ML18057B518: Difference between revisions

JPM NO: JPA-081A

2011 NRC Admin A1-a RO & SRO: OPERATIONAL

LEAK RATE TEST (STP-114.002) W/O IPCS LEAK

RATE PROGRAM AVAILABLE

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 5

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Saturday, September 03, 2011 Page 1 of 10

TASK:

002-001-02-01 PERFORM REACTOR COOLANT SYSTEM WATER INVENTORY

BALANCE

TASK STANDARD:

Unidentified leak rate determined to be outside Technical Specification limits.

TERMINATING CUE: Unidentified leakage calculated.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES: STP-114.002 OPERATIONAL LEAK TEST

INDEX NO. K/A NO. RO SRO

002000A401 A4.01 RCS leakage calculation program using 3.5 3.8

the computer

002000K405 K4.05 Detection of RCS leakage 3.8 4.2

002000A301 A3.01 Reactor coolant leak detection system 3.7 3.9

TOOLS: STP-114.002

CURVE BOOK Figure V-7

CURVE BOOK Figure VI-22

T.S. 3.4.6.2

CALCULATOR

EVALUATION TIME 20 TIME CRITICAL No 10CFR55: 41(b)10

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Saturday, September 03, 2011 Page 2 of 10

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL 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.

INITIATING CUES: Perform the manual leak rate calculation, using STP-114.002.

INITIAL DATA, TIME START 0345:

T0499A, RCL MEDIAN TAVG = 587.4°F

L0480A, 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°F

L0480A, 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.c

Saturday, September 03, 2011 Page 3 of 10

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Saturday, September 03, 2011 Page 4 of 10

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL 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.

INITIATING CUES: Perform the manual leak rate calculation, using STP-114.002.

INITIAL DATA, TIME START 0345:

T0499A, RCL MEDIAN TAVG = 587.4°F

L0480A, 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°F

L0480A, 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.c

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Saturday, September 03, 2011

Saturday, September 03, 2011 Page 6 of 10

STEPS

STEP: 1

CUES:

CR SEQ STEP STANDARD:

No Yes Inputs data into TEST DATA SHEET Student inputs data, initial and final

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No Yes Calculates change in test data Student subtracts initial data from final to

determine change in Tavg, Pressurizer

level, VCT level, PRT level and RCDT

level

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

CR SEQ STEP STANDARD:

No Yes Inputs factor for leakage parameters Student inputs data from References

identified at the bottom of leakrate form.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 7 of 10

STEP: 4

CUES:

CR SEQ STEP STANDARD:

Yes Yes Calculates TOTAL LEAKAGE Student 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 of

calculated TOTAL Leakage of 1.5514

and 1.5664 gpm.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

No Yes Calculates IDENTIFIED LEAKAGE Student calculates IDENTIFIED

LEAKAGE per STP-114.002 between 0

and 0.15 gpm.. Tolerance given to allow

using 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.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 8 of 10

STEP: 6

CUES:

CR SEQ STEP STANDARD:

Yes Yes Calculates UNIDENTIFIED LEAKAGE Student 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.

COMMENTS: SAT

UNSAT

STEP: 7

CUES:

May prompt operator to report findings.

CR SEQ STEP STANDARD:

Yes Yes Student identifies Tech Spec LCO not Student reports to CRS that

satisfied. UNIDENTIFIED LEAKAGE is in excess

of T.S. 3.4.6.2.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Saturday, September 03, 2011 Page 9 of 10

JPM SETUP SHEET

JPM NO: JPA-081A

DESCRIPTION: 2011 NRC Admin A1-a RO & SRO: OPERATIONAL LEAK RATE TEST (STP-

114.002) W/O IPCS LEAK RATE PROGRAM AVAILABLE

IC SET:

INSTRUCTIONS:

COMMENTS:

Saturday, September 03, 2011 Page 10 of 10

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-006B

2011 NRC Admin A1-b RO: CALCULATE

REACTIVITY CONTROL PARAMETERS (Base on

new core at MOL)

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 5

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Wednesday, September 07, 2011 Page 1 of 11

TASK:

004-006-01-01 PERFORM BORON CHANGE CALCULATIONS

TASK STANDARD:

OAP-100.6, Attachment IA, Reactivity Control Parameters, completed.

TERMINATING CUE: Examinee provides OAP-100.06, Attachment 1A to the Examiner.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES: SAP-155 REACTIVITY MANAGEMENT

OAP-100.6 CONTROL ROOM CONDUCT AND CONTROL OF

ACTIVITIES

INDEX NO. K/A NO. RO SRO

1940012118 2.1.18 Ability to make accurate, clear and 3.6 3.8

concise logs, records, status boards,

and reports.

TOOLS: OAP-100.6 ATTACHMENT IA

CALCULATOR

VC SUMMER CURVE BOOK (sections)

OAP-100.6, Attachment IA Answer Key (Examiner Copy)

EVALUATION TIME 15 TIME CRITICAL NO 10CFR55: 45(a)12

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Wednesday, September 07, 2011 Page 2 of 11

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant is operating at 100%, steady-state power. It is Sunday day

shift.

INITIATING CUES: The CRS directs the NROATC to complete OAP-100.6, Attachment IA,

Reactivity Control Parameters.

PARAMETER DATA:

RCS Boron Concentration = 1050 ppm

BURNUP = 10,000 MWD/MTU

BAT in Service = BAT "A"

BAT "A" Boron Concentration = 7000 ppm

BAT "B" Boron Concentration = 7581 ppm

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Wednesday, September 07, 2011 Page 3 of 11

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant is operating at 100%, steady-state power. It is Sunday day

shift.

INITIATING CUES: The CRS directs the NROATC to complete OAP-100.6, Attachment IA,

Reactivity Control Parameters.

PARAMETER DATA:

RCS Boron Concentration = 1050 ppm

BURNUP = 10,000 MWD/MTU

BAT in Service = BAT "A"

BAT "A" Boron Concentration = 7000 ppm

BAT "B" Boron Concentration = 7581 ppm

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Wednesday, September 07, 2011

STEPS

STEP: 1

CUES:

NOTE: Provide Examinee with blank copy of OAP-100.6, Attachment 1A, Reactivity Control

Parameter Data Sheet and Station Curve Book. NOTE: Value obtained from Initiating Cues.

CR SEQ STEP STANDARD:

No Yes RCS Boron Concentration _______ ppm Enters 1050 ppm.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

NOTE: Value obtained from Initiating Cues.

CR SEQ STEP STANDARD:

No Yes Burnup _________ MWD/MTU Enters 10,000 MWD/MTU.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

NOTE: Value obtained from Initiating Cues.

CR SEQ STEP STANDARD:

No Yes (Check BAT in Service) Checks BAT "A" inservice.

Enters BAT "A" Boron Concentration =

7000 ppm.

Enters BAT "B" Boron Concentration =

7581 ppm.

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 5 of 11

STEP: 4

CUES:

NOTE: Value obtained from Table on Fig. II-3.7 for 10,000 MWD/MTU.

CR SEQ STEP STANDARD:

No Yes Moderator Temperature Coefficient (MTC) Enters (-)16.6 - (-)17.6.

(Fig. II-3.7, HFP) ______ pcm/ppm

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

NOTE: Value obtained from Table on Fig. II-7.2 for 1050 ppm.

CR SEQ STEP STANDARD:

Yes Yes Differential Boron Worth (DBW) (Fig. II-7.2, Enters - 6.83 to -6.96 pcm/ppm. (see

HFP) _______ pcm/ppm key for derivation)

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

CR SEQ STEP STANDARD:

No Yes Gallons of Boric Acid or Reactor Makeup Enters 2.385 to 2.577 for ppm Boron

Water required to change RCS average Change/°F. (see key for derivation)

temperature by one (1) degree:

MTC/DBW = _____/______ = ________

ppm Boron Change/°F

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 6 of 11

STEP: 7

CUES:

CR SEQ STEP STANDARD:

Yes Yes (Fig. III-2) ______ gal. Acid/°F Enters 19.79-21.65 for gal. Acid/°F.

(see key for derivation)

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

Yes Yes (Fig. III-3) _________ gal. RMW/°F Enters 108.04-128.59 for gal. RMW/°F.

(see key for derivation)

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

NOTE: Values from Fig. II-2: 1717 PD @ 100% RTP - 1549 PD @ 90% RTP = 168

CR SEQ STEP STANDARD:

Yes Yes Power Defect (PD) for 10% power change Enters 168 Power Defect, ppm.

(100% to 90%) (Fig. II-2).

_____ PD @ 100% RTP - _____ PD @ 90%

= _____ Power Defect, ppm

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 7 of 11

STEP: 10

CUES:

CR SEQ STEP STANDARD:

Yes Yes Gallons of Boric Acid only to reduce reactor Enters 24.1 to 24.6 ppm Boron. (see key

power from 100% to 90%: for derivation)

Power Defect/DBW = _____ / _____ =

_______ ppm Boron

COMMENTS: SAT

UNSAT

STEP: 11

CUES:

CR SEQ STEP STANDARD:

Yes Yes (Figure III-2) ________ gal. Boric Acid/10% Enters 200.27-207.64 for gal. Boric

RTP Acid/10% RTP. (see key for derivation)

COMMENTS: SAT

UNSAT

STEP: 12

CUES:

NOTE: Examinee determines value is taken from Step 9.

CR SEQ STEP STANDARD:

No Yes Final rod height using rods only to reduce Enters 168 pcm.

reactor power from 100% to 90%:

Power Defect = Integrated Rod Worth

(IRW) = _____ pcm

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 8 of 11

STEP: 13

CUES:

CR SEQ STEP STANDARD:

No Yes (Fig. II-10) ___________ final rod height Enters 178 to 185 final rod height Bank

Bank D D. (see key for derivation)

COMMENTS: SAT

UNSAT

STEP: 14

CUES:

CR SEQ STEP STANDARD:

Yes Yes For a 100% to 90% load reduction: Enters 100 - 104 for gallons boric acid

Use ______ gallons boric acid (1/2 the and 193 - 200 for steps on bank D.

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).

COMMENTS: SAT

UNSAT

STEP: 15

CUES:

CR SEQ STEP STANDARD:

No Yes Copies data from page 1 to page 2. Right values are transposed from page 1

and placed on page 2.

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 9 of 11

STEP: 16

CUES:

CR SEQ STEP STANDARD:

Yes No FCV 113 A&B, pot setting for current RCS Enters 4.50.

boron concentration.

COMMENTS: SAT

UNSAT

STEP: 17

CUES:

CR SEQ STEP STANDARD:

No Yes Expected Boric Acid flowrate for VCT Enters 18.

makeup _____

COMMENTS: SAT

UNSAT

STEP: 18

CUES:

CR SEQ STEP STANDARD:

No Yes Expected Boric Acid total gallons on an Auto Enters 40-41.

Makeup based on current BAT in service:

_______

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Wednesday, September 07, 2011 Page 10 of 11

JPM SETUP SHEET

JPM NO: JPA-006B

DESCRIPTION: 2011 NRC Admin A1-b RO: CALCULATE REACTIVITY CONTROL

PARAMETERS (Base on new core at MOL)

IC SET:

INSTRUCTIONS:

COMMENTS:

Wednesday, September 07, 2011 Page 11 of 11

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-009

2011 NRC Admin A1-b SRO: DETERMINE SHIFT

MANNING REQUIREMENTS

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 5

CANDIDATE:

EXAMINER:

SRO ONLY

THIS JPM IS APPROVED

Wednesday, September 07, 2011 Page 1 of 7

TASK:

341-050-01-03 SS RELIEF CHECKLIST REVIEW (SAP-200)

TASK STANDARD:

Determines personnel to hold over that will meet the full crew complement and completes FEP

MANNING SHEET.

TERMINATING CUE: Completes FEP MANNING SHEET.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES: SAP-152 FATIGUE MANAGEMENT AND WORK HOUR LIMI

OAP-100.2 OPERATIONS PERSONNEL EXPECTATIONS AND

RESPONSIBILITIES

SAP-200 CONDUCT OF OPERATIONS

INDEX NO. K/A NO. RO SRO

1940012103 2.1.3 Knowledge of shift or short-term relief 3.7 3.9

turnover practices.

TOOLS: OAP-100.2, Operating Personnel Expectations and Responsibilities

SAP-152, Fatigue Management and Work Hour Limits

SAP-200, Conduct of Operations

EVALUATION TIME 15 TIME CRITICAL NO 10CFR55: 41b10

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Wednesday, September 07, 2011 Page 2 of 7

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to assist with a long term manning plan.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Wednesday, September 07, 2011 Page 3 of 7

This page left blank

Wednesday, September 07, 2011 Page 4 of 7

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to assist with a long term manning plan.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Wednesday, September 07, 2011

STEPS

STEP: 1

CUES:

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 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months .

CR SEQ STEP STANDARD:

Yes Yes Review the shift manning to determine Determine that an ABUL, ABLL, and

actions for normal full complement and CBAO is needed. For the first 4 hrs, the

completes FEP MANNING SHEET. 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 may

be held over to be ABUL.

See key for how FEP MANNING SHEET

must be completed.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Wednesday, September 07, 2011 Page 6 of 7

JPM SETUP SHEET

JPM NO: JPA-009

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

IC SET:

INSTRUCTIONS:

COMMENTS:

Wednesday, September 07, 2011 Page 7 of 7

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-025

2011 NRC A2 RO: TAGOUT "B" MDEFP

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 3

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Wednesday, September 07, 2011 Page 1 of 8

TASK:

119-012-03-01 CONDUCT EQUIPMENT TAGOUTS (EQUIPMENT CLEARANCE AND

SWITCHING)

TASK 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 VLV

2. XVT11007, MOTOR DRIVEN EF PUMP B VENT VALVE

TERMINATING CUE:

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES: SAP-201 DANGER TAGGING

INDEX NO. K/A NO. RO SRO

1940012213 2.2.13 Knowledge of tagging and clearance 4.1 4.3

procedures.

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).

EVALUATION TIME 45 TIME CRITICAL NO 10CFR55: 45.13

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Wednesday, September 07, 2011 Page 2 of 8

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

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.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Wednesday, September 07, 2011 Page 3 of 8

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

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.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Wednesday, September 07, 2011

STEPS

STEP: 1

CUES:

Tag number is not critical, only the sequence is.

CR SEQ STEP STANDARD:

No No TAG - Enter the sequential tag number. See completed Attachment VIC.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No No ISSUED TO - Check blocks for which See completed Attachment VIC.

discipline each component is tagged.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

CR SEQ STEP STANDARD:

No No HOLD TAG INST - Enter a check mark if a See completed Attachment VIC.

Hold Tag is to be placed on a control panel

component.

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 5 of 8

STEP: 4

CUES:

CR SEQ STEP STANDARD:

Yes No COMPONENT I.D. - Enter the complete See completed Attachment VIC.

CHAMPS identification number of the

component being tagged.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

No Yes PLANT LOC - Enter the specific plant See completed Attachment VIC.

location of the component being tagged.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

CR SEQ STEP STANDARD:

Yes Yes REQ'D TAG POSIT - Enter the position in See completed Attachment VIC.

which the component is to be tagged.

COMMENTS: SAT

UNSAT

Wednesday, September 07, 2011 Page 6 of 8

STEP: 7

CUES:

CR SEQ STEP STANDARD:

Yes Yes INST SEQ - Enter sequence that tags are to See completed Attachment VIC.

be installed. 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.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Wednesday, September 07, 2011 Page 7 of 8

JPM SETUP SHEET

JPM NO: JPA-025

DESCRIPTION: 2011 NRC A2 RO: TAGOUT "B" MDEFP

IC SET:

INSTRUCTIONS:

COMMENTS:

Wednesday, September 07, 2011 Page 8 of 8

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-025A

2011 NRC Admin A2 SRO: REVIEW TAGOUT FOR

"B" MDEFP

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 5

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Thursday, September 08, 2011 Page 1 of 10

TASK:

342-005-03-02 AUTHORIZE HANGING OF TAGS ON PLANT EQUIPMENT

TASK 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.

TERMINATING CUE:

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: SAP-201 DANGER TAGGING

INDEX NO. K/A NO. RO SRO

1940012213 2.2.13 Knowledge of tagging and clearance 4.1 4.3

procedures.

TOOLS: 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 - IV

EVALUATION TIME 30 TIME CRITICAL NO 10CFR55: 45.13

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Thursday, September 08, 2011 Page 2 of 10

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

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.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Thursday, September 08, 2011 Page 3 of 10

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

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.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Thursday, September 08, 2011

STEPS

STEP: 1

CUES:

If required during this JPM, remind examinee to limit review to the preparation section of OAP-

102.1, Attachment VI.

CR SEQ STEP STANDARD:

No Yes Checks correct train work week. Notes that B1 train work week is

indicated.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

Yes Yes Scope of all work requiring tags within the Must note the following errors in the

tagout boundary. specified isolation during this review:

- XVT01028B missing from boundary

- XVG1001A incorrectly specified,

should be XVG1001B

May note the following errors in the

specified isolation during this review

(NOT critical):

- XVT11006 vent valve position specified

as CLOSED incorrectly

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 5 of 10

STEP: 3

CUES:

CR SEQ STEP STANDARD:

Yes Yes All power sources are tagged as required Must note the following error:

per job scope

- XMC1DB2X 03 AD (isolation of power

to XVG1001B MOV) is missing.

COMMENTS: SAT

UNSAT

STEP: 4

CUES:

CR SEQ STEP STANDARD:

No Yes Install sequence logical Notes that install sequence meets

requirements.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

No Yes Are hold tags needed and identified for Notes pump breaker indicates HOLD tag

switches, MCB gages, or status lights? required.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

CR SEQ STEP STANDARD:

No Yes Restoration position in a Clear Tag Not required

Enclosure has been verified per SOP.

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 6 of 10

STEP: 7

CUES:

If required, remind examinee that this is not required for this review.

CR SEQ STEP STANDARD:

No Yes Component worked has a "NO TAG" Not required

assigned to it and sequence in the Clear

Tag Enclosure.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

Remind student that since the package has to be done manually the conflict check provided by the

computer system is not available.

CR SEQ STEP STANDARD:

No No Conflict check performed and warning flags N/A

are evaluated and understood?

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

CR SEQ STEP STANDARD:

No Yes Electrical Feeder list review and included, if Determines that electrical feeder list is

necessary. included in package.

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 7 of 10

STEP: 10

CUES:

CR SEQ STEP STANDARD:

No Yes System/ Electrical drawing utilized are Notes that drawing is correctly marked.

marked up with tagout boundaries and

tagout index#

COMMENTS: SAT

UNSAT

STEP: 11

CUES:

CR SEQ STEP STANDARD:

No Yes Vent and Drain information Sheet included if Notes Vent and Drain Information sheet

necessary? included.

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 8 of 10

STEP: 12

CUES:

CR SEQ STEP STANDARD:

Yes Yes All errors found Must 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 XVG1001B

May note the following errors in the

specified isolation during this

review:(NOT critical):

- XVT11006 vent valve position

CLOSED incorrectly

Determines that tagout cannot be

authorized as written.

COMMENTS: SAT

UNSAT

STEP: 13

CUES:

CR SEQ STEP STANDARD:

No Yes Work Document numbers on WPO? Determines that WPO is not required

with only one work request for the tagout

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Thursday, September 08, 2011 Page 9 of 10

JPM SETUP SHEET

JPM NO: JPA-025A

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

IC SET:

INSTRUCTIONS:

COMMENTS:

Thursday, September 08, 2011 Page 10 of 10

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-083A(R

1)

2011 NRC Admin A3 RO & SRO: APPLY FACILITY

ALARA PRINCIPLES TO A SPECIFIC TASK AND

DETERMINE OVERALL DOSE

APPROVAL: RJ APPROVAL DATE: 8/11/2011

REV NO: 2

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Wednesday, August 24, 2011 Page 1 of 7

TASK:

000-061-05-01 RESPOND TO AREA RADIATION MONITORING SYSTEM ALARMS

TASK STANDARD:

All critical tasks evaluated as SAT.

TERMINATING CUE: All options have been prioritized and provided to the Examiner.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES:

INDEX NO. K/A NO. RO SRO

1940012312 2.3.12 Knowledge of radiological safety 3.2 3.7

principles pertaining to licensed operator

duties, such as containment entry

requirements, fuel handling

responsibilities, access to locked high-

radiation areas, aligning filters, etc.

TOOLS: HPP-0153, HPP-0155

Calculator

EVALUATION TIME 15 TIME CRITICAL NO 10CFR55: 45.B.10

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Wednesday, August 24, 2011 Page 2 of 7

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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).

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.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Wednesday, August 24, 2011 Page 3 of 7

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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).

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.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Wednesday, August 24, 2011

STEPS

STEP: 1

CUES:

CR SEQ STEP STANDARD:

No Yes Calculate dose for each option. Reviews conditions.

May refer to facility/corporate

procedures for respirator factors and

DAC conversion.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

Acceptable range is 537 to 538 mR.

CR SEQ STEP STANDARD:

Yes Yes Calculate dose for each option. (1000 mr/hr) (1 hr/60 minutes) (30

- One person without respirator. minutes) + (30 DAC) (30 minutes) (1

hr/60 minutes) (2.5 mr/DAC-hr) = 537.5

mR.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

The candidate may not use the protection factor because the difference is negligable. Acceptable

range is 550 - 551 mR.

CR SEQ STEP STANDARD:

Yes Yes Calculate dose for each option. (1000 mr/hr) (1 hr/60 minutes) (30

- One person with a respirator. minutes) (1.1)+ (30 DAC) (30 minutes)

(1 hr/60 minutes) (2.5 mr/DAC-hr) (1.1) /

(1000 protection factor)= 550.04125 mR

COMMENTS: SAT

UNSAT

Wednesday, August 24, 2011 Page 5 of 7

STEP: 4

CUES:

CR SEQ STEP STANDARD:

Yes Yes Prioritize options IAW the lowest total dose. 1. One person without respirator.

2. One person with a repirator.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Wednesday, August 24, 2011 Page 6 of 7

JPM SETUP SHEET

JPM NO: JPA-083A(R 1)

DESCRIPTION: 2011 NRC Admin A3 RO & SRO: APPLY FACILITY ALARA PRINCIPLES TO A

SPECIFIC TASK AND DETERMINE OVERALL DOSE

IC SET: N/A

INSTRUCTIONS:

COMMENTS:

Wednesday, August 24, 2011 Page 7 of 7

V.C. SUMMER NUCLEAR STATION

JPM NO: JPA-020

2011 NRC Admin A4 SRO: CLASSIFY EMERGENCY

PLAN EVENT

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 7

CANDIDATE:

EXAMINER:

SRO ONLY

THIS JPM IS APPROVED

TIME CRITICAL JPM

Thursday, September 08, 2011 Page 1 of 11

TASK:

344-019-03-02 CLASSIFY EMERGENCY EVENTS REQUIRING EMERGENCY PLAN

IMPLEMENTATION

TASK 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.

TERMINATING CUE: Classification has been made and NUCLEAR POWER PLANT

EMERGENCY NOTIFICATION FORM (ENF) form has been completed.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

CLASSROOM PERFORM

REFERENCES: EPP-001 ACTIVATION AND IMPLEMENTATION OF THE EM

INDEX NO. K/A NO. RO SRO

1940012106 2.1.6 Ability to manage the control room crew 3.8 4.8

during plant transients.

TOOLS: EPP-001- Attachment I.

EPP-001 Full.

EPP-002 Full

Access to a computer for other potential references. Technical

Specifications, EPP-108 act.

EVALUATION TIME 30 TIME CRITICAL YES 10CFR55: 45(a)11

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Thursday, September 08, 2011 Page 2 of 11

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

Thursday, September 08, 2011 Page 3 of 11

RCS conditions are stable and net charging indicates 70 gpm.

Meteorological data is not available.

THIS IS A DRILL.

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.

THIS IS A TIME CRITICAL JPM!

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Thursday, September 08, 2011 Page 4 of 11

This page is left blank.

Thursday, September 08, 2011 Page 5 of 11

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

Thursday, 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

STEPS

STEP: 1

CUES:

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).

CR SEQ STEP STANDARD:

Yes Yes Evaluate plant conditions and classify event Classifies event, per EPP-001 as a SITE

per EPP-001. AREA 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.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No Yes Completes line 1 of NUCLEAR POWER Checks "Drill" and writes message

PLANT EMERGENCY NOTIFICATION number as "1".

FORM (ENF).

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 8 of 11

STEP: 3

CUES:

CR SEQ STEP STANDARD:

Yes Yes Completes line 2 of ENF. Checks "Initial".

COMMENTS: SAT

UNSAT

STEP: 4

CUES:

CR SEQ STEP STANDARD:

Yes Yes Completes line 4 of ENF. Checks "Site Area Emergency" writes in

"FS 1.1" and "Loss or potential loss of

any two barriers" or the equivalent.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

Yes Yes Completes line 5 of ENF. Checks "Is Occurring"

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

This step is not critical.

CR SEQ STEP STANDARD:

No Yes Completes line 7. Checks "Above normal operating limits"

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 9 of 11

STEP: 7

CUES:

This step is not critical.

CR SEQ STEP STANDARD:

No Yes Completes line 8. Checks "Stable"

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

Yes Yes Completes line 10 Checks "Declaration" and includes

declaration time.

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

CR SEQ STEP STANDARD:

Yes Yes Completes line 12. Writes % Power as 0 and indicates time

of trip (10 minutes prior to start of JPM).

COMMENTS: SAT

UNSAT

Thursday, September 08, 2011 Page 10 of 11

STEP: 10

CUES:

This step is not critical.

CR SEQ STEP STANDARD:

No Yes Completes line 13. Writes summary of occurrence at the

plant. To include failed fuel, a steam

generator tube leak, and an uncontrolled

release of steam from the steam

generator with a tube leak.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Thursday, September 08, 2011 Page 11 of 11

JPM SETUP SHEET

JPM NO: JPA-020

DESCRIPTION: 2011 NRC Admin A4 SRO: CLASSIFY EMERGENCY PLAN EVENT

IC SET:

INSTRUCTIONS:

COMMENTS:

Thursday, September 08, 2011 Page 12 of 11

Facility: VC SUMMER Scenario No.:1 Op Test No.: 2011 NRC

Examiners: Operators: CRS

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 Malf. No. Event Type* Event

No. Description

I-RO, N-BOP

1. NIS007G Power Range upper detector NI-44A fails high RO1, BOP1

TS- CRS

C- BOP,

2. FWM009A HP heater tube leak BOP2

3. N/A R-RO Reduce power to isolate HP FW heater string

EPS018A&B

and EPS- 115KV offsite power is lost, the A EDG rolls but trips: 1DA is

C - RO,BOP

4. 006A deenergized. RO Must start B train CCW pump and charging

TS-CRS pump. BOP will start restoration of 1DA. RO2

IND ES071 &

073=>0

5. N/A N-RO, CRS Restore letdown

6. PCS013B M-ALL Inadvertent FW Isolation Signal, Train B

C- BOP,

7. FWM003B B MDEFW pump fails to start

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

8. VLV-MS001F

CRS 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 1 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 Technical 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 2 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 3 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 4 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

Appendix D 5 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

Evaluators 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, POWER RANGE CHANNEL FAILURE

Enters AOP-401.10

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

IOA &

If Power Range Channel N-44 has failed, THEN place the ROD CNTRL

CRITICAL RO

BANK SEL Switch in MAN (Prior to rods going below the RIL)

TASK

IOA Crew Stabilize any plant transients in progress.

Crew Maintain stable plant conditions.

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

Appendix D 6 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Place ROD STOP BYPASS Switch (on the MISCELLANEOUS CONTROL

RO AND INDICATION PANEL) for the failed Power Range channel (N-44) in

BYPASS.

Verify the appropriate Rod Stop Bypass status light is bright:

For N-41, A1 OP ROD STOP BYP (XCP-6111 4-1).

RO 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).

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

Notify the I&C Department to record detector currents and status lights on

Crew

POWER RANGE A and POWER RANGE B drawers

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.

Appendix D 7 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Deenergize the failed Power Range channel: (N-44)

a. Remove the CONTROL POWER fuses from the POWER RANGE A

BOP drawer.

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

drawer.

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

BOP COMPARATOR AND RATE drawer).

2) UPPER SECTION Switch (on the DETECTOR CURRENT

COMPARATOR drawer).

3) LOWER SECTION Switch (on the DETECTOR CURRENT

COMPARATOR drawer).

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

Crew Check if Reactor power is LESS THAN 75% (NO)

Crew Initiate GTP-702, Attachment IV.F.

Evaluator Note:

GTP-702 Attachment IV.F requires that STP0108.001 be performed every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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)

Crew Initiate GTP-702, Attachment IV.D

Appendix D 8 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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

condition: (N/A)

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

From Table 3.3-1 Functional Units 2 & 3 require action 2# and Function

Unit 19 requires action 7

Appendix D 9 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . DONE

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable

channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the

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

Appendix D 10 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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.

Appendix D 11 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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).

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)

NOTE

This alarm has reflash capabilities.

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).

Appendix D 12 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

IOA BOP Verify Turbine Load is LESS THAN 950 MWe (NO)

IOA BOP Using any method available, reduce Turbine Load by 40 MWe to 50 MWe

BOP Verify Turbine Load is GREATER THAN 700 MWe (YES)

CREW Monitor DELTA T PWR on ZZMENU (Screens 1 and 2) on the IPCS

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

Verify the following are NOT ISOLATED:

HEATER #2A.

BOP HEATER #2B

MS DRN TANK A.

MS DRN TANK B. (YES)

Verify the following are NOT ISOLATED:

HEATER #1A.

BOP HEATER #1B

RH DRN TANK A.

RH DRN TANK B. (NO)

Appendix D 13 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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)

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.

Maintains Tavg within 1°F of Tref;

RO 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

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 Tref by

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

management plan.

AOP 204.1

Appendix D 14 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Maintain the following operating limits:

a. Axial Flux Difference within the target band. Check the RAOC or BASELOAD

display on the IPCS.

b. Control Rods above RIL:

RO 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

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.

Appendix D 15 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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.

Ensure a Train B Component Cooling Pump is running:

XPP-0001B, PUMP B. (STARTS)

XPP-0001C, PUMP C TRAIN B.

Ensure a Train B Charging Pump is running:

XPP-0043B, PUMP B. (STARTS)

XPP-0043C, PUMP C TRAIN B.

Appendix D 16 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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)

RO Verify Component Cooling Water Loop B is the Active Loop. (NO)

Close the following Charging and Letdown Valves:

a) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

RO 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).

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

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.

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

RO Starts XPP-001B, PUMP B

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

Appendix D 17 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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.

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

connects

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

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

Ensure the following valves have not automatically closed due to high flow:

1) MVG-9625, CC TO RB.

RO 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.

Locally verify greater than 1 gpm sample flow on RML0002B,

LIQUID RAD MON COMPONENT COOLING (IB-412).

Booth Operator Instructions:

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

Appendix D 18 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Check if a Train B Service Water Pump is running:

XPP-0039B, PUMP B. (YES)

XPP-0039C, PUMP C TRAIN B.

AOP-304.1

Ensure HVAC Chilled Water Loop B is operating:

XPP-48B, PUMP B, AND XHX-1B, CHILLER 1B, are running. (STARTS)

Crew OR

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

running.

Crew Check if RHR cooling is required. (NO)

CRS GO TO Step 8

RO Ensures Instrument Air Compressor B is running (YES)

WHEN Component Cooling Water is available for non-essential loads, THEN verify

Letdown flow on FI-150, LO PRESS LTDN FLOW GPM (NO)

RO Set PCV-145, LO PRESS LTDN, to 70%.

Start Event 5, AOP

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

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

RO Open PVT-8152, LTDN LINE ISOL.

Appendix D 19 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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

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).

Adjust FCV-122, CHG FLOW, to maintain TI-140, REGEN HX OUT TEMP °F,

between 250"F and 350 °F while maintaining PZR level.

Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN PRESS

PSIG, between 300 psig and 400 psig.

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

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

RO Ensure Letdown temperature is stable.

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

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

Appendix D 20 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

End Event 5, AOP

Ensure Spent Fuel Cooling Loop B is in service. (YES) REFER TO SOP-123, SPENT

Crew

FUEL COOLING SYSTEM.

Booth Operator Instructions:

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

Place the following Control Switches in PULL TO LK NON-A:

Charging Pump A.

Crew

Charging Pump C (Train A).

Emergency Feedwater Pump A.

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

PROCEDURE, for annunciator(s) in alarm.

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.

Dispatch operators to the following areas to locally investigate for problems:

XTF0004 and XTF0005, ESF Transformers.

XTF0031, Emergency Aux Transformer #1.

Crew XSW1DA.

XCX5201, Diesel Generator A Local Control Panel.

GENERATOR & XFMR ELECTRICAL RELAY BOARD (CB-463), XCP6221A-

EG and XCP6225-EG.

Appendix D 21 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 .

Crew Consult with the System Controller to determine possible causes.

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).

Booth Operator Instructions:

When called to record relay flags report that there are no relay flags to reset.

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

Crew

Supervisor.

Verify an offsite power source is available to the ESF Bus:

BUS 1DA NORM FEED, potential lights are energized (NO)

BUS 1DA ALT FEED, potential lights are energized.(YES)

Appendix D 22 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Verify all of the following conditions exist:

The cause of the power loss has been determined. (YES, Storm damage in

the Parr switch yard)

Crew 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)

NOTE - Step 16

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

Record the AS FOUND Main Control Board Train A switch positions, then align the

switches to After-Stop. REFER TO Attachment 1A.

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

Crew

436).

Enters Technical Specification 3.0.3 due to one offsite source and both EDGs

CRS 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

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

Crew

maintenance assistance.

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

the next event

Appendix D 23 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 24 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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

Direct entry into EOP-1.0, REACTOR TRIP SAFETY INJECTION

ACTUATION

Enters EOP-1.0

Verify Reactor Trip:

Trip the Reactor using either Reactor Trip Switch.

IOA RO Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.(YES)

Booth Operator Instructions:

When called to transfer DRPI to 1FB, do so by using Trigger 9

Verify Turbine/Generator Trip:

a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

IOA BOP

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.(YES)

IOA BOP Verify both ESF buses are energized. (NO)

Appendix D 24 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 25 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Perform the following:

a) Verify at least one ESF bus is energized:

7.2 KV BUS 1DA is energized. (NO)

7.2 KV BUS 1DB is energized. (YES)

IOA BOP

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)

Check if SI is actuated:

a. Check if either:

SI ACT status light is bright on XCP-6107 1-1.

IOA RO

Or

Any red first out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch (NO)

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

IOA Crew

Steamline pressure LESS THAN 675 psig. OR

Steamline differential pressure GREATER THAN 97

psig.

b. Actuate SI using either SI ACTUATION Switch. (NO)

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

Appendix D 25 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 26 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Crew Determines that a Red Path Exists on Heat Sink

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.

NOTE

Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001,

ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

Check if a secondary heat sink is required:

a. Verify RCS pressure is GREATER THAN any NON-FAULTED SG

Crew

pressure.

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

Appendix D 26 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 27 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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)

Evaluator note; 8000B is deenergized in the open position.

Locally close XMC1DA2X 06IM, PRESSURIZER PRESSURE RELIEF ISO

VALVE XVG8000B-RC breaker on MCC (IB-463).

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).

Open the Block Valve for any PZR PORV that has been isolated due to

excessive seat leakage:

RO MVG-8000A, RELIEF 445 A ISOL. (NO)

MVG-8000B, RELIEF 444 B ISOL. (NO)

MVG-8000C, RELIEF 445 B ISOL. (NO)

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.

Appendix D 27 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 28 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Ensure the following valves are

closed: '

SG Blowdown, PVG-503A(B)(C).

SG Sample, SVX-9398A(B)(C).

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.

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

Crew

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)

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)

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

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

Appendix D 28 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 29 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

IF XSW1DA normal power source is NOT available, THEN energize

XSW1DA from the alternate power

BOP 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.

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.

Ensure all EFW valves are open;

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

Crew 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)

Crew Try to restore any EFW flow.

Evaluator Note:

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

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.

Appendix D 29 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 30 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Ensure one Condensate Pump is running (this permits leaving more

Crew

than one running- need is for at least one to be running.)

Crew Ensure two Feedwater Booster Pumps are running.

Ensure Main FW Control Valves are closed:

FCV-478, A FCV.

Crew

FCV-488, B FCV.

FCV-498, C FCV.

Place all Main FW Bypass Valve Controllers in MAN and closed:

FCV-3321,LOOP A MAIN FW BYP.

Crew

FCV-3331,LOOP B MAIN FW BYP.

FCV-3341,LOOP C MAIN FW BYP.

Locally place the following key switches in BYPASS (CB-448):

XVG01611A,B,C (XPN 7114).

Crew

IFV03321,3331,3341 TRAIN A (XPN 7115).

IFV03321,3331,3341 TRAIN B (XPN 7121).

Booth Operator Instructions:

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

Trigger 7.

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

Appendix D 30 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 31 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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.

Align the MS Isolation Valves to depressurize only one SG:

1) Verify the MS Isolation Valve, PVM-2801A(B)(C), is open for the

Crew SG to be depressurized.

2) Ensure the remaining two MS Isolation Valves, PVM-2801A(B)(C),

are closed.

Place the following switches in AUTO:

PVG-1611A(B)(C), A(B)(C) ISOL.

Crew

FCV-3321,3331,3341, FW CNTRL BYP VLVS, Train A Switch.

FCV-3321,3331,3341, MAIN FW BYPASS VLVS, Train B Switch.

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

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.)

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

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

Appendix D 31 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 32 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Evaluator note; FW pumps cannot be reset because the FW isolation signal is still present.

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

Crew

(cannot).

Throttle open FCV-3321(3331)(3341), LOOP A(B)(C) MAIN FW BYP, to

Crew

the unisolated SG.

NOTE - Step 11

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

increase SG level.

Evaluator Note:

After restoring a supply of water to the SGs 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.

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.

RO Ensure all RCPs are tripped.

Appendix D 32 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 33 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Crew Actuate SI using either SI ACTUATION Switch.

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.

Verify an RCS feed path:

a. Ensure at least one Charging Pump is running. (B)

b. Ensure all the following are open:

RO 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.

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

Reset Containment Isolation:

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

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

Place both ESF LOADING SEQ A(B) RESETS to:

BOP a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

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.

Appendix D 33 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 34 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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.

Establish an RCS bleed path:

CRITICAL a. Open all PZR PORV Block Valves, MVG-8000A(B)(C). .

b. Open all PZR PORVs:

TASK RO

PCV-445A, PWR RELIEF

(backup) PCV-445B, PWR RELIEF

PCV-444B, PWR RELIEF

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.

Perform Steps 1 through 8 of EOP-1.0, REACTOR TRIP/SAFETY

INJECTION ACTUATION, while continuing with this procedure.

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.

Maintain RCS heat removal:

Crew Maintain SI flow.

Maintain at least two PZR PORVs open.

Appendix D 34 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 35 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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.

Check if RB Spray should be stopped:

a. Check if any RB Spray Pumps are running.

Crew

b. Verify RB pressure is LESS THAN 11 psig.

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

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.

Crew Consult with TSC personnel concerning RB Spray System operation.

Booth Operator Instructions:

When called as TSC recommend that RB spray be left running.

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.

Appendix D 35 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 36 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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.

Continue to try to establish a secondary heat sink in at least one SG

REFER TO Step 5 for EFW flow.

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

Consult with TSC personnel to try to establish any available low

pressure water source

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.

Evaluator Note:

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

flow using Steps 8-11 follow that.

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.

Appendix D 36 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 37 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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).

Crew 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)

Booth Operator Instructions:

When called to investigate the EFW pumps. Report 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)

CRS Refer to AOP-304.1 to restore power to IDA (unsuccessful).

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

IF XSW1DA normal power source is NOT available, THEN energize

XSW1DA from the alternate power

BOP 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.

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.

Appendix D 37 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 38 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

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).

Crew 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)

Crew Try to restore any EFW flow.

Evaluator Note:

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

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.

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

Crew Ensure two Feedwater Booster Pumps are running.

Ensure Main FW Control Valves are closed:

FCV-478, A FCV.

Crew

FCV-488, B FCV.

FCV-498, C FCV.

Appendix D 38 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 39 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Place all Main FW Bypass Valve Controllers in MAN and closed:

FCV-3321,LOOP A MAIN FW BYP.

Crew

FCV-3331,LOOP B MAIN FW BYP.

FCV-3341,LOOP C MAIN FW BYP.

Locally place the following key switches in BYPASS (CB-448):

XVG01611A,B,C (XPN 7114).

Crew

IFV03321,3331,3341 TRAIN A (XPN 7115).

IFV03321,3331,3341 TRAIN B (XPN 7121).

Booth Operator Instructions:

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

Trigger 7.

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

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.

Align the MS Isolation Valves to depressurize only one SG:

3) Verify the MS Isolation Valve, PVM-2801A(B)(C), is open for the

Crew SG to be depressurized.

4) Ensure the remaining two MS Isolation Valves, PVM-2801A(B)(C),

are closed.

Appendix D 39 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 40 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Place the following switches in AUTO:

PVG-1611A(B)(C), A(B)(C) ISOL.

Crew

FCV-3321,3331,3341, FW CNTRL BYP VLVS, Train A Switch.

FCV-3321,3331,3341, MAIN FW BYPASS VLVS, Train B Switch.

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

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.)

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

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

CRITICAL

Crew Adjust feed flow to restore SG level.

TASK

NOTE - Step 11

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

increase SG level.

Appendix D 40 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 41 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Evaluator Note:

After restoring a supply of water to the SGs 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

Crew Verify RCS temperatures are decreasing.

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.

Crew

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.

Booth Operator Instructions:

When asked to sample the secondary sides of the SGs as Chemistry wait 30 minutes and

then report that all activities are normal.

NOTE - Step 31

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

Verify Narrow Range level is GREATER THAN 26% [41%] in the SG being

Crew

used as a heat sink

Check RCS temperatures:

Crew Verify core exit TC temperatures are decreasing

Verify RCS Thot is decreasing

Appendix D 41 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 42 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Ensure any Reactor Vessel Head Vent Valves opened in Step 24 are

Crew

closed.

Check if SI can be terminated:

a. Verify RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER

Crew THAN 52.5°F [67.5°F].

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

c. GO TO STEP 36

NOTE - Step 35

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

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.

Crew

c. Wait for RCS subcooling to increase to GREATER THAN 80°F or to

stabilize.

d. RETURN TO Step 34.

Evaluator Note:

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

created in the proceeding steps.

Crew Stop all but one Charging Pump.

Crew If an PZR PORVs are open, ensure that only one is left open.

Appendix D 42 NUREG 1021 Revision 9

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

Op Test No.: 2011 NRC Scenario # 1 Event # Events Page 43 of 43

6,7,8

Event Description: Loss of Main Feedwater, no Emergency Feedwater available

Time Position Applicants Actions or Behavior

Establish Normal Charging:

a. Close FCV-122, CHG FLOW.

b. Open both MVG-8107 and MVG-8108, CHG LINE ISOL.

Crew 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.

After restoring a supply of water to the SGs 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.

Appendix D 43 NUREG 1021 Revision 9

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

Facility: VC SUMMER Scenario Op Test 2011 NRC

No.:2 No.:

Examiners: Operators: CRS

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 Malf. No. Event Type* Event Description

No.

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

ANN- Main Transformer high side OCB gas pressure 75 psig, crew should

4. C-CRS, BOP

TS001 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

AUX

6. C-RO, CRS Loss of Instrument Air RO1

14A&B

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

7. CVC004A

TS- CRS 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

PMP-

11. C- RO, CRS B SWBP fails to autostart

SW006F

Terminate set after SI flow terminated, RCS temperature controlled, and RB

cooling restored

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D 1 NUREG 1021 Revision 9

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

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 SF6 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 REACTOR 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.

Appendix D 2 NUREG 1021 Revision 9

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

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

Appendix D 3 NUREG 1021 Revision 9

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

EVENT 4: SF6 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 615 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)

Appendix D 4 NUREG 1021 Revision 9

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

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

Appendix D 5 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

Verifies sufficient volume exists in the Recycle Holdup Tanks to receive

Reactor Coolant displaced during planned dilution operation.

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 %.

RO Verify at least one Reactor Coolant Pump is running.

RO Place RX COOL SYS MU switch to STOP.

RO Place RX COOL SYS MU MODE SELECT switch to ALT DIL. (Peer )

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

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

(Peer )

Appendix D 6 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Place RX COOL SYS MU switch to START.

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

Verify alternate dilution stops when preset volume is reached on FIS-168,

TOTAL MU FLOW, batch integrator.

RO Place RX COOL SYS MU switch to STOP.

RO Place RX COOL SYS MU MODE SELECT switch to AUTO. (Peer )

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

RO Place RX COOL SYS MU switch to START.

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

Appendix D 7 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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

Select OK.

1) Verify the following:

a) MSVs 1, 3, and 4 indicate 0%.

BOP 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%.

BOP Close MVG-2897, COMB CNTRL VLV BSD

e. Slowly open MSV2 on the Control/Pre-warming screen, while

BOP maintaining differential temperature between CV Chest Inner and CV

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

Booth operator instructions; if contacted as Shift Supervisor, direct positioning MSV2

0.3% open at a 0.1% per minute ramp

Appendix D 8 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

BOP g) enter 0.3%.

h) Select OK

i) confirm setpoint

j) Select OK

k) Verify proper system operation

.

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

Appendix D 9 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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).

AUTOMATIC ACTIONS:

1. None.

CORRECTIVE ACTIONS:

Refer to AOP-401.8, Intermediate Range Channel Failure, and to AOP-

401.9, Source Range Channel Failure

NOTE

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

SUPPLEMENTAL ACTIONS:

Refer to Technical Specification Table 3.3-1 for instrumentation

requirements.

Appendix D 10 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

CRS Enters AOP-401.8, Intermediate Range Channel Failure

RO Stabilize reactor power at the current level

Bypass the failed Intermediate Range level channel

RO Place LEVEL TRIP switch for affected channel in BYPASS

Verify IR&SR TRIP BYP (XCP-620, 4-5) is LIT

RO Check if reactor power is less than 7.5X10-6% (NO)

RO Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , verify P-6 is BRIGHT

RO Maintain reactor power less than 5%

RO Monitor the operable Intermediate Range channel

RO Ensure NR-45 is selected to the operable channels (NO)

Refer to Technical Specifications

TS 3.3.1 action 3 for Functional Unit 5

Tech Specs

CRS Enters AOP-401.9, SOURCE RANGE CHANNEL FAILURE

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

Appendix D 11 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

IOA CRS/RO Stop all positive reactivity additions.

RO Verify NI-31 OR NI-32 is operable (N32 is).

Check if the Reactor Building evacuation alarm has actuated: (NO)

GO TO Step 6.

Bypass the failed Source Range channel:

RO a. Place LEVEL TRIP Switch for the AFFECTED channel in BYPASS.

b. Verify IR&SR TRIP BYP (XCP-620 4-5), annunciator is lit.

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),

RO Monitor an operable NI channel (N32).

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

Appendix D 12 NUREG 1021 Revision 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 Applicants Actions or Behavior

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

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

Crew

assistance.

On Lead Examiners cue, proceed to the next event.

Appendix D 13 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

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

PROBABLE CAUSE:

1. Spring charge pump failure.

2. SF6 gas leak.

3. Blown rupture disc.

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 SF6 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 SF6

Lockout Relay to re-enable breaker closure.

AUTOMATIC ACTIONS:

1. None.

CORRECTIVE ACTIONS:

1. Dispatch an operator to verify the following:

a. SF6 gas density is greater than 90%.

Crew b. Spring charge indicator is in the ENERGY STORAGE position.

c. SF6 gas pressure compared to SF6 gas temperature is normal per characteristic

chart.

Appendix D 14 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

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.

SUPPLEMENTAL ACTIONS:

BOP Notify the System Controller of problem.

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.

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.

Verifies that XTF0031 and XTF0032, EMERGENCY AUXILIARY TRANSFORMER #1

and #2, are in service per SOP-302.

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

Verifies that XTF0001, MAIN TRANSFORMER, and XTF0002, UNIT AUXILIARY

TRANSFORMER, are in service per SOP-302.

Appendix D 15 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

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.

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

BOP Close BUS 1A ALT FEED breaker. (PEER )

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

BOP Verify BUS 1A potential lights remain lit.

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

BOP Place BUS 1B AUTO-MAN XFER Switch in MAN.

BOP Close BUS 1B ALT FEED breaker. (PEER )

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

BOP Verify BUS 1B potential lights remain lit.

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

Appendix D 16 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

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.

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

BOP Close BUS 1C ALT FEED breaker. (PEER )

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

BOP Verify BUS 1C potential lights remain lit.

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

BOP Open OCB 8902

Booth operator instructions; if contacted again as Unit 5, report SF6 pressure as 74 psig and still

dropping slowly (do not report less than 72 psig since that would prevent breaker operation).

Determine bus voltage limits from Enclosure B (next page)

Lower Limit = 219.0 KV Upper Limit = 239.6 KV

Appendix D 17 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

Notify the System Controller of the applicable bus voltage limits from

Enclosure B.

Booth Operator Instructions:

When called as System Controller acknowledge bus voltage limits.

Appendix D 18 NUREG 1021 Revision 9

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 SF6 pressure

Time Position Applicants Actions or Behavior

If required, adjust the 115KV and/or 230KV alarm setpoints per Attachment VA and/or

Attachment VB for the current lineup.

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 Examiners cue, proceed to the next event

Appendix D 19 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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

approx. 564°F).

Identifies zero output (demand) from steam dump controller. Controller

BOP/CRS

does not respond in AUTO.

BOP Opens steam dumps in MANUAL

BOP Verifies SG PORVs close if open

Conducts post-event brief and notifies SS. May request I&C assistance

Crew

due to failed instrument (must prioritize NIS work vs. steam dump control.)

On Lead Examiners cue that temperature is stable, proceed to the next event

Appendix D 20 NUREG 1021 Revision 9

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 doesnt start

Time Position Applicants Actions or Behavior

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.

NOTE

This alarm has reflash capabilities.

CORRECTIVE ACTIONS:

If Instrument Air Compressor A trips, ensure the standby air compressor

starts. (WONT)

Dispatch an operator to Instrument Air Compressor A to determine the

cause of the alarm.

Appendix D 21 NUREG 1021 Revision 9

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 doesnt start

Time Position Applicants Actions or Behavior

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.

RO Ensure the standby Instrument Air Compressor is running. (NO)

RO Check if Instrument Air header pressure is increasing. (NO)

RO Start XAC-12-IA, SUPP INST AIR COMPRESSOR. (YES)

May locally start the Diesel Driven Air Compressor. (conservative until

RO Supplemental verified running sat and to supply Service Air.) REFER TO

SOP-220,STATION AND BACKUP INSTRUMENT AIR SYSTEMS.

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)

Appendix D 22 NUREG 1021 Revision 9

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 doesnt start

Time Position Applicants Actions or Behavior

Performs post-event brief and contacts SS. May contact mechanical

Crew

maintenance for compressor troubleshooting.

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

Appendix D 23 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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.

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.

Booth Operator Instructions:

Use LOA Resets page to install fuses for PVT-8141A-FU-CS75

Appendix D 24 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Ensure seal injection flow is GREATER THAN 8 gpm for the affected

Reactor Coolant Pump on FI-130A, RCP A INJ FLO GPM.

Ensure Component Cooling Water flow to the affected Reactor Coolant

RO 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).

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

NOTE - Step 6 -

When PVT-8141A, A SEAL LKOFF, is closed, the #1 seal P indication will be unreliable.

Check if Reactor power is GREATER THAN 38% (Reactor Permissive

Crew

P-8, REACTOR TRIP BLOCKED, is dim). (NO)

RO Stop the affected Reactor Coolant Pump (A)

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

Appendix D 25 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

RO/CRS

Coolant Pump by locally unlocking and throttling one of the

following:

o XVN08369A-CS, RCP A SEAL SUPPLY THROTTLE

VALVE (AB-412 West Pen).

Booth Operator Instructions:

When called to throttle seal supply use trigger 11 LOA-CVC038, V 8369A - SEAL

INJECTION THROTTLE VALVE, to do so.

Within one hour, shut down the plant to hot standby. GO TO the

CRS appropriate GOP: GOP-5, REACTOR SHUTDOWN FROM STARTUP

TO HOT STANDBY (MODE 2 TO MODE 3).

Enters GOP-5 section 3

Complete GTP-702 Attachment II.K, Operational Mode Change Plant

CRS Shutdown - Entering Mode 3 Or Plant Trip To Mode 3 From Modes 1 Or

2.

Perform a Mode Change Brief per OAP-100.4 Attachment I. The SS and

System Controller would notified at some point during this transient.

RO Select both Intermediate Range Channels on NR-45, NIS RECORDER.

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.

Appendix D 26 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

CRS Perform a Pre-job brief per OAP-100.3, Human Performance Tools.

Select one Intermediate Range and one Source Range Channel on NR-

45, NIS RECORDER.

BOP Ensure both Motor Driven Emergency Feedwater Pumps are running.

(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.

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.

Verify greater than 30 gpm flow on FI-110, EMERG BORATE FLOW

GPM.

Appendix D 27 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Refer to STP-134.001, Shutdown Margin Verification, to determine the

RO required boron concentration needed for the anticipated Plant Mode and

temperature:

Booth operator instructions; if contacted as the Shift Engineer, report required CB is 1589

ppm.

Borate the outage Mixed Bed Demineralizer by placing in service per

SOP-102,Section IV. (N/A)

When boration is no longer desired, perform the following:

RO a) Close MVT-8104, EMERG BORATE.

b) Verify no flow on FI-110, EMERG BORATE FLOW GPM.

RO Place RX TRIP Switch CS-CR01 in TRIP.

RO Verify all Reactor Trip and Bypass Breakers are open.

RO Verify all Rod Bottom lights are lit.

Appendix D 28 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

RO Verify Reactor Power level is decreasing.

Ensure RCS temperature is being maintained between 555°F and 559°F

using the Steam Dump System or Steamline PORVs.

Place both SOURCE RANGE HIGH FLUX AT SHUTDOWN Switches in

BLOCK.

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.

CRS Proceed to Step 3.7.

Monitor Source Range counts per SOP-404, Excore Nuclear

Instrumentation System.

Appendix D 29 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

CAUTION 3.8

Shutdown Margin may decrease by as much as 3000 pcm due to Xenon decay over a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

period. Any deviation from the conditions used in the Shutdown Margin calculation requires

reverification of adequate Shutdown Margin.

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

Appendix D 30 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

Verify Reactor Trip:

Trip the Reactor using either Reactor Trip Switch.

IOA RO Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

Verify Turbine/Generator Trip:

a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

IOA BOP

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP Verify both ESF buses are energized.

Check if SI is actuated:

a. Check if either:

SI ACT status light is bright on XCP-6107 1-1.

IOA RO

Or

Any red first out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch

BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION.

Appendix D 31 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Evaluator Note:

The steps for Attachment 3, SI EQUIPMENT VERIFICATION can be found at the end of this

scenario guide. (after page 38)

Crew Announce plant conditions over the page system.

Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB

PSIG (P-951), red pen. (NO)

Verify both the following annunciators are lit:

RO XCP-612 3-2 (RB SPR ACT).

XCP-612 4-2 (PHASE B ISOL).

Verify Phase B Isolation by ensuring RB SPRAY/PHASE B ISOL monitor

lights are bright on XCP-6105.

Ensure the following are open:

CRITICAL MVG-3001A(B), RWST TO SPRAY PUMP A(B) SUCT.

MVG-3002A(B), NAOH TO SPRAY PUMP A(B) SUCT.

TASK MVG-3003A(B), SPRAY HDR ISOL LOOP A(B). (NO)

RO Ensure both RB Spray Pumps are running.

RO Stop all RCPs.

Appendix D 32 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Check RCS temperatures:

With no RCP running, RCS Tcold is stable at OR trending to 557°F. (NO)

RO Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

RO Continue to direct local throttling of EFW or if IA is restored throttle EFW.

Initiate ATTACHMENT 6, STEAM VALVE ISOLATION, while continuing

with this procedure.

RO Check if PZR PORVs are closed.

RO Check if PZR Spray Valves are closed.

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

RO Verify at least one PZR PORV Block Valve is open.

NOTE - Step 11

Seal Injection flow should be maintained to all RCPs.

RO Check if RCPs should be stopped: (RCPs already stopped)

Appendix D 33 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Verify no SG is FAULTED:

RO No SG pressure is decreasing in an uncontrolled manner.

No SG is completely depressurized. (NO)

CRS GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.

Exits EOP-1.0

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.

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.

NOTE - Step 1

A FAULTED SG is any SG that is depressurizing in an uncontrolled manner OR that is completely

depressurized.

RO Check RCS Tcold stable or increasing (NO)

BOP Ensure Steamline PORVs are closed.

Appendix D 34 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

BOP Ensure Condenser Steam Dump Valves are closed.(YES)

RO Stop any cooldown with the RHR System if it is in service. (NO)

Maintain total EFW flow GREATER THAN 450 gpm until Narrow Range

level is GREATER THAN 26% [41%] in at least one NON-FAULTED SG

BOP Reduce EFW flow to NON-FAULTED SG(s).

Ensure valves associated with each FAULTED SG are closed:

BOP MS Isolation, PVM-2801A(B)(C)

MS Isolation Bypass, PVM-2869A(B)(C)

BOP Close MVG-2802B, MS LOOP C TO TD EFP

Open XMC1DB2Y 05EH, EMERG FEEDWATER PUMP MAIN STEAM

BLOCK XVG2802B-MS (AB-463)

Booth Operator Instructions:

When called to open XMC1DB2Y 05EH use LOA/RESETS page to do so.

CRITICAL If any SG is NOT FAULTED, THEN isolate all feedwater to FAULTED

SG(s) unless necessary for RCS temperature control.

TASK

Appendix D 35 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Evaluator Note:

This is the first procedure step that directs isolation of EFW to the FAULTED SG (C).

However, OAP-103.4, EOP/AOP USERS GUIDE, allows the crew to isolate EFW prior to

direction in the EOPs.

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

RO Verify at least one PZR PORV Block Valve is open.

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.

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).

Both XCP-6106 1-12 and 2-12 (RCS TO RHR IN ISOL

8701B(8702B) OPEN

CRS GO TO Step 3.d.

RO Verify PZR pressure is LESS THAN 2330 psig (yes).

Appendix D 36 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Ensure all PZR PORVs are closed (yes)..

RO Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM

Check if SI can be terminated:

a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN

RO 105°F[120°F].

b. Check RVLIS level GREATER THAN the following: With 0 RCPs

running RVLIS level 61% NR

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

Reset Containment Isolation:

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

RESET PHASE B - TRAIN A(B) CNTMT ISOL

Place both ESF LOADING SEQ A(B) RESETS to:

BOP a. NON-ESF LCKOUTS

b. AUTO-START BLOCKS

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

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).

Appendix D 37 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Stop any RHR Pump operating in the SI mode.

RO Stop all but one Charging Pump.

Establish Normal Charging

a. Close FCV-122, CHG FLOW

RO 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.

Verify SI flow is NOT required:

a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN

RO/CRS 52.5°F[67.5°F].

b. Check RVLIS level GREATER THAN the following: With 0 RCPs

running RVLIS level 61% NR.

Crew Verify RCS Thot is stable by using EFW control and SG PORVs

Evaluator Note:

The scenario can be terminated when SI flow is reduced, RCS Thot is being maintained

stable, and RB pressure rise is mitigated.

Appendix D 38 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Facility: VC SUMMER Scenario No.:3 Op Test No.: 2011 NRC

Examiners: Operators: CRS

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 Malf. No. Event Type* Event

No. Description

N-BOP,CRS

1. Power escalation toward 38%

R-RO

SG pressure transmitter PT-2010 fails high, opening SG PORV

2. XMT-MS036O I- BOP,CRS

BOP1

Compensating B SG pressure transmitter PT-485 fails high,

3. MSS001E TS-CRS

increasing Main Feedwater flow BOP2

C- RO,

4. RCS007C C RCP vibrations ramp up, pump must be shutdown RO1

TS-CRS

5. PRS001B C-RO, TS-CRS PT-445 fails high, causing entry to DNB TS. RO2

CCW007A Running CCW pump trips. Standby pump on A train fails to

C-RO, BOP,

6. PMP-CC003F. start. Opposite Train pump starts but bearing fails, causing

PMP-CC002B 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)

Pressurizer Safety valve fails open, requiring manual SI

9. PRS007A M-ALL

alignment

Terminate after EOP-2.1 (Post LOCA Cooldown and

Depressurization) entry

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D 1 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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 valve 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.

Appendix D 2 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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).

Appendix D 3 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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

Appendix D 4 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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

Appendix D 5 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

At 250 MWe perform the following:

1) Ensure all Extraction Drain Valves are latched.

Crew

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.

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-

Crew

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

Appendix D 6 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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

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

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

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

Appendix D 7 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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

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

Appendix D 8 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

Appendix D 9 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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

Appendix D 10 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

PROBABLE CAUSE:

1. Steam line break.

2. Instrument failure.

3. Testing in progress.

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)

CORRECTIVE ACTIONS:

BOP Verify steam line pressure indications on the Main Control Board.

SUPPLEMENTAL ACTIONS:

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).

Appendix D 11 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Select the operable flow channel:

Place FW CONTROL CHANNEL SEL Switch to the operable

IOA BOP channel.

Place STEAM CONTROL CHANNEL SEL Switch to the operable

channel.

IOA BOP Verify Turbine Load is LESS THAN 950 MWe.(YES)

IOA BOP Verify only one SG is AFFECTED. (YES)

Adjust the Feedwater Flow Control Valve as necessary to restore feed flow

IOA BOP

to the AFFECTED SG

Check if Feedwater Pump speed control is operating properly:

Feedwater Header pressure is GREATER THAN Main Steam

IOA BOP Header pressure.

Feed flow is normal for steam flow and power level.

All operating Feedwater Pump speeds and flows are balanced.

BOP Verify Narrow Range levels in all SGs are between 60% and 65%.

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.

Appendix D 12 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , 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

Identify Technical Specifications:

Table 3.3-1 Item 14: Action 6 Trip bistables in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (may be bypassed

CRS for testing for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months )

Table 3.3-3 Items 1.e, 1.f, 4.e: Action 24 Trip bistables in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (may be

bypassed for testing for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months )

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

Appendix D 13 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Booth Instructor:

When directed, activate trigger 4.

Indications available:

XCP-619 1-3, RCP C VIBR HI

Crew Refer to alarm response procedure

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.

AUTOMATIC ACTIONS:

1. None.

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.

Appendix D 14 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

CORRECTIVE ACTIONS:

Monitor Reactor Coolant Pump C vibration indicators to determine the

source and severity of the vibration.

Monitor RCS temperature and pressure to verify they are within limits for

Reactor Coolant Pump operation.

SUPPLEMENTAL ACTIONS:

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)

Crew

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)

Appendix D 15 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Crew

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.

Crew Verifies reactor power is less than 38% (P-8 permissive is illuminated).

CRS Acknowledges that the plant is being placed in Hot Standby.

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)

RO If the RCS is solid, place PCV-145, LO PRESS LTDN, in MAN. (NA)

Appendix D 16 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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)

If the RCS is solid, return PCV-145, LO PRESS LTDN, to AUTO, if desired.

(NA)

Verify Seal Injection to the secured Reactor Coolant Pump using the

applicable following indicator:

RO a. FI-130A, RCP A INJ FLO GPM.

b. FI-127A, RCP B INJ FLO GPM.

c. FI-124A, RCP C INJ FLO GPM.

Maintain Component Cooling Water to the secured Reactor Coolant Pump

Crew

thermal barrier until RCS temperature is less than 150°F.

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.

BOP 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.

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.

Appendix D 17 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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).

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.

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.

Evaluator Note:

This guide does not include steps to lower power down to 38%.

NOTE 3.3

Step 3.3 lowers Reactor Power from 48% to 25%.

Appendix D 18 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Reduce load

As load decreases, adjust Megavars using GEN FIELD VOLT ADJ as

BOP requested by the Load Dispatcher and within the Estimated Generator

Capability curve (Enclosure A).

As load decreases, Borate or dilute per SOP-106, Reactor Makeup Water

System, to maintain Control Rods above the Rod Insertion Limit.

Between 30% and 35% Reactor Power, reduce to two Feedwater Booster

Pumps per SOP-210, Feedwater System.

As load decreases, maintain the Blowdown Heat Exchanger condensate

outlet temperatures at least 30 degrees below the DA temperature.

Appendix D 19 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Crew

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).

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.

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.

Crew

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.

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.

Appendix D 20 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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.

At the discretion of the Lead Examiner, proceed to the next event

Appendix D 21 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 PORVs cycling at 1970 psig

XCP-616, 2-6, PZR CNTRL PRESS HI

Crew Refer to alarm response procedures

Crew Refer to XCP-616, 2-6

PROBABLE CAUSE:

1. Instrument failure.

2. Rapid load reduction.

AUTOMATIC ACTIONS:

1. PCV-445A(445B), PWR RELIEF, open.

CORRECTIVE ACTIONS:

Compare PI-445, CNTL CHAN PRESS PSIG, with other Pressurizer

RO pressure indications to determine if IPT00445, PRESSURIZER

PRESSURE CONTROL PRESS XMTR, has failed high (YES).

Appendix D 22 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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.

IOA RO Verify the PZR PORVs are closed: (NO)

IF PZR pressure is LESS THAN 2300 psig, THEN perform the following:

Close the AFFECTED PZR PORV(s):

IOA RO PCV-445A, PWR RELIEF (YES)

PCV-445B, PWR RELIEF (YES)

PCV-444B, PWR RELIEF (NO)

NOTE - Step 2

PZR PRESS control channels PI-444 and PI-445 connect to the same reference leg line as

protection channel PI-457.

Compare the PZR control channel indication to the protection channel

indications: (ONLY 445 reading high)

IOA RO PI-455, PRESS PSIG

PI-456, PRESS PSIG

PI-457, PRESS PSIG

Appendix D 23 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Check if PI-444, CNTROL CHAN PRESS PSIG, indication is NORMAL.

IOA RO

(YES)

Check if PI-445, CNTRL CHAN PRESS PSIG, indication is NORMAL.

(NO)

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

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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and

HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Tech Specs

RO Ensure ROD CNTRL BANK SEL Switch is in AUTO.

RO Maintain RCS pressure between 2220 psig and 2250 psig.

While regaining pressure monitor Technical Specification:3.2.5: Indicated

Pressurizer Pressure 2206 psig

CRS Action: With any of the above parameters exceeding its limit, restore the

parameter to within its limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to

less than 5% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Tech Specs

Appendix D 24 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Appendix D 25 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

PROBABLE CAUSE:

1. Overcurrent trip in conjunction with an overload alarm.

AUTOMATIC ACTIONS:

Standby pump starts. (Starts but indication of a sheared shaft)

NOTE

This alarm has reflash capabilities.

CORRECTIVE ACTIONS:

RO Ensure the standby pump starts. (Starts but with sheared shaft)

Appendix D 26 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 27 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 Applicants Actions or Behavior

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.

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.

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.

If a Train B Component Cooling Pump was started, establish Train B as the

active loop per SOP-118. (B CCW overloads)

RO Verify system pressures, temperatures, and flows are normal. (NO)

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

Appendix D 27 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

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 Applicants Actions or Behavior

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.

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.

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

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.

Appendix D 28 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 29 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 Applicants Actions or Behavior

Determine the cause for the loss of CCW:

a. Check for annunciators on XCP-601, 602, and 603.

IOA RO

b. REFER TO the appropriate ARPs.

c. Attempt to correct the cause for loss of CCW.

Establish either train of CCW as the Active Loop. REFER TO *

IOA RO SOP-118, COMPONENT COOLING WATER. (CANNOT until C

swapped)

RO Verify CCW cooling is available to each running Charging Pump. (NO)

Initiate Attachment 1, Charging. Pump Temperature Monitoring, Page 4 of

4.

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.

Crew Check if at least one CCW loop is restored: (NO)

Appendix D 29 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 30 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 Applicants Actions or Behavior

Place any non-running Charging Pump which does NOT have CCW

cooling in PULL TO LK NON-A. (B and C)

Close all Letdown Isolation Valves:

1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

RO 2) LCV-459, LTDN LINE ISOL.

3) LCV-460, LTDN LINE ISOL.

4) HCV-142, LTDN FROM RHR.

Establish Charging Pump alternate cooling using Chilled Water per

Crew

Attachment 1.

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.

CRS GO TO Step 11.

Within 10 minutes Trip the reactor and Enter EOP-1.0, REACTOR

Crew

TRIP/SAFETY INJECTION ACTUATION

Evaluator Note:

The crew will continue with the steps of AOP-118.1 concurrently with the EOPs. The

remaining steps for AOP-118.1 can be found at the end of this guide (page 39)

Transitions to EOP-1.0

Appendix D 30 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 31 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 Applicants Actions or Behavior

Verify Reactor Trip:

Trip the Reactor using either Reactor Trip Switch.

IOA RO Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

Verify Turbine/Generator Trip:

a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

IOA BOP

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP Verify both ESF buses are energized

Check if SI is actuated:

a. Check if either:

a. SI ACT status light is bright on XCP-6107 1-1.

IOA RO

Or

b. Any red first out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch

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

IOA Crew

Steamline pressure LESS THAN 675 psig. OR

Steamline differential pressure GREATER THAN 97

psig.

b. Actuate SI using either SI ACTUATION Switch.

RO Trip the RCP(s)

Appendix D 31 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 32 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 Applicants Actions or Behavior

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

Transitions to EOP-1.1

Crew Announce plant conditions over the page system.

Check FW status:

Ensure the FW Flow Control Valves, FCV-478(488)(498), are

closed.

BOP 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.

Ensure EFW Pumps are running:

BOP 1) Ensure both MD EFW Pumps are running.

2) Verify the TD EFW Pump is running if necessary to maintain SG levels.

BOP Verify total EFW flow is GREATER THAN 450 gpm.

BOP Trip all Main FW pumps.

Appendix D 32 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 33 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 Applicants Actions or Behavior

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.

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).

Determines that IFV03551-EF will not close using the potentiometers

BOP (placing the MCB CLOSE/AUTO/MAN switch in CLOSE will close the

valve).

Booth Operator Instructions:

If called to locally throttle 3551 use malfunction VLV-EF005P=0 to close the valve.

BOP Ensure the TDEFW pump is running

CRITICAL 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).

TASK

Appendix D 33 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 34 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 Applicants Actions or Behavior

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.

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)

CRS GO TO Step 5.

RO Verify all Control Rods are fully inserted.

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

BOP 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).

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

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%.

Appendix D 34 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 35 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 Applicants Actions or Behavior

RO Verify PZR pressure is GREATER THAN 1850 psig.

Verify PZR pressure is stable at OR trending to 2235 psig (2220 psig to

2250 psig).

BOP Verify Narrow Range level in all SGs is GREATER THAN 26%.

Control EFW flow to maintain Narrow Range SG level between 40% and

60%.

Verify all AC buses are energized by offsite power:

BOP ESF AC buses

BOP AC buses.

BOP Verify PERMISV C-9 status light is bright on XCP-6114 1-3.

WHEN RCS Tavg is LESS THAN P-12 (552°F), THEN place both STM

DUMP INTERLOCK Switches to BYP INTLK.

BOP Verify the MS Isolation Valves, PVM-2801A(B)(C), are open.

BOP Place the STM DUMP CNTRL Controller in MAN and closed.

Appendix D 35 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 36 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 Applicants Actions or Behavior

BOP Ensure the STM DUMP CNTRL Controller is set to 8.4.

BOP Place the STM DUMP MODE SELECT Switch in STM PRESS.

BOP Place the STM DUMP CNTRL Controller in AUTO.

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.

RO Verify RCP A is running. (NO)

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.

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 COMPONENT COOLING WATER Attachment 4 could be

used to restore RCP operation.

Appendix D 36 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 37 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 Applicants Actions or Behavior

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.

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.

Shut down and stabilize the Secondary Plant. REFER TO AOP-214.1,

TURBINE TRIP.

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.

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).

COMPLETE Attachment I of SAP-116, PLANT TRIP/SAFETY INJECTION

PLANT RECOVERY.

Appendix D 37 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7, & 8 Page 38 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 Applicants Actions or Behavior

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.

Determine if natural circulation cooldown is required:

Crew a. All RCPs are stopped. (YES)

b. CST level is LESS THAN 14.5 ft. (NO)

Notify the SS and Management Duty Supervisor of plant conditions and

Crew

request direction.

Booth Operator Instructions:

When contacted as MDS ask for crews recommended course of action and concur with it.

Appendix D 38 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 39 of 52

Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicants Actions or Behavior

The following actions are from AOP-118.1 after the reactor trip they would be done in

conjunction with the EOP steps.

12. Isolate Charging and Letdown:

a. Close all Letdown Isolation Valves:

1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

RO 2) LCV-459, LTDN LINE ISOL.

3) LCV-460, LTDN LINE ISOL.

4) HCV-142, LTDN FROM RHR.

b. Close FCV-122, CHG FLOW.

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).

WHEN cooling is established to any Charging Pump, THEN REFER TO

ATTACHMENT 4, STARTING A CHARGING PUMP AND SUPPLYING

Crew

RCP SEAL COOLING, to start the Charging Pump and supply RCP Seal

cooling.

CAUTION

RCPs should NOT be restarted prior to an Engineering evaluation, to prevent RCP Seal failure.

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.

Appendix D 39 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 40 of 52

Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicants Actions or Behavior

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.

Crew Check if the RHR System is operating. (NO)

CRS GO TO Step 19.

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.

Crew 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.

Crew Check if at least one CCW loop is restored: (YES)

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.

Appendix D 40 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 41 of 52

Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicants Actions or Behavior

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.

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

Start one of the following in slow speed: (PEER )

1) XPP-0001B, PUMP B. Prior to establishing Letdown.

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.

Start MVB-9503A, CC TO RHR HX A, stroking in the closed

direction.(PEER )

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.

RO 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.

Appendix D 41 NUREG 1021 Revision 9

2011 NRC Scenario 3 after workup Scenario Outline Form ES-D-1

Op Test No.: 2011 NRC Scenario # 3 Event # 6,7,8 Page 42 of 52

Event Description: Loss of all CCW forces Rx trip, Emergency FW FCV fails open

Time Position Applicants Actions or Behavior

Locally verify greater than 1 gpm sample flow on RML0002B, LIQUID RAD

Crew

MON COMPONENT COOLING (IB-412).

Booth Operator Instructions:

When called to verify flow on RM-L2 report that it is >5gpm.

Ensure the following valves have not automatically closed due to high flow:

1) MVG-9625, CC TO RB.

RO 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.

RO Transfer the in-service Charging Pump to Train B per SOP-102.

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

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.

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.

Place PCV-145, LO PRESS LTDN, in MAN and open to 70%. (PEER )

Appendix D 42 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Place TCV-144, CC TO LTDN HX, in MAN and open to 100%.

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

Open PVT-8152, LTDN LINE ISOL.

Open the following:

a. LCV-459, LTDN LINE ISOL.

b. LCV-460, LTDN LINE ISOL.

Ensure the following Charging Line Isolation Valves are open:

a. MVG-8107, CHG LINE ISOL.

b. MVG-8108, CHG LINE ISOL.

Slowly open FCV-122, CHG FLOW, to establish 60 gpm flow as indicated

on FI-122A, CHG FLOW GPM.

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).

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.

Appendix D 43 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN

PRESS PSIG, between 300 psig and 400 psig.

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

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.

When Pressurizer level is within 1% of and trending to programmed level,

place the PZR LEVEL MASTER CONTROL in MAN.

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 )

Adjust PZR LEVEL MASTER CONTROL in MAN, as necessary, to

maintain Pressurizer level at or near programmed level.

When Pressurizer level is within 1% of and trending to programmed level,

place PZR LEVEL MASTER CONTROL in AUTO. (PEER )

Monitor LR-459, PZR % LEVEL & LEVEL SP, recorder to verify that

Charging flow is maintaining actual Pressurizer level at or near the

programmed setpoint.

Appendix D 44 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

After the Letdown temperatures have stabilized, place TCV-143, LTDN TO

VCT OR DEMIN, in DEMIN/AUTO.

After letdown is established, the lead evaluator can cue the Safety Valve failure

Appendix D 45 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Booth operator; when directed activate trigger 7

RO Reports rapidly lowering RCS Pressure/AUTO SI.

CRS Returns to EOP-1.0.

Evaluators 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.

Evaluators 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.

BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION (at end of

scenario form D2.

CRITICAL Either actuates containment isolation manually with switch SG02B or

BOP individually closes at least one valve in each line (expected to use the

TASK

one operable switch, CS-SG02A is failed).

Manually opens either MVG-8801A or B to establish a high head

CRITICAL injection path. (This must be accomplished prior to NR RVLIS reaching

34% density with no RCPs running-Orange Path challenge to Core

TASK Cooling.)

CREW Announce plant conditions over the page system.

Appendix D 46 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB

PSIG (P-951), red pen (YES)

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)

IF RCS temperature is LESS THAN 557 F 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 557F.

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).

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.

Appendix D 47 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Verify at least one PZR PORV Block Valve is open. (YES)

Procedure Note: Seal Injection flow should be maintained to all RCPs.

RO Check if RCPs should be stopped (already stopped):

BOP Verify no SG is FAULTED:

No SG pressure is decreasing in an uncontrolled manner. (YES)

No SG is completely depressurized. (YES)

Verify Secondary radiation levels indicate SG tubes are NOT

CREW

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.

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)

Transitions to EOP-2.0, LOSS OF REACTOR OR

SECONDARY COOLANT.

Appendix D 48 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

RO Check if RCPs should be stopped (None running).

BOP Verify no SG is FAULTED

No SG decreasing in an uncontrolled manner (YES)

No SG completely depressurized (YES)

BOP Check Intact SG levels

NR level in intact SGs >26% [41%]

Control EFW flow to maintain 40-60% NR level

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

RO Reset Containment Isolation:

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

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

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.

Appendix D 49 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

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)

RO/BOP Place both ESF LOADING SEQ A(B) RESETS to:

NON-ESF LCKOUTS

AUTO-START BLOCKS

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.

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)

CRS GO TO Step 11.

RO Check if RB Spray should be stopped:

Check if any RB Spray Pumps are running. (NO)

Appendix D 50 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

RO Check if RCS pressure is stable or decreasing. (YES)

BOP Check if pressure in all SGs is stable or increasing. (YES)

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.

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)

RO Obtain necessary chemistry samples

RO Shutdown and stabilize the Secondary Plant

RO Check If RCS Cooldown and Depressurization is required (YES)

Appendix D 51 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RCS pressure greater than 325 psig (YES)

Goes TO EOP-2.1 POST-LOCA COOLDOWN AND

DEPRESSURIZATION (crew brief expected).

Evaluators Note; Scenario may be terminated after transition to EOP-2.1

Appendix D 52 NUREG 1021 Revision 9

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

Facility: VC SUMMER Scenario No: Op Test No.: 2011 NRC

Spare

Examiners: Operators: CRS

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 Malf. No. Event Type* Event

No. Description

High temperature on Transformer 1A1 requires transfer of

1. ANN-EM008 C-BOP, CRS

480V busses 1A1 and 1A2 to alternate power . BOP-1

C-RO, CRS

2. CRF004L11 Dropped control rod RO-2

TS-CRS

N-BOP, CRS R-

N/A Decrease power to recover rod

RO,

3. MAL-PRS001A I-RO, CRS PT-444 fails high RO-3

C-RO, CRS

4. PMP-CS004B Running charging pump bearing seizes RO-1

TS-CRS

5. CNH-FW002O C-BOP, CRS FW Bypass valve fails open. BOP-2

VLV-RH007L

6. VLV-RH009L M-ALL Non isolable LOCA outside containment

FLX-RHR001

MAL-PCS005A

7. C-ALL Failure of SI to auto-initiate.

MAL-PCS005B

PMP-AH022F

8. C-BOP Failure of XFN-30A,B, EMERG FLTR FAN A,B to start.

and AH023F

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D 1 NUREG 1021 Revision 9

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

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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 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.

Appendix D 2 NUREG 1021 Revision 9

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

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.

Appendix D 3 NUREG 1021 Revision 9

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

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

Appendix D 4 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

BOP Directs TB operator to investigate transformer XTF-1A1

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.

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

Appendix D 5 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 racked 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.

Perform the following for buses having Bus Tie Breakers

(XSW1A1, XSW1A2, XSW1A3, XSW1B1, XSW1B2, XSW1B3,

XSW1B4, XSW1C1, XSW1C3 and XSW1C4):

a. Pull the Bus Tie Breaker control switch up, to the Manual

BOP 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.

Perform the following steps on the affected 480 Volt Buses not

BOP having a Bus Tie Breaker connection: (NONE)

Appendix D 6 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

BOP Open the 7.2 KV/480V Transformer Feeder Breaker.

Caution:

Opening a breaker does not provide an acceptable safety margin for electrical work. The

breaker should be racked out and any associated air disconnects opened prior to

commencing maintenance.

Calls AO to:

Unlock and remove the key from the 480 Volt Main Incoming

Crew 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

Evaluators 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.

Appendix D 7 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

A trouble alarm for the B IA compressor is received: it clears when power

is reestablished.

Not expected; ARPs

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

BOP 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

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

Appendix D 8 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

Appendix D 9 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

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.

AUTOMATIC ACTIONS:

2. Automatic outward rod motion to match Tave to Tref until the withdrawal

limit is reached.

Appendix D 10 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

CORRECTIVE ACTIONS:

CRS 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).

IOA RO Place ROD CNTRL BANK SEL Switch in MAN.

Stabilize the plant;

a. Decrease Main Turbine load to maintain Tavg within 5°F of Tref .

Crew 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.

RO Check if Reactor power is LESS THAN 75%. (yes)

Initiate GTP-702, Attachments IV.A, IV.B, and IV.C to monitor Shutdown

Margin, rod deviation, and rod insertion.

Notify the following plant personnel prior to moving Control Rods:

Management Duty Supervisor and Rod Control System Engineer.

Appendix D 11 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Provide Reactor Engineering with the following information:

RO Determine and correct the cause of the failure (will not be corrected).

NOTE - Step 9 This Step must be completed before continuing with Step 10.

Obtain the following information from Reactor Engineering:

RO Power level at which recovery is to be performed: (35%).

Rate of Control Rod movement during recovery: no restriction

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.

Appendix D 12 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

If necessary, reduce Reactor Power to the power level determined in

Crew Step 9. REFER TO GOP-4B, POWER OPERATION (MODE 1 -

DESCENDING) OR GOP-4C, RAPID POWER REDUCTION.

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%.

Reduce load

Appendix D 13 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

As load decreases, adjust Megavars using GEN FIELD VOLT ADJ as

BOP requested by the Load Dispatcher and within the Estimated Generator

Capability curve (Enclosure A).

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).

After a >5% power change, proceed to the next event with Lead Evaluator concurrence.

Appendix D 14 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

AUTOMATIC ACTIONS:

1. Pressurizer heaters cut off.

2. PCV-444B, PWR RELIEF, opens.

3. PCV-444C(444D), PZR SPRAY, open fully.

Appendix D 15 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

CORRECTIVE ACTIONS:

Compare PI-444, CNTL CHN PRESS PSIG, with other Pressurizer pressure

RO indications to determine if IPT00444, PRESSURIZER PRESSURE

CONTROL PRESS XMTR, has failed high (yes).

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.

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.

IOA RO Verify the PZR PORVs are closed: (NO)

Appendix D 16 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

IF PZR pressure is LESS THAN 2300 psig, THEN perform the following:

Close the AFFECTED PZR PORV(s):

IOA RO PCV-445A, PWR RELIEF (NO)

PCV-445B, PWR RELIEF (NO)

PCV-444B, PWR RELIEF (YES)

NOTE - Step 2 PZR PRESS control channels PI-444 and PI-445 connect to the same reference

leg line as protection channel PI-457.

Compare the PZR control channel indication to the protection channel

indications: (ONLY 444 reading high)

IOA RO PI-455, PRESS PSIG

PI-456, PRESS PSIG

PI-457, PRESS PSIG

IOA RO Check if PI-444, CNTROL CHAN PRESS PSIG, indication is NORMAL. (NO)

a) Ensure the PZR Spray Valves are

closed:

PCV-444C. PZR SPRAY

PCV-444D, PZR SPRAY

IOA RO

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

Appendix D 17 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Check if PI-445, CNTRL CHAN PRESS PSIG, indication is NORMAL. (YES)

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:

CRS 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and

HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Tech Specs

RO Ensure ROD CNTRL BANK SEL Switch is in AUTO.

RO Maintain RCS pressure between 2220 psig and 2250 psig.

While regaining pressure monitor Technical Specification:3.2.5: Indicated

Pressurizer Pressure 2206 psig

CRS Action: With any of the above parameters exceeding its limit, restore the

parameter to within its limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to

less than 5% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Tech Specs

Determine and correct the cause of the channel failure (will not be

Crew

corrected during scenario).

Appendix D 18 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Booth Operator Instructions:

When called as I&C report that a troubleshooting plan is being developed.

Crew Conducts post-event brief, contacts SS and I&C.

At the discretion of the Lead Examiner, proceed to the next event.

Appendix D 19 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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

AUTOMATIC ACTIONS: 1. None.

CORRECTIVE ACTIONS:

RO 1. If the running Charging Pump amps are abnormal (yes), secure the

Charging Pump and go to AOP-102.2, Loss of Charging.

CRS Enters AOP-102.2, LOSS OF CHARGING

Enters AOP-102.2

RO Checks if charging flow is normal (NO)

Appendix D 20 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

IF Charging Pump suction is aligned to the VCT THEN ensure both LCV-

115C(E), VCT OUTLET ISOL, are open (YES)

Appendix D 21 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Appendix D 22 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

6) Locally verify Charging Pump suction pressure is between 50 psig and

100 psig as indicated on the following:

RO PI-151A, SUCTION PRESS, for Charging Pump A.

PI-152A, SUCTION PRESS, for Charging Pump B.

PI-153A, SUCTION PRESS, for Charging Pump C.

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 during 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.

Appendix D 23 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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 difference in Boric Acid Concentration in the

stagnant piping could change RCS Tave, depending on time in core life, by as much as

0.2°F when the pump is placed in service.

Directs racking up C charging pump on A train or starting B train CCW

Crew

and B train charging pump

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.

RO Starts XPP-0043B(C), PUMP B(C). (PEER check)

RO Verifies XPP-43B(C)-PP1, CHG PP B(C) AUX OIL PP, stops automatically

Appendix D 24 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Verifies PI-121, CHG PRESS PSIG, is between 2650 psig and 2850 psig

Monitors the following for proper pump operation:

a. LR-459, PZR % LEVEL & LEVEL SP.

RO 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.

Places PCV-145, LO PRESS LTDN, in MAN and open to 70%. (PEER

check)

RO Places TCV-144, CC TO LTDN HX, in MAN and open to 100%.

RO Places TCV-143, LTDN TO VCT OR DEMIN, in VCT.

RO Opens PVT-8152, LTDN LINE ISOL.

Appendix D 25 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Opens the following:

RO a. LCV-459, LTDN LINE ISOL.

b. LCV-460, LTDN LINE ISOL.

Ensure the following Charging Line Isolation Valves are open:

RO a. MVG-8107, CHG LINE ISOL.

b. MVG-8108, CHG LINE ISOL.

Slowly open FCV-122, CHG FLOW, to establish 60 gpm flow as indicated on

FI-122A, CHG FLOW GPM.

Open Orifice Isolation Valves to obtain the desired Letdown flow rate

(60 gpm to 120 gpm):

RO 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).

Adjust FCV-122, CHG FLOW, as required to maintain TI-140, REGEN HX

RO OUT TEMP °F, between 250°F and 350°F while maintaining Pressurizer

level.

Appendix D 26 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Adjust PCV-145, LO PRESS LTDN, to maintain PI-145, LO PRESS LTDN

PRESS PSIG, between 300 psig and 400 psig.

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

Adjust TCV-144, CC TO LTDN HX, potentiometer as necessary to maintain

the desired VCT temperature and place in AUTO.

When Pressurizer level is within 1% of and trending to programmed level,

place the PZR LEVEL MASTER CONTROL in MAN.

Establish automatic FCV-122, CHG FLOW, control as follows:

a. Determine the correct PZR LEVEL MASTER CONTROL setpoint by

RO 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)

Adjust PZR LEVEL MASTER CONTROL in MAN, as necessary, to maintain

Pressurizer level at or near programmed level.

When Pressurizer level is within 1% of and trending to programmed level,

place PZR LEVEL MASTER CONTROL in AUTO. . (PEER check)

Appendix D 27 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Monitor LR-459, PZR % LEVEL & LEVEL SP, recorder to verify that

RO Charging flow is maintaining actual Pressurizer level at or near the

programmed setpoint.

After the Letdown temperatures have stabilized, place TCV-143, LTDN TO

VCT OR DEMIN, in DEMIN/AUTO.

Conducts Post-event brief, contacts SS. May contact Mechanical

Crew

Maintenance for pump repair.

At the discretion of the Lead Examiner, proceed to the next event

Appendix D 28 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

AUTOMATIC ACTIONS:

1. FCV-478, A FCV, will modulate to attempt to restore level to 61.6%.

Appendix D 29 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

CORRECTIVE ACTIONS:

1. If required, restore Steam Generator A level to between 60% and 65% by

BOP performing the following:

a. Manually control PVT-478, SG A FWF

SUPPLEMENTAL ACTIONS:

1. Correct the level deviation and restore automatic control (NO, valve is failed

open).

Booth Operator Instructions: When called as I&C report that you will develop a troubleshooting

plan.

Appendix D 30 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Conducts post-event brief and contacts SS. May contact I&C for Bypass Feed

Crew

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

Appendix D 31 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Booth Instructor:

When directed, activate trigger 6.

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.

.

Transitions to AOP-101.1 LOSS OF REACTOR COOLANT NOT

REQUIRING SI

Appendix D 32 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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).

IOA RO a) Open FCV-122. CHG FLOW as necessary to maintain PZR level.

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.

IOA RO 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.

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

IOA RO minimized.

PZR level is approaching 12% (yes).

PZR pressure is approaching 1870 psig.

VCT level is approaching 5% (yes).

Appendix D 33 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

b. Perform the following:

1) Trip the Reactor

IOA RO 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

Verify Reactor Trip:

Trip the Reactor using either Reactor Trip Switch.

IOA RO Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

Verify Turbine/Generator Trip:

a. Verify all Turbine STM Stop VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

IOA BOP

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP Verify both ESF buses are energized.

Appendix D 34 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Check if SI is actuated:

a. Check if either:

SI ACT status light is bright on XCP-6107 1-1 (NO).

IOA RO

Or

Any red first out SI annunciator is lit on XCP-626 top row (YES).

CRITICAL

RO b. Actuate SI using either SI ACTUATION Switch

TASK

BOP Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION.

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.

Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB

PSIG (P-951), red pen. (YES)

Appendix D 35 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Verify both the following annunciators are lit; (NO)

RO c. XCP-612 3-2 (RB SPR ACT).

d. XCP-612 4-2 (PHASE B ISOL).

Check RCS temperatures:

With any RCP OR RCS Tavg is stable at or trending to 557°F OR With no

RO 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%.

RO Check if PZR PORVs are closed (yes).

RO Check if PZR Spray Valves are closed (yes).

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).

RO Verify at least one PZR PORV Block Valve is open (yes)..

NOTE - Step 11

Seal Injection flow should be maintained to all RCPs.

Appendix D 36 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

RO Check if RCPs should be stopped: (YES)

Critical

RO Stop all Reactor Coolant Pumps

Task

Verify no SG is FAULTED:

RO No SG pressure is decreasing in an uncontrolled manner (yes).

No SG is completely depressurized. (yes).

Verify Secondary radiation levels indicate SG tubes are NOT

RUPTURED: (yes)

Appendix D 37 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Check if the RCS is INTACT: (YES based on CNTMT conditions)

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

Reset Containment Isolation:

RO * RESET PHASE A - TRAIN A(B) CNTMT ISOL. '

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

Place both ESF LOADING SEQ A(B) '

RESETS to:

BOP a. NON-ESF LCKOUTS. '

b. AUTO-START BLOCKS.

Appendix D 38 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Evaluators 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.

Establish Instrument Air to the RB:

a. Verifies the A IA compressor is running and

Verifies the B IA compressor is in standby(NO)

RO 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.

RO Check if SI flow should be reduced: (no)

Initiate monitoring of the Critical Safety Function Status Trees. REFER TO

CRS EOP-12.0, MONITORING OF CRITICAL SAFETY FUNCTIONS.

Evaluators note; STA can perform this function as directed 10 minutes after he is called to

the control room.

Check SG levels;

RO a. Verify level in all SGs > 26% (yes)

b. Control EFW flow to maintain NR levels 40%-60%

Appendix D 39 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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)

Check for loss of Reactor Coolant outside Containment (yes)

Appendix D 40 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Evaluator Note: The closure of the MSIVs 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

Appendix D 41 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

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.

Crew Announces plant conditions over the page system.

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.

(YES)

Appendix D 42 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

(ALL CLOSED)

RO Check if RCS pressure is continuing to decrease (yes).

Appendix D 43 NUREG 1021 Revision 9

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 Applicants Actions or Behavior

Booth operator instructions; adjust size of flex leak as required to keep RCS

pressure trending down.

4. Try to identify and isolate the break: (requires operating A and

RO B train power lockout switches to restore control power)

a. Close MVG-8888A, RHR LP A TO COLD LEGS.

RO Check if RCS pressure is continuing to decrease (yes)

RO c. Open MVG-8888A, RHR LP A TO COLD LEGS.

Critical

RO d. Close MVG-8888B, RHR LP B TO COLD LEGS

Task

RO Check if RCS pressure is continuing to decrease (no)

Transitions to EOP-2.0 LOSS OF EMERGENCY COOLANT

RECIRCULATION.

Lead Examiner can terminate the scenario at this point.

Appendix D 44 NUREG 1021 Revision 9

V.C. SUMMER NUCLEAR STATION

JPM NO: JPPF-049

2011 NRC InPlant i RO: CONTROL ROOM

EVACUATION (DUTIES OF BOP OPERATOR)

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 7

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Saturday, September 03, 2011 Page 1 of 12

TASK:

000-068-05-01 PERFORM CONTROL ROOM EVACUATION

TASK STANDARD:

AOP-600.1 Attachment II performed with the following complete:

1. All MFPs have been tripped

2. Rod Drive MG set feeder breakers have been tripped

3. 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.

TERMINATING CUE: Step 12 of Attachment II is complete or when examinee returns procedure

to examiner.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

PLANT SIMULATE

REFERENCES: SOP-313 LOCAL SWITCHGEAR BREAKER OPERATIONS

ISP-027 ELECTRICAL SAFETY

AOP-600.1 CONTROL ROOM EVACUATION

INDEX NO. K/A NO. RO SRO

0000682130 2.1.30 Ability to locate and operate 4.4 4.0

components, including local controls.

TOOLS: AOP-600.1, Attachment II, Steps 10-12

ISP-027 Electrical Safety

SOP-313

Picture of the inside of a 7.2 KV breaker.

EVALUATION TIME 14 TIME CRITICAL No 10CFR55: 45(a)13

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Saturday, September 03, 2011 Page 2 of 12

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The Control Room Supervisor directs the BOP Operator to perform

Attachment 2 of AOP-600.1, Steps 10 through 12.

AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!

FOR ELECTRICAL MANIPULATIONS,

AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Saturday, September 03, 2011 Page 3 of 12

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The Control Room Supervisor directs the BOP Operator to perform

Attachment 2 of AOP-600.1, Steps 10 through 12.

AT NO TIME ARE YOU TO OPERATE ANY

PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Saturday, September 03, 2011

STEPS

STEP: 1

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Verifies reactor has been tripped. Calls the reactor operator and verifies

reactor has been tripped.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

Yes Yes Locally trip all Main Feedwater Pumps (436' Pulls MFP "PULL TO TRIP" handle on

TB). front standard for MFP's "A" "B" & "C".

Verifies trip by noting RPM decrease

locally OR trips MFPs from local DCS

station.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 5 of 12

STEP: 3

CUES:

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 shirt

or 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.

CR SEQ STEP STANDARD:

No Yes Locally at XSW1A Switchgear Room (TB- Trips rod drive MG set "B" bkr 06C at

436): Trips ROD DRIVE M/G SET "B" - XSW-1B1 by pushing on red TRIP

XMG0001B-CR, XSW1B1 06C. pushbutton on left side on front of

breaker. Verifies a green "OPEN" flag

results and red light OFF, green light ON

COMMENTS: SAT

UNSAT

STEP: 4

CUES:

Examiner informs examinee that the "A" FWBP, bkr 06 red light is lit.

CR SEQ STEP STANDARD:

No Yes Check status of XSW1A 06 FD WTR Verifies that the "A" FWBP, bkr 06 is

BOOSTER PUMP "A" XPP0028A-FW closed by observing red light on outside

breaker. of cubicle door.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 6 of 12

STEP: 5

CUES:

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 running in Step 12.c.)

CR SEQ STEP STANDARD:

No Yes Checks status of XSW1A 09, RX COOLANT Checks RCP "A" breaker at XSW1A 09.

PUMP "A" XPP0030A-RC. Verifies a green light on outside of

cubicle door.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

Examiner informs examinee that the "A" condensate pump breaker red light is lit.

CR SEQ STEP STANDARD:

No Yes Check status of XSW1A 07, COND PUMP Verifies that the "A" condensate pump

"A" XPP0042A-CO breaker. bkr 07 is closed by observing red light on

outside of cubicle door.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 7 of 12

STEP: 7

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Locally at XSW1B and XSW1C Switchgear Trips breaker XSW1B 09 for Cond

Room (TB-412): If Condensate Pump "A" is Pump "B" by pushing the "MANUAL

running THEN trip both of the following: Trip TRIP" lever on front of breaker (inside

XSW1B 09, COND PUMP "B" XPP0042B- cubicle door). Verifies a green light on

CO breaker. outside of cubicle door results.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

Examiner informs examinee the cubicle for COND PUMP "C" XPP0042C has a green light lit on

the front of the cubicle.

CR SEQ STEP STANDARD:

No Yes Checks status of XSW1C 06, COND PUMP Checks COND PUMP "C" Breaker,

"C" XPP0042C-CO breaker. XSW01C 06. Verifies a green light ON

outside of cubicle door.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 8 of 12

STEP: 9

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes If Feedwater Booster Pump "A" is running, Trips the FWBP "B" bkr 06 manually at

THEN trip all of the following: Trips XSW1B XSW-1B by pushing the "MANUAL

06, FD WTR BOOSTER PUMP "B" TRIP" lever on front of breaker (inside

XPP0028B-FW breaker. cubicle door). Verifies a green light on

outside of cubicle door results.

COMMENTS: SAT

UNSAT

STEP: 10

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Trips XSW1B 13, FD WTR BOOSTER Trips the FWBP "D" bkr 13 manually at

PUMP "D" XPP0028D-FW breaker. 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.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 9 of 12

STEP: 11

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Trips XSW1C 08, FD WTR BOOSTER Trips the FWBP "C" bkr 08 manually at

PUMP "C" XPP0028C-FW breaker. 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.

COMMENTS: SAT

UNSAT

STEP: 12

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes If RCP A is running (NO), goes to RNO. Does NOT trip the RCP "B" bkr 07 at

Ensure one of the following is open: XSW1B XSW-1B (because RCP "C" bkr 03 at

07, RX COOLANT PUMP "B" XPP0030B- XSW-1C is already open).

RC OR XSW1C 03, RX COOLANT PUMP

"C" XPP0030C-RC.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 10 of 12

STEP: 13

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Ensure XSW 1C 02 Press Heater Verifies that the PZR Heater

Transformer XTF 4103-RC is closed. 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.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Saturday, September 03, 2011 Page 11 of 12

JPM SETUP SHEET

JPM NO: JPPF-049

DESCRIPTION: 2011 NRC InPlant i RO: CONTROL ROOM EVACUATION (DUTIES OF BOP

OPERATOR)

IC SET:

INSTRUCTIONS:

COMMENTS:

Saturday, September 03, 2011 Page 12 of 12

V.C. SUMMER NUCLEAR STATION

JPM NO: JPPF-044

2011 NRC InPlant i SRO: CONTROL ROOM

EVACUATION (Followup Actions of CRS)

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 15

CANDIDATE:

EXAMINER:

SRO ONLY

THIS JPM IS APPROVED

Friday, September 02, 2011 Page 1 of 21

TASK:

000-068-05-01 PERFORM CONTROL ROOM EVACUATION

TASK 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.

TERMINATING CUE: Emergency boration is completed or emergency boration is (incorrectly)

deemed "not required" or when examinee returns procedure to examiner.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

PLANT SIMULATE

REFERENCES: AOP-600.1 CONTROL ROOM EVACUATION

INDEX NO. K/A NO. RO SRO

000068K318 AK3.18 Actions contained in EOP for control 4.2 4.5

room evacuation emergency task

000068K309 AK3.09 Transfer of the following to local control: 3.9 4.4

charging pumps, charging header flow

control valve, PZR heaters, and boric

acid transfer pumps

TOOLS: AOP-600.1, BEGINNING WITH STEP 4

EVALUATION TIME 25 TIME CRITICAL No 10CFR55: 45(a)13

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Friday, September 02, 2011 Page 2 of 21

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The Shift Supervisor directs you, the CRS, to perform AOP-600.1,

CONTROL ROOM EVACUATION, at the CREP, beginning with Step 4.

AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!

FOR ELECTRICAL MANIPULATIONS,

AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Friday, September 02, 2011 Page 3 of 21

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The Shift Supervisor directs you, the CRS, to perform AOP-600.1,

CONTROL ROOM EVACUATION, at the CREP, beginning with Step 4.

AT NO TIME ARE YOU TO OPERATE ANY

PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Friday, September 02, 2011

STEPS

STEP: 1

CUES:

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 any change in indication will occur.

CR SEQ STEP STANDARD:

Yes No Align the following controls (CREP XPN- Rotates the potentiometer wheel

7200A): Set FCV-122, CHG FLOW, clockwise until 5 appears in the

potentiometer to 5.0. window.(5 full turns).

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Set IFV-3536, TD EFP to SG A, Rotates IFV-3536 potentiometer

potentiometer fully clockwise. clockwise until no further rotation can be

made.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Set IFV-3546, TD EFP to SG B, Rotates IFV-3546 potentiometer

potentiometer fully clockwise. clockwise until no further rotation can be

made.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 5 of 21

STEP: 4

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Set IFV-3556, TD EFP to SG C, Rotates IFV-3556 potentiometer

potentiometer fully clockwise. clockwise until no further rotation can be

made.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

Yes No Place LCV-459, LTDN LINE ISOL, in OPEN. Positions the LCV-459 control switch to

the OPEN position.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

CR SEQ STEP STANDARD:

Yes No Place LCV-460, LTDN LINE ISOL, in OPEN. Positions the LCV-460 control switch to

the OPEN position.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 6 of 21

STEP: 7

CUES:

CR SEQ STEP STANDARD:

Yes No Place two letdown orifices in OPEN and one Positions two of three PVT-8149 (A,B,C)

in CLOSE LTDN ORIFICE (A,B,C) ISOL control

switches to the OPEN position. Ensures

one is positioned to CLOSE.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

Yes No Place TSC BYPASS in ON Positions the TSC BYPASS switch to

the ON position.

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No At the Auxiliary Panel, place PCV-445A, Verifies the PCV-445A control switch is

PORV in CLOSE. in the CLOSE position.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 7 of 21

STEP: 10

CUES:

After switch placed in LOCAL, cue operator that red light is lit on PZR HTRS BU GROUP 1.

CR SEQ STEP STANDARD:

Yes No Transfer the following to LOCAL (CREP Positions the transfer switch from

XPN-7200A): PZR HTRS BU GROUP 1 REMOTE to LOCAL

XFER to LOCAL.

COMMENTS: SAT

UNSAT

STEP: 11

CUES:

After switch placed in LOCAL, cue operator that there was no change in FI-122B.

CR SEQ STEP STANDARD:

Yes No FCV-122, CHG FLOW CNTRL XFER to Positions the transfer switch from

LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 12

CUES:

After switch placed in LOCAL, cue operator that red light is lit on SW PUMP A

CR SEQ STEP STANDARD:

Yes No XPP-0039A, SW PUMP A XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 8 of 21

STEP: 13

CUES:

After switch placed in LOCAL, cue operator that no lights are lit on SW Pump C.

CR SEQ STEP STANDARD:

No No XPP-0039C, SW PP C TRAIN A XFER to Positions the transfer switch from

LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 14

CUES:

Examiner Note: There will be no change in indications with this transfer.

CR SEQ STEP STANDARD:

Yes No TD EFP FD VLV XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 15

CUES:

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).

CR SEQ STEP STANDARD:

Yes No LCV-459, LTDN LINE ISOL XFER to LOCAL. Positions transfer switch from REMOTE

to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 9 of 21

STEP: 16

CUES:

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).

CR SEQ STEP STANDARD:

Yes No LCV-460, LTDN LINE ISOL XFER to LOCAL. Positions transfer switch from REMOTE

to LOCAL

COMMENTS: SAT

UNSAT

STEP: 17

CUES:

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 by operator in step 7 of JPM).

CR SEQ STEP STANDARD:

Yes No PVT-8149A, LTDN LINE A ISOL XFER to Positions transfer switch from REMOTE

LOCAL. to LOCAL

COMMENTS: SAT

UNSAT

STEP: 18

CUES:

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 by operator in step 7 of JPM).

CR SEQ STEP STANDARD:

Yes No PVT-8149B, LTDN LINE B ISOL XFER to Positions transfer switch from REMOTE

LOCAL. to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 10 of 21

STEP: 19

CUES:

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 by operator in step 7 of JPM).

CR SEQ STEP STANDARD:

Yes No PVT-8149C, LTDN LINE C ISOL XFER to Positions transfer switch from REMOTE

LOCAL. to LOCAL

COMMENTS: SAT

UNSAT

STEP: 20

CUES:

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).

CR SEQ STEP STANDARD:

Yes No PCV-445A, PORV XFER (Auxiliary Panel) to Positions transfer switch from REMOTE

LOCAL. to LOCAL

COMMENTS: SAT

UNSAT

STEP: 21

CUES:

Examiner cues operator that Service Water Pump breaker for Service Water Pump "A" indicator

red light is lit and no lights are lit on Service Water Pump "C".

CR SEQ STEP STANDARD:

No Yes Ensure one Service Water Pump running on Verifies Service Water Pump "A" red

Train A (CREP A) light lit.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 11 of 21

STEP: 22

CUES:

Evaluator 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.

CR SEQ STEP STANDARD:

No No Align the following controls (CREP XPN- Rotates IFV-3531 potentiometer

7200B): Set IFV-3531, MD EFP TO SG A clockwise until no further rotation can be

potentiometer fully clockwise made.

COMMENTS: SAT

UNSAT

STEP: 23

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Set IFV-3541, MD EFP TO SG B Rotates IFV-3541 potentiometer

potentiometer fully clockwise clockwise until no further rotation can be

made.

COMMENTS: SAT

UNSAT

STEP: 24

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Set IFV-3551, MD EFP TO SG C Rotates IFV-3551 potentiometer

potentiometer fully clockwise clockwise until no further rotation can be

made.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 12 of 21

STEP: 25

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No Place XPP-13B, BA XFER PUMP B in OFF Verifies the B.A. Transfer Pump "B"

control switch in OFF.

COMMENTS: SAT

UNSAT

STEP: 26

CUES:

CR SEQ STEP STANDARD:

Yes No Place XVT-8152, LTDN ISOL in OPEN Positions the XVT-8152 control switch to

OPEN.

COMMENTS: SAT

UNSAT

STEP: 27

CUES:

CR SEQ STEP STANDARD:

Yes No Place PVG-2030, STEAM TO TD EFP in Positions the XVT-2030 control switch to

OPEN OPEN.

COMMENTS: SAT

UNSAT

STEP: 28

CUES:

CR SEQ STEP STANDARD:

Yes No Place TSC BYPASS in ON Positions the TSC BYPASS Switch to

the ON position.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 13 of 21

STEP: 29

CUES:

This is the expected position and so no operator action should have to be taken. Cue candidate

that position is how it appears.

CR SEQ STEP STANDARD:

No No At the Auxiliary Panel, place PORV PCV- Verifies the PCV-444B control switch is

444B in CLOSE in CLOSE.

COMMENTS: SAT

UNSAT

STEP: 30

CUES:

After switch placed in LOCAL, cue operator that the green light is lit.

CR SEQ STEP STANDARD:

Yes No Transfer the following to LOCAL (CREP Positions the transfer switch from

XPN-7200B): PZR HTRS BU GROUP 2 REMOTE to LOCAL

XFER to LOCAL

COMMENTS: SAT

UNSAT

STEP: 31

CUES:

After switch placed in LOCAL, cue operator that the green light is lit.

CR SEQ STEP STANDARD:

Yes No MVT-8104, EMERG BA FLOW CNTRL Positions the transfer switch from

XFER to LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 14 of 21

STEP: 32

CUES:

After switch placed in LOCAL, cue operator that the red light is lit.

CR SEQ STEP STANDARD:

Yes No XPP-0039B, SW PUMP B XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 33

CUES:

After switch placed in LOCAL, cue operator that no lights are lit.

CR SEQ STEP STANDARD:

Yes No XPP-0039C, SW PUMP C TRAIN B XFER Positions the transfer switch from

to LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 34

CUES:

Examiner Note: There will be no change in indications with this transfer.

CR SEQ STEP STANDARD:

Yes No MD EFP FEED VALVES XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 15 of 21

STEP: 35

CUES:

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 light lit).

CR SEQ STEP STANDARD:

Yes No XPP-13B, BA PUMP B XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 36

CUES:

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).

CR SEQ STEP STANDARD:

Yes No XVT-8152, LTDN ISOL XFER to LOCAL. Positions the transfer switch from

REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 37

CUES:

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).

CR SEQ STEP STANDARD:

Yes No PVG-2030, STEAM TO TD EFP XFER to Positions the transfer switch from

LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 16 of 21

STEP: 38

CUES:

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 light lit).

CR SEQ STEP STANDARD:

Yes No PCV-444B, PORV XFER (Auxiliary Panel) to Positions the transfer switch from

LOCAL. REMOTE to LOCAL

COMMENTS: SAT

UNSAT

STEP: 39

CUES:

Examiner cues operator that Service Water Pump breaker for Service Water Pump "B" indicator

red light is lit and no lights are lit on Service Water Pump "C".

CR SEQ STEP STANDARD:

No Yes Ensures one Service Water pump running Verifies the Service Water Pump "B" red

on Train B (CREP B) light lit.

COMMENTS: SAT

UNSAT

STEP: 40

CUES:

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 range counts, inform examinee that NI-32A reads 1000 counts.

CR SEQ STEP STANDARD:

No Yes Check if N-33 can be aligned. Determines sufficient time has passed to

align N-33.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 17 of 21

STEP: 41

CUES:

If examinee asks for specific source range counts, inform examinee that NI-33 reads 1,000 counts.

CR SEQ STEP STANDARD:

Yes Yes On XPN7300, place INI-0033, N33 DET Positions the switch to ON position as

HIGH VOLTAGE Switch in ON indicated by red light lit.

COMMENTS: SAT

UNSAT

STEP: 42

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Check if Emergency boration is required. Checks for plant conditions which would

require emergency boration from chart in

AOP-600.1

COMMENTS: SAT

UNSAT

STEP: 43

CUES:

After switch placed in OPEN, cue operator that red light is lit.

CR SEQ STEP STANDARD:

Yes Yes Open MVT-8104 EMERG BA FLOW CNTRL Rotates control switch to OPEN position

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 18 of 21

STEP: 44

CUES:

After switch placed in START, cue operator that red light is lit.

CR SEQ STEP STANDARD:

Yes Yes Start XPP-13B, BA XFER PUMP B Rotates control switch to START position

COMMENTS: SAT

UNSAT

STEP: 45

CUES:

Cue operator that FI-110A indicates 100 GPM.

CR SEQ STEP STANDARD:

Yes Yes Verify flow on FI-110A, EMERGENCY BA Checks indication on FI-110A

FLOW GPM. EMERGENCY BA FLOW GPM.

COMMENTS: SAT

UNSAT

STEP: 46

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Verify required boration is completed. Notes that it will take 25 minutes for

required boration.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 19 of 21

STEP: 47

CUES:

Cue operator that the green light is lit.

If asked about FI-110A, cue the operator the flow has decreased to 0 gpm.

CR SEQ STEP STANDARD:

Yes Yes CLOSE MVT-8104, EMERG BA FLOW Rotates control switch to CLOSE position

CNTRL.

COMMENTS: SAT

UNSAT

STEP: 48

CUES:

Cue operator that the green light is lit

CR SEQ STEP STANDARD:

Yes Yes Stop XPP-13B , BA XFER PUMP B Rotates control switch to OFF position

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Friday, September 02, 2011 Page 20 of 21

JPM SETUP SHEET

JPM NO: JPPF-044

DESCRIPTION: 2011 NRC InPlant i SRO: CONTROL ROOM EVACUATION (Followup Actions

of CRS)

IC SET:

INSTRUCTIONS:

COMMENTS:

Friday, September 02, 2011 Page 21 of 21

V.C. SUMMER NUCLEAR STATION

JPM NO: JPP-205

2011 NRC InPlant j RO & SRO: CROSS TRAIN

CONNECTION OF BATTERY CHARGER XBC1A-1B

(ALIGNING AC FROM TRAIN A AND DC TO TRAIN

B)

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 3

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Friday, September 02, 2011 Page 1 of 10

TASK:

063-007-01-04 PLACE A BATTERY CHARGER IN SERVICE

TASK 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.

TERMINATING CUE: Enclosure K is complete or student hands JPM back to examiner.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

PLANT SIMULATE

REFERENCES: FEP-2.0 TRAIN A PLANT SHUTDOWN TO HOT STANDBY

INDEX NO. K/A NO. RO SRO

000068A110 AA1.10 Power distribution: ac and dc 3.7 3.9

TOOLS: FEP-2.0, Enclosure E page 3 and K

FEP-2.0

FLASHLIGHT

5A plant key (typically on operator key ring).

EVALUATION TIME 15 TIME CRITICAL NO 10CFR55: 45(a)8

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Friday, September 02, 2011 Page 2 of 10

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

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.

AT NO TIME ARE YOU TO OPERATE

ANY PLANT EQUIPMENT!

FOR ELECTRICAL MANIPULATIONS,

AT NO TIME ARE YOU TO BREAK THE

PLANE OF THE ELECTRICAL PANEL!

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Friday, September 02, 2011 Page 3 of 10

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

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.

AT NO TIME ARE YOU TO OPERATE ANY

PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Friday, September 02, 2011

STEPS

STEP: 1

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Verify that XBC1A-1B, SWING BATTERY On XBC1A-1B, ensures the Train A-DC

CHARGER, is not supplying DPN-1HA breaker is OFF (pointing down).

(TRAIN A-DC breaker is OFF).

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Open both TRAIN A-AC and TRAIN B-AC At XET-4003, opens both Train A-AC

breakers and both TRAIN A-DC and TRAIN and Train B-AC and both Train A-DC

B-DC breakers on XET-4003. and Train B-DC breakers (pointing

down) to the "OFF" position.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 5 of 10

STEP: 3

CUES:

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 hand

breaker 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 way a physical bar to allow the breakers to close.

CR SEQ STEP STANDARD:

Yes Yes Insert the spare interlock key into the TRAIN Operator inserts spare interlock key into

A-AC or TRAIN B-DC interlock key slot on either TRAIN A-AC or TRAIN B-DC

XET-4003 and bypass the interlock. interlock key slot on XET-4003 and

places switch in "OFF".

COMMENTS: SAT

UNSAT

STEP: 4

CUES:

Breakers move freely in up direction.

CR SEQ STEP STANDARD:

Yes Yes Close the TRAIN A-AC breaker on XET- Operator positions TRAIN A-AC breaker

4003. upward to the "ON" position on XET-

4003.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 6 of 10

STEP: 5

CUES:

Breaker moves freely in up direction.

CR SEQ STEP STANDARD:

Yes Yes Close the TRAIN B-DC breaker on XET- Operator positions TRAIN B-DC breaker

4003. upward to the "ON" position on XET-

4003.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

NOTE: Breaker is 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 LEFT direction to "OFF" and step is

then critical.

CR SEQ STEP STANDARD:

No Yes Open DPN-1HA-ED 13, BATTERY Operator places breaker 13 (BATTERY

CHARGER 1A-1B FEED TO DPN1HA. CHARGER 1A-1B FEED TO DPN1HA)

in DPN-1HA-ED to the LEFT (OFF)

position.

COMMENTS: SAT

UNSAT

STEP: 7

CUES:

Breaker moves freely upward to the "ON" position

CR SEQ STEP STANDARD:

Yes Yes Close the following on XBC1A-1B Battery Operator places breakers DC OUTPUT

Charger: DC OUTPUT(CB2); AC INPUT and AC INPUT to the "UP" position on

(CB1) on the left side. XBC1A-1B Battery Charger.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 7 of 10

STEP: 8

CUES:

Examiner uses pen or pencil to point to 135 volts on the "DC OUTPUT" VOLTMETER (half way

between 120 & 150 marks).

CR SEQ STEP STANDARD:

No Yes Verify DC OUTPUT VOLTMETER stabilizes Operator checks that DC OUTPUT

between 129 and 140 volts. VOLTMETER stabilizes between 129

and 140 volts.

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

Procedure Note 9: "Allow five to ten seconds for the capacitors to fully charge and the battery

charger to stabilize."

CR SEQ STEP STANDARD:

No Yes Verify the capacitors are fully charged by After 5-10 seconds (per NOTE 9),

observing that the red indicator lights on operator verifies red indicator lights for

XPN5294 ED, BATT CHARGER CAP BOX, the capacitors are lit on XPN-5294-ED.

are illuminated.

COMMENTS: SAT

UNSAT

STEP: 10

CUES:

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 battery recharges."

CR SEQ STEP STANDARD:

Yes Yes Close DPN-1HB-ED 13, BATTERY Operator places breaker 13 on DPN-

CHARGER 1A-1B FEED TO DPN1HB. 1HB-ED to right ("ON") position.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 8 of 10

STEP: 11

CUES:

Examiner, as Control Room repeats back communication. (Ensure 3-way communication is used.)

CR SEQ STEP STANDARD:

No Yes Notify the Control Room that XBC1A 1B is Operator reports XBC1A-1B is cross

cross connected. connected to Control Room, using

expected communications techniques.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Friday, September 02, 2011 Page 9 of 10

JPM SETUP SHEET

JPM NO: JPP-205

DESCRIPTION: 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".

Friday, September 02, 2011 Page 10 of 10

V. C. SUMMER NUCLEAR STA TION

1PM NO: JPP-408

2011 NRC InPlant k RO & SRO: ALIGN SPENT FUEL

COOLING LOOP B TO RETURN REFUELING

CAVITY WATER TO THE RWST

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REVNO: 3

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Friday, September 02, 2011 Page 1 of 12

TASK:

344-042-03-02 DIRECT CORRECTIVE ACTIONS TO MITIGATE THE

CONSEQUENCES OF THE OFF NORMAL EVENT

TASK STANDARD:

Water is aligned so that it can be transferred to the RWST from the refueling cavity.

TERMINATING CUE: Attachment 1 of AOP-1 15.4 is complete or candidate turns in JPM sheet.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

PLANT SIMULATE

REFERENCES:

INDEX NO. K/A NO. RO SRO

0330002120 2.1.20 Ability to interpret and execute 4.6 4.6

procedure steps.

TOOLS: AOP-115.4, Attachment 1.

EVALUATION TIME 30 TIME CRITICAL NO 1OCFRS5: 55.45.b.8

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Friday, September 02, 2011 Page 2 of 12

INSTRUCTIONS To OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: Plant is in MODE 6. Refueling was occurring when all RHR was lost

and was not able to be return to service. Containment Closure has

been established. Cold leg injection from the A Charging pump has

been established. The Spent Fuel Pool Gate has been installed.

INITIATING CUES: The CRS directs you to Align Spent Fuel Cooling Loop B to return

Refueling Cavity water to the RWST by performing AOP-1 15.4

Attachment 1.

r I

AT NO TIME ARE YOU TO OPERATE I

!ANY PLANT EQUIPMENT!

_.

r

FOR ELECTRICAL MANIPULATIONS,

A T NO TIME ARE YOU TO BREAK THE:

PLANE OF THE ELECTRICAL PANEL!

I I

I. _ _J

HAND JPM BRIEFING SHEET TO OPERA TOR AT THIS TIME!

Friday, September 02, 2011 Page 3 of 12

1PM BRIEFING SHEET

OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION: Plant is in MODE 6. Refueling was occurring when all RHR was lost

and was not able to be return to service. Containment Closure has

been established. Cold leg injection from the A Charging pump has

been established. The Spent Fuel Pool Gate has been installed.

INITIATING CUES: The CRS directs you to Align Spent Fuel Cooling Loop B to return

Refueling Cavity water to the RWST by performing AOP-1 15.4

Attachment 1.

A T NO TIME A RE YOU TO OPERA TE ANY

PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Friday, September 02, 2011

STEPS

STEP: 1

CUES:

Ifcancdateasksstatus of Spent Fu& CooNng report from the control room that A is in service and

is secured.

11f candidate walks to pumps to determine operation, cue candidate that A is running (red light lit

1and flow noeand B shutdown (reen Nght ht and no flow noisej.

CR SEQ STEP STANDARD:

No Yes Check if Spent Fuel Cooling Loop A is Calls control room and using three-way

operating and if Loop B is shutdown. communication asks status of Spent

Fuel Cooling or goes to the Spent Fuel

Cooling pumps and determines that

XPPOO32A-SF, SPENT FUEL PIT

COOLING PUMP A, is running and

XPPOO32B-SF, SPENT FUEL PIT

COOLING PUMP B, is secured. The

candidate can also walk up to the pumps

and determine their operating condition.

COMMENTS:

UNSA T

STEP: 2

CUES:

CR SEQ STEP STANDARD:

Yes Yes Align Component Cooling Water to Spent Opens XVB09624B-CC, SPENT FUEL

Fuel Pool Heat Exchanger B (AB-388): HTEXCHBCCWTR INLET VALVE

Open XVB09624B-CC, SPENT FUEL HT (AB-388). by rotating handwheel

EXCH B CC WTR INLET VALVE (AB-388). completely counter-clockwise.

COMMENTS:

UNSA T

Friday, September 02, 2011 Page5ofl2

STEP: 3

CUES:

Evakjator Note: Cue the candidate that the valve dTcates5OD/oopen The candidate can choose

to leave the valve in an throttled Losition.

CR SEQ STEP STANDARD:

No Yes Ensure XVB09628B, CC SPENT FUEL HT Verifies valve is throttled open to a mid

EXCH B CC WTR OUTLET VLV is throttled position based on free movement of the

open (AB-388) handwheel in both the clockwise and

counter-clockwise directions or by

looking at valve position indicator.

COMMENTS:

UNSA T

STEP: 4

CUES:

candidate that XPPO14 SPENT FUEL PURICATION PUMP 15 opd_____

CR SEQ STEP STANDARD:

No Yes Align Spent Fuel Cooling Loop B to return Candidate can verify stopped motor or

Refueling Cavity water to the RWST: Ensure can use control switch position to

XPPOO14, SPENT FUEL PURIFICATION determine if XPPO14 is stopped.

PUMP (AB-412) is stopped.

COMMENTS:

UNSA T

STEP: 5

CUES:

Exarniner Note: Steps 5-1 3of the JPM are all part of procedure step 4b. and do nothavetobe

,comleted in anyarticular order.

CR SEQ STEP STANDARD:

No No Ensure the following are closed: Ensure Verifies that handwheel does not move

XVD06669-SF, SPENT FUEL POOL PUR in clockwise direction.

HDR ISOL VALVE (FB-436) is closed.

COMMENTS:

UNSA T

Friday, September 02, 2011 Page 6 of 12

STEP: 6

CUES:

CR SEQ STEP STA NDARD:

No No Ensure XVD06674-SF, SPENT FUEL POOL Verifies that handwheel does not move

PUR HDR SUPPLY VALVE (FB-436) is in clockwise direction.

closed.

COMMENTS: SAT

UNSA T

STEP: 7

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVG06666-SF, CASK LOADING Verifies that handwheel does not move

AREA SF HEADER ISOL VALVE (FB-436) in clockwise direction.

is closed.

COMMENTS: SAT

UNSA T

STEP: 8

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVG06660-SF, SPENT FUEL POOL Verifies that handwheel does not move

OUTLET HDR ISOL VALVE (AB-412) is in clockwise direction.

closed.

COMMENTS: SAT

UNSA T

Friday, September 02, 2011 Page 7 of 12

STEP: 9

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVG06664-SF, REFUEL WTR STG Verifies that handwheel does not move

TK SF HDR B SUCT ISOL (AB-412) is in clockwise direction.

closed.

COMMENTS:

UNSA T

STEP: 10

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVG06667-SF, SF HDR B CASK Verifies that handwheel does not move

LOADING AREA ISOL VALVE (AB-388) is in clockwise direction.

closed.

COMMENTS: SAT

UNSA T

STEP: 11

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVG0666 1-SF, SF COOLING Verifies that handwheel does not move

PUMP B SF POOL HDR ISOL VLV (AB- in clockwise direction.

388) is closed.

COMMENTS:

UNSA T

Friday, September 02, 2011 Page 8 of 12

STEP: 12

CUES:

CR SEQ STEP STANDARD:

No No Ensure XVD06692-SF, SF PUR HDR SF Verifies that handwheel does not move

HEADER B SUP ISOL VALVE (AB-388) is in clockwise direction.

closed.

COMMENTS:

UNSA T

STEP: 13

CUES:

CR SEQ STEP STANDARD:

Yes Yes Unlock and open XVG06668-SF, FUEL Removes locking device and takes

TRANSFER CANAL SF HDR ISOL VALVE handwheel in fully counterclockwise

(FB-436) direction.

COMMENTS:

UNSA T

STEP: 14

CUES:

Exarniner Note: Steps 14-18 of the JPM are all part of procedure step 4d. and do nothavetobe

comIeted in anyarticular order.

CR SEQ STEP STANDARD:

Yes No Open the following: Open XVG06665-SF, Turns handwheel in the fully

SPENT FUEL COOLING PUMP B SUCT counterclockwise direction.

ISOL VLV (AB-412)

COMMENTS:

UNSA T

Friday, September 02, 2011 Page 9of 12

STEP: 15

CUES:

CR SEQ STEP STA NDARD:

Yes No Open XVG06651-SF, SPENT FUEL Turns handwheel in the fully

COOLING PUMP B SUCTION VALVE tAB- counterclockwise direction.

412).

COMMENTS: SAT

UNSA T

STEP: 16

CUES:

CR SEQ STEP STA NDARD:

Yes No Open XVG06655-SF, SPENT FUEL Turns handwheel in the fully

COOLING PUMP B DISCHARGE VLV (AB- counterclockwise direction.

412).

COMMENTS: SAT

UNSA T

STEP: 17

CUES:

CR SEQ STEP STANDARD:

Yes No Open XVG06662-SF, REFUEL WTR STG Turns handwheel in the fully

1K SPENT FUEL ISOL VALVE (YD-170 W). counterclockwise direction.

COMMENTS: SAT

UNSA T

STEP: 18

CUES:

CR SEQ STEP STANDARD:

Yes No Open XVG06663-SF, SPENT FUEL Turns handwheel in the fully

HEADER B DISCH ISOL VALVE (AB-388). counterclockwise direction.

COMMENTS: SAT

UNSA T

Friday, September 02, 2011 Page 10 of 12

STEP: 19

CUES:

thdewtstochec start indicate thatolevelisasseen

CR SEQ STEP STANDARD:

Yes Yes Start XPPOO32B-SF, SPENT FUEL PIT Takes switch to start verifies pump

COOLING PUMP B (AB-412). starts and that red light is lit. (May

check oil level of pump prior to pump

start)

COMMENTS: SAT

UNSA T

STEP: 20

CUES:

Procedure Caution: To prevent damage to the Spent Fu&Coong PumpJoop flow should NOT

1be throttled to LESS THAN 600 gpm.

1lf called as control room report that level is 460 ft 3 inches. After candidate opens valve report

levels are risina.

CR SEQ STEP STANDARD:

Yes Yes Adjust XVT06659-SF, SPENT FUEL HEAT Contacts control room and throttles

EXCHANGER B OUTLET VLV (AB-388), as XVT06659-SF as directed.

necessary to maintain Refueling Cavity level

greater than 460 ft 6 inches.

COMMENTS: SAT

UNSA T

Examiner ends JPM at this point.

Friday, Sepkmber 02, 2011 Page 11 of 12

JPM SETUP SHEET

JPMNO: JPR.408

DESCRIPTION: 2011 NRC InPiant k RO & SRO: ALIGN SPENT FUEL COOLING LOOP B TO

RETURN REFUELING CAVITY WATER TO THE RWST

IC SET:

INSTRUCTIONS:

COMMENTS:

Friday, September 02, 2011 Page 12 of12

V.C. SUMMER NUCLEAR STATION

JPM NO: JPSF-045B

2011 NRC Sim a RO & SRO: ENSURE

CONTAINMENT ISOLATION

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 2

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Tuesday, August 23, 2011 Page 1 of 7

TASK:

000-055-05-01 RESPOND TO LOSS OF OFF SITE AND ON SITE POWER

TASK 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.

TERMINATING CUE: XVT-2662 A is closed and local operator reports IFV-4701B is closed.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: EOP-1.0 REACTOR TRIP/SAFETY INJECTION ACTUATION

INDEX NO. K/A NO. RO SRO

103000K102 K1.02 Containment isolation/containment 3.9 4.1

integrity

TOOLS: EOP-1.0, Attachment 3, Step 13-14. Attachment 4 and 5.

EVALUATION TIME 10 TIME CRITICAL NO 10CFR55: 45(a)3

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Tuesday, August 23, 2011 Page 2 of 7

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant has just experienced a LOCA and safety injection.

INITIATING CUES: The CRS directs verifying Phase "A" and Containment Ventilation

Isolation per EOP-1.0, Attachment 3, Step 13.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Tuesday, August 23, 2011 Page 3 of 7

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant has just experienced a LOCA and safety injection.

INITIATING CUES: The CRS directs verifying Phase "A" and Containment Ventilation

Isolation per EOP-1.0, Attachment 3, Step 13.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Tuesday, August 23, 2011

STEPS

STEP: 1

CUES:

CR SEQ STEP STANDARD:

No Yes Verifies Phase "A" and Containment Operator ensures Phase "A" Isolation by

Ventilation Isolation on XCP-6103, 6104 and appearance of phase "A" valve status

6106. REFER TO ATTACHMENT 4, lights on MCB XCP-6104, 6103 and

CONTAINMENT ISOLATION VALVE MCB 6106. Refers to Attachment 4. Notes

STATUS LIGHT LOCATIONS, as needed. RB AIR SERV ISOL 2662A(B) CLSD are

both dim. Also notes that SG B BLWDN

ISOL 503B CLSD and CDRM CLG WTR

(This is EOP-1.0 Att. 3 Step 13). ISOL 7501 CLSD are also both dim.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No Yes Actuates Phase A/Containment Ventilation Places either TRAIN A & B CS-

Isolation. 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.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

NOTE TO EVALUATOR: Placing 2662A RB AIR SERV ISOL to closed is the critical part of this

step.

CR SEQ STEP STANDARD:

Yes Yes Operator attempts to close 503B, 2662 A, Places the control switches (individually)

and 2662 B from the MCB valve control for 503B, 2662 A, and 2662 B to the

switches. "CLOSED" position. Notes 2662 A

closes but that the other valves still

indicate that they are open.

COMMENTS: SAT

UNSAT

Tuesday, August 23, 2011 Page 5 of 7

STEP: 4

CUES:

NOTE TO EVALUATOR: Steps 3, 4, and 5 should be performed in sequence.

CR SEQ STEP STANDARD:

No Yes Operator refers to Attachment 5 to identify Operator determines that IFV4701B is

backup isolation valve for XVG-503B the backup valve for XVG-503B. (Page 1

of Attachment 5).

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

NOTE: 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.

CR SEQ STEP STANDARD:

Yes Yes Directs AO to locally close IFV-4701B Uses plant page or radio to direct AB

lower to close IFV-4701B backup to

MVG-503B, STEAM GEN B

BLOWDOWN HEADER ISOL VALVE.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Tuesday, August 23, 2011 Page 6 of 7

JPM SETUP SHEET

JPM NO: JPSF-045B

DESCRIPTION: 2011 NRC Sim a RO & SRO: ENSURE CONTAINMENT ISOLATION

IC SET: 10

INSTRUCTIONS:

(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 correctly

Event 1: X021053A==1l X021054A==1

VLV-AC001P SEVERITY=0 RAMP=25 (XVT 7501A closes when Phase A initiated)

Event 2: X021407C==1

VLV-IA003P SEVERITY=100 DELETE= 01 (XVT-2662A is allowed to be closed)

MAL-RCS005A (Large break LOCA on 'A' loop)

2. RUN 120 Seconds

3. While running, trip RCP's and perform immediate action of EOP-1.0.

4. When student is ready:

RUN

5. 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".

Tuesday, August 23, 2011 Page 7 of 7

V.C. SUMMER NUCLEAR STATION

JPM NO: JPS-161

2011 NRC Sim b RO & SRO: BLOCK SOURCE

RANGE HI FLUX TRIP.

APPROVAL: RJ APPROVAL DATE: 9/3/2011

REV NO: 2

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Saturday, September 03, 2011 Page 1 of 8

TASK:

001-025-01-01 OPERATE CONTROL RODS MANUALLY AT POWER

TASK STANDARD:

Reactor power is increased and stabilized at 10-3% without causing a reactor trip.

TERMINATING CUE: Reactor power is stabilized at 10-3%.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES:

INDEX NO. K/A NO. RO SRO

015000A403 A4.03 Trip bypasses 3.8 3.9

TOOLS: GOP-3, REACTOR STARTUP FROM HOT STANDBY TO

STARTUP (MODE 3 TO MODE 2)

EVALUATION TIME 25 TIME CRITICAL NO 10CFR55: 55.45.b.6

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Saturday, September 03, 2011 Page 2 of 8

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

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.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Saturday, September 03, 2011 Page 3 of 8

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

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.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Saturday, September 03, 2011

STEPS

STEP: 1

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Establish a stable Startup Rate of less than Withdraws rods to establish a stable

one decade per minute. startup rate of less than one decade per

minute.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No Yes At 7.5x10-6%, perform the following: Verifies P6 energize to bright and a one

1) Verify P6 Permissive energizes to bright. decade overlap exists between source

2) Verify a minimum of one decade overlap and intermediate range power channels.

between Source Range Channels and

Intermediate Range Channels.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

CR SEQ STEP STANDARD:

Yes Yes Prior to 1E5 CPS, perform the following: Places SR TRAIN A Switch to BLOCK.

Momentarily place SR TRAIN A Switch in

BLOCK.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 5 of 8

STEP: 4

CUES:

CR SEQ STEP STANDARD:

No Yes Verify SR A TRIP BLCK Permissive Verifies SR A TRIP BLCK Permissive

energizes to bright. energizes to bright.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

Yes Yes Momentarily place SR TRAIN B Switch in Places SR TRAIN B Switch to BLOCK.

BLOCK.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

CR SEQ STEP STANDARD:

No Yes Verify SR B TRIP BLCK Permissive Verifies SR B TRIP BLCK Permissive

energizes to bright. energizes to bright.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 6 of 8

STEP: 7

CUES:

CR SEQ STEP STANDARD:

No Yes Perform one of the following for continued Selects one power range and one

monitoring of Intermediate and Power intermediate range channel on NR-45.

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.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

Yes Yes Stabilize Reactor Power at 10-3%. Inserts rods to stabilize power at 10-3%.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Saturday, September 03, 2011 Page 7 of 8

JPM SETUP SHEET

JPM NO: JPS-161

DESCRIPTION: 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:

Saturday, September 03, 2011 Page 8 of 8

V.C. SUMMER NUCLEAR STATION

JPM NO: JPSF-012A

2011 NRC Sim c RO: DROPPED ROD RECOVERY

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 8

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Saturday, September 03, 2011 Page 1 of 11

TASK:

000-003-05-01 RESPOND TO DROPPED CONTROL ROD

TASK 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.

TERMINATING CUE: Manual reactor trip inserted.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: AOP-403.6 DROPPED CONTROL ROD

INDEX NO. K/A NO. RO SRO

000003A102 AA1.02 Controls and components necessary to 3.6 3.4

recover rod

TOOLS: AOP-403.6 (TO RECORD AFFECTED BANK HEIGHTS and to

provide engineering numbers for limitations on rod withdrawal rates).

EVALUATION TIME 15 TIME CRITICAL No 10CFR55: 45(A)5

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Saturday, September 03, 2011 Page 2 of 11

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: CRS has directed NROATC to recover Control Rod "F2" per AOP-

403.6, starting with Step 11.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Saturday, September 03, 2011 Page 3 of 11

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: CRS has directed NROATC to recover Control Rod "F2" per AOP-

403.6, starting with Step 11.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Saturday, September 03, 2011

STEPS

STEP: 1

CUES:

PROCEDURE NOTE: Steps 11 through 15

Throughout 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".

CR SEQ STEP STANDARD:

No Yes Record Step Counter readings for both Step counter reading for both groups in

groups of the AFFECTED bank. Control Bank "A" have been recorded as

230 steps.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

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".

CR SEQ STEP STANDARD:

No Yes Record P/A Converter Reading. P/A Converter reading has been

recorded.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

CR SEQ STEP STANDARD:

Yes Yes Rotate ROD CNTRL BANK SEL Switch ROD CNTRL BANK SEL Switch has

clockwise to the AFFECTED bank position. been rotated clockwise to the CBA

position.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 5 of 11

STEP: 4

CUES:

Resetting Shutdown Bank A vs. Control Bank A constitutes a failure of this step if the error is not

detected and corrected before withdrawing the dropped rod.

CR SEQ STEP STANDARD:

Yes Yes Reset the Step Counter for the AFFECTED Momentarily depresses the RS

group to zero. pushbutton on the Step Counter for

Bank A GROUP 1. Notes the indication

is 000.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Place all Lift Coil Disconnect Switches for All lift coil disconnect switches for

the affected bank, except switches for the Control Bank "A" rods, except Rod "F2"

dropped rod, to the ROD DISCONNECTED have been placed in the ROD

position. DISCONNECTED position.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

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 realigned.

CR SEQ STEP STANDARD:

Yes Yes Withdraw the dropped rod: Drive the Rod F2 is moving in the outward

affected bank out. direction.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 6 of 11

STEP: 7

CUES:

CR SEQ STEP STANDARD:

No Yes Verify dropped rod movement on DRPI. DRPI indicator for rod "F2" in Control

Bank "A" is verified to be moving out in 6

step increments.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

No Yes When dropped rod moves 6 steps, then ONE ROD ON BOTTOM annunciator is

verify ONE ROD ON BOTTOM annunciator observed to be flashing (in the reset

clears. condition).

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

No turbine manipulations are required since Tavg will remain within 5°F of Tref.

CR SEQ STEP STANDARD:

No Yes Adjust turbine load to maintain Tavg within +/- Tavg - Tref within +/- 5°F.

5°F of Tref.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 7 of 11

STEP: 10

CUES:

CR SEQ STEP STANDARD:

Yes Yes Continue rod withdrawal to the demand Rod withdrawn at not more than 48

position. steps per minute or 80% power as

determined in step 6.

COMMENTS: SAT

UNSAT

STEP: 11

CUES:

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 by Examiner.

CR SEQ STEP STANDARD:

Yes Yes Observes that Rod F2 stops moving at 48 Notices that rod F2 is stuck and stops

steps and is apparently stuck. rod withdrawal before step counter

reads 62 steps. (Stopping at 61 or less

is satisfactory).

COMMENTS: SAT

UNSAT

STEP: 12

CUES:

CR SEQ STEP STANDARD:

No Yes Observes that Rod H2 drops into the core Evaluates as 2 dropped rods.

and rod F2 drops into the core as well.

COMMENTS: SAT

UNSAT

Saturday, September 03, 2011 Page 8 of 11

STEP: 13

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Inserts a manual reactor trip. Places 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.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Saturday, September 03, 2011 Page 9 of 11

JPM SETUP SHEET

JPM NO: JPSF-012A

DESCRIPTION: 2011 NRC Sim c RO: DROPPED ROD RECOVERY

IC SET: 11

INSTRUCTIONS:

(320 for 2011)

1. RUN

2. 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 = 0

4. 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. FREEZE

9. 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)

Saturday, September 03, 2011 Page 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, 2011 Page 11 of 11

V.C. SUMMER NUCLEAR STATION

JPM NO: JPS-002A

2011 NRC Sim d RO: TRANSFER TO HOT LEG

RECIRCULATION

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 4

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Tuesday, August 30, 2011 Page 1 of 9

TASK:

000-137-05-01 TRANSFER RHR FROM COLD LEG TO HOT LEG RECIRCULATION

TASK 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.

TERMINATING CUE: 'B' charging pump is started.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: EOP-2.0 LOSS OF REACTOR OR SECONDARY COOLANT

EOP-2.3 TRANSFER TO HOT LEG RECIRCULATION

INDEX NO. K/A NO. RO SRO

006000A402 A4.02 Valves 4.0 3.8

006000K418 K4.18 Valves normally isolated from their 3.6 3.7

control power

TOOLS: EOP-2.3

EVALUATION TIME 10 TIME CRITICAL No 10CFR55: 45(a)7

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Tuesday, August 30, 2011 Page 2 of 9

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: It has been 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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.

INITIATING CUES: The CRS directs the NROATC to transfer from Cold Leg to Hot Leg

Recirculation per EOP-2.3.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Tuesday, August 30, 2011 Page 3 of 9

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION: It has been 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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.

INITIATING CUES: The CRS directs the NROATC to transfer from Cold Leg to Hot Leg

Recirculation per EOP-2.3.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Tuesday, August 30, 2011

STEPS

STEP: 1

CUES:

Procedure 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 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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 failing.

CR SEQ STEP STANDARD:

Yes Yes Align Train A Charging Pumps for Hot Leg Places CHG/SI Pump 'A' control switch

Recirculation: to STOP and verifies CHG/SI Pump 'A'

Stop the Charging Pump on "A" Train indicates OFF.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No Yes Check if CHG/SI Pump C is aligned to Train XFER SWITCH XET 2002C on Train A

A by verifying XFER switch XET 2002C ON is not lit, goes to alternative action.

TRAIN A IS LIT.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

CR SEQ STEP STANDARD:

No Yes Ensure MVG-8132A and MVG-8132B, CHG Verifies MVG-8132A and MVG-8132B

PP C TO LP A DISCH are closed. CHG PP C TO LP A DISCH are closed,

verifying green light ON and red light is

OFF for each valve.

COMMENTS: SAT

UNSAT

Tuesday, August 30, 2011 Page 5 of 9

STEP: 4

CUES:

CR SEQ STEP STANDARD:

Yes Yes Close charging LP "A" ALT to COLD LEG MVG-8885, CHG LP A TO COLD LEGS,

(MVG-8885). indicates CLOSE.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

Examiner Note: Candidate must energize power lockout to change the position of MVG-8884

CR SEQ STEP STANDARD:

Yes Yes Open CHG LP "A" to HOT LEGS (MVG- MVG-8884, CHG LP A TO HOT LEGS,

8884). indicates OPEN.

COMMENTS: SAT

UNSAT

STEP: 6

CUES:

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 psig.

CR SEQ STEP STANDARD:

Yes Yes Start "A" Charging Pump. Places CHG/SI Pump 'A control switch

to START and verifies CHG/SI PUMP

"A" indicates ON with normal running

amps.

COMMENTS: SAT

UNSAT

Tuesday, August 30, 2011 Page 6 of 9

STEP: 7

CUES:

CR SEQ STEP STANDARD:

Yes Yes Align Train B Charging Pumps for Hot Leg Places CHG/SI Pump 'B control switch

Recirculation: to STOP and verifies CHG/SI Pump 'B'

Stop "B" charging pump. indicates OFF with 0 amps.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

CR SEQ STEP STANDARD:

No Yes Check if 'C' charging pump is aligned to Verifies XFER SWITCH XET2000C ON

Train B. TRAIN B is lit.

COMMENTS: SAT

UNSAT

STEP: 9

CUES:

CR SEQ STEP STANDARD:

No Yes Ensure MVG-8132A and MVG-8132B, CHG Ensures MVG-8132A and MVG-8132B,

PP C TO LP A DISCH, are closed. CHG PP C TO LP A DISCH, indicate

CLOSED.

COMMENTS: SAT

UNSAT

STEP: 10

CUES:

CR SEQ STEP STANDARD:

No Yes Ensure MVG-8801A, HI HEAD to COLD MVG-8801A, HI HEAD TO COLD LEG

LEG INJECTION, is closed. INJ indicates CLOSED.

COMMENTS: SAT

UNSAT

Tuesday, August 30, 2011 Page 7 of 9

STEP: 11

CUES:

Examiner Note: If 8801B is closed with "B" Charging Pump running, this deadheads the pump and

constitutes failure of the JPM.

CR SEQ STEP STANDARD:

Yes Yes Close MVG-8801B, HI HEAD TO COLD Takes control switch for MVG-8801B, HI

LEG INJECTION valve. HEAD TO COLD LEG INJ, to the closed

position, checks red light OFF and green

light ON.

COMMENTS: SAT

UNSAT

STEP: 12

CUES:

Examiner Note: Candidate must energize power lockout to change the position of MVG-8886

CR SEQ STEP STANDARD:

Yes Yes Open MVG-8886,CHG LP B TO HOT LEGS. MVG-8886, CHG LP B TO HOT LEGS,

indicates OPEN.

COMMENTS: SAT

UNSAT

STEP: 13

CUES:

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 psig.

CR SEQ STEP STANDARD:

Yes Yes Start "B" CHG/SI pump. Places CHG/SI Pump 'B control switch

to START and verifies CHG/SI Pump 'B'

indicates ON with normal running amps.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Tuesday, August 30, 2011 Page 8 of 9

JPM SETUP SHEET

JPM NO: JPS-002A

DESCRIPTION: 2011 NRC Sim d RO: TRANSFER TO HOT LEG RECIRCULATION

IC SET: 10

INSTRUCTIONS:

(323 for 2011)

1. Activate

MAL-RCS005A RCS Loop 'A' DBA LOCA

2. RUN

3. Perform actions of EOP-1.0 and 2.0

4. FREEZE

5. Ensure RHR Sump Level >415', then activate LOA-AUX115 SEVERITY=0.17 (17% in RWST)

6. RUN

7. 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 fast

9. Swap C Charging pump to B Train

LOA CVC045 Charging pump C disconnect switch SELECT= TRAIN B.

10. FREEZE

11. When student is ready:

RUN

COMMENTS:

Charging Pumps must be stopped before opening Hot Leg High Head Valves (8884/8886) to prevent

pump runout.

Tuesday, August 30, 2011 Page 9 of 9

V.C. SUMMER NUCLEAR STATION

JPM NO: JPSF-007

2011 NRC Sim e RO: STEAM GENERATOR TUBE

RUPTURE (DEPRESSURIZE RCS TO <

RUPTURED S/G PRESSURE)

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 15

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Tuesday, August 30, 2011 Page 1 of 8

TASK:

000-038-05-01 RESPOND TO STEAM GENERATOR TUBE RUPTURE

TASK 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"

TERMINATING CUE: RCS depressurization complete when task standard met and PCV-444C &

D are closed.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: EOP-4.0 STEAM GENERATOR TUBE RUPTURE

INDEX NO. K/A NO. RO SRO

000038A104 EA1.04 PZR spray, to reduce coolant system 4.3 4.1

pressure

TOOLS: EOP-4.0

EVALUATION TIME 10 TIME CRITICAL No 10CFR55: 45(a)6

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Tuesday, August 30, 2011 Page 2 of 8

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: Control Room Supervisor directs operator to depressurize the RCS

using PZR Spray, per EOP-4.0, Step 22.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Tuesday, August 30, 2011 Page 3 of 8

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: Control Room Supervisor directs operator to depressurize the RCS

using PZR Spray, per EOP-4.0, Step 22.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Tuesday, August 30, 2011

STEPS

STEP: 1

CUES:

Examiner Note: Give examinee 1-2 minutes to familiarize himself with his control board indications

and his place in the procedure.

CR SEQ STEP STANDARD:

Yes Yes Depressurize the RCS using normal spray Places PZR Spray PVC-444C & 444D

valves PCV-444C and 444D. controllers in MANUAL and increases

output to 100% demand. Verifies red

light ON and green light OFF for both

PCV-444C & D.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

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

terminating on either one is satisfactory.

CR SEQ STEP STANDARD:

No Yes Use maximum available spray until any Recognizes from MCB indication that

termination criteria is met; RCS pressure < RCS pressure is less than 'C' S/G

Ruptured ('C') S/G pressure and PZR level > pressure with PZR level >10% or PZR

10%; or PZR level >76%; or RCS level >76%, or RCS subcooling <52.5°F.

subcooling <52.5°F.

COMMENTS: SAT

UNSAT

STEP: 3

CUES:

Examiner Note: The critical part of this step is closing PCV-444C.

CR SEQ STEP STANDARD:

Yes Yes Stop RCS depressurization. Decreases PCV-444C & 444D controller

output demand to zero. Notes that PCV-

444D did not go closed.

COMMENTS: SAT

UNSAT

Tuesday, August 30, 2011 Page 5 of 8

STEP: 4

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Identify failure of PCV-444D to close and 'A' RCP tripped to stop

secures 'A' RCP. depressurization. Also stops either 'B'

RCP or 'C' RCP if pressure continues to

decrease.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

CR SEQ STEP STANDARD:

No Yes Close PVT-8145, PZR SPRAY FR CVCS. Verifies PVT-8145 green light ON and

red light OFF.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Tuesday, August 30, 2011 Page 6 of 8

JPM SETUP SHEET

JPM NO: JPSF-007

DESCRIPTION: 2011 NRC Sim e RO: STEAM GENERATOR TUBE RUPTURE

(DEPRESSURIZE RCS TO < RUPTURED S/G PRESSURE)

IC SET: 10

INSTRUCTIONS:

(324 for 2011)

1. Activate

MAL-RCS002C SEVERITY=450 RAMP=30 (S/G Tube Rupture on 'C' S/G)

2. RUN

3. 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. FREEZE

7. 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. FREEZE

11. When student is ready:

RUN

12. 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 > 0.9

COMMENTS:

This JPM can be run from the same snap as JPS007 with the addition of MAL-PRS003B = 100%

Tuesday, August 30, 2011 Page 7 of 8

Tuesday, August 30, 2011 Page 8 of 8

V. C. SUMMER NUCLEAR $TA TION

JPMNO: JPS-042

2011 NRC Sim f RO: IDENTIFY AND ISOLATE RCS

LEAK TO CCW SYSTEM

APPROVAL: DOW APPROVAL DATE: 7/3/2007

REVNO: 9

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Saturday, September 03, 2011 Page 1 of 14

TASK:

344-00 1-03-02 ANALYZE INDICATIONS TO DETERMINE THAT ABNORMAL PLANT

EVENT IS IN PROGRESS

TASK STANDARD:

Intersystem leakage stopped by isolating letdown per ARP-019-XCP-644, pt 1-3.

TERMINATING CUE: Letdown Isolated

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: ARP-01 9-XCP-644 RADIATION MONITORING PANEL

INDEX NO. K/A NO. RO SRO

008000A204 A2.04 PRMS alarm 3.3 3.5

TOOLS: ARP-019-XCP-644-1-3, CC LOOP A RM-L2A HI RAD

SOP-102, CHEMICAL AND VOLUME CONTROL SYSTEM

EVALUATION TIME 20 TIME CRITICAL No 1OCfRS5: 45(a)7

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Saturday, September 03, 2011 Page 2 of 14

INSTRUCTIONS To OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant is operating at 100% power with all systems in Automatic.

INITIATING CUES: CRS directs NROATC to respond to RM-L2A HI RAD annunciator.

HAND JPM BRIEFING SHEET TO OPERA TOR AT THIS TIME!

Saturday, September 03, 2011 Page 3 of 14

1PM BRIEFING SHEET

OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant is operating at 100% power with all systems in Automatic.

INITIATING CUES: CRS directs NROATC to respond to RM-L2A HI RAD annunciator.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Saturday, September 03, 2011

STEPS

STEP: I

CUES:

aatorNot at any me the candkiate HicHcates that they wilT transftion to AOP-iOi. 1, LOSS

10F REACTOR COOLANT NOT REQUIRING SI, cue the candidate that the actions of AOP-1O1.1

will beer1ormedbyanotheroerator.

CR SEQ STEP STANDARD:

No Yes Verify automatic action has occurred. Verifies PVV-7096, CC SURGE TK VLV,

is closed.

COMMENTS: SAT

UNSA T

STEP: 2

CUES:

CR SEQ STEP STANDARD:

No No Verify high radiation via COMPONENT Identifies COMPONENT COOLING

COOLING LIQUID MONITORS on XCP-644 LIQUID MONITORS RML-2A

RADIATION MONITORS meters and

R/R-5 trending up and are above high

alarm setpoint on XCP-644.

COMMENTS: SAT

UNSA T

STEP: 3

CUES:

Booth Operator When caNed to survey the CCW system, respondthat there are eTevated - - -

.reanas downstream of TCV-144 and that a other points are at normal radiation levels.

CR SEQ STEP STANDARD:

No Yes Notify Health Physics personnel to survey Instruct Health Physics personnel to

CCW system. check radiation levels in CCW system in

the areas of letdown heat exchanger,

RCS and PZR sample coolers, RCP

Thermal Barrier lines, Excess Letdown

Heat Exchanger for abnormal radiation

levels.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 PageS of 14

STEP: 4

CUES:

Booth Operator When called to sample CCW, respond that sarneswW be taken.

Evaluator Note: The sample analysis will take longer than the length of the JPM and so no results

will be reoorted. I

I

CR SEQ STEP STANDARD:

No Yes Notify Chemistry to sample CCW. Notifies Chemistry to sample CCW

system.

COMMENTS: SAT

UNSA T

STEP: 5

CUES:

Evakiator Note: The candate may not need to investigate flow if the leaocaon is determined

to be the letdown heat exchanr.

CR SEQ STEP STANDARD:

No No Monitor CCW flow and temperatures on Checks CCW flows and CCW

M2CC temperatures from RCP A, RCP B, RCP

C thermal barrier by depressing the

appropriate pushbutton point readouts

on M2CC and verifies points TM-7140

and FM-7138 for RCP A, TM-7160 and

FM-7158 for RCP B and TM-7180 and

RM-7178 for RCP C read in the normal

range for thermal barrier return to CCW

COMMENTS: SAT

UNSA T

STEP: 6

CUES:

CR SEQ STEP STANDARD:

No Yes Isolate the source of in leakage when NROATC announces leak is in letdown

confirmed by sample analysis or a heat exchanger from MCB and reactor

radiological makeup system indications and survey

survey, results.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 6 of 14

STEP: 7

CUES:

When examinee determines leak in the Tetdown heat exchanger, the CRS dects the NROATC

,to perform the ARP actions to isolate the leakage from the letdown heat exchanger.

Cue candidate that Pre-Job Brief can be waived, and the RCDT is aligned for normal operation.

Examiner Note: 1.3 is met because the ARP requires excess letdown. Note 2 is met because

1simulator is below 2898MWt.

CR SEQ STEP STANDARD:

No Yes Places excess letdown in service per SOP- Checks initial conditions and procedure

102. Note 2.0 to place excess letdown in

service.

1.1 A Pre-Job Brief has been

conducted per OAP-100.3, Human

Performance Tools.

1.2 The RCDT is aligned for normal

operation per SOP-108, Liquid Waste

Processing System.

1.3 RCS heatup is in progress or

increased Letdown is required.

NOTE 2.0: Due to the heat loss

generated not being an input to the

calorimetric thermal power calculation,

Core Power should be maintained at

less than or equal to 2898 MWt prior to

and during Excess Letdown operations.

COMMENTS: SAT

UNSA T

STEP: 8

CUES:

CR SEQ STEP STANDARD:

No Yes Verify flow on Fl-7106, XS LTDN HX FLOW. Verifies flow on FI-7106, XS LTDN HX

FLOW.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 7 of 14

STEP: 9

CUES:

CR SEQ STEP STANDARD:

No Yes Ensure HCV-137, XS LTDN HX, is closed. Verifies controller is fully turned counter

clockwise.

COMMENTS: SAT

UNSA T

STEP: 10

CUES:

aminer Note: This step is desi9pated as reqLng a eer check.

CR SEQ STEP STANDARD:

No Yes Places PVM-8143, XS LTDN TO VCT OR Takes PVM-8143 to the RCDT position.

RCDT to the RCDT position.

COMMENTS: SAT

UNSA T

STEP: 11

CUES:

CR SEQ STEP STANDARD:

No Yes If required, reset Phase A Isolation by Identifies that Phase A is not actuated.

depressing the following:

a. RESET PHASE A TRAIN A CNTMT

-

ISOL

b. RESET PHASE A TRAIN B CNTMT

-

ISOL

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 8 of 14

STEP: 12

CUES:

CR SEQ STEP STANDARD:

No Yes Ensure MVG-9583, FROM XS LTDN HX, is Verifies MVG-9583, FROM XS LTDN

open. HX, is open.

COMMENTS: SAT

UNSA T

STEP: 13

CUES:

CR SEQ STEP STANDARD:

No Yes Open PVT-8153, XS LTDN ISOL. Takes PVT-8153, XS LTDN ISOL, to

open.

COMMENTS: SAT

UNSA T

STEP: 14

CUES:

CR SEQ STEP STANDARD:

No Yes Open PVT-8154, XS LTDN ISOL. Takes PVT-8154, XS LTDN ISOL, to

open.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 9 of 14

STEP: 15

CUES:

Procedure Note Z&When sendig Excess Letdown tothe RCDT, RCDTTeveI pirp

1operation should be monitored locally at XPNOO7, WASTE PROCESSING/BORON RECYCLE

100NT PNL (AB-412)

Booth Operator: When called to monitor RCDT level and pump operation respond that you are at

1the 2anel If called later report that the RCDT Pump is peraUnaas requhed to controHev&.

CR SEQ STEP STANDARD:

No No Establish Excess Letdown flow as follows: Slowly throttles open HCV-137 and

a. Slowly throttle open HCV-137, XS LTDN monitors TI-139.

HX.

b. Monitor Tl-139, XS LETDOWN HX OUT

TEMP °F, to maintain less than 165 F.

COMMENTS: SAT

UNSA T

STEP: 16

CUES:

Procedure Note 2.9: The design flowrate for the Excess Letdown Heat Exchanger is 25 gpm. -

1Flushing for ten minutes at this flowrate will result in an 18% change in VCT level and is equivalent1

1to 70% of RCDT volume.

Cue candkiate that 10 minutes have elajsecL

CR SEQ STEP STANDARD:

No Yes Flush Excess Letdown to the RCDT for ten Determines that excess letdown must be

minutes. flushed for 10 minutes.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 10 of 14

STEP: 17

CUES:

CR SEQ STEP STANDARD:

No Yes When flush is complete and Excess Verifies MVT-8100, SEAL WTR RTN

Letdown flow is to diverted to the VCT, open ISOL, is open.

the following:

a. MVT-8100, SEAL WTR RTN ISOL.

COMMENTS: SAT

UNSA T

STEP: 18

CUES:

CR SEQ STEP STANDARD:

No Yes Open MVT-81 12, SEAL WTR RTN ISOL. Verifies MVT-81 12, SEAL WTR RIN

ISOL, is open.

COMMENTS: SAT

UNSA T

STEP: 19

CUES:

Procedure Note 2i 1: Excess Letdown shoid normally be dhected to the VCT. If requed,

1Excess Letdown may be aligned to the RCDT.

ExarninerNot This step is desinated as requirhig a eer check.

CR SEQ STEP STANDARD:

No Yes Place PVM-8 143, XS LTDN TO VCT OR Takes switch for PVM-8143, XS LTDN

RCDT, to VCT. TO VCT OR RCDT, to VCT.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 11 of 14

STEP: 25

CUES:

CR SEQ STEP STANDARD:

No Yes Monitors FR-154A, RCP SL LKOFF HI Ensures flow between 0.2 gpm and 5.0

RANGE and FR-154B, RCP SL LKOFF LO gpm.

RANGE.

COMMENTS: SAT

UNSA T

STEP: 26

CUES:

lsolation of tdown flow path by cng LCV-456, LCV-460, PVT-81 52 or all 8149 vves - -

1sufficienttoaccornphshtask.

CR SEQ STEP STANDARD:

Yes Yes Closes PVT-8149A (B, C), LCV-460, LCV- PVT-8149 A (B,C) LTDN ORIFICE A

459 and PVT-8152. (B,C) ISOL and LCV-459, LCV-460 and

PVT-8 152 LTDN LINE ISOL are taken to

close.

COMMENTS: SAT

UNSA T

STEP: 27

CUES:

Evaftiator Not Candidate may place CO PRESS LTDN PCV-145NM staon in MANUAL and -

reduce the outut to zero as well.

CR SEQ STEP STANDARD:

No Yes Close PCV-145, CO PRESS LTDN. Verifies that PCV-145 is closed.

COMMENTS: SAT

UNSA T

Saturday, September 03, 2011 Page 12 of 14

STEP: 28

CUES:

CR SEQ STEP STANDARD:

No Yes Close FCV-122, CHG FLOW. Places CHG FLOW FCV-122 NM

station in MANUAL and reduces output

to zero.

COMMENTS: SAT

UNSA T

STEP: 29

CUES:

EvahjatorNote HCV-186 does not have T0 be adjuste but candate may call to align air to HCV

1186 so that future adjustments may be made.

1Booth Operator If called to alin air to HCV-1 86, J FLOW, use the LOA Resets to do so.

CR SEQ STEP STANDARD:

No Yes Adjusts HCV-186, NJ FLOW, to maintain 6- Determines that HCV-186, INJ FLOW,

13 gpm per pump potentiometer does not need to be

adjusted to keep RCP NB/C INJ FLOW

GPM (IFI-130N127N124A) between 6

and 13 gpm.

COMMENTS: SAT

UNSA T

Examiner ends JPM at this point.

Saturday, September 03, 2011 Page 13 of 14

JPM SETUP SHEET

JPMNO: JPS-042

DESCRIPTION: 2011 NRC Sim f RO: IDENTIFY AND ISOLATE RCS LEAK TO CCW SYSTEM

IC SET:

INSTRUCTIONS:

(319 for 2011)

1. MAL-CCWOO1 Severity3o Ramp=7 minutes. (RCS to CCW leak in letdown HEX)

Set to Event Trigger #1.

2. RUN: Activate Trigger #1.

3. Ensure power is <2898 MWt.

4. When the student is ready go to run.

COMMENTS:

Based on the Initiating cue, the trigger is activated before going to run. The cue reads as it does to

steer the examinee away from wanting to respond to the RCS leak by wanting to enter AOP-101.1,

LOSS OF REACTOR COOLANT NOT REQUIRING SI, but a separate cue is included to ensure the

student does not go to AOP-101.1.

Saturday, September 03, 2011 Page 14 of 14

V.C. SUMMER NUCLEAR STATION

JPM NO: JPS-149A

2011 NRC Sim g RO: RESPONSE TO STEAM

GENERATOR OVERPRESSURE IAW EOP-15.3

APPROVAL: RJ APPROVAL DATE: 7/30/2011

REV NO: 4

CANDIDATE:

EXAMINER:

THIS JPM IS APPROVED

Friday, September 02, 2011 Page 1 of 10

TASK:

311-006-06-01 RESPONSE TO LOSS OF SECONDARY HEAT SINK

TASK STANDARD:

S/G pressures has been lowered to <1170 psig

TERMINATING CUE: S/G pressures are returned to normal.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOD

SIMULATOR PERFORM

REFERENCES: EOP-15.3 RESPONSE TO LOSS OF NORMAL STEAM RELEA

CAPABILITIES

INDEX NO. K/A NO. RO SRO

0410002120 2.1.20 Ability to interpret and execute 4.6 4.6

procedure steps.

TOOLS: EOP-15.3

EVALUATION TIME 10 TIME CRITICAL NO 10CFR55: 55.45.b.6

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

EXAMINER:

SIGNATURE DATE

Friday, September 02, 2011 Page 2 of 10

INSTRUCTIONS TO OPERATOR

READ TO OPERATOR:

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.

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The CRS directs you to implement EOP-15.3.

HAND JPM BRIEFING SHEET TO OPERATOR AT THIS TIME!

Friday, September 02, 2011 Page 3 of 10

JPM BRIEFING SHEET

OPERATOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

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.

INITIATING CUES: The CRS directs you to implement EOP-15.3.

HAND THIS PAPER BACK TO YOUR

EVALUATOR WHEN YOU FEEL THAT YOU

HAVE SATISFACTORILY COMPLETED THE

ASSIGNED TASK.

Friday, September 02, 2011

STEPS

STEP: 1

CUES:

CR SEQ STEP STANDARD:

No Yes CAUTION Reads caution and note.

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.

COMMENTS: SAT

UNSAT

STEP: 2

CUES:

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.

CR SEQ STEP STANDARD:

No Yes Verify PERMISV C-9 status light is bright on Operator locates and verifies C-9 is

XCP-6114 1-3. bright on XCP-6114 1-3.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 5 of 10

STEP: 3

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Verify the MS Isolation Valves, PVM- Determines that MS Isolation Valves,

2801A(B)(C), are open. PVM-2801A(B)(C), are closed.

OR Depresses both MAIN STEAM ISOL

Open MS Isolation Bypass Valves: VALVES RESET TRAIN A(B).

1) Depress both MAIN STEAM ISOL Opens MS Isolation Bypass Valves,

VALVES RESET TRAIN A(B). PVM-2869A(B)(C) and verifies red light

2) Open MS Isolation Bypass Valves, PVM- lit green light dim.

2869A(B)(C).

COMMENTS: SAT

UNSAT

STEP: 4

CUES:

CR SEQ STEP STANDARD:

No Yes Place the STM DUMP CNTRL Controller in Operator locates and places STM

MAN and closed. DUMP CNTRL Controller in MAN and

closed.

COMMENTS: SAT

UNSAT

STEP: 5

CUES:

NOTE: IC was snapped with controller already at 8.4.

CR SEQ STEP STANDARD:

No Yes Ensure the STM DUMP CNTRL Controller is STM DUMP CNTRL Controller is set to

set to 8.4 (1090 psig). 8.4 (1090 psig).

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 6 of 10

STEP: 6

CUES:

CR SEQ STEP STANDARD:

No Yes Place the STM DUMP MODE SELECT STM DUMP MODE SELECT Switch is

Switch in STM PRESS. in STM PRESS.

COMMENTS: SAT

UNSAT

STEP: 7

CUES:

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.

CR SEQ STEP STANDARD:

Yes Yes Place the STM DUMP CNTRL Controller in STM DUMP CNTRL Controller is in

AUTO. AUTO.

COMMENTS: SAT

UNSAT

STEP: 8

CUES:

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 longer exists to EOP-15.3.

CR SEQ STEP STANDARD:

No Yes Verify Condenser Steam Dumps are open. Determines proper operation of steam

dumps.

COMMENTS: SAT

UNSAT

Friday, September 02, 2011 Page 7 of 10

STEP: 9

CUES:

CR SEQ STEP STANDARD:

No Yes Verify SG pressures are LESS THAN 1170 Determines that all steam generator

psig. pressures are now <1170 psig.

COMMENTS: SAT

UNSAT

Examiner ends JPM at this point.

Friday, September 02, 2011 Page 8 of 10

JPM SETUP SHEET

JPM NO: JPS-149A

DESCRIPTION: 2011 NRC Sim g RO: RESPONSE TO STEAM GENERATOR

OVERPRESSURE IAW EOP-15.3

IC SET: 10

INSTRUCTIONS:

(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 =10.0

OVR-MB006B, PC-2010 STM DMP LINE B POT SIGNAL =10.0

OVR-MB007B, PC-2020 STM DMP LINE C POT SIGNAL =10.0

Overrides Pots so that steamline porv's do not open enough to lower pressure.

BST-MS054, ILS02806A REL VLV MS = INHIBITED

BST-MS055, ILS02806B REL VLV MS = INHIBITED

BST-MS059, ILS02806F REL VLV MS = INHIBITED

BST-MS060, ILS02806G REL VLV MS = INHIBITED

BST-MS064, ILS02806K REL VLV MS = INHIBITED

BST-MS065, ILS02806L REL VLV MS = INHIBITED

Overrides 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 START

PMP-EF002F, MOTOR DRIVEN EFW PMP B FAIL TO START

Ensure that the snap is generated fast enough to ensure that C-9 remains bright.

FREEZE

When 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.

Friday, September 02, 2011 Page 9 of 10

Friday, September 02, 2011 Page 10 of 10

V.C. SUMMER NUCLEAR STATION