Text

2015-09 Final Operating Test
	ML15278A231
Person / Time
Site:	Waterford
Issue date:	09/14/2015
From:	Vincent Gaddy; Operations Branch IV
To:	; Entergy Operations
References
	Download: ML15278A231 (327)
	v • d • e

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Waterford 3 Date of Examination: 9/14/2015 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic Type Describe activity to be performed (see Note) Code*

A1 2.1.25, Ability to interpret reference materials, such as graphs, curves, tables, etc.

Conduct of Operations Determine Spent Fuel Pool (SFP) level by alternate N, R monitoring and calculate time to reach 212°F in the SFP per K/A Importance: 3.9 OP-901-513, SFP Cooling Malfunction.

A2 2.1.18, Ability to make accurate, clear, and concise logs, records, status boards, and reports.

Conduct of Operations Perform OP-903-001, Technical Specification Surveillance D,R Logs, Attachment 11.18, Adjustment of CPC and Excore K/A Importance: 3.6 Nuclear Instrumentation Data.

A3 2.2.12, Knowledge of surveillance procedures.

Equipment Control Determine Acceptability of Containment Temperature in P,D,R accordance with OP-903-001, Technical Specification Surveillance Logs, Attachments 11.1 and 11.20.

K/A Importance: 3.7 (From 2012 NRC Exam)

A4 2.3.4, Knowledge of radiation exposure limits under normal and emergency conditions.

Radiation Control D,R Calculate stay time to perform a tagout verification. Room dose rate and operators yearly dose provided K/A Importance: 3.2 Emergency Plan Not Selected NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected) 2015 NRC Revision 0

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Waterford 3 Date of Examination: 9/14/2015 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic Type Describe activity to be performed (see Note) Code*

A5 2.1.20, Ability to interpret and execute procedure steps.

Conduct of Operations Perform SM/CRS review of OP-901-501, PMC or Core D,R Operating Limit Supervisory System Malfunction, Attachments 1, 2 and 3 following a PMC failure.

K/A Importance: 4.6 A6 2.1.18, Ability to make accurate, clear, and concise logs, records, status boards, and reports.

Conduct of Operations D,R Review and approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC K/A Importance: 3.8 and Excore Nuclear Instrumentation Data.

A7 2.2.12, Knowledge of Surveillance Procedures Equipment Control Review a completed Containment Pressure calculation in P,D,R accordance with OP-903-001, Technical Specification K/A Importance: 4.1 Surveillance Logs, Attachment 11.5, Containment Pressure Calculation.

(From 2012 NRC Exam)

A8 2.3.11, Ability to Control Radiation Releases.

Radiation Control Terminate release after review of OP-903-001, Technical N,R Specification Surveillance Logs, Attachment 11.6, Containment Purge Cumulative Hours Calculation.

K/A Importance: 4.3 A9 2.4.41, Knowledge of the emergency action level thresholds Emergency Plan and classifications.

N,R Determine appropriate Emergency Plan EAL.

K/A Importance: 4.6 NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected) 2015 NRC Revision 1

Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A1 Determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction Applicant:

Examiner:

JPM A1 JOB PERFORMANCE MEASURE DATA PAGE Task: Determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction Task Standard: Determined Spent Fuel Pool (SFP) level by alternate monitoring and calculated time to boil in the SFP per OP-901-513, SFP Cooling Malfunction.

References:

OP-901-513, revision 14 Alternate Path: No Time Critical: No Validation Time: 10 mins.

K/A 2.1.25 Ability to interpret reference materials, Importance Rating 3.9 such as graphs, curves, tables, etc. RO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 6 2015 RO NRC Exam

JPM A1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-513, revision 14

==

Description:==

This JPM requires the applicant to determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to reach 212°F in the SFP per OP-901-513, SFP Cooling Malfunction READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 6 2015 RO NRC Exam

JPM A1 Evaluator Note The applicant will determine Spent Fuel Pool (SFP) level by alternate monitoring and calculate time to boil in the SFP per OP-901-513, SFP Cooling Malfunction. (all required data to perform the two calculations is supplied on the cue sheet)

TASK ELEMENT 1 STANDARD Determines Spent Fuel Pool level using the data provided on the applicant cue sheet along with the guidance and table located in Attachment 2 of 42.7 feet OP-901-513, Spent Fuel Pool Cooling Malfunction.

Comment: Critical The applicant will use Spent Fuel Pool temperature and suction pressure from Fuel Pool Pump A to determine Spent Fuel Pool level in accordance SAT / UNSAT with the table in Attachment 2, Alternate SFP Parameter Monitoring.

Note:

TASK ELEMENT 2 STANDARD Determines time to reach 212°F in the Spent Fuel Pool using the data provided on the applicant cue sheet along with the curves provided in 55 to 58 hours6.712963e-4 days 0.0161 hours 9.589947e-5 weeks 2.2069e-5 months of OP-901-513, Spent Fuel Pool Cooling Malfunction.

Comment: Critical The applicant will use Spent Fuel Pool temperature, knowledge of the SFP gates removed, and the date provided in the cue sheet to determine SAT / UNSAT time to reach 212°F in the SFP using Graph B in Attachment 3, Spent Fuel Pool Level Graphs.

The applicant will interpolate between the 110 and 120 °F lines and the time since the last refueling shutdown to determine the correct answer.

END OF TASK Revision 0 Page 4 of 6 2015 RO NRC Exam

JPM A1 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 5 of 6 2015 RO NRC Exam

JPM A1 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The date is 9/10/2015 The crew has entered OP-901-513, Spent Fuel Pool Cooling Malfunction A loss of AC power has rendered Fuel Pool Pumps and Fuel Pool level annunciators in the Control Room unavailable and SFP level cannot be monitored locally on the FHB +46.

SFP level is not below the suction of the Fuel Pool Pumps and the FHB +46 area is not pressurized.

The Spent Fuel Pool Gates are removed.

Spent Fuel Pool temperature is 115°F.

The suction pressure reading from FS-102A (Fuel Pool Pump A suction drain) is 17.9 psig.

INITIATING CUES:

The CRS directs you to determine Spent Fuel Pool level by alternate monitoring and calculate time to reach 212°F in the Spent Fuel Pool per OP-901-513, SFP Cooling Malfunction.

Document the results on this cue sheet.

Spent Fuel Pool level: _______________

Time to reach 212°F: _______________

Revision 0 Page 6 of 6 2015 RO NRC Exam

Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE A2 Perform OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Applicant:

Examiner:

JPM A2 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Task Standard: Applicant correctly calculates new values for Core Protection Calculator constants KCAL, TCREF, and TPC in accordance with OP-903-001, Technical Specification Surveillance Logs.

References:

OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 2.1.18 Ability to make accurate, clear, and Importance Rating 3.6 concise logs, records, status boards, and RO reports.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 6 2015 NRC Exam

JPM A2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data

==

Description:==

Applicant will use given values for PMC and Core Protection Calculator B to input data and calculate CPC constants KCAL, TCREF, and TPC. The procedure has provisions to collect 5 sets of data and average them over a 5 minute period, but it is optional at the supervisors request. The applicants will not have to collect 5 sets of data. The applicants will not have to change the constants, just perform the calculations.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 6 2015 NRC Exam

JPM A2 TASK ELEMENT 1 STANDARD Student must record values given in Complete OP-903-001, Attachment 11.18 according to key. correct places and Determine new values correctly for KCAL, TCREF, and TPC.

Comment: Critical Data entry and calculations are displayed on the key.

Information that would be N/A is not critical. SAT / UNSAT END OF TASK Revision 0 Page 4 of 6 2015 NRC Exam

JPM A2 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 5 of 6 2015 NRC Exam

JPM A2 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

1. COLSS is Operable.

2. The UFM is in service.

3. The plant is at steady state operation.

4. Channel B CPC and applicable PMC readings are as follows:

TPC, CPC PID 064 = 0.84399 KCAL, CPC PID 065 = 1.0070 PCALIB, CPC PID 104 = 100 TC 1, CPC PID 160 = 543.59 TC 2, CPC PID 161 = 543.46 PHICAL, CPC PID 171 = 99.96 BDT, CPC PID 177 = 99.82 TCORF, CPC PID 180 = 0.99902 BSCAL, C24230 = 99.87 BDELT, C24104 = 99.78 BTSFP, C24101 = 99.50 INITIATING CUES:

The CRS directs you to complete the following calculations for Channel B on 1.18:

step 11.10.6 for KCAL and TCREF step 11.10.7 for TPC Linear potentiometer data collection is not required for this task.

Data collection from CP-10 is not required for this task.

The CRS directs you to fill in required data once for column 0, averaging columns 0 through 4 is not required.

This task is complete when you reach step 11.10.8.

Revision 0 Page 6 of 6 2015 NRC Exam

A2 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA DATE _______________ CHANNEL UNDER ADJUSTMENT: A B C D 11.10.3.1 Calculate and record the averages of each parameter in the space provided.

0 1 2 3 4 Average Adjusted BSCAL 99.87 PMC PID-C24230 HI LINEAR POWER N/A BISTABLE 1 VOLTS HIGH LINEAR POWER %

N/A VOLT X 20 PHICAL.

(Calibrated Neutron Flux Power) 99.96 CPC PID 171 BDT (Static Thermal Power) 99.82 CPC PID 177 Calculations Performed by: Verified by:

Signature Signature Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linear power is not 35% steady state. Document indication used in Remarks.

If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determine Secondary Calorimetric Power substitute when PMC or CORE POWER is specified.

Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made to PHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment 11.1 Note 9.8). Otherwise N/A this block. Use the Average value, not the Adjusted value, for DVM calculation.

11.10.4 Record the following for channel under adjustment:

TPC (Thermal Power Calibration Constant) 0.84399 CPC PID 064 ...................................................

KCAL (Neutron Flux Power Cal. Constant) 1.0070 CPC PID 065 ...................................................

PCALIB (Secondary Calorimetric Power Used in 100 Latest CPC Power Calibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) 543.59 CPC PID 160 ...................................................

TC 2 (Loop 2 Cold Leg Temperature) 543.46 CPC PID 161 ...................................................

TCORF (Temp Shadowing Correction Factor) 0.99902 CPC PID 180 ...................................................

EXCORE LINEAR POWER CALIBRATE N/A POTENTIOMETER POSITION ROM ..............

OP-903-001 Revision 061 Attachment 11.18 (1 of 3) 147

A2 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.5 Calculate the new DVM reading or new potentiometer position as follows:

Avg. Core Power (Step 11.10.3.1)* N/A DVM (new) = =

20 20

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

DVM (new) = N/A or Potentiometer position (new) =

Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)

Avg. Linear Power % (Step 11.10.4)

N/A X N/A N/A

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

Potentiometer position (new) = ______N/A_______

Performed by: N/A IV by: N/A (Initials) (Initials) 11.10.6.1 Calculate KCAL (new):

(Step 11.10.3.1)* (step 11.10.4) (step 11.10.4)

KCAL Avg. Core Power (%) x KCAL x TCORF

=

(new) Avg. PHICAL (step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.6.

KCAL 99.87 x 1.0070 x .99902

=

(new) 99.96 KCAL 1.0051

=

(new)

KCAL (new) = 1.0051 (CPC PID 065) 11.10.6.3 New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:

TC 1 (CPC PID 160) or TC 2 (CPC PID 161).

TCREF (new) = 543.46 (CPC PID 098)

Performed by: IV by:

(Initials) (Initials)

OP-903-001 Revision 061 Attachment 11.18 (2 of 3) 148

A2 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.7 Calculate TPC (CPC PID 064):

Avg. Core Power % (Step 11.10.3.1)* X TPC (Step 11.10.4)

TPC (new)=

Avg. BDT (Step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.7.

99.87 X 0.84399 TPC (new)=

99.82 TPC (new) = 0.84441 (CPC PID 064).

Performed by: IV by:

(Initials) (Initials) 11.10.11.1 Record the following:

Applicable CORE POWER PMC.................................... ___________

PCALIB CPC PID 104 .............................................. ___________

HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________

HI LINEAR POWER % VOLTS x 20 .............................. ___________

PHICAL CPC PID 171 .............................................. ___________

BDT CPC PID 177 .............................................. ___________

11.10.11.2.1 Record answers:

HI LINEAR POWER %, VOLTS X 20.................... YES/NO ________

PHICAL, CPC PID 171 ..................................... YES/NO ________

BDT, CPC PID 177 ..................................... YES/NO ________

11.10.12 Performed by: IV by:

(Initials) (Initials) 11.10.13 Reviewed by: _________________________ _________________

SM/CRS Date/Time OP-903-001 Revision 061 Attachment 11.18 (3 of 3) 149

A2 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA DATE _______________ CHANNEL UNDER ADJUSTMENT: A B C D 11.10.3.1 Calculate and record the averages of each parameter in the space provided.

0 1 2 3 4 Average Adjusted BSCAL PMC PID-C24230 HI LINEAR POWER N/A BISTABLE 1 VOLTS HIGH LINEAR POWER %

N/A VOLT X 20 PHICAL.

(Calibrated Neutron Flux Power)

CPC PID 171 BDT (Static Thermal Power)

CPC PID 177 Calculations Performed by: Verified by:

Signature Signature Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linear power is not 35% steady state. Document indication used in Remarks.

If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determine Secondary Calorimetric Power substitute when PMC or CORE POWER is specified.

Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made to PHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment 11.1 Note 9.8). Otherwise N/A this block. Use the Average value, not the Adjusted value, for DVM calculation.

11.10.4 Record the following for channel under adjustment:

TPC (Thermal Power Calibration Constant)

CPC PID 064 ...................................................

KCAL (Neutron Flux Power Cal. Constant)

CPC PID 065 ...................................................

PCALIB (Secondary Calorimetric Power Used in Latest CPC Power Calibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature)

CPC PID 160 ...................................................

TC 2 (Loop 2 Cold Leg Temperature)

CPC PID 161 ...................................................

TCORF (Temp Shadowing Correction Factor)

CPC PID 180 ...................................................

EXCORE LINEAR POWER CALIBRATE N/A POTENTIOMETER POSITION ROM ..............

OP-903-001 Revision 061 Attachment 11.18 (1 of 3) 145

A2 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.5 Calculate the new DVM reading or new potentiometer position as follows:

Avg. Core Power (Step 11.10.3.1)* N/A DVM (new) = =

20 20

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

DVM (new) = N/A or Potentiometer position (new) =

Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)

Avg. Linear Power % (Step 11.10.4)

N/A X N/A N/A

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

Potentiometer position (new) = ______N/A_______

Performed by: N/A Verified by: N/A (Initials) (Initials) 11.10.6.1 Calculate KCAL (new):

(Step 11.10.3.1)* (step 11.10.4) (step 11.10.4)

KCAL Avg. Core Power (%) x KCAL x TCORF

=

(new) Avg. PHICAL (step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.6.

KCAL x x

=

(new)

KCAL

=

(new)

KCAL (new) = (CPC PID 065) 11.10.6.3 New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:

TC 1 (CPC PID 160) or TC 2 (CPC PID 161).

TCREF (new) = (CPC PID 098)

Performed by: IV by:

(Initials) (Initials)

OP-903-001 Revision 061 Attachment 11.18 (2 of 3) 146

A2 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.7 Calculate TPC (CPC PID 064):

Avg. Core Power % (Step 11.10.3.1)* X TPC (Step 11.10.4)

TPC (new)=

Avg. BDT (Step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.7.

X TPC (new)=

TPC (new) = (CPC PID 064).

Performed by: IV by:

(Initials) (Initials) 11.10.11.1 Record the following:

Applicable CORE POWER PMC.................................... ___________

PCALIB CPC PID 104 .............................................. ___________

HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________

HI LINEAR POWER % VOLTS x 20 .............................. ___________

PHICAL CPC PID 171 .............................................. ___________

BDT CPC PID 177 .............................................. ___________

11.10.11.2.1 Record answers:

HI LINEAR POWER %, VOLTS X 20.................... YES/NO ________

PHICAL, CPC PID 171 ..................................... YES/NO ________

BDT, CPC PID 177 ..................................... YES/NO ________

11.10.12 Performed by: IV by:

(Initials) (Initials) 11.10.13 Reviewed by: _________________________ _________________

SM/CRS Date/Time OP-903-001 Revision 061 Attachment 11.18 (3 of 3) 147

Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A3 Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Applicant:

Examiner:

JPM A3 JOB PERFORMANCE MEASURE DATA PAGE Task: Determine Acceptability of Containment Temperature In Accordance With OP-903-001 Task Standard: Determined Containment Average Temperature does not meet acceptance criteria of OP-903-001, Technical Specification Surveillance Logs and Tech Spec 3.6.1.5 entry is required.

References:

OP-903-001, revision 61; TS 3.6.1.5; TS Bases 3/4.6 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 2.2.12, Knowledge of surveillance Importance Rating 3.7 procedures. RO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 6 2015 RO NRC Exam

JPM A3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-001, Attachment 11.1 MODES 1-4 Technical Specification Surveillance Logs, revision 61 OP-903-001, Attachment 11.20 MODES 1-4 PMC Technical Specification Surveillance Logs revision 61 Waterford 3 Technical Specifications

==

Description:==

This JPM requires the candidate to use Containment temperature readings from the PMC (provided on the cue sheet), calculate the average temperature using 3 of the 4 readings, and determine compliance with TS 3.6.1.5 and OP-903-001. Based on the readings of the 3 running CFC intake temperatures and tighter acceptance criteria of OP-903-001 (based on instrument error) TS 3.6.1.5 ACTION a must be complied with.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 6 2015 RO NRC Exam

JPM A3 Evaluator Note The candidate will determine Containment Average Temperature using Containment Fan Cooler inlet temperatures from the PMC, Containment Fan Coolers running, and reactor power (all provided on the cue sheet)

TASK ELEMENT 1 STANDARD Determines Containment Average Temperature 98.3 F -99.7 F Comment: Critical

1. The applicant will use the provided CFC temperatures and average the 3 running CFC temperatures (A, C and D). The SAT / UNSAT average will be 98.7 F.

Note: Averaging the 3 running CFC temperatures is preferred but not required. Any 3 can be used. The range given covers the various combinations that can be averaged.

TASK ELEMENT 2 STANDARD Determined that Determines Average Containment Temperature does NOT meet acceptance criteria is not Acceptance Criteria. met and TS 3.6.1.5 entry is required.

Comment: Critical If the candidate just compares the temperature to the 3.6.1.5 LCO they will determine that no action is required and acceptance criteria is met. SAT / UNSAT However, Tech Spec 3.6.1.5 does not take into account instrument uncertainties. and notes 2.0 - 2.3 of OP-903-001, Attachment 11.1 should be reviewed to determine acceptability of Containment Temperature.

END OF TASK Revision 0 Page 4 of 6 2015 RO NRC Exam

JPM A3 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 5 of 6 2015 RO NRC Exam

JPM A3 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER TO UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Reactor power is at 100%

I & C has just completed calibration of CFC Air Intake temperature loops Containment Fan Coolers A, C, and D are operating Primary Containment Average Air temperatures are as follows:

PID A51115, CFC A Air Inlet Temp reads 97 F PID A51119, CFC B Air Inlet Temp reads 100 F PID A51123, CFC C Air Inlet Temp reads 101 F PID A51127, CFC D Air Inlet Temp reads 98 F INITIATING CUES:

The CRS directs you to determine compliance of Containment Average Temperature per OP-903-001.

Document results and actions required, if any, on OP-903-001, Attachment 11.20.

Revision 0 Page 6 of 6 2015 RO NRC Exam

Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE A4 Calculate Stay Times Based on Dose Rates Applicant:

Examiner:

JPM A4 JOB PERFORMANCE MEASURE DATA PAGE Task: Calculate Stay Times Based on Dose Rates Task Standard: Applicant correctly calculated the allowed stay time to complete the described tagout without exceeding his yearly Waterford 3 administrative radiation dose limits.

References:

UNT-001-016, Radiation Protection Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 2.3.4, Knowledge of radiation exposure limits Importance Rating 3.2 under normal and emergency conditions. RO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 6 2015 RO NRC Exam

JPM A4 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

None

==

Description:==

This JPM requires the applicant to correctly calculate the allowed stay time to complete the described tagout without exceeding his yearly Waterford 3 administrative radiation dose limits.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 6 2015 RO NRC Exam

JPM A4 TASK ELEMENT STANDARD Calculate stay time based on dose rate and Waterford 3 yearly Applicant calculated the stay time as TEDE limits. 8 minutes.

Comment: Critical SAT / UNSAT Waterford 3 administrative TEDE limit: 2000 mrem Dose for the year: 1875 mrem Remaining dose for the year: 125 mrem Time allowed in room: 125 mrem / 850 mrem/hour 0.147 hour0.0017 days 0.0408 hours 2.430556e-4 weeks 5.59335e-5 months or 8.8 minutes END OF TASK Revision 0 Page 4 of 6 2015 RO NRC Exam

JPM A4 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 5 of 6 2015 RO NRC Exam

JPM A4 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

You have been assigned to verify a 5 valve tagout on the -11 Elevation in Containment.

Your yearly dose to date is 1875 mrem TEDE for the year.

The dose rate in that area is 850 mrem/hour.

Based on Waterford 3 yearly administrative limits, what is your MAXIMUM allowed stay time in the room in COMPLETE WHOLE MINUTES?

Do all of your calculations on this sheet.

Revision 0 Page 6 of 6 2015 RO NRC Exam

Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A5 Review DNBR and LPD Limits Associated with OP-901-501, PMC or COLSS Malfunction Applicant:

Examiner:

JPM A5 JOB PERFORMANCE MEASURE DATA PAGE Task: Review DNBR and LPD Limits Associated with OP-901-501, PMC or COLSS Malfunction Task Standard: Applicant reviews completed OP-901-501 paperwork and discovers the three errors on Attachments 2 and 3. Errors are identified 1, 2, and 3 on the answer key.

References:

OP-901-501, PMC or COLSS Malfunction Technical Specification 3.2.4 and COLR 3.2.4 Alternate Path: No Time Critical: No Validation Time: 25 mins.

K/A 2.1.20, Ability to interpret and execute Importance Rating 4.6 procedure steps. SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 2 Page 2 of 6 NRC SRO Exam 2015

JPM A5 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-501, PMC or Core Operating Limit Supervisory System Malfunction

==

Description:==

This JPM requires the applicant to review completed OP-901-501 paperwork and discover errors on Attachments 2 and Attachment 3.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 2 Page 3 of 6 NRC SRO Exam 2015

JPM A5 TASK ELEMENT STANDARD Corrected CPC LPD limits to 12.12, Applicant discovers that all 4 CPC LPD limits calculated on 11.91, 12.11, and 13.41 for were done with the calculation in step 5 vice step 4.

Channels A through D.

Comment: Critical SAT / UNSAT TASK ELEMENT STANDARD Applicant corrected the 4 CPC LPD OP-901-501 Attachment 3 LPD limit lists correct value.

limits on Attachment 3.

Comment:

SAT / UNSAT TASK ELEMENT STANDARD Applicant determined Channel A or Applicant discovers that the BOP operator filled in No for DNBR Channel B meet the limits of Tech within limits of Tech Spec 3.2.4 on any operable CPC Channel. Spec 3.2.4, using COLR figure 8A on page 3/4-2-6B.

Comment: Critical SAT / UNSAT END OF TASK Revision 2 Page 4 of 6 NRC SRO Exam 2015

JPM A5 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 2 Page 5 of 6 NRC SRO Exam 2015

JPM A5 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

100% power Both CEACs are operable 250 EFPD Containment temperature is 102 °F The Plant Monitoring Computer failed at 1900 on 9/14/2015.

You have entered OP-901-501, PMC or Core Operating Limit Supervisory System Malfunction.

INITIATING CUES:

The BOP operator has completed Attachment 1, CPC DNBR Limit Calculation, Attachment 2, CPC LPD Limit Calculation , and Attachment 3, 15 Minute Log, of OP-901-501.

Review the attached paperwork for accuracy and document any errors or discrepancies identified.

Revision 2 Page 6 of 6 NRC SRO Exam 2015

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 A5 Key ATTACHMENT 1: CPC DNBR LIMIT CALCULATION

1. Record CPC DNBR in column (1) and CPC PHICAL in column (3) using data from CPCs.

2. Record COLSS DNBR POL in column (2) using last valid value for COLSS DNBR POL, PMC PID C24560 as found on dedicated trend pen recorder.

3. Perform CPC DNBR Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).

[(2) - (3)] X 0.03 = (4)

4. If available DNBR margin > 0.15, then perform the following calculation. Record results in column (5).

(1) - 0.1 = (5)

5. If available DNBR margin 0.15, then perform the following calculation. Record results in column (5).

(1) - (4) = (5)

Available DNBR Limit (1) (2) (3) (4) (5)

CPC CPC DNBR COLSS CPC PHICAL Available CPC DNBR Channel PID 406 DNBR POL PID 171 Margin Limit A 2.17 109 100.7 0.249 2.07 B 2.13 109 100.5 0.255 2.03 C 2.17 109 100.5 0.255 2.07 D 2.13 109 100.9 0.243 2.03 Performed ___jhmendoza________________________ Date/Time__9/14/15 1905 Verified ___joe operator_______________________ Date/Time__9/14/15 1910 SM/CRS _______________________________________ Date/Time___________

Transmit with OP-903-001, Technical Specification Surveillance Logs.

1

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 A5 KEY ATTACHMENT 2: CPC LPD LIMIT CALCULATION

1. Record CPC LPD in column (1) and CPC PHICAL in column (3) using data from CPCs.

2. Record COLSS KW/FT POL (2) using last valid value for COLSS KW/FT POL, PMC PID C24561 as found on dedicated trend pen recorder.

(2) ( 3)

( 4) 18

3. Perform CPC KW/FT Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).

4. If available LPD margin > 0.4, then perform the following calculation. Record results in column (5).

(1) + 0.25 = (5)

5. If available LPD margin 0.4, then perform the following calculation. Record results in column (5).

(1) + (4) = (5)

(1) Incorrect LPD limit calculated Available LPD Margin Limit (1) (2) (3) (4) (5)

CPC CPC LPD COLSS CPC PHICAL Available CPC LPD Channel PID 179 KW/FT POL PID 171 Margin Limit A 11.87 113 100.7 0.683 12.55 B 11.66 113 100.5 0.694 12.35 C 11.86 113 100.5 0.694 12.55 D 13.16 113 100.9 0.672 13.83 Performed _____jhemdoza________________________ Date/Time_9/14/15 1905 Verified _____joe operator______________________ Date/Time_9/14/15 1910 SM/CRS ________________________________________Date/Time_________

Transmit with OP-903-001, Technical Specification Surveillance Logs.

2

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 7 of 7 A5 KEY ATTACHMENT 3: 15 MINUTE LOG

[P-461, P-13445, P-13446, P-20634]

(2) Incorrect limits for LPD from Attachment 2)

TIME: 1915 1930 CPC Channel A Limits LPD PID 179 11.87 11.87 LPD = _12.55___ DNBR PID 406 2.17 2.15 (COLR met, 2.11 required)

DNBR = ____2.07_ ASI PID 268 0.01 0.01 CPC Channel B Limits LPD PID 179 11.66 11.67 LPD = __12.35__ DNBR PID 406 2.13 2.12 (COLR met, 2.09 required)

DNBR = ___2.03_ ASI PID 268 -0.02 -0.02 CPC Channel C Limits LPD PID 179 11.86 11.85 LPD = __12.55__ DNBR PID 406 2.10 2.06 (COLR not met , 2.10 required)

DNBR = ____2.07_ ASI PID 268 -0.005 -0.01 CPC Channel D Limits LPD PID 179 13.16 13.17 LPD = __13.83__ DNBR PID 406 2.07 2.04 (COLR not met, 2.10 required)

DNBR = ___2.03__ ASI PID 268 -0.01 -0.015 CPC LPD < CPC LPD LIMIT ON ALL Y Y OPERABLE CPC CHANNELS (Y/N)

LPD WITHIN LIMITS OF T.S. 3.2.1 ON ANY OPERABLE CPC CHANNEL. (Y/N) Y Y Note (1) and (2)

CPC DNBR > CPC DNBR LIMIT ON ALL Y N OPERABLE CPC CHANNELS (Y/N)

DNBR WITHIN LIMITS OF T.S. 3.2.4 ON ANY Y N (3) Should be a Y, A OPERABLE CPC CHANNEL (Y/N) ** and B meeting COLR ASI ACCEPTABLE (Y/N) *** Y Y PERFORMED BY (INITIALS) jho jho Note (1) IF LPD is not within the limits of T.S. 3.2.1 on any operable CPC Channel, then enter Technical Specification 3.2.1.

Note (2) If complying with the applicable action of Technical Specification 3.6.1.5 due to low Containment temperatures, then apply the action in the COLR 3.2.1 for reducing LPD.

This requirement for Containment temperature is applicable when > 70% power. (Due to instrument inaccuracies, OP-903-001 applies the minimum temperature of 100 F vice 95 F.)

- If DNBR is not within the limits of T.S. 3.2.4 on any operable CPC Channel, then enter Technical Specification 3.2.4.

- - ASI is acceptable IF within limits of Technical Specification 3.2.7.

Performed by: joe operator 9/14/15 (Signature) (Date)

SM/CRS Review: /

(Signature) (Date/Time)

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 A5 Student ATTACHMENT 1: CPC DNBR LIMIT CALCULATION

1. Record CPC DNBR in column (1) and CPC PHICAL in column (3) using data from CPCs.

2. Record COLSS DNBR POL in column (2) using last valid value for COLSS DNBR POL, PMC PID C24560 as found on dedicated trend pen recorder.

3. Perform CPC DNBR Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).

[(2) - (3)] X 0.03 = (4)

4. If available DNBR margin > 0.15, then perform the following calculation. Record results in column (5).

(1) - 0.1 = (5)

5. If available DNBR margin 0.15, then perform the following calculation. Record results in column (5).

(1) - (4) = (5)

Available DNBR Limit (1) (2) (3) (4) (5)

CPC CPC DNBR COLSS CPC PHICAL Available CPC DNBR Channel PID 406 DNBR POL PID 171 Margin Limit A 2.17 109 100.7 0.249 2.07 B 2.13 109 100.5 0.255 2.03 C 2.17 109 100.5 0.255 2.07 D 2.13 109 100.9 0.243 2.03 Performed ___jhmendoza________________________ Date/Time__9/14/15 1900 Verified ___joe operator_______________________ Date/Time__9/14/15 1910 SM/CRS _______________________________________ Date/Time___________

Transmit with OP-903-001, Technical Specification Surveillance Logs.

1

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 1 of 1 ATTACHMENT 2: CPC LPD LIMIT CALCULATION

1. Record CPC LPD in column (1) and CPC PHICAL in column (3) using data from CPCs.

2. Record COLSS KW/FT POL (2) using last valid value for COLSS KW/FT POL, PMC PID C24561 as found on dedicated trend pen recorder.

3. Perform CPC KW/FT Limit calculation for each CPC Channel with data from applicable column using the formula shown below. Record results in column (4).

(2) ( 3)

( 4) 18

4. If available LPD margin > 0.4, then perform the following calculation. Record results in column (5).

(1) + 0.25 = (5)

5. If available LPD margin 0.4, then perform the following calculation. Record results in column (5).

(1) + (4) = (5)

Available LPD Margin Limit (1) (2) (3) (4) (5)

CPC CPC LPD COLSS CPC PHICAL Available CPC LPD Channel PID 179 KW/FT POL PID 171 Margin Limit A 11.87 113 100.7 0.683 12.55 B 11.66 113 100.5 0.694 12.35 C 11.86 113 100.5 0.694 12.55 D 13.16 113 100.9 0.672 13.83 Performed _____jhemdoza________________________ Date/Time_9/14/15 1900 Verified _____joe operator______________________ Date/Time_9/14/15 1910 SM/CRS ________________________________________Date/Time_________

Transmit with OP-903-001, Technical Specification Surveillance Logs.

2

Off Normal Procedure OP-901-501 PMC or Core Operating Limit Supervisory System Malfunction Revision 015 Page 7 of 7 ATTACHMENT 3: 15 MINUTE LOG

[P-461, P-13445, P-13446, P-20634]

TIME: 1915 1930 CPC Channel A Limits LPD PID 179 11.87 11.87 LPD = _12.55___ DNBR PID 406 2.17 2.15 DNBR = ____2.07_ ASI PID 268 0.01 0.01 CPC Channel B Limits LPD PID 179 11.66 11.67 LPD = __12.35__ DNBR PID 406 2.13 2.12 DNBR = ___2.03_ ASI PID 268 -0.02 -0.02 CPC Channel C Limits LPD PID 179 11.86 11.85 LPD = __12.55__ DNBR PID 406 2.10 2.06 DNBR = ____2.07_ ASI PID 268 -0.005 -0.01 CPC Channel D Limits LPD PID 179 13.16 13.17 LPD = __13.83__ DNBR PID 406 2.07 2.04 DNBR = ___2.03__ ASI PID 268 -0.01 -0.015 CPC LPD < CPC LPD LIMIT ON ALL Y Y OPERABLE CPC CHANNELS (Y/N)

LPD WITHIN LIMITS OF T.S. 3.2.1 ON ANY OPERABLE CPC CHANNEL. (Y/N) Y Y Note (1) and (2)

CPC DNBR > CPC DNBR LIMIT ON ALL Y N OPERABLE CPC CHANNELS (Y/N)

DNBR WITHIN LIMITS OF T.S. 3.2.4 ON ANY OPERABLE CPC CHANNEL (Y/N) **

Y N ASI ACCEPTABLE (Y/N) *** Y Y PERFORMED BY (INITIALS) jho jho Note (1) IF LPD is not within the limits of T.S. 3.2.1 on any operable CPC Channel, then enter Technical Specification 3.2.1.

Note (2) If complying with the applicable action of Technical Specification 3.6.1.5 due to low Containment temperatures, then apply the action in the COLR 3.2.1 for reducing LPD.

This requirement for Containment temperature is applicable when > 70% power. (Due to instrument inaccuracies, OP-903-001 applies the minimum temperature of 100 F vice 95 F.)

- If DNBR is not within the limits of T.S. 3.2.4 on any operable CPC Channel, then enter Technical Specification 3.2.4.

- - ASI is acceptable IF within limits of Technical Specification 3.2.7.

Performed by: joe operator 9/14/15 (Signature) (Date)

SM/CRS Review: /

(Signature) (Date/Time)

Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A6 Review and Approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data.

Applicant:

Examiner:

JPM A6 JOB PERFORMANCE MEASURE DATA PAGE Task: Review and approve OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data.

Task Standard: Applicant discovers 3 errors on the surveillance affecting power calibrations in accordance with the OP-903-001, Technical Specification Surveillance Logs and the JPM key.

References:

OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data Alternate Path: No Time Critical: No Validation Time: 20 mins.

K/A 2.1.18, Ability to make accurate, clear, and Importance Rating 3.8 concise logs, records, status boards, and SRO reports Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 6 2015 SRO NRC Exam

JPM A6 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data

==

Description:==

Applicant will review a completed set of calculations for CPC constants KCAL, TCREF, and TPC.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 6 2015 SRO NRC Exam

JPM A6 TASK ELEMENT 1 STANDARD Applicant must identify 3 errors that were Review and approve OP-903-001, Attachment 11.18. committed performing the surveillance in accordance with the A6 Key.

Comment: Critical Error 1: Step 11.10.6.1, In the KCAL calculation, BDT power was recorded instead of PHICAL. SAT / UNSAT Error 2: Step 11.10.6.1, Error 1 caused an error to be carried forward in the calculation of KCAL.

Error 3: Step 11.10.6.3, the minimum Tc was not selected.

PID 161 should have been selected instead of PID 160.

END OF TASK Revision 0 Page 4 of 6 2015 SRO NRC Exam

JPM A6 SIMULATOR OPERATOR INSTRUCTIONS None Revision 0 Page 5 of 6 2015 SRO NRC Exam

JPM A6 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Reactor power is 100% and steady The UFM is in service.

OP-903-001, Technical Specification Surveillance Logs, Attachment 11.18, Adjustment of CPC and Excore Nuclear Instrumentation Data, has been completed for Channel B.

Data collection from CP-10 and for the Linear Power Potentiometer is not required for this task. N/A has been placed on the surveillance for those items.

INITIATING CUES:

Review and approve the provided surveillance The previous CRS directed the reactor operator to gather required data once for column 0, averages were not required.

Revision 0 Page 6 of 6 2015 SRO NRC Exam

A6 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA DATE _______________ CHANNEL UNDER ADJUSTMENT: A B C D 11.10.3.1 Calculate and record the averages of each parameter in the space provided.

0 1 2 3 4 Average Adjusted BSCAL 99.87 PMC PID-C24230 HI LINEAR POWER N/A BISTABLE 1 VOLTS HIGH LINEAR POWER %

N/A VOLT X 20 PHICAL.

(Calibrated Neutron Flux Power) 99.96 CPC PID 171 BDT (Static Thermal Power) 99.82 CPC PID 177 Calculations Performed by: joe operator Verified by: jane operator Signature Signature Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linear power is not 35% steady state. Document indication used in Remarks.

If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determine Secondary Calorimetric Power substitute when PMC or CORE POWER is specified.

Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made to PHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment 11.1 Note 9.8). Otherwise N/A this block. Use the Average value, not the Adjusted value, for DVM calculation.

11.10.4 Record the following for channel under adjustment:

TPC (Thermal Power Calibration Constant) 0.84399 CPC PID 064 ...................................................

KCAL (Neutron Flux Power Cal. Constant) 1.0070 CPC PID 065 ...................................................

PCALIB (Secondary Calorimetric Power Used in 100 Latest CPC Power Calibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) 543.59 CPC PID 160 ...................................................

TC 2 (Loop 2 Cold Leg Temperature) 543.46 CPC PID 161 ...................................................

TCORF (Temp Shadowing Correction Factor) 0.99902 CPC PID 180 ...................................................

EXCORE LINEAR POWER CALIBRATE N/A POTENTIOMETER POSITION ROM ..............

OP-903-001 Revision 061 Attachment 11.18 (1 of 3) 147

A6 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.5 Calculate the new DVM reading or new potentiometer position as follows:

Avg. Core Power (Step 11.10.3.1)* N/A DVM (new) = =

20 20

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

DVM (new) = N/A or Potentiometer position (new) =

Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)

Avg. Linear Power % (Step 11.10.4)

N/A X N/A N/A

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

Potentiometer position (new) = ______N/A_______

Performed by: N/A Verified by: N/A (Initials) (Initials) 11.10.6.1 Calculate KCAL (new):

(Step 11.10.3.1)* (step 11.10.4) (step 11.10.4)

KCAL Avg. Core Power (%) x KCAL x TCORF

=

(new) Avg. PHICAL (step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.6.

KCAL 99.87 x 1.0070 x .99902

=

(new) 99.96 (99.82, selected BDT instead of PHICAL - ERROR 1)

KCAL 1.0051

= (1.0065, error carried (new) forward - ERROR 2)

KCAL (new) = 1.0051 (1.0065, error carried forward ERROR 2) (CPC PID 065) 11.10.6.3 New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:

TC 1 (CPC PID 160) or TC 2 (CPC PID 161).

TCREF (new) = 543.46 (543.59, not the min Tc ERROR 3) (CPC PID 098)

Performed by: joe operator Verified by: jane operarator (Initials) (Initials)

OP-903-001 Revision 061 Attachment 11.18 (2 of 3) 148

A6 Key 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.7 Calculate TPC (CPC PID 064):

Avg. Core Power % (Step 11.10.3.1)* X TPC (Step 11.10.4)

TPC (new)=

Avg. BDT (Step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.7.

99.87 X 0.84399 TPC (new)=

99.82 TPC (new) = 0.84441 (CPC PID 064).

Performed by: joe operator IV by: jane operarator (Initials) (Initials) 11.10.11.1 Record the following:

Applicable CORE POWER PMC.................................... ___________

PCALIB CPC PID 104 .............................................. ___________

HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________

HI LINEAR POWER % VOLTS x 20 .............................. ___________

PHICAL CPC PID 171 .............................................. ___________

BDT CPC PID 177 .............................................. ___________

11.10.11.2.1 Record answers:

HI LINEAR POWER %, VOLTS X 20.................... YES/NO ________

PHICAL, CPC PID 171 ..................................... YES/NO ________

BDT, CPC PID 177 ..................................... YES/NO ________

11.10.12 Performed by: IV by:

(Initials) (Initials) 11.10.13 Reviewed by: _________________________ _________________

SM/CRS Date/Time OP-903-001 Revision 061 Attachment 11.18 (3 of 3) 149

A6 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA DATE __Today_____ CHANNEL UNDER ADJUSTMENT: A B C D 11.10.3.1 Calculate and record the averages of each parameter in the space provided.

0 1 2 3 4 Average Adjusted BSCAL 99.87 PMC PID-C24230 HI LINEAR POWER N/A BISTABLE 1 VOLTS HIGH LINEAR POWER %

N/A VOLT X 20 PHICAL.

(Calibrated Neutron Flux Power) 99.96 CPC PID 171 BDT (Static Thermal Power) 99.82 CPC PID 177 Calculations Performed by: Verified by:

Signature Signature Refer to attachment 11.1 Note 9.1 to determine appropriate power indication if linear power is not 35% steady state. Document indication used in Remarks.

If COLSS is Inoperable, then use NE-005-201, Heat Balance Calculations, to determine Secondary Calorimetric Power substitute when PMC or CORE POWER is specified.

Adjusted is the average value plus 8.5% (8% to10%) if adjustments are being made to PHICAL and/or BDT as listed in Notes above steps 11.10.6 or 11.10.7 (refer to Attachment 11.1 Note 9.8). Otherwise N/A this block. Use the Average value, not the Adjusted value, for DVM calculation.

11.10.4 Record the following for channel under adjustment:

TPC (Thermal Power Calibration Constant) 0.84399 CPC PID 064 ...................................................

KCAL (Neutron Flux Power Cal. Constant) 1.0070 CPC PID 065 ...................................................

PCALIB (Secondary Calorimetric Power Used in 100 Latest CPC Power Calibration) CPC PID 104 TC 1 (Loop 1 Cold Leg Temperature) 543.59 CPC PID 160 ...................................................

TC 2 (Loop 2 Cold Leg Temperature) 543.46 CPC PID 161 ...................................................

TCORF (Temp Shadowing Correction Factor) 0.99902 CPC PID 180 ...................................................

EXCORE LINEAR POWER CALIBRATE N/A POTENTIOMETER POSITION ROM ..............

OP-903-001 Revision 061 Attachment 11.18 (1 of 3) 147

A6 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.5 Calculate the new DVM reading or new potentiometer position as follows:

Avg. Core Power (Step 11.10.3.1)* N/A DVM (new) = =

20 20

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

DVM (new) = N/A or Potentiometer position (new) =

Avg. Core Power % (Step 11.10.3.1)* X Old Potentiometer Setting (Step 11.10.4)

Avg. Linear Power % (Step 11.10.4)

N/A X N/A N/A

Use the Average value from the table of step 11.10.3.1, not the Adjusted value.

Potentiometer position (new) = ______N/A_______

Performed by: N/A Verified by: N/A (Initials) (Initials) 11.10.6.1 Calculate KCAL (new):

(Step 11.10.3.1)* (step 11.10.4) (step 11.10.4)

KCAL Avg. Core Power (%) x KCAL x TCORF

=

(new) Avg. PHICAL (step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.6.

KCAL 99.87 x 1.0070 x .99902

=

(new) 99.82 KCAL 1.0065

=

(new)

KCAL (new) = 1.0065 (CPC PID 065) 11.10.6.3 New TCREF (CPC PID 098) = Minimum TC from step 11.10.4:

TC 1 (CPC PID 160) or TC 2 (CPC PID 161).

TCREF (new) = 543.59 (CPC PID 098)

Performed by: PO Verified by: VO (Initials) (Initials)

OP-903-001 Revision 061 Attachment 11.18 (2 of 3) 148

A6 Student 11.18 ADJUSTMENT OF CPC AND EXCORE NUCLEAR INSTRUMENTATION DATA (CONTD) 11.10.7 Calculate TPC (CPC PID 064):

Avg. Core Power % (Step 11.10.3.1)* X TPC (Step 11.10.4)

TPC (new)=

Avg. BDT (Step 11.10.3.1)

An Adjusted value may be required. Refer to Note preceding step 11.10.7.

99.87 X 0.84399 TPC (new)=

99.82 TPC (new) = 0.84441 (CPC PID 064).

Performed by: PO IV by: VO (Initials) (Initials) 11.10.11.1 Record the following:

Applicable CORE POWER PMC.................................... ___________

PCALIB CPC PID 104 .............................................. ___________

HI LINEAR POWER BISTABLE 1 VOLTS ..................... ___________

HI LINEAR POWER % VOLTS x 20 .............................. ___________

PHICAL CPC PID 171 .............................................. ___________

BDT CPC PID 177 .............................................. ___________

11.10.11.2.1 Record answers:

HI LINEAR POWER %, VOLTS X 20.................... YES/NO ________

PHICAL, CPC PID 171 ..................................... YES/NO ________

BDT, CPC PID 177 ..................................... YES/NO ________

11.10.12 Performed by: IV by:

(Initials) (Initials) 11.10.13 Reviewed by: _________________________ _________________

SM/CRS Date/Time OP-903-001 Revision 061 Attachment 11.18 (3 of 3) 149

Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A7 Review of Containment Pressure Calculation Applicant:

Examiner:

JPM A7 JOB PERFORMANCE MEASURE DATA PAGE Task: Review of Containment pressure calculation Task Standard: Applicant reviewed a calculation for containment pressure in accordance with OP-903-001, Technical Specification Surveillance Logs. The results conform to the answer key. The applicant identified that Tech Spec 3.6.1.4 entry is required and identified the applicable Tech Spec action.

References:

OP-903-001, Technical Specification Surveillance Logs Technical Specification 3.6.1.4 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 2.2.12 Knowledge of Surveillance Importance Rating 4.1 procedures SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 7 2015 NRC Exam

JPM A7 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-001, Technical Specification Surveillance Logs Copy of Attachment 11.15, Containment Pressure Calculation (performed by the ATC)

Calculator

==

Description:==

This JPM requires the applicant to verify a containment pressure calculation performed by the ATC.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 7 2015 NRC Exam

JPM A7 TASK ELEMENT 1 STANDARD 11.15.1 Barometric Pressure as measured by PMC (PID C48516). If local reading used, then add 0.05 INHG to obtain a value equivalent to Met Tower PMC point. BP=___________ INHG Verified 29.44 entered.

11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable Comment:

Applicant should not add .05 INHG because the PMC is operable. If he adds .05 INHG, the final value of this calculation will be greater than the SAT / UNSAT TS limit.

TASK ELEMENT 2 STANDARD 11.15.2 Containment to Ambient Differential Pressure Verified -5.4 entered (PMC PID-A51000) C/A=____________ INWC Comment:

Value is from initial conditions SAT / UNSAT TASK ELEMENT 3 STANDARD 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:

Verified BP (PSIA) in the BP(PSIA) = [BP(INHG) x 0.4912 PSIA/INHG]

range of 14.46 to 14.461.

BP(PSIA) = [______________ INHG x 0.4912 PSIA/INHG]

BP(PSIA) = _______________ PSIA Comment:

14.46 is rounded from 14.460928.

SAT / UNSAT TASK ELEMENT 4 STANDARD 11.15.4 Convert Containment to Ambient Differential pressure (C/A) from INWC to PSIA by performing the following:

Recognize the wrong C/A(PSIA) = [CA(INWC) x 0.0361 PSIA/INWC]

number inserted C/A(PSIA) = [______________ INWC x 0.0361 PSIA/INWC]

C/A(PSIA) = _______________ PSIA Comment: Critical

-.195 is rounded from -.19494.

SAT / UNSAT The applicant should indentify that a positive number has been inserted and calculated for this step. The number is correct but the value should be negative. If this error is not identified, the final value of this calculation will be within TS limits.

Revision 0 Page 4 of 7 2015 NRC Exam

JPM A7 TASK ELEMENT 5 STANDARD 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by Recognized the error performing the following: carried forward from the CP(PSIA) = BP(PSIA) + C/A(PSIA) previous step. Corrected CP(PSIA) = ______________ PSIA + _______________ PSIA value should be 14.265 (14.26-14.27)

CP(PSIA) = _______________ PSIA Comment: Critical CP(PSIA) should be 14.265 when corrected. This number is below the minimum TS limit. SAT / UNSAT TASK ELEMENT 6 STANDARD Identified corrected value is The applicant should identify the corrected value is less than the less than 14.275 PSIA.

Technical Specification 3.6.14 limit for containment pressure (14.275 Identified TS 3.6.1.4 entry PSIA) and the actions for Technical Specification 3.6.1.4 are required. and the correct action required.

Comment: Critical The action for TS 3.6.1.4 is to restore the internal pressure to within the limits within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or 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 SAT / UNSAT and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Note: If applicant does not provide the action for TS 3.6.1.4, ask what the action is.

END OF TASK Revision 0 Page 5 of 7 2015 NRC Exam

JPM A7 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 6 of 7 2015 NRC Exam

JPM A7 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power.

Containment pressure reduction was secured during the previous shift.

Containment Pressure is -5.4 INWC (PMC Point A51000).

Barometric Pressure reading is 29.44 INHG as indicated on the PMC (Point C48516).

INITIATING CUE:

Verify the containment pressure calculation performed by the ATC using OP-903-001, Technical Specification Surveillance Logs and identify any TS actions required, if any.

Revision 0 Page 7 of 7 2015 NRC Exam

A7 KEY 11.15 CONTAINMENT PRESSURE CALCULATION 11.15.1 Barometric Pressure as measured by PMC (PID C48516).

If local reading used, then add 0.05 INHG to obtain a value equivalent to Met Tower PMC point. BP = ______29.44 INHG 11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable.

11.15.2 Containment to Ambient Differential Pressure (PMC PID-A51000 or CAPIDPI5171 if PID is bad) C/A = ____-5.4___ INWC 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:

BP(PSIA) = [BP (INHG) X 0.4912 PSIA/INHG]

BP(PSIA) = [ ______29.44_______ INHG X 0.4912 PSIA/INHG]

BP(PSIA) = ____14.46_________ PSIA 11.15.4 Convert Containment to Ambient Differential Pressure (C/A) from INWC to PSIA by performing the following:

C/A(PSIA) = [C/A (INWC) X 0.0361 PSIA/INWC]

C/A(PSIA) = [ __5.4_____(-5.4)_____ INWC X 0.0361 PSIA/INWC]

C/A(PSIA) = __.195_____(-.195)____ PSIA 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing the following:

CP(PSIA) = BP(PSIA) + C/A(PSIA)

CP(PSIA) = ________14.46_______ PSIA + _.195_(-.195)___ PSIA CP(PSIA) = __14.655__(14.265)__ PSIA 11.15.6 Attach this Attachment to Attachment 11.1, Mode 1-4 Technical Specification Surveillance Log.

OP-903-001 Revision 061 Attachment 11.15 (1 of 1) 144

A7 Student 11.15 CONTAINMENT PRESSURE CALCULATION 11.15.1 Barometric Pressure as measured by PMC (PID C48516).

If local reading used, then add 0.05 INHG to obtain a value equivalent to Met Tower PMC point. BP = ___29.44__ INHG 11.15.1.2 Record M&TE data on TS Logs Remarks and WR, if applicable.

11.15.2 Containment to Ambient Differential Pressure (PMC PID-A51000 or CAPIDPI5171 if PID is bad) C/A = ____-5.4___ INWC 11.15.3 Convert Barometric Pressure (BP) from INHG to PSIA by performing the following:

BP(PSIA) = [BP (INHG) X 0.4912 PSIA/INHG]

BP(PSIA) = [ ______29.44_______ INHG X 0.4912 PSIA/INHG]

BP(PSIA) = ____14.46_________ PSIA 11.15.4 Convert Containment to Ambient Differential Pressure (C/A) from INWC to PSIA by performing the following:

C/A(PSIA) = [C/A (INWC) X 0.0361 PSIA/INWC]

C/A(PSIA) = [ _______5.4_______ INWC X 0.0361 PSIA/INWC]

C/A(PSIA) = _____0.195____ PSIA 11.15.5 Calculate Absolute Containment Internal Pressure (CP) by performing the following:

CP(PSIA) = BP(PSIA) + C/A(PSIA)

CP(PSIA) = ________14.46_______ PSIA + ______0.195___ PSIA CP(PSIA) = _________14.655___ PSIA 11.15.6 Attach this Attachment to Attachment 11.1, Mode 1-4 Technical Specification Surveillance Log.

OP-903-001 Revision 061 Attachment 11.15 (1 of 1) 144

Waterford 3 2015 NRC SRO Exam JOB PERFORMANCE MEASURE A8 Review Containment Purge Hours and Terminate Release Applicant:

Examiner:

JPM A8 JOB PERFORMANCE MEASURE DATA PAGE Task: Review OP-903-001, Technical Specification Surveillance Logs, Attachment 11.6, Containment Purge Cumulative Hours Calculation, as the Control Room Supervisor.

Task Standard: Determined containment purge hour limits of TS 3.6.1.7 have been exceeded in accordance with OP-903-001, Tech Spec Surveillance Logs. Entered TS 3.6.1.7 action 'a' to terminate release within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

References:

OP-903-001, Technical Specification Surveillance Logs, Rev 61 Technical Specification 3.6.1.7 Alternate Path: No Time Critical: No Validation Time: 15 mins.

K/A 2.3.11, Ability to Control Radiation Releases Importance Rating 4.3 SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2015 NRC SRO Exam

JPM A8 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

Copy of OP-903-001, Technical Specification Surveillance Logs, Attachment 11.6, Containment Purge Cumulative Hours Calculation, completed by a Reactor Operator (Handout)

Calculator Copy of Technical Specifications

==

Description:==

This JPM requires the applicant to review a containment purge cumulative hours calculation performed by the Reactor Operator. Errors in the calculation will show that actual purge hours allowed by Technical Specifications have been exceed requiring termination of the release by securing containment purge.

READ TO APPLICANT DIRECTION TO APPLICANT:

Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 1 Page 3 of 8 2015 NRC SRO Exam

JPM A8 TASK ELEMENT 1 STANDARD 11.6.1 If a Purge is performed in Modes 1-4, then perform the following Performs six subsequent on the Containment Purge Tracking Hours Calculation Data steps Sheet:

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Verified date and mode 11.6.1.1 Enter the date and mode in the column Date/Mode. entered Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 11.6.1.2 Enter the time the Purge was Initiated in the column Time Verified time entered Initiated. If the Purge was in service at 0000, then enter 0000.

Comment:

SAT / UNSAT TASK ELEMENT 4 STANDARD 11.6.1.3 Enter the time the Purge was Terminated in the column Time Terminated. If the Purge was continued at 2400, then enter Verified time entered 2400.

Comment:

SAT / UNSAT TASK ELEMENT 5 STANDARD Recognized and corrected 11.6.1.4 Subtract column Time Initiated from column Time Terminated error on second row of and enter the result in the column Time. page 3 (see key)

Comment: Critical SAT / UNSAT Revision 1 Page 4 of 8 2015 NRC SRO Exam

JPM A8 TASK ELEMENT 6 STANDARD 11.6.1.5 Initial for performance of all of the entries in column Performed. Verified initials entered Comment:

SAT / UNSAT TASK ELEMENT 7 STANDARD 11.6.1.6 Verifier check all entries and initial column Verified. Verified initials entered Comment:

SAT / UNSAT TASK ELEMENT 8 STANDARD 11.6.2 If a Purge was performed with the Plant in Modes 1-4, then complete the following on the Containment Purge Cumulative Performs six subsequent Hours/Daily Calculation Data Sheet, for the previous day, on the steps 19-07 shift:

Comment:

SAT / UNSAT TASK ELEMENT 9 STANDARD Verified date and mode 11.6.2.1 Enter the date and mode in the column Date/Mode. entered Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD Recognized and corrected 11.6.2.2 From the Containment Purge Cumulative Hours Tracking Data error on third row of page 4 Sheet add all the entries in the column Time for the previous day under "Purge Time" (see and record in the column Purge Time. key)

Comment: Critical Error carried forward from Task Element 5.

SAT / UNSAT Revision 1 Page 5 of 8 2015 NRC SRO Exam

JPM A8 TASK ELEMENT 11 STANDARD Recognized and corrected 11.6.2.3 Add column Purge Time to column Accumulated Purge Time error on third row of page 4 and enter the result in column Sub Total. under "Sub Total" (see key)

Comment:

Error carried forward from Task Element 5.

SAT / UNSAT TASK ELEMENT 12 STANDARD Recognized and corrected 11.6.2.4 Find the date 365 days past and record the value from column error on third row of page 4 Purge Time from that date in column Purge Time Last YRS Date under "Purge Time Last Yrs for the present Date. Date" (see key)

Comment: Critical SAT / UNSAT TASK ELEMENT 13 STANDARD Recognized and corrected 11.6.2.5 Subtract column Purge Time Last YRS Date from column Sub error on third row of page 4 Total and record this value in column Accumulated Purge Time. under "Accumulated Purge Time" (see key)

Comment: Critical Error carried forward from Task Element 12.

SAT / UNSAT TASK ELEMENT 14 STANDARD Determined <90 hour limit has been exceeded, 11.6.2.6 Verify column Accumulated Purge Time result is <90 hours and entered TS 3.6.1.7 action a, record YES/NO in column <90 HRS. and secured purge to terminate release within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Comment: Critical The calculated value for "Accumulated Purge Time" is the total accumulated time up to midnight on 9-13-15. Since containment purge SAT / UNSAT has been in service for two hours past midnight actual total accumulated purge hours is 92 hours0.00106 days 0.0256 hours 1.521164e-4 weeks 3.5006e-5 months .

END OF TASK Revision 1 Page 6 of 8 2015 NRC SRO Exam

JPM A8 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 1 Page 7 of 8 2015 NRC SRO Exam

JPM A8 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power.

A Containment Purge batch release was initiated/terminated as shown on the attached cumulative hours tracking data sheet.

Containment Purge is currently in progress.

Current date and time is 9-14-2015, 0200.

INITIATING CUE:

Review the containment purge cumulative hours calculation performed by the Reactor Operator using OP-903-001, Technical Specification Surveillance Logs. Make corrections as necessary and identify TS actions, if any.

Revision 1 Page 8 of 8 2015 NRC SRO Exam

A8 KEY 11.6 CONTAINMENT PURGE CUMULATIVE HOURS CALCULATION 11.6.1 If a Purge is performed in Modes 1-4, then perform the following on the Containment Purge Tracking Hours Calculation Data Sheet:

11.6.1.1 Enter the date and mode in the column Date/Mode.

11.6.1.2 Enter the time the Purge was Initiated in the column Time Initiated. If the Purge was in service at 0000, then enter 0000.

11.6.1.3 Enter the time the Purge was Terminated in the column Time Terminated. If the Purge was continued at 2400, then enter 2400.

11.6.1.4 Subtract column Time Initiated from column Time Terminated and enter the result in the column Time.

11.6.1.5 Initial for performance of all of the entries in column Performed.

11.6.1.6 Verifier check all entries and initial column Verified.

11.6.2 If a Purge was performed with the Plant in Modes 1-4, then complete the following on the Containment Purge Cumulative Hours/Daily Calculation Data Sheet, for the previous day, on the 19-07 shift:

11.6.2.1 Enter the date and mode in the column Date/Mode.

11.6.2.2 From the Containment Purge Cumulative Hours Tracking Data Sheet add all the entries in the column Time for the previous day and record in the column Purge Time.

11.6.2.3 Add column Purge Time to column Accumulated Purge Time and enter the result in column Sub Total.

11.6.2.4 Find the date 365 days past and record the value from column Purge Time from that date in column Purge Time Last YRS Date for the present Date.

11.6.2.5 Subtract column Purge Time Last YRS Date from column Sub Total and record this value in column Accumulated Purge Time.

11.6.2.6 Verify column Accumulated Purge Time result is <90 hours and record YES/NO in column <90 HRS.

11.6.2.7 Initial for performance of all of the entries in column Performed.

11.6.2.8 Verifier check all entries and initials in column Verified.

OP-903-001 Revision 061 Attachment 11.6 (1 of 4) 1

A8 KEY 11.6.3 If a Containment Purge was not performed on the previous day, or the Plant was in Mode 5 or 6 on the previous day, then perform the following on the Containment Purge Cumulative Hours/Daily Calculation Data Sheet, on the 19-07 shift.

11.6.3.1 Enter the previous date and mode in the column Date/Mode.

11.6.3.2 Enter 0 in column Purge Time.

11.6.3.3 Add column Purge Time to the previous value in column Accumulated Purge Time and enter the results in column Sub Total.

11.6.3.4 Find the date 365 days and record the value from column Purge Time from that date in column Purge Time Last YRS Date for the present Date.

11.6.3.5 Subtract column Purge Time Last YRS Date from column Sub Total and record this value in column Accumulated Purge Time.

11.6.3.6 Verify column Accumulated Purge Time result is <90 hours and record YES/NO in column <90 HRS.

11.6.3.7 Initial for performance of all the entries in column Performed.

11.6.3.8 Verifier check all entries and initials in column Verified.

OP-903-001 Revision 061 Attachment 11.6 (2 of 4) 2

A8 KEY Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

TIME TIME PERFORMED VERIFIED DATE/MODE TIME INITIATED TERMINATED (Initial) (Initial) 9-13-15 / 1 0900 1000 1 ge jm 9-13-15 / 1 1300 1500 1 2 ge jm 9-13-15 / 1 2100 2400 3 ge jm 9-14-15 / 1 0000 OP-903-001 Revision 061 Attachment 11.6 (3 of 4) 3

A8 KEY Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

PURGE TIME ACCUMULATED <90 HRS PERFORMED VERIFIED DATE/MODE PURGE TIME SUB TOTAL LAST YRS DATE PURGE TIME YES/NO (Initial) (Initial) 9-11-15 / 1 0 88 0 88 yes ge jm 9-12-15 / 1 0 88 4 84 yes ge jm 9-13-15 / 1 5 6 89 90 3 0 86 90 yes no ge jm Accumulated Purge Time Sub Total Purge Time Total hrs from from 9-12-15 minus Purge from last year column "Time" plus Purge Time Last Yrs 9-13-14 on page 3 Time from Date on page 5 9-13-15 (90-0)

(84+6)

OP-903-001 Revision 061 Attachment 11.6 (4 of 4) 4

A8 KEY Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

PURGE TIME ACCUMULATED <90 HRS PERFORMED VERIFIED DATE/MODE PURGE TIME SUB TOTAL LAST YRS DATE PURGE TIME YES/NO (Initial) (Initial) 9-11-14 / 1 0 44 0 44 yes jm ge 9-12-14 / 3 4 48 3 45 yes jm ge 9-13-14 / 4 0 45 3 42 yes jm ge 9-14-14 / 4 0 42 0 42 yes jm ge 9-15-14 / 5 0 42 0 42 yes jm ge 9-16-14 / 5 0 42 0 42 yes jm ge 9-17-14 / 6 0 42 0 42 yes jm ge 9-18-14 / 6 0 42 3 39 yes jm ge 9-19-14 / 6 0 39 0 39 yes jm ge 9-20-14 / 6 0 39 0 39 yes jm ge 9-21-14 / 6 0 39 0 39 yes jm ge 9-22-14 / 6 0 39 0 39 yes jm ge 9-23-14 / 6 0 39 0 39 yes jm ge 9-24-14 / 6 0 39 0 39 yes jm ge 9-25-14 / 6 0 39 0 39 yes jm ge 9-26-14 / 6 0 39 0 39 yes jm ge 9-27-14 / 6 0 39 0 39 yes jm ge 9-28-14 / 6 0 39 0 39 yes jm ge 9-29-14 / 6 0 39 0 39 yes jm ge 9-30-14 / 6 0 39 0 39 yes jm ge 10-1-14 / 6 0 39 0 39 yes jm ge OP-903-001 Revision 061 Attachment 11.6 (4 of 4) 5

A8 Applicant Handout 11.6 CONTAINMENT PURGE CUMULATIVE HOURS CALCULATION 11.6.1 If a Purge is performed in Modes 1-4, then perform the following on the Containment Purge Tracking Hours Calculation Data Sheet:

11.6.1.1 Enter the date and mode in the column Date/Mode.

11.6.1.2 Enter the time the Purge was Initiated in the column Time Initiated. If the Purge was in service at 0000, then enter 0000.

11.6.1.3 Enter the time the Purge was Terminated in the column Time Terminated. If the Purge was continued at 2400, then enter 2400.

11.6.1.4 Subtract column Time Initiated from column Time Terminated and enter the result in the column Time.

11.6.1.5 Initial for performance of all of the entries in column Performed.

11.6.1.6 Verifier check all entries and initial column Verified.

11.6.2 If a Purge was performed with the Plant in Modes 1-4, then complete the following on the Containment Purge Cumulative Hours/Daily Calculation Data Sheet, for the previous day, on the 19-07 shift:

11.6.2.1 Enter the date and mode in the column Date/Mode.

11.6.2.2 From the Containment Purge Cumulative Hours Tracking Data Sheet add all the entries in the column Time for the previous day and record in the column Purge Time.

11.6.2.3 Add column Purge Time to column Accumulated Purge Time and enter the result in column Sub Total.

11.6.2.4 Find the date 365 days past and record the value from column Purge Time from that date in column Purge Time Last YRS Date for the present Date.

11.6.2.5 Subtract column Purge Time Last YRS Date from column Sub Total and record this value in column Accumulated Purge Time.

11.6.2.6 Verify column Accumulated Purge Time result is <90 hours and record YES/NO in column <90 HRS.

11.6.2.7 Initial for performance of all of the entries in column Performed.

11.6.2.8 Verifier check all entries and initials in column Verified.

OP-903-001 Revision 061 Attachment 11.6 (1 of 4) 1

A8 Applicant Handout 11.6.3 If a Containment Purge was not performed on the previous day, or the Plant was in Mode 5 or 6 on the previous day, then perform the following on the Containment Purge Cumulative Hours/Daily Calculation Data Sheet, on the 19-07 shift.

11.6.3.1 Enter the previous date and mode in the column Date/Mode.

11.6.3.2 Enter 0 in column Purge Time.

11.6.3.3 Add column Purge Time to the previous value in column Accumulated Purge Time and enter the results in column Sub Total.

11.6.3.4 Find the date 365 days and record the value from column Purge Time from that date in column Purge Time Last YRS Date for the present Date.

11.6.3.5 Subtract column Purge Time Last YRS Date from column Sub Total and record this value in column Accumulated Purge Time.

11.6.3.6 Verify column Accumulated Purge Time result is <90 hours and record YES/NO in column <90 HRS.

11.6.3.7 Initial for performance of all the entries in column Performed.

11.6.3.8 Verifier check all entries and initials in column Verified.

OP-903-001 Revision 061 Attachment 11.6 (2 of 4) 2

A8 Applicant Handout Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

TIME TIME PERFORMED VERIFIED DATE/MODE TIME INITIATED TERMINATED (Initial) (Initial) 9-13-15 / 1 0900 1000 1 ge jm 9-13-15 / 1 1300 1500 1 ge jm 9-13-15 / 1 2100 2400 3 ge jm 9-14-15 / 1 0000 OP-903-001 Revision 061 Attachment 11.6 (3 of 4) 3

A8 Applicant Handout Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

PURGE TIME ACCUMULATED <90 HRS PERFORMED VERIFIED DATE/MODE PURGE TIME SUB TOTAL LAST YRS DATE PURGE TIME YES/NO (Initial) (Initial) 9-11-15 / 1 0 88 0 88 yes ge jm 9-12-15 / 1 0 88 4 84 yes ge jm 9-13-15 / 1 5 89 3 86 yes ge jm OP-903-001 Revision 061 Attachment 11.6 (4 of 4) 4

A8 Applicant Handout Containment Purge Cumulative Hours Tracking Data Sheet (Typical)

PURGE TIME ACCUMULATED <90 HRS PERFORMED VERIFIED DATE/MODE PURGE TIME SUB TOTAL LAST YRS DATE PURGE TIME YES/NO (Initial) (Initial) 9-11-14 / 1 0 44 0 44 yes jm ge 9-12-14 / 3 4 48 3 45 yes jm ge 9-13-14 / 4 0 45 3 42 yes jm ge 9-14-14 / 4 0 42 0 42 yes jm ge 9-15-14 / 5 0 42 0 42 yes jm ge 9-16-14 / 5 0 42 0 42 yes jm ge 9-17-14 / 6 0 42 0 42 yes jm ge 9-18-14 / 6 0 42 3 39 yes jm ge 9-19-14 / 6 0 39 0 39 yes jm ge 9-20-14 / 6 0 39 0 39 yes jm ge 9-21-14 / 6 0 39 0 39 yes jm ge 9-22-14 / 6 0 39 0 39 yes jm ge 9-23-14 / 6 0 39 0 39 yes jm ge 9-24-14 / 6 0 39 0 39 yes jm ge 9-25-14 / 6 0 39 0 39 yes jm ge 9-26-14 / 6 0 39 0 39 yes jm ge 9-27-14 / 6 0 39 0 39 yes jm ge 9-28-14 / 6 0 39 0 39 yes jm ge 9-29-14 / 6 0 39 0 39 yes jm ge 9-30-14 / 6 0 39 0 39 yes jm ge 10-1-14 / 6 0 39 0 39 yes jm ge OP-903-001 Revision 061 Attachment 11.6 (4 of 4) 5

Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE A9 Classify an Emergency Event Applicant:

Examiner:

JPM A9 JOB PERFORMANCE MEASURE DATA PAGE Task: Classify an Emergency event Task Standard: Event classified correctly and declared within 15 minutes of JPM start.

References:

EP-001-001, Recognition and Classification of Emergency Conditions Rev 30 Alternate Path: No Time Critical: Yes Validation Time: 10 mins.

K/A 2.4.41, Knowledge of the emergency action Importance Rating 4.6 level thresholds and classifications SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: 15 minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 7 2015 SRO NRC Exam

JPM A9 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

EP-001-001, Recognition and Classification of Emergency Conditions

==

Description:==

This JPM requires the applicant to determine the emergency action level from the initial conditions within 15 minutes IAW EP-001-001. The Declaration/Initiating Condition will be FA1 ANY loss or ANY potential loss of EITHER fuel clad or RCS. The appropriate EAL can be either RCB2 or RCB3. The JPM will be performed in the classroom using given data obtained from the Initial Conditions.

READ TO APPLICANT DIRECTION TO APPLICANT:

This is a Time Critical Task Each administrative JPM has a cue sheet with the instructions for that JPM. Each administrative JPM stands alone, and conditions from 1 JPM do not carry over to any other JPM. If you have any questions, raise your hand and I will come to your desk.

Provide all answers on the sheets provided.

(Read the Initial Condition and Cues from the Applicant cue Sheet, and then give the cue sheet and a copy of EP-001-001 to applicant)

Revision 0 Page 3 of 7 2015 SRO NRC Exam

JPM A9 EXAMINER NOTE This JPM will be performed in the classroom using data obtained from the cue sheet provided. Ensure that the applicant turns in all paperwork prior to releasing.

Time Start:

TASK ELEMENT 1 STANDARD 5.2 Classification Determined Event is Real 5.2.1 Verify the off-normal event to ensure that the event is real. by initial conditions Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD 5.2.2 Match the off-normal event with one of the following six emergency categories:

5.2.2.1 Abnormal Radiation Levels/Radiological Effluents TAB A 5.2.2.2 Cold Shutdown/Refueling System Malfunction TAB C Determined Tab F is 5.2.2.3 ISFSI Malfunction TAB E applicable 5.2.2.4 Fission Product Barrier Degradation TAB F 5.2.2.5 Hazards and Other Conditions Affecting Plant Safety TAB H 5.2.2.6 System Malfunction TAB S Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 5.2.3 Refer to Attachment 7.1 Emergency Categories, under the category Determined RCS Barrier TAB selected in step 5.2.2 above; match the off-normal condition with the Loss/Potential loss (FA1) appropriate IC to determine the emergency classification.

Critical SAT / UNSAT Revision 0 Page 4 of 7 2015 SRO NRC Exam

JPM A9 TASK ELEMENT 4 STANDARD 5.2.4 If an event or condition existed which met or exceeded an IC but no emergency was declared the basis for the emergency classification no longer exists at the time of the discovery (rapidly concluded event, missed classification or misclassified event), then do not classify the emergency Determined step is N/A or make offsite notifications.

5.2.4.1 Notify the NRC within one hour of the discovery of the undeclared or misclassified event in accordance with UNT-006-010.

Comment:

SAT / UNSAT TASK ELEMENT 5 STANDARD Procedure Note:

The effects of combinations of initiating conditions that individually Note reviewed constitute a lower classification may be considered as a possibly higher emergency classification.

Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD Declared Alert based on 5.2.5 Declare the highest emergency classification for which an IC has FA1; EAL RCB3 or RCB2 been met or exceeded within 15 minutes of JPM start Comment: Critical SAT / UNSAT Time Complete:

Examiner Note: TIME CRITICAL STEP END OF TASK Revision 0 Page 5 of 7 2015 SRO NRC Exam

JPM A9 SIMULATOR OPERATOR INSTRUCTIONS None.

Revision 0 Page 6 of 7 2015 SRO NRC Exam

JPM A9 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Plant was operating at 100% when a Steam Generator Tube Rupture occurred.

Plant conditions:

o Steam Generator Tube leakage is 180 gpm o RCS Pressure = 1200 PSIA and dropping o The Condenser Exhaust WRGM reached a release rate of 4 E+2 Ci/sec for 10 minutes and now is trending down.

o The only manual actions taken by the crew was tripping the reactor.

INITIATING CUES:

You are directed to classify and declare this event in accordance with EP-001-001, Recognition and Classification of Emergency Conditions This is a time critical task Write your Declaration (include Emergency Classification, Initiating Condition and Emergency Action Level(s) ) on this sheet Declaration ____________________________________________________

Revision 0 Page 7 of 7 2015 SRO NRC Exam

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Waterford 3 Date of Examination: 9/14/2015 Exam Level RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive; ATC Operator Immediate Operator Actions on A, D, S 1 2 Dropped CEAs from OP-901-102, CEA or CEDMCS Malfunction Fault: The first and second reactor trip options do not function, requires performance of the final reactor trip contingency from EOP OP-902-000, Standard Post Trip Actions.

A2.13 ATWS RO - 4.4, SRO - 4.6 S2 004 Chemical and Volume Control System, Align Charging Pumps to N,S,L 2 discharge through HPSI Header A in accordance with OP-902-009 Appendix 30, Charging to the RCS via the HPSI Header A4.08, Charging RO - 3.8, SRO - 3.4 S3 005 Shutdown Cooling System; Place Shutdown Cooling Train A in A,D,L,P,S 4P Service Fault: After LPSI Pump A is running, SI-405A will fail closed, requiring the operator to take immediate operator actions IAW OP-901-131, Shutdown Cooling Malfunction, to secure LPSI Pump A.

(Repeat from 2012 NRC Exam)

A4.01 Controls and indication for RHR pumps RO - 3.6, SRO - 3.4 S4 039 Main and Reheat Steam System; BOP operator immediate A,D,S 4S operator actions on evacuation of the Control Room in accordance with OP-901-502, Control Room Evacuation Fault: Atmospheric Dump Valve B will spuriously open, requiring the applicant to take contingency actions to control Steam Generator pressure.

A4.01 Main steam supply. Valves RO - 2.9, SRO - 2.8 S5 026 Containment Spray System D,EN,P,L,S 5 Reset CSAS in accordance with OP-902-009, Standard Appendices, Section 5 - E (Repeat from 2014 NRC Exam)

A4.01 CSS Controls RO - 4.5, SRO - 4.3 S6 064 Emergency Diesel Generators A,M,S 6 Restore Power to Safety Bus 3B in accordance with OP-902-000, Standard Post Trip Actions.

Fault: EDG B voltage is low out of the band preventing auto closure of the EDG B output breaker. (WF3 OE)

A4.02 Adjustment of exciter voltage (using voltage control switch)

RO - 3.3, SRO - 3.4 1 2015 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 S7 015 Nuclear Instrumentation System L,D,S 7 Perform Range Check functional test of startup Channels in accordance with OP-903-101, Startup Channel Functional Test 015 A3.03, Verification of proper functioning/operability RO - 3.9, SRO - 3.9 S8 034 Fuel Handling Equipment N, S, L 8 Place the FHB Emergency Filtration Unit in service in accordance with OP-002-009, Fuel Handling Building HVAC A4.01 Radiation levels RO - 3.3, SRO - 3.7 In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P1 045 Main Turbine Generator System N,E,L 4S Start an Air Side Seal Oil Pump following a loss of single train of offsite power per OP-902-009 Attachment 33-C.

G2.4.6 Knowledge of EOP mitigation strategies RO - 3.7, SRO - 4.7 P2 064 Emergency Diesel Generator (ED/G) System; Trip Emergency A,D,R 6 Diesel Generator B locally.

Fault: The first method the applicant performs to trip the EDG B will fail, requiring contingency actions to secure EDG B.

K4.02 Trips for ED/G while operating (normal or emergency)

RO - 3.9, SRO - 4.2 P3 008 Component Cooling Water System; Restore Power to the DCT D,R,E,L 8 Sump Pumps Following a Loss of Off Site Power in accordance with OP-902-009, Standard Appendices G2.4.34 Knowledge of RO tasks performed outside the main control room during an emergency and the resultant operational effects.

RO - 4.2, SRO - 4.1

All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 5 (C)ontrol room 0 (D)irect from bank 9/ 8/ 4 7 (E)mergency or abnormal in-plant 1/ 1/ 1 2 (EN)gineered safety feature 1 / 1 / 1 (control room system) 1 (L)ow-Power / Shutdown 1/ 1/ 1 7 (N)ew or (M)odified from bank including 1(A) 2/ 2/ 1 4 (P)revious 2 exams 3/ 3/ 2 (randomly selected) 2 (R)CA 1/ 1/ 1 2 (S)imulator 8 2 2015 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Waterford 3 Date of Examination: 9/14/2015 Exam Level RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems:

8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Safety Code* Function S1 001 Control Rod Drive; ATC Operator Immediate Operator Actions on A,D,S 1 2 Dropped CEAs from OP-901-102, CEA or CEDMCS Malfunction Fault: The first and second reactor trip options do not function, requires performance of the final reactor trip contingency from EOP OP-902-000, Standard Post Trip Actions.

A2.13 ATWS RO - 4.4, SRO - 4.6 S2 S3 S4 S5 026 Containment Spray System D,EN,P,L,S 5 Reset CSAS in accordance with OP-902-009, Standard Appendices, Section 5 - E (Repeat from 2014 NRC Exam)

A4.01 CSS Controls RO - 4.5, SRO - 4.3 S6 064 Emergency Diesel Generators A,M,S 6 Restore Power to Safety Bus 3B in accordance with OP-902-000, Standard Post Trip Actions.

Fault: EDG B voltage is low out of the band preventing auto closure of the EDG B output breaker. (WF3 OE)

A4.02 Adjustment of exciter voltage (using voltage control switch)

RO - 3.3, SRO - 3.4 S7.

S8.

3 2015 NRC Revision 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 In-Plant Systems* (3 for RO);(3 for SRO-I); (3 or 2 for SRO-U)

P1 045 Main Turbine Generator System N,E,L 4S Start an Air Side Seal Oil Pump following a loss of single train of offsite power per OP-902-009 Attachment 33-C.

G2.4.6 Knowledge of EOP mitigation strategies RO - 3.7, SRO - 4.7 P2 P3 008 Component Cooling Water System; Restore Power to the DCT D,R,E,L 8 Sump Pumps Following a Loss of Off Site Power in accordance with OP-902-009, Standard Appendices G2.4.34 Knowledge of RO tasks performed outside the main control room during an emergency and the resultant operational effects.

RO - 4.2, SRO - 4.1

All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 2 (C)ontrol room 0 (D)irect from bank 9/ 8/ 4 3 (E)mergency or abnormal in-plant 1/ 1/ 1 2 (EN)gineered safety feature 1 / 1 / 1 (control room system) 1 (L)ow-Power / Shutdown 1/ 1/ 1 3 (N)ew or (M)odified from bank including 1(A) 2/ 2/ 1 2 (P)revious 2 exams 3/ 3/ 2 (randomly selected) 1 (R)CA 1/ 1/ 1 1 (S)imulator 3 4 2015 NRC Revision 1

Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE P1 Start an Air Side Seal Oil Pump following a Loss of a Single Train of Offsite Power Applicant:

Examiner:

JPM P1 JOB PERFORMANCE MEASURE DATA PAGE Task: Start an Air Side Seal Oil Pump following a Loss of Offsite Power to the Train A Electrical busses and then secure the Air Side Seal Oil Backup Pump (DC) in accordance with OP-902-009 Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power.

Task Standard: Applicant energizes and starts the Air Side Seal Oil Pump from MCC-215B and then secures the Air Side Seal Oil Backup Pump (DC).

References:

OP-902-009 Attachment-33, Generator Auxiliary Operations-Loss of Single Train Off-Site Power Alternate Path: No Time Critical: No Validation Time: 10 mins.

K/A G2.4.6 Knowledge of EOP mitigation Importance Rating 3.7 / 4.7 strategies RO/SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 6 2015 NRC Exam

JPM P1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009 Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power (Handout 1).

==

Description:==

This task is performed on the TGB +40 Elevation (east side). The applicant will energize and start the Air Side Seal Oil Pump from MCC-215B and then secure the Air Side Seal Oil Backup Pump (DC) in accordance with OP-902-009 Attachment 33-C, Generator Auxiliary Operations-Loss of Single Train Off-Site Power. Six pictures are provided for the examiner to cue expected indications at the Seal Oil Skid and at the Hydrogen Control Panel (Handout 2).

READ TO APPLICANT DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated, do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.

After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.

Revision 1 Page 3 of 6 2015 NRC Exam

JPM P1 Evaluator Note

1. This JPM will take place on the TGB +40 East side.

TASK ELEMENT 1 STANDARD Verified Air Side Seal Oil

1. Check Air Side Seal Oil Pump operating.

Pump is not operating.

Comment: The applicant may verify Air Side Seal Oil Pump not running locally at the pump or using light indications at the Hydrogen Control Panel. SAT / UNSAT Examiner Cue: If asked, provide picture(s) of Initial Indications of Seal Oil Skid and/or Hydrogen Control Panel. If asked, inform applicant that alarms F-1 (Air Aide Seal Oil BU Pump Running/UV) and G-1 (Air Aide Seal Oil Pump Off) are in alarm.

TASK ELEMENT 2 STANDARD

2. IF Air Side Seal Oil pump is de-energized, THEN perform the Verified status of Air Side following to transfer power source: Seal Oil Pump Transfer

a. Check status of Air Side Seal Oil Pump Transfer Switch Source Switch Source Available Available and Load Connected lights. and Load Connected lights.

Comment:

Examiner Cue: Cue the applicant that the Emergency Source Available light is illuminated and the Normal Source Available light is not SAT / UNSAT illuminated.

Examiner Cue: Cue the applicant that the Load Connected to Normal and Load Connected to Emergency lights are extinguished.

TASK ELEMENT 3 STANDARD

b. If Emergency Source (MCC-215B) Available light is illuminated, then perform the following: Transferred the Control Switch to TRANSFER TO

1) Toggle the Transfer Control Switch to TRANSFER TO EMERGENCY position.

EMERGENCY and THEN release the switch to neutral position.

Comment: Critical SAT / UNSAT Revision 1 Page 4 of 6 2015 NRC Exam

JPM P1 TASK ELEMENT 4 STANDARD

2) Check both of the following:

Proper light configuration is Load Connected to Emergency light illuminated.

verified.

Load Connected to Normal light extinguished.

Comment:

Examiner Cue: Notify the applicant that the Load Connected to Emergency light is illuminated and that the Load Connected to Normal SAT / UNSAT light is extinguished.

TASK ELEMENT 5 STANDARD Verified Air Side Seal Oil

d. Verify Air Side Seal Oil pump operating.

pump is operating.

Comment: The applicant may verify Air Side Seal Oil Pump running locally at the pump or using light indications at the Hydrogen Control Panel. SAT / UNSAT Examiner Cue: If asked, provide pictures of Step 2.d Indications. If asked, alarm G-1 (Air Aide Seal Oil Pump Off) has cleared.

TASK ELEMENT 6 STANDARD Control switch labeled

e. Stop the Air Side Seal Oil Backup Pump (DC) at Hydrogen Control "Back Up Pump Motor panel.

Control" is taken to Stop.

Comment: Control Switch is labeled "Back Up Pump Motor Control" Critical Examiner Cue: If asked, provide pictures of Step 2.e Indications. If asked, SAT / UNSAT alarm F-1 (Air Aide Seal Oil BU Pump Running/UV) has cleared.

TASK ELEMENT 7 STANDARD

3. Check Seal Oil DP 10 to 14 psid. Seal Oil DP is verified.

Comment: The correct gauge is the furthest to the left on the Seal Oil skid, labeled "Air Side Seal Oil/Gen Gas DP" (bar type indicator). Step 2.e Indications of the Seal Oil Skid can be used to provide other gauge SAT / UNSAT indications, if asked for.

Examiner Cue: After the applicant identifies the correct gauge, inform the applicant that Seal Oil DP is 13 psid.

END OF TASK Revision 1 Page 5 of 6 2015 NRC Exam

JPM P1 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

A loss of offsite power to Train A Electrical busses has occurred.

INITIATING CUE:

The CRS has directed you to start the Air Side Seal Oil Pump on the MCC-215B electrical bus in accordance with OP-902-009, Attachment 33-C: Generator Auxiliary Operations-Loss of Single Train Off-Site Power Revision 1 Page 6 of 6 2015 NRC Exam

WATERFORD 3 SES OP-902-009 Revision 310 Page 174 of 177 STANDARD APPENDICES Attachment 33-C Page 1 of 4 Generator Auxiliary Operations Attachment 33-C: Generator Auxiliary Operations - Loss of Single Train Off-Site Power INSTRUCTIONS

1. Check Air Side Seal Oil pump operating.

2. IF Air Side Seal Oil pump is de-energized, THEN perform the following to transfer power source:

a. Check status of Air Side Seal Oil Pump Transfer Switch Source Available and Load Connected lights.

b. IF Emergency Source (MCC 215B) Available light is illuminated, THEN perform the following:

1) Toggle the Transfer Control switch to TRANSFER TO EMERGENCY and THEN release the switch to neutral position.

2) Check BOTH of the following:

Load Connected to Emergency light illuminated.

Load Connected to Normal light extinguished.

c. IF Normal Source (MCC 215A) Available light is illuminated, THEN perform the following:

1) Toggle the Transfer Control switch to TRANSFER TO NORMAL and THEN release the switch to neutral position.

2) Check BOTH of the following:

Load Connected to Normal light illuminated.

Load Connected to Emergency light extinguished.

d. Verify Air Side Seal Oil pump operating.

e. Stop the Air Side Seal Oil Backup Pump (DC) at Hydrogen Control panel.

3. Check Seal Oil DP 10 to 14 psid.

Equipment Pictures Withheld Under 10 CFR 2.390(a)(4)

Waterford 3 2015 RO NRC Exam JOB PERFORMANCE MEASURE P2 Trip Emergency Diesel Generator B Locally Applicant:

Examiner:

JPM P2 JOB PERFORMANCE MEASURE DATA PAGE Task: Trip Emergency Diesel Generator B locally.

Task Standard: Applicant trips EDG B after initial efforts to trip the diesel fail and secures the Standby Fuel Oil Booster Pump in accordance with OP-009-002, Emergency Diesel Generator.

References:

OP-009-002, Emergency Diesel Generator, Attachment 8.7 Performing an Emergency Shutdown of the Emergency Diesel Generator. Revision 325 Alternate Path: Yes Time Critical: No Validation Time: 5 mins.

K/A 064 K4.02 Trips for EDG while operating Importance Rating 3.9 / 4.2 (normal or emergency) RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2015 NRC Exam

JPM P2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-009-002, Emergency Diesel Generator

==

Description:==

The applicant will be directed to trip EDG B locally. This JPM will require entry into the RCA, +21 level. The first method the applicant uses to trip the diesel will not function and the applicant will be required to trip the diesel using another method. The reason for tripping EDG B will be due to a fuel oil leak, so depressing the System Reset pushbutton on the local control panel is required.

READ TO APPLICANT DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated, do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.

After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.

Revision 1 Page 3 of 8 2015 NRC Exam

JPM P2 TASK ELEMENT 1 STANDARD NOTE If control air is lost during any EDG run, then the Fuel Rack Override lever Note reviewed.

must be used to shutdown the EDG.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD CAUTION SUBSECTION 8.7 IS FOR EMERGENCY CONDITIONS, WHEN Caution reviewed.

NORMAL SHUTDOWN IS INOPERATIVE OR IT IS NECESSARY TO RAPIDLY STOP THE EMERGENCY DIESEL GENERATOR.

Comment:

SAT / UNSAT Evaluator Note Step 8.7.1 is not applicable since Emergency Diesel Generator B is running in Emergency Mode.

TASK ELEMENT 3 STANDARD NOTE Two Operators are required to secure the EDG in Emergency Mode using Note reviewed.

method 2 of step 8.7.2.

Comment:

SAT / UNSAT Revision 1 Page 4 of 8 2015 NRC Exam

JPM P2 TASK ELEMENT 4 STANDARD CAUTION THE EDG WILL RESTART IF THE FUEL RACK OVERRIDE LEVER IS Caution reviewed.

RELEASED AND THE UNDERVOLTAGE OR SIAS SIGNAL IS PRESENT PRIOR TO COMPLETING STEP 8.7.2.2.2.

Comment:

SAT / UNSAT Evaluator Note There are 2 acceptable methods to trip an EDG running in emergency mode. The applicant could choose either method to perform first. Which ever method used first will fail, requiring the applicant to exercise the other method.

ALTERNATE PATH starts after the first method is attempted (Task Element 5 or 6).

8.7.2 With the Emergency Diesel Generator B in Emergency Mode, Stop the Emergency Diesel Generator B by performing one of the following methods:

TASK ELEMENT 5 STANDARD 8.7.2.1 Method 1: Pull the manual Fuel Oil Overspeed Trip on the Overspeed pulled.

Overspeed Governor.

Comment: Critical This plunger is located on the upper level of the EDG. If this is attempted first, cue that the EDG B is still running. (Alternate Path) SAT / UNSAT If this is attempted secondly, cue that the EDG B has stopped.

TASK ELEMENT 6 STANDARD 8.7.2.2 Method 2:

8.7.2.2.1 Pull down and hold the Fuel Rack Override Lever on the North Handle is held down.

side of the Emergency Diesel Generator A(B) engine.

Comment: Critical If this is attempted first, cue the applicant that the lever did not move and that the EDG B is still running. (Alternate Path) SAT / UNSAT If this is attempted secondly, cue that the EDG B has stopped.

Evaluator Note If the applicant uses the fuel lever second, cue him that another operator has arrived to assist. After the applicant is holding the fuel rack lever, cue that another operator is now holding the lever.

Revision 1 Page 5 of 8 2015 NRC Exam

JPM P2 TASK ELEMENT 7 STANDARD 8.7.2.2.2 To prevent the Emergency Diesel Generator A(B) from Starting, Unlock and Close the following valves:

Valves are closed.

EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation Comment: Critical SAT / UNSAT TASK ELEMENT 8 STANDARD 8.7.2.2.3 Release Fuel Rack Override Lever. Lever released.

Comment:

SAT / UNSAT TASK ELEMENT 9 STANDARD 8.7.2.2.4 Place the EDG A(B) Fuel Rack Override Lever in the Vertical and Latched position.

Lever in the Vertical and 8.7.2.2.4.1 Document on Attachment 11.18, Performing an Emergency latched position Shutdown of the Emergency Diesel Generator Valve Restoration or other, appropriate document.

Comment:

Examiner Cue: Inform the applicant that the control room is preparing the attachment and he may continue on. SAT / UNSAT TASK ELEMENT 10 STANDARD NOTE Depressing the System Reset pushbutton after the EDG has stopped will Note reviewed.

secure the Standby Fuel Oil Booster Pump, which may help mitigate the fuel oil leak.

Comment:

SAT / UNSAT Revision 1 Page 6 of 8 2015 NRC Exam

JPM P2 TASK ELEMENT 11 STANDARD 8.7.3 If a fuel oil leak is in progress, when the Emergency Diesel Pushbutton depressed.

Generator A(B) has stopped then depress the System Reset pushbutton.

Comment: Critical If asked, cue the applicant that annunciator C-4 (Emergency Stop or Unit S/D) is locked in and G-2 (Stby Fuel Oil Booster Pump Running/Trouble) SAT / UNSAT came in and cleared. Also, the Fuel Oil Booster Pump control switch green light is illuminated and the red light is extinguished.

TASK ELEMENT 12 STANDARD 8.7.4 Verify steps applicable or directed by the SM/CRS in Subsection 6.5, Control Room informed.

Unloading, Stopping and Returning EDG A(B) to Standby, are completed.

Comment:

SAT / UNSAT END OF TASK Revision 1 Page 7 of 8 2015 NRC Exam

JPM P2 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

Emergency Diesel Generator B is running in Emergency Mode A fuel oil leak has developed on the EDG B.

INITIATING CUE:

The CRS directs you to locally trip EDG B in accordance with OP-009-002, Emergency Diesel Generator, section 8.7 Performing an Emergency Shutdown of the EDG.

Revision 1 Page 8 of 8 2015 NRC Exam

System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 8.7 PERFORMING AN EMERGENCY SHUTDOWN OF THE EMERGENCY DIESEL GENERATOR NOTE If control air is lost during any EDG run, then the Fuel Rack Override lever must be used to shutdown the EDG.

CAUTION SUBSECTION 8.7 IS FOR EMERGENCY CONDITIONS, WHEN NORMAL SHUTDOWN IS INOPERATIVE OR IT IS NECESSARY TO RAPIDLY STOP THE EMERGENCY DIESEL GENERATOR.

8.7.1 With Emergency Diesel Generator A(B) in Test Mode:

8.7.1.1 For no Cooldown cycle, then perform one of the following:

Depress Emergency Stop Pushbutton on CP-1.

Depress the Emergency Stop pushbutton on Emergency Diesel Generator A(B) Control Panel.

Pull manual Fuel Oil Overspeed Trip on Overspeed Governor.

Pull down and hold Fuel Rack Override Lever on North side of Emergency Diesel Generator A(B) engine until the engine comes to a complete Stop. (Once released, ensure the the EDG A(B) Fuel Rack Override Lever is Vertical & Latched and document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document) 8.7.1.2 For a 5 minute Cooldown cycle, then perform one of the following:

Position Diesel Cranking Control Switch at CP-1 to STOP.

Position Control Switch on Emergency Diesel Generator A(B) Control Panel to STOP.

48

System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 NOTE Two Operators are required to secure the EDG in Emergency Mode using method 2 of step 8.7.2.

CAUTION THE EDG WILL RESTART IF THE FUEL RACK OVERRIDE LEVER IS RELEASED AND THE UNDERVOLTAGE OR SIAS SIGNAL IS PRESENT PRIOR TO COMPLETING STEP 8.7.2.2.2.

8.7.2 With the Emergency Diesel Generator A(B) in Emergency Mode, Stop the Emergency Diesel Generator A(B) by performing one of the following methods:

8.7.2.1 Method 1: Pull the manual Fuel Oil Overspeed Trip on the Overspeed Governor.

Or 8.7.2.2 Method 2:

8.7.2.2.1 Pull down and hold the EDG A(B) Fuel Rack Override Lever on the North side of the Emergency Diesel Generator A(B) engine.

8.7.2.2.2 To prevent the Emergency Diesel Generator A(B) from Starting, Unlock and Close the following valves:

EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.2.2.3 Release Fuel Rack Override Lever.

8.7.2.2.4 Place the EDG A(B) Fuel Rack Override Lever in the Vertical and Latched position.

8.7.2.2.4.1 Document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document.

49

System Operating Procedure OP-009-002 Emergency Diesel Generator Revision 325 NOTE Depressing the System Reset pushbutton after the EDG has stopped will secure the Standby Fuel Oil Booster Pump, which may help mitigate the fuel oil leak.

8.7.3 If a fuel oil leak is in progress, when the Emergency Diesel Generator A(B) has stopped then depress the System Reset pushbutton.

8.7.4 Verify steps applicable or directed by the SM/CRS in Subsection 6.5, Unloading, Stopping and Returning EDG A(B) to Standby, are completed.

8.7.5 When conditions allow, then Open and lock the valves closed in Step 8.7.2.2.2 EGA-152A(B) A(B) Air Receiver A2(B2) Outlet Isolation EGA-153A(B) A(B) Air Receiver A1(B1) Outlet Isolation 8.7.5.1 Document on Attachment 11.18, Performing an Emergency Shutdown of the Emergency Diesel Generator Valve Restoration, or other, appropriate document.

50

Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE P3 Restore Power to the DCT Sump Pumps Following a Loss of Off Site Power Applicant:

Examiner:

JPM P3 JOB PERFORMANCE MEASURE DATA PAGE Task: Restore power to the DCT Sump Pumps following a Loss of Off Site Power.

Task Standard: Dry Cooling Tower Sump 1 and 2 Sump Pumps are energized from the MCC 314A bus.

References:

OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps Alternate Path: No Time Critical: No Validation Time: 10 Mins.

K/A G2.4.34 Knowledge of RO tasks performed Importance Rating 4.2 / 4.1 outside the main control room during an RO / SRO emergency and the resultant operational effects.

Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 2 Page 2 of 7 2015 NRC Exam

JPM P3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-009, Standard Appendices, Appendix 20, Operation of DCT Sump Pumps

==

Description:==

Applicant will strip non-safety loads from MCC 314 A. The safety to non-safety bus tie breaker will then be closed. The task is complete after the breakers are closed to the train 'A' powered DCT Sump pumps. All elements of this JPM are performed at the 314 A/B Switchgear area on the +1 level of the Fuel Handling Building.

READ TO APPLICANT DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All steps for this JPM will be simulated, do not manipulate any plant components. Make all necessary communications to me. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

NOTE for JPM Validation Only When performing JPM validation, actions are necessary to ensure exam security is maintained. Prior to commencing in plant JPM validation, contact Health Physics and direct them to disable all cameras in the CAA in a manner that prevents anyone from viewing any of the CAA cameras.

After all in plant JPMs are complete, contact Health Physics to restore the disabled cameras.

Revision 2 Page 3 of 7 2015 NRC Exam

JPM P3 TASK ELEMENT 1 STANDARD Procedure Note:

This attachment should be performed following any power interruption to either the 3A or 3B Safety Bus (as directed from EOPs)

If a Probable Maximum Precipitation (PMP) event is in progress and any Dry Cooling Tower (DCT) Motor Driven Sump pump is unavailable, then both of the following shall be performed for the Note reviewed affected DCT sump pump to prevent flooding of associated 315A(B)

Motor Control Center and Transformer within time frames as listed:

One DCT Motor Driven Sump pump is aligned for operation within 30 minutes of the PMP event.

The DCT Portable Sump pump (diesel driven) is aligned for operation within three hours of the PMP event.

Comment:

EVALUATOR CUE: If the applicant should asks, inform the applicant that a PMP event is not in progress. SAT / UNSAT TASK ELEMENT 2 STANDARD

1. At MCC-314A, place BOTH of the following switches to BYPASS:

Both Radiation Monitor DCT #1 Sump Pump A Radiation Monitor Bypass switch Bypass Switches in DCT #2 Sump Pump A Radiation Monitor Bypass switch BYPASS on MCC-314A (cubicles 4F & 5F)

Comment: CRITICAL SAT / UNSAT TASK ELEMENT 3 STANDARD

2. At MCC-314B, place BOTH of the following switches to BYPASS:

Both Radiation Monitor DCT #1 Sump Pump B Radiation Monitor Bypass switch Bypass Switches in DCT #2 Sump Pump B Radiation Monitor Bypass switch BYPASS on MCC-314B (cubicles 5F & 4F)

Comment:

Examiner Note: This step is not critical because if the MCC-314B bypass switches are not positioned to bypass there is still two DCT sump pumps SAT / UNSAT energized from the MCC-314A bus.

TASK ELEMENT 4 STANDARD

3. IF MCC-314A is energized, AND breaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie is open, THEN perform the following: Sequencer timed out is given in Initial Conditions

a. Verify EDG A SEQUENCER is timed out.

Revision 2 Page 4 of 7 2015 NRC Exam

JPM P3 Comment:

EVALUATOR CUE: If asked, inform the applicant that the breaker SSD-EBKR-314A-2M, MCC-314A Safety to Non-Safety Tie mechanical flag SAT / UNSAT says Open; the "CB Close" (red light) is OFF; and the "CB Open" (green light) is ON.

EXAMINER NOTE The following table describes as found breaker positions and position required by applicant. This applies to task element 5. The applicant should not open any safety related breakers on this bus.

Component number Component Description As Found Required position LTN-EBKR-314A-3BL Lighting Panel 349 FHB +46 Fuel Pool ON OFF Underwater Ltg FHS-EBKR-314A-3BR New Fuel Elevator Supply Breaker OFF* OFF SSD-EBKR-314A-3D 480V Power Receptacle ON OFF SSD-EBKR-314A-4BL Fhb Receptacles F1A To F4A ON OFF ACC-EBKR-314A-4BR Wet Cooling Tower A Basin Filtration ON OFF SP-EBKR-314A-4F West Dry Cooling Tower Sump Pump A ON OFF SP-EBKR-314A-4H Fuel Handling Building Sump Pump A ON OFF HVF-EBKR-314A-4M Fhb Normal Exhaust Fan A ON OFF FHS-EBKR-314A-5BL Spent Fuel Handling Machine LOCKED OFF* OFF FHS-EBKR-314A-5BR SFHM Upender OFF OFF FS-EBKR-314A-5D Fuel Pool Purification Pump OFF* OFF SP-EBKR-314A-5F East Dry Cooling Tower Sump Pump A ON OFF HVF-EBKR-314A-5HL FHB HVAC Room Heater ON OFF FS-EBKR-314A-5M Fuel Pool Pump A ON OFF CRN-EBKR-314A-6C Fuel Handling Building Crane ON OFF

Breaker may be ON for new fuel receipt.

TASK ELEMENT 5 STANDARD All breakers on the non-

b. Open ALL MCC-314A Non-Safety Load breakers. safety side of MCC-314A are open.

Revision 2 Page 5 of 7 2015 NRC Exam

JPM P3 Comment:

EVALUATOR CUE: The non-safety side of MCC 314A will be the right side of the tie breaker, where all of the breaker cubicle numbers are > 2. SAT / UNSAT See the note before this task element.

Evaluator Note: This step is not critical because the applicant still meets the task standard if all non-safety loads are not stripped. This step is applicable to diesel loading requirements.

TASK ELEMENT 6 STANDARD SSD-EBKR314A-2M is

c. Close SSD-EBKR-314A-2M, MCC 314A Safety to Non-safety Tie.

closed.

Comment: CRITICAL EVALUATOR CUE: The candidate must lift the CLOSE lever on the face of the tie breaker or depress the CLOSE pushbutton above the CLOSE SAT / UNSAT lever. If the candidate performs either of these actions report the mechanical flag says Closed; the "CB Close" (red light) is ON; and the "CB Open" (green light) is OFF.

EVALUATOR CUE: If a candidate attempts to Close the Safety to Non-Safety Tie using the electrical pushbuttons at the mid level of the cubicle, report that the breaker is still open. These switches (by the red and green lights) are not tied into the circuit.

TASK ELEMENT 7 STANDARD

d. Close BOTH of the following Supply breakers:

SP-EBKR-314A-4F, West Dry Cooling Tower Sump Pump A Both breakers are closed.

SP-EBKR-314A-5F, East Dry Cooling Tower Sump Pump A Comment: CRITICAL The applicant will want to continue on to the B Train. End JPM after this Task Element is completed. SAT / UNSAT END OF TASK Revision 2 Page 6 of 7 2015 NRC Exam

JPM P3 APPLICANT CUE SHEET Do Not Manipulate Any Plant Components (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The Plant has experienced a Loss of Offsite Power and recovery actions of OP-902-003 are being performed.

Emergency Diesel Generators A and B are supplying power to Train A and Train B Safety Buses with both Sequencers timed out.

INITIATING CUE:

The CRS has directed you to restore power to the DCT Sump Pumps 1A, 2A, 1B, and 2B in accordance with OP-902-009, Appendix 20.

Revision 2 Page 7 of 7 2015 NRC Exam

Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S1 ATC Immediate Operator Actions on 2 Dropped CEAs Applicant:

Examiner:

JPM S1 JOB PERFORMANCE MEASURE DATA PAGE Task: ATC Immediate Operator Actions on 2 Dropped CEAs Task Standard: Applicant inserts CEA #79 using the Manual Individual mode per OP-004-004, Control Element Drive Mechanism System and then tripped the reactor using 32 A and 32 B breakers because of two dropped rods in accordance with OP-902-000, Standard Post Trip Actions.

References:

OP-004-004 Control Element Drive Mechanism System OP-901-102, CEA or CEDMCS Malfunction OP-902-000, Standard Post Trip Actions Alternate Path: Yes Time Critical: No Validation Time: 15 mins.

K/A 001 A2.13, ATWS Importance Rating 4.4 / 4.6 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 2 Page 2 of 9 2015 NRC Exam

JPM S1 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

None

==

Description:==

Applicant will insert CEA #79 using the Manual Individual Mode. After the MI insertion, CEAs 79 and 86 will drop into the core. The applicant should notice the condition, announce the condition, and trip the reactor without direction. The normal reactor trip pushbuttons will not function. The applicant should move to the first contingency and use the Diverse Reactor Trip pushbuttons. One of these buttons is faulted. The DRTS alarms will come in, but the CEA MG set load contactors will not open. The applicant should then move to the second contingency, and open both 32 Bus Feeder breakers, and reclose them 5 seconds later. The task should be stopped after the applicant completes the immediate operator actions for the ATC position.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 2 Page 3 of 9 2015 NRC Exam

JPM S1 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-164 Verify the following Malfunctions:

No Trigger o RP01A, RPS manual pushbutton a o RP01B, RPS manual pushbutton b o RP01C, RPS manual pushbutton c o RP01D, RPS manual pushbutton d o M_K04 Fail off Trigger 1:

o RD02A79, dropped CEA 79 o RD02A86, dropped CEA 86 Verify the following Overrides:

No Trigger o DI-02A06S02-1, DRT pushbutton 1 of 2 to OFF Monitor PMC point C33840 (CEA79 position) in the booth and coordinate with examiner to initiate Trigger 1 after CEA #79 has been inserted.

Revision 2 Page 4 of 9 2015 NRC Exam

JPM S1 OP-004-004 Control Element Drive Mechanism System 6.6 Operation of CEAs in Manual Individual (MI) Mode TASK ELEMENT 1 STANDARD Procedure Caution:

IF PLANT MONITORING COMPUTER IS NOT IN OPERATION OR CEA INITIALIZATION PROGRAM NOT RUNNING, THEN CEA GROUP Caution Reviewed MOVEMENT IS PREVENTED DUE TO THE INOPERABLE CEA PULSE COUNTERS. ONLY MANUAL INDIVIDUAL MODE OF CEA CONTROL WILL BE UNAFEECTED.

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Caution:

THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE Caution Reviewed REACTIVITY SAT / UNSAT TASK ELEMENT 3 STANDARD 6.6.1 Select desired CEA to be inserted or withdrawn as follows: Individual selection switch is selected to CEA#79 Position Individual CEA Selection switches to desired CEA Group Select switch is selected to 2.

Position Group Select switch to group containing CEA Critical SAT / UNSAT TASK ELEMENT 4 STANDARD 6.6.2 Place Mode Select switch to MI and verify the following:

MI light Illuminates White lights Illuminates on Group Selection Matrix for Mode Select switch is taken group that contains the CEA to be moved to MI White selection light for individual CEA to be moved Illuminates Critical SAT / UNSAT Revision 2 Page 5 of 9 2015 NRC Exam

JPM S1 TASK ELEMENT 5 STANDARD Procedure Caution:

(1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THE REACTOR IS NOT CRITICAL (2) MISALIGNMENT OF A CEA WITH RESPECT TO THE OTHER CEAS IN ITS GROUP WILL OCCUR WHILE USING MANUAL INDIVIDUAL (MI) MODE OF OPERATION. IF MISALIGNMENT IS Caution Reviewed EXCESSIVE TO CAUSE CONTROL PANEL ALARMS, THEN MOVEMENT SHOULD BE STOPPED. ANY CONTINUATION OF MOVEMENT COULD RESULT IN CORE PROTECTION CALCULATOR (CPC) CHANNEL TRIP OR CAUSE A REACTOR TRIP.

SAT / UNSAT TASK ELEMENT 6 STANDARD RX 6.6.3 Operate CEA Manual Shim switch to WITHDRAW or INSERT CEA to desired height while monitoring the following:

CEA Position Indicator for selected CEA is moving in desired direction. CEA Manual Switch taken to insert and CEA #79 is If Reactor is critical, then monitor the following: inserted Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)

Critical SAT / UNSAT TASK ELEMENT 7 STANDARD Procedure Note:

The area in front of the CEA Drive Mechanism Control Panel should not Note Reviewed be left without the Mode Select switch being placed in OFF.

SAT / UNSAT Revision 2 Page 6 of 9 2015 NRC Exam

JPM S1 TASK ELEMENT 8 STANDARD 6.6.4 When desired set of moves have been completed, Mode Select switch is taken then place Mode Select switch to OFF. to OFF SAT / UNSAT Evaluator Note

1. All of the listed steps are from OP-901-102, CEA or CEDMCS Malfunction, and OP-902-000, Standard Post Trip Actions, but the applicant is required to perform the listed steps from memory.

2. Direct simulator operator to initiate trigger 1 when CEA #79 has been inserted.

TASK ELEMENT 9 STANDARD OP-901-102 D.1. If in Mode 1 and two or more Control Element Pushes both reactor trip Assemblies drop or are misaligned by > 19 inches, then manually trip the pushbuttons on CP-2 or Reactor and go to OP-902-00, Standard Post Trip Actions. CP-8.

Comment: Critical Trip pushbuttons are faulted and Reactor Trip Circuit Breakers will not open. SAT / UNSAT Applicant determines 2 CEAs have dropped, attempts to trip the reactor from CP-2 or CP-8 Critical because not attempting to manually trip the reactor from the reactor control console will cause an inadvertent E-Plan declaration of a Site Area Emergency vs. an Unusual Event TASK ELEMENT 10 STANDARD Pushes both DRTS OP-902-000 1.a.1.2 Manually initiate DIVERSE REACTOR TRIP.

pushbuttons on CP-2.

Comment: Critical One DRTS pushbutton is faulted and CEA MG set load contactors will not open. SAT / UNSAT Critical because not attempting to manually trip the reactor from the reactor control console will cause an inadvertent E-Plan declaration of a Site Area Emergency vs. an Unusual Event.

Revision 2 Page 7 of 9 2015 NRC Exam

JPM S1 TASK ELEMENT 11 STANDARD Opens SST A32 FEEDER OP-902-000 1.a.1.3 Open BOTH the following breakers for 5 seconds and SST B32 FEEDER and close:

breakers for 5 seconds and

SST A32 FEEDER then re-closes both

SST B32 FEEDER breakers.

Comment: Critical Evaluator: If applicant stops after re-closing the A and B 32 Feeder breakers, prompt him as the CRS to perform his Standard Post Trip SAT / UNSAT Actions.

TASK ELEMENT 12 STANDARD

1. Determine Reactivity Control acceptance criteria are met:

Check reactor power is dropping.

Check startup rate is negative. Verifies listed parameters.

Check less than TWO CEAs are NOT fully inserted.

Comment:

Evaluator: Notify the applicant that the JPM is complete after the Reactivity Control Acceptance criteria is complete. SAT / UNSAT END OF TASK Revision 2 Page 8 of 9 2015 NRC Exam

JPM S1 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power.

INITIATING CUES:

Insert CEA #79 using the Manual Individual Mode approximately 3 to 4 inches for I&C post-maintenance.testing.

Revision 2 Page 9 of 9 2015 NRC Exam

Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S2 Charging to the RCS via the HPSI Header Applicant:

Examiner:

JPM S2 JOB PERFORMANCE MEASURE DATA PAGE Task: ATC aligns Charging to HPSI Header A Task Standard: Applicant establishes charging flow to HPSI header A in accordance with OP-901-112, Charging or Letdown Malfunction

References:

OP-901-112, Charging or Letdown Malfunction, revision 6 Alternate Path: No Time Critical: No Validation Time: 9 mins.

K/A 004 A4.08, Charging Importance Rating 3.8 / 3.4 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 8 2015 NRC Exam

JPM S2 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-901-112, Charging or Letdown Malfunction

==

Description:==

This task is performed at CP-8 and CP-4. The operator aligns charging flow to High Pressure Safety Injection (HPSI) Header A due to a rupture of the charging line inside containment. The operator will perform step 6 of section E1 (Charging Malfunction) of OP-901-112, Charging or Letdown Malfunction.

This JPM is to be performed concurrently with JPM S8.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 1 Page 3 of 8 2015 NRC Exam

JPM S2 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-165

2. For 2015 NRC Exam, JPM S8 is performed concurrently.

3. Verify the following Malfunction:

a. CV16 10% severity inserted (active)

4. Verify the following Overrides:

b. None

5. Verify the following Remotes

a. SIR05 for SI-504 on event Trigger 2

b. CVR 27 for CVC-199 on event Trigger 3

6. Booth operator to monitor the HPSI mimic on the PMC to verify Charging pump flow and provide this information to the NRC. (Note: flow indication may be slow to update)

Setup with specific IC unavailable or for non NRC/AUDIT exams:

1. Reset the simulator to an IC in Mode 3

2. Insert malfunction CV16 with a 10% severity

3. Place all Charging pumps in OFF and close CVC-101

4. Allow simulator to run until all conditions stabilize

5. Acknowledge annunciators

6. Place simulator in freeze and save IC Revision 0 Page 4 of 8 2015 NRC Exam

JPM S2 Evaluator Note

7. Cue the Simulator Operator to place the Simulator in RUN.

TASK ELEMENT 1 STANDARD Procedure Caution: Caution reviewed and HPSI IF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS pumps are verified to be not SHOULD NOT BE ALIGNED TO HPSI HEADER. operating.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Note:

Aligning Charging to HPSI Train A renders HPSI train A INOPERABLE Note reviewed.

and Charging Pumps INOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3.

Comment:

Examiner Note: Initial conditions states that TS have already been addressed. SAT / UNSAT

6. IF flow can NOT be established through the normal Charging Pump discharge path, THEN align Charging Pumps to discharge through HPSI Header A as follows:

TASK ELEMENT 3 STANDARD 6.1 Locally open CHARGING HEADER XCONN TO HPSI HEADER A Directs NAO to open SI-ISOLATION (SI 504) 504.

(-35 Wing Area, Col. 6A & L).

Comment: Critical Examiner Note: Cue the booth operator to initiate trigger 2 to open SI-504 SAT / UNSAT Examiner Cue: Inform the applicant that SI-504, Charging Header Xconn to HPSI Header A Isolation, has been opened.

If this step is not completed, there will be no flow to the cold leg selected later in the procedure when the Charging pump is started.

Revision 0 Page 5 of 8 2015 NRC Exam

JPM S2 TASK ELEMENT 4 STANDARD 6.2 Open ONE of the following Train A HPSI COLD LEG INJECTION valves:

1A (SI 225A) Applicant opens one of the 1B (SI 226A) listed Train A HPSI Cold Leg Injection valves.

2A (SI 227A) 2B (SI 228A)

Comment: Critical SAT / UNSAT TASK ELEMENT 5 STANDARD 6.3 Locally open CHARGING PUMPS DISCHARGE TO HPSI ISOLATION Directs the NAO to open (CVC 199)

CVC-199 (Charging Pump Room A).

Comment: Critical Examiner Note: Cue the booth operator to initiate trigger 3 to open CVC-199. SAT / UNSAT Examiner Cue: Inform the applicant that CHARGING PUMPS DISCHARGE TO HPSI ISOLATION (CVC 199) is open.

If this step is not completed, there will be no flow to the cold leg selected later in the procedure when the Charging pump is started.

TASK ELEMENT 6 STANDARD Procedure Note:

Charging Header flow will not indicate with CHARGING PUMPS HEADER Reviewed note ISOLATION VALVE (CVC 209) closed.

Comment:

SAT / UNSAT TASK ELEMENT 7 STANDARD 6.4 Close Charging Pumps Header Isolation Valve (CVC 209). Applicant closes CVC 209.

Revision 0 Page 6 of 8 2015 NRC Exam

JPM S2 Comment: Critical SAT / UNSAT TASK ELEMENT 8 STANDARD 6.5 Operate Charging Pumps as necessary to maintain Pressurizer level Applicant starts at least one within the limits of Attachment 1, Pressurizer Level Versus Tave Curve. Charging Pump Comment: Critical Examiner Note: The applicant may ask the CRS if he desires the seal package running before starting the Charging Pump. Inform the applicant SAT / UNSAT it is not required to start the seal package.

Examiner Note: Loop 1A, 1B, 2A or 2B INJ LINE CHECK VLV LEAKAGE on Cabinet M or Cabinet N is an expected alarm depending on which HPSI FCV was opened.

Examiner Note: The JPM is complete when at least one Charging Pump has been started. If applicant asks which Charging pump should be started, inform applicant to start Charging pump B.

Examiner Note: The applicant can verify flow by checking the SI mimic for flow through the HPSI cold leg selected, monitoring Pressurizer level, or a slight increase in flow on the indicator on CP-8 for the path selected. Loop 1A, 1B, 2A or 2B INJ LINE CHECK VLV LEAKAGE on Cabinet M or Cabinet N would also be indication of flow.

If any valve (including local valves) are not manipulated correctly, charging flow will not be initiated to the HPSI header.

Expected Charging flow will be approximately 40 gpm. The Charging pumps are positive displacement pumps that deliver 44 gpm flow.

END OF TASK Revision 0 Page 7 of 8 2015 NRC Exam

JPM S2 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 3 The normal charging path is not available due to a break downstream of CVC-209.

The crew is responding in accordance with OP-901-112, Charging or Letdown Malfunction.

Letdown Stop Valve (CVC-101) is closed and all Charging Pumps are in OFF in accordance with Section E1, step 5, Charging or Letdown Malfunction.

Tech Spec implications for this event have already been addressed.

INITIATING CUES:

The CRS has directed you to align Charging to the RCS via the HPSI Header in accordance with OP-901-112, Charging or Letdown Malfunction, sect. E1 step 6.

Once Charging is aligned to the HPSI Header, you are directed to maintain pressurizer level 33%-35%.

Revision 0 Page 8 of 8 2015 NRC Exam

Off Normal Procedure OP-901-112 Charging or Letdown Malfunction Revision 006 E1 CHARGING MALFUNCTION (CONTD)

CAUTION IF HPSI PUMPS ARE OPERATING, THEN CHARGING PUMPS SHOULD NOT BE ALIGNED TO HPSI HEADER.

NOTE Aligning Charging to HPSI Train A renders HPSI train A INOPERABLE and Charging Pumps INOPERABLE. Enter TS 3.5.2 and 3.1.2.4. Refer to TS 3.5.3.

PLACEKEEPER START DONE N/A

6. IF flow can NOT be established through the normal Charging Pump discharge path, THEN align Charging Pumps to discharge through HPSI Header A as follows:

6.1 Locally open CHARGING HEADER XCONN TO HPSI HEADER A ISOLATION (SI 504)

(-35 Wing Area, Col. 6A & L).

6.2 Open ONE of the following Train A HPSI COLD LEG INJECTION valves:

1A (SI 225A) 1B (SI 226A) 2A (SI 227A) 2B (SI 228A) 6.3 Locally open CHARGING PUMPS DISCHARGE TO HPSI ISOLATION (CVC 199)

(Charging Pump Room A).

11

Off Normal Procedure OP-901-112 Charging or Letdown Malfunction Revision 006 E1 CHARGING MALFUNCTION (CONTD)

PLACEKEEPER START DONE N/A NOTE Charging Header flow will not indicate with CHARGING PUMPS HEADER ISOLATION VALVE (CVC 209) closed.

6.4 Close Charging Pumps Header Isolation Valve (CVC 209).

6.5 Operate Charging Pumps as necessary to maintain Pressurizer level within the limits of Attachment 1, Pressurizer Level Versus Tave Curve.

7. WHEN repairs have been completed to the Charging Header, THEN restore Charging Pumps discharge alignment to normal as follows:

7.1 Stop ALL Charging Pumps.

7.2 Restore HPSI Header as follows:

7.2.1 Locally close CHARGING HEADER XCONN TO HPSI HEADER A ISOLATION (SI 504)

(-35 Wing Area, Col. 6A & L).

7.2.2 Verify closed the following Train A HPSI COLD LEG INJECTION valves:

1A (SI 225A) 1B (SI 226A) 2A (SI 227A) 2B (SI 228A) 7.2.3 Locally close CHARGING PUMP DISCHARGE TO HPSI ISOLATION (CVC 199) (Charging Pump Room A).

12

Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S3 Place Shutdown Cooling Train B in Service Applicant:

Examiner:

JPM S3 JOB PERFORMANCE MEASURE DATA PAGE Task: Place Shutdown Cooling Train B in Service Task Standard: Applicant places Shutdown Cooling Train B in service in accordance with OP-009-005 and secures Low Pressure Safety Injection Pump B after SI-405B fails closed in accordance with OP-901-131, Shutdown Cooling Malfunction.

References:

OP-009-005, Shutdown Cooling OP-901-131, Shutdown Cooling Malfunction Alternate Path: Yes Time Critical: No Validation Time: 20 mins.

K/A 005 A4.01, Controls and indication for RHR Importance Rating 3.6 / 3.4 pumps RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 12 2015 NRC Exam

JPM S3 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-009-005, Shutdown Cooling

==

Description:==

This task is performed at CP-8. The applicant must place Shutdown Cooling Train B in service. The fault in this task is that SI-405B, RC Loop 2 SDC Suction Inside Containment Isol, will fail closed, requiring the applicant to secure Low Pressure Safety Injection Pump B. The task can be stopped after LPSI Pump B is secured.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet (next page),

and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 12 2015 NRC Exam

JPM S3 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-167 Verify the following Malfunctions:

SI23B for SI-405B on Trigger 1 Coordinate with the examiner so that when SI-135 B is fully closed at step 6.2.12.3, Trigger 1 is initiated to close SI-405B. (Use Extreme View to monitor SI-135B position)

Revision 0 Page 4 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 1 STANDARD Procedure Caution: THE FOLLOWING SECTION HAS THE Caution reviewed.

POTENTIAL TO AFFECT CORE REACTIVITY.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Note:

(1)The Shutdown Cooling Train placed in service should be on the Protected Train.

(2) The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the Notes reviewed.

vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.

Comment:

Protected Train is B as given in initial conditions.

SAT / UNSAT TASK ELEMENT 3 STANDARD Procedure Caution: Following a design basis tornado event, delaying the initiation of Shutdown Cooling (SDC) for up to 7 days will be required to ensure the Component Cooling Water System is capable of removing Reactor Coolant System decay heat. The actual delay time Caution reviewed.

will depend on UHS damage and ambient temperature and will be determined by engineering. Emergency Feedwater supports decay heat removal until SDC can be initiated.

Comment:

SAT / UNSAT TASK ELEMENT 4 STANDARD 6.2.1: Verify Shutdown Cooling Train B has been aligned to Standby Notes Section 5.4 is complete condition in accordance with Section 5.4, Alignment of Shutdown and continues in procedure.

Cooling Train B to Standby Condition.

Comment:

Cue sheet lists this as complete.

SAT / UNSAT Revision 0 Page 5 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 5 STANDARD 6.2.2: Verify sufficient number of Dry Cooling Tower Fans running to Continues in procedure after accept increased heat load on CCW System. cue.

Comment:

EVALUATOR CUE: Inform the applicant to leave the Dry Cooling SAT / UNSAT Tower Fans in automatic and allow Auxiliary Component Cooling Water to pick up the heat load.

TASK ELEMENT 6 STANDARD Procedure Caution:

(1)CC-963B is required to be maintained open while in Mode 4 to preserve the design temperature basis of piping and associated components at the CCW outlet of shutdown cooling heat exchanger B.

With CC-963B open, flow through Shutdown Cooling Heat Exchanger Caution reviewed.

A will be maintained above 2305 gpm.

(2) Shutdown Heat Exchanger B CCW Flow Control, CC-963B, is also required to remain open if LPSI pump B discharge flow control, SI-129B has been forced closed per OP-009-008 following a loss of instrument air.

Comment:

SAT / UNSAT TASK ELEMENT 7 STANDARD 6.2.3: Place Shutdown HX B CCW Flow Control, CC-963B, control CC-963 B control switch taken switch to Open. to the open position.

Comment: Critical SAT / UNSAT Revision 0 Page 6 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 8 STANDARD Procedure Caution:

(1) The following Reactor Coolant System limits shall be met for Shutdown Cooling Entry:

RCS temperature limit: < 350 °F RCS pressure limit: < 392 psia If Containment harsh environment conditions (>200°F) have Caution reviewed.

been exceeded then RCS pressure limit: <358 Psia (2) If Containment Spray Header B Isolation, CS-125 B, is open while Shutdown Cooling Train B is operating, then Containment Spray B riser may fill and possibly spray water into Containment, due to leakage past Containment Spray Pump A discharge stop check, CS-117B.

Comment:

SAT / UNSAT TASK ELEMENT 9 STANDARD 6.2.4: To minimize the effect of air introduction to a LPSI pump Verify RC Loop 2 SDC suction piping meets one of the following conditions:

The SDC Train is placed in-service with RCS pressure > 100 PSIA by PMC indication (PIDs A12203, A12204, A12222) or >

One of the conditions is 110 PSIA by board indication (RC-IPI0103,-0104,-0105,-0106).

verified. Cue sheet lists SDC or Train B suction penetration has The SDC Trains suction penetration has been manually been manually vented in vented. Venting should be accomplished through SI-4051B accordance with Attachment using RCS/Cavity as water source in accordance with 11.7 (satisfies second bullet).

Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping.

or The SDC Train was previously in-service since the unit has been shutdown.

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 6.2.5: Unlock and Open RC Loop 1 SDC Suction Outside Containment SI-407 B is open.

Isol, SI-407B.

Comment: Critical Key 142 required.

SAT / UNSAT Revision 0 Page 7 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 11 STANDARD 6.2.6: Inform Radiation Protection Department that Shutdown Cooling Call is made.

Train B is being placed in service.

Comment:

SAT / UNSAT TASK ELEMENT 12 STANDARD 6.2.7: Start LPSI Pump B. LPSI Pump B is started.

Comment: Critical Annunciator LPSI Pump B Flow Lost (Cabinet N, F-13) is expected. It will clear when the applicant raises flow > 2900 gpm. SAT / UNSAT TASK ELEMENT 13 STANDARD Procedure Note: If Instrument Air is unavailable, LPSI Pump B Discharge Flow Control, SI-129B, will need to be operated locally per OP-009-008. If the safeguards rooms are inaccessible (post RAS),

LPSI Pump B Discharge Flow Control, SI-129B, must be remotely Note reviewed.

forced closed per OP-009-008. In this case, SDC flow/temperature will need to be controlled using Shutdown Cooling HX B Temperature Control, SI-415B.

Comment:

SAT / UNSAT TASK ELEMENT 14 STANDARD 6.2.8: Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow controller 1A/1B, SI-IFIC-0306, output until Shutdown Cooling Header B Flow indicates 4100 GPM, as Flow is raised to ~ 4100 GPM.

indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

Comment: Critical SAT / UNSAT Revision 0 Page 8 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 15 STANDARD 6.2.9: Adjust LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, Setpoint potentiometer is ~

setpoint potentiometer to 73%, and place controller to AUTO. 73%, and controller is in AUTO Comment: Critical SAT / UNSAT TASK ELEMENT 16 STANDARD 6.2.10: Verify LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, is maintaining 4100 GPM Shutdown Cooling Header A flow, as Flow is verified.

indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

Comment:

SAT / UNSAT TASK ELEMENT 17 STANDARD Procedure note: If a sample was drawn prior to shutdown and no interim shutdown has occurred where SDC was placed in service and Note reviewed.

boron concentration could have been reduced, then sampling is not required.

Comment:

SAT / UNSAT TASK ELEMENT 18 STANDARD 6.2.11: At SM/CRS discretion, direct Chemistry Department to sample None Shutdown Cooling Train B for boron concentration.

Comment:

EVALUATOR CUE: When requested provide information to applicant SAT / UNSAT that all required Chemistry requirements are met.

Revision 0 Page 9 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 19 STANDARD Procedure Note: Shutdown Cooling Train B requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be Note reviewed.

operable.

Comment:

SAT / UNSAT TASK ELEMENT 20 STANDARD Procedure Caution: The Reactor Coolant System shall not exceed the Caution reviewed.

100 °F per hour cooldown rate of Technical Specification 3.4.8.1.

Comment:

Examiner Note: If asked, state that another operator is tracking SAT / UNSAT cooldown rates.

6.2.12 Raise Shutdown Cooling Train B temperature to within 100 °F of Reactor Coolant Hot temperature as follows:

TASK ELEMENT 21 STANDARD 6.2.12.1: Open the following valves:

SI-139 B and SI-138 B are SI-139B LPSI Header to RC Loop 1A Flow Control open.

SI-138B LPSI Header to RC Loop 1B Flow Control Comment: Critical SAT / UNSAT TASK ELEMENT 21 STANDARD 6.2.12.2: Throttle Closed RC Loop 1 Shdn Cooling Warmup, SI-135B, until one of the following is within 100°F of Shutdown Cooling Train B temperature, as indicated by LPSI Pump B Discharge Header Temperature Indicator, SI-ITI-0352X:

Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Temperature is within 100 °F Leg Temperature Indicator, RC-ITI-0112-HB or Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg Temperature Indicator, RC-ITI-0122-HA Comment: Critical SI-135 B is a large gate valve with a very long stroke. SAT / UNSAT Revision 0 Page 10 of 12 2015 NRC Exam

JPM S3 TASK ELEMENT 22 STANDARD 6.2.12.3: Close RC Loop 2 Shdn Cooling Warmup, SI-135 B. SI-135 B is closed Comment: Critical SAT / UNSAT Evaluator Note Coordinate with the simulator operator to initiate trigger 1 to close SI-405 B.

TASK ELEMENT 23 STANDARD Secure LPSI Pump B LPSI Pump B is off.

Comment: Critical This is an immediate operator action in accordance with OP-901-131, SAT / UNSAT Shutdown Cooling Malfunction, section D.1.

END OF TASK Revision 0 Page 11 of 12 2015 NRC Exam

JPM S3 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 4 Protected Train is B RCS temperature is approximately 322 °F RCS pressure is approximately 370 PSIA Shutdown Cooling Train A is in service.

SDC Train B suction penetration piping has been manually vented in accordance with Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping.

Shutdown Cooling Train B has been placed in Standby in accordance with OP-009-005, Shutdown Cooling, section 5.4.

INITIATING CUE:

The CRS has directed you to place Shutdown Cooling Train B in service in accordance with OP-009-005, section 6.2.

Revision 0 Page 12 of 12 2015 NRC Exam

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 The maximum temperature for Purification Ion Exchanger(s) is 140 F.

3.1.2 If Letdown to Ion Exchangers Inlet/Bypass, CVC-140, is in AUTO then Purification Ion Exchangers will automatically bypass at 140 F.

3.1.3 The following applies to Shutdown Cooling flow:

3.1.3.1 A total minimum Shutdown Cooling flow necessary to remove decay heat and prevent boron stratification should be maintained at all times.

3.1.3.2 When considering the minimum Shutdown Cooling flow required to adequately remove decay heat and prevent boron stratification, then the flow from the operating Shutdown Cooling train or the combined flow of both operating Shutdown Cooling trains may be used.

3.1.3.3 The required minimum Shutdown Cooling flow for Modes 5 and 6 are as follows:

TIME AFTER SHUTDOWN (HOURS) REQUIRED FLOW (GPM) 0 - <175 hours 4000 GPM 175 - <375 hours 3000 GPM 375 hours0.00434 days 0.104 hours 6.200397e-4 weeks 1.426875e-4 months 2000 GPM If the Reactor has been shutdown <175 hours, then Shutdown Cooling flow may be reduced to 3000 GPM, if RCS temperature is verified to be

<135 F at least once per hour.

3.1.3.4 Changes to the Shutdown Cooling flow rate will cause the Alternate Shutdown Cooling Purification flow rate to change with SI-424 throttled or full open. For example, with Alternate Shutdown Cooling Purification in service via SI-424, if Shutdown Cooling flow rate is lowered, then the Alternate Shutdown Cooling Purification flow rate will increase due to increased LPSI Discharge Header pressure. This change in flow rate may require readjustment of SI-424 so the 250 GPM limit is not exceeded.

3.1.3.5 The maximum Shutdown Cooling Flow rate to prevent vortexing for one train operating at RCS Midloop condition is 3130 gpm. Refer to Attachment 11.6, SDC Maximum Flowrates to Prevent Vortexing (Per Train), for additional flow rates. [ECM98-007]

5

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.1.3.6 The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.

3.1.4 LPSI pumps shall not be run for >3 hours in any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period on recirculation flow only.

3.1.5 If LPSI Pump flow is limited to >100 gpm and <2000 gpm for 3 consecutive hours, then contact the System Engineer for guidance on LPSI Pump monitoring.

[CR-W3-2000-1376]

3.1.6 To minimize a hydraulic transient that could challenge the integrity of SI-406A(B) during the opening of SI-405A(B), one of the following conditions shall be met prior to opening SI-405A(B). [ EC-14765, ECN-25944]

Piping between SI-407A(B) and SI-405A(B) is pressurized through SI-4052A(B) with SI-401A(A) open.

or The SDC Trains suction penetration piping has been manually vented.

Venting should be accomplished in accordance with Attachment 11.7, Manual Venting of SDC Train suction penetration piping.

or The SDC Train was previously in-service since the unit has been shutdown.

or If RC Loop 2(1) SDC Suct Hdr Press Equalizing and Insd Cntmnt Isol, SI-4052A(B) fails to open, RCS pressure is <213 psia by PMC indication (PIDs A12203, A12204, A12221, A12222) or <203 psia by control board indication (RC-IPI0103, -0104, -0105, -0106).

[ EC-14765, ECN-25944]

3.1.7 The preferred pressure indication to use for entering shutdown cooling is RC-IPI-0103, RC-IPI-0104, RC-IPI-0105, and RC-IPI-0106 or the associated PMC PIDs A12203, A12204, A12221, and A12222. The highest indication on functioning instrumentation should be used to make the entry decision. Low Range RCS pressure indication is preferred because at shutdown cooling entry conditions this pressure instrumentation is the least affected by instrument uncertainties.

3.1.8 A RCS pressure limitation is established for SDC entry if Containment Harsh Environment Conditions (>200°F) have been exceeded. This limitation is to prevent lifting SDC suction thermal relief valves SI-408A or SI-408B.

6

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.2 LIMITATIONS 3.2.1 Shutdown Cooling shall not be initiated until Reactor Coolant System (RCS) temperature <350 F and RCS Pressure <392 PSIA. [P-4055]

3.2.2 If Containment Harsh Environment Conditions (>200°F) have been exceeded then SDC shall not be initiated until RCS Pressure <358 PSIA. [CR-WF3-2012-1036]

3.2.3 RCS temperature changes shall be limited by the following:

A maximum heatup rate of 60 F per hour A maximum cooldown rate of 100 F per hour 3.2.4 RCS temperature and pressure shall be limited in accordance with the limit lines shown on Technical Specification Figures 3.4-2 and 3.4-3 with instrument uncertainty incorporated for pressure and temperature as follows:

[ER-W3-2004-00439]

Subtract 30 F from indicated temperature Add 35 PSI to the indicated pressure from the following instruments:

CP-2 RC IPI0103 (100-750 PSIA)

RC IPI0104 (100-750 PSIA)

CP-4 RC IPI0105 (100-750 PSIA)

RC IPI0106 (100-750 PSIA)

CP-7 RC IPI0101A(B,C,D) (1500-2500 PSIA)

LCP-43 RC IPI0105-1 (100-750 PSIA)

RC IPI0106-1 (100-750 PSIA)

Add 110 PSI to the indicated pressure from the following instruments:

CP-2 RC IPI0102A3 (B3) (0-3000 PSIA)

CP-4 RC IPI0102A2 (B2) (0-3000 PSIA)

CP-7 RC IPI0102A (B,C,D) (0-3000 PSIA)

LCP-43 RC IPI0102A1 (B1,C1,D1) (0-3000 PSIA) 7

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.2.5 Maximum flow through a Purification Ion Exchanger is 126 GPM.

3.2.6 When RCS is in Mode 4 and any RCS Cold Leg temperature is <230 F or in Mode 5 or Mode 6 with Reactor Vessel Head on, then Low Temperature Overpressure Protection (Tech. Spec. 3.4.8.3) shall be provided by one of the following: [P-5804]

Both Shutdown Cooling Suction Header Relief Valves aligned to RCS or RCS depressurized with an RCS vent 5.6 in2 3.2.7 In Mode 4 with RCS pressure >400 PSIA, Both Containment Spray Trains shall be operable in accordance with Tech Spec 3.6.2.1.

3.2.8 The Shutdown Cooling Train placed in service should be on the Protected Train.

3.2.9 Scaffolding will be required to Vent CS Header A, when restoring CS to operation after securing Shutdown Cooling.

3.3.10 Shutdown Cooling requires one Operable Low Pressure Safety Injection Flow Control Valve per train for Shutdown Cooling to be Operable.

3.3.11 The Shutdown Cooling suction line piping upstream of SI-407A(B) should not be filled from an external water source due to the potential to cause thermal binding of SI-405A(B). There is a possibility of air intrusion into and voiding of the Shutdown Cooling suction line piping upstream of SI-407A(B) following a period of operation in Modes 1 - 4, when the Safety Injection and Containment Spray Systems are aligned for the normal injection mode. This condition has been evaluated and is described in the Design Basis Document for the Safety Injection System (W3-DBD-001). The Safety Injection System retains the capability of performing its design safety function with the described voiding and no actions are required to fill the subject section of piping.

[ER-W3-2002-0283-002, CR-WF3-2004-01300, ECM03-003, W3-DBD-01]

8

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.2.12 Each pump start stresses motor windings both thermally and mechanically. A start means motor comes up to rated speed. Starts for LPSI pumps should be limited as follows:

3.2.12.1 LPSI Pump A:

3.2.12.1.1 With motor at ambient temperature, do not attempt more than 6 consecutive starts.

3.2.12.1.2 With motor at operating temperature, do not attempt more than 4 consecutive starts.

3.2.12.1.3 Allowed time between additional starts is 15 minutes with motor at operating temperature or 30 minutes with motor at ambient temperature.

3.2.12.2 LPSI Pump B:

3.2.12.2.1 With motor at ambient temperature, do not attempt more than 2 consecutive starts.

3.2.12.2.2 With motor at operating temperature, do not attempt more than 1 consecutive start.

3.2.12.2.3 Allowed time between additional starts is 15 minutes with motor at operating temperature or 45 minutes with motor at ambient temperature.

3.2.13 Following a Design Basis Tornado Event, delaying the initiation of Shutdown Cooling (SDC) for up to 7 days will be required to ensure the Component Cooling Water system is capable of removing Reactor Coolant System decay heat. The actual delay time will depend on UHS damage and ambient temperature and will be determined by Engineering. Emergency Feedwater supports decay heat removal until SDC can be initiated. [EC-530]

9

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 3.2.14 To assure that the RCS does not drop to the minimum RCS bolt up Temperature indicated on TS figures 3.4-2 and 3.4-3, the limits on the following instruments apply:

Instrument Description Min Value Location SI IT7114 / SI IT7115 RWSP Temperature 67.3°F PMC SI IT0351 X / SI IT0352 X LPSI Pump Outlet Temperature 66.09°F QSPDS CS IT0303 X AND Y Shutdown Cooling Outlet Temperature 66.09°F QSPDS 3.2.15 When Alternate Shutdown Cooling Purification is aligned with parallel Purification Ion Exchangers and SI-424 is throttled or full open, then:

A maximum Total Shutdown Cooling Purification flow of 250 GPM should not be exceeded.

A minimum Total Shutdown Cooling Purification flow of 50 GPM should be minimized.

If Total Shutdown Cooling Purification flow is to be <50 GPM, then single Purification Ion Exchanger operation is required.

PMC PID S39205, SDC/LD Purification Full Range Flow is the only available indication when Letdown flow is >150 GPM.

10

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 CAUTION RX THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.

[INPO 06-006]

6.2 PLACING SHUTDOWN COOLING TRAIN B IN SERVICE NOTE (1) The Shutdown Cooling Train placed in service should be on the Protected Train.

(2) The SDC loop may be removed from operations for up to one hour per 8-hour period during the performance of Core Alterations in the vicinity of the reactor pressure vessel hot legs, provided no operations are permitted that would cause introduction into the RCS, coolant with boron concentration less than required to meet the minimum required boron concentration of Technical Specification 3.9.1.

CAUTION FOLLOWING A DESIGN BASIS TORNADO EVENT, DELAYING THE INITIATION OF SHUTDOWN COOLING (SDC) FOR UP TO 7 DAYS WILL BE REQUIRED TO ENSURE THE COMPONENT COOLING WATER SYSTEM IS CAPABLE OF REMOVING REACTOR COOLANT SYSTEM DECAY HEAT. THE ACTUAL DELAY TIME WILL DEPEND ON UHS DAMAGE AND AMBIENT TEMPERATURE AND WILL BE DETERMINED BY ENGINEERING. EMERGENCY FEEDWATER SUPPORTS DECAY HEAT REMOVAL UNTIL SDC CAN BE INITIATED. [EC-530]

6.2.1 Verify Shutdown Cooling Train B has been aligned to Standby condition in accordance with Section 5.4, Alignment of Shutdown Cooling Train B to Standby Condition.

6.2.2 Verify sufficient number of Dry Cooling Tower Fans running to accept increased heat load on CCW System.

30

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 CAUTION (1) CC-963B IS REQUIRED TO BE MAINTAINED OPEN WHILE IN MODE 4 TO PRESERVE THE DESIGN TEMPERATURE BASIS OF PIPING AND ASSOCIATED COMPONENTS AT THE CCW OUTLET OF SHUTDOWN COOLING HEAT EXCHANGER B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLING HEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM. [EC-738] [EC-30976]

(2) SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSO REQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL, SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OF INSTRUMENT AIR.

6.2.3 Place Shutdown HX B CCW Flow Control, CC-963B, control switch to Open.

CAUTION

1) THE FOLLOWING REACTOR COOLANT SYSTEM LIMITS SHALL BE MET FOR SHUTDOWN COOLING ENTRY:

RCS TEMPERATURE LIMIT: <350 F RCS PRESSURE LIMIT: <392 PSIA IF CONTAINMENT HARSH ENVIRONMENT CONDITIONS (>200°F) HAVE BEEN EXCEEDED THEN RCS PRESSURE LIMIT: <358 PSIA (2) IF CONTAINMENT SPRAY HEADER B ISOLATION, CS-125B, IS OPEN WHILE SHUTDOWN COOLING TRAIN B IS OPERATING, THEN CONTAINMENT SPRAY B RISER MAY FILL AND POSSIBLY SPRAY WATER INTO CONTAINMENT, DUE TO LEAKAGE PAST CONTAINMENT SPRAY PUMP B DISCHARGE STOP CHECK, CS-117B.

6.2.4 To minimize the effect of air introduction to a LPSI Pump Verify RC Loop 2 SDC suction piping meets one of the following conditions:

The SDC Train is placed in-service with RCS pressure 100 PSIA by PMC indication (PIDs A12203, A12204, A12221, A12222) or 110 PSIA by board indication (RC-IPI0103, -0104, -0105, -0106).

or The SDC Trains suction penetration piping has been manually vented.

Venting should be accomplished through SI-4051B using RCS/Cavity as water source in accordance with Attachment 11.7, Manual Venting of SDC Train Suction Penetration Piping.

31

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 or The SDC Train was previously in-service since the unit has been shutdown.

6.2.5 Unlock and Open RC Loop 1 SDC Suction Outside Containment Isol, SI-407B.

6.2.6 Inform Radiation Protection Department that Shutdown Cooling Train B is being placed in service.

6.2.7 Start LPSI Pump B.

NOTE If Instrument Air is unavailable, LPSI Pump B Discharge Flow Control, SI-129B, will need to be operated locally per OP-009-008. If the Safeguards rooms are inaccessible (post RAS),

LPSI Pump B Discharge Flow Control, SI-129B, must be remotely forced closed per OP-009-008. In this case, SDC flow/ temperature will need to be controlled using Shutdown Cooling HX B Temperature Control, SI-415B. [EC-30976]

6.2.8 Raise Shutdown Cooling flow by Manually adjusting LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, output until Shutdown Cooling Header B flow indicates 4100 GPM, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

6.2.9 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to 73%, and place controller to AUTO.

6.2.10 Verify LPSI Header Flow Controller 1A/1B, SI-IFIC-0306, is maintaining 4100 GPM Shutdown Cooling Header B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

NOTE If a sample was drawn prior to shutdown and no interim shutdown has occurred where SDC was placed in service and boron concentration could have been reduced, then sampling is not required.

6.2.11 At SM/CRS discretion, direct Chemistry Department to sample Shutdown Cooling Train B for boron concentration.

6.2.11.1 When Chemical Analysis results indicate that Shutdown Cooling Train B boron concentration is greater than Reactor Coolant boron concentration or 2050 PPM (required for Mode 6), then proceed to next step.

32

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 NOTE Shutdown Cooling Train B requires one operable Low Pressure Safety Injection Flow Control Valve for the train to be operable.

CAUTION THE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOUR COOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1.

RX 6.2.12 Raise Shutdown Cooling Train B temperature to within 100 F of Reactor Coolant Hot Leg temperature as follows:

6.2.12.1 Open the following valves:

SI-139B LPSI Header to RC Loop 1A Flow Control SI-138B LPSI Header to RC Loop 1B Flow Control 33

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 6.2.12.2 Throttle Closed RC Loop 1 Shdn Cooling Warmup, SI-135B, until one of the following is within 100 F of Shutdown Cooling Train B temperature, as indicated by LPSI Pump B Discharge Header Temperature Indicator, SI-ITI-0352X: [P-23174]

Hot Leg 1 temperature, as indicated by RC Loop 1 Hot Leg Temperature Indicator, RC-ITI-0112-HB or Hot Leg 2 temperature, as indicated by RC Loop 2 Hot Leg Temperature Indicator, RC-ITI-0122-HA 6.2.12.3 Close RC Loop 1 Shdn Cooling Warmup, SI-135B.

CAUTION THE FOLLOWING APPLIES TO SHUTDOWN COOLING FLOW:

(1) A TOTAL MINIMUM SHUTDOWN COOLING FLOW NECESSARY TO REMOVE DECAY HEAT AND PREVENT BORON STRATIFICATION SHOULD BE MAINTAINED AT ALL TIMES.

(2) WHEN CONSIDERING THE MINIMUM SHUTDOWN COOLING FLOW REQUIRED TO ADEQUATELY REMOVE DECAY HEAT AND PREVENT BORON STRATIFICATION, THE FLOW OF BOTH OPERATING SHUTDOWN COOLING TRAINS MAY BE USED.

(3) THE REQUIRED MINIMUM SHUTDOWN COOLING FLOW FOR MODES 5 AND 6 ARE AS FOLLOWS:

TIME AFTER SHUTDOWN (HOURS) REQUIRED FLOW (GPM)

<175 HOURS

4000 GPM 175 HOURS 3000 GPM 375 HOURS 2000 GPM

IF THE REACTOR HAS BEEN SHUTDOWN <175 HOURS, THEN SHUTDOWN COOLING FLOW MAY BE REDUCED TO 3000 GPM IF RCS TEMPERATURE IS VERIFIED TO BE <135 F AT LEAST ONCE PER HOUR.

6.2.13 Adjust LPSI Header Flow controller 1A/1B, SI-IFIC-0306, setpoint potentiometer to obtain desired Shutdown Cooling Train B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

34

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 CAUTION (1) THE REACTOR COOLANT SYSTEM SHALL NOT EXCEED THE 100 F PER HOUR COOLDOWN RATE OF TECHNICAL SPECIFICATION 3.4.8.1.

(2) CC-963B IS REQUIRED TO BE MAINTAINED OPEN WHILE IN MODE 4 TO PRESERVE THE DESIGN TEMPERATURE BASIS OF PIPING AND ASSOCIATED COMPONENTS AT THE CCW OUTLET OF SHUTDOWN COOLING HEAT EXCHANGER B. WITH CC-963B OPEN, FLOW THROUGH SHUTDOWN COOLING HEAT EXCHANGER B WILL BE MAINTAINED ABOVE 2305 GPM. [EC-738] [EC-30976]

(3) SHUTDOWN HEAT EXCHANGER B CCW FLOW CONTROL, CC-963B, IS ALSO REQUIRED TO REMAIN OPEN IF LPSI PUMP B DISCHARGE FLOW CONTROL, SI-129B HAS BEEN FORCED CLOSED PER OP-009-008 FOLLOWING A LOSS OF INSTRUMENT AIR.

RX 6.2.14 Maintain RCS temperature control as follows:

6.2.14.1 Throttle Open Shutdown Cooling HX B Temperature Control, SI-415B, as required.

6.2.14.2 Place Shutdown HX B CCW Flow Control, CC-963B, to Open or Setpoint, as required.

NOTE Once activated the SHUTDOWN COOLING TROUBLE annunciator (Window H-18 on cabinet N) will alarm since the Low Flow setpoints are initially failed High.

6.2.15 Verify Computer Point PID B43800, SDCS Alarm Processing, set to ACTIVE state in accordance with OP-004-012, Plant Computer System.

6.2.16 Verify Computer Point PID K43201, SDCS/LPSI PMP B LOW FLOW LIM, set to approximately 200 gpm below the established Shutdown Cooling Train B flow, as indicated by RC Loop 1 Shdn Line Flow Indicator, SI-IFI-1306-B1.

6.2.17 If Shutdown Cooling Train A is not in service, then set Computer Point PID K43101 SDCS/LPSI PMP A LOW FLOW LIM, to Zero in accordance with OP-004-012, Plant Computer System.

6.2.18 If CETs from QSPDS Channel 1(2) are not available, then set PID C26417(C26510), TRCET Representative CET, to Zero.

6.2.19 Verify SHUTDOWN COOLING TROUBLE annunciator (WINDOW H-18 ON CABINET N) is Clear.

35

System Operating Procedure OP-009-005 Shutdown Cooling Revision 035 NOTE (1) Due to thermal expansion, the Shutdown Cooling Heat Exchanger A Outlet Stop Check, CS-117A, must be re-tightened in the Closed direction approximately 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months after Shutdown Cooling Train A is placed in service.

(2) To ensure CS-117A(B) properly seats when the valve reaches the closed position, it is necessary to apply sufficient torque in the closed direction, approximately 100 lbf on the installed handwheel, until the torque-limiter slips.

6.2.20 Verify Closed Shutdown Cooling Heat Exchanger B Stop Check, CS-117B, approximately 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months after Shutdown Cooling Train B is placed in service.

6.2.21 If splitting of CCW Trains is necessary as directed by the SM/CRS, then go to Section 6.13, Splitting Out CCW Trains when on Shutdown Cooling.

36

Waterford 3 2015 NRC RO Exam JOB PERFORMANCE MEASURE S4 Balance of Plant Operator Immediate Operator Actions on Control Room Evacuation Applicant:

Examiner:

JPM S4 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform balance of plant operators immediate operator action on Control Room evacuation with fire conditions.

Task Standard: Applicant performed immediate operator actions for BOP position for a fire in the Control Room in accordance with OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown.

Applicant manually closed Atmospheric Dump Valve #2 due to setpoint failure.

References:

OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown Alternate Path: Yes Time Critical: No Validation Time: 4 mins.

K/A 039 A4.01 Main Steam Supply Valves Importance Rating 2.9 / 2.8 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 7 2015 NRC Exam

JPM S4 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

None

==

Description:==

The applicant will be cued that there is a fire in CP-33. The CRS will direct him to carry out his immediate operator actions as BOP operator. ADV #2 setpoint will fail to 666 PSIG, spuriously opening ADV #2. The applicant will be required to place that controller to manual and set it to 0% output to close ADV #2. The task will end when the applicant goes to the key locker.

DIRECTION TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 7 2015 NRC Exam

JPM S4 SIMULATOR OPERATOR INSTRUCTIONS Reset to IC-166 Verify the following Malfunctions:

o MS23B to 666 psi on Trigger 1 with a 5 second delay Verify the following Overrides:

o DI-02A04S01-0 on Trigger 1 (Reactor Trip push button 'A')

o DI-02A04S02-0 on Trigger 1 (Reactor Trip push button 'D')

Coordinate with examiner to initiate Trigger 1 on his cue. This will trip the reactor and insert the ADV #2 malfunction.

Revision 0 Page 4 of 7 2015 NRC Exam

JPM S4 Evaluator Note Cue the Simulator Operator to place the Simulator in RUN and initiate Trigger 1.

TASK ELEMENT 1 STANDARD 2.1 Verify Turbine trip:

Governor valves Closed Verification complete.

Throttle valves Closed Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD 2.2 Verify Generator trip:

Exciter Field Breaker Tripped Verification complete.

Generator Breaker A Tripped Generator Breaker B Tripped Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD 2.3 RESET Moisture Separator Reheater controls. Reset was depressed.

Comment: Critical SAT / UNSAT Revision 0 Page 5 of 7 2015 NRC Exam

JPM S4 Evaluator Note The Alternate Path becomes applicable when the applicant addresses the Atmospheric Dump Valves.

ADV #2 will have spuriously opened.

2.4 IF evacuating the Control Room due to fire, THEN perform the following:

TASK ELEMENT 4 STANDARD 2.4.1 IF EITHER of the following valves has spuriously Opened, THEN place the applicable controller(s) in MANUAL AND lower the output to ADV #2 controller is placed zero:

in manual and output MS-116A SG 1 Atmospheric Dump lowered to 0%.

MS-116B SG 2 Atmospheric Dump Comment: Critical ADV #2 setpoint fails, driving ADV #2 open with normal pressure in S/G

2. SAT / UNSAT TASK ELEMENT 5 STANDARD 2.4.2 Close the following valves:

MS-124 A & MS-124 B are MS-124A Main Steam Isol Valve #1 closed.

MS-124B Main Steam Isol Valve #2 Comment: Critical SAT / UNSAT TASK ELEMENT 6 STANDARD 2.5 Obtain assigned Operations Security Key Ring AND proceed to RAB Keys obtained.

+35 Relay Room.

Comment:

Examiner Note: The key to open the "SM Security Cab" is located in the controlled key panel next to the RO desk. Next, the applicant will open the SAT / UNSAT SM key locker and grab the BOP key ring.

END OF TASK Revision 0 Page 6 of 7 2015 NRC Exam

JPM S4 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is at 100% power A fire has started in CP-33 The CRS has entered OP-901-502, Evacuation of Control Room and Subsequent Plant Shutdown The ATC is performing his immediate operator actions.

INITIATING CUE:

The CRS directs you to perform the BOP immediate operator actions.

Revision 0 Page 7 of 7 2015 NRC Exam

Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S5 Realign Containment Spray for Auto Initiation following CSAS Applicant:

Examiner:

JPM S5 JOB PERFORMANCE MEASURE DATA PAGE Task: Realign Containment Spray for Auto Initiation Following CSAS in accordance with OP-902-009 Attachment 5E, CSAS Reset Procedure Task Standard: Reset initiation and actuation relays, stopped CS Pumps, and realigned discharge valves in accordance with OP-902-009 Attachment 5E, CSAS Reset Procedure.

References:

OP-902-009 Attachment 5E, CSAS Reset Procedure Rev 310 Alternate Path: No Time Critical: No Validation Time: 13 min.

K/A 026A4.01 CSS controls Importance Rating 4.5/4.3 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 9 2015 NRC Exam

JPM S5 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-902-004, Excess Steam Demand Recovery OP-902-009, Standard Appendices (Handout 1)

This JPM is performed concurrently with JPM S7.

==

Description:==

This task will be performed at CP-8, CP-10, and CP-33 0 following an excess steam demand accident that resulted in a CSAS. Containment pressure has since reduced below 16.4 PSIA and conditions have been met to reset Containment Spray.

The operator will realign containment spray for automatic initiation IAW OP-902-009 Appendix 5 Attachment 5-E. There are no faults associated with this JPM.

DIRECTIONS TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 9 2015 NRC Exam

JPM S5 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-168

2. Verify containment pressure < 16.4 PSIA

3. For 2015 NRC Exam, JPM S7 is performed concurrently.

4. For 2015 NRC Exam, ensure the applicant travels to CP-10 and CP-8 in a direction that limits encounters with the applicant performing S7.

Setup with specific IC unavailable or for non NRC exams:

1. Reset the simulator to an IC at any power level in Mode 1

2. Insert a main steam line break inside Containment

3. When Containment Spray Actuates, delete the malfunction and insert the main steam line break on the same Steam Generator outside Containment (This is to empty the Steam Generator without raising Containment pressure too high)

4. Stop all RCPs

5. Once Steam Generator Blowdown is complete, delete the malfunction

6. Secure both EDGs; lower ACC-126 A&B setpoints to 75F

7. Allow Containment pressure to reduce below 16.4 PSIA

8. Allow conditions to stabilize.

9. Place simulator in freeze and save IC Revision 0 Page 4 of 9 2015 NRC Exam

JPM S5 EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN.

TASK ELEMENT 1 STANDARD

1. Place Control switches for ALL CCW to RCP isolation valves to "CLOSE:"

Control switches for CC-

CC 641, CCW RCP INLET OUTSIDE ISOL 641, CC-710, CC-713 in

CC 710, CCW RCP OUTLET INSIDE ISOL CLOSE

CC 713, CCW RCP OUTLET OUTSIDE ISOL Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD 2 Reset CSAS Initiation relays on ALL four channels as follows: Trains A, B, C, D reset

a. Place the Reset Permissive switch to "UNLK" position. (CP-10) permissive switch unlocked,

b. Press CSAS Reset pushbutton. CSAS reset pushbuttons

c. Verify the initiation relay indicator is illuminated on the ENGINNERED depressed for each train, SAFETY FEATURES SYSTEM mimic. trains A, B, C, D, reset

d. Place the Reset permissive switch to "LK" position. permissive switch to LK Comment: Critical Key # 218 SAT / UNSAT TASK ELEMENT 3 STANDARD 3 Reset CSAS actuation logic on BOTH trains as follows: Train A and B CSAS reset

a. Press the CSAS Reset pushbuttons. (CP-33) pushbuttons depressed Comment: Critical SAT / UNSAT Revision 0 Page 5 of 9 2015 NRC Exam

JPM S5 TASK ELEMENT 4 STANDARD 3 Reset CSAS actuation logic on BOTH trains as follows:

b. Verify the actuation relay indicator is illuminated on the Verified relay indicators lit ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10)

Comment:

SAT / UNSAT TASK ELEMENT 5 STANDARD

4. IF BOTH CS Pumps are operating, THEN perform the following:

a. Stop ONE CS pump Either A or B CS pump CS Pump A switch placed to stop CS Pump B Comment: Critical Examiner Note: If asked which CS Pump the CRS would like to secure SAT / UNSAT first, inform the applicant to secure CS Pump A.

TASK ELEMENT 6 STANDARD 4.

The CS pump control

b. Verify associated CS Pump Control Switch in mid-position switch that was secured is in the mid-position Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 4.

c. Monitor CNTMT parameters (pressure and temperature) for rising Containment pressure and trends temperature monitored Comment:

SAT / UNSAT Revision 0 Page 6 of 9 2015 NRC Exam

JPM S5 TASK ELEMENT 8 STANDARD 4.

d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN perform the following: Evaluate that there is not a

1) Evaluate need to continue to operate CS need to restart CS or exit this attachment 2.) Exit this attachment Comment:

SAT / UNSAT TASK ELEMENT 9 STANDARD 4.

e. IF containment parameters (pressure and temperature) are stable or trending down, THEN GO TO step 5: Proceed to step 5 Comment:

Examiner Note: If applicant states there is a slow rise in parameters, SAT / UNSAT acknowledge the report and inform the applicant to continue.

TASK ELEMENT 10 STANDARD 5 IF ONE CS pump is operating, THEN perform the following:

a. Stop CS pump CS pump that was not stopped previously is CS Pump A stopped CS Pump B Comment: Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 5

The second CS pump

b. Verify associated CS Pump Control switch in mid-position. control switch is in the mid-position Comment: Critical SAT / UNSAT Revision 0 Page 7 of 9 2015 NRC Exam

JPM S5 TASK ELEMENT 12 STANDARD 5

c. Monitor CNTMT parameters (pressure and temperature) for rising Containment pressure and trends. temperature trends are monitored.

Comment:

SAT / UNSAT TASK ELEMENT 13 STANDARD 5

d. IF adverse CNTMT parameters (pressure and temperature) rising, Determine no need to THEN evaluate need to restart CS. restart CS.

Comment:

Examiner Cue: Containment temperature and pressure will be very slowly SAT / UNSAT rising due to normal ambient heatup. If applicant asks CRS for guidance, inform the applicant to continue on with the procedure.

TASK ELEMENT 14 STANDARD 6 Verify Containment Spray valve(s) closed for ANY stopped CS pump(s):

CS 125A, CNTMT SPRAY HEADER A ISOL CS-125A and CS-125B

CS 125B, CNTMT SPRAY HEADER B ISOL closed Comment: Critical SAT / UNSAT EXAMINER NOTE: These valves will be closed by placing the control switch to open and then to close.

END OF TASK Revision 0 Page 8 of 9 2015 NRC Exam

JPM S5 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

An Excess Steam Demand Event had occurred but is now isolated The crew is responding in accordance with OP-902-004, Excess Steam Demand Recovery Containment pressure has been reduced to <16.4 PSIA and is stable INITIATING CUE:

The CRS has directed you reset Containment Spray Actuation Signal in accordance with OP-902-009 Appendix 5E.

Revision 0 Page 9 of 9 2015 NRC Exam

WATERFORD 3 SES OP-902-009 Revision 310 Page 58 of 177 STANDARD APPENDICES Attachment 5-E Page 1 of 3 ESFAS Reset Attachment 5-E: CSAS Reset Procedure INSTRUCTIONS

1. Place Control switches for ALL CCW to RCP Isolation valves to CLOSE:

CC 641, RCP INLET OUTSIDE ISOL CC 710, RCP OUTLET INSIDE ISOL CC 713, RCP OUTLET OUTSIDE ISOL

2. Reset CSAS Initiation relays on ALL four channels as follows:

a. Place the Reset Permissive switch to UNLK position. (CP-10)

b. Press CSAS Reset pushbutton.

c. Verify the initiation relay indicator is illuminated on the ENGINNERED SAFETY FEATURES SYSTEM mimic.

d. Place the Reset permissive switch to LK position.

3. Reset CSAS actuation logic on BOTH trains as follows:

a. Press the CSAS Reset pushbuttons. (CP-33)

b. Verify the actuation relay indicator is illuminated on the ENGINEERED SAFETY FEATURES SYSTEM mimic. (CP-10)

WATERFORD 3 SES OP-902-009 Revision 310 Page 59 of 177 STANDARD APPENDICES Attachment 5-E Page 2 of 3 INSTRUCTIONS

4. IF BOTH CS pumps are operating, THEN perform the following:

a. Stop ONE CS pump:

CS Pump A CS Pump B

b. Verify associated CS Pump Control switch in mid-position.

c. Monitor CNTMT parameters (pressure and temperature) for rising trends.

d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN perform the following:

1) Evaluate need to continue to operate CS.

2) Exit this attachment.

e. IF CNTMT parameters (pressure and temperature) are stable or trending down, THEN GO TO step 5.

WATERFORD 3 SES OP-902-009 Revision 310 Page 60 of 177 STANDARD APPENDICES Attachment 5-E Page 3 of 3 INSTRUCTIONS

5. IF ONE CS pump is operating, THEN perform the following :

a. Stop CS pump:

CS Pump A CS Pump B

b. Verify associated CS Pump Control switch in mid-position.

c. Monitor CNTMT parameters (pressure and temperature) for rising trends.

d. IF adverse CNTMT parameters (pressure and temperature) rising, THEN evaluate need to restart CS.

6. Verify CNTMT Spray Header valve(s) closed for ANY stopped CS pump(s):

CS 125A, CNTMT SPRAY HEADER A ISOL CS 125B, CNTMT SPRAY HEADER B ISOL End of Appendix 5

Waterford 3 2015 NRC RO/SRO Exam JOB PERFORMANCE MEASURE S6 Restore Power to Bus 3B Applicant:

Examiner:

JPM S6 JOB PERFORMANCE MEASURE DATA PAGE Task: Restore Power to Safety Bus 3B IAW OP-902-000, Standard Post Trip Actions.

Task Standard: Applicant transfers Train A to Unit Auxiliary Transformer (UAT) A.

Upon transfer of Train B to UAT B, the Reactor and turbine trip, the applicant performs Standard Post Trip Actions to restore power to Safety Bus 3B by adjusting EDG voltage.

References:

OP-006-001, Plant Distribution (7KV, 4KV, and SSD) System Rev 316 OP-902-000, Standard Post Trip Actions Rev 15 Alternate Path: Yes Time Critical: No Validation Time: 7 min.

K/A A4.02 Adjustment of exciter voltage (using Importance Rating 3.3/3.4 voltage control switch RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 0 Page 2 of 10 2015 NRC Exam

JPM S6 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-006-001, Plant Distribution (7KV, 4KV, and SSD) System (Handout 1)

OP-902-000, Standard Post Trip Actions

==

Description:==

This task takes place at CP-1. The applicant will assume the shift as the BOP operator during a plant startup at the step to transfer auxiliaries to the Unit Auxiliary Transformers. The applicant will align the A train busses and when the B train is aligned, the B UAT will fail. The failure will result in a Reactor Trip due to a loss of flow to the RCS. The B generator output breaker will fail to open resulting in a loss of offsite power to the B electrical busses. The applicant will perform the maintenance of vital auxiliaries section of OP-902-000 from memory. The applicant will trip the main generator using the trip pushbuttons, trip the generator output breaker, and recognize that the EDG started but did not supply its respective bus. The applicant will perform immediate action to raise EDG voltage to 3920 to 4350 AC volts allowing the EDG to provide power to bus 3B.

DIRECTIONS TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 0 Page 3 of 10 2015 NRC Exam

JPM S6 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-169

2. RESET ANY FAULT RELAYS ON CP-15 BETWEEN EACH RESET FOR THIS JPM

3. RESET SIMULATOR LIGHTING BETWEEN EACH RESET FOR THIS JPM

4. Verify the following (Should be loaded in IC):

a. EG04B, MAIN GENERATOR B OUTPUT BREAKER FAILS TO OPEN (Active)

b. EG04B is set to delete in 1 second on Event Trigger 2

c. EG13B, EDG B AUTO VOLTAGE REG FAILED LO, tied to Event Trigger 1 (Inactive)

d. ED02F, LOSS OF UAT-B TRANSFORMER tied to Event Trigger 1 (Inactive)

5. Ensure Event Trigger 1 is inserted as follows (Should be loaded in IC)

a. Event - UAT/SUT B SWITCH in UAT

b. Code is ZDIEDSTECS2235(1) == 1

6. Ensure Event Trigger 2 is inserted as follows: (Should be loaded in IC)

a. Event - Generator Trip - Both Required

b. Code is ZDIEGGENECS2201(1) == 1 & ZDIEGGENECS2205(1) == 1 Setup with specific IC unavailable or for non NRC exams:

1. Reset the simulator to an IC with the turbine ready to sync to the Grid

2. Sync the turbine to the grid in accordance with OP-010-004

3. Adjust Generator load to obtain approximately 60 MWe

4. Stabilize plant conditions

5. Enter malfunctions and Triggers listed above

6. Place simulator in freeze and save IC Revision 0 Page 4 of 10 2015 NRC Exam

JPM S6 EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN. Task Elements 1-8 are performed using OP-006-001, Plant Distribution (7KV, 4KV and SSD) System.

TASK ELEMENT 1 STANDARD 6.3.1 Transfer from Startup Transformer (SUT) A to Unit Auxiliary Transformer (UAT) A as follows: Verified with initial 6.3.1.1 Verify Unit Auxiliary Transformer A in service in accordance with conditions OP-006-008, Transformer Operation.

Comment:

SAT / UNSAT EXAMINER CUE: If asked, provide cue that the both UAT are in service in accordance with OP-006-008, Transformer Operation TASK ELEMENT 2 STANDARD 6.3.1.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Fault Relays verified reset Transformer A.

Comment:

SAT / UNSAT TASK ELEMENT 3 STANDARD Bus A transfer switch in 6.3.1.3 Place Bus A Transfer switch to UAT.

UAT Comment: Critical SAT / UNSAT TASK ELEMENT 4 STANDARD 6.3.1.3.1 Verify the following Startup Transformer A breakers Open:

7KV-EBKR-1A-4 and 4KV-7KV-EBKR-1A-4 Startup Transformer A 7KV Isolation EBKR-2A-4 checked open 4KV-EBKR-2A-4 Startup Transformer A 4KV Isolation Comment:

SAT / UNSAT Revision 0 Page 5 of 10 2015 NRC Exam

JPM S6 TASK ELEMENT 5 STANDARD 6.3.1.3.2 Verify the following Unit Auxiliary Transformer A breakers Closed: Verifies the breakers are 7KV-EBKR-1A-1 Unit Auxiliary Transformer A 7KV Isolation closed 4KV-EBKR-2A-1 Unit Auxiliary Transformer A 4KV Isolation Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 6.3.2 Transfer from Startup Transformer (SUT) B to Unit Auxiliary Transformer (UAT) B as follows: Verified with initial 6.3.2.1 Verify Unit Auxiliary Transformer B in service in accordance with conditions OP-006-008, Transformer Operation.

Comment:

SAT / UNSAT TASK ELEMENT 7 STANDARD 6.3.2.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Fault Relays verified reset Transformer B.

Comment:

SAT / UNSAT EXAMINER NOTE The fault is inserted at the following step and these steps should be performed from memory.

TASK ELEMENT 8 STANDARD Bus B transfer switch in 6.3.2.3 Place Bus B Transfer switch to UAT.

UAT Comment: Critical SAT / UNSAT Revision 0 Page 6 of 10 2015 NRC Exam

JPM S6 TASK ELEMENT 9 STANDARD Steps for OP-902-000, Recognize Turbine and Reactor Trip, proceed to SPTAs Standard Post Trip Actions, are commenced.

Comment:

EXAMINER NOTE: Alternate Path Begins Here SAT / UNSAT EXAMINER CUE: Provide cue to applicant to perform Standard Post Trip Actions as the Balance of Plant Operator TASK ELEMENT 10 STANDARD

2. Determine that Maintenance of Vital Auxiliaries acceptance criteria are met:

a. Check the Main Turbine is tripped: Governor valves and throttle

Governor valves closed valves checked closed

Throttle valves closed Comment:

SAT / UNSAT TASK ELEMENT 11 STANDARD

b. Check the Main Generator is tripped:

Determined Generator

GENERATOR BREAKER A tripped Breaker B is closed and

GENERATOR BREAKER B tripped proceeded to contingency

EXCITER FIELD BREAKER tripped Comment:

SAT / UNSAT Revision 0 Page 7 of 10 2015 NRC Exam

JPM S6 TASK ELEMENT 12 STANDARD b.1 Perform ANY of the following:

1) Manually trip the Main Generator using BOTH GENERATOR EMERG TRIP pushbuttons.

Pushed Both Generator

2) Manually trip the Main Generator by performing ALL of the following:

emergency Trip

a. Transfer BOTH electrical buses from UAT to SUT.

pushbuttons or opened

b. Open the following breakers:

Generator Breaker B

GENERATOR BREAKER A

GENERATOR BREAKER B

EXCITER FIELD BREAKER Comment:

SAT / UNSAT EXAMINER NOTE: Applicant will be successful either by pushing both Generator Emergency pushbuttons or manually tripping the Generator output breaker. Preferred order would be using the Generator Pushbuttons as they are numbered steps.

The motoring of the Generator isolated offsite power due to the breaker failure to open scheme so the Generator is no longer motoring after offsite power was lost to the B busses.

TASK ELEMENT 13 STANDARD

c. Check station loads are energized from offsite electrical power as follows:

Train A

A1, 6.9 KV non safety bus

A2, 4.16 KV non safety bus

A3, 4.16 KV safety bus

A-DC electrical bus Recognized bus B3

A or C vital AC Instrument Channel deenergized and proceeded Train B to contingency

B1, 6.9 KV non safety bus

B2, 4.16 KV non safety bus

B3, 4.16 KV safety bus

B-DC electrical bus

B or D vital AC Instrument Channel Comment:

SAT / UNSAT Revision 0 Page 8 of 10 2015 NRC Exam

JPM S6 TASK ELEMENT 14 STANDARD c.1 IF ANY 4.16 KV safety bus is NOT powered from offsite, THEN: Determined EDG output

1) Verify associated EDG has started AND EDG output breaker closed. Breaker not closed, EDG

2) IF EDG output breaker is NOT closed Voltage checked and THEN: determined to be out of the

Verify stable EDG Voltage 3920 - 4350 AC Volts. band low, adjusted voltages

Verify 3-2 Breaker open. to within the band, verified

Check Sequencer LOCKOUT NOT illuminated. 3-2 tie breaker open,

3) IF EDG output breaker is NOT closed AND Step c.1.2) is met THEN checked sequencer lockout locally close EDG output breaker. not illuminated, and checked CCW pump

4) Verify CCW cooling available to EDG.

running for B EDG.

Comment: Critical EXAMINER NOTE: Only the adjustment of EDG voltage is critical for task SAT / UNSAT completion. The EDG B output breaker will auto closed when voltage is within the band.

Examiner NOTE: The JPM is complete once the EDG B output breaker has closed.

END OF TASK Revision 0 Page 9 of 10 2015 NRC Exam

JPM S6 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is performing a startup S/G levels are being maintained by an additional operator ATC watch is controlling RCS parameters You are the BOP operator Both Startup Transformers are in service Both Unit Auxiliary Transformers are in service in accordance with OP-006-008, Transformer Operation.

INITIATING CUE:

The CRS directs you to transfer auxiliaries from the Startup Transformers to the Unit Auxiliary Transformers in accordance with OP-006-001, section 6.3.

Revision 0 Page 10 of 10 2015 NRC Exam

Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 317 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 If any electrical maintenance is being performed at any time when equipment is to be energized or power supplies are to be aligned, then particular consideration must be given to the possibility of backfeed to persons working.

3.1.2 No more than one incoming supply feeder per bus may be energized unless making live bus transfers from synchronized sources.

3.1.3 Prior to attempting any bus transfer, supply power should be verified available from the source that will be transferred to. Interlocks must not be relied upon.

3.1.4 Prior to attempting to cross-connect the following switchgear, the switchgear being cross-connected must be verified deenergized from its primary source:

SSD-ESWGR-21A, Switchgear 21A, to SSD-ESWGR-21B, Switchgear 21B SSD-ESWGR-22A, Switchgear 22A, to SSD-ESWGR-22B, Switchgear 22B SSD-ESWGR-4A, Switchgear 4A, to SSD-ESWGR-4B, Switchgear 4B 3.1.5 Prior to attempting to restore the primary source of power to the following switchgear, the switchgear being restored to its primary source must be verified deenergized from its respective cross-connected source:

SSD-ESWGR-21A Switchgear 21A SSD-ESWGR-21B Switchgear 21B SSD-ESWGR-22A Switchgear 22A SSD-ESWGR-22B Switchgear 22B 4KV-ESWGR-4A Switchgear 4A 4KV-ESWGR-4B Switchgear 4B 3.1.6 Transfer of power source to the following busses and motor control centers (MCCs) will be a dead bus transfer. Components fed from these busses will be deenergized during transfer:

4KV-ESWGR-3AB Switchgear 3AB SSD-ESWGR-31AB Switchgear 31AB SSD-EMCC-222AB Motor Control Center 222AB 3.1.7 The Main Turbine Generator must be shut down before attempting a backfeed of the Main Transformers to supply plant auxiliaries.

5

Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 317 3.1.8 Security Diesel Generator engine radiator fill cap may only be removed if radiator coolant temperature is below its boiling point. Extreme care must be taken when coolant is hot to ensure the radiator is not under pressure by loosening fill cap to the vent position before fully removing it.

3.1.9 Security Diesel Generator engine oil pressure should rise to > 20 PSIG within 10 seconds of starting. If Security Diesel Generator engine oil pressure is < 20 PSIG after 10 seconds, then Security Diesel Generator should be secured immediately by placing the Automatic/Manual select toggle switch to Automatic.

3.1.10 If the Security Diesel Generator engine is stopped at any time while operating under load, and the load contactor is verified open, then an attempt should be made to re-start it by placing Automatic/Manual select toggle switch to OFF &

RESET, then back to MANUAL. This is to allow cooldown with no load to prevent overheating of turbocharger parts.

3.1.11 Isophase Bus duct fans must be danger tagged in accordance with OP-102, Protective and Caution Tagging, prior to removing Main Generator disconnect links to prevent introducing dust and debris into Isophase Bus. As a minimum, the following breakers must be tagged:

GEN-EBKR-211A-2H Isophase Bus Duct Exhaust Fan GEN-EBKR-212A-3M Isophase Bus Duct Supply Fan A GEN-EBKR-212B-3M Isophase Bus Duct Supply Fan B 3.1.12 Proper Personnel Protection Equipment and safety requirements are required in accordance with EN-IS-123, Electrical Safety, when closing any of the following breakers with the breaker cubicle door open:

SSD-EBKR-21A-4B Switchgear 21A Feeder SSD-EBKR-21B-4B Switchgear 21B Feeder SSD-EBKR-21B-4C Switchgear 21B Tie To Switchgear 21A 3.2 LIMITATIONS 3.2.1 Appropriate guidelines have been incorporated into this procedure to ensure compliance with EN-OP-116. The following sections have been identified as infrequently performed tests or evolutions in accordance with EN-OP-116, Infrequently Performed Tests or Evolutions:

Section 8.4, Backfeed of Main Transformers to Supply Plant Auxiliaries Section 8.5, Restoration of Main Transformers for Normal Service 3.2.2 Gretna Transmissions Operations Center operates equipment in the Switchyard and will require notification to realign breakers S7172, S7176, S7182, and S7186, if necessary.

6

Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 317 3.2.3 If the Security Diesel Generator engine cranks for 30 seconds without starting, then the Security Diesel Generator should be stopped by placing Automatic/Manual select toggle switch to Automatic.

3.2.4 The Security Diesel Fuel Oil Tank should not be allowed to run out of fuel. If Security Diesel Generator engine stops due to lack of fuel supply, then it may necessitate refilling and bleeding of engine fuel lines.

3.2.5 If during startup or operation of the Security Diesel Generator there is a significantly noticeable diesel exhaust plume that is visible for >6 minutes in any consecutive 60 minute period, then UNT-006-010, Event Notification and Reporting, must be complied with.

3.2.6 When closing any of the following breakers with the breaker fully racked in, the door on the front of the breaker cubicle must be open and the Close Latch on the breaker must be depressed (similar to discharging the closing springs when these breakers are fully racked out). The black Close button on the front of the breaker only works in the test position:

SSD-EBKR-21A-4B Switchgear 21A Feeder SSD-EBKR-21B-4B Switchgear 21B Feeder SSD-EBKR-21B-4C Switchgear 21B Tie To Switchgear 21A 7

Operating Procedure OP-006-001 Plant Distribution (7KV, 4KV and SSD) System Revision 317 6.3 TRANSFER FROM STARTUP TO UNIT AUXILIARY TRANSFORMER [C]

6.3.1 Transfer from Startup Transformer (SUT) A to Unit Auxiliary Transformer (UAT) A as follows:

6.3.1.1 Verify Unit Auxiliary Transformer A in service in accordance with OP-006-008, Transformer Operation.

6.3.1.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer A.

6.3.1.3 Place Bus A Transfer switch to UAT.

6.3.1.3.1 Verify the following Startup Transformer A breakers Open:

7KV-EBKR-1A-4 Startup Transformer A 7KV Isolation 4KV-EBKR-2A-4 Startup Transformer A 4KV Isolation 6.3.1.3.2 Verify the following Unit Auxiliary Transformer A breakers Closed:

7KV-EBKR-1A-1 Unit Auxiliary Transformer A 7KV Isolation 4KV-EBKR-2A-1 Unit Auxiliary Transformer A 4KV Isolation 6.3.2 Transfer from Startup Transformer (SUT) B to Unit Auxiliary Transformer (UAT) B as follows:

6.3.2.1 Verify Unit Auxiliary Transformer B in service in accordance with OP-006-008, Transformer Operation.

6.3.2.2 Verify all fault relays Reset on CP-15 for Unit Auxiliary Transformer B.

6.3.2.3 Place Bus B Transfer switch to UAT.

6.3.2.3.1 Verify the following Startup Transformer B breakers Open:

7KV-EBKR-1B-4 Startup Transformer B 7KV Isolation 4KV-EBKR-2B-4 Startup Transformer B 4KV Isolation 6.3.2.3.2 Verify the following Unit Auxiliary Transformer B breakers Closed:

7KV-EBKR-1B-1 Unit Auxiliary Transformer B 7KV Isolation 4KV-EBKR-2B-1 Unit Auxiliary Transformer B 4KV Isolation 24

Waterford 3 2014 AUDIT Exam JOB PERFORMANCE MEASURE S7 Functional Check of Startup Channel Applicant:

Examiner:

JPM S7 JOB PERFORMANCE MEASURE DATA PAGE Task: Perform Range check functional test of Startup Channel 1 Task Standard: Range Check Functional test complete for Startup Channel 1

References:

OP-903-101, Startup Channel Functional Test Channel 1 and 2, Rev 8

Alternate Path: No Time Critical: No Validation Time: 18 min.

K/A 015 A3.03, Verification of proper Importance Rating 3.9 / 3.9 functioning/operability RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 9 2015 NRC Exam

JPM S7 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-903-101, Startup Channel Functional Test Channel 1 and 2 Handout 1 This JPM is performed concurrently with S5.

==

Description:==

The JPM begins with the plant in Mode 3 and stable. The applicant will be directed to perform Surveillance procedure OP-903-101 for range checks on Startup Channel 1. This JPM takes place at CP-2 and CP-12. There are no malfunctions associated with this JPM.

DIRECTIONS TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 1 Page 3 of 9 2015 NRC Exam

JPM S7 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-168

2. Place Simulator in Run on Lead Examiners cue

3. For 2015 NRC Exam, JPM S5 is performed concurrently

4. For 2015 NRC Exam, ensure the applicant travels to CP-12 in a direction that limits encounters with the applicant performing S5.

5. Verify the following (Should be loaded in IC):

a. Override AO-02A03AR5A-1 (S/U Ch.1 Recorder red pen on CP-2) is set to a value of 98,000.2 and assigned to Event Trigger 3 (Inactive)

6. Ensure Event Trigger 3 is inserted as follows (Should be loaded in IC):

a. Event - RRS-1 (CP-12A, S/U Channel #1) in "Test High"

b. Code is ZDINISCCTESTHI(1) == 1

7. Monitor CP-12A S/U Ch.1 "Operate/Test Low/Test High" control switch on Extreme View.

a. Verify that the above override is automatically inserted when the applicant places the C/S in "Test High".

b. When the applicant returns the C/S to "Operate", manually remove the override by right-clicking and removing the override.

There are no malfunctions associated with this JPM Setup with specific IC unavailable or for non NRC/AUDIT exams:

1. Reset the simulator to an IC in Mode 3

2. Allow simulator to run until all conditions stabilize

3. Acknowledge annunciators

4. Create Event Trigger "X" to be inserted as follows:

a. Event - RRS-1 (CP-12A, S/U Channel #1) in "Test High"

b. Code is ZDINISCCTESTHI(1) == 1

5. Override AO-02A03AR5A-1 (S/U Ch.1 Recorder red pen on CP-2) to a set value of 98,000 and assign it to Event Trigger "X" (Inactive). Note: This value will be displayed as 7.9E+4 on CP-2 recorder (not pegged high).

6. Place simulator in freeze and save IC Revision 1 Page 4 of 9 2015 NRC Exam

JPM S7 EXAMINER NOTE When Applicant is ready, cue the simulator operator to place the simulator in RUN.

TASK ELEMENT 1 STANDARD 7.2 RANGE CHECKS Trouble lamp on CP-12A 7.2.1 Momentarily depress local Trouble bistable lamp, verify Trouble depressed and documented bistable lamp is extinguished and document on Attachment 10.1, on Att. 10.1 Startup Channel Functional Test Data Sheet.

Comment:

CP-12A is located behind the main Control Room panels.

SAT / UNSAT TASK ELEMENT 2 STANDARD 7.2.2 Place AUDIO COUNT CHANNEL SELECT switch (CP-2) to the Select switch on CP-2 is channel not being tested. taken to Channel 2 Comment: Critical SAT / UNSAT TASK ELEMENT 3 STANDARD 7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch in Test Low and Switch on CP-12A in "Test document on Attachment 10.1, Startup Channel Functional Test Data Low" and documented on Sheet. Att. 10.1 Comment: Critical SAT / UNSAT TASK ELEMENT 4 STANDARD 7.2.4 Verify local Trouble bistable lamp is illuminated and document on bistable verified and data Attachment 10.1, Startup Channel Functional Test Data Sheet. recorded Comment:

SAT / UNSAT Revision 1 Page 5 of 9 2015 NRC Exam

JPM S7 TASK ELEMENT 5 STANDARD 7.2.5 Verify Control/Startup Channel 1(2) Trouble annunciator Alarms (M-Annunciator verified and 3 (M-4), Cabinet H) and document on Attachment 10.1, Startup data recorded Channel Functional Test Data Sheet.

Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 7.2.6 Record the following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:

Drawer local counts data recorded (see key)

Remote recorder ENI-IJR-0005 (0006)

Remote meter ENI-IJI-0005 (0006)

Comment: Critical SAT / UNSAT TASK ELEMENT 7 STANDARD 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High and Switch on CP-12A in "Test document on Attachment 10.1, Startup Channel Functional Test High" and data recorded Data Sheet.

Comment: Critical SAT / UNSAT TASK ELEMENT 8 STANDARD 7.2.8 Verify Channel 1(2) Neutron Flux High annunciator Alarms (K-3 (K-Annunciator verified and 4), Cabinet H) and document on Attachment 10.1, Startup Channel data recorded Functional Test Data Sheet.

Comment:

SAT / UNSAT Revision 1 Page 6 of 9 2015 NRC Exam

JPM S7 TASK ELEMENT 9 STANDARD 7.2.9 Verify RCS Boron Channel 1(2) Dilution Hi annunciator Alarms (L-3 Annunciator verified and (L-4), Cabinet G) and document on Attachment 10.1, Startup data recorded Channel Functional Test Data Sheet.

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 7.2.10 Record following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:

Drawer local counts data recorded (see key)

Remote recorder ENI-IJR-0005 (0006)

Remote meter ENI-IJI-0005 (0006)

Comment: Critical SAT / UNSAT TASK ELEMENT 11 STANDARD 7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate and Switch in Operate and data document on Attachment 10.1, Startup Channel Functional Test recorded Data Sheet.

Comment: Critical SAT / UNSAT TASK ELEMENT 12 STANDARD 7.2.12 Momentarily depress local Trouble bistable lamp, verify Trouble Button depressed, bistable bistable lamp is extinguished and document on Attachment 10.1, verified and data recorded Startup Channel Functional Test Data Sheet.

Comment: Critical Applicant must depress and hold momentarily to allow proper reset.

SAT / UNSAT Revision 1 Page 7 of 9 2015 NRC Exam

JPM S7 TASK ELEMENT 13 STANDARD 7.2.13 Verify Control/Startup Channel 1 (2) Trouble annunciator (M-3 (M-Annunciator verified and 4), Cabinet H) is clear and document on Attachment 10.1, Startup data recorded Channel Functional Test Data Sheet.

Comment:

SAT / UNSAT TASK ELEMENT 14 STANDARD 7.2.14 Verify Channel 1 (2) Neutron Flux High annunicator (K-3 (K-4),

Annunciator verified and Cabinet H) is clear and document on Attachment 10.1, Startup data recorded Channel Functional Test Data Sheet.

Comment:

SAT / UNSAT TASK ELEMENT 15 STANDARD 7.2.15 Verify RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3 (L-4),

Annunciator verified and Cabinet G) is clear and document on Attachment 10.1, Startup data recorded Channel Functional Test Data Sheet.

Comment:

SAT / UNSAT END OF TASK Revision 1 Page 8 of 9 2015 NRC Exam

JPM S7 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 3 INITIATING CUE:

The CRS directs you, to perform section 7.2 for Range Checks only for Startup Channel 1 in accordance with OP-903-101, Startup Channel Functional Test Startup Channel 1 and 2.

Revision 1 Page 9 of 9 2015 NRC Exam

KEY 10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET Startup Channel _ ____1 and ____2 (Check Applicable Space)

Permission: Joe Supervisor________/_____Today/Now_____________ WO#:___123456_______________

SM/CRS Date/Time STEP DESCRIPTION INITIALS STARTUP CHANNEL HIGH VOLTAGE TEST 7.1.1 Startup HV Low lamp is extinguished. _____N/A__

7.1.2 Startup HV On lamp is illuminated. _____N/A__

7.1.3 Startup HV Off lamp is extinguished. _____N/A__

7.1.4 STARTUP HV X 3/CONTROL HV X 1 switch in Startup HV X 3 . _____N/A__

7.1.5 Startup High Voltage meter reading: _______ VDC (600 to 800 VDC). _____N/A__

RANGE CHECKS 7.2.1 Local Trouble bistable lamp is extinguished. __________

7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch to Test-Low. __________

7.2.4 Local Trouble bistable lamp is illuminated. __________

7.2.5 Control/Startup Channel 1(2) Trouble alarms (M-3 (M-4), Cabinet H). __________

7.2.6 LOCATION REQUIRED ACTUAL Drawer local counts 5 x 101 to 2 x 102 CPS 95 (+/-10%) CPS __________

Remote recorder ENI-IJR-0005 (0006) 5 x 101 to 2 x 102 CPS 99 (+/-10%) CPS __________

Remote meter ENI-IJI-0005 (0006) 5 x 101 to 2 x 102 CPS 90 (+/-10%) CPS __________

OP-903-101 Revision 008 Attachment 10.1 (1 of 3) 1

KEY 10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET (CONTD)

Startup Channel __ ___1 and ____2 (Check Applicable Space)

STEP DESCRIPTION INITIALS RANGE CHECKS (CONTD) 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High. __________

7.2.8 Channel 1(2) Neutron Flux High alarms (K-3 (K-4), Cabinet H). __________

7.2.9 RCS Boron Chnl 1(2) Dilution Hi alarms (L-3 (L-4), Cabinet G). __________

7.2.10 LOCATION REQUIRED ACTUAL Drawer local counts 5 x 104 to 2 x 105 CPS 105 to 2x105 CPS __________

Remote recorder ENI-IJR-0005 (0006) 5 x 104 to not pegged hi 8E+4 (+/-10%) CPS __________

Remote meter ENI-IJI-0005 (0006) 5 x 104 to not pegged hi 8.5E+4 (+/-10%) CPS __________

7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate. __________

7.2.12 Local Trouble bistable lamp is extinguished. __________

7.2.13 Control/Startup Channel 1 (2) Trouble annunciators (M-3(M-4), Cabinet H) are clear. __________

7.2.14 Channel 1 (2) Neutron Flux High annunciators (K-3(K-4) Cabinet H) are clear. __________

7.2.15 RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3(L-4) Cabinet G) is clear. __________

OP-903-101 Revision 008 Attachment 10.1 (2 of 3) 2

KEY 10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET (CONTD)

Startup Channel __ ___1 and ____2 (Check Applicable Space)

STEP DESCRIPTION INITIALS AUDIBLE COUNT RATE 7.3.1 Audible count rate is present on Channel 1: Control Room __________

Containment __________

7.3.2 Audible count rate is present on Channel 2: Control Room __________

Containment __________

RESTORATION SWITCH POSITION PERFORMED IV 7.4.1.1 OPERATE/TEST LOW/TEST HIGH Operate __________ __________

7.4.1.2 ZERO/OPERATE/125% Operate __________ __________

7.4.1.3 TRIP TEST Off __________ __________

TEST ACCEPTANCE: INITIAL Startup Channel Functional Test performed satisfactory in accordance with Section 6.0, Acceptance Criteria. ________

Remarks: ___________________________________________________________________________________________

Performed By: ________________/________________

Operator Date/Time IV By: __________________/________________ Reviewed By: _______________/_____________

Operator Date/Time SM/CRS Date/Time OP-903-101 Revision 008 [LAST PAGE] Attachment 10.1 (3 of 3) 3

10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET Startup Channel _ ____1 and ____2 (Check Applicable Space)

Permission: Joe Supervisor________/_____Today/Now_____________ WO#:___123456_______________

SM/CRS Date/Time STEP DESCRIPTION INITIALS STARTUP CHANNEL HIGH VOLTAGE TEST 7.1.1 Startup HV Low lamp is extinguished. _____N/A__

7.1.2 Startup HV On lamp is illuminated. _____N/A__

7.1.3 Startup HV Off lamp is extinguished. _____N/A__

7.1.4 STARTUP HV X 3/CONTROL HV X 1 switch in Startup HV X 3 . _____N/A__

7.1.5 Startup High Voltage meter reading: _______ VDC (600 to 800 VDC). _____N/A__

RANGE CHECKS 7.2.1 Local Trouble bistable lamp is extinguished. __________

7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch to Test-Low. __________

7.2.4 Local Trouble bistable lamp is illuminated. __________

7.2.5 Control/Startup Channel 1(2) Trouble alarms (M-3 (M-4), Cabinet H). __________

7.2.6 LOCATION REQUIRED ACTUAL Drawer local counts 5 x 101 to 2 x 102 CPS __________ CPS __________

Remote recorder ENI-IJR-0005 (0006) 5 x 101 to 2 x 102 CPS __________ CPS __________

Remote meter ENI-IJI-0005 (0006) 5 x 101 to 2 x 102 CPS __________ CPS __________

OP-903-101 Revision 008 Attachment 10.1 (1 of 3) 1

10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET (CONTD)

Startup Channel __ ___1 and ____2 (Check Applicable Space)

STEP DESCRIPTION INITIALS RANGE CHECKS (CONTD) 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High. __________

7.2.8 Channel 1(2) Neutron Flux High alarms (K-3 (K-4), Cabinet H). __________

7.2.9 RCS Boron Chnl 1(2) Dilution Hi alarms (L-3 (L-4), Cabinet G). __________

7.2.10 LOCATION REQUIRED ACTUAL Drawer local counts 5 x 104 to 2 x 105 CPS __________ CPS __________

Remote recorder ENI-IJR-0005 (0006) 5 x 104 to not pegged hi __________ CPS __________

Remote meter ENI-IJI-0005 (0006) 5 x 104 to not pegged hi __________ CPS __________

7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate. __________

7.2.12 Local Trouble bistable lamp is extinguished. __________

7.2.13 Control/Startup Channel 1 (2) Trouble annunciators (M-3(M-4), Cabinet H) are clear. __________

7.2.14 Channel 1 (2) Neutron Flux High annunciators (K-3(K-4) Cabinet H) are clear. __________

7.2.15 RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3(L-4) Cabinet G) is clear. __________

OP-903-101 Revision 008 Attachment 10.1 (2 of 3) 2

10.1 STARTUP CHANNEL FUNCTIONAL TEST DATA SHEET (CONTD)

Startup Channel __ ___1 and ____2 (Check Applicable Space)

STEP DESCRIPTION INITIALS AUDIBLE COUNT RATE 7.3.1 Audible count rate is present on Channel 1: Control Room __________

Containment __________

7.3.2 Audible count rate is present on Channel 2: Control Room __________

Containment __________

RESTORATION SWITCH POSITION PERFORMED IV 7.4.1.1 OPERATE/TEST LOW/TEST HIGH Operate __________ __________

7.4.1.2 ZERO/OPERATE/125% Operate __________ __________

7.4.1.3 TRIP TEST Off __________ __________

TEST ACCEPTANCE: INITIAL Startup Channel Functional Test performed satisfactory in accordance with Section 6.0, Acceptance Criteria. ________

Remarks: ___________________________________________________________________________________________

Performed By: ________________/________________

Operator Date/Time IV By: __________________/________________ Reviewed By: _______________/_____________

Operator Date/Time SM/CRS Date/Time OP-903-101 Revision 008 [LAST PAGE] Attachment 10.1 (3 of 3) 3

Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 Verify only one Startup Drawer is under test at any given time.

3.2 LIMITATIONS 3.2.1 Do not energize Source Range High Voltage with Reactor Power >10-6%. High Neutron Flux will destroy Startup BF3 detectors over time (long term concern).

5

Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 7.2 RANGE CHECKS 7.2.1 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.2 Place AUDIO COUNT CHANNEL SELECT switch (CP-2) to the channel not being tested.

7.2.3 Place OPERATE/TEST LOW/TEST HIGH switch in Test Low and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.4 Verify local Trouble bistable lamp is illuminated and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.5 Verify Control/Startup Channel 1(2) Trouble annunciator Alarms (M-3 (M-4),

Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.6 Record the following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:

Drawer local counts Remote recorder ENI-IJR-0005 (0006)

Remote meter ENI-IJI-0005 (0006) 7.2.7 Place OPERATE/TEST LOW/TEST HIGH switch to Test-High and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.8 Verify Channel 1(2) Neutron Flux High annunciator Alarms (K-3 (K-4), Cabinet H) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.9 Verify RCS Boron Channel 1(2) Dilution Hi annunciator Alarms (L-3 (L-4), Cabinet G) and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

10

Surveillance Procedure OP-903-101 Startup Channel Functional Test Startup Channel ___1 and ___2 Revision 008 7.2.10 Record following Startup Channel 1(2) indications and document on Attachment 10.1, Startup Channel Functional Test Data Sheet:

Drawer local counts Remote recorder ENI-IJR-0005 (0006)

Remote meter ENI-IJI-0005 (0006) 7.2.11 Place OPERATE/TEST LOW/TEST HIGH switch in Operate and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.12 Momentarily depress local Trouble bistable lamp, verify Trouble bistable lamp is extinguished and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.13 Verify Control/Startup Channel 1 (2) Trouble annunciator (M-3 (M-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.14 Verify Channel 1 (2) Neutron Flux High annunicator (K-3 (K-4), Cabinet H) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

7.2.15 Verify RCS Boron Channel 1 (2) Dilution Hi annunciator (L-3 (L-4), Cabinet G) is clear and document on Attachment 10.1, Startup Channel Functional Test Data Sheet.

11

Waterford 3 2015 NRC Exam JOB PERFORMANCE MEASURE S8 Placing Fuel Handling Building Emergency Filtration Unit A in Service Applicant:

Examiner:

JPM S8 JOB PERFORMANCE MEASURE DATA PAGE Task: Place FHB Emergency Filtration Unit A in service in accordance with OP-002-009, Fuel Handling Building HVAC.

Task Standard: Applicant aligned Fuel Handling Building Emergency Filtration Unit A to Service in accordance with OP-002-009, Fuel Handling Building HVAC.

References:

OP-002-009, Fuel Handling Building HVAC, revision 13 Alternate Path: No Time Critical: No Validation Time: 20 min.

K/A A4.01 Radiation levels Importance Rating 3.3 / 3.7 RO / SRO Applicant:

Time Start: Time Finish:

Performance Time: minutes Critical Time: N/A minutes Performance Rating: SAT UNSAT Comments:

Examiner: Date:

Signature Revision 1 Page 2 of 12 2015 NRC Exam

JPM S8 EXAMINER COPY ONLY Tools/Equipment/Procedures Needed:

OP-002-009, Fuel Handling Building HVAC, revision 13

==

Description:==

This task takes place at CP-18. The applicant will secure FHB Normal HVAC and then place FHB Emergency Filtration Unit A is in service OP-002-009, Fuel Handling Building HVAC.

This JPM is to be performed concurrently with S2.

DIRECTIONS TO APPLICANT:

I will explain the initial conditions, and state the task to be performed. All control room steps shall be performed for this JPM, including any required communications. I will provide initiating cues and reports on other actions when directed by you. Indicate to me when you understand your assigned task.

(Read the Initial Condition and Cues from the Applicant Cue Sheet, and then give the cue sheet to the applicant.)

Revision 1 Page 3 of 12 2015 NRC Exam

JPM S8 SIMULATOR OPERATOR INSTRUCTIONS

1. Reset to IC-165

2. For 2015 NRC Exam, JPM S2 is performed concurrently.

Revision 1 Page 4 of 12 2015 NRC Exam

JPM S8 EXAMINER NOTE Cue the Simulator Operator to place the Simulator in RUN. This JPM is performed concurrently with S2.

TASK ELEMENT 1 STANDARD 6.3 Placing FHB Emergency Filtration Unit in Service:

Procedure Note: FHB Normal HVAC is maintained in service to provide air Note reviewed cooling to equipment located in non-rad areas.

Comment:

SAT / UNSAT TASK ELEMENT 2 STANDARD Procedure Caution:

(1) SECURE FHB NORMAL HVAC IF EITHER OF THE FOLLOWING OCCURS:

FHB EXHAUST RAD MONITOR FOR THE RUNNING FHB NORMAL EXHAUST FAN SHOWS AN UNEXPLAINED INCREASE IN RADIATION LEVELS, OR RADIATION PROTECTION REPORTS AN INCREASE IN Caution reviewed RADIATION LEVELS IN NON-RAD AREAS OF FHB (2) IF PAINTING IS IN PROGRESS, OR FIRE OR CHEMICAL RELEASE OCCURS INSIDE THE FHB, THEN FHB EMERGENCY FILTRATION UNITS SHOULD NOT BE RUN FOR NON-EMERGENCY PURPOSES (3) GUIDANCE CONTAINED IN PRECAUTION 3.1.3 OF THIS PROCEDURE LISTS COMPONENTS SUCH AS DOORS AND FLOOR PLUGS THAT AFFECT OPERABILITY OF FHB EMERGENCY FILTRATION UNITS.

Comment:

Instructor Note: If asked: Inform the applicant that there is no painting, or fire or chemical release occurring in the FHB. SAT / UNSAT Revision 1 Page 5 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 3 STANDARD 6.3.1 Notify Radiation Protection of Placing FHB Emergency Filtration Unit RP notified in Service.

Comment:

SAT / UNSAT TASK ELEMENT 4 STANDARD Applicant transitions to 6.3.2 Remove FHB Normal HVAC from Service in accordance with section 7.1 to remove FHB Section 7.1, Removing FHB Normal HVAC from Service.

Normal HVAC from service Comment:

Instructor Note. The applicant will transition to section 7.1 of OP-002-009 to secure FHB Normal Ventilation SAT / UNSAT TASK ELEMENT 5 STANDARD 7.1 Removing FHB Normal HVAC from service Procedure Note: Fire detection instruments FPDEDETFHB-26R and FPDEDETFHB-26T may initiate alarms when FHB HVAC is secured for Note reviewed extended periods of time due to increase in humidity. Fire detection should be impaired in accordance with FP-001-015 and disarmed at the FDMCP if this occurs Comment:

SAT / UNSAT TASK ELEMENT 6 STANDARD 7.1.1 Notify Radiation Protection of Removing FHB Normal HVAC from RP notified Service.

Comment:

SAT / UNSAT Revision 1 Page 6 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 7 STANDARD 7.1.2 If FHB Normal Exhaust Fan will be secured for an extended period of time (> 1 hr), then Notify Maintenance Support to secure the Step is reviewed Temporary Chiller.

Comment:

Instructor Note: If asked of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months duration, inform the applicant that FHB Normal Exhaust will not be secured > 1 hr. SAT / UNSAT TASK ELEMENT 8 STANDARD 7.1.3 Denote which FHB Normal Exhaust Fan is being stopped (circle one):

Stopped FHB Normal A B Exhaust Fan A 7.1.3.1 Place control switch for the running FHB Normal Exhaust Fan, HVF-0003A(B), to STOP Comment: Critical Instructor Note: Placing the control switch for the FHB Normal Exhaust Fan, HVF-0003A, to STOP is the critical portion of this step. SAT / UNSAT TASK ELEMENT 9 STANDARD 7.1.4 Verify FHB Exhaust Fan A(B) Inlet Damper CLOSED:

HVF-111A (PID D53642) FHB Exhaust Fan A Inlet damper (HVF-111A) is or verified closed.

HVF-111B (PID D53643)

Comment:

SAT / UNSAT TASK ELEMENT 10 STANDARD 7.1.5 Place control switch for FHB Normal Supply Fan, HVF-0002, to Stopped the FHB Normal STOP. Supply fan Comment: Critical SAT / UNSAT Revision 1 Page 7 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 11 STANDARD 7.1.6 Verify FHB Normal Supply Fan Inlet and Outlet Dampers CLOSED:

FHB Normal Supply Inlet HVF-101 (PID D53641) and Outlet Dampers are verified closed HVF-102 (PID D53668)

Comment:

Examiner Note: The applicant will transition back to OP-002-009 step 6.3.3 SAT / UNSAT TASK ELEMENT 12 STANDARD 6.3.3 Place both FHB Isol Damper control switches to CLOSE and verify the following dampers Close:

HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper Both FHB Isol Damper control switches taken to HVF-106 Spent Fuel Handling HVAC Downstream Supply close and dampers verified Damper closed.

HVF-107 Spent Fuel Handling HVAC Upstream Return Damper HVF-108 Spent Fuel Handling HVAC Downstream Return Damper Comment: Critical Examiner Note: Placing both FHB Isol Damper control switches (C/S) to CLOSE is the critical portion of this step. HVF-105 & 108 are operated by SAT / UNSAT a common C/S. HVF-106 & 107 are operated by a common C/S.

TASK ELEMENT 13 STANDARD 6.3.4 Place both FHB Vent Mode Select control switches to Bypass, and perform the following:

6.3.4.1 Verify the following dampers Closed:

Both FHB Vent Mode Select HVF-103 FP Cool & Purif HVAC Supply Damper control switches in bypass HVF-104 FP Cool & Purif HVAC Supply Damper and dampers verified 6.3.4.2 Verify the following Open:

HVF-109 FP Cool & Purif HVAC Return Damper HVF-110 FP Cool & Purif HVAC Return Damper Comment: Critical Examiner Note: Placing both FHB Vent Mode Select control switches to Bypass is the critical portion of this step. SAT / UNSAT Revision 1 Page 8 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 14 STANDARD 6.3.5 Denote which FHB Emergency Fltr Unit(s) is being started (circle one):

Placed FHB EFU A to start.

A B 6.3.5.1 Place control switch for desired FHB Emergency Fltr Unit(s), HVF-0005A(B), to START.

Comment: Critical Instructor Note: Placing the control switch for FHB Emergency Fltr Unit A, HVF-0005A, to START is the critical portion of this step. SAT / UNSAT TASK ELEMENT 15 STANDARD Procedure Caution: IF REQUIRED FHB EMERGENCY FILTRATION UNIT DIFFERENTIAL PRESSURE CANNOT BE ACHIEVED, EVEN THROUGH THE USE OF MANUAL ADJUSTMENTS TO THE INLET Caution reviewed DAMPER HVFMVAAA202A(B), THEN A WORK REQUEST SHOULD BE GENERATED IN ACCORDANCE WITH WM-100, WORK ORDER GENERATION, SCREENING AND CLASSIFICATION.

Comment:

SAT / UNSAT TASK ELEMENT 16 STANDARD 6.3.6 Verify FHB Emergency Fltr Unit DP 8.7 to 9.2 INWC. Verified DP within the band Comment:

SAT / UNSAT Revision 1 Page 9 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 17 STANDARD 6.3.7 Denote which FHB H&V Exhaust Fan is being started (circle one):

One FHB H&V Exhaust Fan A B is started 6.3.7.1 Place control switch for FHB H&V Exhaust Fan A(B), HVF-0006A(B), to START.

Comment: Critical Instructor Note: Placing the control switch for FHB H&V Exhaust Fan A(B),

HVF-0006A(B), to START is the critical portion of this step. SAT / UNSAT TASK ELEMENT 18 STANDARD 6.3.8 Verify FHB H&V Room Exhaust Fan A(B) Intake Damper Open:

HVF-301A PID D53664 OPEN PID D53665 NT CLSD Verified intake dampers open for the exhaust fan or that was started.

HVF-301B PID D53666 OPEN PID D53667 NT CLSD Comment:

SAT / UNSAT TASK ELEMENT 19 STANDARD 6.3.9 Verify Sample Pump running for FHB Emergency Exhaust WRGM, Sample pump started PRM-IRI-3032, at either CP-6 or CP-52.

Comment: Critical Examiner Note: If applicant motions towards CP-6 and another applicant is at CP-6, ask "Where else can this step be performed?" as a cue to use SAT / UNSAT CP-52. Otherwise, allow the applicant to use either control panel.

Revision 1 Page 10 of 12 2015 NRC Exam

JPM S8 TASK ELEMENT 20 STANDARD 6.3.10 Monitor applicable Range and Effluent Level for FHB Emergency Step reviewed Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52..

Comment:

Instructor Note: If the applicant desires to pull a trend at the RM-11 station, inform the applicant that the ATC will monitor trends such as not SAT / UNSAT to interfere with JPM S2.

TASK ELEMENT 21 STANDARD 6.3.11 If radiation levels permit, then Place FHB Normal HVAC in Service in accordance with Section 6.1, Placing FHB Normal Step reviewed HVAC in Service.

Comment:

Examiner Note: Inform the applicant that another operator will place FHB Normal HVAC in service. This JPM is complete. SAT / UNSAT END OF TASK Revision 1 Page 11 of 12 2015 NRC Exam

JPM S8 APPLICANT CUE SHEET (TO BE RETURNED TO EXAMINER UPON COMPLETION OF TASK)

INITIAL CONDITIONS:

The plant is in Mode 3 No painting, or fire or chemical release is occurring in the FHB INITIATING CUE:

The CRS directs you to Place FHB Emergency Filtration Unit A in service in accordance with section 6.3 of OP-002-009, Fuel Handling Building HVAC Revision 1 Page 12 of 12 2015 NRC Exam

S8 Handout 1 System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 3.0 PRECAUTIONS AND LIMITATIONS 3.1 PRECAUTIONS 3.1.1 Operability requirements for FHB Radioactive Gaseous Effluent Monitoring instrumentation are given by Technical Specification 3.3.3.1 and Technical Requirement 3.3.3.11.

3.1.2 If painting is in progress, or fire or chemical release occurs inside the FHB, then FHB Emergency Filtration Units should not be run for non-emergency purposes.

3.1.3 With the exception of normal personnel transit of the FHB, both FHB Emergency Filtration Units are Inoperable when any of the doors or floor plugs listed below are Open, Propped Open or otherwise impaired (refer to OP-100-014):

DOOR #D037 +21 Q-Deck to FHB DOOR #D067 +21 FHB to +1 FHB DOOR #D068 +1 FHB Railroad Cargo Train Bay DOOR #D069 +21 FHB to +46 FHB DOOR #D069A +30 FHB Access Area To Unloading Bay Door DOOR #D187 +46 FHB Spent Fuel Pool Door DOOR #D188 +1 FHB to +21 FHB Floor Plug from FHB +46 to the FHB +21 Floor Plug from FHB +21 to the FHB +1 3.2 LIMITATIONS 3.2.1 Notify Radiation Protection when changing FHB HVAC alignments.

3.2.2 If required FHB Emergency Filtration Unit differential pressure cannot be achieved, even through the use of manual adjustments to the inlet damper HVFMVAAA202A(B), then a Work Request should be generated in accordance with WM-100, Work Order Generation, Screening and Classification.

3.2.3 Fire detection instruments FPDEDETFHB-26R and FPDEDETFHB-26T may initiate alarms when FHB HVAC is secured for extended periods of time, due to increase in humidity. Fire detection should be impaired in accordance with FP-001-015 and disarmed at the Fire Detection Main Control Panel if this occurs.

4

S8 Handout 1 System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 6.3 PLACING FHB EMERGENCY FILTRATION UNIT IN SERVICE NOTE FHB Normal HVAC is maintained in service to provide air cooling to equipment located in non-rad areas.

CAUTION (1) SECURE FHB NORMAL HVAC IF EITHER OF THE FOLLOWING OCCURS:

FHB EXHAUST RAD MONITOR FOR THE RUNNING FHB NORMAL EXHAUST FAN SHOWS AN UNEXPLAINED INCREASE IN RADIATION LEVELS, OR RADIATION PROTECTION REPORTS AN INCREASE IN RADIATION LEVELS IN NON-RAD AREAS OF FHB (2) IF PAINTING IS IN PROGRESS, OR FIRE OR CHEMICAL RELEASE OCCURS INSIDE THE FHB, THEN FHB EMERGENCY FILTRATION UNITS SHOULD NOT BE RUN FOR NON-EMERGENCY PURPOSES (3) GUIDANCE CONTAINED IN PRECAUTION 3.1.3 OF THIS PROCEDURE LISTS COMPONENTS SUCH AS DOORS AND FLOOR PLUGS THAT AFFECT OPERABILITY OF FHB EMERGENCY FILTRATION UNITS.

6.3.1 Notify Radiation Protection of Placing FHB Emergency Filtration Unit in Service.

6.3.2 Remove FHB Normal HVAC from Service in accordance with Section 7.1, Removing FHB Normal HVAC from Service.

6.3.3 Place both FHB Isol Damper control switches to CLOSE and verify the following dampers Close:

HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper HVF-106 Spent Fuel Handling HVAC Downstream Supply Damper HVF-107 Spent Fuel Handling HVAC Upstream Return Damper HVF-108 Spent Fuel Handling HVAC Downstream Return Damper 9

S8 Handout 1 System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 6.3.4 Place both FHB Vent Mode Select control switches to Bypass, and perform the following:

6.3.4.1 Verify the following dampers Closed:

HVF-103 FP Cool & Purif HVAC Supply Damper HVF-104 FP Cool & Purif HVAC Supply Damper 6.3.4.2 Verify the following Open:

HVF-109 FP Cool & Purif HVAC Return Damper HVF-110 FP Cool & Purif HVAC Return Damper 6.3.5 Denote which FHB Emergency Fltr Unit(s) is being started (circle one):

A B 6.3.5.1 Place control switch for desired FHB Emergency Fltr Unit(s),

HVF-0005A(B), to START.

CAUTION IF REQUIRED FHB EMERGENCY FILTRATION UNIT DIFFERENTIAL PRESSURE CANNOT BE ACHIEVED, EVEN THROUGH THE USE OF MANUAL ADJUSTMENTS TO THE INLET DAMPER HVFMVAAA202A(B), THEN A WORK REQUEST SHOULD BE GENERATED IN ACCORDANCE WITH WM-100, WORK ORDER GENERATION, SCREENING AND CLASSIFICATION.

6.3.6 Verify FHB Emergency Fltr Unit DP 8.7 to 9.2 INWC.

6.3.7 Denote which FHB H&V Exhaust Fan is being started (circle one):

A B 6.3.7.1 Place control switch for FHB H&V Exhaust Fan A(B), HVF-0006A(B), to START.

6.3.8 Verify FHB H&V Room Exhaust Fan A(B) Intake Damper Open:

HVF-301A PID D53664 ................................................................... OPEN PID D53665............................................................... NT CLSD or HVF-301B PID D53666.................................................................... OPEN PID D53667............................................................... NT CLSD 10

S8 Handout 1 System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 6.3.9 Verify Sample Pump running for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52.

6.3.10 Monitor applicable Range and Effluent Level for FHB Emergency Exhaust WRGM, PRM-IRI-3032, at either CP-6 or CP-52.

6.3.11 If radiation levels permit, then Place FHB Normal HVAC in Service in accordance with Section 6.1, Placing FHB Normal HVAC in Service.

6.3.12 If temporary FHB air conditioning is installed, then the following dampers, may be reopened to facilitate cooling of the +46 elevation of the Fuel Handling Building:

HVF-105 Spent Fuel Handling HVAC Upstream Supply Damper HVF-106 Spent Fuel Handling HVAC Downstream Supply Damper HVF-107 Spent Fuel Handling HVAC Upstream Return Damper HVF-108 Spent Fuel Handling HVAC Downstream Return Damper 11

S8 Handout 2 System Operating Procedure OP-002-009 Fuel Handling Building HVAC Revision 013 7.0 SYSTEM SHUTDOWN 7.1 REMOVING FHB NORMAL HVAC FROM SERVICE NOTE Fire detection instruments FPDEDETFHB-26R and FPDEDETFHB-26T may initiate alarms when FHB HVAC is secured for extended periods of time due to increase in humidity. Fire detection should be impaired in accordance with FP-001-015 and disarmed at the FDMCP if this occurs.

7.1.1 Notify Radiation Protection of Removing FHB Normal HVAC from Service.

7.1.2 If FHB Normal Exhaust Fan will be secured for an extended period of time

(> 1 hr), then Notify Maintenance Support to secure the Temporary Chiller.

7.1.3 Denote which FHB Normal Exhaust Fan is being stopped (circle one):

A B 7.1.3.1 Place control switch for the running FHB Normal Exhaust Fan, HVF-0003A(B), to STOP.

7.1.4 Verify FHB Exhaust Fan A(B) Inlet Damper CLOSED:

HVF-111A (PID D53642) or HVF-111B (PID D53643) 7.1.5 Place control switch for FHB Normal Supply Fan, HVF-0002, to STOP.

7.1.6 Verify FHB Normal Supply Fan Inlet and Outlet Dampers CLOSED:

HVF-101 (PID D53641)

HVF-102 (PID D53668) 12

Appendix D Scenario Outline Form ES-D-1 Facility: Waterford Scenario No.: 1 Op Test No.: 1 Examiners: Operators:

Initial Conditions: Reactor power is 100%, MOC Turnover:

Protected Train is B, AB Bus is aligned to Train B, Low Press Safety Injection (LPSI) pump A is tagged out. Perform a down power to ~90% for Heater Drain Pump 'A' planned maintenance.

Event Malf. Event Event No. No. Type* Description R - ATC N - BOP 1 N/A N - SRO Initiate a normal plant down power.

Plant Protection System Channel D Containment I - BOP Pressure (CIAS), CB-IPI-6701SMD, fails high I - SRO requiring Technical Specification entry and bypass of 2 CH08E1 TS - SRO channel trip bistables. (TS 3.3.1 & 3.3.2)

I - BOP Steam Generator #1 Feedwater flow instrument FW-I - SRO IFR-1111 fails low. OP-901-201, Steam Generator 3 FW26A Level Control Malfunction. (TRM 3.3.5)

Pressurizer Level Control Channel Level Transmitter, I - ATC RC-ILT-0110X, fails high requiring implementation of I - SRO OP-901-110, Pressurizer Level Control Malfunction.

4 RC15A1 TS - SRO (TS 3.3.3.5 & 3.3.3.6)

L_L10 A seismic event causes a loss of offsite power and L_M10 main turbine trip (auto reactor trip). Two CEAs fail to ED01A,B,C,D insert. (Critical Task 1, Emergency Borate using TU06 CVCS). The crew will enter OP-902-000, Standard RD11A32 Post Trip Actions and diagnose into OP-902-003, Loss 5 RD11A47 M - All of Offsite Power/Forced Circulation.

Large RCS Cold Leg break will cause the crew to re-diagnose and enter OP-902-002, Loss of Coolant 6 RC23A M - All Accident Recovery Procedure.

RP05A3 RP05B3 Containment Spray (CS) fails to AUTO Actuate RP05C3 I - ATC requiring manual actuation. (Critical Task 2, 7 RP05D3 I - SRO Manually Initiate Containment Spray)

LPSI pump B trips requiring implementation of OP-902-008, Functional Recovery Procedure. The crew will align CS pump B to replace LPSI pump B in C - BOP accordance with OP-902-009, Standard Appendices, 8 SI01E C - SRO Att. 27. (Critical Task 3, Establish LPSI flow)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2015 NRC Exam Scenario 1 D-1 Rev 2

Scenario Event Description NRC Scenario 1 The crew assumes the shift at 100% power with instructions to perform a plant down power to ~90% in preparation for planned Heater Drain Pump 'A' maintenance. The SRO should direct the plant down power in accordance with OP-010-005, Plant Shutdown and the provided reactivity plan.

At lead examiners discretion, CB-IPI-6701SMD, Containment Pressure (CIAS) fails high. The SRO should review Technical Specifications 3.3.1 and 3.3.2. Per Table 3.3-1 under Containment Pressure -

High (Functional Unit 6) the SRO should enter Technical Specification 3.3.1 action 2. Per Table 3.3-3 under Functional Units 1b (Safety Injection, Containment Pressure-High), 3b (Containment Isolation, Containment Pressure-High), and 4c (Main Steam Line Isolation, Containment Pressure High) the SRO should enter Tech 3.3.2 action 13. The SRO should direct the BOP to bypass the Containment Pressure High (RPS) and Containment Pressure High (ESF) trip bistables (13&16) in PPS Channel D within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The BOP should bypass the trip bistables in accordance with OP-009-007, Plant Protection System.

After the trip bistables have been placed in bypass, Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low. The Feedwater Control System will respond by increasing Feedwater flow to Steam Generator #1. The SRO should enter OP-901-201, Steam Generator Level Control Malfunction. The BOP will be required to take manual control and match Feedwater and Main Steam flow. The Ultrasonic Flow Meter will fail as a result of the instrument failure and require entry into TRM 3.3.5. Feedwater controls for Steam Generator #1 may remain in manual as a result of this failure requiring manual positioning of the valves on a Reactor Trip.

After the crew has restored Steam Generator 1 to between 50% and 70% Narrow Range, Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails high. The SRO should enter OP-901-110, Pressurizer Level Control Malfunction and implement Section E1. The crew should take manual control of the Pressurizer Level Controller and/or operate Charging Pumps to restore Pressurizer level, swap control to the Channel Y level channel, and return the Pressurizer Level Controller back to AUTO. The SRO should review Technical Specifications 3.3.3.5 and 3.3.3.6 and OP-903-013, Monthly Channel Checks. The SRO should determine that TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a.

After Pressurizer Level Control is in AUTO, a seismic event causes a loss of offsite power, a main turbine trip and a reactor trip. Two CEAs fail to insert on the reactor trip. The ATC should commence Emergency Boration in accordance with OP-901-103, Emergency Boration (CRITICAL TASK 1). The SRO should implement OP-902-000, Standard Post Trip Actions (SPTA) and verify that the ATC has commenced emergency boration. The crew will diagnose into OP-902-003, Loss of Offsite Power/Forced Circulation.

Once the crew diagnoses OP-902-003, Loss of Offsite Power/Forced Circulation, an RCS leak occurs on RCS Cold Leg 1A that progresses to a Large Break Loss of Coolant Accident. When Containment Pressure exceeds the Containment Spray (CSAS) setpoint, Containment Spray fails to actuate. The ATC should manually initiate Containment Spray (CRITICAL TASK 2). The crew should re-diagnose to OP-902-002, Loss of Coolant Accident Recovery Procedure.

After the crew verifies proper operation of Component Cooling Water or at lead examiners discretion, Low Pressure Safety Injection (LPSI) pump B will trip on overcurrent. The crew should recognize that OP-902-002 safety functions are not met and the SRO should go to OP-902-008, Functional Recovery. When the SRO performs prioritization, Inventory Control (IC-2) should be the highest priority. The SRO should request TSC/Shift Manager permission and direct the BOP to align Containment Spray pump B to replace LPSI pump B and re-establish LPSI flow (CRITICAL TASK 3).

The scenario can be terminated after the crew has re-established low pressure safety injection flow or at the lead examiners discretion.

2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 CRITICAL TASKS

1. ESTABLISH REACTIVITY CONTROL This task is satisfied by establishing emergency boration prior to exiting OP-902-000, Standard Post Trip Actions. This task becomes applicable after the reactor trips. OP-902-000, Standard Post Trip Actions, directs this as a contingency action to satisfy the Reactivity Control safety function. OP-901-103, Emergency Boration, contains the immediate operator actions required to be taken.

2. ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROL This task is satisfied by manually initiating Containment Spray Actuation Signal prior to exiting step 15 (Verify Containment Spray Actuation) of OP-902-002, Loss of Coolant Accident Recovery Procedure, or Containment pressure exceeding 44 PSIG (59 PSIA). This task becomes applicable after Containment Pressure rises above 17.7 PSIA. OP-902-000, Standard Post Trip Actions, directs this activity to satisfy the Containment Pressure and Temperature Control safety function.

3. ESTABLISH LOW PRESSURE SAFETY INJECTION This task is satisfied by establishing low pressure safety injection using a Containment Spray pump prior to exiting the Inventory Control (IC-2) safety function in OP-902-008, Functional Recovery Procedure. This task becomes applicable after the running LPSI pump trips. OP-902-008, Functional Recovery Procedure, directs this in Inventory Control Continuing Actions with the required operator actions in OP-902-009, Standard Appendices, Attachment 27.

Scenario Quantitative Attributes

1. Malfunctions after EOP entry (1-2) 2

2. Abnormal events (2-4) 2

3. Major transients (1-2) 2

4. EOPs entered/requiring substantive actions (1-2) 2

5. EOP contingencies requiring substantive actions (0-2) 1

6. EOP based Critical tasks (2-3) 3 2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 SCENARIO SETUP A. Reset Simulator to IC-161 B. Verify Scenario Malfunctions and Remotes are loaded, as listed in the Scenario Timeline.

C. Place LPSI pump A control switch in 'OFF' with a Danger tag.

D. Place a Protected Equipment cover on LPSI pump B control switch.

E. Place a copy of OP-010-005, Plant Shutdown, with step 9.1.6 (begin boration) circled on the BOP desk. Circle and slash the prior steps to show completion.

F. Ensure Protected Train B sign is placed in SM office window.

G. Verify EOOS is 10.0 Green with LPSI Pump A removed.

H. Complete the simulator setup checklist.

I. Start Insight, open file Crew Performance.tis.

2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 SIMULATOR BOOTH INSTRUCTIONS Event 1 Plant Down Power

1. If the Senior Line Manager/Duty Plant Manager is called, acknowledge the report and inform the Control Room that you will remain in the protected area for the down power.

2. If Woodlands (Load Dispatcher) is called, acknowledge the report.

Event 2 Containment Pressure PPS Channel D (CIAS) CB-IPI-6701SMD Fails High

1. On Lead Examiner's cue, initiate Event Trigger 2.

2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

Event 3 Steam Generator #1 Feedwater Flow Instrument FW-IFR-1111 Fails Low

1. On Lead Examiner's cue, initiate Event Trigger 3.

2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

Event 4 Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, Fails High

1. On Lead Examiner's cue, initiate Event Trigger 4.

2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

3. If sent to LCP-43, wait 3 minutes and report indicator RC-ILI-0110-X1 appears to be failed high. If asked to report Ch. 'Y', report value as read on Extreme View.

Event 5 Seismic Event / Loss of Offsite power / Turbine Trip / 2 Stuck CEAs

1. On Lead Examiner's cue, initiate Event Trigger 5.

2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.

3. If requested to check Emergency Diesel Generators (EDG), wait 3 minutes and report EDGs are operating properly. Initiate event triggers 20&21 to acknowledge local annunciator panels.

4. If called as an NAO to locally close MSR temperature control valves, wait 5 minutes, initiate event trigger 22 and report all MSR temperature valves are closed.

5. If called as an NAO to align power to the DCT sump pumps, wait 5 minutes, run schedule file "Re-energize A(B) Powered DCT Sump Pumps.sch" as appropriate and make report to the Control Room after the schedule file completes all actions.

6. If called as an NAO to align Potable Water to Instrument Air compressors, wait 5 minutes, run schedule file "IA Comp A(B) Align to PW.sch" as appropriate and make report to the Control Room after the schedule file completes all actions.

Event 6/7 Large RCS Cold Leg break / Containment Spray Fails to AUTO Actuate

1. On Lead Examiner's cue, initiate Event Trigger 6.

2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.

3. If Chemistry is called to perform samples acknowledge the request.

2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 Event 8 Low Pressure Safety Injection Pump B Trips / Align CS to replace LPSI

1. On Lead Examiner's cue, initiate Event Trigger 7.

2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.

3. If Chemistry is called to perform samples acknowledge the request.

4. If called as an NAO to investigate the trip at the breaker, report overcurrent flags on all 3 phases.

5. If called as an NAO to investigate the trip at the pump, report that there is no oil visible on the motor bearing sightglass and oil is dripping from the motor housing.

6. If called as an NAO to rack out LPSI pump B breaker or open the knife switch, wait 2 minutes, initiate event trigger 8 (SIR33) and then make report to the Control Room that you have done so.

7. If called as an NAO to place CS-125B override keyswitch in "Override", wait 2 minutes and then initiate event trigger 9 (CSR13B) to place CS-125B in override. Make report to the Control Room that you have done so.

8. If called as an NAO to locally close SI-129B, wait 3 minutes and then initiate event trigger 23 (SIR50 & SIR51) to close SI-129B. Pull up Extreme View - LP Safety Injection to check position and make report to the Control Room that you have done so.

9. At the end of the scenario, before resetting, complete data collection by saving the file as 2015 Scenario 1-(start-end time).tid. Export to .csv file. Save the file into the folder for the appropriate crew.

2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 SCENARIO TIMELINE DELAY RAMP EVENT KEY DESCRIPTION TRIGGER FINAL HH:MM:SS HH:MM:SS EVENT DESCRIPTION N/A SIR32 LPSI PUMP A BREAKER RACKED OUT (Not listed in Summary) N/A N/A N/A RKOUT LOW PRESS SAFETY INJECTION PUMP A TAGGED OUT 1 N/A N/A N/A N/A N/A N/A PLANT DOWN POWER 2 CH08E1 CNTMT PRESS TRANSMITTER 6701 SMD FAILS HI 2 00:00:00 00:00:00 ACTIVE CONTAINMENT PRESSURE PPS CHANNEL D (CIAS) CB-IPI-6701SMD FAILS HIGH 3 FW26A SG1 FEED FLOW INST FAILS LOW TO 17% 3 00:00:00 00:00:10 17%

STEAM GENERATOR #1 FEEDWATER FLOW INSTRUMENT FW-IFR-1111 FAILS LOW 4 RC15A1 PZR LEVEL CONTROL CHANNEL, RC-ILT-0110X, FAILS HIGH 4 00:00:00 00:00:00 ACTIVE PRESSURIZER LEVEL CONTROL CHANNEL LEVEL TRANSMITTER, RC-ILT-0110X, FAILS HIGH 5 L_L10 SEISMIC RECORDERS IN OPERATION (Delete after 30 Seconds) 5 00:00:00 00:00:00 FAIL_ON SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 L_M10 SEISMIC EVENT 5 00:00:00 00:00:00 FAIL_ON SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01A LOSS OF OFFSITE POWER (LINE A) 5 00:00:03 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01B LOSS OF OFFSITE POWER (LINE A) 5 00:00:03 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01C LOSS OF OFFSITE POWER (LINE B) 5 00:00:07 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 ED01D LOSS OF OFFSITE POWER (LINE B) 5 00:00:07 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 DELAY RAMP EVENT KEY DESCRIPTION TRIGGER FINAL HH:MM:SS HH:MM:SS EVENT DESCRIPTION 5 TU06 TURBINE TRIP 5 00:00:07 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 RD11A32 CEA 32 MECHANICALLY STUCK N/A 00:00:00 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 5 RD11A47 CEA 47 MECHANICALLY STUCK N/A 00:00:00 00:00:00 ACTIVE SEISMIC EVENT / LOSS OF OFFSITE POWER / TURBINE TRIP / 2 STUCK CEAS 6 RC23A RCS COLD LEG 1A RUPTURE 6 00:00:00 00:03:00 14%

LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05A3 FAILS TO TRIP CH A HI-HI CONT. PRESS (CSAS) N/A 00:00:00 00:00:00 ACTIVE LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05B3 FAILS TO TRIP CH B HI-HI CONT. PRESS (CSAS) N/A 00:00:00 00:00:00 ACTIVE LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05C3 FAILS TO TRIP CH C HI-HI CONT. PRESS (CSAS) N/A 00:00:00 00:00:00 ACTIVE LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 7 RP05D3 FAILS TO TRIP CH D HI-HI CONT. PRESS (CSAS) N/A 00:00:00 00:00:00 ACTIVE LARGE RCS COLD LEG BREAK / CONTAINMENT SPRAY FAILS TO AUTO ACTUATE 8 SI01E LOSS OF LOW PRESS SAFETY INJECTION PUMP B 7 00:00:00 00:00:00 ACTIVE LOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B 8 SIR33 LPSI PUMP B BREAKER RACKED OUT 8 N/A N/A RKOUT LOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B 8 CSR13B CS-125B OVERRIDE KEYSWITCH 9 N/A N/A OVRD LOW PRESS SAFETY INJECTION PUMP B TRIPS / ALIGN CS PUMP B TO REPLACE LPSI PUMP B 2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 DELAY RAMP EVENT KEY DESCRIPTION TRIGGER FINAL HH:MM:SS HH:MM:SS EVENT DESCRIPTION N/A EGR26 EDG A LOCAL ANNUN ACK 20 N/A N/A ACKN EDG A LOCAL ANNUNCIATOR PANEL N/A EGR27 EDG B LOCAL ANNUN ACK 21 N/A N/A ACKN EDG B LOCAL ANNUNCIATOR PANEL N/A MSR43 CLOSE MSR TEMPERATURE CNTRL VALVES 22 N/A N/A CLSD CLOSE MSR TEMPERATURE CNTRL VALVES N/A SIR50 SI-129B - SDC B FCV CONTROL 23 N/A N/A LOCAL SI-129B - SDC B FCV CONTROL N/A SIR51 SI-129B - SDC B FCV POSITION 23 00:00:05 00:00:00 0%

SI-129B - SDC B FCV POSITION 2015 NRC Exam Scenario 1 D-1 Rev 2

NRC Scenario 1 REFERENCES Event Procedures 1 OP-010-005, Plant Shutdown, Rev. 326 OP-002-005, Chemical and Volume Control, Rev. 47 OP-005-007, Main Turbine and Generator, Rev. 303 OP-004-004, Control Element Drive, Rev. 19 2 OP-009-007, Plant Protection System, Rev. 16 OP-903-013, Monthly Channel Checks, Rev. 18 Technical Specification 3.3.1 Technical Specification 3.3.2 3 OP-901-201, Steam Generator Level Control Malfunction, Rev. 6 EN-OP-115, Conduct of Operations, Rev. 15 Tech Requirement Manual 3.3.5 4 OP-901-110, Pressurizer Level Control Malfunction, Rev. 8 OP-903-013, Monthly Channel Checks, Rev. 18 Technical Specification 3.3.3.5 Technical Specification 3.3.3.6 5 OP-902-000, Standard Post Trip Actions, Rev. 15 OP-901-103, Emergency Boration, Rev. 3 OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),

Appendix 2 (Figures) 6 OP-902-002, Loss of Coolant Accident Recovery Procedure, Rev. 19 OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),

Appendix 2 (Figures) 7 EN-OP-115, Conduct of Operations, Rev. 15 8 OP-902-008, Functional Recovery Procedure, Rev. 23 OP-902-009, Standard Appendices, Rev. 310, Appendix 27 (Aligning CS to replace LPSI),

and Appendix 21 (Overrides for Containment Isolation) 2015 NRC Exam Scenario 1 D-1 Rev 2

Appendix D Scenario Outline Form ES-D-1 Facility: Waterford Scenario No.: 3 Op Test No.: 1 Examiners: Operators:

Initial Conditions: Mode 2, Reactor Power ~1%. Two Charging Pumps in operation.

Turnover:

Protected Train is B. AB Bus is aligned to Train B. Dilute to 5-10% power.

Event Malf. Event Event No. No. Type* Description R - ATC Dilute to 5-10% power, perform 100 gallon PMU 1 N/A N - SRO addition.

I - BOP Narrow Range Safety Pressure Instrument, RC-IPT-I - SRO 0101B, fails low requiring TS 3.3.1 entry and 2 RC22B2 TS - SRO bypassing of affected trip bistables.

C - ATC CV35A C - BOP During dilution, PMU counter fails to secure flow OP-3 CVR101 C - SRO 901-104, Inadvertent Positive Reactivity Addition.

C - BOP Component Cooling Water Pump A trips requiring C - SRO entry into OP-901-510, Component Cooling Water 4 CC01A TS - SRO System Malfunction (TS 3.7.3 & Cascading).

Pressurizer Pressure RC-IPR-0100 X fails high, Main I - ATC Spray Valves open requiring entry into OP-901-120, 5 RX14A I - SRO Pressurizer Pressure Malfunction.

Main Steam Line Break outside Containment, SG 1, OP-902-004, Excess Steam Demand Recovery.

(Critical Task 1, stabilize RCS temperature within P/T limits prior to lifting a PZR safety or SG safety)

(Critical Task 2, stabilize RCS pressure within P/T limits and less than or equal to 1600 psid of the faulted SG prior to RCS pressure exceeding 2500 PSIA) 6 MS13A M - All (Critical Task 3, isolate Steam Generator #1)

C - BOP Main Feedwater Isolation Valve Steam Generator 1, 7 RP08G C - SRO FW-184A fails to AUTO close on MSIS.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 2015 NRC Exam Scenario 3 D-1 Rev 2

Scenario Event Description NRC Scenario 3 The crew assumes the shift with the reactor at 1% power following a forced outage. The turnover will include instructions to perform RCS dilution to 5 - 10% power.

The reactivity plan will include instructions to dilute in multiple PMU batches. The initial batch will be 100 gallons of PMU. Each subsequent batch will be 50 gallons of PMU. This will allow for an observable power rise without concern for a reactor trip on the PMU failure.

After the first 100 gallons of PMU are added, Pressurizer pressure instrument, RC-IPI-0101B fails low.

The ATC operator will receive the annunciators for this failure. The CRS should evaluate Tech Specs and enter Tech Spec 3.3.1 and determine that the Plant Protection System bistables for high LPD, low DNBR and high Pressurizer pressure (3, 4, & 5) must be bypassed within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months on Channel B. Tech Spec 3.3.3.5 and 3.3.3.6 should be referenced but not entered.

During the second dilution, the Primary Water counter will fail to secure dilution. The ATC should attempt to secure Primary Water Flow by operating PMU-144 and CVC-510. Neither of these actions will secure flow. The CRS should enter OP-901-104, Inadvertent Positive Reactivity Addition, and secure Primary Makeup Pump A.

After these actions are completed, Component Cooling Water Pump A trips on overcurrent. The SRO should enter OP-901-510, Component Cooling Water System Malfunction, and direct the start of Component Cooling Water Pump AB to replace Component Cooling Water Pump A. The SRO should enter Technical Specification 3.7.3, TRM 3.7.3, and cascading Technical Specifications per OP-100-014, Technical Specification and Technical Requirements Compliance.

After the Tech Specs are evaluated, Pressurizer pressure instrument RC-IPR-0100 X fails high. This causes both Main Spray valves to open. The SRO should direct the ATC to take manual control and close the spray valves and enter OP-901-120, Pressurizer Pressure Malfunction. The ATC will align the non-faulted Pressurizer pressure channel.

After the Pressurizer Pressure Control Channel Y is selected, a non-isolable Main Steam line break outside Containment occurs on Main Steam Line 1, resulting in a reactor trip, Safety Injection Actuation Signal (SIAS), Containment Isolation Actuation Signal (CIAS) and Main Steam Isolation Signal (MSIS).

FW-184A, Feedwater Isolation Valve A fails to close automatically on the MSIS requiring the BOP to manually close the valve. The SRO should diagnose to OP-902-004, Excess Steam Demand Recovery Procedure. The crew should take action to stabilize Reactor Coolant System temperature (CRITICAL TASK 1) and pressure (CRITICAL TASK 2) when Reactor Coolant System pressure AND Core Exit Thermocouple temperatures start to rise. The crew should also take action to isolate Steam Generator #1 in accordance OP-902-004, Excess Steam Demand Recovery (CRITICAL TASK 3).

The scenario can be terminated after the crew has isolated Steam Generator 1 or at the lead examiners discretion.

2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 CRITICAL TASKS

1. ESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROL This task is satisfied by taking action to stabilize Reactor Coolant System temperature within the limits of the Reactor Coolant System Pressure/Temperature Limits curve using Atmospheric Dump Valve 2 and establishing EFW flow to Steam Generator 2 prior to lifting a Pressurizer safety (2500 psia) or Steam Generator safety (1070 psig). This task becomes applicable once CET temperature and PZR pressure begin to rise following the Main Steam Line Break. Either OP-902-000, Standard Post Trip Actions or OP-902-004, Excess Steam Demand Recovery direct actions to satisfy this task.

2. ESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROL This task is satisfied by taking actions to stabilize RCS pressure within the limits of the Reactor Coolant System P/T curve and less than or equal to 1600 psid of the faulted steam generator by throttling HPSI flow. Action to address this task should commence prior to RCS pressure exceeding 2500 PSIA (e.g. solid plant conditions). This task becomes applicable once CET temperature and PZR pressure begin to rise following the Main Steam Line Break. Either OP-902-000, Standard Post Trip Actions or OP-902-004, Excess Steam Demand Recovery direct actions to satisfy this task.

3. ISOLATE STEAM GENERATOR #1 This task is satisfied by taking actions to isolate Steam Generator #1 in accordance with OP-902-004, Excess Steam Demand Recovery step 14. This task should be completed prior to the crew indicating that step 14 (Isolate Most Affected SG) of OP-902-004 is completed. This task becomes applicable once indications of an Excess Steam Demand accident are present in the simulator. OP-902-004, Excess Steam Demand Recovery directs actions to satisfy this task.

Scenario Quantitative Attributes

1. Malfunctions after EOP entry (1-2) 1

2. Abnormal events (2-4) 3

3. Major transients (1-2) 1

4. EOPs entered/requiring substantive actions (1-2) 1

5. EOP contingencies requiring substantive actions (0-2) 0

6. EOP based Critical tasks (2-3) 3 2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 SCENARIO SETUP A. Reset Simulator to IC-163.

1. Use keys 165 - 168 for S/G high level bypass setup.

B. Verify Scenario Malfunctions and Remotes are loaded, as listed in the Scenario Timeline.

C. Ensure Event Trigger 10 is inserted as follows (Should be loaded in IC):

1. Event - PMU Pump A to STOP

2. Code is ZDIFWPMUECS1357(1) == 1 D. Ensure Protected Train B sign is placed in SM office window.

E. Verify EOOS is 10.0 Green F. Place a copy of OP-010-003, Plant Startup, on CRS's desk with step 9.4.54 (raise power to 5%)

circled and several of the previous steps circle-slashed to show progress. Fill in initials (and circle-slash) steps 9.4.59 (mode 1 Tech Spec logs) and 9.4.60 (Chemistry contacted) as complete. Sign step 9.4.61 (SM permission to enter mode 1).

G. Complete the simulator setup checklist.

H. Remove PMC point D39502 from scan (DFP).

I. Start Insight, open file Crew Performance.tis.

2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 SIMULATOR BOOTH INSTRUCTIONS Event 1 Dilute to 5-10% power, Perform 100 gallon PMU addition

1. If called as Chemistry to verify SG chemistry is within specification, inform the caller that SG chemistry is satisfactory. If asked for your name, say Joe Chemist.

2. If called as an NAO to open or throttle open MS-148, acknowledge the communication. Wait 5 minutes, report that you will be slowly opening/throttling MS-148, MS Supply to Gland Seal Isolation. Initiate Event Trigger 1. After MS-148 completes ramping, report that MS-148 is open/throttled open. If you are directed to further throttle open MS-148, simply acknowledge the request, wait ~30 seconds and report the new throttled position. Repeat as necessary until it is reported that MS-148 is fully open.

3. If called as an NAO to transfer Auxiliary Steam from Aux Boiler Steam to Main Steam, acknowledge the communication. Wait 15 minutes, and then report that Auxiliary Steam has been transferred to Main Steam (no remote necessary).

4. If called as an NAO to secure the Portable Auxiliary Boiler, acknowledge the communication. Wait 5 minutes, initiate Event Trigger 17 and report that the Portable Aux Boiler is secured.

Event 2 Narrow Range Safety Pressure Instrument, RC-IPT-0101B, fails Low

1. After the first 100 gallon addition is completed or on Lead Examiner's cue, initiate Event Trigger 2.

2. If Work Week Manager or PMI are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

Event 3 PMU flow malfunction

1. On Lead Examiner's cue, insert Event Trigger 3 after the ATC has established PMU flow (second addition).

2. If called to operate valves listed in OP-901-104, acknowledge communication and report that you will work on valve list.

Event 4 Component Cooling Water Pump A Trips

1. On Lead Examiner's cue, initiate Event Trigger 4.

2. If called as the watchstander and sent to CCW Pump A, wait 3 minutes, report that the pump looks normal locally.

3. If called as the watchstander and sent to CCW Pump A breaker, wait 3 minutes, report that the breaker indicates open and that there are various breaker parts on the floor of the cubicle.

4. If Work Week Manager or PME are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

Event 5 Pressurizer pressure instrument RC-IPR-0100 X fails High

1. On Lead Examiner's cue, initiate Event Trigger 5.

2. If Work Week Manager or I&C are called, inform the caller that a work package will be assembled and a team will be sent to the Control Room.

2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 Event 6 Main Steam Line Break outside Containment, SG 1

1. On Lead Examiner's cue, initiate Event Trigger 6.

2. If the Duty Plant Manager is called, inform the caller that you will make the necessary calls.

3. If Chemistry is called to perform samples acknowledge the request.

4. If requested to check Emergency Diesel Generators (EDG), wait 3 minutes and report EDGs are operating properly. Initiate event triggers 15 & 16 to acknowledge local annunciator panels.

5. If called as an NAO to check for steam outside, wait 2 minutes, report that a large amount of steam is issuing from the west MSIV area.

Event 7 Main Feedwater Isol Valve SG1, FW-184A, fails to AUTO close on MSIS

1. No communications should occur for this evolution.

2. At the end of the scenario, before resetting, complete data collection by saving the file as 2015 Scenario 3-(start-end time).tid. Export to .csv file. Save the file into the folder for the appropriate crew. Restore PMC point D39502 (RTP).

3. After the simulator is reset, verify PMC point D39502 is in service by displaying and then escaping from the display.

2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 SCENARIO TIMELINE DELAY RAMP EVENT KEY DESCRIPTION TRIGGER FINAL HH:MM:SS HH:MM:SS EVENT DESCRIPTION 1 MSR09 MS-148 MS to GS ISOL VALVE 1 00:00:00 00:01:00 12%

DILUTE TO RAISE POWER 2 RC22B2 PZR CPC SAFETY, RC-IPT-0101B, FAILS LOW 2 00:00:00 00:00:00 ACTIVE NR SAFETY PRESSURE INSTRUMENT, RC-IPT-0101B, FAILS LOW 3 CV35A MAKUP CTRLR FAILS TO ISSUE VLV CLSR WHEN BATCH COMP 3 00:00:00 00:00:00 ACTIVE DURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 3 CVR101 PMU-140 DILUTION TO CVCS PUMP SUCTION (0-100%) 3 00:00:00 00:00:00 2%

DURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 3 CVR101 PMU-140 DILUTION TO CVCS PUMP SUCTION (0-100%) 10 00:00:00 00:00:00 0%

DURING DILUTION, PMU COUNTER FAILS TO SECURE FLOW 4 CC01A CCW PUMP A TRIP 4 00:00:00 00:00:00 ACTIVE COMPONENT COOLING WATER PUMP A TRIP 5 RX14A PZR PRESSURE CNTL CHL 100 X FAIL (0-100%) (1500-2500 PSIA) 5 00:00:00 00:00:00 100%

PRESSURIZER PRESSURE RC-IPR-0100 X FAILS HIGH 6 MS13A MS A BREAK OUTSIDE CNTMT BEFORE MSIV (0-100%) 6 00:00:00 00:00:00 6%

NON-ISOLABLE MAIN STEAM LINE A BREAK OUTSIDE CONTAINMENT 7 RP08G RELAY K305 FAILED, MSIS TRAIN A (MS/FW) N/A 00:00:00 00:00:00 ACTIVE FW-184A (SG1 FW ISOL VLV) FAILS TO AUTO CLOSE ON MSIS N/A EGR26 EDG A LOCAL ANNUN ACK 15 N/A N/A ACKN EDG A LOCAL ANNUNCIATOR PANEL N/A EGR27 EDG B LOCAL ANNUN ACK 16 N/A N/A ACKN EDG B LOCAL ANNUNCIATOR PANEL 2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 DELAY RAMP EVENT KEY DESCRIPTION TRIGGER FINAL HH:MM:SS HH:MM:SS EVENT DESCRIPTION N/A MSR32 TEMPORARY AUX BOILER 17 N/A N/A OFFLINE TEMPORARY AUX BOILER (16 MIN TILL RATED PRESS) 2015 NRC Exam Scenario 3 D-1 Rev 2

NRC Scenario 3 REFERENCES Event Procedures 1 OP-010-003, Plant Startup, Rev. 335 OP-002-005, Chemical and Volume Control, Rev. 47 2 OP-009-007, Plant Protection System, Rev. 16 OP-903-013, Monthly Channel Checks, Rev. 18 Technical Specification 3.3.1 3 OP-901-104, Inadvertent Positive Reactivity Addition, Rev. 302 4 OP-901-510, Component Cooling Water Malfunction, Rev. 303 OP-100-014, TS & TRM Compliance, Rev. 328 Technical Specification 3.7.3 & Cascading Tech Requirement Manual 3.7.3 5 OP-901-120, Pressurizer Pressure Control Malfunction, Rev. 302 Technical Specification 3.2.8 6 OP-902-000, Standard Post Trip Actions, Rev. 15 OP-902-004, Excess Steam Demand Recovery Procedure, Rev. 15 OP-902-009, Standard Appendices, Rev. 310, Appendix 1 (Diagnostic Flow Chart),

Appendix 2 (Figures) 7 OP-902-004, Excess Steam Demand Recovery Procedure, Rev. 15 OI-038-000, EOP Operations Expectations/Guidance, Rev. 10 EN-OP-115, Conduct of Operations, Rev. 15 2015 NRC Exam Scenario 3 D-1 Rev 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 1 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior Examiner Note Event 1 is a normal plant evolution. The crew will be pre-briefed and ready to start the down power once they take the shift.

OP-010-005, Section 9.1, Plant Shutdown to Hot Standby SRO 9.1.6 Begin RCS boration in accordance with OP-002-005, Chemical and Volume Control to reduce Reactor power.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 2 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior The SRO directs the ATC to coordinate with the BOP and perform a plant down power to ~90%. The SRO will direct the ATC to initiate RCS (note) boration in accordance with OP-002-005. SRO direction should include an RCS temperature band and instructions on how to maintain ASI using CEAs.

CAUTION CONTROL RODS SHOULD NEVER BE WITHDRAWN OR MANUALLY INSERTED EXCEPT IN A DELIBERATE CAREFULLY CONTROLLED MANNER WHILE CLOSELY MONITORING THE REACTORS RESPONSE.

SRO 9.1.7 Maintain ASI using CEA Reg. Group 5, 6 or Group P Control Element Assemblies in accordance with Attachment 9.10, Axial Shape Control Guidelines. (Refer to T.S. 3.1.3.6).

SRO 9.1.8 When Average Reactor Coolant Temperature (Tavg) begins to drop, then reduce Generator load to match Tavg and Reference Temperature (Tref) in accordance with OP-005-007, Main Turbine and Generator.

NOTE (1) If USBSCAL is not in service, the COLSS Steam Calorimetric will be automatically disabled when MSBSCAL (PMC PID C24246) drops below 95% Power, and will revert back to FWBSCAL (PMC PID C24235).

(2) If USBSCAL is not in service, there may be a step change in COLSS indicated Plant Power of 1.0%, when COLSS Steam Calorimetric is disabled.

SRO 9.1.9 When reactor power consistently indicates less than 98% power, as indicated on computer point C24631, MAIN STEAM RAW POWER (MSBSRAW), or an alternate point provided by Reactor Engineering, then verify the value of C24648, BSCAL SMOOTHING VAL. APPLD (DUMOUT17), automatically changes to 1.

9.1.9.1 If C24648 does not automatically change to 1, then inform Reactor Engineering and set the value of 1 for COLSS power smoothing constant K24250, [ADDRSSBL SMOOTHING FOR BSCAL (ALPHA)] in accordance with OP-004-005, Core Operating Limits Supervisory System.

OP-002-005, Section 6.7, Direct Boration to RCS CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 3 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIOR TO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.

ATC 6.7.1 Inform SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD)

ATC 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode.

ATC 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired.

Procedure does not give specific steps to set the counter. 155 gal of acid on the counter is set by pressing:

UP arrow button ENTER button (note) the side arrow button to move the cursor the raise button to enter 155 ( per reactivity plan)

ENTER RESET (note) 155 gallons is an approximate amount per the reactivity plan. The SRO may decide to add a slightly different amount. Any amount of 155 +/- 5 is satisfactory.

ATC 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 4 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior ATC 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.

ATC 6.7.6 Place Makeup Mode selector switch to BORATE.

ATC 6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.

ATC 6.7.8 Verify Direct Boration Valve, BAM-143, Opens.

NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

ATC will likely use manual boric acid flow control. "CVCS Boric Acid (note) Makeup Flow Hi/Lo" on CP-4 is an expected annunciator. Acid flow can be read on the red pen of recorder BAM-IFR-0210Y.

ATC 6.7.9 If manual control of Boric Acid flow is desired, then perform the following:

6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.

ATC 6.7.10 If automatic control of Boric Acid flow is desired, then perform the following:

6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, in Auto.

6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, setpoint potentiometer to >3 GPM flow rate.

ATC 6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

ATC 6.7.12 Observe Boric Acid flow rate for proper indication.

ATC 6.7.13 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

NOTE Step 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 5 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior ATC 6.7.14 If additional boric acid addition is required and with SM/CRS permission, then perform the following:

6.7.14.1 Reset Boric Acid Makeup Batch Counter.

6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

6.7.14.3 Observe Boric Acid flow rate for proper indication.

6.7.14.4 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

The ATC, with the SRO's direction, may secure boric acid addition at any time by lowering the output on the acid flow controller BAM-IFIC-(note) 0210Y to zero or by closing BAM-143. Steps 6.7.15-6.7.20 secure the full acid addition lineup.

ATC 6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

ATC 6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output and setpoint potentiometer set to zero.

ATC 6.7.17 Place Makeup Mode selector switch to MANUAL.

ATC 6.7.18 Verify Selected Boric Acid Makeup Pump A(B) Stops.

ATC 6.7.19 Verify Direct Boration Valve, BAM-143, Closed.

ATC 6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.

OP-005-007, Section 6.2, Main Turbine & Generator Operation CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. REACTOR POWER, RCS TEMPERATURE, AND MAIN GENERATOR MW LOAD SHOULD BE CLOSELY MONITORED DURING PERFORMANCE OF THIS SECTION. [INPO 06-006]

BOP 6.2.1 To change Load/Rate perform the following:

6.2.1.1 Depress LOAD/RATE MW/MIN pushbutton.

6.2.1.2 Depress appropriate numerical pushbuttons for desired load rate.

6.2.1.3 Depress ENTER pushbutton.

NOTE Prior to changing Reference Demand, Main Turbine load must not be changing.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 6 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior BOP 6.2.2 To change Main Turbine load, perform the following:

6.2.2.1 Depress REF pushbutton.

6.2.2.2 Depress appropriate numerical pushbuttons for desired MW load.

6.2.2.3 Depress ENTER pushbutton.

6.2.2.4 Depress GO pushbutton.

6.2.2.5 Verify Turbine load change stops at the desired MW load.

Examiner Note The steps to insert CEAs for ASI control are included below for your reference. It is not necessary to complete these steps prior to advancing with the scenario.

OP-004-004, Section 6.7, Operation of CEAs in Manual Group (MG) Mode CAUTION (1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THE REACTOR IS NOT CRITICAL.

(2) OBSERVE APPLICABLE GROUP INSERTION LIMITS IN ACCORDANCE WITH TECHNICAL SPECIFICATION 3.1.3.6 (REG GROUP), AND TECHNICAL SPECIFICATION 3.1.3.5 (SHUTDOWN BANKS).

(3) IMPROPER OPERATION OF CEAS IN MANUAL GROUP MODE MAY CAUSE A REACTOR TRIP BASED ON AN OUT-OF-SEQUENCE CONDITION.

(4) CEA INITIALIZATION PROGRAM MUST BE RUNNING IN THE PLANT MONITORING COMPUTER TO HAVE GROUP STOPS AND SEQUENTIAL PERMISSIVES AVAILABLE.

CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. [INPO 06-006]

ATC 6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.

ATC 6.7.2 Position Group Select switch to desired group.

ATC 6.7.3 Place Mode Select switch to Manual Group (MG) and verify the following:

White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 Page 7 of 35 Event

Description:

Normal Plant Down Power Time Position Applicants Actions or Behavior ATC 6.7.4 Operate CEA Manual Shim switch to WITHDRAW or INSERT group to desired height while monitoring the following:

CEA Position Indicator selected CEA group is moving in desired direction If Reactor is critical, then monitor the following:

Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)

NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.

ATC 6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.

Examiner Note This event is complete when both the ATC and BOP have performed actions to commence a plant down power and the reactivity manipulation is satisfied OR As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 2 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 8 of 35 Event

Description:

Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails high Time Position Applicants Actions or Behavior ATC/BOP Recognizes and reports indications of failed channel.

Alarms:

RPS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, A-17)

CNTMT PRESSURE HI PRETRIP B/D (Cabinet K, C-17)

RPS CHANNEL D TROUBLE (Cabinet K, H-18)

ESFAS CHANNEL TRIP CNTMT PRESSURE HI (Cabinet K, L-17)

CNTMT PRESSURE HI ESFAS PRETRIP B/D (Cabinet K, N-17)

Indications:

PPS Channel D Containment Pressure (CIAS), CB-IPI-6701SMD failed high on CP-7 All other Containment Pressure instruments reading normal on CP-7 Pretrip and Trip Bistable Lights illuminated for Containment Pressure HI CNT PRESS (RPS and ESF) on Channel D CP-7 ROM.

OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation All BOP manipulations for OP-009-007 are located at CP-10 (back (note) panel) except as noted.

SRO 6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist in determination of Trip Channels requiring placement in bypass.

SRO determines the following bistables are affected and need to be bypassed:

(note) 13 - HI CNT PRESS (RPS) 16 - HI CNT PRESS (SIAS/CIAS/MSIS)

SRO Directs BOP to bypass the HI CNT PRESS (RPS) and HI CNT PRESS (SIAS/CIAS/MSIS) bistables in PPS Channel D within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in accordance with OP-009-007, Plant Protection System.

BOP 6.2.2 To place a bistable in or remove a bistable from bypass, go to Attachment 11.10, Trip Channel Bypass Operation.

BOP 11.10.1 To Bypass a Trip Channel, perform the following:

11.10.1.1 Circle the bistable numbers selected for bypass under Step 11.10.1.4.

(note) BOP circles bistable numbers 13 and 16 in Step 11.10.1.4 table 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 9 of 35 Event

Description:

Containment Pressure PPS Channel D (CIAS), CB-IPI-6701SMD, fails high Time Position Applicants Actions or Behavior BOP 11.10.1.2 Check desired Trip Channel is not Bypassed on another PPS Channel.

BOP 11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.

BOP 11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP 11.10.1.5 Check all selected bistable Bypass push buttons remain in a Depressed state.

BOP 11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP for the desired Trip Channels.

CREW 11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM for the desired Trip Channels.

Crew verifies correct bistables lit on CP-7 PPS Channel D Remote (note)

Operator Module.

SRO Reviews the following Technical Specifications and determines applicable actions:

3.3.1 action 2 (Bypass w/in 1 hr) 3.3.2 action 13 (Bypass w/in 1 hr) 3.3.3.5 - no actions required (restore w/in 7 days) 3.3.3.6 - no actions required (restore w/in 30 days)

Examiner Note This event is complete when bistables are bypassed and Technical Specifications have been addressed OR As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 3 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 10 of 35 Event

Description:

Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low Time Position Applicants Actions or Behavior BOP Recognize and report indications of Feedwater flow instrument failure.

Alarms:

Steam Generator 1 Steam/FW Flow Signal Dev (Cabinet F, T-17)

Steam Generator 2 Steam/FW Flow Signal Dev (Cabinet F, U-17)

SG 1 Level Hi/Lo (Cabinet F, U-14)

COLSS MASTER (Cabinet L, A-6)

Indications:

Feedwater Flow indicator FW-IFR-1111 fails low Steam Generator 1 Level Rising (SG-ILR1-1105 and 1111)

Deviation between steam flow AND feedwater flow on SG 1 The Ultrasonic Flow Meter quality goes to BAD on this malfunction.

The ATC should not disrupt the CRS and the BOP when trying to (note) stabilize S/G #1 level. The ATC should inform the CRS after the plant is stable and the flow chart is complete. TRM 3.3.5 entry is required on a failure of the UFM.

TRM 3.3.5 action a is entered. The action is to reduce thermal power to less than or equal to 99.5% within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Examiner Note When a control system is not operating properly in automatic, it is acceptable for the SRO to direct taking manual control prior to entering the appropriate procedure.

SRO Directs BOP to take manual control of Feedwater Control System 1 (FWCS) and match Feedwater flow and Steam flow on Steam Generator 1 and restore level to 50-70% NR.

BOP Will take manual control of FWCS 1 and Match Feedwater Flow and Steam Flow.

(note) Manual control involves taking the Master controller and/or the Main FRV controller to manual (white lights). Most likely the Master controller first and then if necessary the Main FRV. If the high level override setpoint is reached (74% NR) it may be necessary to take all three to manual to stabilize level.

FW-IFIC-1111 - SG1 Master Controller FW-IHIC-1111 - SG1 Main Feedwater Regulating Valve FW-IHIC-1105 - SG1 Startup Feedwater Regulating Valve SRO Enters and directs the implementation of OP-901-201, Steam Generator Level Malfunction 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 11 of 35 Event

Description:

Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low Time Position Applicants Actions or Behavior OP-901-201, Steam Generator Level Malfunction, E0, General SRO 1. Go to Attachment 1, General Actions.

OP-901-201, Steam Generator Level Malfunction, Attachment 1, General Actions SRO Did a Reactor Trip occur? NO - continue with flowchart SRO/BOP Observe the affected Steam Generator FWCS controllers AND note ANY controllers that are behaving erratically.

Steam Generator 1 FW IFIC 1111 , S/G 1 FWCS Master Controller FW IHIC 1111 , S/G 1 Main FRV Controller FW IHIC 1105 , S/G 1 S / U FRV Controller FW IHIC 1107 , SGFP A Speed Controller Steam Generator 2 FW IFIC 1121 , S/G 2 FWCS Master Controller FW IHIC 1121 , S/G 2 Main FRV Controller FW IHIC 1106 , S/G 2 S / U FRV Controller FW IHIC 1108 , SGFP B Speed Controller (note) BOP should determine that no controllers are malfunctioning.

N/A Place appropriate controllers for the affected FWCS in manual AND establish control of S/G level.

(note) Controllers already in MANUAL (prior order)

SRO/BOP Is the output of the affected FWCS Master Controller behaving erratically?

(note) NO - continue with flowchart SRO/BOP Verify SGFP Discharge pressure for BOTH SGFP ' s is matched AND is greater than S / G pressures.

(note) BOP verifies - continue with flowchart SRO Stop turbine load changes except to match Tave and Tref.

SRO should direct ATC/BOP to stop downpower and stabilize the plant. ATC will secure adding boric acid to the RCS and the BOP will (note) stop turbine load reduction. After stopping the downpower, Turbine load adjustments are allowed to match Tave and Tref.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 12 of 35 Event

Description:

Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low Time Position Applicants Actions or Behavior SRO/BOP Review the following guidelines AND restore S /G level to 50-70% NR:

1. IF one SGFP Speed controller is in auto, THEN use its output to help set the SGFP Speed controller that is in manual.

2. Momentary taps on the raise AND lower buttons of the Main Feedwater Reg Valve Controller have a noticeable impact on associated Steam Generator level.

3. Use the Startup Feedwater Reg Valve Controller to control Steam Generator level at low power levels.

4. Use indications on the unaffected FWCS controllers to help set affected FWCS controllers.

(note) SRO & BOP review guidance SRO/BOP Check the following Control Channel indicators to determine if a Control Channel has failed: (See Note 3)

FW IFR 1111, Steam Generator 1 Feedwater Flow (green pen )

FW IFR 1011, Steam Generator 1 Steam Flow (red pen )

FW IFR 1121, Steam Generator 2 Feedwater Flow (green pen )

FW IFR 1021, Steam Generator 2 Steam Flow (red pen )

SG ILR1111, Steam Generator 1 Downcomer Level (green pen )

SG ILR1105, Steam Generator 1 Downcomer Level (red pen )

SG ILR1121, Steam Generator 2 Downcomer Level (green pen )

SG ILR1106, Steam Generator 2 Downcomer Level (red pen )

BOP should determine FW IFR 1111, Steam Generator 1 Feedwater (note) Flow (green pen) is failed low.

SRO Control Channel level deviation of > 7%?

(note) NO - continue with flowchart SRO Main Feedwater Pump Speed Controller malfunction?

(note) NO - continue with flowchart SRO Is feedwater flow for the affected SG abnormally high?

(note) NO - continue with flowchart SRO/BOP Determine AND correct the cause of the malfunction.

BOP should report which controllers are still in MANUAL. SRO and (note) BOP should discuss contingency actions for FWCS 1 being in MANUAL. SRO will conduct a brief at this point.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 13 of 35 Event

Description:

Steam Generator #1 Feedwater flow instrument FW-IFR-1111 fails low Time Position Applicants Actions or Behavior Examiner Note This event is complete after the SRO has completed the flowchart and Steam Generator 1 level is being controlled OR As directed by the Lead Evaluator.

Examiner Note Cue the Simulator Operator when ready for Event 4 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4 Page 14 of 35 Event

Description:

Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails high Time Position Applicants Actions or Behavior ATC Recognize and report indications of failed instrument.

Alarms:

PRESSURIZER LEVEL HI/LO (Cabinet H, B-1)

PRESSURIZER LEVEL HI-HI (Cabinet H, A-1)

LETDOWN FLOW HI/LO (Cabinet G, C-1)

LETDOWN HX OUTLET PRESS HI (Cabinet G, A-2)

Indications Mismatch between Charging (CVC-IFI-0212) AND Letdown (CVC-IFI-0202) flow indications. Letdown rises to maximum, with 1 charging pump running Deviation between indicated level AND programmed level as indicated on Pressurizer level recorder (RC-ILR-0110).

RC-ILI-0110X reading ~ 100%

Actual Pressurizer level RC-ILI-0110Y slowly lowering.

Pressurizer Backup Heaters energize SRO may direct the ATC to take manual control of Pressurizer Level (note) Controller, RC-ILIC-0110 and match Letdown flow and Charging flow prior to entering procedure.

SRO Enter and direct the implementation of OP-901-110, Pressurizer Level Control Malfunction.

OP-901-110, Section E0, General Actions SRO 1. Stop Turbine load changes.

If not already performed in the previous event, the SRO should direct ATC/BOP to stop downpower. ATC will secure adding boric acid to the (note) RCS and the BOP will stop turbine load reduction. After stopping the downpower, Turbine load adjustments are allowed to match Tave and Tref.

N/A 2. IF malfunction is due to failure of Letdown Flow Control valve, THEN go to OP-901-112, CHARGING/LETDOWN MALFUNCTION.

SRO 3. IF malfunction is due to failure of Pressurizer Level Control Channel (incorrect readings on either RC-ILI-0110X OR RC-ILI-0110Y), then go to Subsection E1, Pressurizer Level Control Channel Malfunction.

OP-901-110, Section E1, Pressurizer Level Control Channel Malfunction 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4 Page 15 of 35 Event

Description:

Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails high Time Position Applicants Actions or Behavior NOTE Selecting the non-faulted channel may cause automatic actions to occur if actual level is not at program level.

ATC 1. Place Pressurizer Level Controller (RC-ILIC-0110) in MAN and adjust OUTPUT to slowly adjust letdown flow to restore Pressurizer level.

ATC 2. Transfer Pressurizer Level Control CHANNEL SELECT switch to non-faulted channel.

ATC 3. Transfer Pressurizer CHANNEL SELECT LO LEVEL HEATER CUTOFF switch to non-faulted channel.

ATC 4. Verify desired backup Charging pumps in AUTO.

ATC 5. Verify all PROPORTIONAL and BACKUP HEATER BANKS reset.

ATC 6. Place Pressurizer Level Controller (RC-ILIC-0110) in AUTO and verify Pressurizer Level is being restored to setpoint.

ATC 7. Verify Pressurizer level controlling at program setpoint in accordance with Attachment 1, Pressurizer Level Versus Tave Curve.

SRO 8. Refer to the following Technical Specifications for Operability determination.

3.2.8, Power Distribution Systems, Pressurizer Pressure 3.3.3.5, Instrumentation, Remote Shutdown Instrumentation 3.3.3.6, Instrumentation, Accident Monitoring Instrumentation 3.4.3.1, Reactor Coolant System, Pressurizer The SRO should review Technical Specifications 3.3.3.5 (restore w/in 7 days) and 3.3.3.6 (restore w/in 30 days) and OP-903-013, Monthly (note) Channel Checks. The SRO should determine that TS 3.3.3.6 requirements are met, but enter TS 3.3.3.5 Action a (restore w/in 7 days or shutdown).

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4 Page 16 of 35 Event

Description:

Pressurizer Level Control Channel Level Transmitter, RC-ILT-0110X, fails high Time Position Applicants Actions or Behavior Examiner Note This event is complete after Pressurizer Level Control System is selected to non-faulted channel and returned to automatic operation and Technical Specifications have been addressed OR As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 5 Event Trigger 5 will initiate seismic event alarms, loss of offsite power, and a turbine trip. All will occur in less than 10 seconds and will result in an automatic reactor trip.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 17 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior ATC/BOP Recognize and report indications of Seismic Event / Loss of Offsite Power /

Turbine Trip / Reactor Trip / 2 stuck CEAs Alarms:

SEISMIC RECORDERS IN OPERATION (Cabinet L, L-10)

SEISMIC EVENT (Cabinet L, M-10)

SWITCHING STATION TROUBLE(Cabinet D, T-7) 230 KV LINE A VOLTAGE LOST (Cabinet D, U-7) 230 KV LINE B VOLTAGE LOST (Cabinet D, U-8)

Indications:

Turbine Tripped (All Turbine Valves closed on CP-1 mimic)

Reactor Tripped (All except two rod bottom lights illuminated)

CEA 32 and 47 Rod Bottom Lights NOT illuminated and their Upper Electrical Limit (red) lights remain illuminated Lights in the Control Room dim and re-energize when EDGs tie to their respective safety buses SRO Directs ATC and BOP to carry out Standard Post trip Actions.

OP-902-000, Standard Post Trip Actions (STPAs)

CRITICAL TASK 1 ESTABLISH REACTIVITY CONTROL This task is satisfied by establishing emergency boration prior to exiting OP-902-000, Standard Post Trip Actions.

This task becomes applicable after the reactor trips.

ATC 1. Determine Reactivity Control acceptance criteria are met:

a. Check reactor power is dropping.

b. Check startup rate is negative.

c. Check less than TWO CEAs are NOT fully inserted.

Examiner Note ATC is required to emergency borate due to criteria 1.c NOT met.

Emergency Boration steps:

ATC 1. If Charging is available, then perform the following:

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 18 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior ATC 1.1 Place Makeup Mode selector switch to MANUAL. (CRITICAL)

ATC 1.2 Align borated water source by performing one of the following (a or b):

a. Initiate Emergency Boration using Boric Acid Pump as follows:

Open Emergency Boration Valve, BAM-133.

(CRITICAL)

Start one Boric Acid Pump. (CRITICAL)

Close recirc valve for Boric Acid Pump started:

BAM-126A Boric Acid Makeup Pump Recirc Valve A (CRITICAL) or BAM-126B Boric Acid Makeup Pump Recirc Valve B (CRITICAL)

OR

b. Initiate Emergency Boration using Gravity Feed as follows:

Open the following Boric Acid Makeup Gravity Feed valves:

BAM-113A Boric Acid Makeup Gravity Feed Valve A (CRITICAL)

BAM-113B Boric Acid Makeup Gravity Feed Valve B (CRITICAL)

ATC 1.3 Close VCT Disch Valve, CVC-183. (CRITICAL)

ATC 1.4 Verify at least one Charging Pump operating and Charging Header flow greater than or equal to 40 GPM. (CRITICAL)

OP-902-000, Standard Post Trip Actions (continued)

BOP 2. Determine Maintenance of Vital Auxiliaries acceptance criteria are met:

a. Check the Main Turbine is tripped:

Governor valves closed Throttle valves closed (note) The BOP may take manual action to trip the Main Generator. This is not critical because eventually the Generator will automatically trip.

BOP b. Check the Main Generator is tripped:

GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 19 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior BOP c. Check station loads are energized from offsite electrical power as follows:

Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel BOP c.1 IF ANY 4.16 KV safety bus is NOT powered from offsite, THEN:

1) Verify associated EDG has started AND EDG output breaker closed.

2) IF EDG output breaker is NOT closed THEN:

Verify stable EDG Voltage 3920 - 4350 AC Volts.

Verify 3-2 Breaker open.

Check Sequencer LOCKOUT NOT illuminated.

3) IF EDG output breaker is NOT closed AND Step c.1.2) is met THEN locally close EDG output breaker.

4) Verify CCW cooling available to EDG.

(note) BOP should verify Component Cooling Water pumps running on CP-8 ATC 3. Determine RCS Inventory Control acceptance criteria are met:

a. Check that BOTH the following conditions exist:

Pressurizer level is 7% to 60%

Pressurizer level is trending to 33% to 60%

b. Check RCS subcooling is greater than or equal to 28ºF.

The ATC should use CET subcooling on QSPDS or CP-7 to determine (note)

RCS subcooling due to the loss of RCPs.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 20 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior ATC 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist:

Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia ATC 5. Determine Core Heat Removal acceptance criteria are met:

a. Check at least one RCP is operating.

b. Check operating loop T is less than 13ºF.

c. Check RCS subcooling is greater than or equal to 28ºF.

Core Heat Removal safety function will not be met. All Reactor Coolant Pumps (RCPs) will be stopped due to loss of power; Operators should (note) monitor for natural circulation conditions 5-15 minutes after the loss of RCPs.

BOP 6. Determine RCS Heat Removal acceptance criteria are met:

a. Check that at least one steam generator has BOTH of the following:

Steam generator level is 10% to 76% NR Main Feedwater is available to restore level within 55%-70%

NR. [60-80% NR].

BOP a2. Verify Emergency Feedwater is available to restore level in at least one steam generator within 55%-70% NR [60-80% NR].

Main Feedwater will not be available. BOP should perform contingency (note) action a2.

ATC b. Check RCS TC is 530 ºF to 550 ºF BOP c. Check steam generator pressure is 885 psia to 1040 psia.

BOP d. Check Feedwater Control in Reactor Trip Override:

MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm Both Main Feedwater pumps will trip due to loss of power. Reactor Trip (note) Override actions are not critical since the Main Feed pumps are tripped.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 21 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior BOP e. Reset moisture separator reheaters, and check the temperature control valves closed.

MSR temperature control valve indication will be lost. The BOP should (note) request an NAO to verify the valves are closed locally.

ATC 7. Determine Containment Isolation acceptance criteria are met:

a. Check containment pressure is less than 16.4 psia.

b. Check NO containment area radiation monitor alarms OR unexplained rise in activity.

c. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

ATC/BOP 8 Determine Containment Temperature and Pressure Control acceptance criteria are met:

a. Check containment temperature is less than or equal to 120ºF.

b. Check containment pressure is less than 16.4 psia.

N/A 9. IF ALL safety function acceptance criteria are met, AND NO contingency actions were performed, THEN GO TO OP-902-001, "Reactor Trip Recovery" procedure.

SRO 10. IF ANY safety function acceptance criteria are NOT met, OR ANY contingency action was taken, THEN GO TO Appendix 1, "Diagnostic Flowchart.

OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow Chart Examiner Note Appendix 1 is a flow chart used to diagnose to the correct recovery procedure for the event in progress. The steps below will be followed by a YES or NO to indicate proper flow path.

ATC Rx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted or Emergency Boration in progress (YES)

ATC Pressurizer pressure dropping rapidly and Pressurizer level changing (NO)

BOP At least one 7KV non-safety bus and one 4KV safety bus powered from offsite (same train) (NO)

BOP At least one 4KV safety bus and one 125VDC bus energized (same train)

(YES) 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 22 of 35 Event

Description:

Seismic Event / Loss of Offsite Power / Turbine Trip / 2 Stuck CEAs Time Position Applicants Actions or Behavior SRO Go To OP-902-003, Loss of Offsite/Forced Circulation Recovery OP-902-003, Loss of Offsite Power/Forced Circulation Recovery SRO 1. Confirm diagnosis of a LOOP/LOFC by checking Safety Function Status Check Acceptance criteria are satisfied.

CREW 2. Announce a Loss of Offsite Power or a Loss of Forced Circulation is in progress using the plant page.

Examiner Note This event is complete after the crew diagnoses OP-902-003, Loss of Offsite Power/Forced Circulation Or As directed by the Lead Evaluator.

Examiner Note Cue the Simulator Operator when ready for Events 6 & 7 Event Trigger 6 will initiate the RCS leak on cold leg 1A.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 23 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior Examiner Note Step 15 directs the operators to verify Containment Spray Actuation initiated if containment pressure is 17.7 psia or greater. This step is critical task 2 and has been pulled up since containment pressure will be rising rapidly.

ATC/BOP Recognize and report indications of Loss of Coolant Accident.

Alarms:

Pressurizer Pressure Hi/Lo (Cabinet H, E-1)

Pressurizer Level Hi/Lo (Cabinet H, B-1)

Containment Pressure Hi/Lo (Cabinet M, H-4, Cabinet N, H-14)

Containment Water Leakage Hi (Cabinet N, L-20)

Containment Water Leakage Hi-Hi (Cabinet N, K-20)

Rad Monitoring Sys Activity Hi-Hi (Cabinet L, A-9)

Indications:

RCS pressure dropping (CP-7, CP-2)

Pressurizer level lowering (CP-2, CP-8, QSPDS 1)

Backup Charging Pump starts (CP-4)

Letdown flow goes to minimum (CP-4)

Rising radiation levels in containment (RM-11, CP-6)

If not already automatically initiated, the SRO may direct a preemptive manual initiation of Safety Injection Actuation Signal (SIAS) and Containment Isolation Actuation Signal (CIAS). Containment Spray (note) Actuation Signal (CSAS) is not normally preemptively initiated.

The SRO will then direct the ATC and the BOP back to the diagnostic flow chart.

CRITICAL TASK 2 ESTABLISH CONTAINMENT TEMPERATURE AND PRESSURE CONTROL This task is satisfied by manually initiating Containment Spray Actuation Signal prior to exiting step 15 (Verify Containment Spray Actuation) of OP-902-002, Loss of Coolant Accident Recovery Procedure, or Containment pressure exceeding 44 PSIG (59 PSIA).

This task becomes applicable after Containment Pressure rises above 17.7 PSIA.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 24 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior ATC Verify Containment Spray Actuation

15. IF containment pressure is greater than or equal to 17.7 psia, THEN:

a. Verify CSAS is initiated. (CRITICAL)

b. Verify ALL operating Containment Spray pumps are delivering flow greater than 1750 gpm.

The ATC will manually initiate CSAS at CP-7 by pressing both CSAS (note) push buttons.

OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow Chart ATC Rx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted or Emergency Boration in progress (YES)

ATC Pressurizer pressure dropping rapidly and Pressurizer level changing (YES)

BOP Steam Generator Pressure Abnormally Low (NO)

N/A Primary Break ATC Containment Pressure and Temperature Abnormally High (YES)

ATC Activity in the Steam Plant (NO)

N/A LOCA Inside Containment BOP At least one 4KV safety bus energized (YES)

SRO Go To OP-902-002, Loss of Coolant Accident Recovery OP-902-002, Loss of Coolant Accident Recovery SRO *1. Confirm diagnosis of a LOCA:

a. Check Safety Function Status Check Acceptance criteria are satisfied.

b. IF Steam Generator sample path is available, THEN direct Chemistry to sample BOTH Steam Generators for activity.

If asked to perform step 1.a as the STA, simply acknowledge the (note) request.

CREW 2. Announce a Loss of Coolant Accident is in progress using the plant page.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 25 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior SRO *3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &

Classification of Emergency Condition" and implement the Emergency Plan.

(note) If asked to perform step 3 as the SM, simply acknowledge the request.

SRO *4. REFER TO Section 6.0, "Placekeeper" and record the time of the reactor trip.

CREW *5. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

Crew should send an NAO to restore DCT Sump Pumps on both safety (note) buses.

ATC *6. IF PZR pressure is less than 1684 psia, THEN check SIAS has initiated.

ATC 6.1 Verify SIAS is initiated.

ATC/BOP *7. IF SIAS has initiated, THEN:

a. Verify Safety Injection pumps have started.

b. Check Safety Injection flow is within the following:

Attachment 2-E, "HPSI Flow Curve" Attachment 2-F, "LPSI Flow Curve"

c. Verify ALL available Charging pumps are operating.

Examiner Note Appendix 2-E and Appendix 2-F are contained on the next 2 pages. Injection flow will be meeting all requirements.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 26 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 27 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 28 of 35 Event

Description:

Large RCS Cold Leg Break / Containment Spray Fails to Auto actuate Time Position Applicants Actions or Behavior ATC *8. IF PZR pressure is less than 1621 psia, AND SIAS is actuated, THEN:

a. Verify no more than two RCPs are operating.

b. IF Pressurizer pressure is less than the minimum RCP NPSH of Attachment 2A-D, "RCS Pressure and Temperature Limits," THEN stop ALL RCPs.

N/A 9. IF RCPs are operating, THEN:

a. Verify CCW available to RCPs.

b. IF a CSAS is initiated, THEN stop ALL RCPs.

c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.

BOP *10. Check a CCW pump is operating for each energized 4.16 KV Safety bus.

Examiner Note This event is complete after the crew completes Critical Task 2 and steps 1-10 in OP-902-002.

Or As directed by the Lead Evaluator.

Examiner Note Cue the Simulator Operator when ready for Event 8 Event Trigger 7 will initiate Event 8 (loss of LPSI pump B) 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 29 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior Examiner Note Event Trigger 7 will initiate Event 8 (loss of LPSI pump B)

This will cause a loss of low pressure safety injection and require the crew to enter the Functional Recovery Procedure (OP-902-008) to align a Containment Spray pump to re-establish low pressure safety injection.

BOP Recognizes and reports indications of LPSI pump B trip Alarms LPSI PUMP B TRIP/TROUBLE (Cabinet N, E-13)

Indications LPSI pump B control switch Amber Light (CP-8)

Ammeter above control switch - zero amps (CP-8)

LPSI pump B flow - zero (CP-8)

CREW Recognizes that safety functions for OP-902-002, Loss of Coolant Accident, are not being met. SRO directs going directly to OP-902-008, Functional Recovery.

CRITICAL TASK 3 ESTABLISH LOW PRESSURE SAFETY INJECTION This task is satisfied by establishing low pressure safety injection using a Containment Spray pump prior to exiting the Inventory Control (IC-2) safety function in OP-902-008, Functional Recovery Procedure. This task becomes applicable after the running LPSI pump trips. OP-902-008, Functional Recovery Procedure, directs this in Inventory Control Continuing Actions with the required operator actions in OP-902-009, Standard Appendices, Attachment 27.

OP-902-008, Functional Recovery CREW 1. Announce that the Functional Recovery Procedure is in progress using the plant page.

SRO 2. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &

Classification of Emergency Condition" and implement the Emergency Plan.

SRO 3. REFER TO the "Placekeeper" and record the time of the reactor trip.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 30 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior N/A 4. IF pressurizer pressure is less than 1621 psia, AND SIAS is actuated, THEN

a. Verify no more than two RCPs are operating.

b. IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2A-D, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs.

N/A 5. IF RCPs are operating, THEN:

a. IF a CSAS is initiated, THEN stop ALL RCPs.

b. Verify CCW available to RCPs.

c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.

NOTE The Shift Chemist should be notified if a SIAS or CIAS has occurred. The secondary sampling containment isolation valves should not be opened following an SIAS or CIAS until directed by the Shift Chemist.

SRO 6. Direct Chemistry to sample BOTH steam generators for activity and boron.

NOTE If a Temporary Diesel Generator is the source of AC power, the Verify Equipment Ventilation step must still be performed.

Door Stops and Ceiling Access Panel tool located in Shift Manager Office.

Portable emergency lighting is available in Appendix R lockers located at LCP-43, Remote Shutdown Panel and +35 RAB Relay Room and Shift Manager Office.

Verify Equipment Ventilation N/A 7. IF AC power is lost to BOTH 3A and 3B Safety buses, THEN perform the following within 30 minutes from the onset of SBO:

N/A a. Perform the following behind Control panels:

REFER TO Attachment 7-D, "Process Analog Control Cabinet Doors" and open cabinet doors.

Open Door 259, Secondary Access (southwest corner) 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 31 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior N/A b. Open the following Lighting Panel breakers:

LTN-EPNL-322: (behind CP-8) o LTN-EBKR-322-1 o LTN-EBKR-322-2 o LTN-EBKR-322-3 LTN-EPNL-323: (near main Control Room entrance) o LTN-EBKR-323-2 o LTN-EBKR-323-3 o LTN-EBKR-323-4 N/A c. Open doors in front of Control panels:

Door 84, Equipment Access (north wall double doors)

Door 293, Sound Partition (between west wall and CP-53)

Door 292, Sound Partition (between CP-53 and CP-8)

Door 291,Sound Partition (between CP-18 and CP-15)

Door 77, Main Entrance (northeast corner)

N/A d. Open six Ceiling Access panels, (Control Room proper area).

NOTE If a Temporary Diesel Generator is available and ready to load within 30 minutes of SBO onset, then load stripping via the associated Attachment 7-A or 7-B should not be necessary.

Performing Attachment 7-A and 7-B will remove DC control power from the EDGs including loss of EDG Annunciator Panels and CP-1 indicating lights. An EDG will not start with control power removed.

N/A 8. IF AC power is lost to BOTH 3A and 3B Safety buses, THEN direct NAOs to perform ALL of the following within 30 minutes from the onset of SBO:

Attachment 7-A, "Switchgear Room A Removable Loads" Attachment 7-B, "Switchgear Room B Removable Loads" Attachment 7-C, "Switchgear Room AB Removable Loads" CREW 9. IF power has been interrupted to either 3A or 3B safety buses, THEN perform Appendix 20, "Operation of DCT Sump Pumps".

If not already done, the crew should send an NAO to restore DCT Sump (note)

Pumps on both safety buses.

BOP 10. Place Hydrogen Analyzers in service as follows:

Train A 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 32 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior

a. Place Train A H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. (Key 216)

b. Place H2 ANALYZER A POWER to ON.

c. Check H2 ANALYZER A Pumps indicate ON.

Train B

a. Place Train B H2 ANALYZER CNTMT ISOL VALVE keyswitch to OPEN. (Key 217)

b. Place H2 ANALYZER B POWER to ON.

c. Check H2 ANALYZER B Pumps indicate ON.

SRO 11. Identify success paths to be used to satisfy each safety function using BOTH of the following:

Resource Assessment Trees Safety Function Tracking Sheet SRO should determine priorities and paths as follows on the Safety Function Tracking Sheet: (Priorities may vary depending on time parameters checked; however, Priority 1 should be IC-2)

Reactivity Control, RC-1 = 4 Maintenance of Vital Auxiliaries (DC), MVA-DC-1 = 7 (note) Maintenance of Vital Auxiliaries (AC), MVA-AC-2 = 5 RCS Inventory Control, IC-2 = 1 RCS Pressure Control, PC-2 = 2 RCS and Core Heat Removal, HR-2 = 3 Containment Isolation, CI-1 = 8 Containment Temperature and Pressure Control, CTPC-2 = 6 RCS Inventory Control, IC-2 SRO/ATC 1. Verify SIAS is initiated.

BOP 2. Optimize Safety injection:

a. Verify Safety Injection pumps have started.

b. Check Safety Injection flow is within ALL of the following:

Attachment 2-E, "HPSI Flow Curve" Attachment 2-F, "LPSI Flow Curve"

c. Verify ALL available Charging pumps are operating.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 33 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior The crew will determine that step 2.b is not met. The contingency actions for this step do not provide the guidance needed to align a CS (note) pump to replace a LPSI pump. The SRO will need to pull up step 15 (below) and follow contingency step 15.1 to find the required procedural guidance.

SRO 15. Check IC-2, Safety Injection is satisfied by ALL of the following:

a. IF RAS has NOT initiated, THEN at least ONE Charging pump is operating.

b. IF RAS has NOT initiated, AND LPSI pump stop criteria are NOT met, THEN LPSI flow within Attachment 2-F, "LPSI Flow Curve."

c. IF HPSI throttle criteria are NOT met, THEN HPSI flow within Attachment 2-E, "HPSI Flow Curve."

d. RVLMS LEVEL PLENUM indicates greater than or equal to 20%.

SRO 15.1 IF the RCS Inventory Control safety function is still NOT met, THEN GO TO RCS Inventory Control Continuing Actions.

RCS Inventory Control Continuing Actions SRO 3. Restore the RCS Inventory safety function to a success path by performing ANY of the following:

a. Restore the vital auxiliaries necessary to operate components or systems in the success path.

b. Manually operate alternate components to implement a success path.

c. IF BOTH LPSI pumps are NOT available, AND the TSC concurs, THEN REFER TO Appendix 27, "Aligning CS to Replace LPSI" and align a CS Pump. 7-B: CS Pump B to Replace LPSI Pump B SRO 1. Obtain TSC concurrence prior to performing this evolution.

The SRO should communicate step 1 to the Lead Examiner as if to the (note) Shift Manager. If asked, simply reply, "TSC concurs". The SRO should select train B since LPSI pump A is tagged out.

BOP 2. Verify LPSI Pump B Control switch in "OFF."

BOP 3. Open the Breaker knifeswitch for LPSI Pump B.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 34 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior (note) The Crew will direct an NAO to open the breaker knifeswitch.

BOP 4. Verify Containment Spray Pump B Control switch in "OFF."

BOP 5. Place SI 129B, LPSI FLOW CONTROL VALVE to "AUTO." (Key 146)

BOP 6. Place SI-IFIC-0306, LPSI FLOW CONTROLLER HEADERS 1A/1B in "MAN."

BOP 7. Adjust SI-IFIC-0306, LPSI FLOW CONTROLLERS HEADER 1A/1B to 0% output.

The Crew may direct an NAO to locally close SI-129B since loss of Instrument Air will cause SI-129B to fail open. The position of SI-129B (open or closed) will not affect injection flow to the core. It is preferred (note) to have SI-129B closed so that the discharge from the Containment Spray pump will be directed through the Shutdown Cooling (SDC) Heat Exchanger instead of bypassing around it. In a normal lineup, LPSI flow does not go through the SDC Heat Exchanger.

BOP 8. REFER TO Appendix 21 "Overrides for Containment Isolation" and close CS 125B, CNTMT SPRAY HEADER B ISOL.

BOP 9. Open SI 125B/SI 412B, SHDN HX B ISOL valves. (Key 145)

BOP 10. Start Containment Spray Pump B.

BOP 11. Open SI 415B, LPSI SHUTDOWN TEMP CONTROL valve. (Key 147)

BOP 12. Verify LPSI Header B flow exists. 1-A CS-125B Override

2. Override CS 125B, CNTMT Spray HDR B Isolation as follows:

BOP a. Place CNTMT Spray Pump B Control switch to OFF."

NAO b. Obtain key 76 from SM office.

NAO c. Place keyswitch, Containment Spray 125B Override, to "OVERRIDE." (located on the side of Auxiliary Panel 2, +35 Relay Rm) 2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8 Page 35 of 35 Event

Description:

Low Pressure Safety Injection Pump B Trips / Functional Recovery Procedure Time Position Applicants Actions or Behavior BOP d. Place CS 125B, CNTMT SPRAY HEADER B ISOL valve to "OPEN" and THEN to "CLOSE.

Examiner Note This event is complete after the crew re-establishes Low Pressure Safety Injection flow Or As directed by the Lead Evaluator.

2015 NRC Exam Scenario 1 D-2 Rev 0

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 1 of 34 Event

Description:

Dilute to 5-10% power Time Position Applicants Actions or Behavior Examiner Note Event 1 is a normal plant evolution. The crew will be pre-briefed and ready to start raising power once they take the shift. Per the reactivity plan the crew will add 100 gallons of Primary Makeup Water (PMU) on the first batch followed by 50 gallon batches.

OP-010-003, Section 9.4, Plant Startup to 10% Power SRO 9.4.54 Begin raising Reactor power by CEA withdrawal or boron dilution to 5% full power.

The SRO directs the ATC to coordinate with the BOP and raise power (note) to 5-10%. The SRO will direct the ATC to initiate RCS dilution in accordance with OP-002-005 and the approved reactivity plan.

OP-002-005, Section 6.9, VCT Makeup using the Dilute Makeup Mode (C)

NOTE VCT makeup and RWSP makeup utilize the same supply header. VCT makeup cannot be performed while performing the following procedure sections:

Section 6.12 RWSP Blended Makeup Section 6.13 RWSP Boration.

CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY CAUTION THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

ATC 6.9.1 Inform SM/CRS that this Section is being performed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 2 of 34 Event

Description:

Dilute to 5-10% power Time Position Applicants Actions or Behavior NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD)

N/A 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.

(note) Not applicable, reactivity plan gives required volume.

ATC 6.9.3 Set Primary Makeup Water Batch Counter to volume of Primary Makeup water desired.

Procedure does not give specific steps to set the counter. 100 gal of water on the counter is set by pressing:

UP arrow button ENTER button (note) the side arrow button to move the cursor the raise button to enter 10 (counter reading is multiplied by 10)

ENTER RESET ATC 6.9.4 Place Makeup Mode selector switch to DILUTE.

ATC 6.9.5 Open VCT Makeup Valve, CVC-510.

NOTE The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 3 of 34 Event

Description:

Dilute to 5-10% power Time Position Applicants Actions or Behavior CAUTION DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTIVITY CHANGE OCCURS.

ATC will likely use manual Primary Makeup Water flow control. "CVCS (note) Rx Makeup Wtr Flow Hi/Lo" on CP-4 is an expected annunciator. Red pen on flow recorder PMU-IFR-0210-X will indicate GPM.

ATC 6.9.6 If manual control of Primary Makeup Water flow is desired, then perform the following:

6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.

6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.

ATC 6.9.7 If automatic control of Primary Makeup Water flow is desired, then perform the following:

6.9.7.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Auto.

6.9.7.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, setpoint potentiometer to >5 GPM flow rate.

ATC 6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open ATC 6.9.9 Observe Primary Makeup water flow rate for proper indication ATC 6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.

ATC 6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

NOTE Step 6.9.12 may be repeated as necessary to achieve desired total Primary Makeup Water addition for plant conditions.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 4 of 34 Event

Description:

Dilute to 5-10% power Time Position Applicants Actions or Behavior ATC 6.9.12 If additional Primary Makeup Water addition is required and with SM/CRS permission, then perform the following:

6.9.12.1 Reset Primary Makeup Water Batch Counter.

6.9.12.2 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.

6.9.12.3 Observe Primary Makeup Water flow rate for proper indication.

6.9.12.4 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

The reactivity plan describes that additional PMU additions will be (note) required. The SRO may or may not use this option. It is acceptable if the crew chooses to leave this aligned.

ATC 6.9.13 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.

ATC 6.9.14 Verify both Primary Makeup Water Flow controller, PMU-IFIC-0210X, output and setpoint potentiometer set to zero.

ATC 6.9.15 Close VCT Makeup Valve, CVC-510.

ATC 6.9.16 Place Makeup Mode selector switch to MANUAL.

ATC 6.9.17 Verify VCT Inlet/Bypass To Holdup Tanks, CVC-169, aligned to the VCT and control switch in AUTO.

Examiner Note This event is complete after the crew has added 100 gallons of Primary Makeup Or As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 5 of 34 Event

Description:

Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails low Time Position Applicants Actions or Behavior ATC Recognize and report indications of failed channel.

Alarms:

RPS CHANNEL TRIP LOCAL PWR DENSITY HI (Cabinet K, A-11)

RPS CHANNEL TRIP DNBR LO (Cabinet K, A-12)

RPS CHANNEL B TROUBLE (Cabinet K, F-18)

CORE PROTECT CHNL B CALCULATOR TROUBLE (Cabinet K, N-12)

Indications:

Pressurizer pressure instrument RC-IPI-0101B on CP-7 indicates low DNBR and LPD trip and pre-trip lamps lit on CP-7 Channel B CPC Channel B on CP-7 'Sensor Fail' lamp lit Examiner Note Crew may continue with OP-010-003, Plant Startup. The step to establish Main Steam to Gland Seals is included in this section for your reference.

OP-009-007, Plant Protection System ,Section 6.2, Trip Channel Bypass Operation All BOP manipulations for OP-009-007 are located at CP-10 (back (note) panel) except as noted.

SRO 6.2.1 Refer to Attachment 11.11, PPS Bistable Bypass Chart to assist in determination of Trip Channels requiring placement in bypass.

SRO determines the following bistables are affected and need to be bypassed:

(note) 3 - HI LOCAL POWER 4 - LO DNBR 5 - HI PZR PRESS SRO Directs BOP to bypass the HI LOCAL POWER, LO DNBR, and HI PZR PRESS bistables in PPS Channel B within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in accordance with OP-009-007, Plant Protection System.

BOP 6.2.2 To place a bistable in or remove a bistable from bypass, go to Attachment 11.10, Trip Channel Bypass Operation.

BOP 11.10.1 To Bypass a Trip Channel, perform the following:

11.10.1.1 Circle the bistable numbers selected for bypass under Step 11.10.1.4.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 6 of 34 Event

Description:

Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails low Time Position Applicants Actions or Behavior (note) BOP circles bistable numbers 3, 4 and 5 in Step 11.10.1.4 table BOP 11.10.1.2 Check desired Trip Channel is not Bypassed on another PPS Channel.

BOP 11.10.1.3 Open key-locked portion of BCP in desired PPS Channel.

BOP 11.10.1.4 Depress Bypass push buttons for the desired Trip Channels BOP 11.10.1.5 Check all selected bistable Bypass push buttons remain in a Depressed state.

BOP 11.10.1.6 Check all selected bistable Bypass lights Illuminate on BCP for the desired Trip Channels.

CREW 11.10.1.7 Check all selected bistable Bypass lights Illuminate on ROM for the desired Trip Channels.

Crew verifies correct bistables lit on CP-7 PPS Channel B Remote (note)

Operator Module.

SRO Reviews the following Technical Specifications and determines applicable actions:

3.3.1 action 2 (Bypass 3, 4 & 5 within 1 hr) 3.3.3.5 - no actions required 3.3.3.6 - no actions required OP-903-013, Monthly Channel Checks, does not list this instrument for (note)

Tech Spec 3.3.3.5 and 3.3.3.6 applicability.

Examiner Note The step to establish Main Steam to Gland Seals is included below for your reference. It is not necessary to complete this step prior to advancing with the scenario.

OP-010-003, Section 9.4, Plant Startup to 10% Power (cont.)

BOP 9.4.55 Prior to exceeding 5% power, verify Linear Power Channels are on scale.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 7 of 34 Event

Description:

Narrow Range Safety Pressure Instrument, RC-IPT-0101B fails low Time Position Applicants Actions or Behavior NOTE GS PCV Bypass Valve, GS-104, will normally be Closed, when Main Steam is supplying the Gland Seal System.

CAUTION ATC OPERATOR SHOULD BE NOTIFIED PRIOR TO TRANSFERRING GLAND SEAL STEAM (GS)

SUPPLY TO MAIN STEAM, AS THE CHANGE IN STEAM FLOW MAY CAUSE A CHANGE IN RCS TEMPERATURE AND REACTIVITY.

BOP 9.4.56 Establish Main Steam to Gland Seals as follows:

BOP 9.4.56.1 Adjust GS PCV Bypass Valve, GS-104, to maintain 100 to 140 PSIG on the Gland Steam Header Pressure Recorder (GS-IPR-1801).

NAO 9.4.56.2 Slowly Open Main Steam Supply Valve to Gland Seal Isolation, MS-148.

BOP 9.4.56.3 Close Auxiliary Boiler Steam to Gland Steam, ABS-314.

BOP/NAO 9.4.56.4 Verify HP and LP Turbine Seals are maintaining approximately 1.5 to 3 PSIG.

BOP/NAO 9.4.56.5 Verify Main Feedwater Pump Seals are maintaining approximately 3 to 5 PSIG.

NAO 9.4.57 Transfer Auxiliary Steam supply from Auxiliary Boiler Steam to Main Steam in accordance with OP-005-002, Auxiliary Steam.

NAO 9.4.58 Secure Auxiliary Boiler in accordance with OP-005-001, Auxiliary Boiler.

Examiner Note This event is complete after the SRO has addressed Technical Specifications and PPS Channel B trip bistables are bypassed OR As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 3.

Event 3 must be triggered while PMU is actively flowing to the VCT during the second PMU addition.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 8 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior Examiner Note On this 50 gallon water addition, the PMU Batch Counter will fail to secure PMU flow.

Event 3 must be triggered while PMU is actively flowing to the VCT during the second PMU addition.

ATC aligns for second PMU add (50 gallons) in accordance with OP-(note) 002-005, Chemical and Volume Control.

OP-002-005, Section 6.9, VCT Makeup using the Dilute Makeup Mode (C)

NOTE VCT makeup and RWSP makeup utilize the same supply header. VCT makeup cannot be performed while performing the following procedure sections:

Section 6.12 RWSP Blended Makeup Section 6.13 RWSP Boration.

CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY CAUTION THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSS-CHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

ATC 6.9.1 Inform SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 9 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior N/A 6.9.2 At SM/CRS discretion, calculate volume of Primary Makeup water to be added on Attachment 11.7, Calculation of Primary Makeup Water Volume for Direct Dilution or VCT Dilute Makeup Mode.

(note) Not applicable, reactivity plan gives required volume.

ATC 6.9.3 Set Primary Makeup Water Batch Counter to volume of Primary Makeup water desired.

Procedure does not give specific steps to set the counter. 50 gal of water on the counter is set by pressing:

UP arrow button ENTER button (note) the side arrow button to move the cursor the raise button to enter 5 (counter reading is multiplied by 10)

ENTER RESET ATC 6.9.4 Place Makeup Mode selector switch to DILUTE.

ATC 6.9.5 Open VCT Makeup Valve, CVC-510.

NOTE The Dilution Flow Totalizer will not register below 5 GPM. The Dilution Flow Totalizer is most accurate at >10 GPM.

CAUTION DILUTION SHALL IMMEDIATELY BE STOPPED IF PRE-POWER DEPENDENT INSERTION LIMIT (H-9, CABINET H) ALARM IS INITIATED OR ANY UNEXPECTED REACTIVITY CHANGE OCCURS.

ATC 6.9.6.1 Verify Primary Makeup Water Flow controller, PMU-IFIC-0210X, in Manual.

ATC 6.9.6.2 Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to >5 GPM flow rate.

(note) Red pen on flow recorder PMU-IFR-0210-X indicates PMU flow in GPM.

ATC 6.9.8 Verify Primary Makeup Water Control Valve, PMU-144, Intermediate or Open.

ATC 6.9.9 Observe Primary Makeup water flow rate for proper indication.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 10 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior ATC 6.9.10 Operate VCT Inlet/Bypass to Holdup Tanks, CVC-169 Control Switch to BMS/Auto positions as necessary to maintain VCT pressure and level within normal operating bands.

6.9.11 When Primary Makeup Water Batch Counter has counted down to desired value, then verify Primary Makeup Water Control Valve, PMU-144, Closed.

Examiner Note PMU Batch Counter will fail to secure PMU flow.

ATC Recognize and report indications of PMU failure.

Indications:

PMU flow does not change as the PMU Batch Counter reaches 0 gallons PMU Batch Counter counts through 0 and continues counting with negative numbers.

Dilution Flow Totalizer continues counting up ATC Adjust Primary Makeup Water Flow controller, PMU-IFIC-0210X, output to 0% output.

Close CVC-510, VCT Makeup valve.

(note) These actions will reduce flow, but flow will continue at ~ 7 gpm.

CRS Enter and direct the implementation of OP-901-104, Inadvertent Positive Reactivity Addition, section E1, Actions During Startup, Power Operation, and Shutdown OP-901-104 Section E1, Actions During Startup, Power Operations, and Shutdown ATC 1. Verify REACTOR MAKE UP PRI WTR CONTR VA (PMU 144) Closed.

BOP 2. Stop both Primary Makeup Water Pumps A and B.

(note) PMU flow will go to 0 gpm after PMU Pump A is secured.

SRO/ATC 3. Verify only one Charging Pump operating.

ATC 4. Bypass or secure Purification Ion Exchangers as follows:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 11 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior ATC 4.1 Place LETDOWN TO ION EXCHANGER BYPASS valve (CVC 140) to BYPASS.

N/A 4.2 If Shutdown Cooling Purification is in service, then at SM/CRS discretion, secure SDC Purification in accordance with OP-009-005, Shutdown Cooling System.

SRO 5. If dilution still in progress, then Close PMU Hdr to Dilution Tee and Chem Add Tank Isol, PMU 135 (RAB-4 5A&J).

6. Borate as necessary to maintain stable plant conditions.

Examiner Note Crew may wait to see the effect of the extra PMU prior to performing boration. The steps for Direct Boration and CEA insertion are included in this section. It is not necessary to hold at this point for either action OP-002-005, Section 6.7, Direct Boration to RCS CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY.

CAUTION (1) THIS SECTION AFFECTS REACTIVITY. THIS EVOLUTION SHOULD BE CROSSCHECKED AND COMPLETED PRIOR TO LEAVING CP-4.

(2) AT LEAST ONE REACTOR COOLANT PUMP IN EACH LOOP SHOULD BE OPERATING PRIOR TO PERFORMING DIRECT BORATION OPERATIONS TO ENSURE PROPER CHEMICAL MIXING.

ATC 6.7.1 Inform SM/CRS that this Section is being performed.

NOTE When performing a Plant down power where final RCS Boron Concentration needs to be determined, the following Plant Data Book figure(s) will assist the Operator in determining the required RCS Boron PPM change.

1.2.1.1 Power Defect Vs Power Level 1.4.3.1 Inverse Boron Worth Vs. Tmod at BOC (<30 EFPD) 1.4.4.1 Inverse Boron Worth Vs. Tmod at Peak Boron (30 EFPD up to 170 EFPD) 1.4.5.1 Inverse Boron Worth Vs. Tmod at MOC (170 EFPD up to 340 EFPD) 1.4.6.1 Inverse Boron Worth Vs. Tmod at EOC ( 340 EFPD)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 12 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior ATC 6.7.2 At SM/CRS discretion, calculate volume of Boric Acid to be added on Attachment 11.6, Calculation of Boric Acid Volume for Direct Boration or VCT Borate Makeup Mode.

ATC 6.7.3 Set Boric Acid Makeup Batch Counter to volume of Boric Acid desired.

Procedure does not give specific steps to set the counter. Desired amount of acid on the counter is set by pressing:

UP arrow button ENTER button (note) the side arrow button to move the cursor the raise button to desired amount ENTER RESET ATC 6.7.4 Verify Boric Acid Makeup Pumps selector switch aligned to desired Boric Acid Makeup Pump A(B).

ATC 6.7.5 Place Direct Boration Valve, BAM-143, control switch to AUTO.

ATC 6.7.6 Place Makeup Mode selector switch to BORATE.

ATC 6.7.7 Verify selected Boric Acid Makeup Pump A(B) Starts.

ATC 6.7.8 Verify Direct Boration Valve, BAM-143, Opens.

NOTE The Boric Acid Flow Totalizer will not register below 3 GPM. The Boric Acid Flow Totalizer is most accurate in the range of 10 - 25 GPM.

ATC will likely use manual boric acid flow control. "CVCS Boric Acid (note) Makeup Flow Hi/Lo" on CP-4 is an expected annunciator. Red pen on the Boration flow recorder, BAM-IFR-0210-Y indicates flow in GPM.

ATC 6.7.9 If manual control of Boric Acid flow is desired, then perform the following:

6.7.9.1 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

6.7.9.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, output to >3 GPM flow rate.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 13 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior ATC 6.7.10 If automatic control of Boric Acid flow is desired, then perform the following:

6.7.10.1 Place Boric Acid Flow controller, BAM-IFIC-0210Y, in Auto.

6.7.10.2 Adjust Boric Acid Flow controller, BAM-IFIC-0210Y, setpoint potentiometer to >3 GPM flow rate.

ATC 6.7.11 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

ATC 6.7.12 Observe Boric Acid flow rate for proper indication.

ATC 6.7.13 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

NOTE Step 6.7.14 may be repeated as necessary to achieve desired total boron addition for plant conditions.

ATC 6.7.14 If additional boric acid addition is required and with SM/CRS permission, then perform the following:

6.7.14.1 Reset Boric Acid Makeup Batch Counter.

6.7.14.2 Verify Boric Acid Makeup Control Valve, BAM-141, Intermediate or Open.

6.7.14.3 Observe Boric Acid flow rate for proper indication.

6.7.14.4 When Boric Acid Makeup Batch Counter has counted down to desired value, then verify Boric Acid Makeup Control Valve, BAM-141, Closed.

ATC 6.7.15 Verify Boric Acid Flow controller, BAM-IFIC-0210Y, in Manual.

ATC 6.7.16 Verify both Boric Acid Flow controller, BAM-IFIC-0210Y, output and setpoint potentiometer set to zero.

ATC 6.7.17 Place Makeup Mode selector switch to MANUAL.

ATC 6.7.18 Verify Selected Boric Acid Makeup Pump A(B) Stops.

ATC 6.7.19 Verify Direct Boration Valve, BAM-143, Closed.

ATC 6.7.20 Place Direct Boration Valve, BAM-143, control switch to CLOSE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 14 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior OP-004-004, Section 6.7, Operation of CEAs in Manual Group (MG) Mode CAUTION (1) CRITICALITY SHALL BE ANTICIPATED ANY TIME CEAS ARE WITHDRAWN AND THE REACTOR IS NOT CRITICAL.

(2) OBSERVE APPLICABLE GROUP INSERTION LIMITS IN ACCORDANCE WITH TECHNICAL SPECIFICATION 3.1.3.6 (REG GROUP), AND TECHNICAL SPECIFICATION 3.1.3.5 (SHUTDOWN BANKS).

(3) IMPROPER OPERATION OF CEAS IN MANUAL GROUP MODE MAY CAUSE A REACTOR TRIP BASED ON AN OUT-OF-SEQUENCE CONDITION.

(4) CEA INITIALIZATION PROGRAM MUST BE RUNNING IN THE PLANT MONITORING COMPUTER TO HAVE GROUP STOPS AND SEQUENTIAL PERMISSIVES AVAILABLE.

CAUTION THE FOLLOWING SECTION HAS THE POTENTIAL TO AFFECT CORE REACTIVITY. [INPO 06-006]

ATC 6.7.1 Verify Plant Monitoring Computer operable in accordance with OP-004-012, Plant Monitoring Computer.

ATC 6.7.2 Position Group Select switch to desired group.

ATC 6.7.3 Place Mode Select switch to Manual Group (MG) and verify the following:

White lights Illuminated on Group Selection Matrix for selected group MG light Illuminates ATC 6.7.4 Operate CEA Manual Shim switch to WITHDRAW or INSERT group to desired height while monitoring the following:

CEA Position Indicator selected CEA group is moving in desired direction If Reactor is critical, then monitor the following:

Reactor Power Reactor Coolant System (RCS) temperature Axial Shape Index (ASI)

NOTE The Operator should remain in the area in front of the CEA Drive Mechanism Control Panel when the Mode Select switch is not in OFF.

ATC 6.7.5 When desired set of moves have been completed, then place Mode Select switch to OFF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 3 Page 15 of 34 Event

Description:

PMU Failure / Inadvertent Dilution Time Position Applicants Actions or Behavior Examiner Note This event is complete after the crew has entered OP-901-104 and secured PMU Pump A Or As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 4.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 16 of 34 Event

Description:

Component Cooling Water Pump A trips Time Position Applicants Actions or Behavior BOP Recognize and report indications of tripped CCW Pump.

Alarms:

CCW PUMP A TRIP/TROUBLE (Cabinet M, B-2 )

RCP 1A CCW FLOW LO (Cabinet H, H-3)

RCP 1B CCW FLOW LO (Cabinet H, H-5)

RCP 2A CCW FLOW LO (Cabinet H, H-7)

RCP 2B CCW FLOW LO (Cabinet H, H-10)

Indications Amber trip/trouble light on CCW Pump A control switch CCW System pressure abnormally low and dropping CCW System and component flows abnormally low Based on how long the crew takes to align CCW Pump AB, red RCP (note) Low Flow alarms may come in on CP-2. This should be called out by the ATC.

SRO Enter and direct the implementation of OP-901-510, Component Cooling Water System Malfunction.

OP-901-510 Section E0, General N/A 1. IF ANY of the following occur, THEN GO TO Subsection E1, System Leakage:

CCW Surge Tank level dropping CCW Dry Cooling Towers isolated due to low CCW Surge Tank level CMU-226, WATER STORAGE MAKEUP CCW SURGE TANK, cycling frequently CCW header isolates due to low CCW Surge Tank level Local observation of CCW leak reported to Control Room SRO 2. IF ANY of the following occur, THEN GO TO Subsection E2, Loss of CCW Pump(s):

CCW system OR component flows low Amber trip/trouble light on CCW PUMP A(B)(AB) Control Switch

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 17 of 34 Event

Description:

Component Cooling Water Pump A trips Time Position Applicants Actions or Behavior OP-901-510 Section E2, Loss of CCW Pump(s)

N/A 1. IF CCW is lost to in-service Shutdown Cooling train, THEN implement OP-901-131, SHUTDOWN COOLING MALFUNCTION, AND perform concurrently with this procedure.

N/A 2. IF Component Cooling Water Pump AB has tripped, THEN Start standby CCW Pump.

2.1 PLACE CCW ASSIGNMENT SWITCH TO NORM POSITION.

BOP 3. IF Component Cooling Water Pump A has tripped, THEN align CCW Pump AB for Operation as follows:

BOP 3.1 Position CCW ASSIGNMENT switch to position A.

BOP 3.2 Verify Open the following valves:

CC-126A/CC-114A CCW SUCT & DISCH HEADER TIE VALVES AB TO A CC-127A/CC-115A CCW SUCT & DISCH HEADER TIE VALVES AB TO A BOP 3.3 Start CC-0001AB, Component Cooling Water Pump AB.

SRO 3.4 Evaluate AB Electrical Bus alignment for Technical Specification Operability requirements.

With the AB Electrical Bus aligned to Train B, credit cannot be taken for CCW Pump AB supplying Train A loads.

The SRO should enter Tech Spec 3.7.3 (restore w/in 72 hrs or S/D),

TRM 3.7.3 (restore in 7 days or hourly fire watch) and Cascading Tech Specs per OP-100-014 (1 hr action to verify electrical power; 2 hr action to verify certain safety related components operable).

(note)

The CRS should vocalize the 1 hr requirement and assign the OP-903-066 surveillance to either the BOP or ATC operator (BOP is preferred) to satisfy requirement to verify off site electrical power.

The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months action per Cascading Tech Specs is to verify components that rely on Train B safety power and EFW pump AB operable per 3.8.1.1.d.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 18 of 34 Event

Description:

Component Cooling Water Pump A trips Time Position Applicants Actions or Behavior Examiner Note This event is complete after CCW pump A is started and the SRO has addressed Technical Specifications OR As directed by the Lead Evaluator Examiner Note Cue the Simulator Operator when ready for Event 5.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 19 of 34 Event

Description:

Pressurizer Pressure Control Channel RC-IPR-0100X fails Hi Time Position Applicants Actions or Behavior Examiner Note Without operator action the reactor will trip on low PZR pressure of 1860 PSIA in ~1 minute and 10 seconds.

ATC Recognize and report indications of failed pressure instrument.

Alarms PRESSURIZER PRESSURE HI/LO (Cabinet H, E-1)

PRESSURIZER PRESS SIGNAL DEVIATION (Cabinet H, F-1)

Indications Recorder RC-IPR-0100 red pen fails Hi.

Controller RC-IPIC-0100 process fails Hi.

Controller RC-IPIC-0100 output goes to 100%.

All Pressurizer Proportional and Backup Heaters secure.

Both Pressurizer Main Spray Valves go full open.

Pressurizer Pressure drops rapidly due to the full Main Spray.

ATC Place Pressurizer Spray Controller RC-IHIC-0100 to MAN and close the Main Spray Valves.

This action may be taken before the crew enters OP-901-120.

Operations procedures include allowances for taking manual control of (note) components when their automatic function is not controlling. The CRS should direct this action prior to entering off normal procedure OP-901-120.

CRS Enter and direct the implementation of OP-901-120, Pressurizer Pressure Malfunction, and use sub-section E1, Pressurizer Pressure Control Channel Instrument Failure.

OP-901-120 Section E0, General Caution Steam Generator pressures dropping concurrently with dropping Pressurizer level may be indicative of an excess steam demand.

N/A 1. IF Pressurizer Pressure and Level are dropping concurrently, OR RCS leakage is otherwise indicated, THEN GO TO OP-901-111, Reactor Coolant System Leak.

ATC 2. If Pressurizer Pressure is dropping and any of the following have occurred, then place Pressurizer Spray Controller (RC-IHIC-0100) to MAN and adjust output to 0%:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 20 of 34 Event

Description:

Pressurizer Pressure Control Channel RC-IPR-0100X fails Hi Time Position Applicants Actions or Behavior Pressurizer Pressure Channel X/Y recorder (RC-IPR-0100) indicates in-service Pressurizer Pressure Control Channel instrument has failed high Pressurizer Pressure controller (RC-IPIC-0100) output has failed high Any Pressurizer Spray Valve (RC-301A or RC-301B) has failed open Pressurizer Spray Controller (RC-IHIC-0100) output has failed high.

N/A 2.1 If any Pressurizer spray valve remains failed open, then Place Pressurizer Spray Valves selector switch to select operable Spray Valve.

CRS 3. IF PRESSURIZER PRESSURE CHANNEL X/Y recorder (RC-IPR-0100) indicates a Pressurizer Pressure Control Channel instrument has failed, THEN GO TO Subsection E1, Pressurizer Pressure Control Channel Instrument Failure.

OP-901-510 Subsection E1, Pressurizer Pressure Control Channel Instrument Failure.

ATC 1. Verify control channel instrument failure by checking PRESSURIZER PRESSURE CHANNEL X/Y recorder (RC-IPR-0100).

ATC 2. Transfer Pressurizer pressure control to operable channel using Pressurizer Pressure Channel Selector control switch.

(note) Position Y should be selected.

ATC 3. IF Pressurizer Pressure control channel is failed high, THEN perform the following:

a. Transfer Pressurizer Lo Level Heater Cutout selector switch to the Operable Pressurizer Pressure control channel.

b. Reset Proportional Heater Banks #1 & #2.

c. Place Pressurizer Spray Controller (RC-IHIC-0100) to AUTO.

ATC 4. Verify proper operation of Pressurizer Pressure controller (RC-IPIC-0100)

AND Pressurizer Pressure controlling OR being restored to 2250 PSIA.

CRS Refer to the following Technical Specifications and Technical Requirements:

TS 3.2.8 (Restore pressure w/in 2 hrs; applicable in mode 1 only)

TS 3.4.3.1 (entry not required)

TRM 3.4.3.1 (entry not required)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 21 of 34 Event

Description:

Pressurizer Pressure Control Channel RC-IPR-0100X fails Hi Time Position Applicants Actions or Behavior Pressure should drop below 2125 PSIA. Pressure will recover to

>2125 PSIA after Channel Y is selected and Pressurizer Heaters are energized.

(note)

TS 3.2.8 entry required if RCS pressure drops below 2125 PSIA, but the Tech Spec is only applicable in Mode 1. Power may still be <5%

at this point.

Examiner Note This event is complete when Pressurizer Pressure Control has been transferred to Channel Y.

Or As directed by the Lead Evaluator.

Examiner Note Cue the Simulator Operator when ready for Event 6&7.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 22 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior ATC Recognize and report indications of failed pressure instrument.

Alarms EXCORE /CPC CHNL D POWER DEVIATION (Cabinet K, K-14)

EXCORE /CPC CHNL B POWER DEVIATION (Cabinet K, K-12)

EXCORE /CPC CHNL C POWER DEVIATION (Cabinet K, K-13)

EXCORE /CPC CHNL A POWER DEVIATION (Cabinet K, K-11)

LOCAL POWER DENSITY HI PRETRIP B/D (Cabinet K, C-11)

Indications Lowering Steam Generator Pressure CP-1, CP-8 Lowering Steam Generator Level CP-1, CP-8 Lowering RCS temperatures Tavg, Th, Tc CP-2, CP-7 Reactor Power Rising CP-2, CP-7 SRO Directs a manual reactor trip.

The SRO may also direct a manual actuation of SIAS and CIAS. If not the SRO should direct Emergency Boration per OP-901-103, (note) Emergency Boration due to the uncontrolled cooldown. The following steps are applicable after the reactor is tripped and the crew is performing Standard Post Trip Actions.

Emergency Boration steps:

ATC 1. If Charging is available, then perform the following:

ATC 1.1 Place Makeup Mode selector switch to MANUAL.

ATC 1.2 Align borated water source by performing one of the following (a or b):

a. Initiate Emergency Boration using Boric Acid Pump as follows:

Open Emergency Boration Valve, BAM-133.

Start one Boric Acid Pump.

Close recirc valve for Boric Acid Pump started:

BAM-126A Boric Acid Makeup Pump Recirc Valve A or BAM-126B Boric Acid Makeup Pump Recirc Valve B OR

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 23 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior

b. Initiate Emergency Boration using Gravity Feed as follows:

Open the following Boric Acid Makeup Gravity Feed valves:

BAM-113A Boric Acid Makeup Gravity Feed Valve A BAM-113B Boric Acid Makeup Gravity Feed Valve B ATC 1.3 Close VCT Disch Valve, CVC-183.

ATC 1.4 Verify at least one Charging Pump operating and Charging Header flow greater than or equal to 40 GPM.

OP-902-000, Standard Post Trip Actions (STPAs)

ATC 1. Determine Reactivity Control acceptance criteria are met:

a. Check reactor power is dropping.

b. Check startup rate is negative.

c. Check less than TWO CEAs are NOT fully inserted.

BOP 2. Determine Maintenance of Vital Auxiliaries acceptance criteria are met:

a. Check the Main Turbine is tripped:

Governor valves closed Throttle valves closed BOP b. Check the Main Generator is tripped:

GENERATOR BREAKER A tripped GENERATOR BREAKER B tripped EXCITER FIELD BREAKER tripped

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 24 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP c. Check station loads are energized from offsite electrical power as follows:

Train A A1, 6.9 KV non safety bus A2, 4.16 KV non safety bus A3, 4.16 KV safety bus A-DC electrical bus A or C vital AC Instrument Channel Train B B1, 6.9 KV non safety bus B2, 4.16 KV non safety bus B3, 4.16 KV safety bus B-DC electrical bus B or D vital AC Instrument Channel ATC 3. Determine RCS Inventory Control acceptance criteria are met:

a. Check that BOTH the following conditions exist:

Pressurizer level is 7% to 60%

Pressurizer level is trending to 33% to 60%

b. Check RCS subcooling is greater than or equal to 28ºF.

This safety function may or may not be met, depending on the speed (note) the crew is working Standard Post Trip Actions. Either way, there are no contingencies necessary for this step.

ATC 4. Determine RCS Pressure Control acceptance criteria are met by checking that BOTH of the following conditions exist:

Pressurizer pressure is 1750 psia to 2300 psia Pressurizer pressure is trending to 2125 psia to 2275 psia Examiner Note Pressurizer pressure will eventually lower below the 2 thresholds (1684; 1621 PSIA) after the Pressurizer empties.

SRO/ATC 4.2 IF pressurizer pressure is less than 1684 psia, THEN verify the following have initiated.

SIAS

CIAS ATC If directed by SRO, initiate Safety Injection Actuation (SIAS), Main Steam Isolation (MSIS) and Containment Isolation Actuation (CIAS) at CP-7.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 25 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior ATC 4.3 IF pressurizer pressure is less than 1621 psia, THEN verify no more than two RCPs are operating ATC 4.4 IF pressurizer pressure is less than the minimum RCP NPSH of Appendix 2-A, "RCS Pressure and Temperature Limits", THEN stop ALL RCPs.

Examiner Note Appendix 2-A is contained on the next page. Conditions should allow for 2 RCPs to remain running.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 26 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior ATC 5. Determine Core Heat Removal acceptance criteria are met:

a. Check at least one RCP is operating.

b. Check operating loop T is less than 13ºF.

c. Check RCS subcooling is greater than or equal to 28ºF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 27 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP 6. Determine RCS Heat Removal acceptance criteria are met:

a. Check that at least one steam generator has BOTH of the following:

Steam generator level is 10% to 76% NR Main Feedwater is available to restore level within 55%-70%

NR. [60-80% NR].

BOP a2. Verify Emergency Feedwater is available to restore level in at least one steam generator within 55%-70% NR [60-80% NR].

Main Feedwater will not be available. BOP should perform contingency (note) action a2.

ATC b. Check RCS TC is 530 ºF to 550 ºF SRO b2. IF RCS TC is less than 530 ºF, THEN perform the following:

IF RCS TC is being controlled by an ESD, THEN REFER TO Appendix 13, "Stabilize RCS Temperature" and stabilize RCS temperature using the least affected steam generator.

SRO After Excess Steam Demand is identified, direct ATC and BOP to monitor for the trigger points for the need to stabilize Reactor Coolant System temperature.

Critical parameters are Pressurizer pressure rising and Reactor Coolant System Representative CET temperature rising.

Steps for stabilizing Reactor Coolant System temperature following an excess steam demand are contained in 2 procedures.

Appendix 13 is used if the critical parameters are both rising before the SRO has entered OP-902-004, Excess Steam Demand Recovery.

Step 16 of OP-902-004 is used if both parameters start rising after the crew has entered OP-902-004.

CRITICAL TASK ESTABLISH REACTOR COOLANT SYSTEM TEMPERATURE CONTROL This task is satisfied by taking action to stabilize Reactor Coolant System temperature within the limits of the Reactor Coolant System Pressure/Temperature Limits curve using Atmospheric Dump Valve 2 and establishing EFW flow to Steam Generator 2 prior to lifting a Pressurizer safety (2500 psia) or Steam Generator safety (1070 psig). This task becomes applicable once CET temperature and PZR pressure begin to rise following the Main Steam Line Break.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 28 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior OP-902-009, Appendix 13, Stabilize RCS Temperature (includes HPSI Throttle Criteria)

NOTE Actions to stabilize RCS temperature following an excess steam demand event should be initiated when BOTH of the following parameters are met:

CET temperatures rise Pressurizer pressure rise BOP 1. Place the ADV for the least affected Steam Generator to manual and fully open the ADV.

BOP 2. Manually initiate EFAS for the least affected Steam Generator.

BOP 3. Place the EFW Flow Control Valve to manual and commence feeding the least affected Steam Generator.

BOP 4. IF RCS pressure is greater than or equal to 1500 psia, THEN stabilize RCS pressure at a value not to exceed 1600 psid between the RCS and the lowest SG pressure.

BOP 5. IF RCS pressure is less than 1500 psia, THEN stabilize RCS pressure at greater than HPSI shutoff head (1500-1600 psia).

CRITICAL TASK ESTABLISH REACTOR COOLANT SYSTEM PRESSURE CONTROL This task is satisfied by taking actions to stabilize RCS pressure within the limits of the Reactor Coolant System P/T curve and less than or equal to 1600 psid of the faulted steam generator by throttling HPSI flow. Action to address this task should commence prior to RCS pressure exceeding 2500 PSIA (e.g. solid plant conditions). This task becomes applicable once CET temperature and PZR pressure begin to rise following the Main Steam Line Break. Either OP-902-000, Standard Post Trip Actions or OP-902-004, Excess Steam Demand Recovery direct actions to satisfy this task.

Due to low power history/decay heat, RCS pressure may not rise above 1500 PSIA. In this case, the crew will need to take action to throttle (note)

HPSI to prevent the RCS from going solid using step 6 of App. 13 or step 18 of OP-902-004, Excess Steam Demand Recovery.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 29 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP/ATC *6. IF HPSI pumps are operating, AND ALL of the following conditions are satisfied:

RCS subcooling is greater than or equal to 28ºF Pressurizer level is greater than 7% [23%] and controlled At least ONE Steam Generator level is being maintained or restored to within ANY of the following:

o 55 to 70% NR [60-80% NR] using MFW o 55 to 70% NR [60-80% NR] using EFW in auto or manual RVLMS indicates level higher than Hot Leg by at least ONE of the following:

o QSPDS level 5 NOT voided o VESSEL LEVEL PLENUM greater than or equal to 80%

THEN perform ANY of the following:

Throttle HPSI flow.

Stop ONE HPSI pump at a time.

OP-902-000, Standard Post Trip Actions (Cont.)

BOP c. Check steam generator pressure is 885 psia to 1040 psia.

BOP c1. IF steam generator pressure is less than 885 psia, THEN perform ALL of the following:

1) Verify steam bypass valves are closed.

2) Verify ADVs are closed.

c2. IF steam generator pressure is less than or equal to 666 psia, THEN verify MSIS is initiated.

When MSIS has initiated the BOP should verify that both MSIVs and (note) both MFIVs, FW-184 A(B) close. FW-184A does not close automatically requiring BOP action to close FW-184A.

BOP d. Check Feedwater Control in Reactor Trip Override:

MAIN FW REG valves are closed STARTUP FW REG valves are 13% to 21% open Operating main Feedwater pumps are 3800 rpm to 4000 rpm With a MSIS, MAIN FW REG valves and STARTUP FW REG valves will (note) be closed. Both MFW Pumps will be coasting down.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 30 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP e. Reset moisture separator reheaters, and check the temperature control valves closed.

ATC 7. Determine Containment Isolation acceptance criteria are met:

a. Check containment pressure is less than 16.4 psia.

b. Check NO containment area radiation monitor alarms OR unexplained rise in activity.

c. Check NO steam plant activity monitor alarms OR unexplained rise in activity.

ATC/BOP 8 Determine Containment Temperature and Pressure Control acceptance criteria are met:

a. Check containment temperature is less than or equal to 120ºF.

b. Check containment pressure is less than 16.4 psia.

N/A 9. IF ALL safety function acceptance criteria are met, AND NO contingency actions were performed, THEN GO TO OP-902-001, "Reactor Trip Recovery" procedure.

SRO 10. IF ANY safety function acceptance criteria are NOT met, OR ANY contingency action was taken, THEN GO TO Appendix 1, "Diagnostic Flowchart.

OP-902-009, Standard Appendices, Appendix 1 Diagnostic Flow Chart Examiner Note Appendix 1 is a flow chart used to diagnose to the correct recovery procedure for the event in progress. The steps below will be followed by a YES or NO to indicate proper flow path.

ATC Rx Pwr dropping, SUR negative, and < two CEAs NOT fully inserted or Emergency Boration in progress (YES)

ATC Pressurizer pressure dropping rapidly and Pressurizer level changing (YES)

BOP Steam Generator Pressure Abnormally Low (YES)

ATC Activity in the Steam Plant (NO)

N/A Secondary Break

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 31 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior ATC Containment Pressure and Temperature Abnormally High (NO)

N/A Secondary Break Outside Containment ATC Activity in Containment (NO)

BOP At least one 4KV safety bus energized (YES)

SRO Go To OP-902-004, Excess Steam Demand Recovery Examiner Note The SRO may pull up step 16 to stabilize RCS temperature depending on plant conditions. Step 14 contains actions to isolate Steam Generator #1; step 18 contains HPSI throttle criteria.

OP-902-004, Excess Steam Demand Recovery NOTE The Shift Chemist should be notified if a SIAS or CIAS has occurred. The secondary sampling containment isolation valves should not be opened following a SIAS or CIAS until directed by the Shift Chemist.

SRO/STA

1. Confirm diagnosis of an ESD:

a. Check Safety Function Status Check Acceptance criteria are satisfied.

b. IF Steam Generator sample path is available, THEN direct Chemistry to sample BOTH Steam Generators for activity.

Crew

2. Announce an Excess Steam Demand is in progress using the plant page.

SRO

3. Advise the Shift Manager to REFER TO EP-001-001, "Recognition &

Classification of Emergency Condition" and implement the Emergency Plan.

SRO

4. REFER TO Section 6.0, "Placekeeper" and record the time of the reactor trip.

ATC/BOP

6. IF PZR pressure is less than 1684 psia, THEN verify SIAS has initiated.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 32 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior ATC/BOP

7. IF SIAS has initiated, THEN:

a. Verify Safety Injection pumps have started.

b. Check Safety Injection flow is within BOTH of the following:

o Attachment 2-E, "HPSI Flow Curve" o Attachment 2-F, "LPSI Flow Curve"

c. Verify ALL available Charging pumps are operating.

BOP 8. Verify MSIS Actuation.

ATC

9. IF PZR pressure is less than 1621 psia, AND SIAS is actuated, THEN:

a. Verify no more than two RCPs are operating.

b. IF Pressurizer pressure is less than the minimum RCP NPSH of Attachments 2A-D, "RCS Pressure and Temperature Limits," THEN stop ALL RCPs.

ATC/BOP

10. IF RCPs are operating, THEN:

a. Verify CCW available to RCPs.

b. IF a CSAS is initiated, THEN stop ALL RCPs.

c. IF RCS TC is less than 382ºF [384ºF], THEN verify no more than two RCPs are operating.

BOP

12. Check a CCW pump is operating for each energized 4.16 KV Safety bus.

ATC/BOP

13. Determine the most affected Steam Generator by considering ALL of the following:

High steam flow from Steam Generator Dropping Steam Generator pressure Dropping Steam Generator level Dropping RCS Cold Leg temperature CRITICAL TASK ISOLATE STEAM GENERATOR #1 This task is satisfied by taking actions to isolate Steam Generator #1 in accordance with OP-902-004, Excess Steam Demand Recovery step 14. This task should be completed prior to the crew indicating that step 14 (Isolate Most Affected SG) of OP-902-004 is completed. This task becomes applicable once indications of an Excess Steam Demand accident are present in the simulator. OP-902-004, Excess Steam Demand Recovery directs actions to satisfy this task.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 33 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP

14. IF MSIS has NOT isolated the leak, THEN isolate the most affected Steam Generator:

N/A Steam Generator 1 BOP a. Verify MS 124A, MSIV 1 is closed.

BOP b. Verify FW 184A, MFIV 1 is closed.

BOP c. Verify MS 116A, ADV 1 is closed and the controller in manual.

BOP d. Verify EFW Isolation valves are closed:

o EFW 228A, SG 1 PRIMARY o EFW 229A, SG 1 BACKUP BOP e. Place EFW FLOW CONTROL valves in MAN and close:

o EFW 224A, SG 1 PRIMARY o EFW 223A, SG 1 BACKUP BOP f. Close MS 401A, PUMP AB TURB STM SUPPLY SG 1.

BOP g. Close Main Steam Line Drains:

o MS 120A, NORMAL o MS 119A, BYPASS BOP h. Verify SG Blowdown Isolation valves are closed:

o BD 103A, STM GEN 1 (OUT) o BD 102A, STM GEN 1 (IN)

NAO i. Verify Main Steam Safety valves are closed.

(note) The crew should direct an NAO to locally verify the MS safety valves closed.

ATC/BOP

15. Verify the most affected SG is isolated by observing ALL of the following:

Steam Generator pressures Steam Generator levels RCS Cold Leg temperatures

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6&7 Page 34 of 34 Event

Description:

Main Steam line break outside Containment (SG 1); FW-184A fails to AUTO close on MSIS Time Position Applicants Actions or Behavior BOP

16. Verify RCS temperature is stabilized by performing the following:

BOP a. Place the ADV for the least affected Steam Generator to manual and fully open the ADV.

BOP b. Manually initiate EFAS for the least affected Steam Generator.

BOP c. Place the EFW Flow Control valve to manual and commence feeding the least affected Steam Generator.

BOP d. IF RCS pressure is greater than or equal to 1500 psia, THEN stabilize RCS pressure at a value not to exceed 1600 psid between the RCS and the lowest SG pressure.

BOP d.1 IF RCS pressure is less than 1500 psia, THEN stabilize RCS pressure at greater than HPSI shutoff head (1500 - 1600 psia).

BOP

18. IF HPSI pumps are operating, AND ALL of the following conditions are satisfied:

RCS subcooling is greater than or equal to 28ºF PZR level is greater than 7% [23%] and controlled Verify ALL Steam Generators capable of steaming are being maintained or restored to within 55 to 70% NR [60-80% NR]

using MFW or EFW in auto or manual.

RVLMS indicates level higher than Hot Leg by at least ONE of the following:

o QSPDS REACTOR VESSEL LEVEL 5 NOT voided o VESSEL LEVEL PLENUM greater than or equal to 80%

THEN perform ANY of the following:

Throttle HPSI flow.

Stop ONE HPSI pump at a time.

Examiner Note This scenario is complete after Reactor Coolant System temperature and pressure have been stabilized and steps to isolate Steam Generator 1 have been taken.

OR As directed by the Lead Evaluator.

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Waterford 3 Date of Exam: 9/14/2015 Operating Test No. 1 A E Scenarios P V 1 2 (Spare) 3 N/A T M P E O I L N CREW CREW CREW CREW T N I T POSITION POSITION POSITION POSITION I

C S A B S A B S A B S A B A M

A T R T O R T O R T O R T O L U N Y O C P O C P O C P O C P M(*)

T P E R I U RX 0 1 1 0 NOR 1 1 2 1 1 1 SROU I/C 2,3,4, 2,3,4, 10 4 4 2 7,8 5,7 MAJ 5,6 6 3 2 2 1 TS 2,4 2,4 4 0 2 2 RX 1 1 1 1 0 NOR 0 1 1 1 I/C 4,7 2,3,4, 6 4 4 2 R1,R2,R3 7 MAJ 5,6 6 3 2 2 1 TS 0 0 2 2 RX 1 1 1 1 0 NOR 1 1 1 1 1 R4,R5,R6 I/C 2,3,8 3,5 5 4 4 2 MAJ 5,6 6 3 2 2 1 TS 0 0 2 2 RX 1 1 0 NOR 1 1 1 I/C 4 4 2 MAJ 2 2 1 TS 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls" (ATC) and balance-of-plant" (BOP) positions. Instant SROs (SRO-I) must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an SRO-I additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

4. For licensees that use the ATC operator primarily for monitoring plant parameters, the chief examiner may place SRO-I applicants in either the ATC or BOP position to best evaluate the SRO-I in manipulating plant controls.

2015 NRC Revision 1

ES-301 Competencies Checklist Form ES-301-6 Facility: Waterford 3 Date of Exam: 9/14/2015 Operating Test No.: 1 APPLICANTS R1,R2,R3 R4,R5,R6 U1,U2,U3 (ATC-BOP) (BOP-ATC)

Competencies SCENARIO SCENARIO SCENARIO 1 2 3 4 1 2 3 4 1 2 3 4 Interpret/Diagnose Events 2,4, 4,6, 3,5, 2,3, 2,3, 2,3, and Conditions 5,6, 7 6,8 5,6 4,5, 4,5, 7 6,7, 6 8

Comply With and 1,4, 2,3, 1,2, 1,3, 1,2, 1,2, Use Procedures (1) 5,6, 4,6, 3,5, 5,6 3,4, 3,4, 7 7 6,8 5,6, 5,6 8

Operate Control 1,4, 2,3, 1,2, 1,3, Boards (2) 5,7 4,6, 3,5, 5,6 N/A N/A 7 8 Communicate and Interact ALL ALL ALL ALL ALL ALL Demonstrate Supervisory 1,2, 1,2, Ability (3) 3,4, 3,4, N/A N/A N/A N/A 5,6, 5,6 8

Comply With and 2,4 2,4 Use Tech. Specs. (3) N/A N/A N/A N/A Notes:

(1) Includes Technical Specification compliance for an RO.

(2) Optional for an SRO-U.

(3) Only applicable to SROs.

Instructions:

Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant. (This includes all rating factors for each competency.) (Competency Rating factors as described on forms ES-303-1 and ES-303-3.)

Revision 1

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