMPONENT COOLING (IB-412).

SOP Booth Operator Instructions:

When called to report flow to RML-2B report > 5 gpm.

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 19 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 19 NUREG 1021 Revision 9

RO Check if a Train B Service Water Pump is running: XPP-0039B, PUMP B. (YES) OR XPP-0039C, PUMP C TRAIN B.

AOP-304.1

Crew Ensure HVAC Chilled Water Loop B is operating: XPP-48B, PUMP B, AND XHX-1B, CHILLER 1B, are running. (STARTS)

OR XPP-48C, PUMP C TRAIN B, AND XHX-1C, CHILLER C TRAIN B, are running.

AOP Crew Check if RHR cooling is required. (NO) AOP CRS GO TO Step 8

AOP RO Ensures Instrument Air Compressor B is running

(YES) AOP RO WHEN Component Cooling Water is available for non-essential loads, THEN verify Letdown flow on FI-150, LO PRESS LTDN FLOW GPM (NO) AOP RO Set PCV-145, LO PRESS LTDN, to 70%.

Start Event 5, AOP

RO Fully open TCV-144, CC TO LTDN HX.

AOP RO Place TCV-143, LTDN TO VCT OR DEMIN, in VCT position.

AOP RO Open PVT-8152, LTDN LINE ISOL.

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 20 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 20 NUREG 1021 Revision 9

AOP RO Open both LCV-459 and LCV-460, LTDN LINE ISOL.

AOP RO Slowly adjust FCV-122, CHG FLOW, to obtain 70 gpm Charging flow.

AOP RO Open desired Orifice Isolation Valve(s) to obtain 60 gpm to 120 gpm: PVT-8149A, LTDN ORIFICE A ISOL (45 gpm). PVT-8149B, LTDN ORIFICE B ISOL (60 gpm). PVT-8149C, LTDN ORIFICE C ISOL (60 gpm).

AOP RO Adjust FCV-122, CHG FLOW, to maintain TI-140, REGEN HX OUT TEMP °F, between 250"F and 350 °F while maintaining PZR level.

AOP RO Adjust PCV-145, LO PRESS LTDN, to ma

intain PI-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.

AOP RO Place PCV-145, LO PRESS LTDN, in AUTO.

AOP RO Place TCV-144, CC TO LTDN HX, in AUTO.

AOP RO Ensure Letdown temperature is stable.

AOP RO Place TCV-143, LTDN TO VCT OR DEMIN, in DEMIN/AUTO position.

AOP RO Verify 60 gpm to 120 gpm on FI-150, LO PRESS LTDN FLOW GPM.

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 21 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 21 NUREG 1021 Revision 9

RO Verify PZR level is stable at OR trending to program level.

End Event 5, AOP

Crew Ensure Spent Fuel Cooling Loop B is in service. (

YES) REFER TO SOP-123, SPENT FUEL COOLING SYSTEM.

AOP Booth Operator Instructions:

If called to ensure Spent Fuel Cooling Loop B is in service report that it is.

Crew Place the following Control Switches in PULL TO LK NON-A: Charging Pump A. Charging Pump C (Train A). Emergency Feedwater Pump A.

AOP BOP REFER TO ARP-001 XCP-633 through 641, ANNUNCIATOR RESPONSE

PROCEDURE, for annunciator(s) in alarm.

AOP Booth Operator Instructions: If called as Intermediate Building Operator, report A EDG stopped, receiver pressure at 375 psig

with compressor running, EMERG START and EMERGENCY SHUTDOWN alarms in. A large oil leak is found on the Governor, Mechanical Maintenance has been contacted.

Crew Dispatch operators to the following areas to locally investigate for problems: XTF0004 and XTF0005, ESF Transformers. XTF0031, Emergency Aux Transformer #1. XSW1DA. XCX5201, Diesel Generator A Local Control Panel. GENERATOR & XFMR ELECTRICAL RELAY BOARD (CB-463), XCP6221A-EG and XCP6225-EG.

AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 22 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 22 NUREG 1021 Revision 9

Booth Operator Instructions:

When called as units 5 and 7 (TB and IB AOs)

to investigate the electrical problem report that there

is no apparent damage to 1DA, no flags, no smoke or odor. However, Alternate Incoming breaker

closing springs are discharged and electricians are investigating. Report no external damage to XTF-4 or -5, no voltage but no lockouts on switchgear 1DX,

When called to investigate the "A" DG report that

the governor has a large oil leak and no visible oil

level, mechanics are preparing to replace the governor with a spare .

AOP Crew Consult with the System Controller to determine possible causes.

AOP Booth Operator Instructions: When called as the System Controller report that due to storm damage it is unlikely that the 115 kv

line from Parr will be available for at least a day and that the 13.8 kv line from Parr hydro is also out.

Crew Record all tripped relay flags. (Contacts Operators to record tripped relay flags).

AOP Booth Operator Instructions: When called to record relay flags report that there are no relay flags to reset.

Crew Locally reset tripped relay flags and lockouts only when directed by the Shift

Supervisor.

AOP BOP Verify an offsite power source is available to the ESF Bus: BUS 1DA NORM FEED, potential lights are energized

(NO) OR BUS 1DA ALT FEED, potential lights are energized.

(YES) AOP

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event #s 4 & 5 Page 23 of 43 Event Description: 115KV offsite power is lost, 1DA is deenergized, Restoration of letdown

Time Position Applicant's Actions or Behavior

Appendix D 23 NUREG 1021 Revision 9

Crew Verify all of the following conditions exist: The cause of the power loss has been determined. (YES, Storm damage in the Parr switch yard)

Any damage to XSW1DA has been corrected. (No damage to 1DA)

The cause of the power loss is corrected, OR it does NOT affect restoration of

the bus.

(ALT FEED is not available

due to inoperable alternate incoming

breaker) AOP NOTE - Step 16

Each switch may be placed in After-Stop immediately after recording the AS FOUND position.

AOP BOP Record the AS FOUND Main Control Board Train A switch positions, then align the switches to After-Stop. REFER TO Attachment 1A.

AOP Crew Locally remove power from the Train A ESF Loading Sequencer (XPN-6020 CB-

436). AOP CRS Enters Technical Specification 3.0.3 due to one offsite source and both EDGs INOPERABLE. Technical Specification 3.2.5 will also apply below 2206 psig RCS pressure, as neither only one of backup heaters is available.

Tech Specs

Crew Conduct post-event brief and contact SS. May contact MDS for electrical and maintenance assistance.

AOP When the crew requests that power be removed from Train A ESF Loading Sequencer, proceed to

the next event

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 24 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 24 NUREG 1021 Revision 9

Booth Instructor:

When directed, insert Trigger 5

Indications available: Reactor trip breakers open, TURB TRIP first out

Turbine stop valve closed status lights XCP-624 pt. 1-4 FW ISOL XCP-625 pt. 2-1 FWP A/B/C TRIP

CRS Direct entry into EOP-1.0, REACTOR TRIP SAFETY INJECTION ACTUATION

Enters EOP-1.0

IOA RO Verify Reactor Trip: Trip the Reactor using either Reactor Trip Switch. Verify all Reactor Trip and Bypass Breakers are open. Verify all Rod Bottom Lights are lit. Verify Reactor Power level is decreasing.

(YES) EOP-1.0 Booth Operator Instructions: When called to transfer DRPI to 1FB, do so by using Trigger 9

IOA BOP Verify Turbine/Generator Trip: a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay): 1) Ensure the GEN BKR is open. 2) Ensure the GEN FIELD BKR is open. 3) Ensure the EXC FIELD CNTRL is tripped.

(YES) EOP-1.0 IOA BOP Verify both ESF buses are energized. (NO) EOP-1.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 25 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 25 NUREG 1021 Revision 9

IOA BOP Perform the following: a) Verify at least one ESF bus is energized: 7.2 KV BUS 1DA is energized.

(NO) OR 7.2 KV BUS 1DB is energized.

(YES) IF no ESF bus is energized, THEN GO TO EOP-6.0, LOSS OF ALL

ESF AC POWER, Step 1. (NO)

b) Try to restore power to the deenergized bus while continuing with this procedure. REFER TO AOP-304.1, LOSS OF BUS 1DA(1DB) WITH THE DIESEL NOT AVAILABLE

. (YES) EOP-1.0 IOA RO Check if SI is actuated: a. Check if either: SI ACT status light is bright on XCP-6107 1-1.

Or Any red first out SI annunciator is lit on XCP-626 top row. b. Actuate SI using either SI ACTUATION Switch

(NO) EOP-1.0 IOA Crew Check if SI is required: a. Check if any of the following conditions exist: PZR pressure less than 1850 psig. OR RB pressure GREATER THAN 3.6 psig. OR Steamline pressure LESS THAN 675 psig. OR Steamline differential pressure GREATER THAN 97

psig. b. Actuate SI using either SI ACTUATION Switch. (NO) EOP-1.0 Booth Operator Instructions: As Control Building Operator, silence HVAC board alarms by using Trigger 10

IOA CRS GO TO EOP-1.1, REACTOR TRIP RECOVERY, Step 1.

Enters EOP-1.1

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 26 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 26 NUREG 1021 Revision 9

Crew Determines that a Red Path Exists on Heat Sink

CRS Transitions to EOP-15.0, RESPONSE TO LOSS OF SECONDARY HEAT SINK Transitions to EOP-15.0

Booth Operator Instructions: When called as Unit 4 (CBAO) to remove power from the Train A ESF Loading Sequencer wait until the crew transitions to EOP-15.0 and then do so by using Trigger 8.

Report as electrical maintenance that change-out of the alternate incoming breaker will require

approximately one hour.

CAUTION If total EFW flow is LESS THAN 450 gpm due to operator action, this procedure should NOT be performed, since these actions are NOT appropriate if 450 gpm EFW flow is

available.

If a NON-FAULTED SG is available, feed flow should NOT be reestablished to any FAULTED SG, to prevent thermal shock to SG tubes.

EOP-15.0 NOTE Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

EOP-15.0

Crew Check if a secondary heat sink is required: a. Verify RCS pressure is GREATER THAN any NON-FAULTED SG

pressure. b. Verify RCS Thot is GREATER THAN 350 °F.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 27 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 27 NUREG 1021 Revision 9

RO Verify power is available to all PZR PORV Block Valves: a. MVG-8000A, RELIEF 445 A ISOL. (YES) b. MVG-8000B, RELIEF 444 B ISOL

(NO) c. MVG-8000C, RELIEF 445 B ISOL. (YES) EOP-15.0 Evaluator note; 8000B is deenergized in the open position.

EOP-15.0

RO Locally close XMC1DA2X 06IM, PRESSURIZER PRESSURE RELIEF ISO VALVE XVG8000B-RC breaker on MCC (IB-463).

EOP-15.0

Booth Operator Instructions: If called to locally close XMC1DA2X 06IM, PRESSURIZER PRESSURE RELIEF ISO VALVE XVG8000B-RC breaker wait 3 min and then report that it is already closed. (The reason

power is not available to the valve is that 1DA is not powered, not that this breaker is

open). EOP-15.0

RO Open the Block Valve for any PZR PORV that has been isolated due to excessive seat leakage: MVG-8000A, RELIEF 445 A ISOL. (NO) MVG-8000B, RELIEF 444 B ISOL. (NO) MVG-8000C, RELIEF 445 B ISOL. (NO) EOP-15.0 CAUTION - Steps 4 through 16

If Wide Range level in any two SGs is LESS THAN

12% [20%] OR PZR pressure is GREATER

THAN 2330 psig due to loss of secondary heat sink, Steps 17 through 24

should be immediately initiated for bleed and feed cooling.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 28 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 28 NUREG 1021 Revision 9

BOP Ensure the following valves are

closed: ' * SG Blowdown, PVG-503A(B)(C).

• SG Sample, SVX-9398A(B)(C).

EOP-15.0

Note - Step 5

If EFW flow control can NOT be reestablished from the Control Room, this procedure should be

continued while local operator action is in progress to restore EFW flow.

EOP-15.0

Crew Check Control Room indications for the cause of EFW Failure: 1) Verify no EFW annunciators are lit: XCP-621 3-5 (EFP SUCT HDR PRESS LO XFER TO SW). Any alarm on XCP-622 Any alarm on XCP-623

(YES) 2) Verify CST level is GREATER THAN 5 ft. (YES) 3) Ensure power is available to both MD EFW Pumps.

(NO, MD EFW B AUTOSTART FAIL is lit on XCP-623, pt. 1-3

) EOP-15.0

Booth Operator Instructions:

When called to investigate the EFW pumps. Report as the IB operator that the

instantaneous overcurrent flag for MDEFW B is dropped on A and B phases. Report that

2030 will not open (even if asked to manually bleed air off the valve)

EOP-15.0

CRS Refer to AOP-304.1 to restore power to IDA.

EOP-15.0

BOP Energize XSW1DA from the normal power source: (NOT AVAILABLE)

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 29 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 29 NUREG 1021 Revision 9

BOP IF XSW1DA normal power source is NOT available, THEN energize

XSW1DA from the alternate power a) Ensure BUS 1DA XFER INIT Switch is in OFF.

b) Close BUS 1DA ALT FEED Breaker.

c) Verify BUS 1DA potential lights are energized.

EOP-15.0 CAUTION -

Step 5.a.4

) EFW valves should NOT be opened to SGs with Wide Range level LESS THAN

12% [20%]. If Wide Range level in all SGs is LESS THAN

12% [20%], EFW valves should be open to only one SG, until RCS temperatures are decreasing, to limit any failure to one SG.

EOP-15.0

Crew Ensure all EFW valves are open;

FCV-3531(3541)(3551), MD EFP TO SG A(B)(C). FCV-3536(3546)(3556),TD EFP TO SG A(B)(C).

(TD EFW Pump

not available)

MVG-2802A(B), MS LOOP B(C) TO TD EFP. PVG-2030, STM SPLY TO TD EFP TRN A(B).

(Will not open)

EOP-15.0

Crew Try to restore any EFW flow.

EOP-15.0

Evaluator Note: The following steps establish Feed and Condensate flow using Steps 8-11

EOP-15.0 CAUTION - Step 8

Deaerator Storage Tank level should be monitored closely and maintained between 2.5 ft and 10.5 ft on LI-3135, DEAER STOR TK WR LVL FEET, to prevent tripping Condensate and

Feedwater Booster Pumps.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 30 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 30 NUREG 1021 Revision 9

Crew Ensure one Condensate Pump is running (this permits leaving more than one running- need is for "at least" one to be running

.) EOP-15.0

Crew Ensure two Feedwater Booster Pumps are running.

EOP-15.0

Crew Ensure Main FW Control Valves are closed: FCV-478, A FCV. FCV-488, B FCV. FCV-498, C FCV.

EOP-15.0

Crew Place all Main FW Bypass Valve Controllers in MAN and closed: FCV-3321,LOOP A MAIN FW BYP. FCV-3331,LOOP B MAIN FW BYP. FCV-3341,LOOP C MAIN FW BYP.

EOP-15.0

Crew Locally place the following key switches in BYPASS (CB-448): XVG01611A,B,C (XPN 7114). IFV03321,3331,3341 TRAIN A (XPN 7115). IFV03321,3331,3341 TRAIN B (XPN 7121).

EOP-15.0

Booth Operator Instructions: When called to place the key switches in BYPASS wait 3 minutes and then do so using

Trigger 7.

EOP-15.0

Crew Verify XCP-612 2-1 is NOT lit (RB PRESS HI-2 STM LINE ISOL).

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 31 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 31 NUREG 1021 Revision 9 NOTE - Step 8.g

SG B or C is preferred, so that a steam supply for the TD EFP will be restored as soon as

possible. Before the Low Steamline Pressure SI signal is blocked, Main Steam Isolation will occur if the Low Steam Pressure rate setpoint is exceeded.

EOP-15.0

Crew Align the MS Isolation Valves to depressurize only one SG: 1) Verify the MS Isolation Valve, PVM-2801A(B)(C), is open for the SG to be depressurized. 2) Ensure the remaining two MS Isolation Valves, PVM-2801A(B)(C), are closed.

EOP-15.0

Crew Place the following switches in AUTO: PVG-1611A(B)(C), A(B)(C) ISOL. FCV-3321,3331,3341, FW CNTRL BYP VLVS, Train A Switch. FCV-3321,3331,3341, MAIN FW BYPASS VLVS, Train B Switch.

EOP-15.0

Crew Reset both SI RESET TRAIN A(B) Switches.

EOP-15.0 NOTE - Step 10

Main Feed Pumps trip on SI. If an SI occurs, Steps 9 and 10

should be repeated to restart Main Feed Pumps.(feed pumps will not reset since the "B" train FWIS is still present.)

EOP-15.0

Crew Verify PERMISV C-9 status lights bright on XCP-6114 1-3.

EOP-15.0

Crew Open MOV-1-5A(B)(C), TURB DRN VLV.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 32 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 32 NUREG 1021 Revision 9 Evaluator note; FW pumps cannot be reset because the FW isolation signal is still present.

EOP-15.0

Crew Ensure Feedwater Pump to be started is RESET (MCB or DCS (T ICON))

(cannot). EOP-15.0

Crew Throttle open FCV-3321(3331)(3341), LOOP A(B)(C) MAIN FW BYP, to the unisolated SG.

EOP-15.0 NOTE - Step 11

Step 11 should NOT be performed as long as the Main Feed Pump is supplying sufficient flow to

increase SG level.

EOP-15.0

Evaluator Note: After restoring a supply of water to the SG's either through Step 5 for the MD EFW Pump

or Steps 8-11 for a MFP the scenario can be terminated at the discretion of the Lead

Examiner. Feed and bleed will probably be avoided by prompt EFW or MFW restoration. The following steps will be taken if wide range level falls to 15% WR.

CRS Go to Step 17.

EOP-15.0 CAUTION - Steps 17 through 24

Steps 17 through 24

must be performed quickly to establish RCS heat removal by RCS bleed and feed, to minimize core uncovery.

EOP-15.0

RO Ensure all RCPs are tripped.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 33 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 33 NUREG 1021 Revision 9

Crew Actuate SI using either SI ACTUATION Switch.

EOP-15.0 NOTE - Step 19

Although only one train of SI flow is required to establish an effective RCS feed path, SI flow

should be maximized by operating both Charging Pumps if possible.

EOP-15.0

RO Verify an RCS feed path: a. Ensure at least one Charging Pump is running.

(B) b. Ensure all the following are open: MVG-8801A(B), HI HEAD TO COLD LEG INJ. LCV-115B(D), RWST TO CHG PP SUCT. c. Verify COLD/HOT LEG RECIRC monitor lights are dim on XCP-6104. d. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

EOP-15.0

RO Reset both SI RESET TRAIN A(B) Switches.

EOP-15.0

RO Reset Containment Isolation:

RESET PHASE A - TRAIN A(B) CNTMT ISOL. RESET PHASE B - TRAIN A(B) CNTMT ISOL.

EOP-15.0

BOP Place both ESF LOADING SEQ A(B) RESETS to: a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

EOP-15.0

RO Establish Instrument Air to the RB a. Start one Instrument Air Compressor and place the other in Standby.

b. Open PVA-2659, INST AIR TO RB AIR SERV.

c. Open PVT-2660, AIR SPLY TO RB.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 34 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 34 NUREG 1021 Revision 9 NOTE - Step 24

Establishing a continuous RCS bleed and feed as a means of providing a heat sink results in a breach of the RCS. Conditions should be evaluated for reclassifying the event using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

EOP-15.0

CRITICAL

TASK (backup)

RO Establish an RCS bleed path: a. Open all PZR PORV Block Valves, MVG-8000A(B)(C). .

b. Open all PZR PORVs: PCV-445A, PWR RELIEF PCV-445B, PWR RELIEF PCV-444B, PWR RELIEF

EOP-15.0 CAUTION - Step 25

If RB pressure increases to GREATER THAN 12 psig, RB Spray should be verified per EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, Step 8, to prevent loss of containment

integrity.

EOP-15.0

BOP Perform Steps 1 through 8 of EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, while continuing with this procedure.

EOP-15.0

Evaluator Note: Steps 1 through 8 of EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION which

includes Attachment 3 are found at the end of this scenario.

EOP-15.0

Crew Maintain RCS heat removal: Maintain SI flow. Maintain at least two PZR PORVs open.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 35 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 35 NUREG 1021 Revision 9 CAUTION - Step 27

If RWST level decreases to LESS THAN 18%, the SI System should be aligned for Cold Leg

Recirculation using EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION, to maintain an SI

flowpath.

EOP-15.0

• Crew Check if RB Spray should be stopped: a. Check if any RB Spray Pumps are running.

b. Verify RB pressure is LESS THAN 11 psig.

c. Depress both RESET TRAIN A(B) RB SPRAY.

EOP-15.0 NOTE - Step 27.d

RB Spray must run for a minimum of two hours. Anytime RB Spray Pumps are stopped, MVG-3003A(B), SPRAY HDR ISOL LOOP A(B), should be closed for containment isolation.

EOP-15.0

Crew Consult with TSC personnel concerning RB Spray System operation.

EOP-15.0

Booth Operator Instructions: When called as TSC recommend that RB spray be left running.

EOP-15.0 CAUTION - Step 28

RHR Pumps should NOT be run longer than 90 minutes without CCW flow to the RHR Heat

Exchangers, to prevent RHR Pump damage.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 36 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 36 NUREG 1021 Revision 9 NOTE - Step 28

If RCS Thot is stable OR decreasing, feed flow should be established slowly to only one SG until Wide Range level indication increases. Feed flow should be established slowly to prevent excessive RCS cooldown.

EOP-15.0

Crew Continue to try to establish a secondary heat sink in at least one SG REFER TO Step 5 for EFW flow.

OR REFER TO Steps 8 through 11 for Feed and Condensate flow.

OR Consult with TSC personnel to try to establish any available low pressure water source

EOP-15.0

Booth Operator Instructions: If called as TSC as far as setting up a low pressure water source reply that you will work

on a solution.

EOP-15.0

Evaluator Note: The flowing steps return EFW to service using Step 5. Establishing Feed and Condensate

flow using Steps 8-11 follow that.

EOP-15.0

Note - Step 5

If EFW flow control can NOT be reestablished from the Control Room, this procedure should be

continued while local operator action is in progress to restore EFW flow.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 37 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 37 NUREG 1021 Revision 9

Crew Check Control Room indications for the cause of EFW Failure: 4) Verify no EFW annunciators are lit: XCP-621 3-5 (EFP SUCT HDR PRESS LO XFER TO SW). Any alarm on XCP-622 Any alarm on XCP-623

(NO) 5) Verify CST level is GREATER THAN 5 ft. (YES) 6) Ensure power is available to both MD EFW Pumps.

(NO) EOP-15.0

Booth Operator Instructions:

When called to investigate the EFW pumps. R

eport as the IB operator that the overcurrent for MDEFW B is indicated. Report that 2030 will not open (even if asked to manually bleed

air off the valve)

EOP-15.0

CRS Refer to AOP-304.1 to restore power to IDA

(unsuccessful)

. EOP-15.0

BOP Energize XSW1DA from the normal power source: (NOT AVAILABLE)

EOP-15.0

BOP IF XSW1DA normal power source is NOT available, THEN energize

XSW1DA from the alternate power d) Ensure BUS 1DA XFER INIT Switch is in OFF.

e) Close BUS 1DA ALT FEED Breaker.

f) Verify BUS 1DA potential lights are energized.

EOP-15.0 CAUTION -

Step 5.a.4

) EFW valves should NOT be opened to SGs with Wide Range level LESS THAN 15%

[25%]. If Wide Range level in all SGs is LESS THAN

15% [25%], EFW valves should be open to only one SG, until RCS temperatures are decreasing, to limit any failure to one SG.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 38 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 38 NUREG 1021 Revision 9

Crew Ensure all EFW valves are open: (Applies caution and only opens to

one SG) FCV-3531(3541)(3551), MD EFP TO SG A(B)(C). FCV-3536(3546)(3556),TD EFP TO SG A(B)(C).

(TD EFW Pump

not available)

MVG-2802A(B), MS LOOP B(C) TO TD EFP. PVG-2030, STM SPLY TO TD EFP TRN A(B).

(Will not open)

EOP-15.0

Crew Try to restore any EFW flow.

EOP-15.0

Evaluator Note: The flowing steps establishing Feed and Condensate flow using Steps 8-11

EOP-15.0 CAUTION - Step 8

Deaerator Storage Tank level should be monitored closely and maintained between 2.5 ft and

10.5 ft on LI-3135, DEAER STOR TK WR LVL FEET, to prevent tripping Condensate and

Feedwater Booster Pumps.

EOP-15.0

Crew Ensure (at least) one Condensate Pump is running.

EOP-15.0

Crew Ensure two Feedwater Booster Pumps are running.

EOP-15.0

Crew Ensure Main FW Control Valves are closed: FCV-478, A FCV. FCV-488, B FCV. FCV-498, C FCV.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 39 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 39 NUREG 1021 Revision 9

Crew Place all Main FW Bypass Valve Controllers in MAN and closed: FCV-3321,LOOP A MAIN FW BYP. FCV-3331,LOOP B MAIN FW BYP. FCV-3341,LOOP C MAIN FW BYP.

EOP-15.0

Crew Locally place the following key switches in BYPASS (CB-448): XVG01611A,B,C (XPN 7114). IFV03321,3331,3341 TRAIN A (XPN 7115). IFV03321,3331,3341 TRAIN B (XPN 7121).

EOP-15.0

Booth Operator Instructions: When called to place the key switches in BYPASS wait 3 minutes and then do so using

Trigger 7.

EOP-15.0

Crew Verify XCP-612 2-1 is NOT lit (RB PRESS HI-2 STM LINE ISOL).

EOP-15.0 NOTE - Step 8.g

SG B or C is preferred, so that a steam supply for the TD EFP will be restored as soon as

possible. Before the Low Steamline Pressure SI signal is blocked, Main Steam Isolation will occur if the Low Steam Pressure rate setpoint is exceeded.

EOP-15.0

Crew Align the MS Isolation Valves to depressurize only one SG: 3) Verify the MS Isolation Valve, PVM-2801A(B)(C), is open for the SG to be depressurized. 4) Ensure the remaining two MS Isolation Valves, PVM-2801A(B)(C), are closed.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 40 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 40 NUREG 1021 Revision 9

Crew Place the following switches in AUTO: PVG-1611A(B)(C), A(B)(C) ISOL. FCV-3321,3331,3341, FW CNTRL BYP VLVS, Train A Switch. FCV-3321,3331,3341, MAIN FW BYPASS VLVS, Train B Switch.

EOP-15.0

Crew Reset both SI RESET TRAIN A(B) Switches.

EOP-15.0 NOTE - Step 10

Main Feed Pumps trip on SI. If an SI occurs, Steps 9 and 10

should be repeated to restart Main Feed Pumps. (MFPs cannot be reset since the "B" train FWIS is still present.)

EOP-15.0

Crew Verify PERMISV C-9 status lights bright on XCP-6114 1-3.

EOP-15.0

Crew Open MOV-1-5A(B)(C), TURB DRN VLV.

EOP-15.0

CRITICAL

TASK Crew Adjust feed flow to restore SG level.

EOP-15.0 NOTE - Step 11

Step 11 should NOT be performed as long as the Main Feed Pump is supplying sufficient flow to

increase SG level.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 41 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 41 NUREG 1021 Revision 9

Evaluator Note: After restoring a supply of water to the SG's either through Step 5 for the MD EFW Pump or Steps 8-11 for a MFP the scenario can be terminated at the discretion of the Lead

Examiner. The following steps are to reduce SI flow

EOP-15.0

Crew Verify RCS temperatures are decreasing.

EOP-15.0

Crew Verify the SG being used as a secondary heat sink is INTACT: a. Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.

b. Notify Chemistry to sample all SG secondary sides, and screen samples for abnormal activity using a frisker. c. Radiation level is normal on RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR. d. No SG pressure is decreasing in an uncontrolled manner.

e. No SG is completely depressurized.

EOP-15.0

Booth Operator Instructions: When asked to sample the secondary sides of the SG's as Chemistry wait 30 minutes and

then report that all activities are normal.

EOP-15.0 NOTE - Step 31

This procedure should NOT be continued prior to establishing SG Narrow Range level.

EOP-15.0

Crew Verify Narrow Range level is GREATER THAN 26% [41%] in the SG being used as a heat sink

EOP-15.0

Crew Check RCS temperatures: Verify core exit TC temperatures are decreasing Verify RCS Thot is decreasing

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 42 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 42 NUREG 1021 Revision 9

EOP-15.0

Crew Ensure any Reactor Vessel Head Vent Valves opened in Step 24 are closed. EOP-15.0

Crew Check if SI can be terminated: a. Verify RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER

THAN 52.5°F [67.5°F]

. b. Verify RVLIS Narrow Range level is GREATER THAN 61%

c. GO TO STEP 36

EOP-15.0 NOTE - Step 35

It is preferred to meet the termination criteria with at least one PORV open.

EOP-15.0

Crew Check PZR POR Status: a. Check if any PZR PORV and its associated Block Valve is open.

b. Close one PZR PORV and place in AUTO. c. Wait for RCS subcooling to increase to GREATER THAN 80°F or to stabilize. d. RETURN TO Step 34.

EOP-15.0

Evaluator Note: Crew will check for SI termination criteria while closing one PORV at a time in the loop

created in the proceeding steps.

EOP-15.0

Crew Stop all but one Charging Pump.

EOP-15.0

Crew If an PZR PORV's are open, ensure that only one is left open.

EOP-15.0

2011 NRC Scenario 1 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 1 Event # Events 6,7,8 Page 43 of 43 Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicant's Actions or Behavior

Appendix D 43 NUREG 1021 Revision 9

Crew Establish Normal Charging: a. Close FCV-122, CHG FLOW. b. Open both MVG-8107 and MVG-8108, CHG LINE ISOL.

c. Adjust FCV-122, CHG FLOW, to obtain 60 gpm Charging flow.

d. Close all PZR PORVs and place ' d. IF any PZR PORV can NOT be

in AUTO. e. Close both MVG-8801A(B), HI HEAD TO COLD LEG INJ.

EOP-15.0 After restoring a supply of water to the SG's either through Step 5 for the MD EFW Pump or Steps 8-11 for a MFP the scenario can be terminated at the discretion of the Lead

Examiner.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Appendix D 1 NUREG 1021 Revision 9 Facility: VC SUMMER Scenario

No.:2 Op Test No.: 2011 NRC Examiners: Operators: CRS RO BOP Initial Conditions: IC-39, 2% Power, BOL GOP-4A,

Step 3.5.c and SOP-214 step 2.10.a "B" EDG is OOS to clean the lube oil strainer "B" RB spray pump is out of service for bearing replacement National Weather Service has issued a severe weather alert due to a line of heavy thunderstorms moving into the area Turnover: Complete chest warmup of turbine using provided ramp rate Remain in MODE 2 until EDG is OPERABLE Dilute 100 gallons to adjust rod position per RX Engineering plan Condensate polishing is in service Critical Tasks: Isolate EFW to the faulted within 10 minutes (FSAR 15.4.2.1.4.b.1)

Restore "A" RB Spray flowpath or cooling to "B" train RB Cooling Unit prior to completion of Attachment 3

Event No. Malf. No. Event Type* Event Description 1. R-RO Dilutes 100 gallons 2. N-BOP,CRS Warm Main Turbine 3. NIS008A TS-CRS Intermediate range channel NI35 and Source Range NI31 fail low

4. ANN-TS001 C-CRS, BOP Main Transformer high side OCB gas pressure 75 psig, crew should transfer BOP busses to Emerg Aux transformers and open the OCB BOP2 5. MSS012 C-BOP, CRS Condenser steam dumps drift closed due to PT464 failure

BOP1 6. AUX 14A&B C-RO, CRS Loss of Instrument Air

RO1 7. CVC004A

C - RO, CRS TS- CRS Progressive failure of RCP "A" #1 seal towards 100 gpm over a 15 minute

ramp RO2 8. N/A N-BOP,CRS Shutdown plant to MODE 3 due to only 2 RCPs in service 9. MSS003C M-ALL DBA Main Steamline Break inside Reactor Building "C" SG 10. PCS006A C- BOP, CRS Failure of Train A Phase A signal prevents spray from "A" train 11. PMP-SW006F C- RO, CRS "B" SWBP fails to autostart Terminate set after SI flow terminated, RCS temperature controlled, and RB cooling restored * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Appendix D 2 NUREG 1021 Revision 9 VC Summer NRC Scenario #2

The crew will assume the watch having pre-briefed on the Initial Conditions (stable in MODE 2, rods in MANUAL, on Emergency Feedwater) The plan for this shift is to warm the Main Turbine per SOP-214 and GOP-4A.

The Reactor Operator will dilute 100 gallons as recommended by Reactor Engineering.

Turbine chest Warming is conducted per SOP-214. This exercises reactor power control with MANUAL rod control as heat load varies.

When Makeup Control is Back in AUTO, the Lead Evaluator can cue Intermediate Range

channel N35 failing low (this loss of high voltage also removes indication from source range

GammaMetrics channel N31). The CRS will evaluate Technical Specifications 3.3.1 and 3.3.3.6.

Annunciator XCP-638, MN XFMR OCB 8902 TROUBLE will indicate dropping SF

6 pressure in the Main Transformer High Side breaker. The System Controller will direct opening the breaker,

which requires transfer of the Balance of Plant busses to the Emergency Aux transformer.

After the BOP busses have been transferred to alternate power, the Lead Evaluator can cue the failure of the Main Steam header pressure transmitter drifting low, which will cause the steam

dumps to drift closed in AUTO. Operators will restore temperature control by either controlling the steam dumps in MANUAL or turning the steam dumps off and controlling the SG PORVs.

The running Instrument Air compressor trips with a failure of the Standby

and Supplemental

compressors to autostart. The RO can manually start the supplemental IA compressor from the

main control board.

Reactor Coolant Pump "A" #1 seal fails, ramp to 100 gpm. Crew will stop the "A" RCP and

isolate #1 seal leakoff per AOP-101.2 REACTO

R COOLANT PUMP SEAL FAILURE. This will complicate pressure control later since the "A"

loop provides the most effective Pressurizer spray. The crew will shutdown the plant due to having only 2 Reactor Coolant loops in

operation. A Design Basis Main Steamline Break will occur on the "C" loop, requiring transition to EOP-3.0 FAULTED STEAM GENERATOR ISOLATION and possibly EOP-16.0 RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK. Failure of the available RB spray pump and

one Service Water Booster Pump (RB Cooling Unit supply) will require operator actions to limit Reactor Building pressure increases.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Appendix D 3 NUREG 1021 Revision 9

VCS 2011 NRC Scenario 2 Simulator Setup (SNAP 302 or 306)

Initial Conditions:

IC-39, 2% power, BOL GOP-4A step 3.5 Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires). Conduct two-minute drill Mark up procedures in use with "Circle and slash" as applicable

Pre-Exercise:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch

malfunctions, chart recorders, etc.)

TQP-801 Booth Operator checklist, has been completed

Hang red tags for equipment out of service

PRE-LOAD

LOA AUX 118 = RACK OUT "B" RB Spray pump breaker Malfunction PCS006A = FAILURE TO INIT "A" train Containment Phase A PMP SW006F "B" SWBP fails to autostart LOA-EPS114 = MAINTENANCE ("B" EDG OOS) PMP-IA002F IA compressor B fails to auto start BST-IA001 = FAIL AS IS prevents autostart of Supplemental IA compressor

EVENT 1: Dilute the RCS

No simulator manipulations required Crew will dilute 100 gallons

EVENT 2: Warm the main turbine

No simulator manipulations required

EVENT 3: Loss of N31 and N35 Source and Intermediate range Instruments

Trigger 3, Insert Malfunction NIS008A Repairs will not be made during scenario, I&C troubleshooting

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Appendix D 4 NUREG 1021 Revision 9

EVENT 4: SF

6 leak on Main Transformer High Side Breaker 8902

Trigger 4 Override ANN TS001 = ON System Controller agrees with opening breaker This will require the crew to transfer the Balance of Plant busses to the Emergency

Auxiliary transformers

EVENT 5: Steam dumps fail closed

Trigger 5 Malfunction MSS012 = 0 psig 2 minute ramp

EVENT 6 Loss of Instrument Air

Trigger 6 Malfunction AUX 14 A Trip of Instrument Air Compressor Trigger 14, LOA AUX-110, 2 minute time delay, starts the Diesel air compressor

EVENT 7: Reactor Coolant Pump "A" #1 seal failure

Trigger 7, Malfunction CVC004A=100 gpm, 15 minute ramp Crew will call for installation of fuse for leakoff isolation valve 8141A (insert and remove malfunction VLV CS052W) Trigger 11, LOA-CVC038, V 8369A - SEAL INJECTION THROTTLE VALVE = 0.75

EVENT 8: Shutdown plant to MODE 3

No simulator manipulations required Crew must shutdown in one hour due to Technical Specifications

EVENT 9: Large steamline break inside the Reactor Building

Trigger 9, Insert malfunction MSS003C = 12E6 over a 6

15 minute ramp Crew may attempt local opening of MVG-3003A, VLV-SP005P = 100% 1 minute ramp

Local action to replace fuse 75 for PVT-8141A

Insert and remove malfunction VLV-CS052W

or use "install Fuses PVT-8141A" button on the LOA/RESET panel

Local action to throttle seal injection

Insert trigger 11 LOA-CVC038, adjust as requested

Local action to gag closed SW to CCW surge tank (not expected due to air bottles at

valves) Insert trigger 12 VLV-CC018P & CC019P = 0% (9627A&B closed)

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Appendix D 5 NUREG 1021 Revision 9 Local action to open XVG-3003A spray header isolation valve

Insert trigger 13 VLV-SP005P = 100%, 1 minute ramp, adjust as requested

Local action to start diesel air compressor

Insert Trigger 14 LOA AUX110 Start Diesel Air Compressor & open PVG-2670

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 1 Page 6 of 38 Event Description: Dilute 100 gallons

Time Position Applicant's Actions or Behavior

Appendix D 6 NUREG 1021 Revision 9

Booth Operator Instructions:

No action required for event 1. Check turnover sheet has method 10.e.D reference position 0.3%, ramp 0.1%/second

Evaluator Note:

This event could also occur during events 2 or 3.

SOP-106 section E.1

RO Verifies sufficient volume exists in the Recycle Holdup Tanks to receive Reactor Coolant displaced during planned dilution operation.

SOP NOTE 2.0

1. Energizing additional Pressurizer Heaters will enhance mixing.

2. LCV-115A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70% level on LI-115, VCT LEVEL %.

SOP RO Verify at least one Reactor Coolant Pump is running.

SOP RO Place RX COOL SYS MU switch to STOP.

SOP RO Place RX COOL SYS MU MODE SELECT switch to ALT DIL.

(Peer ) SOP RO Adjust FCV-168, TOTAL MU FLOW SET PT, to desired flow rate.

SOP RO Set FIS-168, TOTAL MU FLOW, batch integrator to desired volume.

(Peer ) SOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 1 Page 7 of 38 Event Description: Dilute 100 gallons

Time Position Applicant's Actions or Behavior

Appendix D 7 NUREG 1021 Revision 9

RO Place RX COOL SYS MU switch to START.

SOP RO Verify desired flow rate on FR-113, TOTAL MU GPM (F-168).

SOP RO Verify alternate dilution stops when preset volume is reached on FIS-168, TOTAL MU FLOW, batch integrator.

SOP RO Place RX COOL SYS MU switch to STOP.

SOP RO Place RX COOL SYS MU MODE SELECT switch to AUTO.

(Peer ) SOP RO Adjust FCV-168, TOTAL MU FLOW SET PT, to 7.5 turns (120 gpm).

SOP RO Place RX COOL SYS MU switch to START.

SOP When reactor makeup is returned to automatic control, proceed to the next event.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 2 Page 8 of 38 Event Description: Warm the main turbine control valve chest

Time Position Applicant's Actions or Behavior

Appendix D 8 NUREG 1021 Revision 9

Booth Operator Instructions:

No action required for event 2

Indications available:

None Applicable

SOP-214 section III.2.10 BOP Ensure MSV2 Position indicates a negative % value.

SOP BOP Select ON on Chest Warming, (a dialog box opens).

SOP BOP Select OK.

1) Verify the following: a) MSVs 1, 3, and 4 indicate 0%.

b) MSV 2 remains at the indicated negative value. c) CVs 1- 4 indicate 0% d) IVs 1 - 4 indicate 0%

e) ISVs 1 - 4 go to 100%.

SOP BOP Close MVG-2897, COMB CNTRL VLV BSD

SOP BOP e. Slowly open MSV2 on the Control/Pre-warming screen, while maintaining differential temperature between CV Chest Inner and CV

Chest Outer less than 150°F by one of the following methods:

SOP Booth operator instructions; if contacted as Shift Supervisor, direct positioning MSV2 0.3% open at a 0.1% per minute ramp

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 2 Page 9 of 38 Event Description: Warm the main turbine control valve chest

Time Position Applicant's Actions or Behavior

Appendix D 9 NUREG 1021 Revision 9

SOP BOP 1) Open MSV2 to warm the inner chest to 350°F by

a) Select

Ramp Rate (a dialog box opens).

b) Enter

0.1%/minute

, select OK. c) Confirm setpoint change, select OK.

f) Select position

g) enter

0.3%. h) Select OK

i) confirm setpoint

j) Select OK

k) Verify proper system operation

. SOP Lead Examiner may direct initiation of the next event at his discretion

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 3 Page 10 of 38 Event Description: Intermediate channel N35 and source range N31 fail low

Time Position Applicant's Actions or Behavior

Appendix D 10 NUREG 1021 Revision 9

Booth Operator Instructions:

When directed insert malfunction for Event 3 (Trigger 3)

Indications available: XCP-620 3-1 SR/IR DETECTOR TROUBLE I

Crew Refer to alarm response procedure ARP-001-XCP-620 3-1

ARP-001-XCP-620 3-1

PROBABLE CAUSE: 1. Loss of Instrument power or blown Instrument power fuse. 2. Intermediate Range channel N35 S-3 test switch in test (located inside Intermediate Range drawer).

ARP AUTOMATIC ACTIONS:

1. None.

ARP CORRECTIVE ACTIONS:

CRS Refer to AOP-401.8, Intermediate Range Channel Failure, and to AOP-401.9, Source Range Channel Failure

ARP NOTE Startup is not allowed with less than 2 Source Range channels operable.

ARP SUPPLEMENTAL ACTIONS:

CRS Refer to Technical Specification Table 3.3-1 for instrumentation

requirements.

ARP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 3 Page 11 of 38 Event Description: Intermediate channel N35 and source range N31 fail low

Time Position Applicant's Actions or Behavior

Appendix D 11 NUREG 1021 Revision 9 CRS Enters AOP-401.8, Intermediate Range Channel Failure

AOP-401.8 RO Stabilize reactor power at the current level AOP-401.8

RO Bypass the failed Intermediate Range level channel Place LEVEL TRIP switch for affected channel in BYPASS Verify IR&SR TRIP BYP (XCP-620, 4-5) is LIT AOP-401.8 RO Check if reactor power is less than 7.5X10

-6% (NO) AOP-401.8 RO Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, verify P-6 is BRIGHT AOP-401.8 RO Maintain reactor power less than 5% AOP-401.8 RO Monitor the operable Intermediate Range channel AOP-401.8 RO Ensure NR-45 is selected to the operable channels

(NO) AOP-401.8

CRS Refer to Technical Specifications TS 3.3.1 action 3 for Functional Unit 5 Tech Specs CRS Enters AOP-401.9, SO

URCE RANGE CHANNEL FAILURE

AOP-401.9

IOA CRS Stop all core alterations (N/A).

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 3 Page 12 of 38 Event Description: Intermediate channel N35 and source range N31 fail low

Time Position Applicant's Actions or Behavior

Appendix D 12 NUREG 1021 Revision 9

AOP-401.9

IOA CRS/RO Stop all positive reactivity additions.

AOP-401.9

RO Verify NI-31 OR NI-32 is operable

(N32 is). AOP-401.9

RO Check if the Reactor Building evacuation alarm has actuated: (NO) GO TO Step 6.

AOP-401.9

RO Bypass the failed Source Range channel: a. Place LEVEL TRIP Switch for the AFFECTED channel in BYPASS. b. Verify IR&SR TRIP BYP (XCP-620 4-5), annunciator is lit.

AOP-401.9

RO Block Source Range High Flux At Shutdown: a. Place HIGH FLUX AT SHUTDOWN Switch for the AFFECTED channel in BLOCK. b. Verify SR HIGH FLUX AT SHUTDN BLOCK (XCP-620 4-4),

AOP-401.9

RO Monitor an operable NI channel

(N32). AOP-401.9

RO Ensure NR-45 is selected to the appropriate operable channels. AOP-401.9

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 3 Page 13 of 38 Event Description: Intermediate channel N35 and source range N31 fail low

Time Position Applicant's Actions or Behavior

Appendix D 13 NUREG 1021 Revision 9

CRS Determines from TS table 3.3-1 that item 5. Requires action 3 and entry into MODE 1 is not permitted (MODE change with LCO not met).

ACTION 3 - With the number of channels OPERABLE one less than the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below the P-6 (Intermediate Range Neutron Flux Interlock) setpoint,

restore the inoperable channel to OPERABLE status prior to

increasing THERMAL POWER above the P-6 Setpoint.

(N/A) b. Above the P-6 (Intermediate Range Neutron Flux Interlock) setpoint but below 10 percent of RATED THERMAL POWER, restore the

inoperable channel to OPERABLE status prior to increasing

THERMAL POWER above 10 percent

of RATED THERMAL POWER. (YES) Tech Specs

Crew Conducts post-event brief and contacts SS. May contact I&C for assistance.

On Lead Examiners cue, proceed to the next event.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 14 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 14 NUREG 1021 Revision 9

Booth Instructor:

When directed, initiate Event 4 (Trigger 4)

Indications available:

XCP-638 1-1, MN XFMR OCB 8902 TROUBLE

ARP XCP-638 1-1

Crew Refer to alarm response procedure ARP-001-XCP-638 1-1

ARP PROBABLE CAUSE: 1. Spring charge pump failure.

2. SF6 gas leak. 3. Blown rupture disc.

ARP NOTE 1. Breaker closure is disabled upon either of the following conditions: a. Spring charge is less than 32.5 mm.

b. SF6 gas pressure is less than 74 psig at 68°F. 2. Breaker trip is disabled by SF

6 gas pressure less than 72 psig at 68°F. 3. If SF6 gas pressure is reduced to less than 74 psig, Switchyard personnel must reset the local SF

6 Lockout Relay to re-enable breaker closure.

ARP AUTOMATIC ACTIONS:

1. None.

ARP CORRECTIVE ACTIONS:

Crew 1. Dispatch an operator to verify the following: a. SF6 gas density is greater than 90%. b. Spring charge indicator is in the ENERGY STORAGE position.

c. SF6 gas pressure compared to SF

6 gas temperature is normal per characteristic chart. ARP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 15 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 15 NUREG 1021 Revision 9

Booth Operator Instructions: When called to investigate OCB8902 report that gas density is 97%, the spring charge indicator is in

the ENERGY STORAGE position, and that gas pressure is 75 psig dropping slowly at 68 °F outside.

ARP SUPPLEMENTAL ACTIONS: BOP Notify the System Controller of problem.

ARP Booth Operator Instructions: When called as system controller, ask for recommendation on opening OCB 8902. Concur with

recommendation: if it is to open, give switching order number as 002 and state that email will follow.

BOP Enters SOP-304, 115KV/7.2KV OPERATIONS,Section IV.A TRANSFERRING BOP BUSES FROM NORMAL TO ALTERNATE FEED

SOP-304 Section IV.A BOP Verifies that the AUTO-MAN XFER Switch for each Balance of Plant bus is in AUTO.

SOP BOP Verifies that XTF0031 and XTF0032, EMERGENCY AUXILIARY TRANSFORMER #1 and #2, are in service per SOP-302.

SOP BOP Determines that conditions exist which require removal of normal feed for the buses.

SOP BOP Verifies that XTF0001, MAIN TRANSFORMER, and XTF0002, UNIT AUXILIARY TRANSFORMER, are in service per SOP-302.

SOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 16 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 16 NUREG 1021 Revision 9 NOTE 2.1 through 2.3

a. When BUS 1A, 1B, or 1C is aligned to its alternate feed, automatic transfer to its normal feed is not

available. b. When transferring the bus, there is a delay while the bus synchronizes. Hold the switch in the closed position until the breaker closes.

SOP BOP Place BUS 1A AUTO-MAN XFER Switch in MAN.

SOP BOP Close BUS 1A ALT FEED breaker.

(PEER ) SOP BOP Open BUS 1A NORM FEED breaker.

(PEER ) SOP BOP Verify BUS 1A potential lights remain lit.

SOP BOP Place BUS 1A AUTO-MAN XFER Switch in AUTO. (PEER ) SOP BOP Place BUS 1B AUTO-MAN XFER Switch in MAN.

SOP BOP Close BUS 1B ALT FEED breaker.

(PEER ) SOP BOP Open BUS 1B NORM FEED breaker.

(PEER ) SOP BOP Verify BUS 1B potential lights remain lit.

SOP BOP Place BUS 1B AUTO-MAN XFER Switch in AUTO. (PEER )

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 17 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 17 NUREG 1021 Revision 9

SOP NOTE 2.3.a and 2.3.b

When placing XSW1C on alternate feed during time critical situations, Steps 2.3.a and 2.3.b shall be done at the end of the transfer. By skipping these steps the bus may be inoperable due to not meeting voltage

requirements or Real Time Contingency Analysis.

SOP BOP Place BUS 1C AUTO-MAN XFER Switch in MAN.

SOP BOP Close BUS 1C ALT FEED breaker.

(PEER ) SOP BOP Open BUS 1C NORM FEED breaker.

(PEER ) SOP BOP Verify BUS 1C potential lights remain lit.

SOP BOP Place BUS 1C AUTO-MAN XFER Switch in AUTO. (PEER ) SOP BOP Open OCB 8902

ARP Booth operator instructions; if contacted again as Unit 5, report SF

6 pressure as 74 psig and still dropping slowly (do not report less than 72 psig since that would prevent breaker operation).

BOP Determine bus voltage limits from Enclosure B

(next page

) Lower Limit = 219.0 KV Upper Limit = 239.6 KV

SOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 18 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 18 NUREG 1021 Revision 9

BOP Notify the System Controller of the applicable bus voltage limits from Enclosure B.

SOP Booth Operator Instructions: When called as System Controller acknowledge bus voltage limits.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 4 Page 19 of 38 Event Description: High side OCB losses SF

6 pressure

Time Position Applicant's Actions or Behavior

Appendix D 19 NUREG 1021 Revision 9

BOP If required, adjust the 115KV and/or 230KV alarm setpoints per Attachment VA and/or Attachment VB for the current lineup.

SOP Evaluator Note: Cue crew that setpoints will be changed by the control building operator.

Simulator Setpoint monitor is different than one used in the plant. Setpoint adjustment is not required

during transients on the simulator.

Crew Conducts post-event brief and notifies SS.

On Lead Examiner's cue, proceed to the next event

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 5 Page 20 of 38 Event Description: Condenser steam dumps drift closed due to PT464 failure

Time Position Applicant's Actions or Behavior

Appendix D 20 NUREG 1021 Revision 9

Booth Operator Instructions:

When directed insert malfunction for Event 5 (Trigger 5)

Indications available: XCP-615 Pt 1-5 RCS TAVG DEV HI/LO OPCRIT alarm for steam dump valves closed

XCP-615 Pt 1-5

RO Identifies excessive RCS heatup (temperature rises until SG PORVs lift,

approx. 564°F).

BOP/CRS Identifies zero output (demand) from steam dump controller. Controller does not respond in AUTO.

BOP Opens steam dumps in MANUAL

BOP Verifies SG PORVs close if open

Crew Conducts post-event brief and notifies SS. May request I&C assistance due to failed instrument (must prioritize NIS work vs. steam dump control.)

On Lead Examiner's cue that temperature is stable, proceed to the next event

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 6 Page 21 of 38 Event Description: Trip of running IA compressor, standby doesn't start

Time Position Applicant's Actions or Behavior

Appendix D 21 NUREG 1021 Revision 9

Booth Operator Instructions:

When directed insert Trigger 6

Indication available: XCP-606 2-1, INSTR AIR CMPR A TRBL XCP-607 2-5, INSTR AIR PRESS LO FLO HI

XCP-607 2-6, SEVR AIR PRESS LO

XCP-607 2-1, INSTR AIR CMPR B TRBL

Crew Refer to Alarm Response Procedure ARP-001-606 2-1

ARP-XCP-606 pt. 2-1

AUTOMATIC ACTIONS: 1. Instrument Air Compressor A will trip

2. Instrument Air Compressor B will start automatically on low receiver tank pressure at 90 psig and cycle between 105 psig and

115 psig.

ARP NOTE This alarm has reflash capabilities.

ARP CORRECTIVE ACTIONS:

RO If Instrument Air Compressor A trips, ensure the standby air compressor

starts. (WON'T)

ARP RO Dispatch an operator to Instrument Air Compressor A to determine the cause of the alarm.

ARP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 6 Page 22 of 38 Event Description: Trip of running IA compressor, standby doesn't start

Time Position Applicant's Actions or Behavior

Appendix D 22 NUREG 1021 Revision 9

Booth Operator Instructions: When sent to the A, B, and Supplemental air compressors report that A tripped on low oil

pressure and has a oil leak, and B had a starter fault, and that

there is no apparent problem with the supplemental air compressor tripped on overcurrent.

CRS Enters AOP-220.1, LOSS OF INSTRUMENT AIR

Enters AOP-220.1 CAUTION

If a Reactor Trip or SI Actuation occurs during this procedure, EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, should be performed while continuing with this procedure.

AOP RO Ensure the standby Instrument Air Compressor is running.

(NO) AOP RO Check if Instrument Air header pressure is increasing.

(NO) AOP RO Start XAC-12-IA, SUPP INST AIR COMPRESSOR. (YES) AOP RO May locally start the Diesel Driven Air Compressor. (conservative until Supplemental verified running sat and to supply Service Air.) REFER TO SOP-220,STATION AND BACKUP INSTRUMENT AIR SYSTEMS.

AOP Booth Operator Instructions: When called to start the diesel driven air compressor, insert trigger 14 and report that it

starts. (LOA AUX-110 starts the diesel air compressor and connects it to the IA system). CRS Returns to procedure and step in effect (SOP-214 for chest warming)

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event # 6 Page 23 of 38 Event Description: Trip of running IA compressor, standby doesn't start

Time Position Applicant's Actions or Behavior

Appendix D 23 NUREG 1021 Revision 9

AOP Crew Performs post-event brief and contacts SS. May contact mechanical

maintenance for compressor troubleshooting.

At the discretion of the lead examiner proceed to the next event

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 24 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 24 NUREG 1021 Revision 9

Booth Instructor:

When directed, initiate Event 7 (Trigger 7)

Indications available: XCP-603, 1-1, RCP A CCW TEMP HI XCP-617, 2-1, RCP A #1 SL LKOFF FLO HI/LO

XCP-617, 2-4, RCP A STANDPIPE LVL HI/LO

XCP-618, 2-2, RCP B #1 SL INJ FLO LO

XCP-619, 2-2, RCP C #1 SL INJ FLO LO

Seal leakoff flow on RCP "A" rising to off-scale high

Crew Refer to Alarm Response Procedures

ARP XCP-617, 2-1

RO Determines RCP A #1 Seal Leakoff is rising rapidly

ARP CRS Enters AOP-101.2, Reactor Coolant Pump Seal Failure

Enters AOP-101.2 CAUTION PVT-8141A, A SEAL LKOFF, should be closed between three minutes and five minutes after the

affected Reactor Coolant Pump is secured.

Reactor Coolant System Controlled Leakage should be limited to 33 gpm per Technical Specification 3.4.6.2 in Modes 1, 2, 3, and 4.

AOP CRS While continuing with this procedure, have an operator install the pre-staged fuses for the AFFECTED RCP's Seal Leakoff Valve in Main

Control Board Panel XCP-6109 Subpanel #5: XVT-8141A-FU-CS75.

AOP Booth Operator Instructions: Use LOA Resets page to install fuses for PVT-8141A-FU-CS75

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 25 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 25 NUREG 1021 Revision 9

AOP RO Ensure seal injection flow is GREATER THAN 8 gpm for the affected Reactor Coolant Pump on FI-130A, RCP A INJ FLO GPM.

AOP RO Ensure Component Cooling Water flow to the affected Reactor Coolant Pump thermal barrier is between 35 gpm (50%) and 60 gpm (87.5%) on

FM-7138, RCP THERM BAR A (MODUFLASH M2 CC POINTS 19).

AOP CRS Check the following conditions for the affected Reactor Coolant Pump

on the IPCS: Bearing water temperature (LOWER SEAL WTR BRG T) on T0417A is LESS THAN 225°F and NOT significantly increasing.

AND #1 seal leakoff temperature (SEAL WTR OUT TEMP) on T0181A is LESS THAN 235°F and NOT significantly increasing (NO). GO TO STEP 6

AOP NOTE - Step 6 -

When PVT-8141A, A SEAL LKOFF, is closed, the #1 seal P indication will be unreliable.

AOP Crew Check if Reactor power is GREATER THAN 38% (Reactor Permissive P-8, REACTOR TRIP BLOCKED, is dim). (

NO) AOP RO Stop the affected Reactor Coolant Pump (A) AOP Note: The BOP may place A Feedwater Regulating Valve in MANUAL to control level swings caused by stopping A RCP. The NROATC may place the "A" spray valve PCV 444D, PZR SPRAY, in MANUAL and 0%

per SOP-101

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 26 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 26 NUREG 1021 Revision 9

AOP RO/CRS Perform the following for the affected Reactor Coolant Pump: Close PVT-8141A, A SEAL LKOFF, between three to five

minutes. Increase seal injection flow to 13 gpm to the affected Reactor Coolant Pump by locally unlocking and throttling one of the

following:

o XVN08369A-CS, RCP A SEAL SUPPLY THROTTLE

VALVE (AB-412 West Pen).

AOP Booth Operator Instructions: When called to throttle seal supply use trigger 11 LOA-CVC038, V 8369A - SEAL

INJECTION THROTTLE VALVE, to do so.

AOP CRS Within one hour, shut down the plant to hot standby. GO TO the appropriate GOP: GOP-5, REACTOR SHUTDOWN FROM STARTUP

TO HOT STANDBY (MODE 2 TO MODE 3).

Enters GOP-5 section 3

CRS Complete GTP-702 Attachment II.K, Operational Mode Change Plant

Shutdown - Entering Mode 3 Or Plant Trip To Mode 3 From Modes 1 Or

2. GOP CRS Perform a Mode Change Brief per OAP-100.4 Attachment I. The SS and System Controller would notified at some point during this transient.

GOP RO Select both Intermediate Range Channels on NR-45, NIS RECORDER.

GOP NOTE 3.4 through 3.5

Control Rods are inserted using Step 3.4 or Step 3.5. Step 3.4 inserts Control Rods via a Manual Reactor Trip. Step 3.5 manually inserts Control Rods.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 27 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 27 NUREG 1021 Revision 9

GOP NOTE 3.4

If performing a manual boration prior to manually tripping the Reactor, consider performance of STP-130.004C, EMERGENCY BORATION VALVE

OPERABILITY TESTING (MODE 4) during the boration.

GOP CRS Perform a Pre-job brief per OAP-100.3, Human Performance Tools.

GOP RO Select one Intermediate Range and one Source Range Channel on NR-45, NIS RECORDER.

GOP BOP Ensure both Motor Driven Emergency Feedwater Pumps are running.

GOP RO (Optional) If desired, commence RCS boration prior to performing a manual Reactor trip: 1) Open MVT-8104, EMERG BORATE.

2) Ensure XPP-13A(B), BA XFER PP A(B),is running.

GOP NOTE 3.4.d.3)

The expectation is to trip the Reactor following verification of greater than 30 gpm flow on FI-110,

EMERG BORATE FLOW GPM. Subsequent steps, 3.4.d.4) through 6) may be performed after

verification of Reactor trip.

GOP RO Verify greater than 30 gpm flow on FI-110, EMERG BORATE FLOW GPM. GOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 28 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 28 NUREG 1021 Revision 9 NOTE 3.4.d.4)

Emergency boration to the STP-134.001, Shutdown Margin Verification, determined Required Boron concentration is not required prior to tripping the Reactor per Step 3.4.e.

GOP RO Refer to STP-134.001, Shutdown Margin Verification, to determine the required boron concentration needed for the anticipated Plant Mode and

temperature:

GOP Booth operator instructions; if contacted as the Shift Engineer, report required C

B is 1589

ppm. RO Borate the outage Mixed Bed Demineralizer by placing in service per

SOP-102,Section IV.

(N/A) GOP RO When boration is no longer desired, perform the following:

a) Close MVT-8104, EMERG BORATE.

b) Verify no flow on FI-110, EMERG BORATE FLOW GPM.

GOP RO Place RX TRIP Switch CS-CR01 in TRIP.

GOP RO Verify all Reactor Trip and Bypass Breakers are open.

GOP RO Verify all Rod Bottom lights are lit.

GOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 29 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 29 NUREG 1021 Revision 9

RO If two or more Control Rods are not fully inserted, then emergency

borate as follows:

(N/A) 1) Open MVT-8104, EMERG BORATE. 2) Verify greater than 30 gpm flow on FI-110, EMERG BORATE

FLOW GPM. 3) If required, refer to AOP-106.1, Emergency Boration, to establish

greater than 30 gpm flow. 4) Borate 2500 gallons if two Control Rods are not fully inserted.

5) Borate 5800 gallons if greater than two Control Rods are not fully inserted.

GOP RO Verify Reactor Power level is decreasing.

GOP BOP Ensure RCS temperature is being maintained between 555°F and 559°F using the Steam Dump System or Steamline PORVs.

GOP RO Place both SOURCE RANGE HIGH FLUX AT SHUTDOWN Switches in

BLOCK. GOP When Reactor Power decreases below 7.5 x 10

-6%, complete the

following: 1) Verify P6 Permissive de-energizes to dim.

2) When on scale indication is observed, select both Source Range Channels on NR-45, NIS RECORDER.

GOP CRS Proceed to Step 3.7.

GOP RO Monitor Source Range counts per SOP-404, Excore Nuclear Instrumentation System.

GOP

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 7&8 Page 30 of 38 Event Description: Progressive Failure of RCP "A" #1 seal, shutdown to MODE 3

Time Position Applicant's Actions or Behavior

Appendix D 30 NUREG 1021 Revision 9 CAUTION 3.8

Shutdown Margin may decrease by as much as 3000 pcm due to Xenon decay over a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period. Any deviation from the conditions used in the Shutdown Margin calculation requires reverification of adequate Shutdown Margin.

GOP At the discretion of the lead examiner proceed to the next event

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 31 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 31 NUREG 1021 Revision 9

Booth Operator Instructions:

When directed, initiate Event 9 (Trigger 9)

Indications available: Safety Injection

Enters EOP-1.0 CRS Enters EOP-1.0, Reactor Trip/Safety Injection Actuation

EOP-1.0 IOA RO Verify Reactor Trip: Trip the Reactor using either Reactor Trip Switch. Verify all Reactor Trip and Bypass Breakers are open. Verify all Rod Bottom Lights are lit. Verify Reactor Power level is decreasing.

EOP-1.0 IOA BOP Verify Turbine/Generator Trip: a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay): 1) Ensure the GEN BKR is open. 2) Ensure the GEN FIELD BKR is open. 3) Ensure the EXC FIELD CNTRL is tripped.

EOP-1.0 IOA BOP Verify both ESF buses are energized.

EOP-1.0 IOA RO Check if SI is actuated: a. Check if either: SI ACT status light is bright on XCP-6107 1-1.

Or Any red first out SI annunciator is lit on XCP-626 top row. b. Actuate SI using either SI ACTUATION Switch

EOP-1.0 BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 32 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 32 NUREG 1021 Revision 9

EOP-1.0 Evaluator Note: The steps for Attachment 3, SI EQUIPMENT VERIFICATION can be found at the end of this

scenario guide. (after page 38)

EOP-1.0 Crew Announce plant conditions over the page system.

EOP-1.0 RO Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB PSIG (P-951), red pen. (NO) EOP-1.0 RO Verify both the following annunciators are lit: XCP-612 3-2 (RB SPR ACT). XCP-612 4-2 (PHASE B ISOL).

EOP-1.0 RO Verify Phase B Isolation by ensuring RB SPRAY/PHASE B ISOL monitor lights are bright on XCP-6105.

EOP-1.0 CRITICAL

TASK RO Ensure the following are open: MVG-3001A(B), RWST TO SPRAY PUMP A(B) SUCT. MVG-3002A(B), NAOH TO SPRAY PUMP A(B) SUCT. MVG-3003A(B), SPRAY HDR ISOL LOOP A(B). (NO) EOP-1.0 RO Ensure both RB Spray Pumps are running.

EOP-1.0 RO Stop all RCPs.

EOP-1.0

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 33 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 33 NUREG 1021 Revision 9

RO Check RCS temperatures: With no RCP running, RCS Tcold is stable at OR trending to 557°F. (NO) EOP-1.0 RO Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

EOP-1.0 RO Continue to direct local throttling of EFW or if IA is restored throttle EFW.

EOP-1.0 BOP Initiate ATTACHMENT 6, STEAM VALVE ISOLATION,

while continuing with this procedure.

EOP-1.0 RO Check if PZR PORVs are closed.

EOP-1.0 RO Check if PZR Spray Valves are closed.

EOP-1.0 RO Verify power is available to at least one PZR PORV Block Valve: MVG-8000A, RELIEF 445 A ISOL. MVG-8000B, RELIEF 444 B ISOL. MVG-8000C, RELIEF 445 B ISOL

EOP-1.0 RO Verify at least one PZR PORV Block Valve is open.

EOP-1.0 NOTE - Step 11

Seal Injection flow should be maintained to all RCPs.

EOP-1.0 RO Check if RCPs should be stopped: (RCP's already stopped)

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 34 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 34 NUREG 1021 Revision 9

EOP-1.0 RO Verify no SG is FAULTED: No SG pressure is decreasing in an uncontrolled manner. No SG is completely depressurized.

(NO) EOP-1.0 CRS GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.

Exits EOP-1.0

CRS Transition to EOP-16.0, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK, based on red path.

Enters EOP-16.0

Note Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN. EOP-16.0 CAUTION - Step 1

If the TD EFW Pump is the only available source of feed flow, the steam supply to the TD EFW

Pump must be maintained from at least one SG, to maintain a secondary heat sink. EOP-16.0 NOTE - Step 1

A FAULTED SG is any SG that is depressurizing in an uncontrolled manner OR that is completely

depressurized. EOP-16.0 RO Check RCS Tcold stable or increasing (NO) EOP-16.0 BOP Ensure Steamline PORVs are closed.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 35 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 35 NUREG 1021 Revision 9 EOP-16.0 BOP Ensure Condenser Steam Dump Valves are closed.(YES) EOP-16.0 RO Stop any cooldown with the RHR System if it is in service. (NO) EOP-16.0

BOP Maintain total EFW flow GREATER THAN 450 gpm until Narrow Range

level is GREATER THAN

26% [41%] in at least one NON-FAULTED SG EOP-16.0 BOP Reduce EFW flow to NON-FAULTED SG(s). EOP-16.0

BOP Ensure valves associated with each FAULTED SG are closed: MS Isolation, PVM-2801A(B)(C)

MS Isolation Bypass, PVM-2869A(B)(C) EOP-16.0 BOP Close MVG-2802B, MS LOOP C TO TD EFP EOP-16.0

BOP Open XMC1DB2Y 05EH, EMERG FEEDWATER PUMP MAIN STEAM BLOCK XVG2802B-MS (AB-463) EOP-16.0

Booth Operator Instructions:

When called to open XMC1DB2Y 05EH use LOA/RESETS page to do so.

CRITICAL

TASK BOP If any SG is NOT FAULTED, THEN isolate all feedwater to FAULTED SG(s) unless necessary for RCS temperature control.

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 36 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 36 NUREG 1021 Revision 9 EOP-16.0

Evaluator Note: This is the first procedure step that directs isolation of EFW to the FAULTED SG (C). However, OAP-103.4, EOP/AOP USER'S GUIDE, allows the crew to isolate EFW prior to

direction in the EOP's.

RO Verify power is available to the PZR PORV Block Valves: 1) MVG-8000A, RELIEF 445 A ISOL 2) MVG-8000B, RELIEF 444 B ISOL 3) MVG-8000C, RELIEF 445 B ISOL EOP-16.0 RO Verify at least one PZR PORV Block Valve is open. EOP-16.0

Caution - Step 3

If any PZR PORV opens because of high PZR pressure Step 3 should be repeated after pressure

decreases to LESS THAN 2300 psig, to ensure the PORV recloses. EOP-16.0

RO Check if the following Monitor Lights are bright: (NO) Both XCP-6106 1-11 and 2-11 (RCS TO RHR IN ISOL 8701A(8702A) OPEN).

OR Both XCP-6106 1-12 and 2-12 (RCS TO RHR IN ISOL

8701B(8702B) OPEN EOP-16.0 CRS GO TO Step 3.d. EOP-16.0 RO Verify PZR pressure is LESS THAN 2330 psig (yes). EOP-16.0

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 37 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 37 NUREG 1021 Revision 9 RO Ensure all PZR PORVs are closed (yes).. EOP-16.0 RO Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM EOP-16.0

RO Check if SI can be terminated: a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN

105°F[120°F].

b. Check RVLIS level GREATER THAN the following: With 0 RCP's

running RVLIS level 61% NR EOP-16.0 RO Reset both SI RESET TRAIN A(B) Switches. EOP-16.0

RO Reset Containment Isolation: RESET PHASE A - TRAIN A(B) CNTMT ISOL RESET PHASE B - TRAIN A(B) CNTMT ISOL EOP-16.0

BOP Place both ESF LOADING SEQ A(B) RESETS to: a. NON-ESF LCKOUTS b. AUTO-START BLOCKS EOP-16.0

RO Establish Instrument Air to the RB

a. Start an IA compressor

b. Open PVA-2659, INST AIR TO RB AIR SERV c. Open PVT-2660, AIR SPLY TO RB EOP-16.0

Evaluator Note: Until IA is restored, the PZR PORVs can be cycled using accumulators. IA should be

restored prior to these accumulators running out, otherwise pressure control is lost (less likely after installation of large air bottles during the last outage).

2011 NRC Scenario 2 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 2 Event #s 9,10,11 Page 38 of 38 Event Description: Main Steamline break inside the Reactor Building

Time Position Applicant's Actions or Behavior

Appendix D 38 NUREG 1021 Revision 9 EOP-16.0 RO Stop any RHR Pump operating in the SI mode. EOP-16.0 RO Stop all but one Charging Pump. EOP-16.0

RO Establish Normal Charging a. Close FCV-122, CHG FLOW

b. Open both MVG-8107 and MVG-8108, CHG LINE ISOL. c. Adjust FCV-122, CHG FLOW, to obtain

70 gpm Charging flow. d. Close both MVG-8801A(B), HI HEAD TO COLD LEG INJ. EOP-16.0

RO/CRS Verify SI flow is NOT required: a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN

52.5°F[67.5°F].

b. Check RVLIS level GREATER THAN the following: With 0 RCPs running RVLIS level 61% NR. EOP-16.0 Crew Verify RCS T

hot is stable by using EFW control and SG PORVs EOP-16.0

Evaluator Note:

The scenario can be terminated when SI flow is reduced, RCS Thot is being maintained

stable, and RB pressure rise is mitigated.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Appendix D 1 NUREG 1021 Revision 9

Facility:VC SUMMER Scenario No.:3 Op Test No.:

2011 NRC Examiners: Operators: CRS RO BOP Initial Conditions: The power was reduced to replace and test a FWIV actuator

IC-40, 25% Power, BOL, GOP-4a, Step 3.12C (IC-303 or IC-307 for 2011) "B" EDG is OOS to clean the lube oil strainer "B" RB spray pump is out of service for bearing replacement National Weather Service has issued a severe weather alert due to a line of heavy thunderstorms moving into the area Turnover: Increase power to 38% per GOP Critical Task: Restore High head safety injection prior to NR RVLIS going less than 34% level (Orange path challenge to Core Cooling)

Control EFW flow to "C" SG prior to filling generator above 90% (WOG M.08) Establish Containment Isolation prior to completion of Att. 3 to EOP-1.0

Event No. Malf. No. Event Type* Event Description

1. N-BOP,CRS R-RO Power escalation toward 38% 2. XMT-MS036O I- BOP,CRS SG pressure transmitter PT-2010 fails high, opening SG PORV

BOP1 3. MSS001E TS-CRS Compensating "B" SG pressure transmitter PT-485 fails high, increasing Main Feedwater flow

BOP2 4. RCS007C

C- RO, TS-CRS "C" RCP vibrations ramp up, pump must be shutdown

RO1 5. PRS001B C-RO,

TS-CRS PT-445 fails high, causing entry to DNB TS.

RO2 6. CCW007A PMP-CC003F.

PMP-CC002B C-RO, BOP, CRS Running CCW pump trips. Standby pump on A train fails to start. Opposite Train pump starts but bearing fails, causing

high amps then overcurrent trip. 7. C-ALL Trip reactor and reactor coolant pumps due to loss of CCW 8. VLV-EF005F C- BOP, CRS FCV 3551 MDEFW to C SG fails as is (open) 9. PRS007A M-ALL Pressurizer Safety valve fails open, requiring manual SI alignment Terminate after EOP-2.1 (Post LOCA Cooldown and Depressurization) entry

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Appendix D 2 NUREG 1021 Revision 9 VC Summer NRC Scenario #3

The crew will assume the watch having pre-briefed on the Initial Conditions (25% power, BOL) increasing

power to 38% per GOP-4A.

The crew increases power until the Lead Evaluator directs inserting the first malfunction.

SG pressure transmitter PT-2010 fails high, opening SG PORV PCV-2010. BOP places controller PK-2010 in

MANUAL and closes the PORV to prevent uncontrolled power increase and loss of condenser inventory.

PT-485, SG "B" compensating pressure channel fails high, requiring action to prevent overfeeding the "B" SG due to indicated feed flow/steam flow mismatch. CRS must evaluate Tech Specs for SG pressure transmitter

failure.

Reactor Coolant Pump vibrations ramp up. Since reactor power is below P-8 (38%) the RO can secure the

RCP per ARP-619 point 1-3, RCP C VIBR HI. The BOP must control SG level in the idle loop and the CRS must evaluate Tech Spec 3.4.1.1 and begin a power reduction to MODE 3 over the next hour.

Pressurizer Pressure Transmitter PT-445 fails high, causing two Pressurizer PORVS to open. The PORVs will

cycle open and closed at the P-11 interlock pressure of 1970 psig. The RO will close the PORVs and their

block valves per AOP-401.5 PRESSURIZER PRESSURE CONTROL CHANNEL FAILURE. The CRS will check that this satisfies Technical Specification 3.4.4 for the PORVs.

All Component Cooling Water flow is lost due to trip of the running pump and failure of the standby pump to start. The RO momentarily restores CCW by starting the opposite train pump and transferring non-essential

CCW loads (including RCPs). The one remaining pump then seizes. This will require the crew to trip the reactor and the running RCPs within 10 minutes per AOP-118.1 TOTAL LOSS OF COMPONENT COOLING

WATER. The CRS will implement EOP-1.0, REACTOR TRIP OR SAFETY INJECTION in conjunction with the AOP. Alternate cooling to the charging pumps must be established within 20 minutes to prevent a loss of RCP

seal cooling (loss of CCW and RCP seals together account for 28% of the core damage frequency).

When the crew attempts to throttle AFW, FCV 3551 MDEFW to C SG will be found to be failed open. The crew will have to either establish local control of the valv

e or secure the motor-driven EFW pumps and realign the turbine-driven pump prior to overfilling the C SG.

One train of CCW is restored by transferring the swing pump to "B" train. Last event is entered after CCW loads are evaluated in AOP-118.1.

A Pressurizer Safety valve drifts open with a failure of both Trains of Containment Isolation Signal and both

High Head injection valves to open.

Crew must return to EOP-1.0 (WOG E-0) and use Att. 3 to

manually Initiate Phase A Containment Isolation and align High Head Safety Injection

. (This must be accomplished prior to Narrow Range RVLIS going less than 34% level, which is the Orange Path challenge to Core Cooling with

no RCPs running.) Scenario may be terminated after entry in EOP-2.1.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Appendix D 3 NUREG 1021 Revision 9

VCS 2011 NRC Scenario 3 Simulator Setup

Initial Conditions:

IC-40, 25% Power, BOL, GOP-4a, Step 3.12 (IC 307 for 2011)

Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires.

VCS 2011 NRC Scenario 3 Simulator Setup (SNAP 307)

Conduct two-minute drill Mark up procedures in use with "Circle and slash" as applicable

Pre-Exercise:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions,

chart recorders, etc.)

TQP-801 Booth Operator checklist, has been completed

Hang Red Tags for equipment out of service

Put copy of AOP-118.1 ATT. 3 pg. 4 in booth

PRE-LOAD

LOA-CCW048 standby Component Cooling Water pump "C" Breaker on "A" train fails to close

Override OVR-EF015A & EF015B = 100% Flow control valve from Motor-driven EFW to C SG fails as-is (open) LOA AUX 118 = RACK OUT "B" RB Spray pump breaker LOA-EPS114 = MAINTENANCE ("B" EDG OOS) MAL PCS-006A and 006B, Containment Isolation Phase A Signal Failure, Train A(B)=FAILURE TO

INIT OVR-SG007 CONT ISO PHASE A CONT VENT ISO=false Define Event 27 x02i054A second (right) Phase A switch CS-SG02B take to actuate Schedule "delete malfunction PCS-006B" on event 27. Run scheduler & minimize (DO NOT CLOSE). PMP-CS004F and CS006F failure of "A" and "B" CHG/SI pumps to autostart VLV-SI003F and SI004F MVG-8801A and B fail as-is (closed) Define Event 28 x03i086o, MVG SS01B C/S taken to OPEN Schedule "delete malfunction vlv-si004f" on event 28. Run scheduler & minimize (DO NOT CLOSE). Define Event 29 x03i085o, MVG SS01A C/S taken to OPEN

Schedule "delete malfunction vlv-si003f" on event 29. Run scheduler & minimize (DO NOT CLOSE).

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Appendix D 4 NUREG 1021 Revision 9 EVENT 1: Power escalation toward 38%

No simulator manipulations required Next event on lead examiner cue

EVENT 2: SG "A" steam pressure transmitter fails high

Trigger 2, XMT-MS036O = 1300#, no ramp Transmitter will not be repaired Steam Generator Power Relief Valve will remain in MANUAL

EVENT 3: "B" SG compensating pressure transmitter fails high

Trigger 3, Malfunction MSS001E = 1300#, 30 second ramp Transmitter will not be repaired Steam and feed flow will remain selected to alternate channel

EVENT 4: Reactor Coolant Pump vibrations require RCP trip

Trigger 4, Insert Malfunction RCS007C=14 mils, no ramp, then; Modify Malfunction RCS007C = 30 mils, 6 minute ramp Power is low enough for crew to trip RCP Insert and remove VLV-CS05W to install fuse for 8141C or use LOA RESETS page on thunderview

display EVENT 5: Pressurizer Pressure Transmitter PT-445 fails high, opening two PORVs

Trigger 5, Malfunction PRS001B = 2500#, 2 minute ramp Pressure transmitter will not be repaired

EVENT 6: Trip of running Component Cooling Water pump and failure of other pumps

Trigger 6, Malfunction CCW007A, trip of "A' CCW pump PMP CC002B = 10, 3 minute Time Delay, 6 minute ramped bearing Seizure of "B" train CCW pump

EVENT 7: Pressurizer Safety drifts open

Trigger 7, Malfunction PRS007A "A" safety drifts fully open, 5 minute ramp Crew must operate individual pumps and valves due to total SSPS failure

Trigger 8 Local action to vent Deaerator

LOA-FWM055, DEAERATOR VENT VALVE 2210-HV , = 1.0 (open), 5 minute TD

Trigger 9 Local action to throttle condensate to blow down heat exchanger flow

LOA-CND044,045,046 TC-3062A/B/C A/M station mode to MANUAL LOA-CND047,048,049 TC-3062A/B/C manual output to 10% open

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Appendix D 5 NUREG 1021 Revision 9 Trigger 10 Local action to transfer "C" CCW pump to "B" train

LOA-CCW044 CELL SWITCH OF CCW PUMP C TRAIN A = RACK OUT, 10 min TD LOA-CCW045 CELL SWITCH OF CCW PUMP C TRAIN B = RACK OUT, 12 min TD LOA-CCW001 CCW PUMP C DISCONNECT SWITCH = TRAIN B, 14 min TD LOA-CCW010 CC PP C SUCT LP A ISO VLV = 0 2 min TD 1min ramp LOA-CCW012 CC PP C DISCH LP A ISO VLV = 0 4 min TD 1min ramp LOA-CCW009 CC PP C SUCT LP B ISO VLV = 1 6 min TD 1min ramp LOA-CCW011 CC PP C DISCH LP B ISO VLV = 1 8 min TD 1min ramp

Local action restore control of seal injection flow

Remove Malfunction VLV-CS010A to restore air to HCV-186

Local action to throttle EFW flow

Use Malfunction VLV-EF005P as requested to locally throttle FCV-3551

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 1 Page 6 of 52 Event Description: Raise power in accordance with GOP-4A towards 38%

Time Position Applicant's Actions or Behavior

Appendix D 6 NUREG 1021 Revision 9

Booth Instructor:

No action required for event 1

Indications available:

None Applicable

GOP-4A BOP Select 1/2 on RATE %/MIN.

GOP-4A BOP Increase LOAD SET in 2% increments to attain 38% Reactor Power.

GOP-4A Crew At 250 MWe perform the following: 1) Ensure all Extraction Drain Valves are latched.

2) Contact Electrical Maintenance to perform thermography on manual disconnects 8901 and 8903.

GOP-4A Booth Operator Instructions: When called to ensure all extraction drain valves are latched wait 15 min and then report

that they are all latched.

When called to perform thermography on the manual disconnects wait 15 min and then

report that thermography indicated good closure of the disconnects.

Crew At 300 MWe, call the TB operator to perform the following to start filling the drain lines from the 2A and 2B Heaters to the DA: 1) Open XVT12083-HD, 1" BYPASS VALVE FOR XVG-02075 (TB-412) (requires ladder). 2) Open XVT12085-HD, 1" BYPASS VALVE FOR XVG-02074 (TB-

412). 3) Throttle XVT02018A-HD, FW HTR 2A DRN TO DEAER LVL CONT VLV BYP, ten turns off the closed seat (TB-463). 4) Throttle XVT02018B-HD, FW HTR 2B DRN TO DEAER LVL CONT VLV BYP, ten turns off the closed seat (TB-463).

GOP-4A

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 1 Page 7 of 52 Event Description: Raise power in accordance with GOP-4A towards 38%

Time Position Applicant's Actions or Behavior

Appendix D 7 NUREG 1021 Revision 9

Booth Operator Instructions: When called to start filling the drain lines from the 2 heaters to the DA time compress

20 minutes and then report that based on flow noise it appears that the line to the DA is

full. BOP Place a second Condensate Pump in service per SOP-208, Condensate System, when total Condensate flow approaches 9000 gpm as indicated

on the following: 1) FI 3026, PUMP A DISCH FLOW. 2) FI 3036, PUMP B DISCH FLOW. 3) FI 3046, PUMP C DISCH FLOW. Uses SOP-208 Section B.2

BOP Ensure the discharge valve for the pump to be started is closed: a. XVB-614A, A DISCH ISOL. b. XVB-614B, B DISCH ISOL. c. XVB-614C, C DISCH ISOL.

SOP-208 BOP Start one of the following: (PEER ) a. XPP-0042A, CO PUMP A.

b. XPP-0042B, CO PUMP B. c. XPP-0042C, CO PUMP C.

SOP-208 BOP Open the associated pump discharge valve: (PEER ) a. XVB-614A, A DISCH ISOL.

b. XVB-614B, B DISCH ISOL. c. XVB-614C, C DISCH ISOL.

SOP-208 Evaluator Note: The following steps are for alternate dilution that may occur on the power increase.

May use SOP-106 Section E.2

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 1 Page 8 of 52 Event Description: Raise power in accordance with GOP-4A towards 38%

Time Position Applicant's Actions or Behavior

Appendix D 8 NUREG 1021 Revision 9 NOTE 2.0

1. Energizing additional Pressurizer Heaters will enhance mixing. 2. LCV-115A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70%

level on LI-115, VCT LEVEL %.

SOP-106 RO Verify at least one Reactor Coolant Pump is running.

SOP-106 RO Place RX COOL SYS MU switch to STOP.

SOP-106 RO Place RX COOL SYS MU MODE SELECT switch to ALT DIL. (Peer ) SOP-106 RO Adjust FCV-168, TOTAL MU FLOW SET PT, to desired flow rate.

SOP-106 RO Set FIS-168, TOTAL MU FLOW, batch integrator to desired volume.

(Peer ) SOP-106 RO Place RX COOL SYS MU switch to START.

SOP-106 RO Verify desired flow rate on FR-113, TOTAL MU GPM (F-168).

SOP-106 RO Verify alternate dilution stops when preset volume is reached on FIS-168, TOTAL MU FLOW, batch integrator.

SOP-106 RO Place RX COOL SYS MU switch to STOP.

SOP-106

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 1 Page 9 of 52 Event Description: Raise power in accordance with GOP-4A towards 38%

Time Position Applicant's Actions or Behavior

Appendix D 9 NUREG 1021 Revision 9 RO Place RX COOL SYS MU MODE SELECT switch to AUTO. (Peer ) SOP-106 RO Adjust FCV-168, TOTAL MU FLOW SET PT, to 7.5 (120 gpm).

SOP-106 RO Place RX COOL SYS MU switch to START. Returns to GOP-4A

At discretion of the Lead Examiner, proceed to the next event

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 2 Page 10 of 52 Event Description: SG pressure transmitter PT-2010 fails high, opening SG PORV

Time Position Applicant's Actions or Behavior

Appendix D 10 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 2

Indications available:

Power Rise.

PORV open indication, OPCRIT alarm. XCP-632 pt. 4-5, IPCS OPCRIT ALARM BOP Determines that PT-2010 has failed high.

BOP Takes M/A station for PWR RELIEF B SETPT to MAN and CLOSED.

BOP May place PCV-2010, B SD/ PWR RLF in PWR RLF

(by OAP-100.2 V.4 and V.3 regarding manual actions).

Evaluator Note:

Per SOP-202 section IV.A pg 4 of 20, if steam release through the SG PORV is required at a later time, the "B" SG switch must be placed in PWR RLF at that time

. Crew Conducts post-event brief, contacts SS, and may inform I&C of failure

Booth Operator Instructions: When called respond as I&C that a troubleshooting plan is being developed.

Returns to GOP-4A

At the discretion of the Lead Examiner, proceed to the next event

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 3 Page 11 of 52 Event Description: Compensating "B" SG pressure transmitter PT-485 fails high, raising Main Feedwater flow

Time Position Applicant's Actions or Behavior

Appendix D 11 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 3

Indications available: XCP-624, 4-1, SG A STMLN P HI XCP-624, 6-1, SG C STMLN P HI Increasing Feed flow to B SG.

XCP-624, 4-1, SG A STMLN P HI Crew Refer to alarm response procedures

ARP PROBABLE CAUSE: 1. Steam line break. 2. Instrument failure.

3. Testing in progress.

ARP AUTOMATIC ACTIONS: 1. Safety Injection when steam line A is 97 psi lower than both the other steam lines as sensed by 2 of 3 pressure channels on steam lines A and C

and on A and B.(

NO, signal is only 1/3)

ARP CORRECTIVE ACTIONS: BOP Verify steam line pressure indications on the Main Control Board.

ARP SUPPLEMENTAL ACTIONS:

CRS If an instrument channel failed, go to AOP-401.3, Steam Flow - Feedwater Flow Protection Channel Failure.

Transitions to AOP-401.3

IOA BOP Verify the failed channel is the controlling channel (

YES).

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 3 Page 12 of 52 Event Description: Compensating "B" SG pressure transmitter PT-485 fails high, raising Main Feedwater flow

Time Position Applicant's Actions or Behavior

Appendix D 12 NUREG 1021 Revision 9 AOP-401.3

IOA BOP Select the operable flow channel: Place FW CONTROL CHANNEL SEL Switch to the operable

channel. Place STEAM CONTROL CHANNEL SEL Switch to the operable channel. AOP-401.3

IOA BOP Verify Turbine Load is LESS THAN 950 MWe.(YES) AOP-401.3

IOA BOP Verify only one SG is AFFECTED. (YES) AOP-401.3

IOA BOP Adjust the Feedwater Flow Control Valve as necessary to restore feed flow

to the AFFECTED SG

AOP-401.3

IOA BOP Check if Feedwater Pump speed control is operating properly: Feedwater Header pressure is GREATER THAN Main Steam

Header pressure. Feed flow is normal for steam flow and power level. All operating Feedwater Pump speeds and flows are balanced.

AOP-401.3

BOP Verify Narrow Range levels in all SGs are between 60% and 65%.

AOP-401.3

Restore the AFFECTED SG control systems to normal: Place the Feedwater Flow Control Valve in AUTO. Place the Feedwater Pump Speed Control System in AUTO. REFER TO SOP-210, FEEDWATER SYSTEM.

AOP-401.3

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 3 Page 13 of 52 Event Description: Compensating "B" SG pressure transmitter PT-485 fails high, raising Main Feedwater flow

Time Position Applicant's Actions or Behavior

Appendix D 13 NUREG 1021 Revision 9 NOTE - Step 9

Steam flow transmitters FT-474, FT-484, FT-494, FT-475, FT-485, and FT-495 are density

compensated by steam pressure transmitters PT-475, PT-485, PT-495, PT-476, PT-486, and PT-

496. AOP-401.3

CRS Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, place the failed channel protection bistables in a tripped

condition:

PB-485A

PB-485B-1

PB-485B-2

PB-475B-1

PB-475B-2

FB-488B AOP-401.3

CRS Identify Technical Specifications: Table 3.3-1 Item 14: Action 6 Trip bistables in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (may be bypassed

for testing for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) Table 3.3-3 Items 1.e, 1.f, 4.e: Action 24 Trip bistables in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (may be bypassed for testing for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) AOP-401.3

Booth Operator Instructions:

When called as I&C, report that you will develop a troubleshooting plan.

Crew Conducts Post-Event brief, contacts SS, may request I&C assistance.

Returns to GOP-4A

When Technical specifications are determined or at the discretion of the Lead Examiner

proceed to the next event

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 14 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 14 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 4.

Indications available: XCP-619 1-3, RCP C VIBR HI

XCP-619 1-3, RCP C VIBR HI Crew Refer to alarm response procedure

ARP PROBABLE CAUSE: 1. Pump shaft vibration caused by: a. Bearing wear.

b. Impeller imbalance.

c. Misalignment.

d. Seismic event. 2. Pump frame vibration caused by: a. Excess shaft vibration.

b. Seismic event. 3. Flywheel imbalance.

4. Loss of Coolant Accident.

ARP AUTOMATIC ACTIONS:

1. None.

ARP CAUTION Reactor Coolant Pump shaft and frame vibrations should increase simultaneously on actual Reactor Coolant Pump high vibration. Channel failure is indicated by the

associated shaft or frame bar graph going to zero on the Yokogowa DX 1000

recorder.

ARP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 15 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 15 NUREG 1021 Revision 9 NOTE a. This alarm has reflash capabilities.

b. This alarm causes XCP-606 3-5, REACTOR BUILDING FANS VIBRATION F MON FLT/WARN to annunciate.

ARP CORRECTIVE ACTIONS:

RO Monitor Reactor Coolant Pump C vibration indicators to determine the source and severity of the vibration.

ARP RO Monitor RCS temperature and pressure to verify they are within limits for Reactor Coolant Pump operation.

ARP SUPPLEMENTAL ACTIONS:

Crew With Reactor Coolant Pump C shaft vibration greater than or equal to 20 mils or greater than or equal to 15 mils and increasing at greater than one

mil per hour, perform one of the following: a. If Reactor Power is greater than 38%, trip the Reactor and secure

Reactor Coolant Pump C per SOP-101.

(NO) b. If Reactor Power is less than 38%, secure Reactor Coolant Pump C per SOP-101 and proceed to Hot Standby per GOP-4B, Power

Operation (Mode 1 - Descending), and GOP-5, Reactor Shutdown

From Startup to Hot Standby (Mode 2 to Mode 3), within one hour.

(YES)

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 16 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 16 NUREG 1021 Revision 9

Crew 2. With Reactor Coolant Pump C frame vibration greater than or equal to five mils or greater than three mils and increasing at greater than 0.2 mils per hour, perform one of the following: a. If Reactor Power is greater than 38%, trip the Reactor and secure

Reactor Coolant Pump C per SOP-101.

b. If Reactor Power is less than 38%

(YES), secure Reactor Coolant Pump C per SOP-101 and proceed to Hot Standby per GOP-4B,

Power Operation (Mode 1 - Descending), and GOP-5, Reactor Shutdown From Startup to Hot Standby (Mode 2 to Mode 3), within

one hour.

Transitions to SOP-101 section IV.A.2.0 NOTE 1.1

The applicable section of Tech Spec 3.4.1 must be met when removing a Reactor

Coolant Pump from service.

SOP Crew Verifies reactor power is less than 38% (P-8 permissive is illuminated).

SOP CRS Acknowledges that the plant is being placed in Hot Standby.

SOP RO Place the associated following Pressurizer Spray Valve for the affected Reactor Coolant Pump in MAN and close:

a. PCV 444D, PZR SPRAY, for Reactor Coolant Pump A. (NO) b. PCV 444C, PZR SPRAY, for Reactor Coolant Pump C. (YES) SOP RO If the RCS is solid, place PCV-145, LO PRESS LTDN, in MAN. (NA) SOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 17 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 17 NUREG 1021 Revision 9

RO Secure one of the following Reactor Coolant Pumps as required: a. XPP-0030A, PUMP A. (NO) b. XPP-0030B, PUMP B.

(NO) c. XPP-0030C, PUMP C.

(YES) SOP RO If the RCS is solid, return PCV-145, LO PRESS LTDN, to AUTO, if desired. (NA) SOP RO Verify Seal Injection to the secured Reactor Coolant Pump using the applicable following indicator:

a. FI-130A, RCP A INJ FLO GPM.

b. FI-127A, RCP B INJ FLO GPM.

c. FI-124A, RCP C INJ FLO GPM.

SOP Crew Maintain Component Cooling Water to the secured Reactor Coolant Pump thermal barrier until RCS temperature is less than 150°F.

SOP BOP Place the following controllers in MAN, as required for the affected RCS loop and maintain Narrow Range Steam Generator level between 60% and

65%: a. PVT-478, SG A FWF.

b. FCV-3321, LOOP A MAIN FW BYP.

c. PVT-488, SG B FWF.

d. FCV-3331, LOOP B MAIN FW BYP. e. PVT-498, SG C FWF. f. FCV-3341, LOOP C MAIN FW BYP.

SOP CAUTION 2.8

Per Tech Spec 3.4.1.1, the plant must be in Hot Standby within one hour of securing the Reactor Coolant Pump.

SOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 18 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 18 NUREG 1021 Revision 9

CRS If not already in Hot Standby, proceed to Hot Standby in accordance with GOP-4B, Power Operation (Mode 1 - Descending), or GOP-4C, Rapid Power Reduction, and GOP-5, Reactor Shutdown From Startup To Hot

Standby (Mode 2 To Mode 3).

SOP CRS Contacts SS and System Controller re. RCP trip and plant shutdown.

Transitions to GOP-4B CAUTION 3.1 through 3.12

a. Thermal Power changes of greater than 15% in any one-hour period requires completion of GTP-702 Attachment III.H.

b. VCS PID Report, POWER CHANGE SEARCH, should be periodically performed to ensure a thermal power change of greater than 15% in any one-hour period is detected.

GOP NOTE 3.1 through 3.12

a. Step 3.1 lowers Reactor Power from 100% to 90%.

b. If the RCS will be opened for maintenance during the shutdown, degassing of the RCS should

be initiated per SOP-102, Chemical And Volume Control System.

c. The setpoint for IFK3136, FLOW TO DEAERATOR, should be adjusted during power changes to maintain LI-3136, DEAER STOR TK NR LVL, between 2.5 and 5.0 feet.

GOP Evaluator Note: This guide does not include steps to lower power down to 38%.

GOP NOTE 3.3

Step 3.3 lowers Reactor Power from 48% to 25%.

GOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 19 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 19 NUREG 1021 Revision 9

BOP Reduce load

GOP BOP As load decreases, adjust Megavars using GEN FIELD VOLT ADJ as requested by the Load Dispatcher and within the Estimated Generator

Capability curve (Enclosure A).

GOP RO As load decreases, Borate or dilute per SOP-106, Reactor Makeup Water System, to maintain Control Rods above the Rod Insertion Limit.

GOP BOP Between 30% and 35% Reactor Power, reduce to two Feedwater Booster Pumps per SOP-210, Feedwater System.

GOP BOP As load decreases, maintain the Blowdown Heat Exchanger condensate outlet temperatures at least 30 degrees below the DA temperature.

GOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 20 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 20 NUREG 1021 Revision 9

Crew When Reactor Power is less than 25%, commence cooling the Feedwater system to less than 180°F as follows: a. Place the following Feedwater Heaters in ISOLAT (I icon) (GRAPHIC 101, 102, 103, 104 or 110 screens):

1) FW HTR 1A OPRTR SELECT ISOLATION.

2) FW HTR 1B OPRTR SELECT ISOLATION.

3) FW HTR 2A OPRTR SELECT ISOLATION.

4) FW HTR 2B OPRTR SELECT ISOLATION. 5) FW HTR 4A OPRTR SELECT ISOLATION. 6) FW HTR 4B OPRTR SELECT ISOLATION. b. Isolate 7th Stage Extraction Steam to the DA as follows: 1) Place IPV-2231, MS/PEGGING STM TO DEAERATOR, in MAN

and close. 2) Close MVG-1212, EXT STM TO DEAER ISOL. c. Open XVG02210-HV, FW HTR DEAERATOR VENT ORF BYP HDR ISOL (TB-463).

GOP Booth Operator Instructions: When called to Open XVG02210-HV, FW HTR DEAERATOR VENT ORF

BYP HDR ISOL use LOA-FWM055, DEAERATOR VENT VALVE 2210-HV (Trigger 8) and then report that it is

open. GOP Crew At less than 25% Reactor Power, verify the following status lights de-energize to dim: 1) CHAN I IR FLUX HI. 2) CHAN II IR FLUX HI.

3) CHAN I PR FLUX LO SET PT.

4) CHAN II PR FLUX LO SET PT.

5) CHAN III PR FLUX LO SET PT. 6) CHAN IV PR FLUX LO SET PT.

GOP BOP When total Condensate flow on the following indicators is less than 9000 gpm, reduce to one Condensate Pump running per SOP-208, Condensate

System:

1) FI-3026, PUMP A DISCH FLOW. 2) FI-3036, PUMP B DISCH FLOW. 3) FI-3046, PUMP C DISCH FLOW.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 4 Page 21 of 52 Event Description:

RCP seal leakage vibration requires trip of Reactor Coolant Pump

Time Position Applicant's Actions or Behavior

Appendix D 21 NUREG 1021 Revision 9

GOP Maintain DA level and temperature control as follows: 1) If necessary to maintain DA level, place FC-3136, FLOW TO DEAERATOR, in MAN. 2) Adjust IPV-2231, MS/PEGGING STM TO DEAERATOR, as necessary, to maintain DA temperature between 130°F and 150°F. 3) If DA cooling is required, LCV 3235, DEAER START UP DRAIN CNTRL, may be used to raise flow through the DA. 4) Ensure Steam Generator Blowdown Condensate return temperature is maintained less than or equal to DA temperature as

load is reduced.

GOP BOP As load decreases, transfer the Steam Dumps to the Steam Pressure

Mode as follows: 1) Place the STM DUMP CNTRL m/a station in MAN.

2) Place the STM DUMP MODE SELECT Switch in STM PRESS.

3) Adjust the STM DUMP CNTRL m/a station setpoint to 8.4.

4) Place the STM DUMP CNTRL m/a station in AUTO.

GOP At the discretion of the Lead Examiner, proceed to the next event

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 5 Page 22 of 52 Event Description: PT-445 fails high

Time Position Applicant's Actions or Behavior

Appendix D 22 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 5

Indications available:

XCP-616, 2-3, PZR PRESS HI/LO

XCP-616, 2-6, PZR CNTRL PRESS HI

XCP-616, 4-1, PZR SAFETY VLV LINE TEMP HI

XCP-616, 4-2, PZR RLF LINE TEMP HI

XCP-616, 4-3, PZR RLF VLV ISOL 2 PORV's cycling at 1970 psig

XCP-616, 2-6, PZR

CNTRL PRESS HI Crew Refer to alarm response procedures

ARP Crew Refer to XCP-616, 2-6

ARP PROBABLE CAUSE: 1. Instrument failure. 2. Rapid load reduction.

ARP AUTOMATIC ACTIONS: 1. PCV-445A(445B), PWR RELIEF, open.

ARP CORRECTIVE ACTIONS:

RO Compare PI-445, CNTL CHAN PRESS PSIG, with other Pressurizer pressure indications to determine if IPT00445, PRESSURIZER

PRESSURE CONTROL PRESS XMTR, has failed high

(YES). ARP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 5 Page 23 of 52 Event Description: PT-445 fails high

Time Position Applicant's Actions or Behavior

Appendix D 23 NUREG 1021 Revision 9 RO If IPT00445, PRESSURIZER PRESSURE CONTROL PRESS XMTR, has failed high, perform the following: a. Close PCV-445A, PWR RELIEF and PCV-445B, PWR RELIEF. b. Refer to AOP-401.5, Pressurizer Pressure Control Channel Failure.

ARP CRS Transition to AOP-401.5, Pressurizer Pressure Control Channel Failure

Transition to AOP-401.5 NOTE: Through this procedure, "AFFECTED" refers to any PZR PORV that has actuated as a result of

the instrument failure.

AOP IOA RO Verify the PZR PORVs are closed: (NO) AOP IOA RO IF PZR pressure is LESS THAN 2300 psig, THEN perform the following: Close the AFFECTED PZR PORV(s): PCV-445A, PWR RELIEF

(YES) PCV-445B, PWR RELIEF

(YES) PCV-444B, PWR RELIEF

(NO) AOP NOTE - Step 2

PZR PRESS control channels PI-444 and PI-445 connect to the same reference leg line as

protection channel PI-457.

AOP IOA RO Compare the PZR control channel indication to the protection channel indications: (ONLY 445 reading high) PI-455, PRESS PSIG PI-456, PRESS PSIG PI-457, PRESS PSIG

AOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 5 Page 24 of 52 Event Description: PT-445 fails high

Time Position Applicant's Actions or Behavior

Appendix D 24 NUREG 1021 Revision 9

IOA RO Check if PI-444, CNTROL CHAN PRESS PSIG, indication is NORMAL. (YES) AOP RO Check if PI-445, CNTRL CHAN PRESS PSIG, indication is NORMAL. (NO) AOP RO If PT-445 is failed, THEN within one hour close the AFFECTED PORV

Block Valves: MVG-8000A, RELIEF 445 A ISOL MVG-8000C, RELIEF 445 B ISOL

AOP CRS Determine above action satisfies Technical Specification 3.4.4 Action a. "With one or more PORV(s) inoperable and capable of being manually

cycled, within 1 hour: 1) Restore the PORV(s) to OPERABLE status or

2) Close the associated block valve(s) and maintain power to the

block valve; otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Tech Specs

RO Ensure ROD CNTRL BANK SEL Switch is in AUTO.

AOP * RO Maintain RCS pressure between 2220 psig and 2250 psig.

AOP CRS While regaining pressure monitor Technical Specification:3.2.5: Indicated

Pressurizer Pressure 2206 psig Action: With any of the above parameters exceeding its limit, restore the parameter to within its limit within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or reduce THERMAL POWER to

less than 5% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

Tech Specs

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 5 Page 25 of 52 Event Description: PT-445 fails high

Time Position Applicant's Actions or Behavior

Appendix D 25 NUREG 1021 Revision 9

Crew Conducts post-event brief and contacts SS. May request I&C assistance.

Booth Operator Instructions: When called that PT-445 has failed high report as I&C that a troubleshooting plan is being

developed.

At the discretion of the Lead Examiner, proceed to the next event.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 26 of 52 Event Description: Total loss of CCW. Trip reactor and reactor coolant pumps due to loss of CCW, FCV 3551 MDEFW to C SG fails as is (open)

Time Position Applicant's Actions or Behavior

Appendix D 26 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate Trigger 6.

Indications available:

XCP-601 1-3, CCP A/C TRIP FAIL Other CCW low flow alarms

XCP-601 1-3, CCP A/C TRIP FAIL Crew Refer to alarm response procedures

ARP PROBABLE CAUSE: 1. Overcurrent trip in conjunction with an overload alarm.

ARP AUTOMATIC ACTIONS: Standby pump starts.

(Starts but indication of a sheared shaft)

ARP NOTE This alarm has reflash capabilities.

ARP CORRECTIVE ACTIONS: RO Ensure the standby pump starts. (Starts but with sheared shaft)

ARP

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Time Position Applicant's Actions or Behavior

Appendix D 27 NUREG 1021 Revision 9 CAUTION 2

a. Any Charging Pump can continue to be operated on a loss of Component Cooling Water to its

oil coolers within one of the following: 1) 20 minutes without local temperature monitoring.

OR 2) No time limit as long as any maximum temperature of Attachment 1, Charging Pump Temperature Monitoring, Page 4 of 4, of AOP-118.1, Total Loss of Component Cooling, is

NOT exceeded AND local Charging Pump temperature monitoring remains in place.

ARP RO If no Train A pumps are running, perform the following: a. Ensure a Train B Component Cooling Pump is running.

b. Start a Train B Charging Pump.

c. Stop the Train A Charging Pump.

ARP RO If a Train B Component Cooling Pump was started, establish Train B as the active loop per SOP-118. (B CCW overloads)

ARP RO Verify system pressures, temperatures, and flows are normal. (NO) ARP CRS If no Component Cooling Pumps can be started, then go to AOP-118.1, Total Loss of Component Cooling Water.

Transitions to AOP-118.1

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Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 28 of 52 Event Description: Total loss of CCW. Trip reactor and reactor coolant pumps due to loss of CCW, FCV 3551 MDEFW to C SG fails as is (open)

Time Position Applicant's Actions or Behavior

Appendix D 28 NUREG 1021 Revision 9

Booth Operator Instructions: When called to investigate the CCW system report that;

• nothing can be seen wrong with the A CCW pump but that the A breaker has a 51 relay flag dropped on the A phase. * C breaker on "A" train closing springs are discharged

• B has an overheated bearing housing

When called as electrical maintenance report

a latch in the "A" train breaker for the "C" CCW pump is broken. Wait 30 min and then report that the "A" train breaker cannot be repaired quickly, must be replaced.

AOP CAUTION Any Charging Pump can be started or continue to be operated on a loss of Component Cooling Water to its oil coolers within one of the following:

o 20 minutes without local Charging Pump temperature monitoring.

OR o No time limit as long as any maximum temperature of Attachment 1, Charging Pump Temperature Monitoring, Page 4 of 4

, is NOT exceeded AND local Charging Pump temperature monitoring remains in place.

Any running Reactor Coolant Pump should be stopped if any of the following conditions

exist: a. Component Cooling Water flow to the motor bearing coolers can NOT be restored within ten minutes. b. Motor Bearing temperature exceeds 195°F.

c. Lower Seal Water Bearing temperature exceeds 225°F.

d. Seal Water Outlet temperature exceeds 235°F

AOP NOTE If a Reactor trip occurs, this procedure should be continued concurrently with the recovery actions

of EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION.

AOP

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Time Position Applicant's Actions or Behavior

Appendix D 29 NUREG 1021 Revision 9

IOA RO Determine the cause for the loss of CCW: a. Check for annunciators on XCP-601, 602, and 603.

b. REFER TO the appropriate ARPs.

c. Attempt to correct the cause for loss of CCW.

AOP IOA RO Establish either train of CCW as the Active Loop. REFER TO *

SOP-118, COMPONENT COOLING WATER. (CANNOT until "C" swapped) AOP * RO Verify CCW cooling is available to each running Charging Pump. (NO) AOP RO Initiate Attachment 1, Charging. Pump Temperature Monitoring, Page 4 of

4. AOP Booth Operator Instructions: When called to monitor A charging pump temperatures wait 5 min and then report that you

are monitoring temperatures. If asked for temperatures indicate that temperatures are rising but are below maximum

values (copy of AOP-118.1 Att. Is in the booth).

ITI17550A CHG/SI PP A GEARBOX LUBE OIL TEMP IND 115-145 MAX 145

ITI07551 PUMP A OIL CLR OUTLET 120-150 MAX 150 ITI07552 THRUST BRG TEMP 130-155 MAX180 Report gearbox at max temperature before safety valve failure to reduce to one pump

running.

CRS GO TO Step 4.

AOP Crew Check if at least one CCW loop is restored:

(NO) AOP

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Time Position Applicant's Actions or Behavior

Appendix D 30 NUREG 1021 Revision 9

RO Place any non-running Charging Pump which does NOT have CCW cooling in PULL TO LK NON-A. (B and C)

AOP RO Close all Letdown Isolation Valves: 1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL. 2) LCV-459, LTDN LINE ISOL. 3) LCV-460, LTDN LINE ISOL.

4) HCV-142, LTDN FROM RHR.

AOP Crew Establish Charging Pump alternate cooling using Chilled Water per

Attachment 1.

AOP Booth Operator Instructions: When called to align chilled water to A charging pump wait 10 minutes and then report that

alternate cooling is being supplied.

CRS Initiate plant shutdown. REFER TO the appropriate GOP.

AOP CRS GO TO Step 11.

AOP Crew Within 10 minutes Trip the reactor and Enter EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION

AOP Evaluator Note: The crew will continue with the steps of AOP-118.1 concurrently with the EOP's. The

remaining steps for AOP-118.1 can be found at the end of this guide (page 39)

Transitions to EOP-1.0

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Time Position Applicant's Actions or Behavior

Appendix D 31 NUREG 1021 Revision 9

IOA RO Verify Reactor Trip: Trip the Reactor using either Reactor Trip Switch. Verify all Reactor Trip and Bypass Breakers are open. Verify all Rod Bottom Lights are lit. Verify Reactor Power level is decreasing.

EOP-1.0 IOA BOP Verify Turbine/Generator Trip: a. Verify all Turbine STM Stop VLVs are closed. b. Ensure Generator Trip (after 30 second delay): 1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

EOP-1.0 IOA BOP Verify both ESF buses are energized

EOP-1.0 IOA RO Check if SI is actuated: a. Check if either: a. SI ACT status light is bright on XCP-6107 1-1.

Or b. Any red first out SI annunciator is lit on XCP-626 top row. b. Actuate SI using either SI ACTUATION Switch

EOP-1.0 IOA Crew Check if SI is required: a. Check if any of the following conditions exist: PZR pressure less than 1850 psig. OR RB pressure GREATER THAN 3.6 psig. OR Steamline pressure LESS THAN 675 psig. OR Steamline differential pressure GREATER THAN 97

psig. b. Actuate SI using either SI ACTUATION Switch.

EOP-1.0 RO Trip the RCP(s)

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Time Position Applicant's Actions or Behavior

Appendix D 32 NUREG 1021 Revision 9

AOP CRS GO TO EOP-1.1, REACTOR TRIP RECOVERY, Step 1.

Transitions to EOP-1.1

Crew Announce plant conditions over the page system.

EOP-1.1 BOP Check FW status: Ensure the FW Flow Control Valves, FCV-478(488)(498), are

closed. Ensure the Main FW Isolation Valves, PVG-1611A(B)(C), are closed. Ensure the FW Flow Control Bypass Valves, FCV-3321(3331)(3341), are closed.

EOP-1.1 BOP Ensure EFW Pumps are running: 1) Ensure both MD EFW Pumps are running.

2) Verify the TD EFW Pump is running if necessary to maintain SG levels.

EOP-1.1 BOP Verify total EFW flow is GREATER THAN 450 gpm.

EOP-1.1 BOP Trip all Main FW pumps.

EOP-1.1

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Time Position Applicant's Actions or Behavior

Appendix D 33 NUREG 1021 Revision 9

BOP IF RCS temperature is LESS THAN 557°F AND decreasing, THEN stabilize temperature by performing the following as required:

a) Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

b) Perform one of the following: IF Narrow Range SG level is LESS THAN 26% [41%] in all SGs, THEN reduce EFW flow as necessary to stop cooldown while maintaining total EFW flow GREATER THAN 450 gpm.

OR WHEN Narrow Range SG level is GREATER THAN 26% [41%] in at least one SG, THEN control EFW flow as necessary to stabilize RCS temperature at 557°F. c) COMMENCE ATTACHMENT 1, STEAM VALVE ISOLATION, while

continuing with this procedure.

d) IF RCS cooldown continues, THEN close: MS Isolation Valves, PVM-2801A(B)(C). MS Isolation Bypass Valves, PVM-2869A(B)(C).

EOP-1.1 BOP Determines that IFV03551-EF will not close using the potentiometers (placing the MCB CLOSE/AUTO/MAN switch in CLOSE will close the valve). EOP-1.1 Booth Operator Instructions: If called to locally throttle 3551 use malfunction VLV-EF005P=0 to close the valve.

EOP-1.1 BOP Ensure the TDEFW pump is running

EOP-1.1 CRITICAL

TASK BOP Close the "C" MD FCV or stop the A and B MDEFW pumps prior to

overfilling "C" SG (reaching 100% indicated NR level on IPCS).

EOP-1.1

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Time Position Applicant's Actions or Behavior

Appendix D 34 NUREG 1021 Revision 9 NOTE - Step 4 (N/A)

If a transition is made to AOP-112.2, STEAM GENERATOR TUBE LEAK NOT REQUIRING SI, the steps of EOP-1.1

which do NOT conflict with AOP-112.2

should be completed as time allows.

EOP-1.1 CRS IF EOP-1.0 was entered from AOP-112.2, THEN RETURN TO AOP-112.2, STEAM GENERATOR TUBE LEAK NOT REQUIRING SI, Step 7. (NO) EOP-1.1 CRS GO TO Step 5.

EOP-1.1 RO Verify all Control Rods are fully inserted.

EOP-1.1 BOP Check DA level control: a. Open LCV-3235, DEAER START UP DRAIN CNTRL, as necessary to

maintain DA level LESS THAN 10.5 ft as indicated on LI-3135, DEAER

STOR TK WR LVL FEET. b. Locally adjust ITV-3062A(B)(C), BD COOLER A(B)(C) CDSTE OUT TEMP, to 90% (XPN-0029, NUCLEAR BLOWDOWN PROCESSING

PANEL, AB-436).

EOP-1.1 Booth Operator Instructions: When called to adjust 3062A(B)(C) to 90% closed use trigger 9

to do so. VLV-CO015P, ITV03062A-CO SG BD HX TR A TMP CTRL FAIL POSITION

VLV-CO016P, ITV03062B-CO SG BD HX TR B TMP CTRL FAIL POSITION

VLV-CO017P, ITV03062C-CO SG BD HX TR C TMP CTRL FAIL POSITION

EOP-1.1 RO Check PZR level control: a. Verify PZR level is GREATER THAN 17%. b. Verify Charging and Letdown are in service.

c. Verify PZR level is trending to 25%.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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Time Position Applicant's Actions or Behavior

Appendix D 35 NUREG 1021 Revision 9

EOP-1.1 RO Verify PZR pressure is GREATER THAN 1850 psig.

EOP-1.1 RO Verify PZR pressure is stable at OR trending to 2235 psig (2220 psig to 2250 psig).

EOP-1.1 BOP Verify Narrow Range level in all SGs is GREATER THAN 26%.

EOP-1.1 BOP Control EFW flow to maintain Narrow Range SG level between 40% and

60%. EOP-1.1 BOP Verify all AC buses are energized by offsite power: ESF AC buses BOP AC buses.

EOP-1.1 BOP Verify PERMISV C-9 status light is bright on XCP-6114 1-3.

EOP-1.1 BOP WHEN RCS Tavg is LESS THAN P-12 (552°F), THEN place both STM DUMP INTERLOCK Switches to BYP INTLK.

EOP-1.1 BOP Verify the MS Isolation Valves, PVM-2801A(B)(C), are open.

EOP-1.1 BOP Place the STM DUMP CNTRL Controller in MAN and closed.

EOP-1.1

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Time Position Applicant's Actions or Behavior

Appendix D 36 NUREG 1021 Revision 9

BOP Ensure the STM DUMP CNTRL Controller is set to 8.4.

EOP-1.1 BOP Place the STM DUMP MODE SELECT Switch in STM PRESS.

EOP-1.1 BOP Place the STM DUMP CNTRL Controller in AUTO.

EOP-1.1 NOTE - Step 12

Priority should be given to running RCP A to supply Normal PZR Spray. Since a time lag is expected after increasing steam flow before natural circulation

parameters can be verified, this procedure should be continued concurrently with the establishment of natural circulation.

EOP-1.1 RO Verify RCP A is running. (NO) EOP-1.1 RO Try to start RCP(s) for Normal PZR Spray: IF no RCP can be started, THEN verify natural circulation from trended

values: RCS subcooling on TI-499A(B), A(B) TEMP "F, is GREATER THAN

30°F. SG pressures are stable OR decreasing. RCS Thot is stable OR decreasing. RCS Tcold is at saturation for the current SG pressure. Core exit TC temperatures are stable OR decreasing. IF natural circulation can NOT be verified, THEN increase dumping steam.

EOP-1.1 Evaluator Note: The above step is written as if CCW is not yet restored. When CCW is restored the actions

of AOP-118.1, TOTAL LOSS OF COMPONEN

T COOLING WATER Attachment 4 could be used to restore RCP operation.

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Time Position Applicant's Actions or Behavior

Appendix D 37 NUREG 1021 Revision 9

RO Check the position of NR-45, NIS RECORDER: a. Verify Intermediate Range Power is LESS THAN P-6 (7.5x10-6%).

b. Transfer NR-45, NIS RECORDER, to both Source Range channels.

c. Initiate GTP-702, Attachment VI.KK.

EOP-1.1 Booth Operator Instructions: When called to calibrate the high flux at shutdown alarm (GTP-702, Attachment VI.KK)

report that you are working on it.

Evaluator Note: The above step is written as if power is already below P-6. If power is not below P-6 then

the crew will continue with the procedure and complete the step when power does drop

below P-6.

BOP Shut down and stabilize the Secondary Plant. REFER TO AOP-214.1, TURBINE TRIP.

EOP-1.1 Maintain stable plant conditions: a. Maintain PZR pressure at 2235 psig (2220 psig to 2250 psig).

b. Maintain PZR level at 25%. c. Maintain Narrow Range SG levels between 40% and 60%. d. Maintain RCS temperature: With any RCP running, Tavg at 557°F.

OR With no RCP running, Tcold at 557°F. ' e. REFER TO GOP-5, REACTOR SHUTDOWN FROM STARTUP TO HOT STANDBY (MODE 2 TO MODE 3).

EOP-1.1 COMPLETE Attachment I of SAP-116, PLANT TRIP/SAFETY INJECTION PLANT RECOVERY.

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Time Position Applicant's Actions or Behavior

Appendix D 38 NUREG 1021 Revision 9

EOP-1.1 NOTE - Step 17

If no BOP bus is energized: A natural circulation cooldown should NOT be initiated unless required by Tech Specs, for plant safety, or CST level decreases to LESS THAN 14.5 ft. The System Controller should be notified of plant conditions to determine the expected duration of the power outage.

EOP-1.1 Crew Determine if natural circulation cooldown is required: a. All RCPs are stopped. (YES) b. CST level is LESS THAN 14.5 ft. (NO) EOP-1.1 Crew Notify the SS and Management Duty Supervisor of plant conditions and request direction.

EOP-1.1 Booth Operator Instructions: When contacted as MDS ask for crew's recommended course of action and concur with it.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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Time Position Applicant's Actions or Behavior

Appendix D 39 NUREG 1021 Revision 9

The following actions are from AOP-118.1 after the reactor trip they would be done in conjunction with the EOP steps.

RO 12. Isolate Charging and Letdown: a. Close all Letdown Isolation Valves: 1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

2) LCV-459, LTDN LINE ISOL. 3) LCV-460, LTDN LINE ISOL. 4) HCV-142, LTDN FROM RHR.

b. Close FCV-122, CHG FLOW.

AOP RO Isolate RCP Seals: a. Close MVT-8100, SEAL WTR RTN ISOL. b. Close MVT-8105, SEAL WTR INJ ISOL.

c. Close MVG-9606, FROM RB LOAD ISOL (ORB).

AOP Crew WHEN cooling is established to any Charging Pump, THEN REFER TO ATTACHMENT 4, STARTING A CHARGING PUMP AND SUPPLYING RCP SEAL COOLING, to start the Charging Pump and supply RCP Seal cooling.

AOP CAUTION RCPs should NOT be restarted prior to an Engineering evaluation, to prevent RCP Seal failure.

AOP Booth Operator Instructions: When called to evaluate the ability to supply CCW to the seals and restart the RCP report

that seal injection should not reestablished and that attachment 4 of AOP-118.1 should not

be completed.

AOP

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Time Position Applicant's Actions or Behavior

Appendix D 40 NUREG 1021 Revision 9 CAUTION - Step 15

RHR Pumps should NOT be run longer than 90 minutes without CCW flow to the RHR Heat Exchangers, to prevent RHR Pump damage.

AOP Crew Check if the RHR System is operating. (NO) AOP CRS GO TO Step 19.

AOP Crew Monitor other CCW System loads: a. Monitor the temperatures of other operating components cooled by the

CCW System: Spent Fuel Pool. RCDT. Waste Gas Compressors. Hydrogen Recombiners. Sample Coolers. Recycle Evaporator. Waste Evaporator. Excess Letdown Heat Exchanger. b. At Shift Supervisor discretion, remove loads from service as necessary to prevent equipment damage. REFER TO the appropriate system SOPs.

AOP Crew Check if at least one CCW loop is restored:

(YES) AOP Booth Operator Instructions: When called to give direction for AOP-118.1 report that CCW should be returned to service

in accordance with SOP-118 and that all loads should be restored to service except for

RCP thermal barriers so that a bubble is not formed in CCW and that normal charging and letdown should be returned to service in accordance with SOP-102.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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Time Position Applicant's Actions or Behavior

Appendix D 41 NUREG 1021 Revision 9

Evaluator Note: At this point AOP-118.1 loops back on itself but direction was given by management in the previous Booth Operator Instruction.

USES SOP-118 section B.2.4 RO Place XPP-58A(B)(C), CCBP A(B)(C), standby pump in OFF.

SOP RO Ensure MVB-9503A, CC TO RHR HX A, is open.

SOP RO Start one of the following in slow speed: (PEER ) 1) XPP-0001B, PUMP B. Prior to establishing Letdown.

SOP CAUTION 2.3.c and 2.3.d

Failure to complete Step 2.3.d in a timely manner after reducing RHR Heat Exchanger flow will result in a loss of flow through the running CCW Pump or excessive flow perturbations in the CCW non-essential loop.

SOP RO Start MVB-9503A, CC TO RHR HX A, stroking in the closed direction.(PEER ) SOP RO When flow, as indicated on FI-7034, HX B FLOW GPM, is between 5000 gpm and 4000 gpm, perform the following in rapid succession: 1) Open MVB-9687B/9525B, LP A NON-ESSEN LOAD ISOL.

2) Open MVB-9524B/9526B, LP A NON-ESSEN LOAD ISOL.

3) Close MVB-9524A/9526A, LP B NON-ESSEN LOAD ISOL.

4) Close MVB-9687A/9525A, LP B NON-ESSEN LOAD ISOL. 5) Open MVB-9503A, CC TO RHR HX A.

SOP

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Time Position Applicant's Actions or Behavior

Appendix D 42 NUREG 1021 Revision 9

Crew Locally verify greater than 1 gpm sample flow on RML0002

B, LIQUID RAD

MON COMPONENT COOLING (IB-412).

SOP Booth Operator Instructions: When called to verify flow on RM-L2 report that it is >5gpm.

RO Ensure the following valves have not automatically closed due to high flow:

1) MVG-9625, CC TO RB.

2) MVG-9626, CC TO RB. 3) MVG-9583, FROM XS LTDN HX.

4) MVT-9593A(B)(C), FROM RCP A(B)(C) THERM BARR.

SOP RO Transfer the in-service Charging Pump to Train

B per SOP-102.

SOP Booth Operator Instructions: If asked to return normal cooling to Charging pump tell them that you will return the

system to prevent status by using the return as found on Attachment 1A

SOP RO Ensure XPP-58A(B)(C), CCBP A(B)(C) are aligned as follows (MCB): 1) One pump is in AUTO and operating. 2) One pump is in AUTO and not operating.

3) One pump is in OFF.

SOP Evaluator Note: The following steps return normal charging and letdown to service. Uses SOP-102 section IV.M.2 Place FCV-122, CHG FLOW, in MAN and close.

SOP Place PCV-145, LO PRESS LTDN, in MAN and open to 70%. (PEER )

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 43 of 52 Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicant's Actions or Behavior

Appendix D 43 NUREG 1021 Revision 9

SOP Place TCV-144, CC TO LTDN HX, in MAN and open to 100%.

SOP Place TCV-143, LTDN TO VCT OR DEMIN, in VCT.

SOP Open PVT-8152, LTDN LINE ISOL.

SOP Open the following: a. LCV-459, LTDN LINE ISOL. b. LCV-460, LTDN LINE ISOL.

SOP Ensure the following Charging Line Isolation Valves are open: a. MVG-8107, CHG LINE ISOL. b. MVG-8108, CHG LINE ISOL.

SOP Slowly open FCV-122, CHG FLOW, to establish 60 gpm flow as indicated on FI-122A, CHG FLOW GPM.

SOP Open Orifice Isolation Valves to obtain the desired Letdown flow rate (60 gpm to 120 gpm):

a. PVT-8149A, LTDN ORIFICE A ISOL (45 gpm).

b. PVT-8149B, LTDN ORIFICE B ISOL (60 gpm).

c. PVT-8149C, LTDN ORIFICE C ISOL (60 gpm).

SOP Adjust FCV-122, CHG FLOW, as required to maintain TI-140, REGEN HX OUT TEMP °F, between 250°F and 350°F while maintaining Pressurizer

level. SOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 44 of 52 Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicant's Actions or Behavior

Appendix D 44 NUREG 1021 Revision 9

Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.

SOP Place PCV-145, LO PRESS LTDN, in AUTO.

SOP Adjust TCV-144, CC TO LTDN HX, potentiometer as necessary to maintain the desired VCT temperature and place in AUTO. Refer to VCS Curve

Book, Figure VII.15.

SOP When Pressurizer level is within 1% of and trending to programmed level, place the PZR LEVEL MASTER CONTROL in MAN.

SOP Establish automatic FCV-122, CHG FLOW, control as follows: a. Determine the correct PZR LEVEL MASTER CONTROL setpoint by dividing the current Charging flow by 1.5.

b. Manually adjust the PZR LEVEL MASTER CONTROL to this setpoint.

c. Place FCV-122, CHG FLOW, in AUTO. (PEER ) SOP Adjust PZR LEVEL MASTER CONTROL in MAN, as necessary, to maintain Pressurizer level at or near programmed level.

SOP When Pressurizer level is within 1% of and trending to programmed level, place PZR LEVEL MASTER CONTROL in AUTO. (PEER ) SOP Monitor LR-459, PZR % LEVEL & LEVEL SP, recorder to verify that Charging flow is maintaining actual Pressurizer level at or near the

programmed setpoint.

SOP

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 45 of 52 Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicant's Actions or Behavior

Appendix D 45 NUREG 1021 Revision 9

After the Letdown temperatures have stabilized, place TCV-143, LTDN TO VCT OR DEMIN, in DEMIN/AUTO.

SOP After letdown is established, the lead evaluator can cue the Safety Valve failure

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 46 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 46 NUREG 1021 Revision 9 Booth operator; when directed activate trigger 7

RO Reports rapidly lowering RCS Pressure/AUTO SI. EOP-1.1

CRS Returns to EOP-1.0.

Evaluator's Note: The EOP-1.0 Reference Page Criteria that applies in this scenario is: REDUCING CONTROL ROOM EMERGENCY VENTILATION * Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505,

CONTROL BUILDING VENTILATION SYSTEM.

Evaluator's Note: Actions for ATTACHMENT

3, SI EQUIPMENT VERIFICATION, are

provided on the final 3 pages of this scenario guide. There is a

critical task to close at least one Phase "A" Isolation Valve in each line that has not properly isolated. EOP-1.0

BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION

(at end of scenario form D2

. CRITICAL

TASK BOP Either actuates containment isolation manually with switch SG02B or individually closes at least one valve in each line (expected to use the

one operable switch, CS-SG02A is failed).

EOP-1.0 CRITICAL

TASK BOP Manually opens either MVG-8801A or B to establish a high head injection path. (This must be accomplished prior to NR RVLIS reaching 34% density with no RCPs running-Orange Path challenge to Core

Cooling.) EOP-1.0 CREW Announce plant conditions over the page system. EOP-1.0

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 47 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 47 NUREG 1021 Revision 9

RO Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB PSIG (P-951), red pen

(YES) EOP-1.0

RO Check RCS temperature:

With any RCP running, RCS Tavg is stable at OR trending to 557°F.

With no RCP running, RCS Tcold is stable at OR trending to 557°F.

(NO) EOP-1.0

BOP IF RCS temperature is LESS THAN 557

ûF AND decreasing, THEN stabilize temperature by performing the following as required:

Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

Perform one of the following:

IF Narrow Range SG level is LESS THAN 26% [41%] in all SGs, THEN reduce EFW flow as necessary to stop cooldown, while maintaining total EFW flow GREATER THAN 450 gpm. OR

WHEN Narrow Range SG level is GREATER THAN 26% [41%] in at least one SG, THEN control EFW flow as necessary to stabilize RCS temperature at 557

ûF. COMMENCE ATTACHMENT 6, STEAM VALVE ISOLATION, while continuing with this procedure.

IF RCS cooldown continues, THEN close:

MS Isolation Valves, PVM-2801A(B)(C).

MS Isolation Bypass Valves, PVM-2869A(B)(C). EOP-1.0

RO Check PZR PORVs and Spray Valves:

PZR PORVs are closed.

(YES) PZR Spray Valves are closed.

(YES) Verify power is available to at least one PZR PORV Block Valve:

(YES) MVG-8000A, RELIEF 445 A ISOL.

MVG-8000B, RELIEF 444 B ISOL

MVG-8000C, RELIEF 445 B ISOL.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 48 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 48 NUREG 1021 Revision 9

Verify at least one PZR PORV Block Valve is open.

(YES) EOP-1.0 Procedure Note: Seal Injection flow should be maintained to all RCPs. EOP-1.0 RO Check if RCPs should be stopped (already stopped)

EOP-1.0 BOP Verify no SG is FAULTED:

No SG pressure is decreasing in an uncontrolled manner.

(YES) No SG is completely depressurized.

(YES) EOP-1.0

CREW Verify Secondary radiation levels indicate SG tubes are NOT RUPTURED: (

YES to all)

RM-G19A (B) (C) STMLN HI RNG GAMMA

RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.

RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.

RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR. EOP-1.0 RO Check if the RCS is INTACT: (

NO to any or all)

RB radiation levels are normal on:

RM-G7, CONTAINMENT HI RNG GAMMA

RM-G18, CNTMNT HI RNG GAMMA.

RB Sump levels are normal.

RB pressure is LESS THAN 1.5 psig.

The following annunciators are NOT lit:

XCP-606 2-2 (RBCU 1A/2A DRN FLO HI)

XCP-607 2-2 (RBCU 1B/2B DRN FLO HI) EOP-1.0

CRS Transitions to EOP-2.0,

LOSS OF REACTOR OR SECONDARY COOLANT.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 49 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 49 NUREG 1021 Revision 9 EOP-2.0 Procedure Notes: * The EOP REFERENCE PAGE should be monitored throughout

the use of this procedure. * Seal Injection flow should be maintained to all RCPs. * Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN. EOP-2.0 RO Check if RCPs should be stopped (None running). EOP-2.0 BOP Verify no SG is FAULTED

No SG decreasing in an uncontrolled manner (YES) No SG completely depressurized (YES) EOP-2.0 BOP Check Intact SG levels

NR level in intact SGs >26% [41%]

Control EFW flow to maintain 40-60% NR level EOP-2.0 RO Reset both SI RESET TRAIN A(B) Switches. EOP-2.0 RO Reset Containment Isolation:

RESET PHASE A - TRAIN A(B) CNTMT ISOL.

RESET PHASE B - TRAIN A(B) CNTMT ISOL. EOP-2.0 RO/BOP Check if Secondary radiation levels are normal: (

YES to all)

Check radiation levels normal on:

RM-G19A(B)(C), STMLN HI RNG GAMMA.

RM-A9, CNDSR EXHAUST GAS ' ATMOS MONITOR.

RM-L3, STEAM GENERATOR ' BLOWDOWN LIQUID MONITOR.

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 50 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 50 NUREG 1021 Revision 9

RM-L10, SG BLOWDOWN CW ' DISCHARGE LIQUID MONITOR.

Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.

Notify Chemistry to sample all SG secondary sides, and screen samples for abnormal activity using a frisker. EOP-2.0 RO Check PZR PORVs and Block Valves:

Verify power is available to the PZR PORV Block Valves:

MVG-8000A, B, C

(YES) Verify all PZR PORVs are closed. (YES) Verify at least one PZR PORV Block Valve is open.

(YES) EOP-2.0 RO/BOP Place both ESF LOADING SEQ A(B) RESETS to:

NON-ESF LCKOUTS

AUTO-START BLOCKS EOP-2.0 RO Establish Instrument Air to the RB:

Start one Instrument Air Compressor and place the other in Standby.

Open PVA-2659, INST AIR TO RB AIR SERV.

Open PVT-2660, AIR SPLY TO RB. EOP-2.0 RO Check if SI flow should be reduced:

RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN

52.5 °F.

(NO) EOP-2.0 CRS GO TO Step 11. EOP-2.0 RO Check if RB Spray should be stopped:

Check if any RB Spray Pumps are running.

(NO)

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 51 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 51 NUREG 1021 Revision 9 CRS GO TO Step 12. Observe the CAUTION prior to Step 12.

RO Check if RHR Pumps should be stopped: (

YES) Stops any running RHR pump EOP-2.0 RO Check if RCS pressure is stable or decreasing.

(YES) EOP-2.0 BOP Check if pressure in all SGs is stable or increasing.

(YES) EOP-2.0 BOP Check if DGs should be stopped:

Verify both ESF buses are energized by offsite power.

(YES) Stop any unloaded DG. REFER TO SOP-306, EMERGENCY DIESEL GENERATOR. EOP-2.0 RO Verify equipment is available for Cold Leg Recirculation:

Verify power is available for at least one RHR Pump: (

YES) Open both MVB-9503A(B), CC TO RHR HX A(B). Caution step 16.c: * If the swing CCW Pump is NOT available, the running pump should NOT be secured to shift it to fast speed, to prevent damage to the Charging Pump on that train

. Leaves the one running CCW in SLOW speed

RO Check the AB for evidence of ECCS leakage (

NO) EOP-2.0

RO Obtain necessary chemistry samples EOP-2.0

RO Shutdown and stabilize the Secondary Plant EOP-2.0

RO Check If RCS Cooldown and Depressurization is required (

YES)

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 9 Page 52 of 52 Event Description: PZR Safety valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 52 NUREG 1021 Revision 9

RCS pressure greater than 325 psig (

YES) EOP-2.0

CRS Goes TO EOP-2.1 POST-LOCA COOLDOWN AND

DEPRESSURIZATION (crew brief expected).

Evaluator's Note; Scenario may be terminated after transition to EOP-2.1

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-1

Appendix D 1 NUREG 1021 Revision 9

Facility: VC SUMMER Scenario No:

Spare Op Test No.:

2011 NRC Examiners: Operators: CRS RO BOP Initial Conditions: 43% Power, MOL, GOP-4a, Step 3.12L (IC-304 for 2011) "B" EDG is OOS to clean the lube oil strainer "B" RB spray pump is out of service for bearing replacement National Weather Service has issued a severe weather alert due to a line of heavy thunderstorms moving into the area Turnover: Raise power to 100%

Critical Task: Actuate SI manually

prior to Core Cooling Orange Path challenge

Trip Reactor Coolant Pumps prior to Core Cooling Orange Path challenge

Isolate the leak by closing MVG-8888B prior to exiting EOP-2.5 (ECA-1.2) Actuate one train of Control Room emergency Ventilation

prior to completion of EOP-

1.0 Attachment 3

Event No. Malf. No. Event Type* Event Description

1. ANN-EM008 C-BOP, CRS High temperature on Transformer 1A1 requires transfer of 480V busses 1A1 and 1A2 to alternate power

. BOP-1 2. CRF004L11 C-RO, CRS TS-CRS Dropped control rod

RO-2 N/A N-BOP, CRS R-

RO, Decrease power to recover rod 3. MAL-PRS001A I-RO, CRS PT-444 fails high

RO-3 4. PMP-CS004B C-RO, CRS TS-CRS Running charging pump bearing seizes

RO-1 5. CNH-FW002O C-BOP, CRS FW Bypass valve fails open.

BOP-2 6. VLV-RH007L VLV-RH009L FLX-RHR001 M-ALL Non isolable LOCA outside containment

7. MAL-PCS005A MAL-PCS005B C-ALL Failure of SI to auto-initiate.

8. PMP-AH022F

and AH023F C-BOP Failure of XFN-30A,B, EMERG FLTR FAN A,B to start. * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-1

Appendix D 2 NUREG 1021 Revision 9 The crew will assume the watch having pre-briefed on the Initial Conditions.. A high temperature alarm is received on the 1A1 transformer. Busses 1A1 and 1A2 must be transferred to alternate power. BOP determines that a fault does not exist on the bus and energizes 1A1 and 1A2 by using the tie breakers (tie breakers need to be pulled up to operate). The 1A1-1A2 feeder breaker must be manually opened to deenergize the transformer; if it is opened prior to closing the tie breaker a loss of power to 1A1 and

1A2 will occur: a trouble alarm for the B IA compressor would be received: it clears when power is reestablished. HVAC alarms would indicate that XFN-17A, XFN-24A, XFN-15 and XFN-24 all tripped (AB ventilation is secured). The crew directs the control building operator to reestablish AB ventilation if it is lost. It is important to reestablish AB ventilation to be able to detect the LOCA outside containment later in the scenario. XCP-632,3-3 GEN AUX PNL TRBL, is also received due to a loss of power to the running stator water cooling pump. The turbine building operator reports that the cause of the alarm is XPN-7201 5-2, RESERVE PUMP RUNNING/PULL TO LOCK: the standby stator pump started with normal flow and pressure. The loss of power also affects exhaust hood spray pump A and vacuum pump C but since those pumps are not running no actions are necessary. Control rod L-11 drops into the core. AOP-403.6, DROPPED CONTROL ROD is entered and RX engineering requests that rod recovery occur at 35% power. Crew reduces power with rods in manual. CRS refers to TS

3.1.1.1, 3.1.3.1, 3.1.3.6, 3.2.4.. 3.1.1.1 is Shutdown margin: STP 134.001 states that SDM is assumed due to cycle design and a SDM calculation is not required. 3.1.3.1 is Group height +/- 12 steps, action d.3 requires reevaluation within 5 days, SDM verification, power distribution monitoring, and thermal power reduction to <75% and high flux trip setpoint reduction to 85% within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. 3.1.3.6 is RIL and makes the misaligned rod

be brought up to the bank (precludes the insertion of the bank to pick up the rod). 3.2.4 is QPTR and requires that the QPTR be in limits above 50% (not applicable since below 50%). Rod will not be recovered. While power is being decreased, PT-444 fails high. This causes PCV-444B, PWR RELIEF, (Pressurizer PORV) to open as well as the PZR sprays to open. This is ramped to give the RO time to diagnose the failure while conducting task of down power. The crew enters AOP-401.5, PRESSURIZER PRESSURE CONTROL CHANNEL FAILURE, to regain control of pressure. If primary pressure goes below 2206 psig, the CRS will

enter TS 3.2.5 POWER DISTRIBUTION LIMITS: DNB PARAMETERS. The A charging pump bearing gradually seizes, permitting either a manual trip or automatic trip on overcurrent. Damage to the A charging pump may cause the crew to enter TS 3.5.2 for a loss of a ECCS system until the C pump is racked up on A train and the A charging pump is racked down. The crew will use AOP-102.2, LOSS OF CHARGING, to reestablish charging and letdown. FW Bypass valve to A SG fails open increasing flow to A SG. BOP should take manual control of feed regulating valve and control level per the ARP to avoid the requirement for manual Reactor trip at 75% level. During the down power the plant experiences a LOCA outside containment due to leaking SI check valves from the RCS loops to RHR (via 8888B) the increased pressure causes a flex leak before the third check valve

to the B RHR pump. The crew will go through AOP-101.1, LOSS OF REACTOR COOLANT NOT REQUIRING SI and determine that an SI is required. A critical task will be for the crew to actuate SI prior to exiting EOP-1.0 (E-0). In EOP-1.0 (E-0) the BOP will discover that neither CB emergency filter fans started as required and will start at least one of the fans; starting one train is critical to limit control room dose during a LOCA outside Containment. The crew will go through EOP 1.0 (E-0) and determine that the RCS leak is outside of containment and transition to EOP-2.5 (ECA-1.2). The crew will isolate the leak and transition to EOP-2.0

(E-1). The scenario can be terminated at this point

.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-1

Appendix D 3 NUREG 1021 Revision 9

VCS 2011 NRC Spare Scenario Simulator Setup (SNAP 304 or 308)

Initial Conditions: 40% Power, MOL, GOP-4a, Step 3.16 Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires. Conduct two-minute drill Mark up procedures in use with "Circle and slash" as applicable Pre-Exercise:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions,

chart recorders, etc.)

TQP-801 Booth Operator checklist, has been completed

Hang Red Tags for equipment out of service

Ensure limiter is at 120% (fully off the limiter).

Ensure all BOP tie breakers are in the full down position.

PRE-LOAD

LOA AUX 118 = RACK OUT "B" RB Spray pump breaker LOA-EPS114 = MAINTENANCE ("B" EDG OOS) MAL PCS005A SAFETY INJECTION FAILURE TRAIN A = FAIL TO AUTO INIT MAL PCS005B SAFETY INJECTION FAILURE TRAIN B = FAIL TO AUTO INIT MAL PMP-AH022F CNTRL ROOM EMERG FAN A FAIL TO START MAL PMP-AH023F CNTRL ROOM EMERG FAN B FAIL TO START OVR RH017B, 018B, and RH007 = OFF/FALSE (keeps RHR valve red lights off)

Trigger 1: Loss of 480VAC bus 1A1 Insert ANN-EM008 XFMR XTF-1A1 HIGH TEMP = ON

Trigger 2: Dropped control rod Malfunction CRF004L11 DROPPED ROD L11 = Stationary Power reduction to recover rod Trigger 3: Master PZR pressure PT-444 fails high Malfunction PRS001A PRESSURIZER PRESSURE CHANNEL 444 FAILURE = 2500#, 30 second

ramp Trigger 4: A charging pump bearing seizes leading to trip Malfunction PMP-CS004B severity 10, 5 minute ramp.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-1

Appendix D 4 NUREG 1021 Revision 9 Trigger 5: Feedwater bypass flow control valve fails open Malfunction CNH-FW002O FW BYPASS VALVE FV-3321 FAILURE =100%, 90 sec ramp Trigger 6: LOCA outside containment Malfunction MAL-RHR013B = 0.05 RHR DISCH CHECK VALVE 8974B LEAKAGE (0.05=800 GPM) Malfunction MAL-RHR013E = 0.05 RHR DISCH CHECK VALVE 8973C LEAKAGE (0.05=800 GPM) Malfunction FLX-RHR011at RLF VLV 8864B = 2500

gpm Trigger 7: rack up C charging pump (when directed by crew) LOA-CVC043 CHARGING PUMP C SUPPLY BRKR TRAIN A = RACK IN LOA-CVC041 CHARGING PUMP C SUPPLY BRKR TRAIN B = RACK OUT Trigger 8: Restart of AB ventilation system (if directed by crew) OVR-AH058E SS-AH011 A.B. HEPA EXH FAN(XFN-24A-AH) SWITCH = True OVR-AH045C CS-AH005 A.B. MAIN SUPPLY FAN(XFN-15A-AH) = True OVR-AH046C CS-AH005 A.B. MAIN SUPPLY FAN(XFN-17A-AH) = True OVR-AH053E SS-AH173 F.H.B. SUPPLY FAN(XFN-20-AH) ST= True

Trigger 9: Match flags on Stator Water cooling LOA-TUR015 Stator Water cooling pump A to OFF LOA-TUR016 Stator Water cooling pump B to ON Trigger 10: Energize RHR Loop A suction valves LOA RHR009 (8701A, 1DA2X) and LOA RHR011 (8702A, 1DB2Y) = CLOSE Trigger 11: Energize RHR Loop B suction valves LOA RHR010 (8701B, 1DA2Y) and LOA RHR012 (8702B, 1DB2Y) = CLOSE Trigger 29: Allow Control Room Emergency fan to start MAL PMP-AH022F CNTRL ROOM EMERG FAN A FAIL TO START Delete in 1 sec. Event: X16I036T == 1 Trigger 30: Allow Control Room Emergency fan to start MAL PMP-AH023F CNTRL ROOM EMERG FAN B FAIL TO START Delete in 1 sec. Event: X16I038T ==1

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 1 Page 5 of 44 Event Description: High temperature on BOP transformer XTF-1A1 requires transfer of BOP loads

Time Position Applicant's Actions or Behavior

Appendix D 5 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 1

Indications available: Electrical panel alarm XCP-635 Point 1-1 XFMR XTF 1A1 HIGH TEMP lit

ARP XCP-635 Pt 1-1

BOP Acknowledges alarm and opens Annunciator Response procedure.

ARP BOP Directs TB operator to investigate transformer XTF-1A1

ARP Booth Instructor: When contacted as Turbine Building operator, report XTF-1A1 winding temperatures indicate 200°Centigrade, smell of hot insulation, NO FIRE at XTF-1A1. If asked if the fan is running respond that it is not and that it will not start.

BOP Determines that a fault does not exist on either buss and energizes 1A1

and 1A2 by using

SOP-308, 480 VOLT NON-ESF DISTRIBUTION

SOP-308 section IV.A.2

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 1 Page 6 of 44 Event Description: High temperature on BOP transformer XTF-1A1 requires transfer of BOP loads

Time Position Applicant's Actions or Behavior

Appendix D 6 NUREG 1021 Revision 9

SOP-308 section IV.A.2

CAUTION:

Instrument Air Compressor A should be in

service before closing the 1B3-1A1 Bus Tie Breaker, as closing the 1B3-1A1 Bus Tie Breaker will trip Instrument Air

Compressor B.

NOTE:

a. Automatic Sync-check takes a few seconds

for the breaker to close. The amount of

time parallel feeding occurs on each bus should be kept to a minimum.

b. XSW1A3 - 1C3 Tie Breaker closure affects CRDM Shroud Exhaust fan operation as

follows: 1) If both XFN0067A and XFN0067B are ra

cked in, then regardless of the operating

fan combination, XFN0067C and XFN0067D will be tripped and XFN0067A and XFN0067B will start when the tie breaker is closed.

2) If either XFN0067A or

XFN0067B is not racked in, then regardless of

the operating

fan combination, neither XFN0067C nor

XFN0067D will be tripped and XFN0067A and FN0067B will not be started

when the tie breaker is closed.

SOP BOP Perform the following for bus

es having Bus Tie Breakers (XSW1A1, XSW1A2, XSW1A3, XSW1B1, XSW1B2, XSW1B3, XSW1B4, XSW1C1, XSW

1C3 and XSW1C4): a. Pull the Bus Tie Breaker cont

rol switch up, to the Manual

position. b. Close the Bus Tie Breaker.

c. Open the 480 Volt Main Incoming Breaker to disconnect the

480 Volt Bus from the transformer being removed from

service.

SOP BOP Perform the following steps on th

e affected 480 Volt Buses not

having a Bus Tie Breaker connection:

(NONE)

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 1 Page 7 of 44 Event Description: High temperature on BOP transformer XTF-1A1 requires transfer of BOP loads

Time Position Applicant's Actions or Behavior

Appendix D 7 NUREG 1021 Revision 9

SOP BOP Open the 7.2 KV/480V Trans

former Feeder Breaker.

SOP Caution:

Opening a breaker does not provi

de an acceptable safety margin for electrical work. The breaker should be racked out and any associated air disconnects opened prior to

commencing maintenance.

SOP Crew Calls AO to: Unlock and remove the key from the 480 Volt Main Incoming

Breaker reinstating the interlock.

Place the key in the 7.2 KV/480V Bank Disconnect and unlock it.

Open the 7.2 KV/480V Bank Disconnect.

Booth Instructor: When called to finalize the removal of the transformer report that

electrical maintenance has requested that it be left in the current configuration and that

they will bringing up a troubleshooting plan.

Crew Notifies SS and Electrical Maintenance of failure

ARP Evaluator's note; if tie breakers are closed prior to opening 7.2KV transformer feeder breaker, no loads are lost. The following events are included if the bus is deenergized.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 1 Page 8 of 44 Event Description: High temperature on BOP transformer XTF-1A1 requires transfer of BOP loads

Time Position Applicant's Actions or Behavior

Appendix D 8 NUREG 1021 Revision 9

BOP A trouble alarm for the B IA compressor is received: it clears when power

is reestablished. Not expected; ARPs

BOP HVAC alarms indicate that XFN-17A, XFN-24A, XFN-15 and XFN-24 all tripped (Aux Bldg ventilation is secured). The crew directs the control

building operator to reestablish AB ventilation. It is important to reestablish

AB ventilation to be able to detect the LOCA outside containment later in

the scenario. Not expected; ARPs

BOP XCP-632,3-3 GEN AUX PNL TRBL, is also received due to a loss of power to the running stator water cooling pump. Not expected; ARPs Booth operator instructions; when contacted as the turbine building operator, report standby stator water coolant pump running and use Trigger 9 to match flags and clear

alarm Not expected; ARPs Crew Notifies Electrical Maintenance of failure

Booth Operator Instructions: When called respond as EM that transformer temperatures

are 200°F and the fan is not running.

BOP Directs TB operator to investigate generator aux panel alarm Not expected; ARPs

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 1 Page 9 of 44 Event Description: High temperature on BOP transformer XTF-1A1 requires transfer of BOP loads

Time Position Applicant's Actions or Behavior

Appendix D 9 NUREG 1021 Revision 9

Booth Operator Instructions: When called as TB operator respond "The turbine building operator reports that the cause of the alarm is XPN-7201 5-2, RESERVE PUMP

RUNNING/PULL TO LOCK: the standby stator pump started with normal flow and pressure." Use Trigger 9 to match flags on stator cooling water pumps. Not expected; ARPs Crew Directs Control Bldg operator to restart AB ventilation Not expected; ARPs

Booth Operator Instructions: When called as Control Building insert Trigger 8 to restart ventilation systems

Not expected; ARPs Crew Conducts post-event brief, contacts SS. Not expected; ARPs

At the discretion of the Lead Examiner, proceed to the next event

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 2 Page 10 of 44 Event Description: Dropped control rod

Time Position Applicant's Actions or Behavior

Appendix D 10 NUREG 1021 Revision 9 Booth Instructor: when directed activate trigger 2

Indications available: XCP-621 pt. 3-1 ONE ROD ON BOTTOM XCP-620 pt. 1-4 PR CHAN DEV XCP-620 pt. 1-5 PR UP DET FLUX HI DEV AUTO DEFEAT

XCP-620 pt. 1-6 PR LOW DET FLUX HI DEV AUTO DEFEAT

XCP-621 DRPI ALARM NON-URGENT

10% reduction in Power range NI-44 reading

ARP XCP-621 pt. 3-1

Crew Refer to alarm response procedures

ARP PROBABLE CAUSE: 1. A shutdown or control group rod fails to withdraw.

2. A shutdown or control group rod dropped (yes). 3. DRPI System malfunction.

4. Plant shutdown in progress.

ARP AUTOMATIC ACTIONS:

2. Automatic outward rod motion to match Tave to Tref until the withdrawal limit is reached.

ARP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 2 Page 11 of 44 Event Description: Dropped control rod

Time Position Applicant's Actions or Behavior

Appendix D 11 NUREG 1021 Revision 9

CRS CORRECTIVE ACTIONS: 2. If a shutdown or control group rod has dropped and the Reactor did not

trip (yes), implement AOP-403.6, Dropped Control Rod.

Enters AOP-403.6

IOA RO Verify only one Control Rod has dropped (yes). AOP IOA RO Place ROD CNTRL BANK SEL Switch in MAN.

AOP Crew Stabilize the plant; a. Decrease Main Turbine load to maintain Tavg within 5°F of T

ref . b. Verify PZR pressure is stable or trending to 2235 psig

(2220 psig to 2250 psig).

c. Verify PZR level is stable at OR trending to program level.

AOP RO Check if Reactor power is LESS THAN 75%. (yes) AOP CRS Initiate GTP-702, Attachments IV.A, IV.B, and IV.C to monitor Shutdown Margin, rod deviation, and rod insertion.

AOP CRS Notify the following plant personnel prior to moving Control Rods:

Management Duty Supervisor and Rod Control System Engineer.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 2 Page 12 of 44 Event Description: Dropped control rod

Time Position Applicant's Actions or Behavior

Appendix D 12 NUREG 1021 Revision 9

CRS Provide Reactor Engineering with the following information:

AOP RO Determine and correct the cause of the failure (will not be corrected).

AOP NOTE - Step 9 This Step

must be completed before continuing with Step 10.

AOP RO Obtain the following information from Reactor Engineering:

Power level at which recovery is to be performed: (35%). Rate of Control Rod movement during recovery:

no restriction

AOP Booth Operator Instructions:

When called as Reactor Engineering, direct recovery at 35% power, with no restriction on the rate of control rod movement during the recovery.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 2 Page 13 of 44 Event Description: Dropped control rod

Time Position Applicant's Actions or Behavior

Appendix D 13 NUREG 1021 Revision 9

AOP Crew If necessary, reduce Reactor Power to the power level determined in Step 9. REFER TO GOP-4B, POWER OPERATION (MODE 1 - DESCENDING) OR GOP-4C, RAPID POWER REDUCTION.

AOP Evaluator Note: GOP-4B expected due to small size of power reduction

Uses GOP-4B

NOTE 3.3 Step 3.3 lowers Reactor Power from 48% to 25%.

GOP BOP Reduce load

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 2 Page 14 of 44 Event Description: Dropped control rod

Time Position Applicant's Actions or Behavior

Appendix D 14 NUREG 1021 Revision 9

GOP BOP As load decreases, adjust Megavars using GEN FIELD VOLT ADJ as requested by the Load Dispatcher and within the Estimated Generator

Capability curve (Enclosure A).

GOP RO As load decreases, Borate or dilute per SOP-106, Reactor Makeup Water System, to maintain Control Rods above the Rod Insertion Limit

(rods are left in manual, AOP adjusts turbine load to keep Tavg within 5°F of

program). GOP After a >5% power change, proceed to the next event with Lead Evaluator concurrence.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 3 Page 15 of 44 Event Description: PZR Pressure Transmitter PT-444 fails high

Time Position Applicant's Actions or Behavior

Appendix D 15 NUREG 1021 Revision 9

Booth Instructor: When directed, activate trigger 3

Indications available:

XCP-616, 2-5, PZR PCS HI

XCP-616, 2-3, PZR PRESS HI/LO

XCP-616, 2-6, PZR CNTRL PRESS HI XCP-616, 4-1, PZR SAFETY VLV LINE TEMP HI XCP-616, 4-2, PZR RLF LINE TEMP HI

XCP-616, 4-3, PZR RLF VLV ISOL

1 PORV and two spray valves open (red lights on, green lights off)

Crew Refer to alarm response procedures

Crew Refer to XCP-616, 2-5

ARP XCP-616, 2-5

PROBABLE CAUSE: 1. Rapid load reduction. 2. Instrument malfunction (yes). 3. Pressure controller failure.

ARP AUTOMATIC ACTIONS:

1. Pressurizer heaters cut off. 2. PCV-444B, PWR RELIEF, opens. 3. PCV-444C(444D), PZR SPRAY, open fully.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 3 Page 16 of 44 Event Description: PZR Pressure Transmitter PT-444 fails high

Time Position Applicant's Actions or Behavior

Appendix D 16 NUREG 1021 Revision 9

ARP CORRECTIVE ACTIONS:

RO Compare PI-444, CNTL CHN PRESS PSIG, with other Pressurizer pressure indications to determine if IPT00444, PRESSURIZER PRESSURE

CONTROL PRESS XMTR, has failed high (yes). ARP RO If IPT00444, PRESSURIZER PRESSURE CONTROL PRESS XMTR, has

failed high (yes),perform the following: a. Close PCV-444B, PWR RELIEF.

b. Close PCV-444C, PZR SPRAY, and PCV-444D, PZR SPRAY.

c. Turn on Pressurizer heaters as necessary to control pressure. d. Place the PZR PRESS MASTER CONTROL in MAN and control pressure

manually. e. Refer to AOP-401.5, Pressurizer Pressure Control Channel Failure.

ARP CRS Transitions to AOP-401.5, Pressurizer Pressure Control Channel Failure

Enters AOP-401.5 NOTE: Through this procedure, "AFFECTED" refers to any PZR PORV that has actuated as a result of the instrument failure.

AOP IOA RO Verify the PZR PORVs are closed: (NO) AOP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 3 Page 17 of 44 Event Description: PZR Pressure Transmitter PT-444 fails high

Time Position Applicant's Actions or Behavior

Appendix D 17 NUREG 1021 Revision 9

IOA RO IF PZR pressure is LESS THAN 2300 psig, THEN perform the following: Close the AFFECTED PZR PORV(s): PCV-445A, PWR RELIEF

(NO) PCV-445B, PWR RELIEF

(NO) PCV-444B, PWR RELIEF

(YES) AOP NOTE - Step 2 PZR PRESS control channels PI-444 and PI-445 connect to the same reference leg line as protection channel PI-457.

AOP IOA RO Compare the PZR control channel indication to the protection channel indications: (ONLY 444 reading high) PI-455, PRESS PSIG PI-456, PRESS PSIG PI-457, PRESS PSIG

AOP IOA RO Check if PI-444, CNTROL CHAN PRESS PSIG, indication is NORMAL. (NO) AOP IOA RO a) Ensure the PZR Spray Valves are

closed:

• PCV-444C. PZR SPRAY

• PCV-444D, PZR SPRAY

b) Control PZR PRESS MASTER CONTROL in MAN. c) Operate the PZR Heaters and Spray Valves in manual to control RCS pressure between 2220 psig and 2250 psig. d) Within one hour; close MVG-8000B. RELIEF 444 B ISOL

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 3 Page 18 of 44 Event Description: PZR Pressure Transmitter PT-444 fails high

Time Position Applicant's Actions or Behavior

Appendix D 18 NUREG 1021 Revision 9

AOP RO Check if PI-445, CNTRL CHAN PRESS PSIG, indication is NORMAL. (YES) AOP CRS Determine above action satisfies Technical Specification 3.4.4 Action a. "With one or more PORV(s) inoperable and capable of being manually

cycled, within 1 hour: 1) Restore the PORV(s) to OPERABLE status or 2) Close the associated block valve(s) and maintain power to the block

valve; otherwise, be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />."

Tech Specs

RO Ensure ROD CNTRL BANK SEL Switch is in AUTO.

AOP * RO Maintain RCS pressure between 2220 psig and 2250 psig.

AOP CRS While regaining pressure monitor Technical Specification:3.2.5: Indicated

Pressurizer Pressure 2206 psig Action: With any of the above parameters exceeding its limit, restore the parameter to within its limit within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or reduce THERMAL POWER to

less than 5% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

Tech Specs

Crew Determine and correct the cause of the channel failure (will not be

corrected during scenario)

.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 3 Page 19 of 44 Event Description: PZR Pressure Transmitter PT-444 fails high

Time Position Applicant's Actions or Behavior

Appendix D 19 NUREG 1021 Revision 9

AOP Booth Operator Instructions: When called as I&C report that a troubleshooting plan is being developed.

AOP Crew Conducts post-event brief, contacts SS and I&C.

AOP At the discretion of the Lead Examiner, proceed to the next event.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 20 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 20 NUREG 1021 Revision 9 Booth Instructor: when directed, activate trigger 4

Indications available: XCP-614 5-1, CHG LINE FLO HI/LO

Charging pump amps increase

Amber overload light above charging pump control switch

ARP XCP-614 5-

1 Crew Refer to alarm response procedure

ARP AUTOMATIC ACTIONS:

1. None.

ARP RO CORRECTIVE ACTIONS: 1. If the running Charging Pump amps are abnormal (yes), secure the Charging Pump and go to AOP-102.2, Loss of Charging.

ARP CRS Enters AOP-102.2, LOSS OF CHARGING

Enters AOP-102.2

RO Checks if charging flow is normal (NO) ARP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 21 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 21 NUREG 1021 Revision 9

RO AOP RO IF Charging Pump suction is aligned to the VCT THEN ensure both LCV-115C(E), VCT OUTLET ISOL, are open (

YES) AOP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 22 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 22 NUREG 1021 Revision 9

RO AOP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 23 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 23 NUREG 1021 Revision 9

AOP RO 6) Locally verify Charging Pump suction pressure is between 50 psig and 100 psig as indicated on the following:

PI-151A, SUCTION PRESS, for Charging Pump A.

PI-152A, SUCTION PRESS, for Charging Pump B. PI-153A, SUCTION PRESS, for Charging Pump C.

AOP Booth Instructor:

When contacted as ABLL, report suction pressure as 57 psig. Booth Instructor: if asked, "B" Charging pump was running yesterday prior to train swap.

Booth Instructor:

When contacted as SS, authorize starting either "B" or "C" charging pump (whichever one

is recommended to be started)

Uses SOP-102 section III.B. 2

CAUTION To ensure proper pump starting du

ring a Blackout or Safety Injection, normally, only one

Charging Pump should be racked in to each train.

NOTE

Normally, only one Charging Pump is run at a

time. This section may be used to start an additional Charging Pump (in the opposite train) for testing purposes only.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 24 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 24 NUREG 1021 Revision 9

CAUTION If the Charging Pump has been out of service

for an extended period of time (30 days to 45

days) during normal plant operation, the differ

ence in Boric Acid Concentration in the

stagnant piping could change RCS Tave, depending on time in core life, by as much as

0.2F when the pump is placed in service.

SOP Crew Directs racking up "C" charging pump on "A" train

or starting "B" train CCW and "B" train charging pump

SOP Booth Instructor:

When contacted as Intermediate Building operator, use trigger 7 to rack up "C" chg pump. Report that the pump was last operated seven days ago. (This shows that the case does not

need to be flushed.) Report that Att. VA to SOP-102 is complete (This shows that the C charging pump has been

aligned to A header)

CRS Determines that flushing of the casing in

not required

SOP section 2.4

RO Checks that XPP-43B(C)-PP1, CHG PP B(C) AUX OIL PP, is running.

SOP RO Starts XPP-0043B(C), PUMP B(C).

(PEER check) SOP RO Verifies XPP-43B(C)-PP1, CHG PP B(C) AUX OIL PP, stops automatically

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 25 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 25 NUREG 1021 Revision 9

SOP RO Verifies PI-121, CHG PRESS PSIG, is between 2650 psig and 2850 psig

SOP RO Monitors the following for proper pump operation: a. LR-459, PZR % LEVEL & LEVEL SP. b. FI-130A, RCP A INJ FLO GPM. c. FI-127A, RCP B INJ FLO GPM.

d. FI-124A, RCP C INJ FLO GPM.

Uses SOP-102 section IV.M.

RO Places FCV-122, CHG FLOW, in MAN and close.

SOP RO Places PCV-145, LO PRESS LTDN, in MAN and open to 70%.

(PEER check) SOP RO Places TCV-144, CC TO LTDN HX, in MAN and open to 100%.

SOP RO Places TCV-143, LTDN TO VCT OR DEMIN, in VCT.

SOP RO Opens PVT-8152, LTDN LINE ISOL.

SOP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 26 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 26 NUREG 1021 Revision 9

RO Opens the following: a. LCV-459, LTDN LINE ISOL.

b. LCV-460, LTDN LINE ISOL.

SOP RO Ensure the following Charging Line Isolation Valves are open: a. MVG-8107, CHG LINE ISOL. b. MVG-8108, CHG LINE ISOL.

SOP RO Slowly open FCV-122, CHG FLOW, to establish 60 gpm flow as indicated on FI-122A, CHG FLOW GPM.

SOP RO Open Orifice Isolation Valves to obtain the desired Letdown flow rate

(60 gpm to 120 gpm):

a. PVT-8149A, LTDN ORIFICE A ISOL (45 gpm).

b. PVT-8149B, LTDN ORIFICE B ISOL (60 gpm) OR

c. PVT-8149C, LTDN ORIFICE C ISOL (60 gpm).

SOP RO Adjust FCV-122, CHG FLOW, as required to maintain TI-140, REGEN HX OUT TEMP °F, between 250°F and 350°F while maintaining Pressurizer

level. SOP

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 27 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 27 NUREG 1021 Revision 9

RO Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.

SOP RO Place PCV-145, LO PRESS LTDN, in AUTO.

SOP RO Adjust TCV-144, CC TO LTDN HX, potentiometer as necessary to maintain the desired VCT temperature and place in AUTO.

SOP RO When Pressurizer level is within 1% of and trending to programmed level, place the PZR LEVEL MASTER CONTROL in MAN.

RO Establish automatic FCV-122, CHG FLOW, control as follows: a. Determine the correct PZR LEVEL MASTER CONTROL setpoint by

dividing the current Charging flow by 1.5.

b. Manually adjust the PZR LEVEL MASTER CONTROL to this setpoint.

c. Place FCV-122, CHG FLOW, in AUTO. .

(PEER check) SOP RO Adjust PZR LEVEL MASTER CONTROL in MAN, as necessary, to maintain Pressurizer level at or near programmed level.

SOP RO When Pressurizer level is within 1% of and trending to programmed level, place PZR LEVEL MASTER CONTROL in AUTO. .

(PEER check)

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 4 Page 28 of 44 Event Description: Charging pump bearing seizes causing loss of charging

Time Position Applicant's Actions or Behavior

Appendix D 28 NUREG 1021 Revision 9

SOP RO Monitor LR-459, PZR % LEVEL & LEVEL SP, recorder to verify that Charging flow is maintaining actual Pressurizer level at or near the

programmed setpoint.

SOP RO After the Letdown temperatures have stabilized, place TCV-143, LTDN TO VCT OR DEMIN, in DEMIN/AUTO.

SOP Crew Conducts Post-event brief, contacts SS. May contact Mechanical

Maintenance for pump repair.

SOP At the discretion of the Lead Examiner, proceed to the next event

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 5 Page 29 of 44 Event Description: Feedwater bypass valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 29 NUREG 1021 Revision 9

Booth Instructor:

When directed, activate trigger 5

Indications available:

XCP-624, 1-5, SG A LVL DEV XCP-624, 1-1, SG A LVL HI-HI

Increasing level on "A" SG. Crew Refer to alarm response procedures Evaluator Note: The crew may attempt to go to AOP-210.1, FEEDWATER FLOW CONTROL VALVE FAILURE but that procedure is written for a failure of the main feed regulation valves and

not the bypass valves so the steps of AOP-210.1 are not included. ARP XCP-624, 1-5

PROBABLE CAUSE:

(none apply) 1. Step load increase or decrease.

2. Steam Generator A level control system malfunction.

3. FCV-478, A FCV, malfunction.

4. Testing in progress.

5. Instrument failure.

ARP AUTOMATIC ACTIONS:

1. FCV-478, A FCV, will modulate to

attempt to restore level to 61.6%.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 5 Page 30 of 44 Event Description: Feedwater bypass valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 30 NUREG 1021 Revision 9

ARP CORRECTIVE ACTIONS:

BOP 1. If required, restore Steam Generator A level to between 60% and 65% by performing the following: a. Manually control PVT-478, SG A FWF

ARP BOP ARP SUPPLEMENTAL ACTIONS:

BOP 1. Correct the level deviation and restore automatic control (

NO, valve is failed

open). ARP Booth Operator Instructions: When called as I&C report that you will develop a troubleshooting

plan.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 5 Page 31 of 44 Event Description: Feedwater bypass valve fails open

Time Position Applicant's Actions or Behavior

Appendix D 31 NUREG 1021 Revision 9

ARP Crew Conducts post-event brief and contacts SS. May contact I&C for Bypass Feed Reg. valve troubleshooting. Evaluator Note: If the crew decides to leave the bypass valve open then they should enter

Technical Specification 3.3.2 Functional unit 1.b action 14. Booth Operator: If called to fail air to the bypass valve so that is closes use VLV-FW010A, IFV03321-FW MN FW BYPASS VLV A LOSS OF AIR to do so. At the discretion of the Lead Examiner proceed to the next event

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 32 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 32 NUREG 1021 Revision 9

Booth Instructor: When directed, activate trigger 6.

Indications available:

Indications available: XCP-614 pt. 5-1 CHG FLO HI/LO XCP-616 pt. 1-5 PZR LCS DEV HI/LO

XCP-616 pt. 2-2 PZR PRESS LO

XCP-616 pt. 2-3 PZR PRESS HI/LO

XCP-616 pt. 1-3 BLCK HTRS ISOL LTDN PZR LCS LO

Crew Refer to alarm response procedures

Uses ARP XCP-614 pt. 5-1

PROBABLE CAUSE:

1. RCS temperature transient. 2. RCS excessive leakage (yes). 3. Flow controller malfunction.

4. Charging Pump malfunction.

5. Flow control valve failure.

. CRS Transitions to AOP-101.1 LOSS OF REACTOR COOLANT NOT

REQUIRING SI

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 33 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 33 NUREG 1021 Revision 9

Transitions to AOP-101.1 NOTE; If a Reactor

Trip occurs AND SI is NOT required, this procedure should be continued

after the actions of

EOP-1.1. REACTOR TRIP RECOVERY,

are completed.

IOA RO Verify PZR level is at or trending to program level

(NO). AOP IOA RO a) Open FCV-122. CHG FLOW as necessary to maintain PZR level.

AOP IOA RO b) If PZR level continues to decrease (yes), THEN reduce Letdown to one

45 gpm orifice: 1) Set PCV-145, LO PRESS LTDN to 70%.

2) Ensure PVT-8149A.

LTDN ORIFICE A ISOL is open.

3) Close both PVT-8149B(C)

LTDN ORIFICE B(C) ISOL. 4) Adjust PCV-145, LO PRESS LTDN to maintain PI-145 LO PRESS LTDN

PRESS PSIG between 300 psig and

400 psig. 5) Place PCV-145, LO PRESS

LTDN, in AUTO.

AOP IOA RO 2. Check if SI is required: a. Check if any of the following criteria are met: * PZR level is decreasing with Charging maximized and Letdown

minimized. * PZR level is approaching 12% (yes). * PZR pressure is approaching 1870 psig.

• VCT level is approaching 5% (yes).

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 34 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 34 NUREG 1021 Revision 9

IOA RO b. Perform the following:

1) Trip the Reactor 2) GO TO EOP-1.0. REACTOR TRIP/SAFETY INJECTION ACTUATION. WHEN EOP-1.0 Immediate Actions are complete,

THEN actuate SI.

CRS Direct entry to EOP-1.0, Reactor Trip/Safety Injection Actuation

Enters EOP-1.0

IOA RO Verify Reactor Trip: Trip the Reactor using either Reactor Trip Switch. Verify all Reactor Trip and Bypass Breakers are open. Verify all Rod Bottom Lights are lit. Verify Reactor Power level is decreasing.

EOP-1.0 IOA BOP Verify Turbine/Generator Trip: a. Verify all Turbine STM Stop VLVs are closed. b. Ensure Generator Trip (after 30 second delay): 1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

EOP-1.0 IOA BOP Verify both ESF buses are energized.

EOP-1.0

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 35 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 35 NUREG 1021 Revision 9

IOA RO Check if SI is actuated: a. Check if either: * SI ACT status light is bright on XCP-6107 1-1

(NO). Or * Any red first out SI annunciator is lit on XCP-626 top row

(YES). EOP-1.0 CRITICAL

TASK RO b. Actuate SI using either SI ACTUATION Switch

EOP-1.0 BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION.

EOP-1.0 Evaluator Note: The steps for Attachment 3, SI EQUIPMENT VERIFICATION can be found at the end of this

scenario guide.

Crew Announce plant conditions over the page system.

EOP-1.0 RO Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB PSIG (P-951), red pen. (YES) EOP-1.0

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 36 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 36 NUREG 1021 Revision 9

RO Verify both the following annunciators are lit; (NO) c. XCP-612 3-2 (RB SPR ACT).

d. XCP-612 4-2 (PHASE B ISOL).

EOP-1.0 RO Check RCS temperatures: With any RCP OR RCS Tavg is stable at or trending to 557°F OR With no RCP running, RCS Tcold is stable at OR trending to 557°F. (NO) Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

Throttle EFW to 450 gpm total until one SG > 26%.

EOP-1.0 RO Check if PZR PORVs are closed (yes). EOP-1.0 RO Check if PZR Spray Valves are closed (yes). EOP-1.0 RO Verify power is available to at least one PZR PORV Block Valve: MVG-8000A, RELIEF 445 A ISOL

(yes). MVG-8000B, RELIEF 444 B ISOL(yes). MVG-8000C, RELIEF 445 B ISOL

(yes). EOP-1.0 RO Verify at least one PZR PORV Block Valve is open (yes).. EOP-1.0 NOTE - Step 11 Seal Injection flow should be maintained to all RCPs.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 37 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 37 NUREG 1021 Revision 9

EOP-1.0 RO Check if RCPs should be stopped: (YES) EOP-1.0 Critical

Task RO Stop all Reactor Coolant Pumps

EOP-1.0 RO Verify no SG is FAULTED: No SG pressure is decreasing in an uncontrolled manner (yes). No SG is completely depressurized. (yes). EOP-1.0 RO Verify Secondary radiation levels indicate SG tubes are NOT RUPTURED: (yes)

EOP-1.0

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 38 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 38 NUREG 1021 Revision 9

RO Check if the RCS is INTACT: (YES based on CNTMT conditions)

EOP-1.0 RO Reset both SI RESET TRAIN A(B) Switches.

EOP-1.0 RO Reset Containment Isolation:

• RESET PHASE A - TRAIN A(B) CNTMT ISOL. ' * RESET PHASE B - TRAIN A(B) CNTMT ISOL.

EOP-1.0 BOP Place both ESF LOADING SEQ A(B)

' RESETS to:

a. NON-ESF LCKOUTS. ' b. AUTO-START BLOCKS.

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 39 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 39 NUREG 1021 Revision 9

EOP-1.0 Evaluator's note; "A" compressor was stripped on load shed but either it or the Supplemental can be started now that non-ESF lockouts are reset. The "B" compressor is

locked out since 1A1 is on alternate feed.

RO Establish Instrument Air to the RB: a. Verifies the "A" IA compressor is running and Verifies the "B" IA compressor is in standby

(NO) Restarts "A", the Supplemental, or the Diesel air compressor. b. Opens PVA-2659, INST AIR TO RB AIR SERV.

c. Opens PVT-2660, AIR SPLY TO RB.

EOP-1.0 RO Check if SI flow should be reduced: (no) EOP-1.0 CRS Initiate monitoring of the Critical Safety Function Status Trees. REFER TO EOP-12.0, MONITORING OF CRITICAL SAFETY FUNCTIONS.

EOP-1.0 Evaluator's note; STA can perform this function as directed 10 minutes after he is called to

the control room.

• RO Check SG levels; a. Verify level in all SGs > 26% (yes) b. Control EFW flow to maintain NR levels 40%-60%

EOP-1.0

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 40 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 40 NUREG 1021 Revision 9 Booth operator note; If contacted as chemistry wait 30 minutes, then report all secondary

activities are normal.

RO Check if secondary activity is normal (yes) EOP-1.0 RO Check for loss of Reactor Coolant outside Containment (yes) EOP-1.0 CRS

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 41 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 41 NUREG 1021 Revision 9 Evaluator Note: The closure of the MSIV's may occur at various points in the scenario based on the time the crew takes, but this is where it occurred during workup week.

CRS Enters EOP-2.5 LOCA OUTSIDE CONTAINMENT

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 42 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 42 NUREG 1021 Revision 9

Enters EOP-2.5 Booth Operator Instructions: ramp flex leak size to 5000 gpm over 5 minutes to maintain RCS pressure decrease trend for clear EOP path.

EOP-2.5 Crew Announces plant conditions over the page system.

EOP-2.5 Booth Operator Instructions: when directed to energize 8701 and 8702 valves, use triggers

10 (A loop) and 11 (C loop) to do so. Evaluator note; a Steamline SI and Main Steam isolation signal may occur above 675# steamline SI; the low decay heat in this snap causes cooldown from SI flow.

EOP-2.5 RO (YES) EOP-2.5

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 43 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 43 NUREG 1021 Revision 9

RO (ALL CLOSED)

EOP-2.5 RO Check if RCS pressure is continuing to decrease (yes).

2011 NRC Spare Scenario after workup Scenario Outline Form ES-D-2 Op Test No.: 2011 NRC Scenario # Spare Event # 6, 7, 8 Page 44 of 44 Event Description: LOCA Outside Containment Time Position Applicant's Actions or Behavior

Appendix D 44 NUREG 1021 Revision 9

Booth operator instructions; adjust si

ze of flex leak as required to keep RCS pressure trending down.

EOP-2.5 RO 4. Try to identify and isolate the break: (requires operating "A" and "B" train "power lockout" switches to restore control power) a. Close MVG-8888A, RHR LP A TO COLD LEGS.

EOP-2.5 RO Check if RCS pressure is continuing to decrease (yes) EOP-2.5 RO c. Open MVG-8888A, RHR LP A TO COLD LEGS.

EOP-2.5 Critical

Task RO d. Close MVG-8888B, RHR LP B TO COLD LEGS

EOP-2.5 RO Check if RCS pressure is continuing to decrease

(no) EOP-2.5 CRS Transitions to EOP-2.0 LOSS OF EMERGENCY COOLANT RECIRCULATION.

Lead Examiner can terminate the scenario at this point.

2011 NRC InPlant i RO: CONTROL ROOM EVACUATION (DUTIES OF BOP OPERATOR)

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPPF-049APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:7THIS JPM IS APPROVEDSaturday, September 03, 2011Page 1 of 12

TASK:000-068-05-01PREFERRED EVALUATION METHODSIMULATEEVALUATION TIME

14TIME CRITICAL

NoTASK STANDARD:AOP-600.1 Attachment II performed with the following complete: 1. All MFPs have been tripped2. Rod Drive MG set feeder breakers have been tripped3. RCP "B" is left running ('A' and 'C' RCP is tripped already).

4. Two condensate pumps have been tripped

5. Three FWBP's have been tripped.The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.PREFERRED EVALUATION LOCATION

PLANTTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)13PERFORM CONTROL ROOM EVACUATIONTOOLS:AOP-600.1, Attachment II, Steps10-12ISP-027 Electrical Safety

SOP-313Picture of the inside of a 7.2 KV breaker.REFERENCES:TERMINATING CUE:Step 12 of Attachment II is complete or when examinee returns procedure to examiner.SOP-313LOCAL SWITCHGEAR BREAKER OPERATIONSISP-027ELECTRICAL SAFETYAOP-600.1CONTROL ROOM EVACUATIONINDEX NO.ROSROK/A NO.0000682130Ability to locate and operate components, including local controls.4.44.02.1.30Saturday, September 03, 2011Page 2 of 12

INITIATING CUES:The Control Room Supervisor directs the BOP Operator to perform Attachment 2 of AOP-600.1, Steps 10 through 12.INITIAL CONDITION:The plant is operating at 100% power, with all controls in automatic. A call has been received that a bomb has been placed in the control

room. The SS has directed a control room evacuation. AC power is available to both ESF Buses. The reactor has been tripped by the Reactor Operator.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!FOR ELECTRICAL MANIPULATIONS, AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!Saturday, September 03, 2011Page 3 of 12

INITIATING CUES:The Control Room Supervisor directs the BOP Operator to perform Attachment 2 of AOP-600.1, Steps 10 through 12.INITIAL CONDITION:The plant is operating at 100% power, with all controls in automatic. A

call has been received that a bomb has been placed in the control

room. The SS has directed a control room evacuation. AC power is available to both ESF Buses. The reactor has been tripped by the Reactor Operator.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TAT NO TIME ARE YO

U TO OPERATE ANY

PLANT EQUIPMENT!Saturday, September 03, 2011

STEPSVerifies reactor has been tripped.Procedure CAUTION - Step 10 "Reactor Trip should be verified with the Reactor Operator prior to securing the Main Feedwater Pumps."Evaluator note: Initial conditions have indicated that the RO has already tripped the reactor. If the candidate calls the Reactor Operator to verify the reactor trip respond as the Reactor Operator that the reactor has been tripped.YesCalls the reactor operator and verifies reactor has been tripped.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Locally trip all Main Feedwater Pumps (436'

TB).YesPulls MFP "PULL TO TRIP" handle on front standard for MFP's "A" "B" & "C".

Verifies trip by noting RPM decrease

locally OR trips MFPs from local DCS

station.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:2Saturday, September 03, 2011Page 5 of 12

Locally at XSW1A Switchgear Room (TB-436): Trips ROD DRIVE M/G SET "B" - XMG0001B-CR, XSW1B1 06C.If asked as the Shift Supervisor if ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements can be waived respond that the requirements can be waived. This waiver will be applied to the rest of the task.Note: If candidate does not wish to waive ISP-027 requirements then the following are required: Hard hat (as posted); safety glasses, hearing protection (as posted); Fire Retardant Pants and shir

tor Fire Retardant coveralls. Examiner provides feedback of "no change in status" if examinee indicates he/she would trip a 480V breaker using the TRIP Pushbutton on the right side of the breaker. This p/b only works when the breaker is racked out to the "test" position.YesTrips rod drive MG set "B" bkr 06C at XSW-1B1 by pushing on red TRIP

pushbutton on left side on front of

breaker. Verifies a green "OPEN" flag results and red light OFF, green light O

NCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Check status of XSW1A 06 FD WTR BOOSTER PUMP "A" XPP0028A-FW

breaker.Examiner informs examinee that the "A" FWBP, bkr 06 red li

ght is lit.YesVerifies that the "A" FWBP, bkr 06 is closed by observing red light on outside

of cubicle door.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Saturday, September 03, 2011Page 6 of 12

Checks status of XSW1A 09, RX COOLANT PUMP "A" XPP0030A-RC.Cue examinee that RCP "A" Bkr has a green light lit on front of cubicle. (Note: This will "setup" alternate path portion of this JPM. Examinee will have to leave 'B' RCP runnin

g in Step 12.c.

)YesChecks RCP "A" breaker at XSW1A 09. Verifies a green light on outside of cubicle door.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Check status of XSW1A 07, COND PUMP "A" XPP0042A-CO breaker.Examiner informs examinee that the "A" condensate pump breaker red li

ght is lit.YesVerifies that the "A" condensate pump bkr 07 is closed by observing red light o

noutside of cubicle door.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Saturday, September 03, 2011Page 7 of 12

Locally at XSW1B and XSW1C Switchgear Room (TB-412): If Condensate Pump "A" is

running THEN trip both of the following: Trip XSW1B 09, COND PUMP "B" XPP0042B-CO breaker.If asked as the Shift Supervisor if ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements can be waived respond that the requirements can be waived.Note: If candidate does not wish to waive ISP-027 requirements then the following are required: 25 Cal/cm2, arc flash suit and hood (use of an arc flash hood without a hard hat in an area with

overhead work in progress will require manager approval. Otherwise no hard had is required when in an arc flash hood). Short sleeve natural fiber shirt, voltage rated gloves, safety glasses, earmuffs are the preferred hearing protection when an arc flash suit is being worn, however

earplugs may be used. Fire Retardant coveralls or Fire Retardant Shirt (tucked in) & Pants. A 10' flash protection boundary is established.Examiner Note: Do not let candidate open the breaker door. A picture has been included of the inside of a 7.2 breaker. Picture shows a breaker racked down and open, but will be used to discuss how the breaker will be tripped.YesTrips breaker XSW1B 09 for Cond Pump "B" by pushing the "MANUAL TRIP" lever on front of breaker (inside

cubicle door). Verifies a green light on

outside of cubicle door results.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Checks status of XSW1C 06, COND PUMP "C" XPP0042C-CO breaker.Examiner informs examinee the cubicle for COND PUMP "C" XPP0042C has a green light lit on the front of the cubicle.YesChecks COND PUMP "C" Breaker, XSW01C 06. Verifies a green light ON outside of cubicle door.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Saturday, September 03, 2011Page 8 of 12

If Feedwater Booster Pump "A" is running, THEN trip all of the following: Trips XSW1B

06, FD WTR BOOSTER PUMP "B" XPP0028B-FW breaker.Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as the Condensate pumps.Examiner Note: Do not let candidate open the breaker door. A picture has been included of the inside of a 7.2 breaker. Picture shows a breaker racked down and open, but will be used to

discuss how the breaker will be tripped.YesTrips the FWBP "B" bkr 06 manually at XSW-1B by pushing the "MANUAL TRIP" lever on front of breaker (inside cubicle door). Verifies a green light on

outside of cubicle door results.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:9Trips XSW1B 13, FD WTR BOOSTER PUMP "D" XPP0028D-FW breaker.Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as the Condensate pumps.Examiner Note: Do not let candidate open the breaker door. A picture has been included of the inside of a 7.2 breaker. Picture shows a breaker racked down and open, but will be used to discuss how the breaker will be tripped.YesTrips the FWBP "D" bkr 13 manually at XSW-1B by pushing the "MANUAL TRIP" lever on front of breaker (inside

cubicle door). Verifies a green light on

outside of cubicle door results.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:10Saturday, September 03, 2011Page 9 of 12

Trips XSW1C 08, FD WTR BOOSTER PUMP "C" XPP0028C-FW breaker.Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as the Condensate pumps.Examiner Note: Do not let candidate open the breaker door. A picture has been included of the inside of a 7.2 breaker. Picture shows a breaker racked down and open, but will be used to

discuss how the breaker will be tripped.YesTrips the FWBP "C" bkr 08 manually at XSW-1C by pushing the "MANUAL TRIP" lever on front of breaker (inside cubicle door). Verifies a green light on

outside of cubicle door results.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:11If RCP A is running (NO), goes to RNO. Ensure one of the following is open: XSW1B 07, RX COOLANT PUMP "B" XPP0030B-

RC OR XSW1C 03, RX COOLANT PUMP

"C" XPP0030C-RC.Cue candidate, when looking at breaker positions, that XSW1B 07, RX COOLANT PUMP B XPP0030B-RC has a red light lit and that XSW1C 03, RX COOLANT PUMP C XPP0030C-RC has a green light lit.This is the alternative path portion of this JPM.It is critical that the "B" RCP be left running since both the "A" and "C" pumps are already tripped in this JPM.Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as the Condensate pumps.YesDoes NOT trip the RCP "B" bkr 07 at XSW-1B (because RCP "C" bkr 03 at

XSW-1C is already open).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:12Saturday, September 03, 2011Page 10 of 12

Examiner ends JPM at this point.Ensure XSW 1C 02 Press Heater Transformer XTF 4103-RC is closed.Same ISP-027 considerations as Condensate pumps if it was to be operated but since only verifying proper position there are no ISP-027 requirements.YesVerifies that the PZR Heater Transformer Breaker 02 at XSW-1C is closed by observing red light on outside of cubicle door or a red "closed" flag on

front of breaker.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:13Saturday, September 03, 2011Page 11 of 12

JPM NO:JPPF-049DESCRIPTION:2011 NRC InPlant i RO: CONTROL ROOM EVACUATION (DUTIES OF BOP OPERATOR)IC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETSaturday, September 03, 2011Page 12 of 12

2011 NRC InPlant i SRO: CONTROL ROOM EVACUATION (Followup Actions of CRS)

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPPF-044APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:15THIS JPM IS APPROVEDSRO ONLYFriday, September 02, 2011Page 1 of 21

TASK:000-068-05-01PREFERRED EVALUATION METHODSIMULATEEVALUATION TIME

25TIME CRITICAL

NoTASK STANDARD:Flow has been established to the RCS and the S/Gs. SW is running to cool D/G's & CCW on both trains. The RCS is emergency borated. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.PREFERRED EVALUATION LOCATION

PLANTTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)13PERFORM CONTROL ROOM EVACUATIONTOOLS:AOP-600.1, BEGINNING WITH STEP 4REFERENCES:TERMINATING CUE:Emergency boration is completed or emergency boration is (incorrectly) deemed "not required" or when examinee returns procedure to examiner.AOP-600.1CONTROL ROOM EVACUATIONINDEX NO.ROSROK/A NO.000068K318Actions contained in EOP for control room evacuation emergency task4.24.5AK3.18000068K309Transfer of the following to local control: charging pumps, charging header flow control valve, PZR heaters, and boric acid transfer pumps3.94.4AK3.09Friday, September 02, 2011Page 2 of 21

INITIATING CUES:The Shift Supervisor directs you, the CRS, to perform AOP-600.1, CONTROL ROOM EVACUATION, at the CREP, beginning with Step 4.INITIAL CONDITION:The plant is operating at 100%, with all controls in automatic. A call has been received that a bomb has been placed in the control room. The

Shift Supervisor has directed a control room evacuation. Bomb detection experts from the State Law Enforcement are on their way to the site.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!FOR ELECTRICAL MANIPULATIONS, AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!Friday, September 02, 2011Page 3 of 21

INITIATING CUES:The Shift Supervisor directs you, the CRS, to perform AOP-600.1, CONTROL ROOM EVACUATION, at the CREP, beginning with Step 4.INITIAL CONDITION:The plant is operating at 100%, with all controls in automatic. A call has

been received that a bomb has been placed in the control room. The

Shift Supervisor has directed a control room evacuation. Bomb detection experts from the State Law Enforcement are on their way to the site.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TAT NO TIME ARE YO

U TO OPERATE ANY

PLANT EQUIPMENT!Friday, September 02, 2011

STEPSAlign the following controls (CREP XPN-7200A): Set FCV-122, CHG FLOW,

potentiometer to 5.0.Evaluator Note: Steps 1 - 21 of the JPM (steps 4-6 of the procedure) are performed in 'A' CREP Room. Evaluator Note: The candidate is just aligning the controls in steps 1-9 of the JPM (step 4 of the procedure

). It is not until controls are taken to local that an

y change in indication will occur.

NoRotates the potentiometer wheel clockwise until 5 appears in the window.(5 full turns).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1Set IFV-3536, TD EFP to SG A, potentiometer fully clockwise.This is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3536 potentiometer clockwise until no further rotation can be

made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Set IFV-3546, TD EFP to SG B, potentiometer fully clockwise.This is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3546 potentiometer clockwise until no further rotation can be made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Friday, September 02, 2011Page 5 of 21

Set IFV-3556, TD EFP to SG C, potentiometer fully clockwise.This is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3556 potentiometer clockwise until no further rotation can be made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Place LCV-459, LTDN LINE ISOL, in OPEN.

NoPositions the LCV-459 control switch to the OPEN position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Place LCV-460, LTDN LINE ISOL, in OPEN.

NoPositions the LCV-460 control switch to the OPEN position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Friday, September 02, 2011Page 6 of 21

Place two letdown orifices in OPEN and one

in CLOSENoPositions two of three PVT-8149 (A,B,C) LTDN ORIFICE (A,B,C) ISOL control

switches to the OPEN position. Ensure

sone is positioned to CLOSE.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Place TSC BYPASS in ON

NoPositions the TSC BYPASS switch to the ON position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:8At the Auxiliary Panel, place PCV-445A, PORV in CLOSE.This is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoVerifies the PCV-445A control switch is in the CLOSE position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Friday, September 02, 2011Page 7 of 21

Transfer the following to LOCAL (CREP XPN-7200A): PZR HTRS BU GROUP 1 XFER to LOCAL.After switch placed in LOCAL, cue operator that red li

ght is lit on PZR HTRS BU GROUP 1.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:10FCV-122, CHG FLOW CNTRL XFER to LOCAL.After switch placed in LOCAL, cue operator that there was no chan

ge in FI-122B.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:11XPP-0039A, SW PUMP A XFER to LOCAL.After switch placed in LOCAL, cue operator that red li

ght is lit on SW PUMP A

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:12Friday, September 02, 2011Page 8 of 21

XPP-0039C, SW PP C TRAIN A XFER to LOCAL.After switch placed in LOCAL, cue operator that no li

ghts are lit on SW Pump C.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:13TD EFP FD VLV XFER to LOCAL.Examiner Note: There will be no chan

ge in indications with this transfer.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:14LCV-459, LTDN LINE ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that red light is lit.Examiner Note: Response here will be based on correct operator action in step 5 of the JPM (if switch was left in closed then indication will be both red and green light lit till valve strokes and then

green light lit).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:15Friday, September 02, 2011Page 9 of 21

LCV-460, LTDN LINE ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that red light is lit.Examiner Note: Response here will be based on correct operator action in step 6 of the JPM (if switch was left in closed then indication will be both red and green light lit till valve strokes and then

green light lit).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:16PVT-8149A, LTDN LINE A ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that red light is lit if selected to open, green light is lit if selected to closed

(as positioned b

y operator in step 7 of JPM

).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:17PVT-8149B, LTDN LINE B ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that red light is lit if selected to open, green light is lit if selected to closed

(as positioned b

y operator in step 7 of JPM

).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:18Friday, September 02, 2011Page 10 of 21

PVT-8149C, LTDN LINE C ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that red light is lit if selected to open, green light is lit if selected to closed

(as positioned b

y operator in step 7 of JPM

).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:19PCV-445A, PORV XFER (Auxiliary Panel) to LOCAL.After switch placed in LOCAL, cue operator that green light is lit.Examiner Note: Response here will be based on correct operator action in step 9 of the JPM (if switch was left in open then indication will be both red and green light lit till valve strokes and then red light lit).NoPositions transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:20Ensure one Service Water Pump running on Train A (CREP A)Examiner cues operator that Service Water Pump breaker for Service Water Pump "A" indicator red light is lit and no li

ghts are lit on Service Water Pump "C".YesVerifies Service Water Pump "A" red light lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:21Friday, September 02, 2011Page 11 of 21

Align the following controls (CREP XPN-7200B): Set IFV-3531, MD EFP TO SG A potentiometer fully clockwiseEvaluator Note: Steps 22 - 48 of the JPM (steps 7-12 of the procedure) are performed in 'B' CREP Room. Evaluator Note: The candidate is just aligning the controls in steps 22-29 of the JPM (step 7 of the procedure). It is not until controls are taken to local that any change in indication will occur.This is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3531 potentiometer clockwise until no further rotation can be

made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:22Set IFV-3541, MD EFP TO SG B potentiometer fully clockwiseThis is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3541 potentiometer clockwise until no further rotation can be made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:23Set IFV-3551, MD EFP TO SG C potentiometer fully clockwiseThis is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoRotates IFV-3551 potentiometer clockwise until no further rotation can be

made.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:24Friday, September 02, 2011Page 12 of 21

Place XPP-13B, BA XFER PUMP B in OFFThis is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoVerifies the B.A. Transfer Pump "B" control switch in OFF.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:25Place XVT-8152, LTDN ISOL in OPEN

NoPositions the XVT-8152 control switch t

oOPEN.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:26Place PVG-2030, STEAM TO TD EFP in

OPENNoPositions the XVT-2030 control switch t

oOPEN.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:27Place TSC BYPASS in ON

NoPositions the TSC BYPASS Switch to the ON position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:28Friday, September 02, 2011Page 13 of 21

At the Auxiliary Panel, place PORV PCV-444B in CLOSEThis is the expected position and so no operator action should have to be taken. Cue candidate that position is how it appears.

NoVerifies the PCV-444B control switch is in CLOSE.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:29Transfer the following to LOCAL (CREP XPN-7200B): PZR HTRS BU GROUP 2

XFER to LOCALAfter switch placed in LOCAL, cue operator that the

green light is lit.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:30MVT-8104, EMERG BA FLOW CNTRL XFER to LOCAL.After switch placed in LOCAL, cue operator that the

green light is lit.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:31Friday, September 02, 2011Page 14 of 21

XPP-0039B, SW PUMP B XFER to LOCAL.After switch placed in LOCAL, cue operator that the red li

ght is lit.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:32XPP-0039C, SW PUMP C TRAIN B XFER to LOCAL.After switch placed in LOCAL, cue operator that no li

ghts are lit.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:33MD EFP FEED VALVES XFER to LOCAL.Examiner Note: There will be no chan

ge in indications with this transfer.

NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:34Friday, September 02, 2011Page 15 of 21

XPP-13B, BA PUMP B XFER to LOCAL.After switch placed in LOCAL, cue operator that the green light is lit.Examiner Note: Response here will be based on correct operator action in step 25 of the JPM (if switch was taken to open then indication will be both red and green light lit till valve strokes and then red li

ght lit).NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:35XVT-8152, LTDN ISOL XFER to LOCAL.After switch placed in LOCAL, cue operator that the red light is lit.Examiner Note: Response here will be based on correct operator action in step 26 of the JPM (if switch was left in closed then indication will be both red and green light lit till valve strokes and then

green light lit).NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:36PVG-2030, STEAM TO TD EFP XFER to LOCAL.After switch placed in LOCAL, cue operator that the red light is lit.Examiner Note: Response here will be based on correct operator action in step 27 of the JPM (if switch was left in closed then indication will be both red and green light lit till valve strokes and then

green light lit).NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:37Friday, September 02, 2011Page 16 of 21

PCV-444B, PORV XFER (Auxiliary Panel) to LOCAL.After switch placed in LOCAL, cue operator that green light is lit.Examiner Note: Response here will be based on correct operator action in step 29 of the JPM (if switch was taken to open then indication will be both red and green light lit till valve strokes and then red li

ght lit).NoPositions the transfer switch from REMOTE to LOCALCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:38Ensures one Service Water pump running on Train B (CREP B)Examiner cues operator that Service Water Pump breaker for Service Water Pump "B" indicator red light is lit and no li

ghts are lit on Service Water Pump "C".YesVerifies the Service Water Pump "B" red light lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:39Check if N-33 can be aligned.After examinee looks at NI-36A (located on the A CREP panel XPN-7200A) cue operator that NROATC tripped the Reactor 27 minutes ago and Intermediate Range power is 1x10-7% power. If examinee asks for specific source ran

ge counts, inform examinee that NI-32A reads 1000 counts.YesDetermines sufficient time has passed t

oalign N-33.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:40Friday, September 02, 2011Page 17 of 21

On XPN7300, place INI-0033, N33 DET HIGH VOLTAGE Switch in ONIf examinee asks for specific source ran

ge counts, inform examinee that NI-33 reads 1,000 counts.YesPositions the switch to ON position as indicated by red light lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:41Check if Emergency boration is required.Procedure Note - Steps 12 through 19: "If Main Control Board damage has occurred OR if equipment does NOT operate as required, it may be operated using appropriate portions of FEP-4.0, CONTROL ROOM EVACUATION DUE TO FIRE"Cue examinee that Rod F10 indicated 18 steps, and rod K2 indicated 96 steps prior to leaving the Control Room.Evaluator Note: This is where this JPM becomes alternate path.YesChecks for plant conditions which would require emergency boration from chart i

nAOP-600.1CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:42Open MVT-8104 EMERG BA FLOW CNTRLAfter switch placed in OPEN, cue operator that red li

ght is lit.YesRotates control switch to OPEN positionCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:43Friday, September 02, 2011Page 18 of 21

Start XPP-13B, BA XFER PUMP BAfter switch placed in START, cue operator that red li

ght is lit.YesRotates control switch to START positio

nCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:44Verify flow on FI-110A, EMERGENCY BA FLOW GPM.Cue operator that FI-110A indicates 100 GPM.YesChecks indication on FI-110A EMERGENCY BA FLOW GPM.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:45Verify required boration is completed.Cue operator that 25 minutes have elapsed since he opened MVT-8104 was opened.If asked about current source range counts indicate that counts are 500 cps.Evaluator Note: It is critical to borate for at least 25 minutes.YesNotes that it will take 25 minutes for required boration.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:46Friday, September 02, 2011Page 19 of 21

Examiner ends JPM at this point.CLOSE MVT-8104, EMERG BA FLOW

CNTRL.Cue operator that the green light is lit. If asked about FI-110A, cue the operator the flow has decreased to 0

gpm.YesRotates control switch to CLOSE positio

nCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:47Stop XPP-13B , BA XFER PUMP BCue operator that the

green light is litYesRotates control switch to OFF positionCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:48Friday, September 02, 2011Page 20 of 21

JPM NO:JPPF-044DESCRIPTION:2011 NRC InPlant i SRO: CONTROL ROOM EVACUATION (Followup Actions of CRS)IC SET:INSTRUCTIONS:COMMENTS:

JPM SETUP SHEETFriday, September 02, 2011Page 21 of 21

2011 NRC InPlant j RO & SRO: CROSS TRAIN CONNECTION OF BATTERY CHARGER XBC1A-1B

(ALIGNING AC FROM TRAIN A AND DC TO TRAIN

B)V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPP-205APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:3THIS JPM IS APPROVEDFriday, September 02, 2011Page 1 of 10

TASK:063-007-01-04PREFERRED EVALUATION METHODSIMULATEEVALUATION TIME

15TIME CRITICAL

NOTASK STANDARD:The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations. AC input from XMC-1DA2Y is aligned to battery charger XBC1A-1B. DC output from XBC1A-1B is aligned

to Train B.PREFERRED EVALUATION LOCATION

PLANTTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)8PLACE A BATTERY CHARGER IN SERVICETOOLS:FEP-2.0, Enclosure E page 3 and KFEP-2.0

FLASHLIGHT5A plant key (typically on operator key ring).REFERENCES:TERMINATING CUE:Enclosure K is complete or student hands JPM back to examiner.FEP-2.0TRAIN A PLANT SHUTDOWN TO HOT STANDBY INDEX NO.ROSROK/A NO.000068A110Power distribution: ac and dc3.73.9AA1.10Friday, September 02, 2011Page 2 of 10

INITIATING CUES:The CRS now directs you to complete FEP-2.0, Enclosure E, Step 6.a., Align the 1A-1B Battery Charger per Enclosure K.INITIAL CONDITION:90 minutes ago, the plant was at 100% power when a fire occurred in

Fire Zone IB-25.4. The Shift Supervisor directed the CRS to

implement the FEPs and the CRS has subsequently selected FEP-2.0 based on the location of the fire. The Control Room Supervisor has directed you, as the AB Upper Level, to perform Enclosure E of FEP-2.0. You have successfully completed the enclosure through Step 5. The "A" Battery Charger, XBC1A is operable and supplying DPN-1HA.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!FOR ELECTRICAL MANIPULATIONS, AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!Friday, September 02, 2011Page 3 of 10

INITIATING CUES:The CRS now directs you to complete FEP-2.0, Enclosure E, Step 6.a., Align the 1A-1B Battery Charger per Enclosure K.INITIAL CONDITION:90 minutes ago, the plant was at 100% power when a fire occurred in

Fire Zone IB-25.4. The Shift Supervisor directed the CRS to

implement the FEPs and the CRS has subsequently selected FEP-2.0 based on the location of the fire. The Control Room Supervisor has directed you, as the AB Upper Level, to perform Enclosure E of FEP-2.0. You have successfully completed the enclosure through Step 5. The "A" Battery Charger, XBC1A is operable and supplying DPN-1HA.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TAT NO TIME ARE YO

U TO OPERATE ANY

PLANT EQUIPMENT!Friday, September 02, 2011

STEPSVerify that XBC1A-1B, SWING BATTERY CHARGER, is not supplying DPN-1HA

(TRAIN A-DC breaker is OFF).Procedure Caution: "If XBC1A is not operable, DO NOT perform this attachment. Leave XVC1A-1B on DPN-1HA and warn the Control Room that they will have to control the Steamline Power

Reliefs and the Emergency Feedwater Flow Control Valves locally when the Train B battery is

exhausted. It is more important in FEP-2.0 to keep a battery charger supplying Train A than Train B".Examiner Note: The operability of XBC1A was given in the initial conditions, but if called as the control room report that XBC1A is operable.YesOn XBC1A-1B, ensures the Train A-DC breaker is OFF (pointing down).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Open both TRAIN A-AC and TRAIN B-AC breakers and both TRAIN A-DC and TRAIN B-DC breakers on XET-4003.NOTE: Breakers are expected to be already open (unless swing charger is in service during exam). If swing charger is in service cue that breakers move freely in down direction to "OFF" and

step is then critical.YesAt XET-4003, opens both Train A-AC and Train B-AC and both Train A-DC and Train B-DC breakers (pointing down) to the "OFF" position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Friday, September 02, 2011Page 5 of 10

Insert the spare interlock key into the TRAIN A-AC or TRAIN B-DC interlock key slot on

XET-4003 and bypass the interlock.Procedure Note - 3:"a. The spare Interlock Key is on the FEP Key Ring.b. The keys for the mechanical breaker interlocks fit in the breakers diagonally opposed to each other as illustrated on Page 3. The key that fits the upper left hand breaker fits the lower right handbreaker and the key that fits the upper right hand breaker, fits the lower left hand breaker."Examiner Note: The 5A key that will allow the operator to access the battery rooms is located on the operator's key ring. The spare interlock key is on the FEP Key Ring which the operator can

obtain from the FEP key locker (AB-412 in the hallway on the way to the battery rooms).Examiner Note: Interlock keys should already be inserted in either both the Train A breakers (in which case the extra interlock key will go into the Train B-DC breaker) or both the Train B breakers

(in which case the extra interlock key will go into the Train A-AC breaker). The keys must be turned to pull wa

y a physical bar to allow the breakers to close.YesOperator inserts spare interlock key into either TRAIN A-AC or TRAIN B-DC interlock key slot on XET-4003 and

places switch in "OFF".CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Close the TRAIN A-AC breaker on XET-

4003.Breakers move freel

y in up direction.YesOperator positions TRAIN A-AC breaker upward to the "ON" position on XET-

4003.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Friday, September 02, 2011Page 6 of 10

Close the TRAIN B-DC breaker on XET-

4003.Breaker moves freel

y in up direction.YesOperator positions TRAIN B-DC breaker upward to the "ON" position on XET-

4003.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Open DPN-1HA-ED 13, BATTERY CHARGER 1A-1B FEED TO DPN1HA.NOTE: Breaker is expected to be already open (unless swing charger is in service during exam). I

fswing charger is in service cue that breakers move freely in LEFT direction to "OFF" and step is then critical.YesOperator places breaker 13 (BATTERY CHARGER 1A-1B FEED TO DPN1HA)

in DPN-1HA-ED to the LEFT (OFF)

position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Close the following on XBC1A-1B Battery Charger: DC OUTPUT(CB2); AC INPUT

(CB1) on the left side.Breaker moves freel

y upward to the "ON" positionYesOperator places breakers DC OUTPUT and AC INPUT to the "UP" position on XBC1A-1B Battery Charger.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Friday, September 02, 2011Page 7 of 10

Verify DC OUTPUT VOLTMETER stabilizes between 129 and 140 volts.Examiner uses pen or pencil to point to 135 volts on the "DC OUTPUT" VOLTMETER (half way between 120 & 150 marks

).YesOperator checks that DC OUTPUT VOLTMETER stabilizes between 129 and 140 volts.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Verify the capacitors are fully charged by observing that the red indicator lights on XPN5294 ED, BATT CHARGER CAP BOX, are illuminated.Procedure Note 9: "Allow five to ten seconds for the capacitors to fully charge and the battery charger to stabilize."YesAfter 5-10 seconds (per NOTE 9), operator verifies red indicator lights for

the capacitors are lit on XPN-5294-ED.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Close DPN-1HB-ED 13, BATTERY CHARGER 1A-1B FEED TO DPN1HB.Procedure Note 10: "If XBA1B has been on a constant discharge, the battery charger voltage may drop below 129 volts with a high charging rate of a nominal 360 amps, but voltage will return to between 129 and 140 volts as the batter

y recharges."YesOperator places breaker 13 on DPN-1HB-ED to right ("ON") position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:10Friday, September 02, 2011Page 8 of 10

Examiner ends JPM at this point.Notify the Control Room that XBC1A 1B is cross connected.Examiner, as Control Room repeats back communication.

(Ensure 3-wa

y communication is used.

)YesOperator reports XBC1A-1B is cross connected to Control Room, using

expected communications techniques.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:11Friday, September 02, 2011Page 9 of 10

JPM NO:JPP-205DESCRIPTION:2011 NRC InPlant j RO & SRO: CROSS TRAIN CONNECTION OF BATTERY CHARGER XBC1A-1B (ALIGNING AC FROM TRAIN A AND DC TO TRAIN B)IC SET:INSTRUCTIONS:COMMENTS:DPN-1HA-ED odd breaker #'s on left, even BKR # on right. All "OFF" positions on outside and all "ON" positions on the inside. BKR 16, 22, 26, & 17 use international symbols of 'I' for "on/closed" & '0' for "off or open".

JPM SETUP SHEETFriday, September 02, 2011Page 10 of 10

2011 NRC Sim a RO & SRO: ENSURE CONTAINMENT ISOLATION

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPSF-045BAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:2THIS JPM IS APPROVEDTuesday, August 23, 2011Page 1 of 7

TASK:000-055-05-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

10TIME CRITICAL

NOTASK STANDARD:Containment isolation verified and complete with IFV-4701B directed to be closed and 2662 A is closed from the Main Control Board. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)3RESPOND TO LOSS OF OFF SITE AND ON SITE POWERTOOLS:EOP-1.0, Attachment 3, Step 13-14. Attachment 4 and 5.REFERENCES:TERMINATING CUE:XVT-2662 A is closed and local operator reports IFV-4701B is closed.EOP-1.0REACTOR TRIP/SAFETY INJECTION ACTUATIO

NINDEX NO.ROSROK/A NO.103000K102Containment isolation/containment integrity3.94.1K1.02Tuesday, August 23, 2011Page 2 of 7

INITIATING CUES:The CRS directs verifying Phase "A" and Containment Ventilation Isolation per EOP-1.0, Attachment 3, Step 13.INITIAL CONDITION:The plant has just experienced a LOCA and safety injection.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Tuesday, August 23, 2011Page 3 of 7

INITIATING CUES:The CRS directs verifying Phase "A" and Containment Ventilation Isolation per EOP-1.0, Attachment 3, Step 13.INITIAL CONDITION:The plant has just experienced a LOCA and safety injection.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TTuesday, August 23, 2011

STEPSVerifies Phase "A" and Containment Ventilation Isolation on XCP-6103, 6104 and

6106. REFER TO ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.(This is EOP-1.0 Att. 3 Step 13).YesOperator ensures Phase "A" Isolation by appearance of phase "A" valve status lights on MCB XCP-6104, 6103 and

6106. Refers to Attachment 4. Notes

RB AIR SERV ISOL 2662A(B) CLSD ar

eboth dim. Also notes that SG B BLWDN

ISOL 503B CLSD and CDRM CLG WT

RISOL 7501 CLSD are also both dim.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Actuates Phase A/Containment Ventilation Isolation.YesPlaces either TRAIN A & B CS-SG02A(B) switch to ACTUATE position.

Notes that CDRM CLG WTR ISOL 7501

CLSD now turns bright, but that none of the other indicators change states.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Operator attempts to close 503B, 2662 A, and 2662 B from the MCB valve control

switches.NOTE TO EVALUATOR: Placing 2662A RB AIR SERV ISOL to closed is the critical part of this

step.YesPlaces the control switches (individually)for 503B, 2662 A, and 2662 B to the "CLOSED" position. Notes 2662 A

closes but that the other valves still

indicate that they are open.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Tuesday, August 23, 2011Page 5 of 7

Examiner ends JPM at this point.Operator refers to Attachment 5 to identify backup isolation valve for XVG-503BNOTE TO EVALUATOR: Steps 3, 4, and 5 should be performed in sequence.YesOperator determines that IFV4701B is the backup valve for XVG-503B. (Page 1

of Attachment 5).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Directs AO to locally close IFV-4701BNOTE: Since 503B is an air operated valve outside of containment the AO may be directed to locally bleed air off 503B to isolate the penetration as well.NOTE to Booth Operator: When requested by student to locally close IFV-4701 B reply that the valve is closed.YesUses plant page or radio to direct AB lower to close IFV-4701B backup to MVG-503B, STEAM GEN B BLOWDOWN HEADER ISOL VALVE.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Tuesday, August 23, 2011Page 6 of 7

JPM NO:JPSF-045BDESCRIPTION:2011 NRC Sim a RO & SRO: ENSURE CONTAINMENT ISOLATIONIC SET:10INSTRUCTIONS:(322 for 2011)1. Activate: VLV-IA003P SEVERITY=100 (XVT-2662A fails to 100% open position) VLV-IA004P SEVERITY=100 (XVT-2662B fails to 100% open position) VLV-BD002P SEVERITY=100 (XVG-503B fails to 100% open position) VLV-AC001P SEVERITY=100 (XVT 7501A fails to 100% open position)Logic to get valves to move correctlyEvent 1: X021053A==1l X021054A==1VLV-AC001P SEVERITY=0 RAMP=25 (XVT 7501A closes when Phase A initiated)Event 2: X021407C==1VLV-IA003P SEVERITY=100 DELETE= 01 (XVT-2662A is allowed to be closed) MAL-RCS005A (Large break LOCA on 'A' loop)2. RUN 120 Seconds3. While running, trip RCP's and perform immediate action of EOP-1.0.4. When student is ready: RUN5. When requested by student to locally close XVT-4701 B reply that time compression is being used and that the valve is closed.COMMENTS:Performance of this JPM is related to PRA event 0-CNTMISOL-HE "Operator fails to manually initiate Phase A Isolation".

JPM SETUP SHEETTuesday, August 23, 2011Page 7 of 7

2011 NRC Sim b RO & SRO: BLOCK SOURCE RANGE HI FLUX TRIP.

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPS-161APPROVAL:

RJAPPROVAL DATE:9/3/2011REV NO:2THIS JPM IS APPROVEDSaturday, September 03, 2011Page 1 of 8

TASK:001-025-01-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

25TIME CRITICAL

NOTASK STANDARD:Reactor power is increased and stabilized at 10-3% without causing a reactor trip.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:55.45.b.6OPERATE CONTROL RODS MANUALLY AT POWERTOOLS:GOP-3, REACTOR STARTUP FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2)REFERENCES:TERMINATING CUE:Reactor power is stabilized at 10-3%.INDEX NO.ROSROK/A NO.015000A403Trip bypasses3.83.9A4.03Saturday, September 03, 2011Page 2 of 8

INITIATING CUES:The CRS directs you to Increase Reactor Power to 10-3% in accordance with GOP-3, REACTOR STARTUP FROM HOT

STANDBY TO STARTUP (MODE 3 TO MODE 2) step 3.12.INITIAL CONDITION:A reactor startup is in progress per GOP-3, REACTOR STARTUP

FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2). The

crew has just brought the reactor critical and has leveled power in accordance with step 3.11. Tave was verified to be above the minimum temperature for criticality 10 minutes prior to criticality,

Critical Rod Height position was 122 steps on Bank D and was verified to be above the Rod Insertion Limit, all in accordance with step 3.11.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Saturday, September 03, 2011Page 3 of 8

INITIATING CUES:The CRS directs you to Increase Reactor Power to 10-3% in accordance with GOP-3, REACTOR STARTUP FROM HOT

STANDBY TO STARTUP (MODE 3 TO MODE 2) step 3.12.INITIAL CONDITION:A reactor startup is in progress per GOP-3, REACTOR STARTUP

FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2). The

crew has just brought the reactor critical and has leveled power in accordance with step 3.11. Tave was verified to be above the minimum temperature for criticality 10 minutes prior to criticality,

Critical Rod Height position was 122 steps on Bank D and was verified to be above the Rod Insertion Limit, all in accordance with step 3.11.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TSaturday, September 03, 2011

STEPSEstablish a stable Startup Rate of less than one decade per minute.Evaluator Note: The candidate may level power to block the source range and then reestablish a positive startup rate. The critical aspect of this step is to raise reactor power.YesWithdraws rods to establish a stable startup rate of less than one decade per

minute.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1At 7.5x10-6%, perform the following:1) Verify P6 Permissive energizes to bright.2) Verify a minimum of one decade overlap

between Source Range Channels and

Intermediate Range Channels.YesVerifies P6 energize to bright and a one decade overlap exists between source

and intermediate range power channels.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Prior to 1E5 CPS, perform the following:Momentarily place SR TRAIN A Switch in

BLOCK.YesPlaces SR TRAIN A Switch to BLOCK.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Saturday, September 03, 2011Page 5 of 8

Verify SR A TRIP BLCK Permissive energizes to bright.YesVerifies SR A TRIP BLCK Permissive energizes to bright.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Momentarily place SR TRAIN B Switch in

BLOCK.YesPlaces SR TRAIN B Switch to BLOCK.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Verify SR B TRIP BLCK Permissive energizes to bright.YesVerifies SR B TRIP BLCK Permissive energizes to bright.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Saturday, September 03, 2011Page 6 of 8

Examiner ends JPM at this point.Perform one of the following for continued monitoring of Intermediate and Power Range instrument:

1) If available for use, select one

Intermediate Range Channel and one Power Range Channel on NR-45, NIS RECORDER.2) Ensure at least one Intermediate Range

and at least one Power Range instrument are selected for continuous monitoring using computer display NR45.YesSelects one power range and one intermediate range channel on NR-45.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:7Stabilize Reactor Power at 10-3%.YesInserts rods to stabilize power at 10-3%.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:8Saturday, September 03, 2011Page 7 of 8

JPM NO:JPS-161DESCRIPTION:2011 NRC Sim b RO & SRO: BLOCK SOURCE RANGE HI FLUX TRIP.IC SET:INSTRUCTIONS:(321 for 2011)1. Start from a snap that is ready for startup training.2. Pull rods to criticality and stabilize power below 7.6E-6 % power.3. Freeze.4. Ensure N-45 is placed into fast speed.5. Set RO IPCS screen to RX STRT on ZZ menu.6. When candidate is ready go to run.COMMENTS:

JPM SETUP SHEETSaturday, September 03, 2011Page 8 of 8

2011 NRC Sim c RO: DROPPED ROD RECOVERY

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPSF-012AAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:8THIS JPM IS APPROVEDSaturday, September 03, 2011Page 1 of 11

TASK:000-003-05-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

15TIME CRITICAL

NoTASK STANDARD:Manual reactor trip inserted after second control rod drops. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(A)5RESPOND TO DROPPED CONTROL RODTOOLS:AOP-403.6 (TO RECORD AFFECTED BANK HEIGHTS and to provide engineering numbers for limitations on rod withdrawal rates).REFERENCES:TERMINATING CUE:Manual reactor trip inserted.AOP-403.6DROPPED CONTROL RODINDEX NO.ROSROK/A NO.000003A102Controls and components necessary to

recover rod3.63.4AA1.02Saturday, September 03, 2011Page 2 of 11

INITIATING CUES:CRS has directed NROATC to recover Control Rod "F2" per AOP-403.6, starting with Step 11.INITIAL CONDITION:The plant was operating at 75% power with all controls in automatic

when Control Rod "F2" dropped due to a blown fuse. The blown fuse

was replaced in the 1AC power cabinet. Actions of AOP-403.6, DROPPED CONTROL ROD, have been completed through Step 10. Maximum power level and rod recovery rate have been established per

the AOP. The control building operator has already taken Key #91 and has reported that the P/A CONVERTER reading for the AFFECTED Bank is 230 steps.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Saturday, September 03, 2011Page 3 of 11

INITIATING CUES:CRS has directed NROATC to recover Control Rod "F2" per AOP-403.6, starting with Step 11.INITIAL CONDITION:The plant was operating at 75% power with all controls in automatic

when Control Rod "F2" dropped due to a blown fuse. The blown fuse

was replaced in the 1AC power cabinet. Actions of AOP-403.6, DROPPED CONTROL ROD, have been completed through Step 10. Maximum power level and rod recovery rate have been established per

the AOP. The control building operator has already taken Key #91 and has reported that the P/A CONVERTER reading for the AFFECTED Bank is 230 steps.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TSaturday, September 03, 2011

STEPSRecord Step Counter readings for both groups of the AFFECTED bank.PROCEDURE NOTE: Steps 11 through 15Throughout the following steps. "AFFECTED" refers to any Control Rod Bank which contains a dropped Control Rod.In this JPM the "AFFECTED" bank is Control Bank "A".YesStep counter reading for both groups in Control Bank "A" have been recorded a

s230 steps.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Record P/A Converter Reading.Booth Operator: It is not expected that you will be called to obtain key 91 and obtain this reading since it is in the initial conditions, but if called report that the P/A CONVERTER reading is 230 steps on Control Bank "A".YesP/A Converter reading has been

recorded.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Rotate ROD CNTRL BANK SEL Switch clockwise to the AFFECTED bank position.YesROD CNTRL BANK SEL Switch has been rotated clockwise to the CBA

position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Saturday, September 03, 2011Page 5 of 11

Reset the Step Counter for the AFFECTED group to zero.Resetting Shutdown Bank A vs. Control Bank A constitutes a failure of this step if the error is not detected and corrected before withdrawin

g the dropped rod.YesMomentarily depresses the RS pushbutton on the Step Counter for Bank A GROUP 1. Notes the indication is 000.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Place all Lift Coil Disconnect Switches for the affected bank, except switches for the dropped rod, to the ROD DISCONNECTED

position.As the CRS, Examiner should prompt the Examinee to disconnect the affected bank. Explain that the BOP Operator will watch the MCB while he accomplishes this task.YesAll lift coil disconnect switches for Control Bank "A" rods, except Rod "F2"

have been placed in the ROD DISCONNECTED position.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Withdraw the dropped rod: Drive the affected bank out.If rod withdrawal rate is requested, inform Examinee to refer to the provided AOP. Rod Control System Fail Urgent Alarm will alarm per procedure note. If Examinee asks whether to depress the

ROD CNTRL ALARM RESET switch, as the CRS, direct Examinee to depress the switch after the

rod has been reali

gned.YesRod F2 is moving in the outward

direction.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Saturday, September 03, 2011Page 6 of 11

Verify dropped rod movement on DRPI.YesDRPI indicator for rod "F2" in Control Bank "A" is verified to be moving out in

6step increments.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:7When dropped rod moves 6 steps, then verify ONE ROD ON BOTTOM annunciator clears.YesONE ROD ON BOTTOM annunciator is observed to be flashing (in the reset

condition).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Adjust turbine load to maintain Tavg within +/- 5°F of Tref.No turbine manipulations are required since Tav

g will remain within 5°F of Tref.YesTavg - Tref within +/- 5°F.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Saturday, September 03, 2011Page 7 of 11

Continue rod withdrawal to the demand position.YesRod withdrawn at not more than 48 steps per minute or 80% power as

determined in step 6.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:10Observes that Rod F2 stops moving at 48 steps and is apparently stuck.Note to Examiner: If candidate notices the stuck rod, but recommends to the CRS to attempt to move rods to ensure the rod is stuck, cue the candidate that the CRS will evaluate that recommendation and will call I&C for a troubleshooting plan.The immediate action for a struck rod is satisfied in this sequence by stopping rod withdrawal and leaving the Rod Bank Selector Switch in CB A but the candidate may transfer rods to MANUAL.When the applicant has identified the stuck rod and stopped rod withdrawal, cue the booth operator to insert the malfunction to drop two rods.Note to Booth Operator: DO NOT insert rod drop malfunction until cued b

y Examiner.YesNotices that rod F2 is stuck and stops rod withdrawal before step counter

reads 62 steps. (Stopping at 61 or less

is satisfactory).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:11Observes that Rod H2 drops into the core and rod F2 drops into the core as well.YesEvaluates as 2 dropped rods.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:12Saturday, September 03, 2011Page 8 of 11

Examiner ends JPM at this point.Inserts a manual reactor trip.The Examinee should insert a manual reactor trip upon observing control rods F2 and H2 drop. Continuing to withdraw original dropped rod more than 12 steps after the second rod is dropped constitutes failure.YesPlaces the manual reactor trip switch to the TRIP position. Both reactor trip breakers indicate green light ON, red

light OFF. All rod bottom lights are lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:13Saturday, September 03, 2011Page 9 of 11

JPM NO:JPSF-012ADESCRIPTION:2011 NRC Sim c RO: DROPPED ROD RECOVERYIC SET:11INSTRUCTIONS:(320 for 2011)

1. RUN2. Activate:MAL-CRF004F2 FAIL TO = STATIONARY (Control rod F2 drops)ANN-CP002 CMPTR NIS PR TILTS = ON Set on Trigger #1 DELETE IN: 30 seconds TD = 04. Control Tavg-Tref deviation within +/-1.5°F with rods in AUTO.

5. Place rod control in MANUAL.6. Allow SIPCS to update QPTR and Axial Flux parameters prior to going to FREEZE.7. Record the following information in AOP-403.6 Step 7 & 9 prior to start: Step 7:

Time Rod Dropped: 15 minutes ago

Dropped Rod Location: "F2"Initial Power Level: 75%Current Power Level: <75%

Current QPTR: 1.02 Step 9:Power Level at which recovery is to be performed: <80%

Rod Rate: not more than 48 steps/min.8. FREEZE9. When student is ready:RUN

10. When control rod F2 is withdrawn to exactly 48 steps, insert using event/trigger1: Event logic: mcrfns(17)==48 (rod at 48 steps). MAL-CRF007F2 SELECT=TRIPPABLE (Rod F2 sticks) 11. When directed by the Examiner insert trigger 2: MAL-CRF004H2 SELECT=STATIONARY (Control rod H2 drops)

JPM SETUP SHEETSaturday, September 03, 2011Page 10 of 11

MAL-CRF007F2 SELECT=TRIPPABLE Delete in 1 second (removes stuck rod) MAL-CRF004F2 SELECT=STATIONARY (Control rod F2 drops)COMMENTS:Booth Operator: When told to take key 91 and go to the Rod Control Cabinet (IB-463) and locally at

XCA4-CR P/A Converter Cabinet for the affected bank give Examinee P/A Converter reading of 230

steps.DO NOT insert rod drop malfunction (trigger 2) until cued by Examiner.Saturday, September 03, 2011Page 11 of 11

2011 NRC Sim d RO: TRANSFER TO HOT LEG RECIRCULATION

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPS-002AAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:4THIS JPM IS APPROVEDTuesday, August 30, 2011Page 1 of 9

TASK:000-137-05-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

10TIME CRITICAL

NoTASK STANDARD:Safety Injection system has been aligned for Hot Leg Recirculation. Charging pumps have not been runout or deadheaded. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)7TRANSFER RHR FROM COLD LEG TO HOT LEG RECIRCULATIONTOOLS:EOP-2.3REFERENCES:TERMINATING CUE:'B' charging pump is started.EOP-2.0LOSS OF REACTOR OR SECONDARY COOLANTEOP-2.3TRANSFER TO HOT LEG RECIRCULATIONINDEX NO.ROSROK/A NO.006000A402Valves4.03.8A4.02006000K418Valves normally isolated from their control power3.63.7K4.18Tuesday, August 30, 2011Page 2 of 9

INITIATING CUES:The CRS directs the NROATC to transfer from Cold Leg to Hot Leg Recirculation per EOP-2.3.INITIAL CONDITION:It has been 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> since a Loss of Coolant Accident occurred and the

plant is presently in the Cold Leg Recirculation mode. The CRS has

entered EOP-2.3 (Hot Leg Recirculation) from EOP-2.0. CHG/SI Pump C is aligned to "B" train.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Tuesday, August 30, 2011Page 3 of 9

INITIATING CUES:The CRS directs the NROATC to transfer from Cold Leg to Hot Leg Recirculation per EOP-2.3.INITIAL CONDITION:It has been 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> since a Loss of Coolant Accident occurred and the

plant is presently in the Cold Leg Recirculation mode. The CRS has

entered EOP-2.3 (Hot Leg Recirculation) from EOP-2.0. CHG/SI Pump C is aligned to "B" train.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TTuesday, August 30, 2011

STEPSAlign Train A Charging Pumps for Hot Leg Recirculation:Stop the Charging Pump on "A" TrainProcedure Note: "Hot Leg Recirculation should be established at eight hours after a Loss of Reactor Coolant Accident." The eight (8) hours is given in the initial conditions, but if the candidate requests this information from the CRS cue the candidate that 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> have elapsed.Examiner Note: If Charging Pump "A" is still running when 8885 is closed, it will be deadheaded; this constitutes failure. Running the charging pump with both 8885 and 8884 open runs the pump out, also failin

g.YesPlaces CHG/SI Pump 'A' control switch to STOP and verifies CHG/SI Pump 'A' indicates OFF.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1Check if CHG/SI Pump C is aligned to Train A by verifying XFER switch XET 2002C ON TRAIN A IS LIT.YesXFER SWITCH XET 2002C on Train A is not lit, goes to alternative action.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Ensure MVG-8132A and MVG-8132B, CHG PP C TO LP A DISCH are closed.YesVerifies MVG-8132A and MVG-8132B CHG PP C TO LP A DISCH are closed,

verifying green light ON and red light is

OFF for each valve.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Tuesday, August 30, 2011Page 5 of 9

Close charging LP "A" ALT to COLD LEG (MVG-8885).YesMVG-8885, CHG LP A TO COLD LEGS

,indicates CLOSE.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Open CHG LP "A" to HOT LEGS (MVG-8884).Examiner Note: Candidate must ener

gize power lockout to chan

ge the position of MVG-8884YesMVG-8884, CHG LP A TO HOT LEGS, indicates OPEN.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:5Start "A" Charging Pump.Booth Operator: If called to check out the "A" charging pump for a start report the pump is ready for start and that suction pressure is 53 psi

g.YesPlaces CHG/SI Pump 'A control switch to START and verifies CHG/SI PUMP

"A" indicates ON with normal running amps.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Tuesday, August 30, 2011Page 6 of 9

Align Train B Charging Pumps for Hot Leg Recirculation:Stop "B" charging pump.YesPlaces CHG/SI Pump 'B control switch to STOP and verifies CHG/SI Pump 'B'

indicates OFF with 0 amps.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Check if 'C' charging pump is aligned to

Train B.YesVerifies XFER SWITCH XET2000C ON TRAIN B is lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Ensure MVG-8132A and MVG-8132B, CHG PP C TO LP A DISCH, are closed.YesEnsures MVG-8132A and MVG-8132B, CHG PP C TO LP A DISCH, indicate

CLOSED.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Ensure MVG-8801A, HI HEAD to COLD LEG INJECTION, is closed.YesMVG-8801A, HI HEAD TO COLD LEG INJ indicates CLOSED.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:10Tuesday, August 30, 2011Page 7 of 9

Examiner ends JPM at this point.Close MVG-8801B, HI HEAD TO COLD LEG INJECTION valve.Examiner Note: If 8801B is closed with "B" Charging Pump running, this deadheads the pump and constitutes failure of the JPM.YesTakes control switch for MVG-8801B, HI HEAD TO COLD LEG INJ, to the closed position, checks red light OFF and gree

nlight ON.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:11Open MVG-8886,CHG LP B TO HOT LEGS.Examiner Note: Candidate must ener

gize power lockout to chan

ge the position of MVG-8886YesMVG-8886, CHG LP B TO HOT LEGS, indicates OPEN.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:12Start "B" CHG/SI pump.Booth Operator: If called to check out the "B" charging pump for a start report the pump is ready for start and that suction pressure is 54 psi

g.YesPlaces CHG/SI Pump 'B control switch to START and verifies CHG/SI Pump 'B'

indicates ON with normal running amps.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:13Tuesday, August 30, 2011Page 8 of 9

JPM NO:JPS-002ADESCRIPTION:2011 NRC Sim d RO: TRANSFER TO HOT LEG RECIRCULATIONIC SET:10INSTRUCTIONS:(323 for 2011)1. Activate MAL-RCS005A RCS Loop 'A' DBA LOCA2. RUN3. Perform actions of EOP-1.0 and 2.04. FREEZE5. Ensure RHR Sump Level >415', then activate LOA-AUX115 SEVERITY=0.17 (17% in RWST)6. RUN7. Transfer Cold Leg Injection to Cold Leg Recirculation IAW EOP-2.2.8. To shift CCW to fast speed during EOP-2.2: LOA-CCW050 SELECT=FAST SPEED 'A' CCW Pump Speed Switch to fast or LOA-CCW052 SELECT=FAST SPEED 'C' CCW Pump Speed Switch to fast9. Swap C Charging pump to B TrainLOA CVC045 Charging pump C disconnect switch SELECT= TRAIN B.10. FREEZE11. When student is ready:

RUNCOMMENTS:Charging Pumps must be stopped before opening Hot Leg High Head Valves (8884/8886) to prevent pump runout.

JPM SETUP SHEETTuesday, August 30, 2011Page 9 of 9

2011 NRC Sim e RO: STEAM GENERATOR TUBE RUPTURE (DEPRESSURIZE RCS TO <

RUPTURED S/G PRESSURE)

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPSF-007APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:15THIS JPM IS APPROVEDTuesday, August 30, 2011Page 1 of 8

TASK:000-038-05-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

10TIME CRITICAL

NoTASK STANDARD:RCS pressure is reduced to less than ruptured S/G pressure with PZR level > 10% or PZR level > 76% or RCS subcooling < 52.5°F. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations. This JPM is related to PRA event OAP2 " Depressurize RCS to stop leakage into ruptured S/G"PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:45(a)6RESPOND TO STEAM GENERATOR TUBE RUPTURETOOLS:EOP-4.0REFERENCES:TERMINATING CUE:RCS depressurization complete when task standard met and PCV-444C & D are closed.EOP-4.0STEAM GENERATOR TUBE RUPTUREINDEX NO.ROSROK/A NO.000038A104PZR spray, to reduce coolant system pressure4.34.1EA1.04Tuesday, August 30, 2011Page 2 of 8

INITIATING CUES:Control Room Supervisor directs operator to depressurize the RCS using PZR Spray, per EOP-4.0, Step 22.INITIAL CONDITION:A Steam Generator Tube Rupture is in progress. S/G "C" has been

isolated per EOP-4.0. An operator initiated cooldown has been

performed according to EOP-4.0, through Step 21.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Tuesday, August 30, 2011Page 3 of 8

INITIATING CUES:Control Room Supervisor directs operator to depressurize the RCS using PZR Spray, per EOP-4.0, Step 22.INITIAL CONDITION:A Steam Generator Tube Rupture is in progress. S/G "C" has been isolated per EOP-4.0. An operator initiated cooldown has been

performed according to EOP-4.0, through Step 21.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TTuesday, August 30, 2011

STEPSDepressurize the RCS using normal spray valves PCV-444C and 444D.Examiner Note: Give examinee 1-2 minutes to familiarize himself with his control board indications and his place in the procedure.YesPlaces PZR Spray PVC-444C & 444D controllers in MANUAL and increases

output to 100% demand. Verifies red

light ON and green light OFF for both PCV-444C & D.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:1Use maximum available spray until any termination criteria is met; RCS pressure <

Ruptured ('C') S/G pressure and PZR level > 10%; or PZR level >76%; or RCS subcooling <52.5°F.Examiner Note: Using the MCB indicators it is most likely that will terminate on RCS pressure < Ruptured ('C') S/G pressure and PZR level > 10%, but if using IPCS values it is more likely that will

terminate on PZR level >76. Both termination criteria occur at about the same time and

terminatin

g on either one is satisfactor

y.YesRecognizes from MCB indication that RCS pressure is less than 'C' S/G pressure with PZR level >10% or PZR level >76%, or RCS subcooling <52.5°F.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Stop RCS depressurization.Examiner Note: The critical part of this step is closin

g PCV-444C.YesDecreases PCV-444C & 444D controller output demand to zero. Notes that PCV

-444D did not go closed.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Tuesday, August 30, 2011Page 5 of 8

Examiner ends JPM at this point.Identify failure of PCV-444D to close and secures 'A' RCP.Examiner Note: It is expected for pressure to continue to decrease slowly after 'A' RCP is stopped and so it is critical to trip two

(2) RCP's.Yes'A' RCP tripped to stop depressurization. Also stops either 'B' RCP or 'C' RCP if pressure continues to

decrease.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:4Close PVT-8145, PZR SPRAY FR CVCS.YesVerifies PVT-8145 green light ON and red light OFF.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Tuesday, August 30, 2011Page 6 of 8

JPM NO:JPSF-007DESCRIPTION:2011 NRC Sim e RO: STEAM GENERATOR TUBE RUPTURE (DEPRESSURIZE RCS TO < RUPTURED S/G PRESSURE)IC SET:10INSTRUCTIONS:(324 for 2011)1. Activate MAL-RCS002C SEVERITY=450 RAMP=30 (S/G Tube Rupture on 'C' S/G)

2. RUN3. Carry out actions of AOP-112.2 until SI occurs.4. Manual SI and perform actions of EOP-1.0 & EOP-4.0 up through step 3g.

5. Throttle EFW to 'C' S/G when level > 40%.6. FREEZE7. Activate LOA-MSS033 SELECT=OPEN (RACK OUT BKR FOR MVG-2802B (STM SUPPLY TO TDEFP))8. RUN

9. Perform actions of steps 3h-21 of EOP-4.0.10. FREEZE11. When student is ready: RUN12. After spray valve is manually full open by the student Activate: (event in place, but is not reliable). MAL-PRS003B SEVERITY=100 RAMP=10 (PCV-444D STUCK OPEN) Use conditional X05i049m > 0.9COMMENTS:This JPM can be run from the same snap as JPS007 with the addition of MAL-PRS003B = 100%

JPM SETUP SHEETTuesday, August 30, 2011Page 7 of 8

Tuesday, August 30, 2011Page 8 of 8

2011 NRC Sim g RO: RESPONSE TO STEAM GENERATOR OVERPRESSURE IAW EOP-15.3

V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPS-149AAPPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:4THIS JPM IS APPROVEDFriday, September 02, 2011Page 1 of 10

TASK:311-006-06-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

10TIME CRITICAL

NOTASK STANDARD:S/G pressures has been lowered to <1170 psigPREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:55.45.b.6RESPONSE TO LOSS OF SECONDARY HEAT SINKTOOLS:EOP-15.3REFERENCES:TERMINATING CUE:S/G pressures are returned to normal.EOP-15.3RESPONSE TO LOSS OF NORMAL STEAM RELE

ACAPABILITIESINDEX NO.ROSROK/A NO.0410002120Ability to interpret and execute procedure steps.4.64.62.1.20Friday, September 02, 2011Page 2 of 10

INITIATING CUES:The CRS directs you to implement EOP-15.3.INITIAL CONDITION:The plant has tripped due to a inadvertent main steam line isolation. Only the Turbine Driven Emergency Feedwater Pump started.

A yellow path exists for a transition to EOP-15.3, RESPONSE TO LOSS OF NORMAL STEAM RELEASE CAPABILITIES.READ TO OPERATOR:SAFETY CONSIDERATIONS:WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Friday, September 02, 2011Page 3 of 10

INITIATING CUES:The CRS directs you to implement EOP-15.3.INITIAL CONDITION:The plant has tripped due to a inadvertent main steam line isolation. Only the Turbine Driven Emergency Feedwater Pump started.

A yellow path exists for a transition to EOP-15.3, RESPONSE TO LOSS OF NORMAL STEAM RELEASE CAPABILITIES.SAFETY CONSIDERATIONS:OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TFriday, September 02, 2011

STEPSCAUTION If SG Narrow Range level increases to

GREATER THAN 90% [83%], steam should NOT be released from that SG until an evaluation is performed for SG overfill

conditions, to prevent damage to steamline

piping and valves.NOTE -Throughout this procedure, "AFFECTED" refers to any SG with pressure GREATER THAN 1170 psig.

- Conditions for implementing Emergency

Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY

PLAN.YesReads caution and note.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Verify PERMISV C-9 status light is bright on XCP-6114 1-3.Evaluator Note: simulator was snapped with the condenser available (and so it is not an alternate path JPM). If candidate delays actions so that C-9 is no longer bright the alternate action to release steam via the PORV may also be used to reduce pressure. Lowering pressure is the

critical part of this JPM.YesOperator locates and verifies C-9 is bright on XCP-6114 1-3.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Friday, September 02, 2011Page 5 of 10

Verify the MS Isolation Valves, PVM-2801A(B)(C), are open.

OR Open MS Isolation Bypass Valves: 1) Depress both MAIN STEAM ISOL

VALVES RESET TRAIN A(B).

2) Open MS Isolation Bypass Valves, PVM-2869A(B)(C).Examiner Note: MS Isolation Bypass Valves, PVM-2869A(B)(C) require two hand operation to open. The common "B" train switch has to be held to open while the individual "A" train switches are operated.Examiner Note: This step is not critical if PORVs are opened in manual to lower pressure. The critical step is to lower pressure.YesDetermines that MS Isolation Valves, PVM-2801A(B)(C), are closed. Depresses both MAIN STEAM ISOL VALVES RESET TRAIN A(B).

Opens MS Isolation Bypass Valves, PVM-2869A(B)(C) and verifies red light lit green light dim.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:3Place the STM DUMP CNTRL Controller in MAN and closed.YesOperator locates and places STM DUMP CNTRL Controller in MAN and

closed.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Ensure the STM DUMP CNTRL Controller is set to 8.4 (1090 psig).NOTE: IC was snapped with controller alread

y at 8.4.YesSTM DUMP CNTRL Controller is set to 8.4 (1090 psig).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Friday, September 02, 2011Page 6 of 10

Place the STM DUMP MODE SELECT Switch in STM PRESS.YesSTM DUMP MODE SELECT Switch is in STM PRESS.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:6Place the STM DUMP CNTRL Controller in

AUTO.Examiner Note: This step is not critical if the PORVs are opened to lower pressure. The critical step in that case is to lower pressure.YesSTM DUMP CNTRL Controller is in AUTO.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:7Verify Condenser Steam Dumps are open.Examiner Note: Because steam line drains are open it is not expected that steam dumps will open immediately. The JPM should be ended as long as the main steam bypass valves are open and a

yellow path no lon

ger exists to EOP-15.3.YesDetermines proper operation of steam

dumps.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:8Friday, September 02, 2011Page 7 of 10

Examiner ends JPM at this point.Verify SG pressures are LESS THAN 1170

psig.YesDetermines that all steam generator pressures are now <1170 psig.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:9Friday, September 02, 2011Page 8 of 10

JPM NO:JPS-149ADESCRIPTION:2011 NRC Sim g RO: RESPONSE TO STEAM GENERATOR OVERPRESSURE IAW EOP-15.3IC SET:10INSTRUCTIONS:(330 for 2011)Trigger 1:MAL-PCS014 INDAVERTENT MS ISOLATION Delete in 1 second.Use a inadvertent closure of all the mainsteam lines (at once to preclude a SI where it would be less likely to direct the completion of a yellow path). Delete in 1 second to allow opening of main steam

isolation bypass valves.OVR-MB005B, PC-2000 STM DMP LINE A POT SIGNAL =10.0OVR-MB006B, PC-2010 STM DMP LINE B POT SIGNAL =10.0

OVR-MB007B, PC-2020 STM DMP LINE C POT SIGNAL =10.0Overrides Pots so that steamline porv's do not open enough to lower pressure.BST-MS054, ILS02806A REL VLV MS = INHIBITEDBST-MS055, ILS02806B REL VLV MS = INHIBITEDBST-MS059, ILS02806F REL VLV MS = INHIBITEDBST-MS060, ILS02806G REL VLV MS = INHIBITED

BST-MS064, ILS02806K REL VLV MS = INHIBITED

BST-MS065, ILS02806L REL VLV MS = INHIBITEDOverrides steam line safeties to maintain pressure >1170 (with two on each line failed pressure drops to 1176 when remaining safeties lift.PMP-EF001F, MOTOR DRIVEN EFW PMP A FAIL TO STARTPMP-EF002F, MOTOR DRIVEN EFW PMP B FAIL TO STARTEnsure that the snap is generated fast enough to ensure that C-9 remains bright.FREEZEWhen the candidate is ready go to RUN (DO NOT RUN for setup).When snapping into IC set verify that all S/G PORV's are set to 8.4 exactly even though IC snap will say they should be at 10.0.COMMENTS:NOTE: PORV pots are overridden do not adjust MCB pots to snap into IC. Use override AFTER rods have stepped all the way out. All steam dump and PORV controllers should read 8.4.

JPM SETUP SHEETFriday, September 02, 2011Page 9 of 10

Friday, September 02, 2011Page 10 of 10

2011 NRC Sim h RO: Respond to electrical grid issues.V.C. SUMMER NUCLEAR STATION

JOB PERFORMANCE MEASURECANDIDATE:EXAMINER:JPM NO:JPSF-160APPROVAL:

RJAPPROVAL DATE:7/30/2011REV NO:1THIS JPM IS APPROVEDTuesday, August 30, 2011Page 1 of 8

TASK:064-003-01-01PREFERRED EVALUATION METHODPERFORMEVALUATION TIME

10TIME CRITICAL

NOTASK STANDARD:Determines that 1DB voltage is too low and starts the 'B' Diesel Generator. When the diesel generator is ready for load opens the normal incoming breaker for 1DB.PREFERRED EVALUATION LOCATIONSIMULATORTIME START:TIME FINISH:PERFORMANCE RATING:SAT:UNSAT:PERFORMANCE TIME:EXAMINER:SIGNATUREDATE10CFR55:55.45.b.3LOAD THE DIESEL GENERATORTOOLS:AOP-301.1, RESPONSE TO ELECTRICAL GRID ISSUESREFERENCES:TERMINATING CUE:1DB is being supplied power from the diesel.INDEX NO.ROSROK/A NO.0000772119Ability to use plant computers to evaluate system or component status.3.93.82.1.190000772120Ability to interpret and execute procedure steps.4.64.62.1.20Tuesday, August 30, 2011Page 2 of 8

INITIATING CUES:The CRS directs you as the BOP to perform AOP-301.1, RESPONSE TO ELECTRICAL GRID ISSUES starting at step 3.INITIAL CONDITION:100% Power. A grid instability condition exists. The crew has entered AOP-301.1, RESPONSE TO ELECTRICAL GRID ISSUES, and has

performed steps 1 and 2.READ TO OPERATOR:SAFETY CONSIDERATIONS:

None.WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THE OBJECTIVE FOR THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.INSTRUCTIONS TO OPERATORHAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!Tuesday, August 30, 2011Page 3 of 8

INITIATING CUES:The CRS directs you as the BOP to perform AOP-301.1, RESPONSE TO ELECTRICAL GRID ISSUES starting at step 3.INITIAL CONDITION:100% Power. A grid instability condition exists. The crew has entered

AOP-301.1, RESPONSE TO ELECTRICAL GRID ISSUES, and has

performed steps 1 and 2.SAFETY CONSIDERATIONS:

None.OPERATOR INSTRUCTIONS:HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

JPM BRIEFING SHEE

TTuesday, August 30, 2011

STEPSCheck that a Turbine Runback is NOT required.YesVerifies that the following annunciators are NOT in alarm.OP Delta T (XCP-615 2-2).

OT Delta T(XCP-615 3-2).Verifies that the following status lights are dim.

PERMISV C-7A PB-447A.

PERMISV C-7B PB-447B. OT DELTA T C-3 (XCP-6109 1-29). OP DELTA T C-4 (XCP-6109 1-31).CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:1Monitor Main Turbine and Generator for proper operation.YesMonitors turbine using AOP301 or TURBRG on IPCSCUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:2Ensure Main Generator MVAR loading is within the limits of the Estimated Generator

Capability Curve.YesDetermines that MVARS are ~305 and uses Attachment 2 or AOP301 on IPCS to determine that MVARS are within limits.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:3Tuesday, August 30, 2011Page 5 of 8

Check if Bus 1DA voltage is greater than 6840 volts.YesFinds 1DA voltage and determines that i

tis normal.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:4Check if Bus 1DB voltage is greater than 6840 volts.Examiner Note: This is when this JPM becomes alternate path.YesDetermines that voltage is less than

6840 volts.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:5Ensure Diesel Generator 'B' has started in the Emergency Mode.YesDepresses, DG 'B' Control, EMERG START pushbutton.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:6Check if Annunciator XCP-640 3-2 is lit (DG A READY FOR LOAD).YesVerifies that XCP-640 3-2 is lit.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRNoSTEP:7Tuesday, August 30, 2011Page 6 of 8

Examiner ends JPM at this point.Ensure the normal and alternate feeder breakers to 1DB are open.YesOpens BUS 1DB NORM FEED Breaker.CUES:SEQSTEP STANDARD:COMMENTS:SATUNSATCRYesSTEP:8Tuesday, August 30, 2011Page 7 of 8

JPM NO:JPSF-160DESCRIPTION:2011 NRC Sim h RO: Respond to electrical grid issues.IC SET:10INSTRUCTIONS:(325 for 2011)1. Insert malfuctions:MAL-EPS006B, DIESEL GENERATOR B FAILURE Set= NO_AUTO_START

MAL-EPS020, DEGRADED GRID VOLTAGE Set=14

2. Insert overrides:IND-DG018, V-1DB 1DB BUS VMTR METER SIGNAL Set =6465IND-ES006, V-1A 1A BUS VOLTMTR METER SIGNAL Set=6742.12

IND-ES007, V-1B 1B BUS VOLTMTR METER SIGNAL Set=6768.1

IND-ES009, V-1C 1C BUS VOLTMTR METER SIGNAL Set=6780Note: the numbers do not truly indicate actual voltage reading on simulator so verify that 1DB is <6840 volts.

3. Lower MVAR to <325 MVARS.4. Run until you get 230 V HI/LO volta alarm.5. When canidate is ready go to run.Trigger 2:IND-DG018, V-1DB 1DB BUS VMTR METER SIGNAL Set = 6465 Delete in 1 sec.X13I070T >0 I as in india, 0's are zeros.COMMENTS:

JPM SETUP SHEETTuesday, August 30, 2011Page 8 of 8