ML20097A446

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2020-02-FINAL Operating Test
ML20097A446
Person / Time
Site: Diablo Canyon  Pacific Gas & Electric icon.png
Issue date: 03/06/2020
From: Greg Werner
Operations Branch IV
To:
Pacific Gas & Electric Co
References
Download: ML20097A446 (306)


Text

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Diablo Canyon Date of Examination: 02/24/2020 Examination Level: RO SRO Operating Test Number: L181 Administrative Topic (see Note) Type Describe activity to be performed Code*

Conduct of Operations Determine H2 Recombiner Settings (NRCL181-A1) M, R 2.1.23 Ability to perform specific system and integrated plant procedures during all modes of plant operation.

(4.3)

(STP Exam 09-2017)

Conduct of Operations Estimate Decay Heat and Heat Removal Rate (NRCL181-A2) M, R 2.1.25 Ability to interpret reference materials such as graphs, curves, tables, etc.

(3.9)

(Bank: LJC-014)

Equipment Control Perform STP I-1A (NRCL181-A3) N, R 2.2.37 Ability to determine Operability and/or availability of safety related equipment.

(3.6)

Radiation Control Perform RM-19 Channel Check N, R (NRCL181-A4) 2.3.5 Ability to use radiation monitoring systems, such as fixed radiation monitors and alarms, portable survey instruments, personnel monitoring equipment, etc. (2.9)

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

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

(P)revious 2 exams ( 1, randomly selected)

Rev 2

ES-301 Administrative Topics Outline Form ES-301-1 Facility: Diablo Canyon Date of Examination: 02/24/2020 Examination Level: RO SRO Operating Test Number: L181 Administrative Topic (see Note) Type Describe activity to be performed Code*

Conduct of Operations Apply Overtime Limit Restrictions (NRCL181-A5) M, R 2.1.5 Ability to use procedures related to shift staffing, such as minimum crew complement, overtime limitations, etc (3.9)

(NRCADM061-COO-SRO1)

Conduct of Operations Evaluate Fire Zone Operability (NRCL181-A6) M, R 2.1.25 Ability to interpret reference materials such as graphs, curves, tables, etc.

(4.2)

(Bank: LJC-014)

Equipment Control Determine 230 kV Operability (NRCL181-A7) N, R 2.2.37 Ability to determine Operability and/or availability of safety related equipment.

(4.6)

Radiation Control Authorize Emergency Exposure (NRCL181-A8) M, R 2.3.4 Knowledge of radiation exposure limits under normal or emergency conditions. (3.7)

(NRCL161-A8)

Emergency Plan Review Emergency Notification for Steam Generator Tube Rupture (NRCL181-A9) N, R 2.4.40 Knowledge of SRO responsibilities in emergency plan implementation.

(4.5)

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

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

(P)revious 2 exams ( 1, randomly selected)

Rev 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181A1

Title:

Determine H2 Recombiner Settings Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

OP H9, Inside Containment H2 Recombination System, R11 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: See Task Standard (pg 2)

Job Designation: RO Rev Comments: Bank from STP Exam 092017 2.1.23 - Ability to perform specific system and integrated plant Gen KA # / Rating: procedures during all modes of plant operation.. 4.3 AUTHOR: LISA TORIBIO DATE: 02/05/2020 OPERATIONS REPRESENTATIVE: CHRIS MEHIGAN DATE: 02/05/2020 Rev. 2

JPM TITLE: Determine H2 Recombiner Settings JPM NUMBER: NRCL181A1 INSTRUCTOR WORKSHEET Directions: The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the step at which to begin.

Required Materials: OP H9, Inside Containment H2 Recombination System, rev 11 Picture of Containment pressure meters on VB1 Containment Temperature trend Initial Conditions: GIVEN:

A LOCA has occurred on Unit 1 Containment hydrogen concentration is 2.5%

The crew is implementing OP H9, Inside Containment H2 Recombination System to reduce containment hydrogen concentration Initiating Cue: The Shift Foreman directs you to determine the power setting for H2 Recombiner 12 in accordance with OP H9, Attachment 3, H2 Recombiner Power Output Calculation NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

NOTE: Do NOT provide examinee with Task Standard Task Standard The candidate determined:

Absolute Containment Pressure = 21.7 psia Cp = 1.35 + 0.05 Power output setting = 56.51 + 2.2 kW Start Time: __________ Stop Time:_____________

Page 2 of 6 Rev. 2

JPM TITLE: Determine H2 Recombiner Settings JPM NUMBER: NRCL181A1 INSTRUCTOR WORKSHEET Recombiner 1-_2_

NOTE: Use additional copies as needed.

1. Record containment pressure (VB1):

PI-934: __7.0__ psig PI-936: __8.0__ psig PI-935: __7.0__ psig PI-937: __6.0__ psig

2. Calculate average absolute containment pressure (AACP) for current conditions using the following formula:

((PI-934 + PI-935 + PI-936 + PI-937) / 4) + 14.7 = AACP

((__7.0_____+___7.0____+__8.0___+__6.0___) /4) + 14.7 = ___21.7___ psia PI-934 PI-935 PI-936 PI-937 AACP

3. Record Pre-LOCA containment temperature: (NA instrument not used)

YR-26 (VB1): _90__°F PPC Archive: __N/A___°F

4. Using Pre-LOCA containment temperature, average absolute containment pressure (AACP), and Attachment , determine power correction factor (Cp ).

Cp:_1.35 + 0.05__

5. Record recombiner reference power (RP) obtained from Volume 9 CMD Table T-VF-1:

RP: _41.86_ kW

6. Calculate recombiner power output setting (PS) using the following formula:

Cp X RP = PS

_1.35_+ 0.05____ X __41.86__ kW = _56.51 + 2.2_ kW Cp Ref Pwr PS Red Box Denotes Critical Step COMMENTS:

PRINT LAST NAME/SIGNATURE INIT DATE PRINT LAST NAME/SIGNATURE INIT DATE PRINT LAST NAME/SIGNATURE INIT DATE PRINT LAST NAME/SIGNATURE INIT DATE Page 3 of 6 Rev. 2

JPM TITLE: Determine H2 Recombiner Settings JPM NUMBER: NRCL181A1 INSTRUCTOR WORKSHEET Page 4 of 6 Rev. 2

JPM TITLE: Determine H2 Recombiner Settings JPM NUMBER: NRCL181A1 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

Page 5 of 6 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181A1 Initial Conditions:

GIVEN:

A LOCA has occurred on Unit 1 Containment hydrogen concentration is 2.5%

The crew is implementing OP H9, Inside Containment H2 Recombination System to reduce containment hydrogen concentration Initiating Cue: The Shift Foreman directs you to determine the power setting for H2 Recombiner 12 in accordance with OP H9, Attachment 3, H2 Recombiner Power Output Calculation NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Page 6 of 6 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181-A2

Title:

Estimate Decay Heat and Heat Removal Rate Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

OP AP SD-5, Loss of Residual Heat Removal, Rev. 10 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: See task standard Job Designation: RO Rev Comments: Revised from Bank LJC-014 2.1.25 - Ability to interpret reference materials such as graphs, Gen KA # / Rating: curves, tables, etc. 3.9 AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE: CHRIS MEHIGAN DATE: 02/05/20 Rev. 2

JPM TITLE: Estimate Decay Heat and Heat Removal Rate JPM NUMBER: NRCL181-A2 INSTRUCTOR WORKSHEET Directions: All actions taken by the examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the step at which to begin.

Required Materials:

  • Calculator

Initial Conditions: GIVEN:

  • Unit 1 was shut down six days ago for a refueling outage
  • RCS has been drained to 108' and is being maintained at that level in accordance with OP A-2:III, Reactor Vessel - Draining to Half Loop/Half Loop Operations With Fuel in Vessel
  • Core is still loaded
  • RHR pump 1-2 just tripped on overcurrent o RHR pump 1-1 can NOT be started o RCS temperature is 106 oF o NR RVRLIS level is 108'
  • The Excel Spreadsheet to calculate heatup rate is unavailable Initiating Cue: The Shift Foreman has directed you to determine the time to reach 200oF per OP AP SD-5, Appendix B.

NOTE:

  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

NOTE: Do NOT provide examinee with Task Standard

  • Determined decay heat load is 12.0 MW (+/-0.5 MW)

Task Standard:

  • Determined heatup rate was 5.4 oF/min (+/- 0.225 oF/min )
  • Determined the time to reach 200oF is 17.4 min (+/-0.8) min Start End Time: Time:

Page 2 of 6 Rev. 2

JPM TITLE: Estimate Decay Heat and Heat Removal Rate JPM NUMBER: NRCL181-A2 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

Page 3 of 6 Rev. 2

JPM TITLE: Estimate Decay Heat and Heat Removal Rate JPM NUMBER: NRCL181-A2 INSTRUCTOR WORKSHEET APPENDIX B Estimation of Decay Heat and Heatup RateT31417 NOTE: This appendix is normally performed using an Excel spreadsheet. The Excel spreadsheet is more accurate than using this appendix, and also contains time to core uncovery calculations. Use of either this appendix (hard copy) or the Excel spreadsheet is acceptable for determining heatup rates and time to 200°F.

1. PREDICTED HEAT LOAD
2.
  • REDUCTION FACTOR FOR REFUELED CORES 12.0 (+/-0.5) MW X 1.0 = 12.0 (+/-0.5) - *Critical MW Predicted Fraction of Previously Estimated Heat Load Used assemblies Decay Heat Load Installed in Core *
  • Use 1.0 if unknown Page 4 of 6 Rev. 2

JPM TITLE: Estimate Decay Heat and Heat Removal Rate JPM NUMBER: NRCL181-A2 ANSWER KEY APPENDIX B (Continued)

3. HEAT UP RATE PREDICTION 12.0 (+/-0.5) MW X 0.45 = 5.4 (+/-0.225) Degrees per
  • Critical-Estimated Inventory Predicted Minute Decay Heat Factor Heat Up Rate Load
a. INVENTORY FACTOR - Degrees/MW Min 107-ft 0.52 108-ft 0.45 Nozzle Dams Installed OR NO Nozzle Dams Installed AND SG Tubes Voided SG Tubes Not Voided 110-ft 0.40 112-ft 0.36 0.29 114-ft 0.33 0.27 116-ft 0.31 0.26 118-ft 0.31 0.054 Upper Internals Removed (Use 118-ft if Upper Internals Installed) 120-ft 0.06 130-ft 0.03 138-ft 0.02
4.
  • ESTIMATED TIME TO REACH 200 DEGREES 200 ____94_______ Delta Temp Existing

-_106__ Temperature ÷ Actual or = _17.4 (+/-0.8)_- *Critical Predicted Minutes to

_94____ Delta Temp _5.4 (5.175 - 5.625)__ Heat Up Rate reach 200 Page 5 of 6 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-A2 Initial Conditions: GIVEN:

  • Unit 1 was shut down six days ago for a refueling outage
  • RCS has been drained to 108' and is being maintained at that level in accordance with OP A-2:III, Reactor Vessel - Draining to Half Loop/Half Loop Operations With Fuel in Vessel
  • Core is still loaded
  • RHR pump 1-2 just tripped on overcurrent o RHR pump 1-1 can NOT be started o RCS temperature is 106 oF o NR RVRLIS level is 108'
  • The Excel Spreadsheet to calculate heatup rate is unavailable Initiating Cue: The Shift Foreman has directed you to determine the time to reach 200oF per OP AP SD-5, Appendix B.

NOTE:

  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Page 6 of 6 Rev. 2

      • ISSUED FOR USE BY: _______________________ DATE: ____________ EXPIRES: ____________ ***

1&2 D IABLO C ANYON POWER P LANT OP AP SD-5 ABNORMAL OPERATING PROCEDURE Rev. 10 UNITS Page 1 of 7 Loss of Residual Heat Removal 04/01/14 Effective Date QUALITY RELATED

1. SCOPE 1.1 This procedure is used in Modes 5 and 6 when RHR system flow is lost. It provides the actions necessary to regain flow and actions to be taken if RHR flow cannot be regained.

1.2 This procedure is NOT to be used if an inventory problem has caused, or has the potential to cause, the loss of the RHR system. Such cases are covered by OP AP SD-2, "Loss of RCS Inventory."

2. SYMPTOMS OR ENTRY CONDITIONS 2.1 Rising reactor cooling temperature indication on core exit thermocouples and/or loop wide range RTDs.

2.2 Rising RHR Heat Exchanger outlet temperatures.

2.3 Loss of flow indication on FI-970 A and B and/or FI-971 A and B.

2.4 Possible Annunciator Alarms:

2.4.1 RHR SYSTEM (PK02-16)

a. RHR Pp _____ Discharge pressure Hi
b. RHR Pp _____ Discharge flow Low 2.4.2 RHR PUMPS (PK02-17)
a. RHR pump trouble alarms OP_AP_SD-5u3r10.DOC 0130.1657

Loss of Residual Heat Removal OP AP SD-5 R10 Page 2 of 7 UNITS 1&2 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

1. CHECK RHR Pp Status:
a. ANY RHR Pp - RUNNING a. START AT LEAST ONE RHR Pp.
b. RHR Flow (FI-970/971) AT LEAST: b. PERFORM the FOLLOWING:
  • 1550 GPM (Mode 6 GREATER
  • ENSURE OPEN FCV-641A/B THAN 57 Hours from SD)
  • CHECK RHR Pp Motor Current -

OR GREATER THAN 28 Amps.

  • 3300 GPM (Mode 6 LESS THAN IF Recirc Flow CANNOT Be Verified, 57 Hours from SD)

THEN STOP the RHR Pp AND CHECK RHR Pp Valve Alignment.

2. ENSURE CCW Flow to RHR Heat REFER TO OP AP SD-4, LOSS of Exchangers: COMPONENT COOLING WATER.
  • FCV-364/365 - OPEN
  • ANY CCW Pp - RUNNING
3. ENSURE AT LEAST ONE RHR Train GO TO step 5.

RESTORED:

  • RHR Pp - IN SERVICE
  • FI-970/971 - FLOW INDICATED
  • RHR HX Outlet Temp - STABLE OR DECREASING
  • RCS Temperature - STABLE OR DECREASING
4. RETURN to Procedure AND Step In Effect OP_AP_SD-5u3r10.DOC 0130.1657

Loss of Residual Heat Removal OP AP SD-5 R10 Page 3 of 7 UNITS 1&2 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED

5. CHECK If RCPs Can Be Run:
a. RCS - INTACT, Capable of Being a. GO TO step 8.

Pressurized

b. ANY RCP - CAPABLE of Running b. GO TO step 8.
  • Pp Coupled
  • Seal Injection - AVAILABLE
  • CCW - AVAILABLE
  • Electrical Power - AVAILABLE
c. RCP Seal Delta-P - GREATER THAN c. IF RCS/VCT pressures CANNOT be 255 PSID adjusted to provide Seal Delta-P of AT LEAST 255 psid, THEN GO TO step 8.
6. START ANY Available RCPT32822/T32591 GO TO step 8.
7. CONTINUE Efforts to Restore RHR Pps
8. CHECK RCS Temperatures - GO TO OP AP SD-0, LOSS OF, or INADEQUATE DECAY HEAT STABLE OR DECREASING REMOVAL.T32822/T32591
9. RETURN to Procedure AND Step In Effect AND Continue Efforts to Restore the RHR System

- END -

OP_AP_SD-5u3r10.DOC 0130.1657

Loss of Residual Heat Removal OP AP SD-5 R10 Page 4 of 7 UNITS 1&2

3. APPENDICES 3.1 Appendix B, Estimation of Decay Heat and Heatup Rate
4. ATTACHMENTS 4.1 Attachment 1, "FoldOut Page"
5. REFERENCES 5.1 PG&E NOS/ISAG Calculational File No. 920815-0, "Heatup Rates During an Outage",

August 21, 1992 5.2 PG&E NOS/ISAG Calculational File No. 920831-0, "Revised Inventory Factors for Reduced Inventory Operations", September 1, 1992 5.3 NESNE Calculational file No. N-147, "Inventory Factors for RCS Heatup", August 19, 1994 OP_AP_SD-5u3r10.DOC 0130.1657

Loss of Residual Heat Removal OP AP SD-5 R10 Page 5 of 7 UNITS 1&2 APPENDIX B Estimation of Decay Heat and Heatup RateT31417/T31098

1. PREDICTED HEAT LOAD
2. REDUCTION FACTOR FOR REFUELED CORES MW X = MW Predicted Fraction of Previously Estimated Heat Load Used Assemblies Decay Heat Installed in Core
  • Load
  • Use 1.0 if unknown OP_AP_SD-5u3r10.DOC 0130.1657

Loss of Residual Heat Removal OP AP SD-5 R10 Page 6 of 7 UNITS 1&2 APPENDIX B (Continued)

3. HEAT UP RATE PREDICTION MW X = Degrees per Minute Estimated Inventory Predicted Decay Heat Factor Heat Up Load Rate
a. INVENTORY FACTOR - Degrees/MW Min 107' 0.52 108' 0.45 Nozzle Dams Installed NO Nozzle Dams Installed OR SG Tubes Voided AND SG Tubes NOT Voided 110' 0.40 -----

112' 0.36 0.29 114' 0.33 0.27 116' 0.31 0.26 118' 0.31 0.054 Upper Internals Removed (Use 118' if Upper Internals Installed) 120' 0.06 130' 0.03 138' 0.02

4. ESTIMATED TIME TO REACH 200 DEGREES 200° Delta Temp Existing

- Temperature ÷ Actual or =

Predicted Minutes to Delta Temp Heat Up Rate reach 200 OP_AP_SD-5u3r10.DOC 0130.1657

OP AP SD-5 R10 Page 7 of 7 Foldout Page for U1&2 OP AP SD-5 U1&2 Attachment 1: Page 1 of 1 NOTE: In core T/C's will not reflect actual core exit temperatures if ECCS injection is into RCS hot legs.

1.0 EVALUATION OF HEATUP RATE If Decay heat removal is lost for > 2 minutes:

  • Evaluate rate of RCS heatup using Appendix B and change in actual In-core T/C temperatures.
  • Determine time until RCS will exceed 200°, inform SM and SFM.

2.0 CONTAINMENT CLOSURE INITIATION CRITERIA Initiate Containment closure if:

  • RCS temperature is projected to raise to > 200° in < one hour T31098
  • RHR not restored within 10 minutes with fuel in vessel.

T31417 3.0 CONTAINMENT CLOSURE ACTIONS If containment closure is required:

  • Sound the Containment Evacuation alarm
  • Evacuate non-essential personnel from containment
  • Periodically monitor Containment Radiation monitors RM 2, 7, 30, 31
  • Ensure Equipment hatch closed
  • Ensure at least one personnel hatch door closed
  • Ensure at least one emergency personnel hatch door closed
  • Ensure SFS-50 closed or transfer tube flange installed
  • Ensure Containment Ventilation Isolation Initiated
  • Run all available CFCUs in fast speed T31098/T32822/T32591 4.0 ALTERNATIVE HEAT REMOVAL METHODS IF
  • RCS begins to pressurize due to loss of RHR
  • RCS temperature is projected to raise above 200° in < one hour THEN Refer to OP AP SD-0 step 7 to select and implement the alternative method(s) of decay heat removal.

OP_AP_SD-5u3r10.DOC 0130.1657

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181-A3

Title:

Perform STP I-1A Examinee:

Evaluator:

Print Signature Date Testing Perform __X Simulate Method:

Results: Sat __________ Unsat __________ Total Time: ________ minutes Comments: Designed for RO candidates in a classroom setting.

References:

STP I-1A, Routine Shift Checks Required by Licenses, rev 141 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: See task standard Job Designation: RO Rev Comments: New G2.2.37 - Ability to determine operability and/or availability of Gen KA # / Rating:

safety related equipment 3.6 RON FORTIER DATE: 02/05/20 AUTHOR CHRIS MEHIGAN DATE: 02/05/20 OPERATIONS REPRESENTATIVE Rev. 1

JPM TITLE: Perform STP I-1A JPM NUMBER: NRCL181-A3 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly documented. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure (as applicable) and told the steps with which to begin.

Required STP I-1A, Routine Shift Checks Required by Licenses, Steps 12.5 and 12.6, rev 141 Materials:

Initial Unit 1 is at 100% power Conditions:

Initiating Cue: You are instructed to perform STP I-1A, Shift Checks Required by Licenses:

  • Inform the SFM of the results NOTE:
  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.
  • If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

NOTE: Do NOT provide examinee with Task Standard :

  • Step 12.5.3 not met o RCS Accumulator 1-2 level change is greater than 3% (5%)

Task Standard:

  • Step 12.6.2 not met o RCS Accumulator 1-2 pressure greater than 640 psig (650 psig) o RCS Accumulator 1-3 pressure less than 600 psig (590/585 psig).

Start Time: ____________

Stop Time: _____________

Follow up Question Documentation:

Question: _____________________________________________________________________________

    • Denotes Critical Step and Sub-Steps Page 2 of 4 Rev. 1

Routine Shift Checks Required by Licenses STP I-1A R141 Page 15 of 118 U1 Section 12: Page 6 of 28 12.5 RCS Accumulator Volume -

a. Select indicators used. _glh1__
b. Record levels for indicators selected. _glh1_
c. Record C-2 level from latest STP C-2 volume. _glh1_

RCS Current STP C-2 % Level Accum. VB-1 Ind or PPC Point Level (%) Level Change LI-950 [X] LI950R [ ] 70 - 68 = 2 1-1 LI-951 [X] LI951R [ ] 70 - 68 = 2 LI-952 [X] LI952R [ ] 73 - 68 = 5*

1-2 73 LI-953 [X] LI953R [ ] - 68 = 5*

LI-954 [X] LI954R [ ] 68 - 67 = 1 1-3 68 - 67 LI-955 [X] LI955R [ ] = 1 69 - 69 = 0 LI-956 [X] LI956R [ ]

1-4 69 - 68 LI-957 [X] LI957R [ ] = 1

d. Calculate level changes in table above. _glh1_

12.5.2 Check all current RCS accumulator levels are 59% [52%] AND 75% [82%]. _glh1_

12.5.3 Check all RCS accumulator level changes are +3% [+5.6%]. _____

12.5.4 IF draining or filling of accumulator(s) has occurred OR level increase is unacceptable, THEN request chemistry to perform STP C-2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for affected accumulator(s). [ ]N/A _glh1_

ANSWER KEY STP_I-1Au1r41.DOC 0806.1531

Routine Shift Checks Required by Licenses STP I-1A R141 Page 16 of 118 U1 Section 12: Page 7 of 28 12.6 RCS Accumulator Nitrogen Pressure * - out of specification Applicability Requirement Parameter MODE 1 SR 3.5.1.3 RCS Accumulator Nitrogen Pressure 12.6.1 In table below, record the following:

a. Select indicators used. _glh1_
b. Record pressure readings for indicators selected. _glh1_

RCS Pressure Accumulator VB-1 Ind or PPC Point (psig)

PI-960 [ X] PI960R [ ] 610 1-1 PI-961 [ X] PI961R [ ] 610 PI-962 [ X] PI962R [ ] 650

  • 1-2 650
  • PI-963 [ X] PI963R [ ]

PI-964 [ X] PI964R [ ] 590

  • 1-3 585
  • PI-965 [ X] PI965R [ ]

PI-966 [ X] PI966R [ ] 615 1-4 615 PI-967 [ X] PI967R [ ]

12.6.2 Check RCS accumulator nitrogen pressures are 600 psig [579 psig]

AND 640 psig [664 psig]. _____

12.7 Pressurizer Level Channels Applicability Requirement Parameter MODE 1 Admin PPC Pressurizer Level Channels 12.7.1 Check the following PPC Pressurizer Level Channels have a quality code of good (green): _____

  • L0480A
  • L0481A ANSWER KEY
  • L0482A 12.7.2 IF a quality code is NOT good, THEN document in a notification. [ ]N/A _____

STP_I-1Au1r41.DOC 0806.1531

JPM TITLE: Perform STP I-1A JPM NUMBER: NRCL181-A3 INSTRUCTOR WORKSHEET Response: _____________________________________________________________________________

Examinee Response - Key See attached marked up procedure

    • Denotes Critical Step and Sub-Steps Page 3 of 4 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-A3 Initial Unit 1 is at 100% power Conditions:

Initiating Cue: You are instructed to perform STP I-1A, Shift Checks Required by Licenses:

  • Inform the SFM of the results NOTE:
  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.
  • If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Page 4 of 4 Rev. 1

69-13523 02/12/09 Page 1 of 2 DIABLO CANYON POWER PLANT TITLE:

STP C-2 ATTACHMENT 9.1 Accumulator Chemical Concentration Data Sheet 1 2 AND A. Unit: ___1___ Operating MODE: ___1___ Date/Time: _02/23/20_/_0230_

B. Reason for Analysis:

[ X ] Monthly (31 Day) Analysis [ ] Other _______________________________________

[ ] 3% level increase or any operational draining or filling. (REFER TO OM12.DC1, "Relieving the Watch,"

Form 69-09377, for date and time of level change as determined by operations.)

Accumulator Level (%)

C. Accumulator Boron in Limits?

Boron Concentration Vertical Board PPC LI950 _68_ LI950R __68.2_

Accumulator #1: _2340_ ppm [X]Yes [ ]No [ ]N/A LI951 _68___ LI951R __68.1_

LI952 _68___ LI952R __67.8_

Accumulator #2: _2298_ ppm [ X ]Yes [ ]No [ ]N/A LI953 _68___ LI953R __67.5_

LI954 _67___ LI954R __67.2_

Accumulator #3: _2318_ ppm [ X ]Yes [ ]No [ ]N/A LI955 _67___ LI955R __67.0_

LI956 _69___ LI956R __68.4_

Accumulator #4: __2322_ ppm [ X ]Yes [ ]No [ ]N/A LI957 _68___ LI957R __68.1_

Acceptance Criteria Accumulator level values have no acceptance criteria in STP C-2.

IF accumulator boron concentration is 2200 ppm and 2500 ppm, THEN the accumulator results are acceptable.

OTHERWISE the results are NOT acceptable.

Accumulator boron concentrations are: [ X] Acceptable [ ] NOT Acceptable IF NOT acceptable, THEN perform the following:

Immediately notify SFM and chemistry foreman.

Create a notification. # _______________

The chemistry foreman shall notify the chemistry engineer of any out-of-limit parameter.

Comments:

STP_C-2u3r10.doc 06 1024.1412

Routine Shift Checks Required by Licenses STP I-1A R141 Page 15 of 118 U1 Section 12: Page 6 of 28 12.5 RCS Accumulator Volume Applicability Requirement Parameter MODE 1 SR 3.5.1.2 RCS Accumulator Volume SR 3.5.1.4 12.5.1 In table below, record the following:

a. Select indicators used. _____
b. Record levels for indicators selected. _____
c. Record C-2 level from latest STP C-2 volume. _____

RCS Current STP C-2  % Level Accum. VB-1 Ind or PPC Point Level (%) Level Change LI-950 [ ] LI950R [ ] - =

1-1 LI-951 [ ] LI951R [ ] - =

LI-952 [ ] LI952R [ ] - =

1-2 LI-953 [ ] LI953R [ ] - =

LI-954 [ ] LI954R [ ] - =

1-3 LI-955 [ ] LI955R [ ] - =

LI-956 [ ] LI956R [ ] - =

1-4 LI-957 [ ] LI957R [ ] - =

d. Calculate level changes in table above. _____

12.5.2 Check all current RCS accumulator levels are 59% [52%] AND 75% [82%]. _____

12.5.3 Check all RCS accumulator level changes are +3% [+5.6%]. _____

12.5.4 IF draining or filling of accumulator(s) has occurred OR level increase is unacceptable, THEN request chemistry to perform STP C-2 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for affected accumulator(s). [ ]N/A _____

STP_I-1Au1r41.DOC 0806.1531

Routine Shift Checks Required by Licenses STP I-1A R141 Page 16 of 118 U1 Section 12: Page 7 of 28 12.6 RCS Accumulator Nitrogen Pressure Applicability Requirement Parameter MODE 1 SR 3.5.1.3 RCS Accumulator Nitrogen Pressure 12.6.1 In table below, record the following:

a. Select indicators used. _____
b. Record pressure readings for indicators selected. _____

RCS Pressure Accumulator VB-1 Ind or PPC Point (psig)

PI-960 [ ] PI960R [ ]

1-1 PI-961 [ ] PI961R [ ]

PI-962 [ ] PI962R [ ]

1-2 PI-963 [ ] PI963R [ ]

PI-964 [ ] PI964R [ ]

1-3 PI-965 [ ] PI965R [ ]

PI-966 [ ] PI966R [ ]

1-4 PI-967 [ ] PI967R [ ]

12.6.2 Check RCS accumulator nitrogen pressures are 600 psig [579 psig]

AND 640 psig [664 psig]. _____

12.7 Pressurizer Level Channels Applicability Requirement Parameter MODE 1 Admin PPC Pressurizer Level Channels 12.7.1 Check the following PPC Pressurizer Level Channels have a quality code of good (green): _____

  • L0480A
  • L0481A
  • L0482A 12.7.2 IF a quality code is NOT good, THEN document in a notification. [ ]N/A _____

STP_I-1Au1r41.DOC 0806.1531

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181-A4

Title:

Perform RM-19 Channel Check Examinee:

Evaluator:

Print Signature Date Testing Perform __X Simulate Method:

Results: Sat __________ Unsat __________ Total Time: ________ minutes Comments: Designed for RO candidates in a classroom setting.

Operations Policy B-5, Channel Check Criteria, rev 6

References:

Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: Per Examinee Response - Key Job Designation: RO Rev Comments: New G2.3.5 -Ability to use radiation monitoring systems, such as Gen KA # / Rating: fixed radiation monitors and alarms, portable survey instruments, personnel monitoring equipment, etc. 2.9 RON FORTIER DATE: 11/08/19 AUTHOR CHRIS MEHIGAN DATE: 11/26/19 OPERATIONS REPRESENTATIVE Rev. 0

JPM TITLE: Perform RM-19 Channel Check JPM NUMBER: NRCL181-A4 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly documented. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure (as applicable) and told the steps with which to begin.

Required Operations Policy B-5, Materials:

Initial Conditions: GIVEN:

  • Both Unit 1 and 2 are at 100% power
  • STP I-1B, Attachment 12.1, MODES 1, 2, and 3 Daily Checklist is being performed
  • The operator has reached step 15, CHANNEL CHECK the steam generator blowdown liquid monitor, RM-19 Initiating Cue: You are instructed to use Operations Section Policy B-5, Channel Check Criteria to perform the CHANNEL CHECK for steam generator blowdown liquid monitor, RM-19 and document all your results to support your determination.

NOTE:

  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.
  • If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

NOTE: Do NOT provide examinee with Task Standard :

Channel Check is UNSAT due to:

Task Standard:

  • Range selector switch is set to NARROW
  • Setpoint toggle switch selected to HASP #2 (MAINT ONLY)

Start Time: ____________

Stop Time: _____________

Follow up Question Documentation:

    • Denotes Critical Step and Sub-Steps Page 2 of 5 Rev. 0

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 3 of 6

2. WESTINGHOUSE RAD MONITORS (includes RM-3, 11, 12, 18, 19, 22)
a. POWER light is ON.
b. Operation Selector switch set to OPERATE.
c. Range Selector switch set to WIDE.
d. Normal analog channel levels and response.
e. Red LOW ALARM lamp is OFF.

There are additional checks for RM-11, Containment Air Particulate detector:

f. Sample Selector set to MAIN sample.
g. PUMP ON light is lit.
h. FILTER NOT IN MOTION light is OUT.

There is an additional check for RM-3, OWS effluent monitor:

Y

i. Flow verified through the monitor while the OWS is running.

NOTE: RM-19 setpoint toggle switch selected to the HASP #1 (S/G TO B/D) position.

3. VICTOREEN RAD MONITORS KE ANALOG RAD MONITORS (includes RM-71, 72, 73, 74, 30, 31, U-1 RM-29)
a. Switch selector to OPERATE or ALL.
b. Green SAFE/FAIL/RESET light is ON.
c. Normal analog channel levels and response.

ER DIGITAL RMs (includes RM-14/R, 15/R, 24/R, 28/R, 44A/B, U-2 RM-29)

a. White NORMAL panel light is ON.
b. Red SKID PMP light ON.
c. The Remote Display Units (RDU) on the back panels have digital readouts which must update periodically, generally from 15 to 120 seconds.

NOTES:

SW

1. RM-30, 31 detectors measure in R/hr and should generally be less than 1 R/hr on a normal channel check. An auto check of these detectors to 1E3 will occur every 17 minutes to ensure these monitors are not failed low. This auto check is NOT a required channel check.
2. RM-29 (Unit 2) detector has a RANGE light which will illuminate when the detector reading drops below its under-range of less than 0.01 mR/hr. When it AN registers activity greater than 0.01mR/hr, the red RANGE light will go OUT.
4. MISCELLANEOUS RADIATION MONITORS RM-58, 59
a. Switch selected to OPERATE.
b. Green OPERATE light is ON.
c. Normal analog channel levels and response.

NOTE 1: RM-59 will generally read very low, whereas RM-58 may read significantly higher especially following a refueling on that unit.

NOTE 2: RM if no pulses occur within approximately 150 seconds, the failure alarm comes in, otherwise the OPERATE light stays illuminated.

RM-23, RADECO monitor (located in PM-205, 115, Aux Bldg)

a. HIGH and LOW alarm lamps should be ON (these lamps go OUT on an alarm condition).
b. Normal analog channel levels and response.

RM-25, 26, 51, 52, 53, 54

a. White NORMAL light is ON (RM-51 through 54).
b. Yellow FAILURE light is OFF (RM-25, 26).
c. Normal analog channel levels and response.

JPM TITLE: Perform RM-19 Channel Check JPM NUMBER: NRCL181-A4 INSTRUCTOR WORKSHEET Question: _____________________________________________________________________________

Response: _____________________________________________________________________________

Examinee Response - Key RM-19 Channel Check SAT: _____

UNSAT: __X___

Basis for SAT/UNSAT:

  • Range selector switch is set to NARROW
  • Setpoint toggle switch selected to HASP #2 (MAINT ONLY)
    • Denotes Critical Step and Sub-Steps Page 3 of 5 Rev. 0

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-A4 Initial Conditions: GIVEN:

  • Both Unit 1 and 2 are at 100% power
  • STP I-1B, Attachment 12.1, MODES 1, 2, and 3 Daily Checklist is being performed
  • The operator has reached step 15, CHANNEL CHECK the steam generator blowdown liquid monitor, RM-19 Initiating Cue: You are instructed to use Operations Section Policy B-5, Channel Check Criteria to perform the CHANNEL CHECK for steam generator blowdown liquid monitor, RM-19 and document all your results to support your determination.

NOTE:

  • You may use any source of information normally available (procedures, prints, etc.).
  • Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.
  • If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Examinee Response - Key RM-19 Channel Check SAT: _____

UNSAT: _____

Basis for SAT/UNSAT:

Page 4 of 5 Rev. 0

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-A4 Page 5 of 5 Rev. 0

PACIFIC GAS AND ELECTRIC COMPANY Number: B-5 OPERATIONS SECTION POLICY Revision: 6 Date: 6/06/16 Page: 1 of 6 DIABLO CANYON POWER PLANT UNITS 1 AND 2 TITLE: CHANNEL CHECK CRITERIA APPROVED:

Operations Manager As defined in the Technical Specifications (Tech Specs), a CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

The first sentence of the CHANNEL CHECK definition implies that single instrument channel checks are entirely permissible. The second part of the definition goes on to say where possible, a CHANNEL CHECK of independent, redundant channels measuring the same parameter shall be performed. It is also clear from the definition, that quantitative limits are not applicable to CHANNEL CHECKS.

In the past, several different classes of instruments have presented problems to operators in their CHANNEL CHECKS. These include flow instruments, which utilize square root extractors, radiation monitors, and process analysis instruments (ANI/ANRs). This policy was written to standardize the procedure for performing CHANNEL CHECKS. It is very important that the channel check criteria listed below be used as GUIDELINES for determining channel operability. Remember that not all checks need to be satisfied when determining that a particular instrument is OPERABLE. For example, a channel check criterion for the Radiation Monitors is to check the POWER light is ON.

If the POWER light is found OFF, the monitor may still be OPERABLE. Operators need to look at other indications as well. If the RM were indicating normal background radiation, the analog meter needle was oscillating slightly, all switches were in their normal position, and power fuses were installed, the shift operators should consider the Radiation Monitor OPERABLE. In this case, it is probable the POWER ON light bulb is burned out. The guideline status of these CHANNEL CHECK steps must always be recognized.

A. GENERAL CHANNEL CHECK CRITERIA The criteria listed below are applicable to most channel checks and may be applied to single and/or redundant instrument channels. Whenever an instrument channel is declared inoperable, the SFM needs to consider the effect on protection bistables associated with that indication. Certain criterion listed below will apply to instrument classes listed in the following sections of this policy.

1. Most instrument loops at DCPP utilize a 4-20 mA current scheme. Thus, most zero (0) readings occur at 4 mA. This is termed a live zero, since the instrument should generate a current output even for the zero reading (0). However with various accuracy limits among instruments, it is very possible to have a below zero reading which is normal for that channel. However, if the meter needle is hard against its low limit peg and motionless, the channel may have failed low and should be considered inoperable. Contact I&C for evaluation of the instrument and the SFM for status of channel operability.

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 2 of 6

2. For redundant instruments measuring the same parameter, one indicator reading GREATER THAN 5% (of scale) higher or lower than other channels should be declared inoperable. An exception to this rule is with the Pressurizer Level Channels, where one indicator reading GREATER THAN 8.5% (of scale) higher or lower than other channels should be declared inoperable. (Reference A0437900/07).
3. Some parameters are measured by both WIDE RANGE and NARROW RANGE instruments, e.g., accumulator levels. Because the instrument loops are calibrated to different ranges, these channels should NOT be considered redundant channels for the purpose of CHANNEL CHECKS.
4. Most analog meters indicate they are updating properly by showing a slight meter needle movement (oscillation). Most digital meters will refresh their indications periodically, e.g.,

every 20 seconds. If an analog meter needle is rock steady or oscillating excessively or if a digital indication is not updating periodically, then notify the SFM since the instrument may be inoperable. I&C should be contacted for evaluation of the channel response.

5. Many chart recorders provide the plant with permanent logs. In this case, I&C will calibrate the recorder pen trace more accurately than the meter scale pointer. Most meters and recorders exhibit a small amount of needle or pen oscillation. If this oscillation is excessive, e.g., +/-5% of channel scale, the instrument should be considered inoperable. Contact I&C for evaluation of meters or recorders exhibiting this behavior.
6. When comparing NI-31 or 32 with a Gamma-Metrics channel, the channel check is acceptable if the readings are within one decade of each other. (Reference A0603406/03)
7. Section E lists appropriate reference procedures for all instrument checks described within this Policy. Exercise caution when using quantitative test documents for performing CHANNEL CHECKS.

B. RADIATION MONITOR CHECKS Due to the wide variety of radiation monitors currently in use at DCPP, not all the checks listed below can be performed for each class of monitor. Operators should use ONLY those checks which are applicable for the RM they are channel checking. If the validity of an indication on a RMS channel is questioned, the SFM and I&C shall be notified for an evaluation of the problem and a determination of channel operability.

1. Many of the RMS channels below have an analog meter indication. A normal channel check of these meters should indicate background or normal, historical radiation levels. Analog meters are updating properly when they show a slight meter needle movement (oscillation).

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 3 of 6

2. WESTINGHOUSE RAD MONITORS (includes RM-3, 11, 12, 18, 19, 22)
a. POWER light is ON.
b. Operation Selector switch set to OPERATE.
c. Range Selector switch set to WIDE.
d. Normal analog channel levels and response.
e. Red LOW ALARM lamp is OFF.

There are additional checks for RM-11, Containment Air Particulate detector:

f. Sample Selector set to MAIN sample.
g. PUMP ON light is lit.
h. FILTER NOT IN MOTION light is OUT.

There is an additional check for RM-3, OWS effluent monitor:

i. Flow verified through the monitor while the OWS is running.

NOTE: RM-19 setpoint toggle switch selected to the HASP #1 (S/G TO B/D) position.

3. VICTOREEN RAD MONITORS ANALOG RAD MONITORS (includes RM-71, 72, 73, 74, 30, 31, U-1 RM-29)
a. Switch selector to OPERATE or ALL.
b. Green SAFE/FAIL/RESET light is ON.
c. Normal analog channel levels and response.

DIGITAL RMs (includes RM-14/R, 15/R, 24/R, 28/R, 44A/B, U-2 RM-29)

a. White NORMAL panel light is ON.
b. Red SKID PMP light ON.
c. The Remote Display Units (RDU) on the back panels have digital readouts which must update periodically, generally from 15 to 120 seconds.

NOTES:

1. RM-30, 31 detectors measure in R/hr and should generally be less than 1 R/hr on a normal channel check. An auto check of these detectors to 1E3 will occur every 17 minutes to ensure these monitors are not failed low. This auto check is NOT a required channel check.
2. RM-29 (Unit 2) detector has a RANGE light which will illuminate when the detector reading drops below its under-range of less than 0.01 mR/hr. When it registers activity greater than 0.01mR/hr, the red RANGE light will go OUT.
4. MISCELLANEOUS RADIATION MONITORS RM-58, 59
a. Switch selected to OPERATE.
b. Green OPERATE light is ON.
c. Normal analog channel levels and response.

NOTE 1: RM-59 will generally read very low, whereas RM-58 may read significantly higher especially following a refueling on that unit.

NOTE 2: RM if no pulses occur within approximately 150 seconds, the failure alarm comes in, otherwise the OPERATE light stays illuminated.

RM-23, RADECO monitor (located in PM-205, 115, Aux Bldg)

a. HIGH and LOW alarm lamps should be ON (these lamps go OUT on an alarm condition).
b. Normal analog channel levels and response.

RM-25, 26, 51, 52, 53, 54

a. White NORMAL light is ON (RM-51 through 54).
b. Yellow FAILURE light is OFF (RM-25, 26).
c. Normal analog channel levels and response.

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 4 of 6 C. FLOW INSTRUMENT (SQUARE ROOT EXTRACTOR) CHECKS When the plant is operated in a low power condition or following maintenance outages, the accuracy of square root extractor indications is frequently questioned by Operations personnel. In some cases the instrument may be inoperable or it may simply need to be backfilled. It is also possible that low flow conditions will place the square root extractor outside its calibrated range. Any time the validity of an indication is in question, I&C should be notified for an evaluation of the channel.

1. All flow instruments utilizing square root extractors are inherently inaccurate when reading less than 10% of channel scale. No accuracy requirements apply in this range and no operator action is necessary. For example, the AFW flow channels on VB3 are 0-300 gpm scales. No accuracy limits are applicable when reading less than 30 gpm.
2. The following table should aid Operations personnel in performing channel checks on these flow instruments which have no redundant indications:

INSTRUMENT CHANNEL CHANNEL CHECK CRITERIA AFW Flow FI-157,158, >30 gpm, + 5 gpm.

159,160 (Refer. General Channel Check A 1.)

Plant Vent Flow FR-12 Reasonable comparison with fan con-figuration of Aux/Fuel Handling Bldg vent modes, e.g., Bldgs Only - Approx.

13E4 cfm.

Radwaste Discharge FR-20 Verify flow is recording during a Flow release period. If possible, channel check with FR-20A (RWS filter 0-3 discharge).

S/G Blowdown Flow FR-53 Verify flow is recording during a release period. PM-205, multipoint recorder point # 6 in service with a corresponding digital readout (double or 2X digital readout).

NOTE: The Test switch located in 100, GW area of the Aux Bldg should not be used by Operations personnel. That switch is reserved for maintenance activities performed by I&C personnel.

OWS Influent Flow FR-251 If an automatic discharge is not (7 digit totalizer observed, start the turbine building nonresettable) waste pumps manually. Once overboard discharge commences, verify totalizer <100gal/min (which corresponds to 66.7% on FI-251) when the OWS is in service and discharging.

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 5 of 6 D. PROCESS ANALYSIS INSTRUMENT CHECKS The following table should aid Operators in performing channel checks on various process analysis instruments.

INSTRUMENT CHANNEL CHANNEL CHECK CRITERIA Waste Gas O2 ANI/ANR 75,76 Verify FI-905,906 have approx. 1 scfh, Analyzers otherwise run WGC for several minutes. Max. difference between channels is +/- 0.20% O2.

DFO transfer piping ANI-501 Display cycles through cables 1-6 and leak detection all cables indicate OK. If remapping is required, refer to OP J-6C:VI.

E. PROCEDURAL REFERENCES Due to the qualitative nature of a CHANNEL CHECK assessment, the procedures listed below should only be used in a reference capacity. Quantitative limits are not applicable to CHANNEL CHECKS.

Moreover, the guideline nature of this Operations Policy should be recognized and applied appropriately. Remember if these references are consulted; use the correct Unit and most recent revision of the procedure.

RADIATION MONITOR CHECKS

1. STP I-18P1, Functional Test of Oily Water Separator Influent Monitor, RM-3
2. STP I-100A, Containment Air Particulate/Gas Radiation Monitor RM-11/RM-12 Functional Test
3. STP I-102A, Functional Test of Liquid Radwaste Discharge Monitor, RM-18
4. STP I-111A, Functional Test of Steam Generator Blowdown Sample Effluent Liquid Monitor, RM-19
5. STP I-103A, Functional Test of Gas Decay Tank Gas Discharge Monitor, RM-22
6. STP I-39-R71.A, Functional Test of Main Steam Line Radiation Monitor, RM-71, 72, 73, 74
7. STP I-18N1, Functional Test of Containment High Range Radiation Monitors, RM-30, RM-31
8. STP I-39-R29.A, High Range Plant Vent Gross Gamma Monitor RM-29 Functional Test
9. STP I-39-R14.A, Plant Vent Noble Gas Radiation Monitor RM-14 Functional Test
10. STP I-39-R14R.A, Plant Vent Noble Gas Radiation Monitor RM-14R Functional Test
11. STP I-39-R24.A, Plant Vent Iodine Radiation Monitor RM-24 Functional Test
12. STP I-39-R24R.A, Plant Vent Iodine Radiation Monitor RM-24R.A Functional Test
13. STP I-39-R28.A, Plant Vent Particulate Radiation Monitor RM-28 Functional Test
14. STP I-39-R28R.A, Plant Vent Particulate Radiation Monitor RM-28R Functional Test
15. STP I-39-R44A.A, Containment Ventilation Exhaust Radiation Monitor RM-44A Functional Test
16. STP I-39-R44B.A, Containment Ventilation Exhaust Radiation Monitor RM-44B Functional Test
17. STP I-119A, Functional Test: Fuel Handling Building Area Radiation Monitors, RM-58 / RM-59
18. STP I-18F1, Functional Test of S/G Blowdown Tank Radiation Monitor RM-23
19. STP I-18M1, Control Room Air Intake Monitor Functional Test (RM-25 & RM-26)
20. STP I-118A, Functional Test of Control Room Pressurization Radiation Monitors, RM-51, 52, 53, 54

OPERATIONS SECTION POLICY Number: B-5 Channel Check Criteria Revision: 6 Date: 6/06/16 Page: 6 of 6 FLOW INSTRUMENTS

1. STP I-3-F50, Auxiliary Feedwater to Steam Generator 1-1 (2-1) Flow Channel FT-50 Calibration
2. STP I-3-F77, Auxiliary Feedwater to Steam Generator 1-2 (2-2) Flow Channel FT-77 Calibration
3. STP I-3-F78, Auxiliary Feedwater to Steam Generator 1-3 (2-3) Flow Channel FT-78 Calibration
4. STP I-3-F79, Auxiliary Feedwater to Steam Generator 1-4 (2-4) Flow Channel FT-79 Calibration
5. STP I-39-F12.B, Plant Vent Flow Measurements System Calibration
6. STP I-19-F243.A, Liquid Radwaste Effluent Line Flow Channel FIT-243 Functional Test
7. STP I-4-F53.A, Steam Generator Blowdown Effluent Line Flow Channel FT-53 Functional Test
8. STP I-27-F251.A, Oily Water Separator System Flow Channel FT-251 Functional PROCESS ANALYSIS INSTRUMENTS
1. STP I-24-A75.A, Functional Test of Waste Gas System Oxygen Analyzer Channels 75 and 76
2. STP M-121, Diesel Fuel Oil Leak Detection System ANI-501 Functional Test

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181A5

Title:

Apply Overtime Limit Restrictions Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

OM14.ID1, Fatigue Management Rule Program, rev 30 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 20 minutes Critical Steps: See Examinee Response Key Job Designation: SRO Rev Comments: Revised from L061 (NRCADM061COOSRO1)

G2.1.5 - Ability to use procedures related to shift staffing, such as Gen KA # / Rating: minimum crew complement, overtime limitations, etc. 3.9 AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE: CHRIS MEHIGAN DATE: 02/05/20 Rev. 2

JPM TITLE: Apply Overtime Limit Restrictions JPM NUMBER: NRCL181A5 INSTRUCTOR WORKSHEET Directions: All actions taken by the examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the step at which to begin.

Required Materials: OM14.ID1, Fatigue Management Rule Program, rev 30 Initial Conditions: GIVEN:

It is 0600 on Monday, 2/17 Unit 1 is operating at 100% power Unit 2 is in an outage; currently defueled The oncoming Unit 1 Control Operator has just called in sick WorkForce scheduling program is out of service The following licensed Operators are currently available:

Operator #1 Day Start Time End Time Position Sunday, 2/9 0700 1900 Control Operator Monday, 2/10 0700 1900 Control Operator Tuesday, 2/11 0700 1900 Control Operator Wednesday, 2/12 0900 2200 WC Extra Thursday 2/13 Day Off Friday 2/14 0700 2000 Balance of Plant Operator Saturday, 2/15 1400 1500 TeleCon personnel statement Sunday 2/16 0700 1900 Control Operator Monday 2/17 (proposed) 0700 1900 Control Operator Page 2 of 9 Rev. 2

JPM TITLE: Apply Overtime Limit Restrictions JPM NUMBER: NRCL181A5 INSTRUCTOR WORKSHEET Initial Conditions (continued): Operator #2 Day Start Time End Time Position Sunday, 2/9 1900 0700 Work Control Lead Monday, 2/10 1900 0700 Work Control Lead Tuesday, 2/11 Day Off Wednesday, 2/12 1900 0700 Control Operator Thursday, 2/13 1900 0700 Work Control Lead Friday, 2/14 1900 0700 Work Control Lead Saturday, 2/15 1900 0700 Control Operator Sunday 2/16 Day Off Monday 2/17 (proposed) 0700 1900 Control Operator Operator #3 Day Start Time End Time Position Sunday, 2/9 1000 1700 Fire Watch Monday, 2/10 Day Off Tuesday, 2/11 0700 2100 Control Operator Wednesday, 2/12 0700 1900 Balance of Plant Operator Thursday, 2/13 0700 1900 Balance of Plant Operator Friday, 2/14 0700 2000 Balance of Plant Operator Saturday, 2/15 1000 2000 Balance of Plant Operator Sunday 2/16 Day Off Monday 2/17 (proposed) 0700 1900 Control Operator Page 3 of 9 Rev. 2

JPM TITLE: Apply Overtime Limit Restrictions JPM NUMBER: NRCL181A5 INSTRUCTOR WORKSHEET Initiating Cue: Review the hours worked by the available Operators and determine their ability to fill the watch bill. Document reason(s) each operator is available or unavailable.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

NOTE: Do NOT provide examinee with Task Standard Task Standard: See Examinee Response Key.

Start End Time: Time:

Page 4 of 9 Rev. 2

JPM TITLE: Apply Overtime Limit Restrictions JPM NUMBER: NRCL181A5 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

Page 5 of 9 Rev. 2

JPM TITLE: Apply Overtime Limit Restrictions JPM NUMBER: NRCL181A5 INSTRUCTOR WORKSHEET Examinee Response Key Only Operator #2 can accept the watch without a waiver based on the allowable work hours during NonOutage Conditions. NOTE: Only reason for unavailability is critical, hours not required with answer.

Operator #1 - Not Available o Can not exceed 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> in any continuous 24 period: Satisfactory (max was 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />) o Can not exceed 26 hours3.009259e-4 days <br />0.00722 hours <br />4.298942e-5 weeks <br />9.893e-6 months <br /> in any continuous 48 period: Satisfactory (max was 25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />) o Can not exceed 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any continuous 168 period: Satisfactory (max was 63 hours7.291667e-4 days <br />0.0175 hours <br />1.041667e-4 weeks <br />2.39715e-5 months <br />) o 34 hour3.935185e-4 days <br />0.00944 hours <br />5.621693e-5 weeks <br />1.2937e-5 months <br /> continuous break required in any 9 day period: Unsatisfactory (taking the relief watch at 0700 on Monday would result in a continuous break of 33 hours3.819444e-4 days <br />0.00917 hours <br />5.456349e-5 weeks <br />1.25565e-5 months <br /> in the past 9 day period) o 10 hour1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> continuous break minimum break required between shifts: Satisfactory (min was 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)

Operator #2 - Available o Can not exceed 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> in any continuous 24 period: Satisfactory (max was 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />) o Can not exceed 26 hours3.009259e-4 days <br />0.00722 hours <br />4.298942e-5 weeks <br />9.893e-6 months <br /> in any continuous 48 period: Satisfactory (max was 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />) o Can not exceed 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any continuous 168 period: Satisfactory (max was 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) o 34 hour3.935185e-4 days <br />0.00944 hours <br />5.621693e-5 weeks <br />1.2937e-5 months <br /> continuous break required in any 9 day period: Satisfactory (min was 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />) o 10 hour1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> continuous break minimum break required between shifts: Satisfactory (min was 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />)

Operator #3 - Not Available o Can not exceed 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> in any continuous 24 period: Satisfactory (max was 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />) o Can not exceed 26 hours3.009259e-4 days <br />0.00722 hours <br />4.298942e-5 weeks <br />9.893e-6 months <br /> in any continuous 48 period: Satisfactory (max was 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />) o Can not exceed 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> in any continuous 168 period: Unsatisfactory (max was 73.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br />) o 34 hour3.935185e-4 days <br />0.00944 hours <br />5.621693e-5 weeks <br />1.2937e-5 months <br /> continuous break required in any 9 day period: Satisfactory(max was 38 hours4.398148e-4 days <br />0.0106 hours <br />6.283069e-5 weeks <br />1.4459e-5 months <br />) o 10 hour1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> continuous break minimum break required between shifts: Satisfactory (min was 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />)

Page 6 of 9 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181A5 Initial Conditions: GIVEN:

It is 0600 on Monday, 2/17 Unit 1 is operating at 100% power Unit 2 is in an outage; currently defueled The oncoming Unit 1 Control Operator has just called in sick WorkForce scheduling program is out of service The following licensed Operators are currently available:

Operator #1 Day Start End Time Position Time Sunday, 2/9 0700 1900 Control Operator Monday, 2/10 0700 1900 Control Operator Tuesday, 2/11 0700 1900 Control Operator Wednesday, 2/12 0900 2200 WC Extra Thursday 2/13 Day Off Friday 2/14 0700 2000 Balance of Plant Operator Saturday, 2/15 1400 1500 TeleCon personnel statement Sunday 2/16 0700 1900 Control Operator Monday 2/17 (proposed) 0700 1900 Control Operator Page 7 of 9 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181A5 Operator #2 Day Start End Time Position Time Sunday, 2/9 1900 0700 Work Control Lead Monday, 2/10 1900 0700 Work Control Lead Tuesday, 2/11 Day Off Wednesday, 2/12 1900 0700 Control Operator Thursday, 2/13 1900 0700 Work Control Lead Friday, 2/14 1900 0700 Work Control Lead Saturday, 2/15 1900 0700 Control Operator Sunday 2/16 Day Off Monday 2/17 0700 1900 Control Operator (proposed)

Initial Conditions (continued): Operator #3 Day Start End Time Position Time Sunday, 2/9 1000 1700 Fire Watch Monday, 2/10 Day Off Tuesday, 2/11 0700 2100 Control Operator Wednesday, 2/12 0700 1900 Balance of Plant Operator Thursday, 2/13 0700 1900 Balance of Plant Operator Friday, 2/14 0700 2000 Balance of Plant Operator Saturday, 2/15 1000 2000 Balance of Plant Operator Sunday 2/16 Day Off Monday 2/17 0700 1900 Control Operator (proposed)

Page 8 of 9 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181A5 Initiating Cue: Review the hours worked by the available Operators and determine their ability to fill the watch bill. Document reason(s) each operator is available or unavailable.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Evaluation Results and Basis Operator #1 Basis:

___ Available

___ Unavailable Operator #2 Basis:

___ Available

___ Unavailable Operator #3 Basis:

___ Available

___ Unavailable Page 9 of 9 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181A6

Title:

Evaluate Fire Zone Operability Examinee:

Evaluator:

Print Signature Date Testing Method: Perform X Simulate Results: Sat Unsat Total Time: minutes Comments: Designed for SRO candidates in a classroom setting.

References:

ECG 18.7 - Fire Rated Assemblies Fire Protection Drawings 11190621 DCPP Operational Requirements for Doors, Drawing 5152212 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: See Examinee Response Key Job Designation: SRO Rev Comments Bank NRCL161 A6 Gen KA # G2.1.25 Ability to interpret reference materials, such as 4.2 graphs, curves, tables, etc.

RON FORTIER DATE: 02/05/20 AUTHOR CHRIS MEHIGAN DATE: 02/05/20 OPERATIONS REPRESENTATIVE Rev. 1

JPM TITLE: Evaluate Fire Zone Operability JPM NUMBER: NRCL181A6 EVALUATOR WORKSHEET Directions: All actions taken by examinee should be clearly documented. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure (as applicable) and told the steps with which to begin.

Required Materials: ECG 18.7 - Fire Rated Assemblies eSOMS printout Fire Protection Drawings 11190621 DCPP Operational Requirements for Doors, Drawing 5152212 Initial Conditions: GIVEN:

Unit 1 and Unit 2 are both at 100% power Maintenance has just reported that the closing mechanism on Door 326 (Battery Room 115 Elevation) on Unit 1 has failed and the door cannot be closed automatically or manually.

Initiating Cue: The Shift Manager has directed you to determine the required course of action. Document your results and the basis of your decision in the space below before reporting out.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Task Standard: DO NOT READ TASK STANDARD TO EXAMINEE Determined ECG 18.7, Condition A.1 Establish a continuous fire watch on at least one side of the inoperable assembly (door) within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is the only applicable TS/ECG action.

Basis - with inoperable detectors in the area, only action is a continuous fire watch.

o NOTE: Use of an hourly fire watch patrol is not permitted due to the nonfunctional fire detection equipment within the same fire zone as the nonfunctional door.

NRCL181 A6 r1 .docx PAGE 1 OF 5 Rev. 1

JPM TITLE: Evaluate Fire Zone Operability JPM NUMBER: NRCL181A6 EVALUATOR WORKSHEET Stop Time:

Total Time: (Enter total time on the cover page)

NRCL181 A6 r1 .docx PAGE 2 OF 5 Rev. 1

JPM TITLE: Evaluate Fire Zone Operability JPM NUMBER: NRCL181A6 EVALUATOR WORKSHEET Followup Question Documentation:

Question: ____________________________________________________________________

Response: ____________________________________________________________________

NRCL181 A6 r1 .docx PAGE 3 OF 5 Rev. 1

JPM TITLE: Evaluate Fire Zone Operability JPM NUMBER: NRCL181A6 ANSWER KEY EXAMINEE RESPONSE Key Required Action: Establish a continuous fire watch on at least one side of the inoperable assembly within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Basis: Use of an hourly fire watch patrol is not permitted due to the nonfunctional fire detection equipment within the same fire zone as the nonfunctional door.

NRCL181 A6 r1 .docx PAGE 4 OF 5 Rev. 1

JPM TITLE: Evaluate Fire Zone Operability JPM NUMBER: NRCL181A6 EXAMINEE CUE SHEET Initial Conditions: GIVEN:

Unit 1 and Unit 2 are both at 100% power Maintenance has just reported that the closing mechanism on Door 326 (Battery Room 115 Elevation) on Unit 1 has failed and the door cannot be closed automatically or manually.

Initiating Cue: The Shift Manager has directed you to determine the required course of action. Document your results and the basis of your decision in the space below before reporting out.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

EXAMINEE RESPONSE ACTION:

BASIS:

NRCL181 A6 r1 .docx PAGE 5 OF 5 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181-A7

Title:

Determine 230 kV OPERABILITY Examinee:

Evaluator:

Print Signature Date Testing Perform __X Simulate Method:

Results: Sat __________ Unsat __________ Total Time: ________ minutes Comments: Designed for SRO candidates in a classroom setting.

OP J-2:VIII, rev 32

References:

LCO 3.8.1, AC Sources - Operating, rev 12 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: See Examinee Response - Key Job Designation: SRO Rev Comments: New G2.2.37 - Ability to determine operability and/or availability of Gen KA # / Rating:

safety related equipment 4.6 RON FORTIER DATE: 02/05/20 AUTHOR CHRIS MEHIGAN DATE: 02/05/20 OPERATIONS REPRESENTATIVE Rev. 2

JPM TITLE: Determine 230 kV OPERABILITY JPM NUMBER: NRCL181-A7 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly documented. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure (as applicable) and told the steps with which to begin.

Required OP J-2:VIII, rev 32 Materials: LCO 3.8.1 Initial GIVEN:

Conditions: Both Unit 1 and 2 are at 100% power Emergency Diesel Generator 1-2 is declared inoperable Two minutes after Diesel Generator 1-2 is declared inoperable, an earthquake causes a grid disturbance Grid Control reports:

o loss of the Morro Bay-Diablo Canyon 230 kV line o 230 kV voltage is 230 kV o Los Padres Area Load is 350 MW o DCPP has 0 capacitors in service and none available o Mesa has 4 capacitors and 1 transformer in service No operator compensatory actions have been taken No LCO ACTION(s) have been entered for any of the above conditions LTC is in AUTO 52VU11 is OPEN Initiating Cue: You are instructed to:

Using OP J-2:VIII, Guidelines for Reliable Transmission Service for DCPP, Attachment 2, 230kV Offsite Power Operability Evaluation - LTC IN AUTO, determine the OPERABILITY of 230 kV at this time (show your work)

For the given conditions, determine all applicable LCO ACTION(s) to Unit 1, should any exist.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

    • Denotes Critical Step and SubSteps Page 2 of 5 Rev. 2

JPM TITLE: Determine 230 kV OPERABILITY JPM NUMBER: NRCL181-A7 INSTRUCTOR WORKSHEET NOTE: Do NOT provide examinee with Task Standard :

Determined 230 kV system is INOPERABLE for any of the following reasons:

230 kV switchyard voltage is below the minimum required for normal transfer (min = 231 kV vs actual = 230 kV) with no comp actions complete Los Padres Area Load is above the maximum allowed (max = 305 MW vs Task Standard: actual = 350 MW) with no comp actions complete Determined following LCOs all must be entered:

LCO 3.8.1.A for 1 Offsite Circuit Inoperable LCO 3.8.1.B for 1 D/G Inoperable LCO 3.8.1.D for 1 D/G and 1 Offsite Source Inoperable Start End Time: Time:

    • Denotes Critical Step and SubSteps Page 3 of 5 Rev. 2

JPM TITLE: Determine 230 kV OPERABILITY JPM NUMBER: NRCL181-A7 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________

Response: _____________________________________________________________________________

Examinee Response - Key

1. 230 kV is inoperable Determined OP J-2-VIII, Table 1, Row 2-11 (Morro Bay-Diablo Canyon 230 kV Line) applies Determined NO to 230 kV switchyard voltage greater than Table 1 Normal Transfer Level (230 vs 231)

NOTE: Candidate may not explicitly mark up attachment but will have verified the next two steps as part of reaching the conclusion that 230 kV is inoperable (Determined Electrical Configuration is 3, Power, from attachment 1)

(Determined NO to Comp actions complete)

Determined 230 kV inoperable NOTE: candidate may add comp measures that could be taken to make 230 kV OPERABLE. This is NOT part of the grading criteria. If their answer is based on the comp measures, tell student to refer to their initial cue.

2. Any LCO 3.8.1 Action(s) in effect (all required):

Action A Action B Action D

    • Denotes Critical Step and SubSteps Page 4 of 5 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-A7 Initial GIVEN:

Conditions: Both Unit 1 and 2 are at 100% power Emergency Diesel Generator 1-2 is declared inoperable Two minutes after Diesel Generator 1-2 is declared inoperable, an earthquake causes a grid disturbance Grid Control reports:

o loss of the Morro Bay-Diablo Canyon 230 kV line o 230 kV voltage is 230 kV o Los Padres Area Load is 350 MW o DCPP has 0 capacitors in service and none available o Mesa has 4 capacitors and 1 transformer in service No operator compensatory actions have been taken No LCO ACTION(s) have been entered for any of the above conditions LTC is in AUTO 52VU11 is OPEN Initiating Cue: You are instructed to:

Using OP J-2:VIII, Guidelines for Reliable Transmission Service for DCPP, Attachment 2, 230kV Offsite Power Operability Evaluation - LTC IN AUTO, determine the OPERABILITY of 230 kV at this time (show your work)

For the given conditions, determine all applicable LCO ACTION(s) to Unit 1, should any exist.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

Examinee Response

1. 230 kV is inoperable or OPERABLE Basis:
2. LCO Action(s), if any, in effect:

Page 5 of 5 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181A8

Title:

Authorize Emergency Exposure Examinee:

Evaluator:

Print Signature Date Testing Method: Perform X Simulate Results: Sat Unsat Total Time: minutes Comments: Designed for SRO candidates in a classroom setting.

References:

EP RB2 Emergency Exposure Guidelines, Rev 8.

Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: See Examinee Response Key Job Designation: SRO Rev Comments Modified Bank Gen KA # G2.3.4 - Knowledge of radiation exposure limits under normal 3.7 or emergency conditions.

AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/05/20 REV. 2

JPM TITLE: Authorize Emergency Exposure JPM NUMBER: NRCL181A8 EVALUATOR WORKSHEET Directions: All actions taken by the examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed.

After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the step at which to begin.

Required Materials: EP RB2 Emergency Exposure Guidelines, Rev 8.

Completed Emergency Exposure Permits for volunteers (Handout 1)

Initial Conditions: GIVEN:

Both Units were operating at 100% power when a large seismic event occurred resulting in a faulted/ruptured steam generator (S/G 13) on Unit 1.

There is evidence of fuel damage.

MSIV FCV43 has failed open and a break downstream of the MSIV is causing S/G 13 to blow down in the 115 pen area.

The Shift Manager has declared a general emergency, FG1.1, for the loss of all three fission product barriers.

Volunteers have been found to undertake two high priority emergency field activities and the Site Radiation Protection Coordinator has forwarded their associated Emergency Exposure Permits for SEC approval.

Initiating Cue: The Shift Manager directs you to review each completed permit and determine whether or not it should be approved.

Document your recommendations as well as their basis in the space provided below before reporting out NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references. .

NRCL181A8 r2.docx PAGE 2 OF 6 REV. 2

JPM TITLE: Authorize Emergency Exposure JPM NUMBER: NRCL181A8 EVALUATOR WORKSHEET Task Standard: DO NOT READ TASK STANDARD TO EXAMINEE Wayne permit should NOT be authorized - anticipated TEDE was incorrectly calculated as 4.75 REM. The actual anticipated dose is 5.3125 REM which is above the 5 REM sampling limit.

Banner permit should NOT be authorized - Voluntary consent signature line is marked N/A. Voluntary consent signature IS required for a NO LIMIT exposure authorization.

Start End Time: Time:

Followup Question Documentation:

Question: ____________________________________________________________________

Response: ____________________________________________________________________

NRCL181A8 r2.docx PAGE 3 OF 6 REV. 2

JPM TITLE: Authorize Emergency Exposure JPM NUMBER: NRCL181A8 ANSWER KEY Examinee Response KEY Volunteer Approve? Basis for Approval or Rejection Anticipated TEDE was incorrectly calculated as 4.75 REM.

Wayne NO The actual anticipated dose is 5.3125 REM which is above the 5 REM sampling limit.

Requested NO LIMIT exposure is allowable for the associated Banner NO activity type, but the volunteers signature line is incorrectly marked N/A. Volunteer signature is required to acknowledge he/she is fully aware of the risks. (Permit request is for a lifesaving activity, but is missing the volunteers signature).

NRCL181A8 R2.DOCX PAGE 4 OF 6 REV. 2

JPM TITLE: Authorize Emergency Exposure JPM NUMBER: NRCL181A8 EXAMINEE CUE SHEET Initial Conditions: GIVEN:

Both Units were operating at 100% power when a large seismic event occurred resulting in a faulted/ruptured steam generator (S/G 13) on Unit 1.

There is evidence of fuel damage.

MSIV FCV43 has failed open and a break downstream of the MSIV is causing S/G 13 to blow down in the 115 pen area.

The Shift Manager has declared a general emergency, FG1.1, for the loss of all three fission product barriers.

Volunteers have been found to undertake two high priority emergency field activities and the Site Radiation Protection Coordinator has forwarded their associated Emergency Exposure Permits for SEC approval.

Initiating Cue: The Shift Manager directs you to review each completed permit and determine whether or not it should be approved.

Document your recommendations as well as their basis in the space provided below before reporting out NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references. .

NRCL181A8 R2.DOCX PAGE 5 OF 6 REV. 2

JPM TITLE: Authorize Emergency Exposure JPM NUMBER: NRCL181A8 EXAMINEE CUE SHEET EXAMINEE RESPONSE Volunteer Approve? Basis for Approval or Rejection Wayne Banner NRCL181A8 R2.DOCX PAGE 6 OF 6 REV. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181A9

Title:

Review Emergency Notification for Steam Generator Tube Rupture Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

EP G3, Emergency Notification of OffSite Agencies, Rev 61 Alternate Path: Yes No X Time Critical: Yes X No Time Allotment: 15 minutes Critical Steps: Per Examinee Response Key Job Designation: SRO Rev Comments: New G2.4.40 - Knowledge of SRO responsibilities in emergency plan Gen KA # / Rating: implementation. 4.5 AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE: CHRIS MEHIGAN DATE: 02/05/20 Rev.2

JPM TITLE: Review Emergency Notification for Steam Generator Tube Rupture JPM NUMBER: NRCL181A9 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly documented. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure (as applicable) and told the steps with which to begin.

Required Materials: EP G3, Emergency Notification of OffSite Agencies, Rev 61 Initial Conditions: GIVEN:

At 1055, U1 initiated a manual SI due to SGTR RCS temperature is 514°F At 1100, the SM declared FA1.1 The ENF program is not working The WCSFM has manually prepared the Emergency Notification Form for FA1.1 NOTE: for the purposes of this JPM, this is a Drill Initiating Cue: You are directed to review the Emergency Notification Form for the SM to determine if it should be approved, identifying all error should any exist.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

This JPM IS Time Critical NOTE: Do NOT provide examinee with Task Standard Task Standard: Box 6 should be "1100" - based on time of declaration given in Initial Conditions (refer to completed ENF form) Box 8 should be "Radiological Release in progress" - based on item 5, SGTR is a condition attributable to the emergency event Box 10 should be "No PAR" based on emergency classification being less than a General Emergency Start Time:

Stop Time:

Total Time: (Enter total time on the cover page - Time Limit: 15 minutes)

Page 2 of 5 Rev.2

JPM TITLE: Review Emergency Notification for Steam Generator Tube Rupture JPM NUMBER: NRCL181A9 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

Page 3 of 5 Rev.2

JPM TITLE: Review Emergency Notification for Steam Generator Tube Rupture JPM NUMBER: NRCL181A9 INSTRUCTOR WORKSHEET Examinee Response Key See Marked up form - next page Page 4 of 5 Rev.2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181A9 Initial Conditions: GIVEN:

At 1055, U1 initiated a manual SI due to SGTR RCS temperature is 514°F At 1100, the SM declared FA1.1 The ENF program is not working The WCSFM has manually prepared the Emergency Notification Form for FA1.1 NOTE: for the purposes of this JPM, this is a Drill Initiating Cue: You are directed to review the Emergency Notification Form for the SM to determine if it should be approved, identifying all error should any exist.

NOTE:

You may use any source of information normally available (procedures, prints, etc.).

Classroom instruction materials (Lesson Plans, System Training Manuals, PowerPoint presentations, classroom notes, etc.) are not permitted to be used.

If there is a question regarding reference material desired to be used, ask evaluator prior to seeking references.

This JPM IS Time Critical Page 5 of 5 Rev.2

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Diablo Canyon Date of Examination: 02/24/2020 Exam Level: RO SRO-I SRO-U Operating Test Number: L181 Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U System/JPM Title Type Code* Safety Function

a. (S1) (001.A2.11) Dropped Rods During Rod Misalignment Verification A,M,S 1 (Modified LJC-066)
b. (S2) (013.A2.01) Resp to Changing Plant Params During Rx Trip Resp A,N,EN,L,S 2
c. (S3) (E04.EA1.1) Isolate LOCA Outside Containment (Bank LJC-118) D,L,S 3
d. (S4P) (011.EA1.11) Transfer to Cold Leg Recirc (Bank LJC-27A) A,D,L,S 4P
e. (S4S) (059.A2.07) Perform OP AP-15 Immediate Actions for MFP Trip A,D,S 4S (Bank LJC-247)
f. (S5) (E14.E1.2) Manually Initiate Containment Spray (Bank LJC-010) D,L,S 5
g. (S6) (064.A4.06) Crosstie Vital Bus G to H (LJC-032) D,L,S 6
h. (S8) (067.AA2.17) Fire in 480V Bus G Switchgear Room A,N,S 8 In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U
i. (P1) (010.A2.02) Transfer Pzr Heater Grp 23 to Backup Pwr (LJP-029A) D 3
j. (P2) (062.A2.11) Transfer the TSC to Vital Power(LJP-058A) A,D,E,L 6
k. (P3) (G2.1.30) Clear Component Cooling Water Header "A" E,L,N,R 8
  • 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, and in-plant systems and functions may overlap those tested in the control room.
  • Type Codes Criteria for R /SRO-I/SRO-U (A)lternate path 4-6/4-6 /2-3 (C)ontrol room (D)irect from bank 9/ 8/ 4 (E)mergency or abnormal in-plant 1/ 1/ 1 (EN)gineered safety feature 1/ 1/ 1 (control room system)

(L)ow-Power/Shutdown 1/ 1/ 1 (N)ew or (M)odified from bank including 1(A) 2/ 2/ 1 (P)revious 2 exams 3/ 3/ 2 (randomly selected)

(R)CA 1/ 1/ 1 (S)imulator Rev 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Diablo Canyon Date of Examination: 02/24/2020 Exam Level: RO SRO-I SRO-U Operating Test Number: L181 Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U System/JPM Title Type Code* Safety Function

a. (S1) (001.A2.11) Dropped Rods During Rod Misalignment Verification A,M,S 1 (Modified LJC-066)
b. (S2) (013.A2.01) Resp to Changing Plant Params During Rx Trip Resp A,N,EN,L,S 2
c. (S3) (E04.EA1.1) Isolate LOCA Outside Containment (Bank LJC-118) D,L,S 3
d. (S4P) (011.EA1.11) Transfer to Cold Leg Recirc (Bank LJC-27A) A,D,L,S 4P
e. (S4S) (059.A2.07) Perform OP AP-15 Immediate Actions for MFP Trip A,D,S 4S (Bank LJC-247)
f. (S5) (E14.E1.2) Manually Initiate Containment Spray (Bank LJC-010) D,L,S 5 g.
h. (S8) (067.AA2.17) Fire in 480V Bus G Switchgear Room A,N,S 8 In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U
i. (P1) (010.A2.02) Transfer Pzr Heater Grp 23 to Backup Pwr (LJP-029A) D 3
j. (P2) (062.A2.11) Transfer the TSC to Vital Power(LJP-058A) A,D,E,L 6
k. (P3) (G2.1.30) Clear Component Cooling Water Header "A" E,L,N,R 8
  • 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, and in-plant systems and functions may overlap those tested in the control room.
  • Type Codes Criteria for R /SRO-I/SRO-U (A)lternate path 4-6/4-6 /2-3 (C)ontrol room (D)irect from bank 9/ 8/ 4 (E)mergency or abnormal in-plant 1/ 1/ 1 (EN)gineered safety feature 1/ 1/ 1 (control room system)

(L)ow-Power/Shutdown 1/ 1/ 1 (N)ew or (M)odified from bank including 1(A) 2/ 2/ 1 (P)revious 2 exams 3/ 3/ 2 (randomly selected)

(R)CA 1/ 1/ 1 (S)imulator Rev 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Facility: Diablo Canyon Date of Examination: 02/24/2020 Exam Level: RO SRO-I SRO-U Operating Test Number: L181 Control Room Systems:* 8 for RO, 7 for SRO-I, and 2 or 3 for SRO-U System/JPM Title Type Code* Safety Function

a. (S1) (001.A2.11) Dropped Rods During Rod Misalignment Verification A,M,S 1 (Modified LJC-066)
b. (S2) (013.A2.01) Resp to Changing Plant Params During Rx Trip Resp A,N,EN,L,S 2 c.

d.

e.

f.

g.

h.

In-Plant Systems:* 3 for RO, 3 for SRO-I, and 3 or 2 for SRO-U

i. (P1) (010.A2.02) Transfer Pzr Heater Grp 23 to Backup Pwr (LJP-029A) D 3
j. (P2) (062.A2.11) Transfer the TSC to Vital Power(LJP-058A) A,D,E,L 6
k. (P3) (G2.1.30) Clear Component Cooling Water Header "A" E,L,N,R 8
  • 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, and in-plant systems and functions may overlap those tested in the control room.
  • Type Codes Criteria for R /SRO-I/SRO-U (A)lternate path 4-6/4-6 /2-3 (C)ontrol room (D)irect from bank 9/ 8/ 4 (E)mergency or abnormal in-plant 1/ 1/ 1 (EN)gineered safety feature 1/ 1/ 1 (control room system)

(L)ow-Power/Shutdown 1/ 1/ 1 (N)ew or (M)odified from bank including 1(A) 2/ 2/ 1 (P)revious 2 exams 3/ 3/ 2 (randomly selected)

(R)CA 1/ 1/ 1 (S)imulator Rev 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS1

Title:

Verify Misaligned Rod Is Not Stuck Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

OP AP12B, Control Rod Misalignment, Rev. 19 (include Appendix B)

References:

OP AP12C, Dropped Control Rod, Rev. 17 Alternate Path: Yes X No Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: 3.1, 5.1, 5.2, 7.2 Job Designation: RO/SRO Rev Comments/LRN TIPS: Modified from DCPP Bank: LJC066 DCPP Task # / Rating: 80200 4.0 Gen KA # / Rating: 001.A2.03 - Ability to (a) predict the impacts of the following 3.5 / 4.2 malfunction or operations on the CRDS and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: effect of stuck or misaligned rod.

AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator.

The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: OP AP12B, Control Rod Misalignment (Including Appendix B)

OP AP12C, Dropped Control Rod Initial Conditions: Given:

Unit 1 is at approximately 75% power and was in the process of being returned to 100% following curtailment for condenser cleaning.

The power increase was stopped 5 minutes ago when control rod K2 was observed to be greater than 12 steps below the other Control Bank D rods based on DRPI.

Procedure OP AP12B, Control Rod Misalignment, has been implemented.

Initiating Cue: The Shift Foreman directs you to perform Step 14 of OP AP12B.

NOTE: Do NOT provide examinee with Task Standard Task Standard: Determined control rod K2 is NOT stuck by performing the following actions:

o Turned the ROD BANK/MODE SELECT switch to the CBD position o Inserted rods for Control Bank D until a DRPI change on rod K2 is observed Manually tripped reactor before Control Bank D is restored to original demand position recorded on step 2.1 of this JPM.

    • Denotes Critical Step and SubSteps Page 2 of 8 Rev. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. AP12B, Step 14.a Check Grp 1 and grp 2 of 1.1 Read CAUTIONS and NOTE prior to Step 14.a. If each bank - at the same step on demand step asked about RIL, then state the "Another counter. operator will monitor RIL" 1.2 Checked both groups of bank D at the same step as the demand counter.

Step was: Sat __________ Unsat __________

Comments:

NOTE: All positions may be recorded, but are not required.

2. AP12B, Step 14.b Record the bank demand 2.1 Recorded Control Bank D demand position.

positions.

Step was: Sat __________ Unsat __________

Comments:

    • 3. AP12B, Step 14.c Rotate the Rod Bank ** 3.1 Turned the ROD BANK/MODE SELECT switch to Selector Switch to the AFFECTED BANK. the CBD position.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 8 Rev. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

4. AP12B, Step 14.d Record the plant process 4.1 Displayed the Control Bank D position from the computer position for the affected bank. plant computer and records the value.

NOTE: Operator may call up the CBD address listed in App. B of AP12B (U0052), or record the value from an existing group display.

Step was: Sat __________ Unsat __________

Comments:

    • 5. AP12B, Step 14.e,f Drive the affected bank ** 5.1 Inserted rods for Control Bank D until a DRPI in several steps (enough to see a DRPI change is observed.

change).

    • 5.2 Identified that rod K2 moves and diagnoses that rod K2 is not stuck.

5.3 Reported status to Shift Foreman.

NOTE: Status of control rod may be reported after rod restored to its recorded position.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 8 Rev. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

6. AP12B, Step 14.g Return the rods in the 6.1 Attempted to move rods back out to original affected bank to the position recorded in Step position.

14.b.

<< Alternate Path - Start Point >>

NOTE: Second rod will drop will drop upon entry into OP AP12C, "Dropped Control Rod" or after a 30 second delay - whichever comes first.

6.2 Identified single control rod dropped (K02) during restoration of Control Bank D.

6.3 Implemented OP AP12C, "Dropped Control Rod" Step was: Sat _________ Unsat _________

Comments:

Dropped.

Step 1 RNO Trip the Reactor and GO TO EOP E0, "Reactor Trip or Safety Injection"

    • 7.2 Tripped the Reactor.

<< Alternate Path - End Point >>

Step was: Sat _________ Unsat _________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 5 of 8 Rev. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 6 of 8 Rev. 2

JPM TITLE: Verify Misaligned Rod Is Not Stuck JPM NUMBER: NRCL181LJCS1 ATTACHMENT 1, SIMULATOR SETUP Restore IC155 (customized IC built for L181 Exam administration only).

Run Lesson file NRCL181LJCS1.lsn OR Restore the simulator to IC11 (75%, MOL).

Enter Lesson file L181LJCS1 with setup.lsn Description L3 Commands Sets rod k2 15 steps below Bank D insert MAL_ROD3_K02 MOVEABLE delay=0 ramp=0 label ROBERPPCDGRP2NDRF 12 label ROBERPPCDGRP2DRFT(4) 1 label ROBERPPCDGRP2RSPD 1 insert C1_085S_5 1 delay=0 ramp=0 insert C1_086S_1 1 delay=0 ramp=0 delIA MAL_ROD3_K02 2 delay=1 cd='c1_086s_1' delIA C1_086S_1 2 delay=1 cd=

delIA C1_085S_5 2 delay=2 cd=

Freeze Sim after 60 seconds to unfreeze allow for temperature transient freeze delay=60 Drop two rods on Rod Cntl Out insert MAL_ROD3_K02 STATIONARY delay=2 cd='c1_086s_3' insert MAL_ROD3_P10 STATIONARY delay=30 cd='c1_086s_3' FOR ALL SETUPS Verify Sim has run long enough for Tave to settle.

Place Rod Control Switch to Manual after simulator goes to freeze.

Set PPC screen at SRO desk to RBU display (rodconfig).

Verify step counters matched (group 1 and 2) and RBU are updated to current CBD rod position.

Place pink tag for RODS IN MANUAL on CC1.

Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet.

Page 7 of 8 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181LJCS1 Initial Conditions: Given:

Unit 1 is at approximately 75% power and was in the process of being returned to 100%

following curtailment for condenser cleaning.

The power increase was stopped 5 minutes ago when control rod K2 was observed to be greater than 12 steps below the other Control Bank D rods based on DRPI.

Procedure OP AP12B, Control Rod Misalignment, has been implemented.

Initiating Cue: The Shift Foreman directs you to perform Step 14 of OP AP12B.

Page 8 of 8 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS2

Title:

Respond to Changing Plant Parameters During Reactor Trip Response Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

EOP E0.1, Reactor Trip Response, Rev 43 Alternate Path: Yes X No Time Critical: Yes No X Time Allotment: 5 minutes Critical Steps: 2.4, 6.2 Job Designation: RO/SRO Rev Comments/LRN TIPS: New DCPP Task # / Rating: 47080 Gen KA # / Rating: 013.A2.01 - Ability to (a) predict the impacts of the following 4.6 / 4.8 malfunction or operations on the ESFAS system and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations: LOCA.

Directions: All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator.

The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: EOP E0.1, Reactor Trip Response, Rev 43 (with Fold Out Pages)

Initial Conditions: Given:

Unit 1 experienced an inadvertent Reactor Trip. The cause is presently unknown.

The Crew has completed EOP E0 and has now transitioned to EOP E0.1, Reactor Trip Response.

Initiating Cue: The Shift Foreman directs you to begin implementation of EOP E0.1, beginning with Step 1.

You are responsible for all procedure actions including Appendices and Foldout Page items.

NOTE: Do NOT provide examinee with Task Standard Task Standard: Provided greater than 435 gpm Aux Feedwater Flow by starting any of the following:

MDAFW Pump 12 and/or MDAFW Pump 13 and/or TDAFW Pump 11 Before RCPs secured in EOP FRH.1 Manually actuated Safety Injection before subcooling falls below 0oF

    • Denotes Critical Step and SubSteps Page 2 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. E0.1, Step 1 Check RCS Temperature 1.1 Checked RCPs running.

Response - Stable or trending to 547 oF.

1.2 Determined RCS temperature was NORMAL.

Step was: Sat __________ Unsat __________

Comments:

    • 2. E0.1, Step 2 Check Fdwtr Status. 2.1 Checked RCS temperature less than 554oF.

2.2 Checked Feedwater Isolation complete:

Red Activated Light - ON White Status Light OFF NOTE: AFW pump autostarts have been disabled.

2.3 Determined total AFW flow was NOT greater than 435 gpm.

    • 2.4 Started one or more AFW pumps:

MDAFW Pump 12 and/or MDAFW Pump 13 and/or TDAFW Pump 11 Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET Step Expected Operator Actions NOTE: Candidate may respond to indications of a LOCA based on Fold Out Page and not complete checks for Control Rod Insertion and Pressurizer Level Control

3. E0.1, Step 3 - Check all Control Rods fully 3.1 Determined all control rods fully inserted.

inserted.

Step was: Sat __________ Unsat __________

Comments:

4. E0.1, Step 4 - Check PZR Level Controls 4.1 Determined pressurizer level NOT greater than 17%.

4.2 Determined auto isolation of letdown had already occurred.

4.3 Determined pressurizer heaters already off due to low pressurizer level.

4.4 Increased charging flow to maximum by throttling FCV128 full open.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET Step Expected Operator Actions

<< Alternate Path - Start Point >>

NOTE: Any of the following may be used to identify SBLOCA.

5. Identifies multiple indications of a small break 5.1 Identified indications of Small Break LOCA:

LOCA. RCS Pressure lowering Pressurizer level lowering Subcooling lowering Containment sump levels rising Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 5 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 6. Implements Fold Out Page Item #2 NOTE: Auto Safety Injection signal for low RCS pressure (1850 psig) has been disabled 6.1 Determined either Safety Injection Criteria for Fold Out Page Item #2 met:

RCS Subcooling based on Core Exit Thermocouples - Less than 20oF PZR Level - Cannot be maintained greater than 6%

OR RCS Pressure below auto SI setpoint of 1850 psig.

    • 6.2 Manually actuated Safety Injection 6.3 Informed Shift Foreman transition to EOP E0, Reactor Trip or Safety Injection is required.

<< Alternate Path - End Point >>

Step was: Sat __________ Unsat __________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 6 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 7 of 9 Rev. 1

JPM TITLE: Respond to Changing Plant Parameters During Reactor Trip Response JPM NUMBER: NRCL181LJCS2 ATTACHMENT 1, SIMULATOR SETUP Restore IC156 (customized IC built for L181 Exam administration only). No lesson file is required.

OR Restore the simulator to IC12 (50%, MOL).

Enter Lesson file L181LJCS2 Description L3 Commands Fails Auto SI insert MAL_PPL3A AUTO insert MAL_PPL3B AUTO Trip Rx and reset rods insert C1_072S_3 1 delIA C1_072S_3 2 delay=2 cd=

insert C1_064S_1 1 delIA C1_064S_1 2 delay=2 cd=

Freeze Sim after 60 seconds to unfreeze allow for temperature transient freeze delay=60 RCS leak (triggered on AFW pump insert MAL_RCS3B 2.5 cd='h_v3_221r_1 or h_v3_222r_1' start) delay=0 ramp=30 Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet.

Page 8 of 9 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181LJCS2 Initial Conditions: Given:

Unit 1 experienced an inadvertent Reactor Trip. The cause is presently unknown.

The Crew has completed EOP E0 and has now transitioned to EOP E0.1, Reactor Trip Response.

Initiating Cue: The Shift Foreman directs you to begin implementation of EOP E0.1, beginning with Step 1. You are responsible for all procedure actions including Appendices and Foldout Page items.

Page 9 of 9 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181S3

Title:

Isolate a LOCA Outside Containment Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ __________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

EOP ECA1.2, LOCA Outside Containment, Rev. 6C Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: 3.1, 3.2, 3.4 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank: LJC118 DCPP Task # / Rating: 111200, 886600 3.8 / 3.5 Gen KA # / Rating: E04.EA1.1 - Ability to operate and/or monitor components and 4.0 / 4.0 functions of control and safety systems including instrumentation, signals, interlocks, failure modes, and automatic and manual features as they apply to a LOCA Outside Containment.

AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 1

JPM TITLE: Isolate a LOCA Outside Containment JPM NUMBER: NRCL181S3 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator.

The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: EOP ECA1.2, LOCA Outside Containment Initial Conditions: Given:

Unit 1 has experienced a Safety Injection Automatic actuation of safeguards equipment was verified It was determined that SI cannot be terminated and abnormal radiation has been observed in the Auxiliary Building Initiating Cue: The Shift Foreman directs you to perform the actions for a LOCA outside containment, in accordance with ECA1.2, starting on step 1.

DO NOT READ TASK STANDARD TO EXAMINEE Task Standard: Completed actions to isolate LOCA outside containment and identify the correct procedure for recovery as follows:

Cut in series contactor toggle switch for 8809B Closed 8809B, RHR to cold legs 3 and 4 Transitioned to correct EOP procedure - EOP E1, Loss of Reactor or Secondary Coolant

    • Denotes Critical Step and SubSteps Page 2 of 7 Rev. 1

JPM TITLE: Isolate a LOCA Outside Containment JPM NUMBER: NRCL181S3 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. EOP ECA1.2, Step 1 - Verify Proper Valve 1.1 Determined following valves are in the correct Alignment. position:

8702, RCS RHR Suct LP4 HL - CLOSED 8701, RCS RHR Suct LP4 HL - CLOSED 8703, RHR to hot legs 1 and 2 - CLOSED 8802A, SI to hot legs 1 and 2 - CLOSED 8802B, SI to hot legs 3 and 4 - CLOSED Step was: Sat __________ Unsat __________

Comments:

2. EOP ECA1.2, Step 2.a.1 - Try To Identify And 2.1 Cut in series contactor toggle switch for 8809A.

Isolate Break (RHR cold legs 1 and 2) 2.2 Closed 8809A, RHR to cold legs 1 and 2.

2.3 Diagnosed RCS pressure still lowering.

2.4 Reopened 8809A.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 7 Rev. 1

JPM TITLE: Isolate a LOCA Outside Containment JPM NUMBER: NRCL181S3 INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 3. EOP ECA1.2, Step 2.a.2 - Try To Identify And ** 3.1 Cut in series contactor toggle switch for 8809B.

Isolate Break (RHR cold legs 3 and 4)

    • 3.2 Closed 8809B, RHR to cold legs 3 and 4.

3.3 Determined RCS pressure stable or rising.

    • 3.4 Identified EOP E1 as correct procedure for recovery.

Step was: Sat __________ Unsat __________

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 4 of 7 Rev. 1

JPM TITLE: Isolate a LOCA Outside Containment JPM NUMBER: NRCL181S3 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 5 of 7 Rev. 1

JPM TITLE: Isolate a LOCA Outside Containment JPM NUMBER: NRCL181S3 ATTACHMENT 1, SIMULATOR SETUP Restore IC157 (customized IC built for L181 Exam administration only). No lesson file is required.

OR Restore the simulator to IC10.

Run Lesson file drl_1118 or manually enter the following:

Command Description Insert v2_225r_1 0, insert v2_225g_1 1 8701 Green ON, Red OFF Insert v2_226r_1 0, insert v2_226g_1 1 8702 Green ON, Red OFF Insert vlv_rhr1_2 1, label rrhh8701 0.5 8702 OPEN, 8701 to 50%

(closes when 8809B is Insert vlv_rhr1_2 0 cd=rrhh8809_2 lt 0.1 ramp=1 CLOSED)

Insert mal_rhr1 400 ramp=5 RHR system leak delIA mal_rhr1 2 delay=100 Insert c2_030s_2 1, delIA c2_032s_2 2 delay=5 Actuates SI Insert v2_266s_1 1 delay=15 Stops CCP 13 Insert v2_266s_1 2 delay=20 Insert v4_388s_3 1 delay=15 ABV Char Htr ON Insert v4_388s_1 0 Insert v3_179s_2 0 Stops all but one CB PP set Insert v3_224s_1 1, Insert v3_225s_1 1 delIA v3_224s_1 2 delay=60 delIA v3_225s_1 2 delay=60 Insert v3_257s_1 1 delay=150, delIA v3_257s_1 2 delay=180 Closes ALL TDAFP LCVs Insert v3_258s_1 1 delay=150, delIA v3_258s_1 2 delay=180 Insert v3_259s_1 1 delay=150, delIA v3_259s_1 2 delay=180 Insert v3_260s_1 1 delay=150, delIA v3_260s_1 2 delay=180 (only if lesson file NOT RUN) throttle AFW to 150 gpm/SG Throttle AFW (manually)

RUN, then FRZ after 4 minutes RUN for 4 minutes Reset SI, Reset Phase A Isolation, Open FCV584 during 4 minute run.

Scroll chart PR403 forward so operator has a reference point for RCS pressure trends.

Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet.

Page 6 of 7 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181S3 Initial Conditions: Given:

Unit 1 has experienced a Safety Injection Automatic actuation of safeguards equipment was verified It was determined that SI cannot be terminated and abnormal radiation has been observed in the Auxiliary Building Initiating Cue: The Shift Foreman directs you to perform the actions for a LOCA outside containment, in accordance with ECA1.2, starting on step 1.

Page 7 of 7 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS4P

Title:

TRANSFER TO COLD LEG RECIRCULATION Examinee: ____________________________________________

Evaluator: ____________________________ ________________________________ __________________

Print Signature Date Testing Method: Perform _______X________ Simulate _______________

Results: Sat __________ Unsat __________ Total Time: __________ TCOA Time: ___________

Comments: (Note: Any Unsat step requires a numbered comment; use back as needed.)

EOP E1.3, Transfer to Cold Leg Recirculation, Rev. 34

References:

OP1.ID2, Time Critical/Sensitive Operator Action, Rev. 12 Alternate Path: Yes ______X _ No Time Critical: Yes X No Time Allotment: 10 minutes 2.2, 2.5, 3.2, 4.1, 5.1, 5.3, 6.2, 6.4, 7.2, 7.4, 10.1, 10.3, 11.3, Critical Steps:

11.6, 11.7 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank LJC027A 3.5 / 4.5 / 4.0 / 4.0 /

DCPP Task # / Rating: 331200, 43200, 324800, 323600, 324600 4.0 (all RO) 011.EA1.1 - Ability to operate and/or monitor components and functions of the control and safety systems including Gen KA # / Rating: 4.2 / 4.2 instrumentation, signals, interlocks, failure modes, and automatic and manual features.

UTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by the examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. If the task is being done in the plant or lab, and after identifying the appropriate procedure for the task, the examinee may be given the procedure and told what step to begin the task at.

Required Provide a copy of the reference procedure (partial procedure allowed), if the task is Materials: being done in the plant or lab.

Initial Conditions: Given:

Unit 1 experienced a LBLOCA and RWST level is approaching 33%.

Initiating Cue: The Shift Foreman directs you to preview and perform EOP E1.3 to align RHR for cold leg recirculation starting at step 1.

This is a time critical JPM.

NOTE: Do NOT provide examinee with Task Standard Task Standard: RHR has been aligned to the suction of the SI pumps and CCPs for cold leg recirculation by performing the following:

Stopped RHR Pump 11 Closed 8700A Closed 8716A and B Closed 8974A and B (only 1 of 2 required; series valves)

Closed 8105 and 8106 (only 1 of 2 required; series valves)

Opened 8807A and B (only 1 of 2 required; parallel valves)

Opened 8982A Restarted RHR Pump 11 Opened 8804A Within the 10 minutes of JPM start time.

Time Critical This JPM was evaluated against TCOA #8 - Operator must transfer to cold leg Operator Action recirculation within 10 minutes of the RWST reaching the low level setpoint which (TCOA): corresponds to the start time of this JPM. Case 2 - one RHR pump (12) does not trip and cannot be stopped from the control room for up to 5 minutes after the RWST reaches 33%.

TCOA start time is when RWST reaches 33% as indicated by PK 0301 coming into alarm.

TCOA stop time is when 8804A indicates full open (RED light on, Green light OFF).

This TCOA is applicable to this JPM; the appropriate steps will be designated as critical and the TCOA will be designated time critical.

Page 2 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions Note the time PK0301, RWST VLV CLSD/LVL HI LOW, comes into alarm (TCOA start time):

1. E1.3, Step 1 Implement Appendix EE. 1.1 Read note regarding FR procedures.

1.2 Assigned operator to complete Appendix EE.

Note: Actions for Appendix EE have already been completed in the setup for this JPM.

Cue: Using time compression, Appendix EE is complete".

Step was: Sat _________ Unsat __________

Comments:

    • 2. E1.3, Step 2 Ensure RHR PP 12 stopped. 2.1 Observed that both RHR pumps were running (red light ON and/or amps indicated).

<< Alternate Path - Start Point >>

    • 2.2 Secured RHR PP 11.

2.3 Attempted to secure RHR PP 12.

2.4 Dispatched a Nuclear Operator to locally open the breaker for RHR PP 12 (52HH11).

    • 2.5 Skipped to E1.3, step 4 (Did NOT close 8700B).

Step was: Sat _________ Unsat __________

Comments:

Page 3 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 3. E1.3, step 4 - Ensure RHR PP 11 stopped. 3.1 Observed that RHR PP 11 was running (red light ON and/or amps indicated).
    • 3.2 Secured RHR PP 11 with control switch (green light ON, and/or no amps indicated).

<< Alternate Path - End Point >>

Step was: Sat _________ Unsat __________

Comments:

    • 4. E1.3, step 5 Close 8700A, RHR pump 1 ** 4.1 Closed 8700A.

normal suction valve.

4.2 Observed green light (only) ON for 8700A.

Step was: Sat __________ Unsat __________

Comments:

    • 5. E1.3, step 6 Close 8716A and B, RHR ** 5.1 Closed 8716A.

pump discharge crosstie valves.

5.2 Observed green light (only) ON for 8716A.

    • 5.3 Closed 8716B.

5.4 Observed green light (only) ON for 8716B.

Step was: Sat __________ Unsat __________

Comments:

Page 4 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 6. E1.3, step 7 Isolate ECCS PPs Recirc Paths. 6.1 Observed RCS Pressure is < 1500 psig (VB2, any PPC).

Note: Valves are in series. Only one is required closed to meet the critical step criteria.

    • 6.2 Closed 8974A.

6.3 Observed green light (only) ON for 8974A.

    • 6.4 Closed 8974B.

6.5 Observed green light (only) ON for 8974B.

Step was: Sat __________ Unsat __________

Comments:

    • 7. E1.3, step 7 Isolate ECCS PPs Recirc Paths 7.1 Note: Valves are in series. Only one is required (cont) closed to meet the critical step criteria.
    • 7.2 Closed 8105.

7.3 Observed green light (only) ON for 8105.

    • 7.4 Closed 8106.

7.5 Observed green light (only) ON for 8106.

Step was: Sat __________ Unsat __________

Comments:

8. E1.3, step 8 Check Containment Recirc 8.1 Observed Containment Recirc Sump Level > 92' Sump Level. on LI940 & 941.

Step was: Sat __________ Unsat __________

Page 5 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Comments:

Step Expected Operator Actions

9. E1.3, step 9 - Verify RHR PP 12 Alignment. 9.1 Observed that RHR PP 12 was running (red light ON and/or amps indicated).

<< ALTERNATE PATH START POINT >>

9.2 Skipped to E1.3, step 10.

Step was: Sat __________ Unsat __________

Comments:

    • 10. E1.3, step 10 Crosstie SI PP suction to Note: Valves are in parallel. Only one is required CCPs. open to meet the critical step criteria.
    • 10.1 Opened 8807A.

10.2 Observed red light (only) ON for 8807A.

    • 10.3 Opened 8807B.

10.4 Observed red lights (only) ON for 8807B.

10.5 Observed both ECCS CCPs are running (red lights ON).

<< ALTERNATE PATH END POINT >>

Step was: Sat _______ Unsat __________

Comments:

Page 6 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Step Expected Operator Actions

11. E1.3, step 11 Verify RHR PP 11 11.1 Observed that RHR PP 11 is not running (green Alignment. light ON and/or no amps).

11.2 Observed green light (only) ON for 8700A.

    • 11.3 Opened 8982A.

11.4 Observed red light (only) ON for 8982A.

11.5 Verified RHR HX 11 in service per App EE.

Cue: App EE has been completed. Both RHR HXs are in service per the appendix.

    • 11 E1.3, step 11 Verify RHR PP 11 11.6 Started RHR pump 11.

Alignment (continued)

    • 11.7 Opened 8804A.

Note the time 8804A indicated full OPEN (TCOA stop time):

Step was: Sat __________ Unsat __________

Comments:

12. E1.3, step 12 Check at least one RHR PP **********************************

running in Cold Leg Recirc Lineup. Cue: The SFM has assigned other operators to complete this procedure.

Stop Time:

Total Time: (Enter total time on the cover page)

Page 7 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Note: See page 1 for TCOA start/stop description.

TCOA Start Time PK0301 came into alarm Time:

TCOA Stop Time 8804A indicated full OPEN Time:

TCOA Total (Enter TCOA time on the cover page)

Time:

TCOA: SAT UNSAT (TCOA time must be < 10 minutes)

Page 8 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: __________________________________________________________________

Page 9 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P ATTACHMENT 1, SIMULATOR SETUP Initialize to JPM Custom IC158.

Execute lesson NRCL181LJC4SP.lsn.

This SNAP allows entry into EOP E1.3 at Step 1. RWST level is slightly above 33%.

Both RHR pumps are running.

Step 1 (App EE has been completed by other operators, using time compression).

Inform the examiner that the simulator setup is complete.

NOTE: This JPM is time critical. Do NOT go to run until the examiner or examinee indicates that they are ready to begin. RWST low level will occur shortly after going to RUN.

Go to RUN when the examinee states they are ready to perform the task.

Page 10 of 11 Rev. 2

JPM TITLE: TRANSFER TO COLD LEG RECIRCULATION JPM NUMBER: NRCL181LJCS4P EXAMINEE CUE SHEET Initial Conditions: Given:

Unit 1 experienced a LBLOCA and RWST level is approaching 33%.

Initiating Cue: The Shift Foreman directs you to preview and perform EOP E1.3 to align RHR for cold leg recirculation starting at step 1.

This is a time critical JPM.

Page 11 of 11 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS4S

Title:

PERFORM OP AP15 IMMEDIATE ACTIONS FOR MAIN FEED PUMP TRIP Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ __________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

OP AP15, Loss of Feedwater Flow, Rev 26.

Alternate Path: Yes X No Time Critical: Yes No X Time Allotment: 5 minutes Critical Steps: 2.3, 5.3, 5.4 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank LJC247 DCPP Task # / Rating: 47220 4.0 059.A2.07 - Ability to predict the impact of tripping of the MFW pump turbine on MFW and based on those predictions, use procedures to correct, control, or mitigate the consequences of Gen KA # / Rating: those malfunctions or operations. 3.0 / 3.3 AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator.

The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: Hard Card for Unit 1 OP AP15, Loss of Feedwater Flow Initial Conditions: Given:

Unit 1 is at 100% power PK0912, Main Feedwater Pump Trip, and PK0913, Main Feedwater Pump No. 11, have just alarmed The Shift Foreman has announced he is entering OP AP15, Loss of Feedwater Flow Initiating Cue: The SFM directs you to perform immediate actions in response to plant conditions. OP AP15 Immediate Action Hard Card may be used.

NOTE: Do NOT provide examinee with Task Standard Task Standard: AFW Pumps 12 and 13 are running Rod Control is in MANUAL Rods inserted at maximum available rate (48 steps/min)

    • Denotes Critical Step and SubSteps Page 2 of 8 Rev. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. Obtain the correct Hard Card. 1.1 Hard Card for OP AP15 Immediate Actions.

Step was: Sat __________ Unsat __________

Comments:

    • 2. Step 1 - CHECK Reactor Power Less Than 80%. 2.1 Read CAUTION regarding attempts to stabilize plant online.

2.2 Determined power was greater than 80%.

    • 2.3 Performed Step 1 RNO Started AFW Pp 12 Started AFW Pp 13 Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 8 Rev. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S INSTRUCTOR WORKSHEET Step Expected Operator Actions

3. Step 2 REDUCE Turbine Load. 3.1 Determined turbine load was greater than 650 MW.

3.2 Determined programmed ramp executing appropriately:

DEH MW feedback in service TARGET set for 550 MW RAMP RATE at 225 MW/min Step was: Sat __________ Unsat __________

Comments:

4. Step 3 - CHECK MFW Pp Suction Pressure 4.1 Determined MFW Pp Suction Pressure was GREATER THAN 260 PSIG greater than 260 PSIG.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 8 Rev. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 5. Step 4 - ENSURE Rods Controlling Properly in 5.1 Checked Tave/Tref mismatch greater than 1.5 oF.

AUTO.

5.2 Determined rods were NOT controlling properly in Auto.

<<Alternate Path - Start Point>>

    • 5.3 Placed Rod Control in MANUAL,
    • 5.4 Inserted rods at maximum available rate of 48 steps/min.

<<Alternate Path - End Point>>

Note: Once DRPI has indicated a change in rod position, provide the following Cue:

Cue: Another Operator will continue with the performance of OP AP15.

Step was: Sat __________ Unsat __________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 5 of 8 Rev. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 6 of 8 Rev. 1

JPM TITLE: Perform OP AP15 Immediate Actions for Main Feed Pump TRIP JPM NUMBER: NRCL181LJCS4S ATTACHMENT 1, SIMULATOR SETUP Restore IC159 (customized IC built for L181 Exam administration only). No lesson file is required.

OR Restore the simulator to IC10. .

Run Lesson drl_1247.lsn or manually insert the following:

Inform the examiner that the simulator setup is complete.

Go to RUN when instructed by examiner.

Page 7 of 8 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181LJCS4S Initial Conditions: Given:

Unit 1 is at 100% power PK0912, Main Feedwater Pump Trip, and PK0913, Main Feedwater Pump No. 11, have just alarmed The Shift Foreman has announced he is entering OP AP15, Loss of Feedwater Flow Initiating Cue: The SFM directs you to perform immediate actions in response to plant conditions. OP AP15 Immediate Action Hard Card may be used.

Page 8 of 8 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS5

Title:

Initiate Containment Spray Manually Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ __________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

EOP FRZ.1, Response to High Containment Pressure, Rev. 12 Alternate Path: Yes ______ _ No X Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: 3.1, 4.2, 4.5 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank LJC010 DCPP Task # / Rating: 849200, 835600 3.7 / 3.6 Gen KA # / Rating: E14.EA1.1 - Ability to operate and/or monitor components and the 3.7 / 3.7 functions of control and safety systems, including instrumentation, signals, interlocks, failure modes and automatic and manual features as they apply to high containment pressure.

AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 EVALUATOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by the examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue.

The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. If the task is being done in the plant or lab, and after identifying the appropriate procedure for the task, the examinee may be given the procedure and told what step to begin the task at.

Required Materials: Provide a copy of the reference procedure (partial procedure allowed), if the task is being done in the plant or lab.

Initial Conditions: Given:

Unit 1 experienced a LOCA EOP E1 is in progress and Safety Injection is reset Containment pressure is > 25 psig A MAGENTA path on the Containment Critical Safety Function Status Tree has been confirmed All higher priority critical safety functions have been addressed Initiating Cue: The Shift Foreman directs you to manually initiate containment spray in accordance with EOP FRZ.1, starting at step 3.c DO NOT READ TASK STANDARD TO EXAMINEE Task Standard: Containment spray is manually initiated and aligned for injection phase in accordance with EOP FRZ.1, Step 3 such that:

Containment Spray Pump 11 RUNNING with discharge valve 9001A OPEN Containment Spray Pump 12 RUNNING with discharge valve 9001B OPEN 8994A, Spray Additive Tank Outlet Valve A: OPEN 8994B, Spray Additive Tank Outlet Valve B: OPEN Prior to the completion of FRZ.1.

    • Denotes Critical Step and SubSteps Page 2 of 8 Rev. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 EVALUATOR WORKSHEET Start Time:

Step Expected Operator Actions

1. Obtain the correct procedure. 1.1 References EOP FR Z.1.

Cue (if required): Start with Step 3.c Step was: Sat __________ Unsat __________

Comments:

2. 2.1 Determines Containment Spray IS required FRZ.1, Step 3.c - Containment pressure containment pressure is greater than 22 psig greater than 22 psig.

(PI934, PI935, PI936, PI937 on VB1)

If asked about ECA1.1, provide the following:

Cue: Refer to Initial Conditions.

Step was: Sat __________ Unsat __________

Comments:

    • 3. FRZ.1, Step 3.d RNO Start the containment ** 3.1 Turns control switches to the START position for spray pumps. containment spray pumps 11 and 12 (VB1)

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 8 Rev. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 EVALUATOR WORKSHEET Step Expected Operator Actions

    • 4. SFRZ.1, step 3.e Checks containment spray 4.1 Determines that Containment Spray System is system for proper valve alignment. NOT in proper emergency alignment based on Containment Spray Pump Discharge Valves 9001A and 9001B position indication lights (VB1):

Red lights OFF / Green lights ON

    • 4.2 Takes control switch for 9001A and B to OPEN position and verifies valve position lights indicate OPEN (VB1):

Red lights ON / Green lights OFF 4.3 Verifies 8992 open.

4.4 Determines Spray Add Tank Outlet valves are NOT in proper emergency alignment based on 8994A and 8994B position indication lights (VB1):

Red lights OFF / Green lights ON

    • 4.5 Takes control switch for 8994A and B to OPEN position and verifies valve position lights indicate OPEN (VB1):

Red lights ON / Green lights OFF Step was: Sat __________ Unsat __________

Comments:

5. FRZ.1, Step 3.f - Check Containment Isolation 5.1 Determines Containment Isolation Phase B Phase B valves Closed valves are closed based on Monitor Light Box D indications (VB1):

Red lights ON / White lights OFF Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 8 Rev. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 EVALUATOR WORKSHEET Step Expected Operator Actions

6. FRZ.1, step 3.g - Stops CCP 13. 6.1 Turns control switch to the STOP/RESET position for Centrifugal Charging Pump 13.

Verifies Red light OFF / Green light ON (VB2)

Cue: Another operator will continue with the procedure".

Step was: Sat __________ Unsat __________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 5 of 8 Rev. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 EVALUATOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: __________________________________________________________________

    • Denotes Critical Step and SubSteps Page 6 of 8 Rev. 1

JPM TITLE: Initiate Containment Spray Manually JPM NUMBER: NRCL181LJCS5 ATTACHMENT 1, SIMULATOR SETUP Restore IC160 (customized IC built for L181 Exam administration only). No lesson file is required.

Perform the following:

1. Select CSF5 on SPDS.

After the simulator goes to FREEZE, Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet and has verified containment pressure greater than 22 psig (containment pressure lowers quickly from CFCU cooling once the simulator is taken to RUN).

Page 7 of 8 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181LJCS5 Initial Conditions: Given:

Unit 1 experienced a LOCA EOP E1 is in progress and Safety Injection is reset Containment pressure is > 25 psig A MAGENTA path on the Containment Critical Safety Function Status Tree has been confirmed All higher priority critical safety functions have been addressed Initiating Cue: The Shift Foreman directs you to manually initiate containment spray in accordance with EOP FRZ.1, starting at step 3.c Page 8 of 8 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181-LJCS6

Title:

Crosstie of Vital BUS G to H Examinee: ____________________________________________

Evaluator: ______________________________ ______________________________ __________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

EOP ECA-0.3, Restore 4kV Buses, Appendix X and Appendix Q, Rev. 21 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 20 minutes Critical Steps: 2.1, 3.1, 5.2, 6.1, 7.1, 9.2, 10.1, 12.1, 12.2, 12.3, 13.1, 13.2, 13.3, 17.1 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank LJC-032 DCPP Task # / Rating: 573800 3.5 Gen KA # / Rating: 062.A4.07 - Ability to manually operate and/or monitor 3.1 / 3.1 synchronizing and paralleling of different ac supplies in the control room.

AUTHOR: LISA TORIBIO DATE: 12/03/19 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 12/04/19 REV.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue.

The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: Provide a copy of the reference procedure (partial procedure allowed), if the task is being done in the plant or lab.

Initial Conditions: Given:

  • U-1 was operating at 100%.
  • A reactor trip and safety injection has occurred concurrent with a loss of all off-site power.
  • Diesel generator 11 and diesel generator 13 have failed due to lube oil pressure problems.
  • Diesel generator 12 is supplying 4kV bus G.
  • CCW Pp 12 has failed resulting in a complete loss of CCW flow.
  • Steps 4.a and 4.b of ECA-0.3, Appendix X have been completed.

Initiating Cue: The Shift Foreman directs you to crosstie 4kV bus G to energize 4kV and 480V bus H per EOP ECA-0.3, Appendix X, commencing at step 4.c. The Shift Manager has concurred with this implementation.

DO NOT READ TASK STANDARD TO EXAMINEE Task Standard: 4KV and 480 V bus H are energized from DG 1-2 in accordance with ECA-0.3, appendix X as by performing the following sequence:

  • Step 4.c - Opens 52-HH-10.
  • Step 4.d - Calls the operator in the field to open all 480V Bus H breakers.
  • Step 4.f - Manually depresses both SI reset pushbuttons (Train A and Train B).
  • Step 4.g - Places all Xfer to S/U PWR C/O toggle switches to CUT-OUT for Vital 4kV buses F, G, and H.
  • Step 4.h - Depress all auto transfer reset pushbuttons for Vital 4kV buses F, G, and H.
  • Step 4.j - Opens Startup Feeder Breakers 52-HF-14 and 52-HH-14.
  • Step 4.k - Opens Startup Feeder 52-HG-15.
  • Step 4.m - Inserts sync key for 4kV bus H start up feeder breaker and turns switch to on. Closes 4kV bus H start up feeder breaker 52-HH-14.
  • Step 4.n - Inserts sync key for 4kV bus G start up feeder breaker and turns switch to on. Closes 4kV bus G start up feeder breaker 52-HG-14.
  • Step 4.r - 4kV to 480V bus feeder breaker for bus H, 52-HH-10.
    • Denotes Critical Steps and Sub-Steps Page 2 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Start Time:

Step Expected Operator Actions

1. Obtain the correct procedure. 1.1 References ECA-0.3, Appendix X, step 4.c.

Step was: Sat __________ Unsat __________

Comments:

    • 2. Step 4.c - Verify OPEN the 4kV to 480 VAC bus ** 2.1 Opens 52-HH-10 (VB4).

feeder breaker for the de-energized bus to be reenergized 2.2 Verifies that 52-HH-10 has opened (VB4).

Step was: Sat __________ Unsat __________

Comments:

    • 3. Step 4.d - On the de-energized 480V bus to be ** 3.1 Calls the operator in the field to open all 480V reenergized, open all 480V breakers. Bus H breakers.

Note: 480V Bus H breakers are in the correct OPEN position for this JPM. Inform the Examinee that Time Compression is being used.

Cue: (using time compression) An Operator has opened all the 480V breakers on bus 1H.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 3 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

4. Step 4.e - Cut in the DIR PWR, LOSS OF FIELD, & 4.1 Places D/G DIR PWR, LOSS OF FLD & BKR OC BKR OC PROT RLYS for diesel generator 12. PROT RLYS C/O SW to CUT-IN (VB4).

Step was: Sat __________ Unsat __________

Comments:

    • 5. Step 4.f - Reset SI. 5.1 Checks PK08-21 Safety Injection Actuation status (VB3).
    • 5.2 Manually depresses both pushbuttons.

5.3 Checks at least one of the following:

Monitor Light Box B Safety Injection red light OFF (VB1).

OR PK08-21, Safety Injection Actuation not ON (VB3).

Step was: Sat __________ Unsat __________

Comments:

    • 6. Step 4.g - Cutout the auto transfer FCOs for ** 6.1 Places all Xfer to S/U PWR C/O toggle switch to 4kV and 12kV buses. CUT-OUT (VB4, VB5).

Vital 4kV Non-Vital 4kV 12 kV Bus F ** Bus D Bus D Bus G ** Bus E Bus E Bus H **

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 4 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

    • 7. Step 4.h - Depress all auto transfer reset ** 7.1 Depresses all AUTO XFER RESET pushbuttons, if pushbuttons. required (VB4, VB5).

Vital 4kV Non-Vital 4kV 12 kV Bus F ** Bus D Bus D Bus G ** Bus E Bus E Bus H **

7.2 Verifies that all Auto Xfer indicating blue lights are off. (VB4, VB5).

Step was: Sat __________ Unsat __________

Comments:

8. Step 4.i - Verify OPEN all vital 4kV bus 8.1 Observes that all vital 4kV bus aux feeder auxiliary feeder breakers. breakers are OPEN (VB4):
  • 52-HH-13 OPEN
  • 52-HG-13 OPEN
  • 52-HF-13 OPEN Step was: Sat __________ Unsat __________

Comments:

    • 9. Step 4.j - Verify OPEN all vital 4kV bus startup 9.1 Observes 52-HG-14 is OPEN (VB4).

feeder breakers.

    • 9.2 Opens Startup Feeder Breakers (VB4)
  • 52-HF-14
  • 52-HH-14 Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 5 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

    • 10. Step 4.k - Verify OPEN the 4kV startup feeder ** 10.1 Opens 52-HG-15 (VB4).

breaker 52-HG-15.

10.2 Verifies that 52-HG-15 has opened Step was: Sat __________ Unsat __________

Comments:

11. Step 4.l - Verify that Steps 4.b and 4.c of this 11.1 Reads CAUTION and NOTE.

appendix are complete.

Cue: Another operator will monitor the stability of the DG, and open the S/U feeder breaker if needed.

If requests status of steps 4.b and 4.c, provide the following cue:

Cue: Refer to your initial conditions Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 6 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

    • 12. Step 4.m - Close 4kV startup feeder breaker ** 12.1 Inserts sync key for 4kV bus H startup feeder for the de-energized bus being reenergized. breaker 52-HH-14 (VB4).
    • 12.2 Turns sync switch to ON.
    • 12.3 Closes 52-HH-14.

12.4 Verifies that 52-HH-14 has closed.

Step was: Sat __________ Unsat __________

Comments:

    • 13. Step 4.n - Close the 4kV startup feeder ** 13.1 Inserts sync key for 4kV bus G startup feeder breaker for the bus that will be supplying breaker 52-HG-14 (VB4).

power to the de-energized bus

    • 13.2 Turns sync switch to ON.
    • 13.3 Closes 52-HG-14.

13.4 Verifies that 52-HG-14 has closed.

13.5 Verifies running diesel generator remains stable.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 7 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

14. Step 4.o - Monitors for an SI 14.1 **********************************

Cue: Another operator will monitor for an SI, and open the bus G S/U feeder if required.

15. Step 4.p - IMPLEMENT Appendix Q to start 15.1 **************************************

4kV loads as needed on the reenergized bus Cue: An operator has been stationed at VB4 with Appendix Q and is monitoring the diesel generator.

Cue: The SFM will coordinate the starting of any 4KV loads that are required.

Please continue with Appendix X.

Step was: Sat __________ Unsat __________

Comments:

16. Step 4.q - Verify that Step 4.d of this 16.1 Verifies that Step 4.d of this Appendix is Appendix is complete PRIOR to performing complete.

the next step.

Cue: Steps 4.d of this appendix is complete.

Step was: Sat __________ Unsat __________

Comments:

    • 17. Step 4.r - Close the 4kV to 480V bus feeder ** 17.1 Closes 52-HH-10.

breaker for the reenergized bus.

Verifies that 52-HH-10 has closed.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Steps and Sub-Steps Page 8 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Step Expected Operator Actions

18. Step 4.s - Implement Appendix Q for starting 18.1 Implements Appendix Q for starting 480V bus 480V loads as needed. loads as needed.

Cue: The SFM will coordinate the starting of 480 vac loads that are required.

Another operator will monitor and implement App Q.

Step was: Sat __________ Unsat __________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Steps and Sub-Steps Page 9 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 EVALUATOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: __________________________________________________________________

    • Denotes Critical Steps and Sub-Steps Page 10 of 12 Rev.0

JPM TITLE: Crosstie of Vital BUS G to H JPM NUMBER: NRCL181-LJCS6 ATTACHMENT 1, SIMULATOR SETUP Restore the simulator to the IC-10 (100%, MOL).

Enter lesson file drl_1032 or manually insert the following:

Command Description Insert loa_sis3 OPEN delay=60 Strips vital 4KV Bus H Insert loa_rhr10 OPEN delay=60 Insert loa_css8 OPEN delay=60 Insert loa_ccw31 OPEN delay=60 Insert loa_afw14 OPEN delay=60 Insert dsc_ven14 OPEN delay=60 Insert mal_deg1a 2 Fails DGs 1-1 and 1-3 Insert mal_deg1c 2 Insert mal_syd1 1 Loss of Offsite Power Insert mal_syd1_btw 1 Insert mal_ppl2a 1 Inadvertant SI delIA mal_ppl2a 2 delay=2 insert mal_ppl2b 1 delIA mal_ppl2b 2 delay=2 Insert pmp_ccw2 4 delay=4 OC trip on CCW PP 1-2 RUN Runs simulator Run lesson drl_0063 (Strips 480v bus H). Manual insert is not practical due to large number of actions.

Freeze simulator Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet.

Page 11 of 12 Rev.0

EXAMINEE CUE SHEET JPM NUMBER: NRCL181-LJCS6 Initial Conditions: Given:

  • U-1 was operating at 100%.
  • A reactor trip and safety injection has occurred concurrent with a loss of all off-site power.
  • Diesel generator 11 and diesel generator 13 have failed due to lube oil pressure problems.
  • Diesel generator 12 is supplying 4kV bus G.
  • CCW Pp 12 has failed resulting in a complete loss of CCW flow.
  • Steps 4.a and 4.b of ECA-0.3, Appendix X have been completed.

Initiating Cue: The Shift Foreman directs you to crosstie 4kV bus G to energize 4kV and 480V bus H per EOP ECA-0.3, Appendix X, commencing at step 4.c. The Shift Manager has concurred with this implementation.

Page 12 of 12 Rev.0

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181LJCS8

Title:

Respond to Fire in the 480V Bus G Switchgear Room Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ ________________

Print Signature Date Testing Method: Perform X Simulate Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

References:

OP AP34.3.11, Fire Response - 480 V Bus G Switchgear Room, Rev 0 Alternate Path: Yes X No Time Critical: Yes No X Time Allotment: 10 minutes Critical Steps: 4.1, 4.3, 4.4, 4.9 Job Designation: RO/SRO Rev Comments/LRN TIPS: New DCPP Task # / Rating: 89481 3.0 / 3.0 Gen KA # / Rating: 067.AA2.17 - Ability to determine and interpret the following as 3.5 / 4.3 they apply to the Plant Fire on Site: systems that may be affected by the fire.

AUTHOR: LISA TORIBIO DATE: 02/04/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/04/20 REV. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 INSTRUCTOR WORKSHEET Directions: All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator.

The examinee will be given the initial conditions and initiating cue. The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. After identifying the appropriate procedure for the task, the examinee may be given the procedure and told the steps with which to begin.

Required Materials: OP AP34.3.11, Fire Response - 480 V Bus G Switchgear Room, Rev 0 Initial Conditions: Given:

A fire has been reported and verified as valid in the 480 V Bus G switchgear room.

The crew has entered AP34 and determined Fire Response procedure AP34.3.11 applies.

Initiating Cue: The Shift Foreman directs you to implement OP AP34.3.11, Fire Response - 480 V Bus G Switchgear Room.

NOTE: Do NOT provide examinee with Task Standard Task Standard: Realign charging as follows:

CCP 13 STOPPED Charging pump suction from the RWST, 8805A - OPENED VCT outlet to charging pumps, LCV112B - CLOSED CCP 11 - RUNNING Prior to exiting OP AP34.3.11, Fire Response - 480 V Bus G Switchgear Room

    • Denotes Critical Step and SubSteps Page 2 of 8 Rev. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. AP34.3.11, Step 1 Check reactor does NOT 1.1 Noted reactor was NOT tripped and Safety trip and Safety Injection does NOT actuate. Injection had NOT actuated.

Step was: Sat __________ Unsat __________

Comments:

NOTE: This is a continuous action step. The running charging pump will begin cavitating shortly after the original check, requiring the candidate to return to step 2 to implement RNO actions.

2. AP34.3.11, Step 2 Check suction to running 2.1 Determined VCT level and pressure in normal charging pumps. band.

2.2 Identified charging pump suction flow path available through LCV112B and LCV112C.

2.3 Checked charging pump 13 amps stable.

2.4 Checked charging header flow FI128A stable.

2.5 Checked charging header pressure PI142A stable.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 8 Rev. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 INSTRUCTOR WORKSHEET Step Expected Operator Actions

3. AP34.3.11, Step 3 Check RWST drain path 3.1 Checked PK0821 OFF.

isolated.

NOTE: PK0501, 02, 03, 04 alarm shortly after CCP 13 cavitation begins. If Examinee opts to perform PK steps, provide the following Cue:

Cue: Another Operator will address Annunciator Responses 3.2 Noted reduced flow to RCP seals.

3.3 Identified CCP 13 amps - NOT stable.

Step was: Sat __________ Unsat __________

Comments:

<< Alternate Path - Start Point >>

    • 4. AP34.3.11, Step 2 RNO - Align charging pump ** 4.1 Stopped CCP 13.

suction to RWST.

NOTE: May additionally close letdown isolation valves LCV459 and LCV460.

4.2 Isolated letdown by closing orifice valve:

8149 C

    • 4.3 Opened charging pump suction from the RWST:

8805A

    • 4.4 Closed VCT outlet to the charging pumps:

LCV112B 4.5 Informs Shift Foreman CCP 13 must be vented prior to restart.

4.6 ***************************************

Cue: CCP 13 will be vented prior to restarting the pump (Step continued on next page)

    • Denotes Critical Step and SubSteps Page 4 of 8 Rev. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 INSTRUCTOR WORKSHEET Step Expected Operator Actions

4. AP34.3.11, Step 2 RNO - Align charging 4.7 Checked charging pump recirc isolation lines (cont) pump suction to RWST. 8105 and 8106 are open.

4.8 Closed charging flow control valve FCV128

    • 4.9 Started CCP 11 4.10 Opened FCV128 to establish minimum charging flow to seals only (approx 32 gpm; 8gpm/seal) 4.11 Noted requirement to establish letdown per OP AP17, Loss of Charging

<< Alternate Path - End Point >>

4.12 ***************************************

Cue: Other Operators will continue with system restoration.

Step was: Sat _________ Unsat _________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 5 of 8 Rev. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 6 of 8 Rev. 1

JPM TITLE: Respond to Fire in the 480V Bus G Switchgear Room JPM NUMBER: NRCL181LJCS8 ATTACHMENT 1, SIMULATOR SETUP Restore the simulator to IC10 (100%, MOL).

Enter Lesson file L181LJCS8 Description L3 Commands Activate PK1010 Fire Detected Insert PK1010_0674 FAIL_TO_TRUE Cavitate CCP 13 (Paused) insert CVC_932TASTEM 0.1 ramp=4 Inform the examiner that the simulator setup is complete.

Go to RUN when the examinee is given the cue sheet.

When Examinee goes to check FI128A, Charging Header Flow, on CC2, activate CVC_932TASTEM 0.1 ramp=4 Page 7 of 8 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181LJCS8 Initial Conditions: Given:

A fire has been reported and verified as valid in the 480 V Bus G switchgear room.

The crew has entered AP34 and determined Fire Response procedure AP34.3.11 applies.

Initiating Cue: The Shift Foreman directs you to implement OP AP34.3.11, Fire Response - 480 V Bus G Switchgear Room.

Page 8 of 8 Rev. 1

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181P1

Title:

Transfer Pressurizer Heater Group 23 to Backup Power Examinee: ____________________________________________

Evaluator: ______________________________ ______________________________ __________________

Print Signature Date Testing Method: Perform Simulate X Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments: (Note: Any Unsat step requires a numbered comment; use back as needed.)

This is a Unit 2 JPM

References:

U2 OP A4A:I, Pressurizer Make Available, Rev. 26 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: 4.2, 8.2, 10.1 Job Designation: RO/SRO Rev Comments/LRN TIPS: Bank: LJP029A DCPP Task # / Rating: 109800 3.6 010.A2.01 - Ability to predict the impact of heater failures on the PZR PCS and based on those predictions, use procedures to correct, control, or mitigate the consequences of those Gen KA # / Rating: malfunctions or operations. 3.3 / 3.6 AUTHOR: LISA TORIBIO DATE: 02/05/20 APPROVED BY: CHRIS MEHIGAN DATE: 02/05/20 LINE MANAGER REV.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue.

The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. The examinee should be given the required materials shown below, and access to other plant references as appropriate.

Equipment operation Cues are contingent on proper operation by the examinee and should be adjusted should equipment operation differ from expected.

Required Materials: A copy of U2 OP A4A:I, Section 6.4.

Initial Conditions: Given:

Unit 2 is in MODE 1.

An electrical fault has deenergized 480VAC bus 23E.

Offsite power is available Initiating Cue: The Shift Foreman directs you to transfer pressurizer heater group 23 to its backup power supply in accordance with OP A4A:I, Section 6.4. Another Operator has been assigned to monitor bus loading during the transfer.

NOTE: Do NOT provide examinee with Task Standard Task Standard: Pressurizer heater group 23 is powered from its backup supply as follows:

Control power toggle switch in OFF position Transfer switch EPPH23 in DOWN (backup) position DC control power knife switch 72522H74 CLOSED

    • Denotes Critical Step and SubSteps Page 2 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. Reference procedure section 6.4 1.1 Read caution and note.

1.2 Went to step 6.4.2 for Pzr Heater Group 23.

1.3 Read caution.

1.4 Recognized that offsite power is available and went to Section 6.4.2b.

Step was: Sat __________ Unsat __________

Comments:

2. OP A4A:I, Step 6.4.2.b.1,2 - Place control 2.1 Went to or called the control room to ensure switch for heater group 23 in the OFF position. the position of the control switch for heater group 23 is in OFF.

Cue: The Control Room Operator reports the control switch for heater group 23 is in the OFF position and the green light is ON.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

3. OP A4A:I, Step 6.4.2.b.3.a - Ensure the 3.1 Located the normal breaker for heater group 23 following for 5223E2, Press Heater Group on load center 23E.
  1. 23:

Breaker OPEN 3.2 Ensured that the breaker is OPEN.

Cue: The OPEN (green) indicator is showing on the breaker.

Step was: Sat __________ Unsat __________

Comments:

    • 4. OP A4A:I, Step 6.4.2.b.3.b - Ensure the 4.1 Located the DC control power switch for the following for 5223E2, Press Heater Group heater group 23 normal breaker on load center
  1. 23: 23E.

725223E02, DC Control Power Cut Out Switch, in "OFF"

    • 4.2 Placed the control power toggle switch in the OFF position (left switch in bank of 3).

Note: Use pointer to indicate toggle switch is in the DOWN (OFF) position.

Cue: The toggle switch is positioned here.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

5. OP A4A:I, Step 6.4.2.b.4.aCheck heater 5.1 Located the heater group 23 backup breaker.

group 23 backup breaker 522H74 open.

5.2 Checked that the breaker is open.

Cue: The OPEN (green) indicator is showing on the breaker.

Step was: Sat __________ Unsat __________

Comments:

6. OP A4A:I, Step 6.4.2.b.4.b Check open the 6.1 Located the DC control power knife switch for DC control power knife switch 72522H74 heater group 23 (located above the vital for the heater group 23 backup breaker. breaker).

Cue: You may open the cabinet.

6.2 Ensured the knife switch is open.

Cue: The knife switch is as described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 5 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

7. OP A4A:I, Step 6.4.2.b.5.a Ensure both 7.1 Located the manual transfer switch on the wall white potential lights on manual transfer next to the 522H74 breaker.

switch EPPH23, Press Heater 23 Transfer Switch are OFF.

Note: Normal breaker may be available, white light may be ON.

7.2 Checked BOTH white lights OFF Normal supply 5223E2 Backup supply 522H74 Cue: Both white lights are OFF.

Step was: Sat __________ Unsat __________

Comments:

    • 8. OP A4A:I, Step 6.4.2.b.5.b,c Move the ***************************************

transfer switch down to the backup (vital bus) Cue: Another Operator will complete all position. required sealed component change forms and resealing.

8.1 Simulated removing seal.

    • 8.2 Positioned switch EPPH23 to the backup supply (down position).

Note: Use pointer to indicate transfer switch is in the down (BACKUP) position.

Cue: The transfer switch is positioned here."

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 6 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

9. OP A4A:I, Step 6.4.2.b.6.a Rack in or check Note: This breaker is normally racked in. This racked in 522H74. step would become critical if the breaker were initially racked out. OP J7A:II would only be needed in this unusual case.

9.1 Racked in or checked racked in 522H74, (Breaker is flush with the breaker cabinet RACKED IN).

Cue: Breaker is as described.

Step was: Sat __________ Unsat __________

Comments:

    • 10. OP A4A:I, Step 6.4.2.b.6.b Close the DC ** 10.1 Closed the DC control power knife switch control power knife switch for the heater 72522H74 (knife switch is UP).

group 23 backup breaker.

Cue: The knife switch is as described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 7 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Step Expected Operator Actions

11. OP A4A:I, Step 6.4.2.b.6.c,d Ensure the DC 11.1 Located the DC Charging Power Switch on the Charging Power Switch for heater group 23 lower front of 522H74.

backup breaker (522H74) is on and springs charged.

11.2 Ensured the following:

CHARGING POWER switch is in the ON (UP) position SPRINGS CHARGED flag displayed Cue: The switch is in the described position, and the Springs Charged flag is showing on the breaker.

Step was: Sat __________ Unsat __________

Comments:

12. Notify the control room of the status of 12.1 Notified the control room that heater group 23 heater group 23. has been transferred to the backup power supply.

Cue: The Control Operator will complete the procedure and energize heater group 23.

Step was: Sat __________ Unsat __________

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 8 of 10 Rev.2

JPM TITLE: Transfer Pressurizer Heater Group 23 to Backup Power JPM NUMBER: NRCL181P1 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 9 of 10 Rev.2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181P1 Initial Conditions: Given:

Unit 2 is in MODE 1.

An electrical fault has deenergized 480VAC bus 23E.

Offsite power is available Initiating Cue: The Shift Foreman directs you to transfer pressurizer heater group 23 to its backup power supply in accordance with OP A4A:I, Section 6.4. Another Operator has been assigned to monitor bus loading during the transfer.

Page 10 of 10 Rev.2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181P2

Title:

Transfer the TSC to Vital Power Examinee: ____________________________________________

Evaluator: ______________________________ ______________________________ __________________

Print Signature Date Testing Method: Perform Simulate X Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments:

This is a Unit 1 JPM

References:

EOP ECA2.1, Uncontrolled Depressurization of All Steam Generators, Appendix J, Rev.

27A OP J6B:VI, Manual Operation of DG 13, Unit 1 - Rev. 37 OP J6B:VI, Manual Operation of DG 23, Unit 2 - Rev. 33 Alternate Path: Yes X No Time Critical: Yes No X Time Allotment: 20 minutes Critical Steps: 3.1, 4.1, 7.1, 7.2 Job Designation: RO/SRO Converted to new format, updated references. Rev 2A for reference procedure number Rev Comments/LRN TIPS: revision only - no impact to JPM. LOF supervisor approves.

DCPP Task # / Rating: 896600 3.0 / 3.0 062.A2.11 - Ability to predict the impact of aligning standby equipment with correct emergency power source on the ac distribution system and based on those predictions, use procedures to correct, control, or mitigate the consequences of Gen KA # / Rating: those malfunctions or operations. 3.7 / 4.1 AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE CHRISTOPHER MEHIGAN DATE: 02/05/20 LINE MANAGER REV. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue.

The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. The examinee should be given the required materials shown below, and access to other plant references as appropriate.

Equipment operation Cues are contingent on proper operation by the examinee and should be adjusted should equipment operation differ from expected.

Required Materials: Copy of ECA2.1, Appendix J.

Copy of OP J6B:VI for D/G 13 and 23. (only once asked for)

Initial Conditions: Given:

Unit 1 experienced a steam break and uncontrolled depressurization of all steam generators.

Offsite power was lost to both units.

The SEC has given permission to place the TSC on vital power.

The TSC is manned and requires vital power.

Diesel generator 13 is supplying Unit 1 4 kV Bus F and is carrying 2.12 MW load @ a 0.8 pf.

Diesel generator 23 is supplying Unit 2 4 kV Bus F and is carrying 2.26 MW load @ a 0.8 pf.

Initiating Cue: The Unit 1 Shift Foreman directs you to place the TSC on U1 vital power, per ECA2.1, Appendix J, starting with Step 3.

NOTE: Do NOT provide examinee with Task Standard Task Standard: TSC Transfer Switch Normal Power:

Breaker 5222J40 in the OFF position.

TSC is being provided power from Unit 2 D/G 23 via:

Switch EPTSN to BACKUP power.

Switch EPTSC to the NORMAL (U2) position.

Breaker 522F47 in the ON position.

    • Denotes Critical Step and SubSteps Page 2 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

1. ECA2.1, Appendix J, Step 3 - Check D/G 13 1.1 Referenced D/G 13 load in initial conditions.

loaded and able to support additional loading.

1.2 Referenced OP J6B:VI, Precautions and Limitations Step 5.10 for D/G 13 load limits.

Note: Supply copy of procedure OP J6B:VI P&Ls to student when they indicate they will refer to a procedure for D/G load limits.

1.3 Determined that D/G 13 can support additional 106.2 KW loading. (2.6 Mw - 2.12 MW = .48 MW or 480 KW)

Step was: Sat __________ Unsat __________

Comments:

Note: Examinee may elect to evaluate support capability of D/G 23 at this time, but is expected to align the TSC to D/G 13 per Shift Foreman directions given in cue.

Mark Step N/A if evaluation of D/G 23 not performed at this time.

2. ECA2.1, Appendix J, Step 3 - Check D/G 23 2.1 Referenced OP J6B:VI, Precautions and loaded and able to support additional loading Limitations Step 5.10 for D/G 23 load limits.

(Optional step since D/G 13 is capable of carrying load).

2.2 Determined DG 23 has room for an additional 106.2 KW of load (2.6 Mw - 2.26 MW = .34 MW or 340 KW)

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Step Expected Operator Actions Note: JPM steps 3.1, 3.2, and 3.3 may be done in any order (bulleted steps in the procedure).

    • 3. ECA2.1, Appendix J, Step 5 - Open the ** 3.1 Placed breaker 5222J40 (EPTSN TSC PWR following breakers: TRANSF SW NORMAL SOURCE) in the OFF Open breaker 5222J40 (TSC XFER SW) position.

Note: Use pointer to indicate breaker is in the DOWN (OFF) position.

Cue: An audible "clunk" is heard, and the breaker is positioned here, as described.

Open breaker 522F47 (TSC 480V 3.2 Noted that breaker 522F47 (ON SITE POWER TO EPTSC) TECHNICAL SUPPORT CENTER 480V POWER TO EPTSC) is in the OFF position.

Note: Use pointer to indicate breaker is in the DOWN (OFF) position.

Cue: The breaker is positioned here, as described.

Open breaker 521F67 (TSC 3.3 Noted that breaker 521F67 (TSC TRANSFER TRANSFER SWITCH) SWITCH) is in the OFF position.

Note: Use pointer to indicate breaker is in the DOWN (OFF) position.

Cue: The breaker positioned here, as described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Step Expected Operator Actions Note: Switch is on west wall of 2F 480 VAC switchgear room. When examinee goes describes need to address sealed component change form, provide the following cue:

Cue: The sealed component change form needs will be addressed by another Operator.

    • 4. ECA2.1, Appendix J, Step 6 - In the 2F MCC ** 4.1 Placed switch EPTSN in the BACKUP (EPTSC)

Room, switch EPTSN, TSC Power Transfer position.

Switch, to BACKUP.

Note: Use pointer to indicate breaker is in the BACKUP (EPTSC) position.

Cue: The switch is positioned here, as described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 5 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Step Expected Operator Actions

5. ECA2.1, Appendix J, Step 7 - Supply Power 5.1 Placed EPTSC switch (TSC Power Transfer Unit from Unit 1: Selector Switch) to the BACKUP position.

a) Switch EPTSC, Power Transfer Unit Selector Switch to BACKUP.

Note: Use pointer to indicate breaker is in the BACKUP position.

Cue: The switch is positioned here, as described.

Note: When the Examinee attempts to close the breaker to align power from Unit 1, the breaker WILL NOT CLOSE. The Examinee should recognize aligning TSC to Unit 2 as a viable alternative.

5.2 Attempted to place breaker 521F67 in the ON position.

Cue: The breaker REMAINS AS IS with the word OFF showing on the lower breaker handle.

5.3 Determined Unit 1 is not capable of supplying power to TSC.

Note: If Examinee asks for direction, provide the following CUE:

Cue: What do you recommend?"

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 6 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET

<< Alternate Path - Start Point >>

Step Expected Operator Actions Note: If Examinee requests direction from Control Room due to original field alignment becoming unavailable, provide the following cue:

Cue: Take the appropriate action Note: Mark step N/A if evaluation of D/G 23 load support was performed earlier.

6. ECA2.1, Appendix J, Step 4 - Check D/G 23 6.1 Referenced OP J6B:VI, Precautions and loaded AND able to support an additional Limitations Step 5.10 for D/G 23 load limits.

106.2 KW loading.

6.2 Determined that DG 23 has room for an additional 106.2 KW of load (2.6 MW - 2.26 MW = .34 MW or 340 KW)

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 7 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Step Expected Operator Actions Note: Switch is also on west wall of 2F 480VAC switchgear room, next to EPTSN switch.

Unit 2 is the NORMAL position

    • 7. ECA2.1, Appendix J, Step 8 - Supply Power ** 7.1 Places EPTSC switch (TSC Power Transfer Unit from Unit 2: Selector Switch) to the NORMAL position.

a) Switch EPTSC, Power Transfer Unit Selector Switch to NORMAL.

Note: Use pointer to indicate breaker is in the NORMAL position.

Cue: Cue: The switch is positioned here, as described.

b) Close 522F47, TSC 480V Power to ** 7.2 Places breaker 522F47 in the ON position.

EPTSC.

Note: Use pointer to indicate breaker is in the up (ON) position.

Cue: An audible "clunk" is heard, and the breaker is positioned here, as described.

Step was: Sat __________ Unsat __________

<< Alternate Path - End Point >>

Comments:

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 8 of 10 Rev. 2

JPM TITLE: Transfer the TSC to Vital Power JPM NUMBER: NRCL181P2 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 9 of 10 Rev. 2

EXAMINEE CUE SHEET JPM NUMBER: NRCL181P2 Initial Conditions: Given:

Unit 1 experienced a steam break and uncontrolled depressurization of all steam generators.

Offsite power was lost to both units.

The SEC has given permission to place the TSC on vital power.

The TSC is manned and requires vital power.

Diesel generator 13 is supplying Unit 1 4 kV Bus F and is carrying 2.12 MW load @ a 0.8 pf.

Diesel generator 23 is supplying Unit 2 4 kV Bus F and is carrying 2.26 MW load @ a 0.8 pf.

Initiating Cue: The Unit 1 Shift Foreman directs you to place the TSC on U1 vital power, per ECA2.1, Appendix J, starting with Step 3.

Page 10 of 10 Rev. 2

NUCLEAR POWER GENERATION DIABLO CANYON POWER PLANT JOB PERFORMANCE MEASURE Number: NRCL181P3

Title:

Clear Component Cooling Water Header "A" Examinee: ____________________________________________

Evaluator: ______________________________ ________________________________ __________________

Print Signature Date Testing Method: Perform Simulate X Results: Sat __________ Unsat __________ Total Time: __________ minutes Comments: (Note: Any Unsat step requires a numbered comment; use back as needed.)

OP AP SD4, Loss of Component Cooling Water, Rev 23, Appendix A

References:

OVID 10671402 Alternate Path: Yes No X Time Critical: Yes No X Time Allotment: 15 minutes Critical Steps: 1.4, 2.3, 3.3 Job Designation: RO/SRO Rev Comments/LRN TIPS: New DCPP Task # / Rating:

Gen KA # / Rating: G2.1.30 - Ability to locate and operate components, including local 4.4 / 4.0 controls.

AUTHOR: LISA TORIBIO DATE: 02/05/20 OPERATIONS REPRESENTATIVE: CHRISTOPHER MEHIGAN DATE: 02/05/20 REV. 1

JPM TITLE: Clear Component Cooling Water Header "A" JPM NUMBER: NRCL181P3 INSTRUCTOR WORKSHEET Directions: No plant controls or equipment are to be operated during the performance of this Job Performance Measure. All actions taken by examinee should be clearly demonstrated and verbalized to the evaluator. The examinee will be given the initial conditions and initiating cue.

The task standard will NOT be read to the examinee. The examiner will then ask if any clarifications are needed. The examinee should be given the required materials shown below, and access to other plant references as appropriate.

Equipment operation Cues are contingent on proper operation by the examinee and should be adjusted should equipment operation differ from expected.

Required Materials: Provide a copy of the reference procedure (partial procedure allowed), if the task is being done in the plant or lab; OP AP SD4, Appendix A OVID 10671402 Initial Conditions: Given:

Unit 1 is in Mode 5.

The Control Room is currently implementing OP AP SD4, Loss of Component Cooling Water, due to CCW system outleakage.

Local inspection of CCW indicates the leak is between CCW Pump 11 discharge and CCW HX 11 outlet valve FCV430.

CCW HX 12 is currently in service.

Initiating Cue: The Shift Foreman directs you to isolate a portion of CCW Header "A" by performing OP AP SD4, Appendix A, Step 1.a.1.

NOTE: Do NOT provide examinee with Task Standard Task Standard: CCW Header "A" loads isolated as follows:

1CCW18, CCW Pump 11 Discharge to Header A CLOSED 1CCW19, CCW Pump 12 Discharge to Header A CLOSED 1CCW20, CCW Pump 13 Discharge to Header A CLOSED

    • Denotes Critical Step and SubSteps Page 2 of 7 Rev. 1

JPM TITLE: Clear Component Cooling Water Header "A" JPM NUMBER: NRCL181P3 INSTRUCTOR WORKSHEET Start Time:

Step Expected Operator Actions

    • 1. OP AP SD4, Appendix A, Step 1.a.1 - Close all 1.1 1CCW18 at the discharge of CCW Pump 11 three CCW pump discharge valves to CCW HX (73' elevation aux building)
  1. 1:

CCW18 1.2 Noted valve is sealed in the open position and will require seal component change forms.

Cue: The Shift Foreman has assigned another operator to complete all required sealed component change forms and resealing.

1.3 Removed seal (simulated).

    • 1.4 Rotated the handle until the arrow points to 0 degrees (or "C") (simulated).

Cue (if required): The valve is now positioned as you described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 3 of 7 Rev. 1

JPM TITLE: Clear Component Cooling Water Header "A" JPM NUMBER: NRCL181P3 INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 2. OP AP SD4, Appendix A, Step 1.a.1 - Close all 2.1 1CCW19 at the discharge of CCW Pump 12 three CCW pump discharge valves to CCW HX (73' elevation aux building)
  1. 1 (cont):

CCW19 2.2 Removed seal (simulated).

2.3 Rotated the handle until the arrow points to 0 degrees (or "C") (simulated).

Cue (if required): The valve is now positioned as you described.

Step was: Sat __________ Unsat __________

Comments:

    • Denotes Critical Step and SubSteps Page 4 of 7 Rev. 1

JPM TITLE: Clear Component Cooling Water Header "A" JPM NUMBER: NRCL181P3 INSTRUCTOR WORKSHEET Step Expected Operator Actions

    • 3. OP AP SD4, Appendix A, Step 1.a.1 - Close all 3.1 1CCW20 at the discharge of CCW Pump 13 three CCW pump discharge valves to CCW HX (73' elevation aux building)
  1. 1 (cont):

CCW20 3.2 Removed seal (simulated).

3.3 Rotated the handle until the arrow points to 0 degrees (or "C") (simulated).

Cue (if required): The valve is now positioned as you described.

Step was: Sat __________ Unsat __________

Comments:

If Candidate continues on in Appendix A ***************************************

Cue: Another operator will complete isolation of CCW Header "A".

Stop Time:

Total Time: (Enter total time on the cover page)

    • Denotes Critical Step and SubSteps Page 5 of 7 Rev. 1

JPM TITLE: Clear Component Cooling Water Header "A" JPM NUMBER: NRCL181P3 INSTRUCTOR WORKSHEET Follow up Question Documentation:

Question: _____________________________________________________________________________________

Response: _____________________________________________________________________________________

    • Denotes Critical Step and SubSteps Page 6 of 7 Rev. 1

EXAMINEE CUE SHEET JPM NUMBER: NRCL181P3 Initial Conditions: Given:

Unit 1 is in Mode 5.

The Control Room is currently implementing OP AP SD4, Loss of Component Cooling Water, due to CCW system outleakage.

Local inspection of CCW indicates the leak is between CCW Pump 11 discharge and CCW HX 11 outlet valve FCV430.

CCW HX 12 is currently in service.

Initiating Cue: The Shift Foreman directs you to isolate a portion of CCW Header "A" by performing OP AP SD4, Appendix A, Step 1.a.1.

Page 7 of 7 Rev. 1

Appendix D (rev 11) Scenario Outline Form ESD1 Facility: Diablo Canyon (PWR) Scenario No: 1 OpTest No: L181 NRC Examiners: Operators:

Initial Conditions: 2% with MFW in service, aligned to StartUp Power. MOL with CFCU 11 OOS.

Turnover: In OP L3, performing step 6.28, raising power to 8%.

Event Malf Event Event Description No No. Type* (See Summary for Narrative Detail) 1 N/A R (ATC, Raise reactor power from 2% to 8% OP L3, sec 6.28.

SRO) 2 VLV_CVC22_2 .5 delay=0 ramp=15 I (ALL) Regen Hx Isolation Valve, LCV459, fails to midposition (OP AP18).

3 H_V1_034M_1, XMT_VEN6_3, TS, C CFCU 12 high stator/bearing temperature due to low CCW XMT_VEN7_3, XMT_VEN8_3 (BOP, flow (AR PK0121, TS 3.6.6.C).

SRO) 4 RLY_PPL63_2 OPEN TS, I SSPS relay actuation causes inadvertent start of TDAFW pump (ALL) and blowdown sample isolation valves to close (AR PK0403, RLY_PPL59_2 OPEN OP D1:III, OP1.DC10; TS 3.7.5.B).

5 MAL_MSS4 1.57E+07 ramp=30 M (ALL) MSLB outside containment.

6 VLV_MSS7_2, VLV_MSS8_2, C (ALL) All MSIVs fail open; No manual close for FCV42.

VLV_MSS9_2, VLV_MSS10_2 1 7 MAL_PPL3B BOTH C (BOP) Safety Injection, Train B fails to actuate.

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor L181 NRC ESD101 r2.docx Page 1 of 3 Rev 2

Appendix D (rev 11) Scenario Outline Form ESD1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) (from form ES3014) Actual Attributes

1. Total malfunctions (5-8) (Events 2,3,4,5,6,7) 6
2. Malfunctions after EOP entry (12) (Events 6,7) 2
3. Abnormal events (1-4) (Events 2,3,4) 3
4. Major transients (12) (Event 5) 1
5. EOPs entered/requiring substantive actions (1-2) (E2, E1.1) 2
6. EOP contingencies requiring substantive actions (0-2) 0
7. Critical tasks (2-3)(See description below) 3 Critical Task Justification Reference (S1CT1) Shutdown TD AFW pump prior to any Carryover into the steam lines can result in damage Tech Spec 3.3.2 Steam Generator Overfill (S/G wide range greater to downstream piping and valves, placing the Basis than 100%) by either: secondary heat sink at risk. High steam generator Documentation Closing LCV106,107, 108, 109 to the level can also result in reactivity excursions due to individual S/Gs excessive cooldown of the primary system.

OR Closing steam supply valves FCV37 and FCV38 to leads 2 and 3 respectively OR Directing FCV95 closed in the field (S1CT2) Stop uncontrolled RCS cooldown before a An event or series of events which leads to a Background severe challenge to Integrity Safety Function relatively rapid and severe reactor vessel Information for develops (magenta path on F0.4 RCS Integrity) as downcomer cooldown can result in a thermal WOG Emergency follows: shock to the vessel wall that may lead to a small Response Close Main Steam Isolation Valves FCV41, flaw, which may already exist in the vessel wall, Guideline FCV43, FCV44. growing into a larger crack. The growth or Dispatch Operator to close FCV42 (S/G 12 extension of such a flaw may lead, in some cases steamline isolation). (where propagation is not stopped within the wall),

Isolate feed flow to S/G 12 by to a loss of vessel integrity closing/verifying closed LCV107 and LCV111.

(Note: LCV107 is critical only when TDAFW pump is running or capable of an autostart).

Isolate steam flow from S/G 12 by closing/verifying closed FCV37.

Maintains the minimum heatsink requirements (435 gpm until S/G NR level is greater than 15% in one nonfaulted S/G) by controlling flow to S/Gs 11, 13, and 14.

(S1CT3) Terminate SI prior to rupture of PRT by Failure to terminate ECCS flow when SI termination Westinghouse closing 8801A/B OR 8803A/B. criteria are met results in overfill of the Pressurizer Owners Group and the eventual rupture of the PRT. This WCAP17711NP constitutes the avoidable degradation of the RCS as a fission product barrier.

Per NUREG1021, Appendix D, if an operator or crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the postscenario review.

L181 NRC ESD101 r2.docx Page 2 of 3 Rev 2

SCENARIO

SUMMARY

- NRC #1

1. Control rods are used to raise power from 2% to 8% OP L3, Secondary Plant Startup, step 6.28. ATC operator complies with 1 step pull and wait procedural requirement while monitoring relevant controls and diverse indicators. Shift Foreman provides reactivity oversight.
2. Regen Hx Isolation Valve, LCV459, drifts to midposition causing letdown orifice valve 8149C to close.

Shift Foreman enters OP AP18, Letdown Line Failure. Excess Letdown is established per OP B1A:IV CVCS Excess Letdown Place In Service and Remove From Service.

3. CFCU 12 has a loss of CCW flow due to debris migration causing stator and motor bearing temperatures to rise rapidly and bring in annunciator alarm PK0121, Contmt Fan Clr. Reactor operators identify low flow indications on vertical boards and rapidly rising stator/bearing temperatures using plant process computer trends. The crew secures the CFCU to prevent motor damage and contacts maintenance/engineering for assistance. Shift Foreman enters TS 3.6.6 Condition C, one required CFCU system inoperable such that a minimum of two CFCUs remain OPERABLE (7 day).
4. SSPS relay actuation results in Turbine Driven AFW (TDAFW) Pump Steam Supply Isolation Valve, FCV95, failing open and isolation of half of the blowdown sample valves inside and outside containment. S/G levels rise and RCS temperature lowers. FCV95 cannot be closed and the crew must isolate the TDAFW Pump by closing the LCVs to the individual S/Gs or by closing steam supply valves FCV37 and FCV38 from leads 2 and 3 respectively, or by directing FCV95 manually closed in the field (S1CT1) Shutdown TD AFW pump prior to Steam Generator Overfill. Shift Foreman implements TS 3.7.5.B, AFW System for one AFW train inoperable (72 hrs).
5. A main steamline break develops downstream of the Main Steam Isolation Valves, outside containment.

S/G pressure drops rapidly resulting in an automatic Reactor Trip and Safety Injection. The crew enters EOP E0, Reactor Trip or Safety Injection.

6. Train B of Safety Injection fails to actuate, requiring the crew to perform numerous manual alignments and pump starts as part of Appendix E, ESF Auto Actions, Secondary and Auxiliaries Status.
7. All four main steam isolation valves fail open. Steam leads 1, 3, and 4 may be closed from the control room, but lead 2 (FCV42) requires field action. The crew transitions to EOP E2, Faulted Steam Generator Isolation to isolate S/G 12 and dispatches an operator to locally close FCV42 as part of the critical task to stop the uncontrolled cooldown (S1CT2) Stop uncontrolled cooldown before a severe challenge (magenta path ) develops on F0.4 RCS Integrity.
8. The crew transitions to EOP E1.1, SI Termination where they complete the final critical task of the scenario (S1CT3) Terminate SI prior to rupture of PRT.

The scenario is terminated once the final critical task is complete.

L181 NRC ESD101 r2.docx Page 3 of 3 Rev 2

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 1 Page 1 of 15 Event

Description:

Raise Power to 8%

Time Position Applicants Actions or Behavior (OP L3, "Secondary Plant Startup", starting at step 6.28)

SRO Reads NOTES prior to step 6.28.

ATC (6.28) Slowly raises power to 8% by pulling control rods one step at a time.

SRO Provides reactivity oversight while raising power.

BOP (6.29) Monitors feed/steam delta P (PI509, VB3 or CC2, DFWCS HMI on CC3).

(6.30) Verifies that DFWCS maintains constant delta P during rise in power.

SRO Reads NOTE prior to step 6.31.

Proceed to the next event once 45 rod pulls complete, per the lead examiner.

    • Critical Task L181 NRC ESD201 r1.docx Page 1 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 2 Page 2 of 15 Event

Description:

Regen Hx Isolation Valve, LCV459, Fails to midposition Time Position Applicants Actions or Behavior ALL Diagnoses charging flow problem from:

  • RCP seal flows lowering (due to controller throttling back) (VB2 meters, PPC).
  • Pzr level rising slowly (due to charging/letdown mismatch) (VB2 meters, PPC, CC2 recorder).
  • VCT level dropping slowly (VB2 recorder, PPC).
  • Dual position indication lights illuminated on mimic board for LCV459 (VB2).

SRO Implements OP AP18, "Letdown Line Failure".

(OP AP18, "Letdown Line Failure")

SRO/ATC (1) Ensures no load changes, heatups, or draindowns are in progress.

SRO/BOP (2) Isolates letdown o Ensures Letdown Orifice Stop Valve, 8149C is closed (VB2).

o Closes other Regen Heat Exchanger Inlet Valve, LCV460 (VB2).

o Verifies RHR to Letdown Flow Control Valve, HCV133 (RHR Letdown) is closed (VB2).

SRO/ATC (3) Checks for RCS Leakage - verifies that Pzr level and RCS press are both stable/rising (VB2, CC2, PPC).

ATC (4) Reduces charging to minimum (RCP seals only), using FCV128 (or HC459D) and HCV142 (approx. 8 gpm on RCP seals, with HCV142 closed or near closed) (CC2).

SRO/BOP (5) Establish Excess Letdown (see next page), per OP B1A:IV, "CVCS Excess Letdown Place In Service and Remove From Service", Section 6.1 "Place Excess Letdown in Service".

BOP (6) Contacts RP and Chemistry regarding Excess Letdown being placed in service.

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 2 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 2 Page 3 of 15 Event

Description:

Regen Hx Isolation Valve, LCV459, Fails to midposition (continued)

Time Position Applicants Actions or Behavior (OP B1A:IV, "Place Excess Letdown in Service")

ALL * (6.1.1) Verifies charging at minimum (seals only) (done, per previous step, or do now).

o Reduces charging to minimum (RCP seals only), using FCV128 and HCV142 (approx. 8 gpm on RCP seals, with HCV142 closed (or near closed).

BOP (6.1.2) Contacts RP for rad conditions/posting.

Note: If Shift Manager asked about flushing or crew attempts to omit flush, provide the following cue:

CUE: Excess letdown line flushing is necessary.

BOP Reads NOTE regarding excess letdown line flushing.

(6.1.3) Performs letdown line flush:

o (6.1.3.a) Contacts Aux Watch to check sufficient level in RCDT 11 to receive a 13% rise in level.

o (6.1.3.b) Directs Aux Watch to monitor RCDT 11 level.

o (6.1.3.c) Places CVCS18143, Excess Letdown Flow Divert Valve, in "DIVERT" (VB2).

(6.1.4) Opens FCV361, CCW to Excess Letdown HX (VB1).

(6.1.5) Verifies pot for HCV123, Excess Letdown Pressure Control, is closed (at 0)

(VB2).

(6.1.6) Opens 8166/8167, Excess Letdown isolation valves (VB2).

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 3 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 2 Page 4 of 15 Event

Description:

Regen Hx Isolation Valve, LCV459, Fails to midposition (continued)

Time Position Applicants Actions or Behavior (OP B1A:IV, "Place Excess Letdown in Service", continued)

BOP (6.1.7) Monitors RCDT 11 level via Aux Watch communication as flush is initiated.

Reads CAUTIONS regarding risk of thermal shock to Excess Letdown Heat Exchanger and the need to operate HCV123, slowly.

Read NOTES regarding monitoring and adjusting excess letdown once in service.

(6.1.8) Slowly opens HCV123 to establish excess letdown (VB2).

(6.1.9) Adjusts HCV123 to provide 40 gpm letdown at normal operating pressure (VB2).

Reads NOTE regarding indications of a leak at the Excess Letdown Heat Exchanger.

(6.1.10) Monitors containment sump level recorders for increased leakage into the sump.

(6.1.11) Places CVCS18143, Excess Letdown Flow Divert Valve, in "NORMAL" when RCDT 11 level has risen 13% (VB2).

(6.1.12) Notes Normal Letdown already isolated. May cross reference OP B1A:XII, CVCS Letdown System Establish Normal Letdown or Change Flow, Section 6.7 Remove Normal Letdown from Service.

ATC/BOP (6.1.1315 HCV123 and FCV128 (or HC459D) are now used to control Pzr Level (to end of scenario).

Proceed to the next event once Excess Letdown established, per the lead examiner.

    • Critical Task L181 NRC ESD201 r1.docx Page 4 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 3 Page 5 of 15 Event

Description:

CFCU 12 high stator/bearing temperature due to low CCW flow Time Position Applicants Actions or Behavior ATC Observes PK0121 (Contmt Fan Clr) and informs the Shift Foreman.

(AR PK0121," Contmt Fan Clr")

SRO Enters AR PK0121, "Contmt Fan Clr" (1.0) Identifies input 441 (Contmt Fans Temp PPC) goes to section 2.1, Fan High Temp.

ATC (2.1.1) Checks annunciator and PPC; determines the affected component is CFCU 12.

Note: The Crew may elect to secure CFCU 12 at any point after discovering the lack of CCW flow and rising CFCU bearing alarms.

BOP (2.1.2) Checks CCW flow on all CFCUs. Observes CFCU 12, FI35 (VB1, vertical section),

is several hundred gpm below normal and trending down.

(2.1.3) Checks containment ambient air temperature less than 120oF. (VB1, vertical section).

SRO Reads note regarding CFCU ability to be run at elevated temperatures (stator/bearings),

without affecting the component lifetime.

(2.1.4) Notes documentation is required if CFCU is left in service with high temperature alarms.

Note 1: Reactor Operators will be monitoring CFCU 12 stator and bearing temperatures using Plant Process Computer (PPC). Actual stator temperature at this point will vary based on crew pace through annunciator response, but is most likely above the limit described below.

Note 2: CFCU 12 will trip on overcurrent if fan is still running 7 min after stator temp reaches 380oF.

SRO (2.1.5) Notes need to contact engineering for evaluation if fan will be left in service with stator temperature above 293oF.

(2.1.6) Provides direction to shutdown CFCU 12 per OP H2:II, "Containment Fan Coolers Shutdown, Placing in Standby, and Clearing" or OP H2:I, "Containment Fan Cooler Units Make Available and System Operation".

Enters TS 3.6.6.C for one required CFCU system inoperable (7 day shutdown tech spec).

o CFCU 12 inoperable due to no CCW flow and beginning stages of damage to the motor.

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 5 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 3 Page 6 of 15 Event

Description:

CFCU 12 high stator/bearing temperature due to low CCW flow (continued)

Time Position Applicants Actions or Behavior (OP H2:II, "Containment Fan Coolers Shutdown, Placing in Standby, and Clearing") if used, else N/A BOP Reviews Precautions and Limitations.

(6.1) Stops CFCU 12, by pressing associated STOP control on VB1 (center).

ATC Acknowledges reflash on PK0121 for CFCU 12 high vibration (expected during coast down) after verifying input.

BOP Resets CFCU Vibration alarm to clear annunciator panel (VB1, lower).

Note 1: There is an 18 second time delay between switch press and actual CFCU start.

(OP H2:I, "Containment Fan Cooler Units Make Available and System Operation") if used, else N/A BOP Reviews Precautions and Limitations.

Reads three notes regarding delay time on start and expected alarms.

(6.4.1.a) Starts CFCU 15 by setting the associated speed select switch to LOW and depressing the switch to start the CFCU VB1 (center).

(6.4.1.b) Checks amps stable VB1 (center).

(6.4.1.c) May switch CFCU to high speed operation as follows:

o Presses "STOP" pushbutton for the CFCU 15.

o Immediately places SPEED SELECT switch to "HIGH" AND depresses switch to restart the CFCU.

o Checks current stabilizes.

o Returns speed select switch to "LOW".

(6.4.1.d) When PK0121, "Contmt Fan Clrs" alarm comes in for high vibration:

o Confirms alarm input is for high vibration on CFCU 15.

o Presses VIB ALARM RESET pushbutton to reset the alarm (VB1).

(6.4.2) Stops CFCU 12, by pressing associated STOP control on VB1 (center).

ATC Acknowledges reflash on PK0121 for CFCU 12 high vibration (expected during coast down) after verifying input.

BOP Resets CFCU Vibration alarm to clear annunciator panel (VB1, lower).

Proceed to the next event once Tech Specs addressed, per Lead Examiner.

    • Critical Task L181 NRC ESD201 r1.docx Page 6 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 4 Page 7 of 15 Event

Description:

SSPS relay actuation causes Inadvertent TDAFW Pump Start and Blowdown Sample Line Isolation (CT)

Time Position Applicants Actions or Behavior ALL Diagnoses TDAFW Pump Start from one or more of the following:

RCS Temperature lowers (secondary cooldown) (CC2, VB2 meters, PPC)

Feedflow / Steamflow rates diverging (CC3, VB3)

RED light on FCV95 illuminated indicating OPEN w/Tach reading ~ 4500 RPM (VB3)

TDAFW Discharge Pressure ~ 1200 psig, AFW Flow to S/Gs all reading top of scale (VB3)

Diagnoses Blowdown Sample Line Isolation from blowdown valve position indicator lights for FCV151, 154, 157, 160, 244, 246, 248, and 250 (VB3)

ALL Reviews primary and secondary side parameters and determines plant is not stable (i.e.

in a transient) based on the following indications:

o RCS Temperature lowers (secondary cooldown) (CC2, VB2 meters, PPC)

Reviews secondary side for changed conditions affecting secondary load/efficiency o Review of secondary side indications identifies Feedflow / Steamflow mismatch due to excess supply from the TDAFW pump. Numerous pressure, flow, and level gauges confirm the pump is actively feeding forward.

SRO/BOP Foreman implements TS 3.7.5.B, AFW System for one AFW train inoperable. Restore to operable status (72 hr).

Directs isolation of the TDAFW Pump. May reference OP D1:III, "Auxiliary Feedwater System - Shutdown and Clearing" or direct isolation by any of the following methods:

Closing the LCVs 106, 107, 108, and 109 to the individual S/Gs **

OR Closing steam supply valves FCV37 and FCV38 to leads 2 and 3 respectively **

OR Directing FCV95 closed in the field **

    • (Critical Task) (S1CT1) Shutdown TD AFW pump prior to any Steam Generator Overfill (S/G wide range greater than 100%)

Proceed to the next event once Tech Spec addressed, per the lead examiner.

    • Critical Task L181 NRC ESD201 r1.docx Page 7 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 5,6,7 Page 8 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open Time Position Applicants Actions or Behavior ALL Crew identifies RCS temperature lowering, pressurizer level and pressure lowering based on the following:

Annunciator Response Alarms:

PK0901, 0902, 0903, 0904 due to lowering S/G pressure and level PK0915, DIGITAL FEEDWATER CONT SYSTEM (due to feedflow/steam flow mismatch)

PK0516, PZR PRESSURE HI/LO (pressure low due to cooldown)

PK0406, PROTECT CHANNEL ACTIVATED (for Tave less than 554oF on loop 1 due to cooldown)

PK0414, REACTOR TRIP ACTUATED (if not manually actuated).

PK0821, SAFETY INJECTION ACTUATION (if not manually actuated w/reactor trip).

RCS Cooldown Indications: PPC, VB2, and CC1 trends Increased Steam Flow: PPC, VB3, CC3 steam flow meters, record, and trends SRO May direct manual reactor trip and shutting of MSIVs.

Implements EOP E0, "Reactor Trip or Safety Injection".

ALL Perform immediate actions.

(EOP E0, "Reactor Trip or Safety Injection")

SRO/ATC (1) Ensures reactor trip (trip bkrs open, rods on bottom, NIs decreasing) (VB2, CC1).

(2) Ensures turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps).

SRO/BOP (3) Ensures all vital 4kv buses energized (VB4, all vital buses white lights on mimic buses with power supplied by Startup).

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 8 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 9 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open (continued)(CT)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection", continued)

SRO/ATC (4) Checks if SI actuated (PK0821 ON) and reports Train B of SI failed to actuate.

SRO/BOP Closes MSIVs FCV41, 43, and 44.**

Reports FCV42 will not close. May dispatch field operator to manually isolate FCV42 following the guidance of EOP E0 or E2, Appendix L.

    • (Critical Task) (S1CT2, Stop RCS Cooldown) Partial SRO/BOP (5) Directs App E implemented (usually to BOP)(see page 13).

o Board manipulations are as follows:

Manually initiates Main Unit Trip (CC3)

Manually actuates Phase A (VB1) o Manually start the following pumps and CFCUs:

CCP 12 ASW 12 (after taking to manual)

SIP 12 RHR 11 CFCU 13 (and CFCU 15 if not running) o Manually positions the following valves:

8803B OPEN LCV112C CLOSED 8801B OPEN 8108 CLOSED 8805B OPEN Stops CCP 13 Closes Excess Letdown Isolation Valves 8166 and 8167 (VB2).

Switch LCV12 to CONT ONLY (VB3).

Main Feedwater Recirc Valves FCV53 & 54: OPEN (VB3).

Stops all but one CB Pp set.

Turn on Aux bldg vent charcoal filter preheater (VB4).

Throttles RCP seal injection flows to normal if needed (FCV128, to 8 13 gpm each, CC2).

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 9 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 10 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open (continued)(CT)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection", continued)

SRO/ATC (6) Checks RCS temperature NOT stable o Throttles AFW flow while maintaining minimum of 435 gpm flow**

o Dispatches field operator to close FCV42 per Appendix L (if not done earlier)**

(7) Checks Pzr PORVs and Pzr safeties (closed) / PORV block valves (all open and power available), and no elevated tailpipe temps or sonic flows on safeties/PORVs (VB2 -

upper panel, far right); checks Pzr sprays closed (CC2).

(8) Checks RCP trip criteria (RCS pressure [VB2, PPC] < 1300 psig and SI or ECCS CCPs running; determines RCPs should be secured (VB2).

(9) Checks for faulted S/Gs o Notes MSIV FCV42 could NOT be closed from the control room.

o S/G pressure continuing to lower on S/G 12 (VB3).

    • (Critical Task) (S1CT2, Stop RCS Cooldown) Partial SRO Transitions to EOP E2 (next page).

(EOP E2, "Faulted S/G Isolation")

SRO Reads three CAUTIONS prior to step 1.

SRO/ATC (1) Checks if MSIV FCV42 is still open.

o Dispatches field operator to close FCV42 per Appendix L (if not done earlier)**

o Notes bypasses are closed (VB3, upper panel, left side).

(2) Checks for any intact S/G - notes S/G 11, 13, and 14 are intact.

    • (Critical Task) (S1CT2, Stop RCS Cooldown) Partial SRO/ATC (3) Identifies 12 S/G as faulted (VB3, pressure is still dropping in uncontrolled manner, or completely depressurized at this point).

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 10 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 11 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open (continued)(CT)

Time Position Applicants Actions or Behavior (EOP E2, "Faulted S/G Isolation")

SRO Reads caution regarding steam supply for TDAFW; determines it does not apply.

(4) Directs Reactor Operator to Implement Appendix HH to isolate the Faulted S/G (see page 15).

SRO/ATC (5) Checks CST level > 10% (VB3, upper panel, center area meter and recorders).

(6) Checks S/Gs not ruptured:

o (6.a) Notes NO valid alarm on PK1106, PK1117, or PK1118.

o (6.b) No upward trends on RE19/15/15R/7174.

o (6.c) Directs Chemistry to sample S/Gs per CAP AP1.

(6.c.1) Ensures Containment Isol Phase A RESET (VB1).

(6.c.2) Opens Containment Instrument Air Isolation Valve, FCV584 (VB4).

(6.c.3) Opens inside containment S/G blowdown valves: FCV760, 761, 762, 763 (VB4).

(7) Checks if ECCS flow should be reduced:

o (7.a) RCS Subcooling GREATER THAN 20°F (SCMM or Appendix C).

o (7.b) Secondary heat sink satisfied by either 435 gpm AFW flow or NR level in at least one S/G greater than 15%.

o (7.c) RCS Pressure STABLE OR RISING.

o (7.d) PZR Level GREATER THAN 12%.

o (7.e) Transitions to EOP E1.1, "SI TERMINATION".

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 11 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 12 of 15 Event

Description:

SI Termination (CT)

Time Position Applicants Actions or Behavior (EOP E1.1, "Terminate SI")

SRO/ATC (1) Checks SI Reset (VB1).

(2) Aligns Charging:

o (a) Checks ECCS CCPs running (VB2).

SRO/BOP (2) Aligns Charging:

o (b) Resets vital 4kV auto transfer relays for all vital buses (VB4).

SRO/ATC (2) Aligns Charging:

o (c) Stops all but one ECCS CCP (VB2).

o (d) Notes CCP 13 already shutdown (VB2).

(3) Checks RCS Pressure STABLE or RISING (VB2 or PPC).

(4) Isolates charging injection (a) Closes 8803A/B (VB1)(S1CT3)**

(b) Closes 8801A/B (VB1)(S1CT3)**

    • (Critical Task) (S1CT3) Terminate SI prior to rupture of PRT by closing 8801A/B or 8803A/B.

(Note: CT is met by closing either 8801A/B OR 8803A/B.)

The scenario is terminated once Critical Task S1CT3, Terminate SI, is complete per Lead Examiner

    • Critical Task L181 NRC ESD201 r1.docx Page 12 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 13 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open (continued)

Time Position Applicants Actions or Behavior (EOP E0, "Appendix E ESF Auto Actions, Secondary and Auxiliaries Status")

BOP Implements "App E (ESF Auto Actions, Secondary and Auxiliaries Status)":

(1) Notifies Plant Personnel.

o Checks no personnel in Containment (part of turnover; may not voice); Announces trip/SI on PA system.

(2) Checks main generator - tripped.

o PK1401 OFF, output breakers OPEN, Exciter Field Breaker OPEN (CC3 right side) o Manually initiates Main Unit Trip (CC3).

(3 & 4) Ensures Phase A and Containment Vent Isolation complete (VB1, ESF status lights, red lights Trn A ON, Trn B OFF, various white lights ON).

o Manually actuates Phase A (VB1).

(5) Ensures ESF (SI) actuation complete (VB1, ESF status lights, red light ON, various white lights ON).

o Manually start the following pumps and CFCUs:

CCP 12 ASW 12 (after taking to manual)

SIP 12 RHR 11 CFCUs 13, (and CFCU 15 if not running) o Manually positions the following valves:

8803B OPEN LCV112C CLOSED 8801B OPEN 8108 CLOSED 8805B OPEN (6) Verifies Feedwater isolation complete (F.W. Isolation and S.G. Level Portions of Monitor Light Box C: red lights ON, white lights OFF (VB1).

(continued on next page)

    • Critical Task L181 NRC ESD201 r1.docx Page 13 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 6 Page 14 of 15 Event

Description:

MSLB Outside Containment, downstream of MSIVs; MSIVs Fail Open (continued)

Time Position Applicants Actions or Behavior (EOP E0, Appendix E ESF Auto Actions, Secondary and Auxiliaries Status)

BOP (7) Determines Containment Spray and Phase B Isolation is NOT required (Contmt Isol, Phase B portion of Monitor Light Box D: red lights are OFF (VB1)).

(8) Checks Main Steamline Isolation complete (Main Steam Isolation portion of Monitor Light Box D: red light ON, white light ON for FCV42 (VB1)).

o Dispatches field operator to close FCV42 per Appendix L if not previously directed.

(9) Checks AFW status o Both MDAFW pumps running with flow throttled to maintain greater than 435 gpm min flow (VB3).

(10) Checks ECCS flows (charging injection (VB2), SI, RHR (VB1) o Shuts down CCP 13 (VB2).

(11) Reports ESF and AFW status to the Shift Foreman (Shift Foreman may direct operator to continue on in Appendix E, or redirect to higher priority tasks).

(12) Isolates excess letdown - 8166 and 8167 (VB2).

(13) Checks secondary systems MFPs tripped (VB3, green lights ON), stops all but one CB Pp set, takes LCV12 control switch to CONT ONLY, takes FCV53 and FCV54 to RECIRC.

(14) Verifies proper operation of Aux Bldg and Control Rm vent systems (VB4 vent status light panel white lights); turns on aux bldg vent charcoal filter preheater (VB4 lower panel, left side) and verifies containment iodine fans secured (VB4, lower panel).

(15) Verifies available DGs running normally (VB4).

(16) Verifies vital batteries indicate normal voltage and positive charging amps VB5).

(17) Verifies MSRs reset (Triconex HMI)(CC3).

(18) Throttles RCP seal injection flows if needed (FCV128, to 813 gpm each, CC2).

(19) Checks PK1104 NOT IN (SFP alarm).

(20) Notifies Shift Foreman of completion.

(Board Operator will rejoin crew upon completion of Appendix or when called upon by Shift Foreman)

    • Critical Task L181 NRC ESD201 r1.docx Page 14 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 1 Event No.: 5,6 Page 15 of 15 Event

Description:

EOP E2, "Appendix HH, Isolate Faulted Steam Generator" (CT)

Time Position Applicants Actions or Behavior EOP E2, "APP HH, Isolate Faulted S/G" BOP (1) Isolates faulted S/G 12:

o (1.a) Ensures MFIVs FCV439 closed.

o (1.b) Ensures SGBD valves FCV761, 154, and 248 (IC, OC, and sample) closed.

o (1.c) Ensures (PCV20) 10% steam dump closed.

o (1.d) Ensures AFW control valves isolated o Ensures closed TDAFW AFW LCV107** (unless closed earlier) o Closes MDAFW AFW LCV111.**

o (1.e) Ensures Steam Supply Valves from S/G 12 is isolated.

o Ensures closed FCV37** (unless closed earlier)

(1.f) Ensures AFW flow still available to S/Gs 11, 13, & 14.

o (1.g) Informs Shift Foreman S/G isolation complete for S/G 12.

    • (Critical Task) (S2CT2, Stop RCS Cooldown) Partial BOP (2) Removes WR Thot input to SCMM for loop2 (behind boards, PAMS panel behind VB3).

o Goes to PAM4 panel.

o Presses Configuration Summary, Presses Failed S/G.

o Presses the PB for the Thot to be disabled (2), Presses Disable Loop 2.

    • Critical Task L181 NRC ESD201 r1.docx Page 15 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION X IC RESTORE IC47 2%; MOL, CB - See Turnover Sheet X Setup N/A CFCU 11 OOS; CFCU 12, 13, 14 running in HIGH; CFCU 15 is OFF.

The Plant Abnormal Status Board for Surveillance Requirements NONE Copies of Procedures, Attachments; Appendixes; Foldout Pages; OP B1A:IV, D1:III, H2:II, PK0121, AP18, EOP E0, E2, E1.1 Annunciator Response Procedures and commonly used forms are in binders and NOT Marked up X 0 min Tools > Simple SBT Before crew takes the watch.

Use Simple SBT, Data Recorder File: sbt_sim.drb, min 960 iterations (30 sec).

Critical Task Specific Data Capture:

S1CT1: TDAFW flow and S/G levels S1CT2: FCV42 position, AFW flow S1CT3: ECCS Injection Flow X 0 min Lesson L181 NRCS1.lsn After SFM reports the crew has taken the watch, load session MALS, OVRs, etc.

by FILE or MANUALLY (below)

X Evt1: Raise Power Placeholder only (approx. 3 min after taking watch per lead examiner)

X Evt2: LCV459, Fails LCV459, Fails to midposition to midposition (Once power raised 0.5%, per lead examiner)

X Evt3: CFCU 12 High Stator and bearing temperatures ramp up over 23 minutes. CFCU will trip on Stator Temp overcurrent if it has not been shut down within 7 minutes of reaching 380oF.

(once Excess Ltdn established, per Lead If crew does not request removing CFCU 12 from service, enter command to Examiner) have CFCU 12 trip on OC when it restarts due to SI signal.

X Evt4: Inadvertent Inadvertent start of TDAFW pump and partial blowdown isolation start of TDAFW pump (Once Evt2 TS have been addressed, per lead examiner)

X Evt5: MSLB on S/G 1 MSLB downstream of MSIVs.

2 (Once Evt4 TS have been addressed, per lead examiner)

(cont on next page)

L181 NRC ESD201 r1.docx Page 16 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions (cont)

X = manual entry required A = activate from EVENT file TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION Evt6: MSIVs Fail All four MSIVs fail open. FCV41, 43, and 44 can be closed in the Open (post trip) ) control room. Crew will need to call to have FCV42 closed.

DO NOT CLOSE FCV42 UNTIL CREW HAS ENTERED E2.

Evt7: SI, Train B fails Crew will manually initiate Safety Injection in response to MSLB.

to actuate (post trip) Failure will require manual starting of Train B ECCS pumps and manual alignment of valves.

L181 NRC ESD201 r1.docx Page 17 of 20 Rev 1

Diablo Canyon Power Plant Operations Shift Log Unit 1 Unit 1 Days at Power: 0 Days Operating Mode: 2 Gross Generation: 0 MWe Power Level: 2% Net Generation: 0 MWe Today - Dayshift Shift Manager Turnover:

PRA RISK STATUS NEXT SHIFT: Green GRID STATUS NEXT SHIFT: Normal AVERAGE RCS CALCULATED LEAKRATE: 0.01 gpm CONDENSER INLEAKAGE: < 0.01 gpd CONDENSER D/Ps: NW 5.7 SW 5.7 NE 5.7 SE 5.8 PSID MAIN GENERATOR H2 USAGE: 325 scfd / 327 scfd 5 day ave SPENT FUEL POOL: Temp = 80oF; Time to 200oF = 30 hrs using actual temp (F ID7A)

NEW EMERGENT WORK:

CFCU 11 OOS for Bearing Replacement SHUTDOWN TECH SPECS / ECGS:

None ECG ACTIONS THAT IF COMPLETION TIME NOT MET ECG 0.3 IS ENTERED:

None TURNOVER ITEMS:

Reactor trip occurred 7 days ago.

The reactor was declared critical and power stabilized at 2% power late last shift.

MFP 11 is in service and supplying feedwater.

The unit is currently aligned to Startup Power (230 kV).

OP L0 has been signed off for Mode 1 Entry.

No one is in Containment.

CFCU 11 OOS for Bearing Replacement.

PRIORITY ITEMS FOR NEXT SHIFT:

Continue with OP L3, step 6.28, and stabilize power at approximately 8%.

ANNUNCIATORS IN ALARM:

There are no unexpected alarms all current alarms are consistent with current mode and power level.

Shift Foreman Turnover 0B TURNOVER ITEMS:

U1: 2% and preparing to raise power to approximately 8%.

U2: maintain 100%.

REACTIVITY MANAGEMENT:

Time in core life: _MOL_.

Power History: Previously at 100% for 17 days. Currently power level is approximately 2% following a reactor trip a week ago (MFP trip during maintenance).

Boron concentration is _1259 ppm_ from a sample taken 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago.

Control Rod Height: 158 steps on CBD.

Rod motion: used to maintain current power level and to raise power to 8%.

CONDITIONAL SURVEILLANCES & INCREASED MONITORING:

None OTHER ABNORMAL PLANT STATUS None

Appendix D (rev 11) Scenario Outline Form ESD1 Facility: Diablo Canyon (PWR) Scenario No: 2 OpTest No: L181 NRC Examiners: Operators:

Initial Conditions: 75% Power, MOL with AFW 12 cleared for a bearing oil leak Turnover: At 75% power for SCCW HX Clearance Event Malf Event Event Description No No. Type* (See Summary for Narrative Detail) 1 H5ESP_INIT_455G 0 ramp=20 I (ATC, Pressurizer Spray Valve PCV455A setpoint failure causing RCCIPCSDI_H5DHC455GSPUPTFFREEZE SRO) RCS pressure to slowly lower (AR PK0516, OP AP13).

TRUE 2 XMT_PZR24_3 ramp=1 TS, I PT474, Pressurizer Pressure Transmitter, Fails Low (OP (BOP, AP5, TS 3.3.1.E, M, 3.3.2.D, 3.4.11.B).

SRO) 3 XMT_CVC2_3 ramp=75 I (BOP, PT135 Fails High causing letdown pressure control valve SRO) to go full open (AR PK0421).

4 MAL_RCS4H 30.0 TS, C 30 gpm SGTL on loop 4; plant shutdown required (OP AP (ALL) 3, OP AP25, TS 3.4.13.B).

5 MAL_RCS4H 400.0 ramp=60 M (ALL) Tube leak grows to 400 gpm rupture during ramp offline.

6 MAL_EPS5A_2 DIFFERENTIAL cd='H_V5 C (BOP, 12 kV Bus D feeder breaker trips on differential on transfer

_194B_1' delay=10 SRO) to startup power.

7 MAL_EPS4D_2 DIFFERENTIAL C (ALL) 4kV Bus G differential trip on transfer to startup power.

cd='h_v4_221r_1'

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor L181 NRC ESD102 r2.docx Page 1 of 4 Rev 2

Appendix D (rev 11) Scenario Outline Form ESD1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) (from form ES3014) Actual Attributes

1. Total malfunctions (5-8) (Events 1,2,3,4,5,6,7) 7
2. Malfunctions after EOP entry (12) (Events 6,7) 2
3. Abnormal events (1-4) (Events 1,2,3,4) 4
4. Major transients (12) (Event 5) 1
5. EOPs entered/requiring substantive actions (1-2) (E3) 1
6. EOP contingencies requiring substantive actions (0-2) 0
7. Critical tasks (2-3)(See description below) 3 Critical Task Justification Reference (S2CT1) Isolate the ruptured steam SG inventory increase leads to water release W Margin to Overfill generator from the intact steam generators through the S/G PORV or safety valve(s) or to SG (CNCRA0553 Rev1) prior to commencing cooldown of the RCS overfill, which would seriously compromise the SG W Offsite Doses (CN in step 10.b (10% steam dump) by as a fissionproduct barrier and complicate CRA0554) completing the following: mitigation. SGTR UFSAR 15.4.3 WCAP17711NP Isolate feedwater by ensuring closed:

LCV109 (TDAFW Level Control Valve)

LCV113 (MDAFW Level Control Valve)

Isolate steam flow by closing FCV44 (MSIV)

(S2CT2) Perform RCS cooldown at Transition to contingency procedures to address W Margin to Overfill maximum rate to CETC target temperature inadequate subcooling or Pressurized Thermal (CNCRA0553 Rev1) specified in E3, step 6, using steam dumps Shock conditions results in delaying RCS SGTR UFSAR 15.4.3 such that RCS subcooled margin still exists depressurization and SI termination. This delay WCAP17711NP following the cooldown. allows excess inventory in the ruptured S/G to continue to increase, with the potential of Maximum rate cooldown requires 10% steam dumps challenging SG overpressure components or on intact S/Gs to be at least 90% open.

causing an overfill condition to occur.

(S2CT3) Depressurize the RCS to meet Failure to stop reactor coolant leakage into a W Margin to Overfill (CN depressurization criteria specified in E3, ruptured SG by depressurizing the RCS complicates CRA0553 Rev1)

App GG prior to stopping any Safety mitigation of the event and constitutes a SGTR UFSAR 15.4.3 Injection pump. significant reduction of safety margin beyond that WCAP17711NP irreparably introduced by the scenario.

Per NUREG1021, Appendix D, if an operator or crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the postscenario review.

L181 NRC ESD102 r2.docx Page 2 of 4 Rev 2

SCENARIO

SUMMARY

- NRC #2

1. Pressurizer Spray Valve controller failure causes PCV455A to ramp open and RCS pressure begins to lower slowly. PK0516, PZR PRESSURE HI/LO alarms when RCS pressure reaches 2210 psig. The crew follows AR PK0516 guidance to take manual control and close the spray valve. The crew may follow up with the actions of OP AP13, Malfunction of Reactor Pressure Control System or OP AP5, Malfunction of Eagle21 Protection or Control Channel, to restore pressure to normal using manual control.

Alternately, the crew may diagnose the failure prior to the annunciator response activating and enter OP AP13 directly which also directs taking manual control and closing the spray valve.

2. PT474, Pressurizer Pressure Transmitter, fails low bringing in multiple Annunciator Alarms. There is no transient associated with this failure, but the failure has significant Operational implications due to its input function as part of various Reactor Protection logic schemes. When failed low, PT474s interlock function prevents Pressurizer PORVs PCV455C and PCV474 from opening on a valid high pressure signal; only PCV456 will still function. The Shift Foreman may elect to enter any of the associated Annunciator Response alarms, but in all cases, will be directed to OP AP5, Malfunction of Eagle21 Protection or Control Channel, which provides information regarding indications, controls, and a listing of the associated Tech Specs:

TS 3.3.1.E, PC474C High Press Trip & TC 441C OT Delta T Trip (72 hrs).

TS 3.3.1.M, PC 474A Low Press Trip (72 hrs).

TS 3.3.2.D, PC 474D Low Press S.I. (72 hrs).

TS 3.4.11, PC 474B PORV Press Interlock o PCV474 (nonclass I), 3.4.11.B1 & B2 to close & remove power from associated block valve (1 hr) o PCV455C (class I), 3.4.11.B1 & B2 to close & remove power from associated block valve (1 hr);

3.4.11.B3 to return to OPERABLE status (72 hrs).

3. PT135, Transmitter for Letdown Pressure Control Valve, fails High causing letdown pressure control valve to go full open and letdown flow to rise. AR PK0421, LETDOWN PRESS / FLOW TEMP comes into alarm for Letdown Heat Exchanger Outlet Pressure High as a result of the failed transmitter, while actual letdown pressure lowers to approximately 90 psig as a result of full open control valve response.

Letdown flow increases approximately 8 gpm above normal, resulting in a charging/letdown mismatch.

Procedural guidance in AR PK0421 directs crew to take manual control of PCV135. Crew performs diagnostic brief to determine nature of the malfunction as well as actions required to restore letdown pressure back to normal band.

4. Steam Generator 14 develops a 30 gpm tube leak as indicated by rising counts on various radiation monitors. The crew enters OP AP3, Steam Generator Tube Failure. Shift Foreman determines TS 3.4.13.B, RCS Operational Leakage applies and enters OP AP25, Rapid Load Reduction or Shutdow for the ramp offline.
5. During the ramp the tube leak develops into a 400 gpm rupture. The crew determines the leak is substantial in size based on a rapid drop in pressurizer level. The Shift Foreman directs a reactor trip and safety injection and the crew enters EOP E0, Reactor Trip or Safety Injection.

(continued)

L181 NRC ESD102 r2.docx Page 3 of 4 Rev 2

SCENARIO

SUMMARY

- NRC #2

6. On the transfer to start up power, 4 kV bus G experiences a differential fault. 12kV bus D also trips on differential causing a loss of vacuum as well as tripping of RCPs 12 and 14.
7. The crew transitions to EOP E3, Steam Generator Tube Rupture, based on RM74 and rising S/G 14 level, where they address the following critical tasks:

(S2CT1) Isolate the ruptured steam generator from the intact steam generators prior to commencing cooldown.

(S2CT2) Perform RCS cooldown at maximum rate to CETC target temperature.

(S2CT3) Depressurize the RCS to meet depressurization criteria specified in Appendix GG.

The scenario is terminated once the crew has completed critical task S2CT3.

L181 NRC ESD102 r2.docx Page 4 of 4 Rev 2

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 1 Page 1 of 21 Event

Description:

Pressurizer Spray PCV455A setpoint fails low Time Position Applicants Actions or Behavior ALL Diagnoses spray problem from:

RCS Pressure lowering (VB2, PPC).

PK0516 actuation when RCS pressure reaches 2210 psig.

Spray valve indicating open (CC2).

(AR PK0516, "PZR PRESSURE HI/LO") if entered, else N/A SRO (2.1.1) Advises crew that entry into EOP E0 is required in the event of a reactor trip.

Note: Crew may refer to AR PK0516 prior to annunciator actuating at 2210 psig, in which case the following step would not apply.

SRO/BOP (2.1.2) Notes RCS pressure is less than 2210 psig.

o Checks PORVs closed (VB2).

o Checks both spray valves closed Notes Pressurizer Spray Valve, PCV455A is NOT closed (CC2).

Takes manual control and closes PCV455A.

Note: Turning on pressurizer backup heaters will allow crew to restore RCS pressure to the normal bank. Manual control, however, will be required for the duration of the scenario.

SRO/ATC (2.1.2) Notes RCS pressure is less than 2210 psig.

o Turns on PZR backup heaters (CC1).

SRO (2.1.3) Checks if RCS pressure is less than 2175 psig.

o If yes, references TS 3.4.1 for RCS departure from nucleate boiling limits.

SRO/ATC (2.1.4) Verifies HC455K, Pzr Pressure Controller, set at 78.8% Setpoint (2235 psig).

SRO/BOP (2.1.5) Performs a channel check of all Pzr pressure channels (VB2).

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 1 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 1 Page 2 of 21 Event

Description:

Pressurizer Spray PCV455A setpoint fails low (continued)

Time Position Applicants Actions or Behavior SRO/ATC Reads note regarding PCS automatic control channel selection.

(2.1.6) Checks pressurizer pressure channel readings for channel check.

SRO o Goes to OP AP5, "Malfunction of Eagle 21 Protection or Control Channel."

(OP AP5, "Malfunction of Eagle21 Protection or Control Channel") if used, else N/A SRO/ATC (1) Determines primary and secondary control systems are NOT controlling properly in AUTO.

o Takes manual control of PCV455A and closes (if not done previously).

SRO/BOP (2) Determines that the failure is not Eagle21 related (PK0601 and PK0603 are OFF).

SRO/ATC (3) Determines failure is associated with Pressurizer Pressure, but failure does not affect the currently selected T channel (VB2).

SRO/BOP (4) Verifies steam dumps are not open.

SRO (5) Notifies I&C of apparent pressurizer spray control failure.

Reads CAUTION regarding Eagle 21 design failure impact to outputs prior to step 6.

(6) Notes requirements to take channel OOS prior to maintenance.

SRO/ATC (78) Determines remaining steps of procedure do not apply and exits OP AP5.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 2 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 1 Page 3 of 21 Event

Description:

Pressurizer Spray PCV455A setpoint fails low (continued)

Time Position Applicants Actions or Behavior (OP AP13, "Malfunction of Reactor Pressure Control System") if entered, else N/A SRO (1) Notes there are no load changes in progress.

SRO/BOP (2) Checks PZR PORVs - CLOSED (VB2).

(3) Checks PZR Safety Relief Valves (VB2):

o (3.a) Sonic flow indicators - approx. ZERO.

o (3.b) Tail pipe temp - LESS THAN 185°F.

SRO Reads Caution regarding RCPs and normal spray supply.

SRO/ATC (4.a) Checks normal PRZ spray valves - CLOSED (CC2):

o PCV455A o PCV455B Notes 455A is NOT closed.

Takes manual control and closes valve.

SRO/BOP (4.b) Checks auxiliary PRZ spray valves - CLOSED (VB2):

o 8145 and 8148 SRO/ATC (5) Checks Pressurizer Heaters (CC1):

o (5.a) Notes normal power is available.

o (5.b) Notes PZR pressure is LESS THAN 2250 psig.

o (5.c RNO) If PZR pressure is NOT GREATER THAN 2210 psig; turns on all available backup PZR heaters.

SRO/BOP (6) Checks all pressure control channels operable (VB2, PCS).

SRO/ATC (7.a) Restores RCS Pressure to normal band (22102260 psig) using manual control.

Proceed to the next event once Pressurizer Pressure under control, per Lead Examiner)

    • Critical Task L181 NRC ESD202 r1.docx Page 3 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 2 Page 4 of 21 Event

Description:

PT474, Pressurizer Pressure Transmitter, Fails Low Time Position Applicants Actions or Behavior (AR PK0406, "PROTECT CHANNEL ACTIVATED") if entered, else mark N/A SRO (1.0) Goes to section 2.1, General Actions.

(2.1.1,2) Notes Annunciator Response contains reactor trip criteria and advises Crew.

(2.1.3) Notes there are no surveillance tests in progress to cause the alarm.

SRO/ATC (2.1.4) Checks PPC for ALL protection channel bistables "OFF".

(2.1.5) Identifies failed channel.

o Refers to TS 3.3.1, "Reactor Trip System (RTS) Instrumentation".

o Goes to OP AP5, "Malfunction of Protection or Control Channel" (see pg 5)

(AR PK0516, "PZR PRESSURE HI/LO") If entered, else mark N/A SRO (1.0) Goes to section 2.1, General Actions.

(2.1.1) Notes Annunciator Response contains reactor trip criteria and advises Crew.

SRO/ATC (2.1.2,3) Notes actual pressurizer pressure is less NOT less than 2210 psig (PORV/spray actuation) or 2175 psig (RCS departure from nucleate boiling limits).

(2.1.4) Verifies HC455K, Pzr Pressure Controller, set at 78.8% Setpoint (2235 psig).

SRO/BOP (2.1.5) Performs a channel check of all Pzr pressure channels; identifies PI474 reading bottom of scale (VB2).

Reads NOTE regarding PCS Control Set input selection scheme (Median Select, based on 2nd highest out of channels) and possible failure scheme (3 of 4 inputs detected bad).

(2.1.6) Checks for Pressurizer pressure channel abnormal reading. Identifies PI474 reading bottom of scale (VB2).

o Check HC455K in AUTO and controlling Pzr pressure with PACT and PREF nearly matched (CC2).

Goes to OP AP5, "Malfunction of Protection or Control Channel" (see next page)

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 4 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 2 Page 5 of 21 Event

Description:

PT474, Pressurizer Pressure Transmitter, Fails Low (continued)

Time Position Applicants Actions or Behavior (AR PK0621, "PROCESS CONTROL SYS TROUBLE") If entered, else mark N/A SRO (1.0) Goes to Section 2.1, PCS Rack Channel Trouble.

SRO/BOP (2.1.1) Checks PCS HMI on CC4 to determine alarming channel.

(2.1.2) May check PY17N (behind hot shutdown panel) for no breakers tripped.

(2.1.3) REFERs to Attachment for individual alarm input.

o Identifies mPzrPres_Dev, PT455/PT456/PT457/PT474 Pzr Press Channel Deviation (NON SAFETY RELATED CONTROL SET 1) o Notes input has no associated automatic or Operator actions.

(OP AP5, "Malfunction of Eagle21 Protection or Control Channel")

SRO/ATC (1) Determines primary and secondary control systems are controlling properly in AUTO.

SRO/BOP (2) Determines that the failure is not Eagle21 related (PK0601 and PK0603 are OFF).

SRO/ATC (3) Determines failure is not associated with the selected T channel (VB2).

SRO/BOP (4) Verifies steam dumps are not open as result of instrument failure or spurious actuation.

SRO (5) Notifies I&C of apparent pressurizer controller failure.

Reads CAUTION regarding Eagle 21 design failure impact to outputs prior to step 6.

(6) Notes requirements to take channel OOS prior to maintenance.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 5 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 2 Page 6 of 21 Event

Description:

PT474, Pressurizer Pressure Transmitter, Fails Low (continued)

Time Position Applicants Actions or Behavior (OP AP5, "Malfunction of Eagle21 Protection or Control Channel", continued)

SRO/ATC (7) Uses Attachments 5.1 and 5.2 to determine affected indicator o (a) Places Outof-Service (OOS) sticker on the following:

PI 474, Pressurizer Pressure Indicator (VB2).

PR 455, Pressurizer Pressure Recorder (CC2) from PCS.

SRO/BOP Reads NOTE regarding inoperable PZR PORV(s) requiring TS actions to be completed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of inoperability.

(8) Uses Attachment 5.1, pg 16, and Attachment 5.2, pg 7, to determine required TS/ECG actions for the inoperable channel:

o TS 3.3.1.E, PC474C High Press Trip & (TC 441C OT Delta T Trip) (Place channel in trip within 72 hrs).

o TS 3.3.1.M, PC 474A Low Press Trip (Place channel in trip within 72 hrs).

o TS 3.3.2.D, PC 474D Low Press S.I. (Place channel in trip within 72 hrs).

o PC 474B PORV Press Interlock:

PCV455C & PCV474: TS 3.4.11.B.1 & B.2 (Close associated block valves and remove power within 1 hr).

PCV455C: also requires TS 3.4.11.B.3 (Since this is a Class I PORV, must restore to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />).

o Identifies affected controls:

PCS (PM 474A) Pzr Press Control.

PORV 455C & 474 Low Press Interlock.

SRO Directs board operator to implement OP A4A:III, "Pressurizer - Shutdown and Clearing" to close and remove power from block valves associated with PCV455C (Section 6.4) and 474 (Section 6.6).

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 6 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 2 Page 7 of 21 Event

Description:

PT474, Pressurizer Pressure Transmitter, Fails Low (continued)

Time Position Applicants Actions or Behavior (OP A4A:III, "Pressurizer - Shutdown and Clearing")

BOP Section 6.4 - "RCS1PCV455C - Removing from Service at Power", step 6.4 (6.4.3) Places PCV455C control switch to CLOSE (VB2)

(6.4.4.a) Closes 8000B, Block Valve B.

(6.4.4.b) Contacts field operator to open associated breaker 521G46.

BOP Section 6.6 - "RCS1PCV474 - Removing from Service at Power", step 6.6.

(6.6.3) Places PCV474 control switch to CLOSE (VB2)

(6.6.4.a) Closes 8000A, Block Valve A.

(6.6.4.b) Contacts field operator to open associated breaker 521F40.

Proceed to the next event once Tech Specs are addressed, per Lead Examiner

    • Critical Task L181 NRC ESD202 r1.docx Page 7 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 3 Page 8 of 21 Event

Description:

PT135, Transmitter for Letdown Pressure Control Valve, Fails High Time Position Applicants Actions or Behavior Note: PK0421 already in alarm from PT474 failure (Event 2), but may be entered.

(AR PK0421, "LETDOWN PRESS / FLO TEMP")

SRO Enters AR PK0421, "LETDOWN PRESS / FLO TEMP" o (1.0) Identifies input 393 (Letdn HX Outlet Press Hi) and goes to section 2.1, General Actions.

o Reads two CAUTIONS (potential reactivity impact of letdown temperature excursions and elevated dose rate concerns if argon injection continues with letdown isolated.

o (2.1.1) Notes if letdown is isolated, argon injection must be isolated as well.

o (2.1.2) Notes requirement to go to seals only charging if letdown gets isolated.

Note: Crew may call for diagnostic brief during annunciator response implementation ALL (2.1.3) Checks for indications of a letdown line break:

o Letdown flow decrease - NO, flow has risen approximately 8 gpm.

o Letdown pressure decrease - PI135 reads high while letdown flow rise indicates pressure has fallen.

o Containment sump level increasing - NO, sumps remain stable.

o VCT level decreasing - NO, VCT level begins to rise very slowly.

Determines indications are not consistent with a letdown leak.

SRO/BOP (2.1.4) Checks if letdown HX outlet pressure is high.

o Notes PI135 reads high, but letdown flow behavior indications the opposite o Takes manual control of PCV135 (VB2).

o Adjusts PCV135 using alternate indications (Letdown flow rate, net charging, etc. ) or from knowledge of normal demand setting for PCV135 Hand Controller (VB2).

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 8 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 3 Page 9 of 21 Event

Description:

PT135, Transmitter for Letdown Pressure Control Valve, Fails High (continued)

Time Position Applicants Actions or Behavior (AR PK0421, "LETDOWN PRESS / FLO TEMP", continued)

SRO Notes letdown flow can be controlled with PPCV135 in manual from previous step.

o (2.1.5) Step is N/A letdown flow is controlling properly in manual; it is not necessary to isolate letdown.

SRO/ATC Determines remainder of PK steps do not match plant conditions o (2.1.6) Step is N/A Letdown Heat Exchanger outlet temperature is NOT high (normal band).

o (2.1.7) Step is N/A Charging flow was slightly low; may adjust as needed to maintain Pressurizer level within established bands.

o (2.1.8) Step is N/A Charging appears norm (not lost).

SRO/BOP Determines remainder of PK steps do not match plant conditions:

o (2.1.9) Step is N/A There are no indications that RV8117 has lifted (PRT temperature, level, and pressure are all normal).

o (2.1.10, 11, 12, 13) Step is N/A Letdown is not at risk; normal Letdown alignment should be maintained.

SRO May review probable causes for the alarm and identify PT135 failed high.

May reference OP AP5, Malfunction of Eagle 21 Protection or Control Channel to aid in diagnostics.

(OP AP5, "Malfunction of Eagle21 Protection or Control Channel") if used, else mark N/A Note: Only step 1 is applicable to the malfunction; remaining steps have not been listed.

SRO/ATC (1) Determines primary and secondary control systems was NOT controlling properly in AUTO, performs RNO actions:

o Takes manual control of PCV135 (VB2).

o Adjusts PCV135 using alternate indications (Letdown flow rate, net charging, etc. ) or from knowledge of normal demand setting for PCV135 Hand Controller (VB2).

Proceed to the next event once PCV135 is being controlled properly in MANUAL, per Lead Examiner

    • Critical Task L181 NRC ESD202 r1.docx Page 9 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 4 Page 10 of 21 Event

Description:

30 gpm SGTL on loop 4 Time Position Applicants Actions or Behavior ALL Diagnoses Steam Generator Tube Leak from one or more of the following:

Increased charging flow (PPC, CC2).

Air ejector offgas hirad in alarm (PPC, RM15/15R) (PK1106).

Steam generator blowdown hirad and/or isolation (PPC, RM19,23) (PK1117).

ATC Observes PK1106 input 423 (SJAE HiRad) alarming and informs the Shift Foreman.

ATC/BOP May check PPC and/or VB2 Recorders (lower left) for upscale readings/ trends on rad monitors.

(AR PK1106, "SJAE HIRAD", starting at step 2.1) if entered, otherwise this section is N/A SRO/BOP (2.1.1) Checks for upscale readings on both RM15 and 15R (PPC, RCDR3 VB2 lower left) (both are in alarm; may be over ranged).

o (2.1.1.a) Implements OP O4, "Primary to Secondary Steam Generator Tube Leak Detection".

o (2.1.1.b) Notifies Chemistry of abnormal condition.

o (2.1.1.c) Transitions to OP AP3, "Steam Generator Tube Failure".

Note: Review of OP O4 shutdown criteria is also covered as part of OP AP3, "Steam Generator Tube Failure" (if not addressed during AR PK1106 response)

BOP Reviews OP O4, "Primary to Secondary Steam Generator Tube Leak Detection" for action levels and shutdown criteria.

Evaluates OP O4 action level using PPC Group Display.

Determines current OP O4 action level as 3 (leak >= 100 gpd) and updates Shift Foreman.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 10 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 4 Page 11 of 21 Event

Description:

30 gpm SGTL on loop 4 (continued)

Time Position Applicants Actions or Behavior (OP AP3, "Steam Generator Tube Failure")

SRO Reads NOTE prior to step 1 regarding requirement to complete procedure actions unless superseded by EOP E3 , "Steam Generator Tube Rupture".

Note: Maintaining Pressurizer level stable is a Continuous Action. Associated RNO steps are performed when crew reports applicable conditions exist (i.e unable to maintain pressurizer level).

SRO/ATC (1) Checks pressurizer level and charging flow.

o (1.a) May take charging to MANUAL control and attempt to adjust charging and seal flow to maintain pressurizer level (CC2).

SRO/BOP o (1.a RNO) May start additional charging pump IF requested by ATC (VB2)

SRO/ATC o (1.b) Checks for continuing decrease in pressurizer level.

Determines leak rate is approximately 30 gpm.

Readjusts charging and seal flow (CC2).

Determines pressurizer level is stable (CC2, PPC) (Continuous Action to Monitor).

May isolate Letdown by closing 8149C and LCV459/460 (VB2).

SRO/BOP (2) Identify affected steam generator.

o (2.a) Determines that no S/G levels are rising unexpectedly (VB3 meters, PPC).

o (2.b) Identifies main steamline rad monitor 74 rising (VB2 recorders, upper left; PPC).

o (2.c) Verifies S/G blowdown isolation/sample valves open (VB3 lower left).

(Depending on pace of crew, blowdown may have isolated due to high rad on RM 23; RNO step is performed to allow sampling by chemistry).

(2.c RNO) Checks blowdown isolation due to RM23 in alarm (PPC, RCDR3 VB2 lower left); Places RE19, 23 Hi Rad S/G Blowdown and Sample Valve iso defeat cutout switch to "cutin" and opens blowdown sample valves (FCV244, 246, 248, 250) (VB3, lower left).

o (2.d) Contacts Chemistry to perform S/G sampling per CAP AP1.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 11 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 4 Page 12 of 21 Event

Description:

30 gpm SGTL on loop 4 (continued); Ramp Offline Time Position Applicants Actions or Behavior (OP AP3, "Steam Generator Tube Failure")

SRO/ATC (3Continuous Action to Monitor) Determines VCT level can be maintained by RCS makeup (CC2,VB2, PPC).

SRO (4) Determines plant shutdown requirement.

o (4.a) Determines leak rate greater than O4 shutdown criteria.

o (4.b) Due to O4 criteria, implements OP AP25, Rapid Load Reduction or Shutdown.

o Reviews T.S. 3.4.13.B, RCS Operational Leakage, - Primary to secondary LEAKAGE.

Required actions: Be in MODE 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

(OP AP25, "Rapid Load Reduction or Shutdown")

SRO (1.a) Determines runback/programmed ramp is not in progress (may not vocalize, since this ramp is initiated by the crew).

SRO/BOP Starts load reduction (guidance is also on lamicoid pegboard on CC3):

o (1.b) Places MW and IMP feedbacks in service (all on Triconex turbine HMI, CC3).

o (1.c,d) Sets load target and ramp rate (greater than or equal to 5 MW/min) o (1.e) Pushes GO.

o (1.f) Contacts Chemistry to advise 15%/hr shutdown rate will be exceeded.

SRO/ATC (2) Ensures control rods are inserting in AUTO (CC1).

(3) Turns on Pressurizer heaters if not on from earlier event (CC1).

(4) Checks charging adequate to prevent flashing in the letdown system; may take manual control to ensure adequate flow (CC2).

SRO/BOP (5) Ensures DFWCS is controlling S/G levels in AUTO (MFW control/bypass valves; MFPs all in AUTO) (CC2)(VB3).

(Continued on next page)

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Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 4 Page 13 of 21 Event

Description:

Tube Rupture during ramp offline Time Position Applicants Actions or Behavior Note 1: Specific boration values will be based on the actual ramp rate and target specified by SRO.

Note 2: Tube leak becomes 400 gpm rupture 30 seconds after boration starts.

SRO/ATC (6) Performs boration (the following guidance is on the boration checklist in the reactivity handbook).

o Presses STOP on M/U Ctrl HMI (CC2).

o Presses BORATE on HMI.

o Sets target gallons for boration; verifies batch is reset.

o Sets boric acid flowrate.

o Presses START, and monitors boration.

o Once stopped, either returns to AUTO (presses AUTO, then START), or performs additional boration per the Shift Foreman(CC2).

SRO/BOP (7) Checks MFP suction pressure greater than 260 psig (VB3).

SRO/ATC (8) Checks Tavg trending to Tref (PPC, CC1).

(9) Checks Pressurizer pressure and level trending to programmed band (PPC, CC2).

Reports rapid decrease in Pressurizer pressure and level.

Returns to OP AP3, step 1.a RNO.

(OP AP3, "Steam Generator Tube Failure", starting at step 1.a RNO)

SRO/BOP (1.a RNO) Starts additional CCP (if not done earlier).

(1.b RNO) Isolates letdown (if not done earlier).

ATC Reports PZR level cannot be maintained.

SRO Directs Rx trip/SI and transition to E0.

ATC Performs Rx trip and SI.

(Continued on next page)

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Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5,6,7 Page 14 of 21 Event

Description:

Reactor Trip / Safety Injection Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection")

SRO/ATC (1) Verifies reactor trip (trip bkrs open, rods on bottom, NIs decreasing) (VB2, CC1).

(2) Verifies turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps).

SRO/BOP (3) Checks vital 4kv bus status (VB4, vital buses F/H white lights on mimic buses).

o Reports differential on bus G following transfer to startup power.

SRO/ATC (4) Checks SI actuated (PK0821 ON, also checks VB1 red train light ON and/or train equipment to verify both trains actuated).

o Both trains of SI actuated as indicated by PK0821, SI red light above Monitor Light Box C (VB1), and both trains of SI/RHR pumps running (VB1 skirt).

SRO (5) Directs implementation of App E (usually given to BOP); See page 19.

o All failures are related to loss of 4kV Bus G. Field Operators should be assigned to manually close associated valves.

o Board manipulations are as follows:

Switch LCV12 to CONT ONLY (VB3).

Main Feedwater Recirc Valves FCV53 & 54: OPEN (VB3).

Turn on Aux bldg vent charcoal filter preheater (VB4).

SRO/ATC (6) Checks RCS temperature stable or lowering to 547oF.

o AFW Pp 12 OOS; 13 is running (VB3).

o TDAFW is running and required (VB3).

(7) Checks Pzr PORVs and Pzr Safeties and Spray Valves.

o Safeties closed; no sonic flow, tailpipe temperature normal (VB2).

o PCV456 is closed with 8000C open; PCV474 is closed - may restore power to 8000A (VB2).

o Pzr Sprays closed (green lights on) (CC2).

(8) Checks RCP trip criteria; o RCS WR Pressure is greater than 1300 PSIG, trip criteria, however RCP 12 and 14 tripped off on loss of 12kV Bus D (VB2).

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 14 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 15 of 21 Event

Description:

Reactor Trip / Safety Injection (continued) (CT)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection") (continued)

SRO/ATC (9) Determines S/G are NOT faulted.

o No S/G lowering in an uncontrolled manner or completely depressurized.

SRO/ATC (10) Checks for ruptured S/G.

o Notes RE74 elevated and S/G 14 level rising.

o Directs transition to EOP E3, "Steam Generator Tube Rupture".

(EOP E3, "Steam Generator Tube Rupture")

SRO/ATC (1) Notes RCPs 12 and 14 are not running (VB2).

SRO/ATC (2) Identifies S/G 14 as ruptured (RM74 in alarm; indications of rising level without feed during E0).

SRO/BOP (3) Implements Appendix FF to isolate ruptured S/G 14 (see pg 21 - contains CT step)

SRO/ATC Reads CAUTION regarding maintaining isolation of Faulted/Ruptured S/G (do not feed).

(4.a) Notes ruptured S/G level is greater than 15%.

(4.b) Isolates Feed flowpaths to S/G 14:

o Takes LCV113 to MANUAL and closes the valve (S2CT1)(partial) **

o Directs field action to close of LCV109 (S2CT1)**

SRO/ATC (5) Checks ruptured S/G pressure greater than 225 psig.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 15 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 16 of 21 Event

Description:

Reactor Trip / Safety Injection (continued)

Time Position Applicants Actions or Behavior (EOP E3, "Steam Generator Tube Rupture", continued)

SRO Reads CAUTION regarding false PTS (Integrity Status Tree indication) for ruptured loop.

(6.a) Determines required cool down target Core Exit Temperature from table based on current ruptured S/G pressure.

LOWEST RUPTURED SG PRESS (PSIG) REQ'D CORE EXIT TEMPERATURE (oF) 1050 and above 516 1030 to 1049 513 1000 to 1029 510 900 to 999 497 800 to 899 483 700 to 799 467 600 to 699 450 225 to 599 350 SRO/ATC (7) Determines Condenser is NOT available.

o PK0814 - OFF.

o Goes to step 10.

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 16 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 17 of 21 Event

Description:

Reactor Trip / Safety Injection (continued) (CT)

Time Position Applicants Actions or Behavior (EOP E3, "Steam Generator Tube Rupture", continued)

SRO/ATC (10) Initiates RCS Cooldown Using 10% Steam Dumps.

o (10.a) Verifies Appendix FF is complete.

o (10.b) Manually opens PCV19, 20, and 21 (10% Steam Dumps) to at least 90%

to dump steam at maximum possible rate. (S2CT2) **

o (10.c) Continues on in procedure at step 11 while cooldown continues.

o (10.d) Stops the cooldown when ALL Core Exit Thermocouples are less the required target temperature. (S2CT2) **

o (10.e) Stabilizes temperature slightly less than required temperature using steam dumps in AUTO.

    • (Critical Task) (S2CT2) Perform RCS cooldown at maximum rate to CETC target temperature specified in E3, step 6, using 10% steam dumps such that RCS subcooled margin still exists following the cooldown.

SRO/BOP (11.a,b) Maintains intact S/G levels while controlling S/G NR levels between 20%65%.

(11.c) May throttle TDAFW flow to maintain level within band.

SRO/BOP (12) CHECK PZR PORVs and Block Valves.

o (12.a,c) Notes power is available to block valve 8000C and valve is open.

Directs field operator to restore power to 8000A (if not done earlier).

o (12.b) PZR PORVs - all closed.

SRO/BOP (13) Resets Safety Injection (VB1).

SRO/BOP (14) Resets both Trains Phase A (Phase B was not in) (VB1).

SRO/BOP (15) Opens FCV584 to restore Instrument Air to Containment and checks header pressure greater than 90 psig (VB4).

(Continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 17 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 18 of 21 Event

Description:

Reactor Trip / Safety Injection (continued) (CT)

Time Position Applicants Actions or Behavior (EOP E3, "Steam Generator Tube Rupture") (continued)

SRO/BOP (16) Shuts down RHR pump 12.

SRO/ATC (17) Checks RCS cooldown stopped before continuing on to depressurization of RCS.

SRO/BOP (18) Checks ruptured S/G pressure stable or rising.

SRO/BOP (19) Checks Subcooling greater than 40oF.

SRO/BOP Reads note regarding use of a PORV for depressurization if normal spray is determined to be ineffective.

(20) Notes RCP 12 not running and determines normal Pressurizer Spray will not be effective.

(21) Depressurizes the RCS using one PZR PORV:

Reduces RCS pressure until criteria of Appendix GG has been met: (S2CT3) **

o RCS Pressure LESS THAN Ruptured S/G Pressure AND o PZR Level - GREATER THAN 12% [40%]

OR o PZR Level - GREATER THAN 74% [66%]

OR o RCS Subcooling Based on Core Exit T/Cs LESS THAN 20°F (Subcooled Margin Monitor, YI31 or Appendix C)

    • (Critical Task) (S2CT3) Depressurize the RCS until Appendix GG criteria has been met.

The scenario is terminated once critical task S2CT3 is complete and PORV used for depressurization has been closed.

L181 NRC ESD202 r1.docx Page 18 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 19 of 21 Event

Description:

SGTR (S/G 14) (cont)

Time Position Applicants Actions or Behavior (EOP E0, Appendix E ESF Auto Actions, Secondary and Auxiliaries Status)

BOP Implements App E (ESF Auto Actions, Secondary and Auxiliaries Status):

(1a) Checks no personnel in Containment (part of turnover; may not voice).

(1b) Announces reactor trip/SI on PA system.

(2) Checks main generator - tripped (PK1401 is ON).

(3) Verifies Phase A (VB1, ESF status lights, red lights ON, some white lights ON).

o Determines all failures are related to loss of 4kV Bus G.

(4) Verifies Containment Vent Isolation complete red lights ON, white lights OFF (VB1).

(5) Verifies ESF (SI) actuation complete red lights ON, some white lights ON (VB1).

o Determines all failures are related to loss of 4kV Bus G.

(6) Verifies Feedwater isolation complete (F.W. Isolation and S.G. Level Portions of Monitor Light Box C: red lights ON, white lights ON (VB1).

o Determines all failures are related to loss of 4kV Bus G.

(7) Determines Containment Spray and Phase B Isolation are NOT required (Contmt Isol, Phase B portion of Monitor Light Box D: red lights are OFF (VB1)).

(8) Checks Main Steamline Isolation complete (Main Steam Isolation portion of Monitor Light Box D: red light OFF, white light OFF (VB1)).

9) Checks AFW status:

o AFW Pp 12 OOS; AFW Pp 13 running.

o TDAFW is running and IS required.

(10) Checks ECCS flows (charging injection (VB2), SI, RHR (VB1).

o Notes CCP 12 and 13 (VB2) off due to bus G loss.

(11) Reports ESF and AFW status to the Shift Foreman (Shift Foreman may direct operator to continue on in Appendix E, or redirect to higher priority tasks).

(12) Checks excess letdown; notes NOT in service prior to trip (VB2).

(13) Checks secondary systems (MFPs tripped (VB2, green lights ON) o Selects FCV53/54 to recirc.

o Stops all but one CB Pp set.

o Takes LCV12 control switch to CONT ONLY.

(continued on next page)

    • Critical Task L181 NRC ESD202 r1.docx Page 19 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 20 of 21 Event

Description:

SGTR (S/G 14) (cont)

Time Position Applicants Actions or Behavior (EOP E0, Appendix E ESF Auto Actions, Secondary and Auxiliaries Status)

BOP (14) Checks proper operation of Aux Bldg and Control Rm vent systems (vent status light panel white lights)(VB4).

o Placed both Unit 1 VENT TRAIN 1 BUS F and H MODE SELECT Switches to Mode 3 (VB4).

(15) Verifies available DGs running normally (freq (60), volts (120), speed (900))(VB4).

(16) Verifies vital batteries supplied by chargers (charger and bus volts)(VB5).

(17) Verifies MSRs reset (Triconex HMI)(CC3).

(18) Throttles RCP seal injection flows to normal if needed (FCV128, to 813 gpm each, CC2).

(19) Checks PK1104 NOT IN (SFP alarm).

(20) Notifies Shift Foreman of completion.

(Board Operator will rejoin crew upon completion of Appendix or when called upon by Shift Foreman)

L181 NRC ESD202 r1.docx Page 20 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 2 Event No.: 5 Page 21 of 21 Event

Description:

EOP E3, Appendix FF, "Isolate Ruptured Steam Generator" (CT)

Time Position Applicants Actions or Behavior (EOP E3, Appendix FF, Isolate Ruptured Steam Generator)

BOP Reads CAUTION regarding TDAFW as only source of feedflow prior to step 1.

(1) Reads step to ensure S/G 14 10% steam dump controller (PCV22) set to 1040 psig and in AUTO (VB3).

(2) Checks S/G 14 10% steam dump valve closed (PCV22) (VB3).

(3) Checks S/G 14 MSIV and bypass (FCV44 and FCV24) valves closed (VB3).

o Closes S/G 14 MSIV, FCV44 (S2CT1)(partial) **

(4) Notes no TDAFW steam valves associated w/ S/G 14 (VB3).

(5) Verifies S/G 14 SGBD valves outside cnmt (FCV160 and FCV244) closed (VB3).

(6) Verifies S/G 14 is isolated from intact S/G (S/G 14 MSIV and MSIV Bypass are both closed as are all intact S/G MSIV and MSIV Bypasses).

(7) Informs Shift Foreman S/G 14 isolation is complete.

BOP (8) Removes WR Thot input to SCMM for loop 4 (behind boards, PAMS panel behind VB3).

o Goes to PAM3 panel.

o Checks Loop 4 Thot Disabled.

(9) Contacts Chemistry to sample S/Gs per CAP AP1.

o Ensures SI Reset (VB1).

o Ensures Phase A, Train A & B Reset (VB1).

o Open Instrument Air to Containment FCV584 (VB4).

o When Chemistry is prepared to Sample, ensures Inside Containment S/G Blowdown Valves FCV760763 opened (VB3).

L181 NRC ESD202 r1.docx Page 21 of 24 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION X IC RESTORE IC11 75%; MOL, CB - See Turnover X Setup Lesson drl_0120.lsn Clears AFW 12 The Plant Abnormal Status Board for Surveillance Requirements None Copies of Procedures, Attachments; Appendixes; Foldout Pages; AR PK0406, PK0421, PK0516, 0621, PK01106, OP AP3, AP5, AP13, AP25, EOP E0, E3 Annunciator Response Procedures and commonly used forms are in binders and NOT Marked up X 0 min Tools > Simple SBT Before crew takes the watch.

Use Simple SBT, Data Recorder File: sbt_sim.drb, min 960 iterations (30 sec).

Critical Task Specific Data Capture:

S2CT1: LCV109 and LCV113 valve position (or flow into S/G 14)

S2CT2: PCV19, 20, 21 valve position; CETC (2 highest)

S2CT3: RCS Pressure, PZR Pressure, S/G 14 Pressure, Subcooling X 0 min Lesson L181 NRCS2.lsn After SFM reports the crew has taken the watch, load session MALS, OVRs, etc.

by FILE or MANUALLY (below)

X Evt1: PCV455A Setpoint ramps to zero over 20 seconds and can not be reset.

setpoint failure (approx. 3 min after taking watch per lead examiner)

X Evt2: PT474 Fails Check for OOS stickers on PI474 and PR455 and pink tags.

Low (once pressurizer When contacted as Turbine Watch, open breakers for 8000A and 8000B when pressure returned to requested (see field action branch of lesson file).

normal band, per lead examiner)

X Evt3: PT135 fails PT135 fails high.

high (once Evt2 TS addressed per lead examiner)

X Evt4: 30 gpm tube Crew will contact chemistry for sampling and power reduction > 15%/hr.

leak on S/G 14 (once PT135 being controlled in manual, per lead examiner)

Evt5: 400 gpm tube Scenario Major - 400 gpm SGTR on S/G 14.

rupture (Major)

(triggers 30 sec after FCV110A opening for boration)

Evt6: 12 kV Bus D Results in loss of Condenser and RCPs 12 & 14.

Feeder Breaker Diff (post trip)

Evt7: 4kV Bus G Diff Crew will contact field for closure of FCV431 and control of TDAFW LCVs on xfer to S/U (post Note: Closing LCV109 is part of the Critical Task to isolate the rupture S/G.

trip) Document the time isolation is requested and when crew notified complete:

Time LCV109 isolation requested: ____________ Time notified:__________

X = manual entry required L181 NRC ESD202 r1.docx Page 22 of 24 Rev 1

Diablo Canyon Power Plant Operations Shift Log Unit 1 Unit 1 Days at Power: 111 Days Operating Mode: 1 Gross Generation: 860 MWe Power Level: 75% Net Generation: 810 MWe Today - Dayshift Shift Manager Turnover:

PRA RISK STATUS NEXT SHIFT: Green GRID STATUS NEXT SHIFT: Normal AVERAGE RCS CALCULATED LEAKRATE: 0.01 gpm CONDENSER INLEAKAGE: < 0.01 gpd CONDENSER D/Ps: NW 5.7 SW 5.7 NE 5.7 SE 5.8 PSID MAIN GENERATOR H2 USAGE: 325 scfd / 327 scfd 5 day ave SPENT FUEL POOL: Temp = 80oF; Time to 200oF = 30 hrs using actual temp (F ID7A)

NEW EMERGENT WORK:

MDAFW 12 OOS due to low dP during routine surveillance test SHUTDOWN TECH SPECS / ECGS:

TS 3.7.5.B MDAFW 12, OOS due in 68 hours7.87037e-4 days <br />0.0189 hours <br />1.124339e-4 weeks <br />2.5874e-5 months <br />.

ECG ACTIONS THAT IF COMPLETION TIME NOT MET ECG 0.3 IS ENTERED:

None TURNOVER ITEMS:

MDAFW 12 estimated RTS is 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Unit is operating at 75% due to a SCCW Hx Clearance PRIORITY ITEMS FOR NEXT SHIFT:

o MDAFW 12 repair

Shift Foreman Turnover 0B ANNUNCIATORS IN ALARM:

There are no unexpected alarms all current alarms are consistent with current mode and power level.

TURNOVER ITEMS:

U1: maintain 75% no one in containment.

U2: maintain 100%.

REACTIVITY MANAGEMENT:

Time in core life: _MOL_.

Power History: Steady State at 75% for past 3 days.

Boron concentration is _966 ppm_ from a sample taken 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago.

Control Rod Height: 194 steps on CBD.

Diluting the RCS approximately 25 gallons every 1.5 hrs.

The last dilution was completed _30 minutes ago.

CONDITIONAL SURVEILLANCES & INCREASED MONITORING:

None OTHER ABNORMAL PLANT STATUS None

Appendix D (rev 11) Scenario Outline Form ESD1 Facility: Diablo Canyon (PWR) Scenario No: 3 OpTest No: L181 NRC Examiners: Operators:

Initial Conditions: 100% Power, MOL with AFW 12 cleared Turnover: At 100% power with AFW 12 cleared Event Malf Event Event Description No No. Type* (See Summary for Narrative Detail) 1 PMP_CVC3_2 OVERLOAD_DEV_FAIL TS, C CCP 13 OC Trip (OP AP17, ECG 8.1.A).

(ALL) 2 AS01ASW_ASP11_MTFSEIZUR 1 TS, C ASW Pp 11 Seizes; Pp 12 can not be started (OP AP10, TS (BOP, 3.0.3).

SRO) 3 MAL_CWS3A 80 C (ALL) High DP on Intake Screens; ramp required (AR PK1301, OP MAL_CWS3B 75 AP7, OP AP25).

MAL_CWS1A 0.15 ramp=120 MAL_CWS1B 0.15 ramp=150 4 PMP_CWS1_2 M Both Circ Water pumps trip off during ramp, requiring OVERLOAD_DEV_FAIL cd='smss lt (ALL) Reactor Trip (OP AP7).

1140' PMP_CWS2_2 OVERLOAD_DEV_FAIL cd='smss lt 1080' 5 MAL_EPS4C_2 DIFFERENTIAL C (ALL) Vital 4kV Bus F differential trip.

cd='fnispr lt 5' delay=30 6 VLV_PZR4_2 0.3 cd='jpplp4' del C (BOP) Pressurizer PORV PCV455C fails slightly open on trip ay=60 requiring manual isolation by associated block valve 7 MAL_AFW1 1 cd='fnispr lt 5' C (ALL) Turbine driven AFW pump overspeed trip.

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor L181 NRC ESD103 r1.docx Page 1 of 3 Rev 1

Appendix D (rev 11) Scenario Outline Form ESD1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) (from form ES3014) Actual Attributes

1. Total malfunctions (5-8) (Events 1,2,3,4,5,6,7) 7
2. Malfunctions after EOP entry (12) (Events 5,6,7) 3
3. Abnormal events (1-4) (Events 1,2,3) 3
4. Major transients (12) (Event 4) 1
5. EOPs entered/requiring substantive actions (1-2) (E0.1, FRH.1) 2
6. EOP contingencies requiring substantive actions (0-2) (FRH.1) 1
7. Critical tasks (2-3)(See description below) 2 Critical Task Justification Reference (S3CT1) Close the motor operated block The open PORV and block valve constitute the Westinghouse Owners valve upstream of the stuck open PORV degradation of a fission product barrier. Closing the Group WCAP17711NP prior to rupture of the PRT. block valve is essential to safety since failure to do so results in the unnecessary continuation of the degraded condition.

(S3CT2) Establish a secondary heat sink as A loss of all feedwater transient is characterized by FRH.1 Background indicated by: a depletion of secondary inventory and eventual Document (HFRH1BG),

WR level rising degradation of secondary heat transfer capability. Rev. 3.

Core Exit Thermocouple As secondary heat transfer capability degrades, temperatures lowering core decay heat generation will increase RCS temperature and pressure causing loss of RCS Prior to reaching bleed and feed criteria inventory similar in nature to a small break loss of which is defined as wide range S/G level in coolant accident. Failure to restore a secondary any three S/Gs less than 18% [26%] AND heat sink when it is possible to do so constitutes a narrow range S/G level in all four S/Gs less significant reduction of safety margin beyond that than 15% [25%] narrow range.

irreparably introduced by the scenario.

Per NUREG1021, Appendix D, if an operator or crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the postscenario review.

L181 NRC ESD103 r1.docx Page 2 of 3 Rev 1

SCENARIO

SUMMARY

- NRC #3

1. Charging Pump CCP 13 trips on over current. The crew responds by entering OP AP17, Loss of Charging to restore normal charging and letdown. Shift Foreman enters ECG 8.1.A - Charging Pump No. 3 Inoperable (establish fire watch; restore to operable status within 7 days).
2. ASW Pump 11 trips due to a seized shaft. Standby ASW Pump 12 fails to autostart and cannot be started manually. The Shift Foreman implements OP AP10, Loss of Auxiliary Salt Water and crossties to the Unit 2 ASW system via the ASW crosstie valve FCV601. Shift Foreman enters T.S. 3.0.3 for two trains of ASW inoperable on Unit 1.
3. Screen differential pressure begins to rise quickly, bringing in AR PK1301, Bar Racks/Screens. Following annunciator guidance, the crew enters OP AP7, Degraded Condenser, Section C: Traveling Screen Problem and begins to reduce load to 50% or less per OP AP25, Rapid Load Reduction.
4. Both Circ Water pumps trip off during ramp, requiring the crew to manually trip the Reactor per OP AP
7. The crew enters EOP E0, Reactor Trip or Safety Injection and performs their immediate actions.
5. On the trip, vital 4 kV bus F trips on differential. DRPI loses power, but crew is able to determine the reactor has tripped based on diverse indications (lowering reactor power and reactor trip breakers open). MDAFW Pump 13 is also lost due to the bus failure.
6. Board operators also identify PCV455C in midposition. The valve will not close and must be isolated using the associated block valve 8000B (S3CT1) Close the motor operated block valve upstream of the stuck open PORV prior to rupture of the PRT.

7.

The TDAFW pump trips on overspeed. Steam Generator levels are initially high enough to provide an adequate secondary side heat sink and the crew transitions to EOP E0.1, Reactor Trip Response to stabilize the plant. Steam Generator levels slowly lower below the minimum required level of 15%

narrow range and the crew transitions to EOP FRH.1, Response to Loss of Secondary Heat Sink. With the condenser unavailable, Condensate is used to restore a secondary side heat sink (S3CT2) Establish a secondary heat sink.

The scenario is terminated once Critical Task S3CT2 is complete L181 NRC ESD103 r1.docx Page 3 of 3 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 1 Page 1 of 14 Event

Description:

Centrifugal Charging Pump 13 OC Trip Time Position Applicants Actions or Behavior ALL Diagnosis of CCP 13 OC trip is made from one or more of the following:

CCP 13 blue OC light is lit, and the pump is no longer running (VB2, lower center).

PK0416 CCP 13 alarm (OC trip input).

PKs 0501 - 0504, due to RCP seal low flow alarms.

Observes low charging flow and/or RCP seal flows (CC2, PPC, VB2 meters).

Observes letdown has isolated (VB2, upper skirt).

SRO Implements OP AP17, "Loss of Charging, Section A, Loss of All Charging."

(OP AP17, "Loss of Charging Section A, Loss of All Charging")

SRO/BOP (1.a) Ensures Letdown is isolated:

o Checks 8149A, 8149B, and 8149C closed (VB2).

SRO/BOP (2.a) Ensures suction flow path:

o Checks VCT level and pressure - normal (VB2, PPC).

o Checks LCV112B and LCV112C open (CCP suction) (VB2, lower center).

SRO (2.b) Determines that pump venting not required at this time.

SRO/BOP (2.c) Verifies 8105 and 8106 are open (CCP recircs) (VB2, lower center).

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 1 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 1 Page 2 of 14 Event

Description:

Centrifugal Charging Pump 13 OC Trip (continued)

Time Position Applicants Actions or Behavior (OP AP17, "Loss of Charging Section A, Loss of All Charging", continued)

SRO/ATC (2.d,e) Places FCV128, CHARGING PUMP FLOW CONTROL, in MANUAL and closes (CC2).

SRO/BOP (2.f) Starts an available charging pump (CCP 11 or 12)(VB2).

SRO/ATC (2.g,h) Adjusts charging in manual to return level to program (FCV128) (CC2).

(3) Adjusts HCV142 to maintain RCP seal flows 813 gpm (CC2).

(4.a) Checks Pzr level > 17% (CC2 recorder, PPC, VB2 meter).

SRO/BOP (4.b) Checks letdown in service; determines normal letdown can be restored (VB2, upper left skirt).

(OP AP17, "Loss of Charging - Appendix R")

BOP/ATC Reads CAUTION prior to step 1, App. R regarding high letdown temperature and the potential for lifting RV8117.

o (1.a) Checks FCV355 open (it is) (VB1, lower left skirt).

o (1.b) Opens TCV130 to 40% demand (VB2, lower middle).

o (1.c) Ensures 8149A,B, and C are closed (they are) (VB2, upper middle skirt).

o (1.d) Opens LCV459 and LCV460 (VB2, upper middle skirt).

o (1.e) Checks 8152 open (VB2, upper middle skirt).

o (1.f) Opens PCV135 to 60% demand (VB2, lower middle).

o (1.g) Adjusts charging to 87 gpm (ATC) (CC2).

o (1.h) Opens 8149B or C - 75 gpm orifice stop valve (VB2, upper middle skirt).

o (1.i) Adjusts PCV135 for 350 psig on PI135 and returns to AUTO (VB2, upper middle).

o (1.j) Adjusts TCV130 for 90oF110oF on TI130 and returns to AUTO (VB2, upper middle).

o (1.k) Checks RV8117 Letdown Relief Valve tailpipe temperature to verify relief valve is seated (TI129 VB2, middle).

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 2 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 1 Page 3 of 14 Event

Description:

Centrifugal Charging Pump 13 OC Trip (continued)

Time Position Applicants Actions or Behavior (OP AP17, "Loss of Charging - Appendix R", continued)

SRO/BOP (4.c) Adjusts charging in manual to return level to program by throttling FCV128 for flow, and maintaining RCP seal flows 813 gpm using HCV142 (CC2).

(5.a - d.) Checks VCT Makeup Control:

o Checks VCT level 14% to 87% (LI112 on VB2).

o Reads NOTE prior to step 5.b.

o Checks VCT pressure 15 to 60 psig (PI135 on VB2).

o VCT makeup control (YIC100) in AUTO mode and set for current RCS boron concentration which is displayed on lamicoid above ATC PPC displays (CC2).

(OP AP17, "Loss of Charging starting at section A, Loss of All Charging", continued)

SRO/BOP (5.e) Verifies instrument air is available (VB4 lower left area).

(6) Checks LCV112B and LCV112C open, providing suction from the VCT(VB2, middle skirt).

SRO (7) Reviews Tech Specs/ECGs and enters ECG 8.1.A - CCP 13 inoperable. Required actions:

o Establish a continuous fire watch in the ECCS Centrifugal Charging Pump (CCP) room Immediately.

OR o Inspect the ECCS CCP room with a fire watch once per hour.

AND o Verify the ECCS CCP associated smoke detection equipment is OPERABLE.

AND o Verify the ECCS CCP associated fire suppression system is OPERABLE.

AND o Restore Charging Pump No. 3 to OPERABLE status within 7 days.

Proceed to the next event once ECGs are addressed, per the lead examiner

    • Critical Task L181 NRC ESD203 r1.docx Page 3 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 2 Page 4 of 14 Event

Description:

ASW Pump 11 Seizure Time Position Applicants Actions or Behavior ATC Observes PK0103 (ASW Pp OC trip) and PK0101 (three low press / low dP inputs) alarming, and informs the Shift Foreman.

ATC/BOP Observes that 11 ASW Pp has a blue OC light (VB1, far left), and reports condition to the Shift Foreman.

(AR PK0103, "Aux Salt Water Pumps") if entered, else N/A SRO (1.0) Goes to section 2.1, due to OC trip inputs.

SRO/BOP (2.1.1) Determines that the standby ASW pump is NOT running with normal current (did not start); takes 12 ASW pp to MAN, and attempts to start it.

SRO * (2.1.2) Determines ASW flow has NOT been restored; goes to OP AP10, Loss of Auxiliary Saltwater.

(OP AP10, "Loss of Auxiliary Salt Water")

SRO/BOP (1) Determines neither ASW pump is running.

(1.a,b,c RNO) Informs SM to contact Watch Commander. Determines Unit 2 ASW Pump 21 is available for crosstie. Goes to Section 6.

(6.2.1) Directs Unit 2 to CLOSE 2FCV495 and OPEN 2FCV496.

(6.2.2) N/A (6.2.3) Opens FCV601 (VB1, lower far left skirt).

(6.2.4) Directs Unit 2 to start standby ASW Pump 21.

SRO (1.e RNO) Implement Tech Spec 3.0.3 for two trains of ASW inoperable. Required action:

Initiate shutdown within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. Be in MODE 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

SRO/BOP (1.f RNO) Contacts Aux Watch to stop any radwaste discharge in progress.

Proceed to the next event once Tech Specs addressed, per the lead examiner.

    • Critical Task L181 NRC ESD203 r1.docx Page 4 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 3 Page 5 of 14 Event

Description:

High Screen DP Time Position Applicants Actions or Behavior ATC Observes PK1301 (Bar Racks/Screens) alarming, and informs the Shift Foreman.

(AR PK1301, "Bar Racks/Screens")

SRO/ATC Reads CAUTION regarding potential screen damage.

(2.2.1) Checks the PPC "Intake Screens" display.

SRO (2.2.22.2.4) N/A.

SRO/BOP (2.2.5) Calls the Intake Watch to check if all available screens are running.

SRO (2.2.6) N/A.

SRO/ATC (2.2.7) Checks if screen D/P of ANY of the bays exceeds 15 inches, and if so, checks the associated screens are operating as follows:

o CWP Bay 11 Screens 11 through 13 running at or trending toward 30 fpm.

o CWP Bay 12 Screens 14 through 16 running at or trending toward 30 fpm.

o U1 ASW Bay Screen 17 running at or trending toward 10.8 feet per minute.

SRO (2.2.8) Determines screen D/P cannot be reduced to less than 8 inches, IMPLEMENTs OP AP7, "Degraded Condenser."

(OP AP7, "Degraded Condenser - Section C, Traveling Screen Problem.")

SRO Reads Cautions about screen stalling, backflow concerns, and need for tripping the reactor if both Circ Water pumps are lost.

Reads Note about PPC indication.

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 5 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 3 Page 6 of 14 Event

Description:

High Screen DP (continued)

Time Position Applicants Actions or Behavior (OP AP7, "Degraded Condenser - Section C, Traveling Screen Problem.", continued)

SRO/ATC (1) Checks Traveling Screen Status:

o (1.a) Determines screen status is NOT normal.

o (1.b) Determines screen differential pressure is greater than 8 inches.

o (1.b RNO) Determines differential pressure is continuously above 8 inches and is NOT due to salp/jellyfish.

Implements OP AP25, "Rapid Load Reduction or Shutdown" to commence load reduction to 50% or less (see page 7).

SRO/ATC o (1.c) Checks screen differential pressure 25 inches OR LESS.

Notes that it is. Actions are the same as for differential pressure is continuously above 8 inches and is NOT due to salp/jellyfish.

Proceeds with implementation of OP AP25 (see page 7).

SRO/ATC o (1.d) Checks screens NOT overloaded.

Screen differential pressure LESS THAN 70 inches.

Each CWP in service has at least two operating screens.

Note: Evt4, CWP 11 Trip will trigger shortly after the crew starts a boration as part of AP25, and before crew reaches remainder of OP AP7; subsequent steps have, been omitted.

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 6 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 3,4 Page 7 of 14 Event

Description:

Ramp / Reactor Trip Time Position Applicants Actions or Behavior (OP AP25, "Rapid Load Reduction or Shutdown")

SRO Directs reduction of turbine load.

o (1.a) Determines runback/programmed ramp is not in progress (may not vocalize, since this ramp is initiated by the crew).

SRO/BOP Directs board operator to input ramp parameters (CC3):

o (1.b) Places MW and IMP feedbacks in service (all on Triconex turbine HMI).

o (1.c,d) Sets load target and ramp rate.

o (1.e) Pushes GO.

o (1.f) Contacts Chemistry to advise 15%/hr shutdown rate will be exceeded.

SRO/ATC (2) Ensures control rods are inserting in AUTO (CC1).

(3) Turns Pressurizer heaters on (CC1).

(4) Checks charging adequate to prevent flashing in the letdown system; may take manual control to ensure adequate flow (CC2).

SRO/BOP (5) Verifies DFWCS in AUTO and controlling S/G levels (CC3 MFW HMI, VB3, PPC):

o (5.a) Checks MFW control and bypass valves in AUTO.

o (5.b) Checks both MFPs and their controller in AUTO.

o (5.c) May check level trends, as well as steam flow/feed flow trends (CC3, PPC, and/or big VB3 DFWCS electronic recorders).

Note: CWP 11 will trip 30 seconds after boration is started causing a programmed ramp to commence. CWP 12 will trip when generator output reaches 1080 MW. Shift Foreman may direct Reactor Trip at this time.

SRO/ATC (6) Initiates boration (CC2).

ALL Identifies CWP 11 trip and notes programmed ramp in progress (VB4).

Identifies CWP 12 trip (VB4).

SRO/ATC Directs/performs Reactor Trip.

Remaining Events Trigger Automatically

    • Critical Task L181 NRC ESD203 r1.docx Page 7 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 5,6,7 Page 8 of 14 Event

Description:

Reactor Trip (continued) (CT)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection")

Note 1: On the trip, a loss of vital 4kV bus F and an overspeed trip of the TDAFW pump leaves the crew with no AFW flow. S/G levels are initially above the minimum required level of 15% NR, but lowering. Crew will enter E0.1, "Reactor Trip Response", but will transition to EOP FRH.1, "Response to Loss of Secondary Heat Sink", once all four S/G levels fall below 15% NR.

Note 2: PCV455C partially opens on the trip, resulting in a critical task to close the associated block valve, 8000B.

SRO/ATC (1) Verifies reactor trip (trip bkrs open, rods on bottom, NIs decreasing) (VB2, CC1)

(2) Verifies turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps)

SRO/BOP (3) Checks vital 4kv bus status (VB4, vital buses G/H white lights on mimic buses).

o Reports differential on bus F.

o (3 RNO) Refers to EOP ECA0.3, "Restore 4kV Buses" while continuing in E0.

SRO/ATC (4) Checks for SI actuated (PK0821 ON), checks safeguards bistable status light panel.

o Reports Safety Injection has not actuated and is NOT required.

SRO/BOP (4.a RNO) continued o Notes no one in containment per shift turnover.

o Directs annoucement of Reactor Trip over Public Address System.

SRO/ATC (4.a RNO) Checks feedflow greater than 435 gpm; notes 0 gpm flow, but S/G NR level IS greater than 15% in atleast one S/G.

o Directs Transition to EOP E0.1 "Reactor Trip Response".

ANY Identifies PORV 455C partially open and attempts to close. Valve will not close.

Closes PORV block valve MOV8000B (VB2 lower right)**

    • (Critical Task) (S3CT1) Close the motor operated block valve upstream of the stuck open PORV prior to rupture of the PRT.

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 8 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 5,7 Page 9 of 14 Event

Description:

Reactor Trip Response Time Position Applicants Actions or Behavior (EOP E0.1, "Reactor Trip Response")

Note 1: Crew will continue to monitor S/G levels and transition to EOP FRH.1, "Response to Loss of Secondary Heat Sink", once all four S/G levels fall below 15% NR. There is no requirement for crew to complete steps of E0.1 once extreme challenge to secondary heat sink condition exists.

SRO/ATC (1) Checks RCS temperature stable or trending to 547oF based on RCS Loop Tavg (RCPs running) (VB2, lower center chart recorders or PPC).

o If RCS temp < 547oF and decreasing: (Not: expected) checks steam dumps (VB3, indicator lights middle) and S/G blowdown isolation valves outside containment (VB3, lower left skirt) all closed.

Also checks MSRs reset on on Turbine Control HMI (CC3).

o RCS temp > 547oF and increasing:

If required, sets 10% dump controllers to 1005 psig, (83.8% setpoint)

(VB3, lower left).

verifies dumps modulate open to control temperature at 547oF.

o Monitoring of RCS temperature stable assigned as Continuous Action.

SRO/BOP (2) Checks Feedwater Status:

o (a) RCS temperature < 554oF (VB2, lower center chart recorders or PPC) (NOTE:

expected).

o (b) Checks if Feedwater Isolation has occurred.

o (b.1) Feedwater Isolation portion of Monitor Light Box C (Red lights ON / White lights OFF) (VB1).

(c) Checks total AFW flow greater than 435 GPM (VB3, upper middle).

SRO/ATC (3) Checks Rods fully inserted (VB2DRPI).

o No DRPI due to loss of 4kV bus F (VB2) o Rx Trip breakers are open, power is lowering (VB2, CC1) o Determines reactor is tripped.

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 9 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 5,7 Page 10 of 14 Event

Description:

Reactor Trip Response (continued) (CT - may already be complete)

Time Position Applicants Actions or Behavior (EOP E0.1, "Reactor Trip Response", continued)

Note 1: Crew will continue to monitor S/G levels and transition to EOP FRH.1, "Response to Loss of Secondary Heat Sink", once all four S/G levels fall below 15% NR. There is no requirement for crew to complete steps of E0.1 once extreme challenge to secondary heat sink condition exists.

SRO/ATC (4) Checks Pressurizer level controls:

o (a) Level greater than 17% (VB2, middle right).

o (b) Charging in service with adequate flow (VB2)(CC2).

o (c) Letdown in service (VB2, upper middle skirt).

o (d) Pressurizer level trending to 22% (VB2, middle right).

o (may adjust charging to maintain level 22% to 60%).

o (e) May energize pressurizer heaters (CC1, lower left).

SRO/ATC Reads CAUTION regarding Aux Spray and notes as N/A (Aux Spray not in service).

(5) Checks Pressurizer pressure control:

o (a) Pressure greater than 1850 psig (VB2, far right).

o (b) Pressure stable or trending to 2235 psig (VB2)(CC2).

o (b RNO) Directs closing of PCV455C block valve, MOV8000B, if not already completed (VB2 lower right)**

    • (Critical Task) (S3CT1) Close the motor operated block valve upstream of the stuck open PORV prior to rupture of the PRT.)

SRO/BOP (6) Checks S/G NR levels greater than 15%:

o (a) Reports all S/G NR levels greater than 15%, but lowering (VB3, upper middle).

o (b) Reports with no AFW flow (VB3, upper middle).

o (c, d) Checks TD AFW Pump required for heat removal.

Reports TD AFW pump is tripped on overspeed (VB3, center skirt).

SRO Directs transition to EOP FRH.1, "Response to Loss of Secondary Heat Sink".

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 10 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 7 Page 11 of 14 Event

Description:

Loss of Secondary Heat Sink Time Position Applicants Actions or Behavior (EOP FRH.1, "Response to Loss of Secondary Heat Sink")

SRO Enters EOP FRH.1 (LOSHS) due to loss of AFW (complete) and low S/G levels.

SRO/BOP (1) Determines total feedflow less than 435 gpm is NOT the result of operator actions.

SRO/ATC (2) Determines Secondary Heat Sink is required.

o (2.a) RCS Pressure is GREATER than any intact S/G ; (RCS pressure (VB2); S/G pressure (VB3)).

o (2.b) RCS Hot Leg Temp is GREATER than 350oF; (VB2, lower (chart recorder)).

SRO/ATC (3) Checks at least one ECCS CCP available.

o (3.a) CCP 12 is either available or in service.

SRO/BOP (4) Tries to establish AFW flow to at least one S/G:

o (4.a) Verifies Blowdown and Sample isolation valves outside containment are closed (VB3, lower left skirt).

o (4.b.1) Verifies CST level is GREATER than 10% (VB3, middle).

o (4.b.2) Verifies none of the AFW pumps are running (VB3, middle).

o (4.bc RNOs) Dispatches operators to locally check lineups and investigate pump trips; May check on status on getting AFW 12 returned to service.

SRO/ATC (5) Stops all four RCPs (VB2, right).

SRO/BOP (6) Notes Condenser is NOT available due to loss of both CWPs (no vacuum).

(6 RNO) Adjusts 10% dump controllers to 1005 psig, (83.8% setpoint) (VB3, lower left).

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 11 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 7 Page 12 of 14 Event

Description:

Loss of Secondary Heat Sink (continued) (CT)

Time Position Applicants Actions or Behavior (EOP FRH.1, "Response to Loss of Secondary Heat Sink", continued)

SRO/BOP Reads CAUTION regarding monitoring of Hotwell level.

(7.a) Checks at least one Condensate Booster Pump Set running in recirc (VB3, center skirt).

SRO/ATC (7.b) Takes manual control of all Main Feedwater Reg Valves and Main Feedwater Reg Valves Bypasses and sets demand to zero (DFWCS HMI on CC3).

SRO/BOP (7.c) Checks Feedwater Isolation Valves open (VB3, lower left).

(7.d) Determines Main Feedwater is NOT available (Condenser NOT available)

(PK0814 NOT lit) and goes to step 9 (Establish Feed from Condensate System).

SRO/ATC Reads CAUTIONS before step 9.a regarding blocking/unblocking of automatic SI actuation.

Reads NOTE regarding parallel performance of S/G and RCS depressurization (steps 9.c in parallel with steps 9.ab) and the need to stop S/G depressurization if PK0606 comes in before SI signal are blocked (needed to prevent unwanted SI):

(9.a.1) Depressurizes RCS to less than 1915 PSIG (P11) using any available PORV (VB2, lower right vertical).

(9.a.2) After P11 actuates (PK0806), blocks RCS low pressure SI ((2) train switches) and low steamline pressure SI signals ((2) train switches)(CC2).

(9.a.3) Maintains RCS pressure below P11 (1500 and 1865 PSIG) using PORV (VB2).

SRO/BOP (9.b.1) Verifies Main Feedwater Isolation Valves OPEN (VB3, lower left)**

(9.b.2) Verifies Main Feedwater Isolation signal OFF (PK0911); resets as needed (VB3, center).

    • (Critical Task) (Part of S3CT2, Establish feedwater flow into at least one S/G prior to reaching bleed and feed criteria).

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 12 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 7 Page 13 of 14 Event

Description:

Loss of Secondary Heat Sink (continued) (CT)

Time Position Applicants Actions or Behavior (EOP FRH.1, "Response to Loss of Secondary Heat Sink", continued)

SRO/BOP (9.b.2) Verifies Main Feedwater Isolation signal OFF (PK0911); resets as needed (VB3, center).

SRO/ATC (9.b.3) Throttles open Main Feedwater Reg Valves OR Main Feedwater Bypass Valves** (CC3 DFWCS HMI).

    • (Critical Task) (Part of S3CT2, Establish feedwater flow into at least one S/G prior to reaching bleed and feed criteria).

SRO/BOP (9.b.4) Bypasses feedwater heaters and condensate demineralizers (opens FCV55 and FCV230) (VB3, skirt, lower right).

Note 1: Once the crew has successfully opened one of the 10% dump valves to 90% or greater, a corresponding safety will temporarily lift, causing pressure to lower faster, and then reseat. This malfunction is added to reduce scenario run time where the crew has no verifiable actions to perform and is simply monitoring the depressurization.

SRO/BOP Reads CAUTION before step 9.c regarding potential for low Tave Feedwater Isolation.

Reads NOTE about Low Tavg causing Feedwater Isolation and the need to reopen feedwater valves.

(9.c) Depressurizes ONE intact S/G to LESS THAN 490 PSIG at MAXIMUM RATE**

o (9.c.1) Verifies all MSIV and MSIV bypass valves closed (VB3, lower left).

o (9.c.2) Places one 10% dump valve in manual and opens to 90% or greater; Red indicator light ON, green indicator light OFF (VB3, middle)**

    • (Critical Task) (Part of S3CT2, Establish feedwater flow into at least one S/G prior to reaching bleed and feed criteria).

SRO/ATC o (9.c.3) Checks charging in service; may maximize during depressurization to prevent losing Pressurizer level during the cooldown.

(continued on next page)

    • Critical Task L181 NRC ESD203 r1.docx Page 13 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 3 Event No.: 7 Page 14 of 14 Event

Description:

Loss of Secondary Heat Sink (continued) (CT)

Time Position Applicants Actions or Behavior (EOP FRH.1, "Response to Loss of Secondary Heat Sink", continued)

SRO/BOP o (9.c.4) Establishes feedflow to at least one S/G (VB3)**

o (9.c.5) Stabilizes depressurized S/G pressure at 480 PSIG (VB3).

Sets depressurized S/G 10% dump valve setpoint to current S/G pressure, approx. 40% (or below) on controller.

Returns controller to AUTO.

    • (Critical Task) (Part of S3CT2, Establish feedwater flow into at least one S/G prior to reaching bleed and feed criteria).

Terminate the scenario once feedwater flow from the Condensate System is established, per the Lead Examiner L181 NRC ESD203 r1.docx Page 14 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION X IC RESTORE IC10 100%; MOL, CB - See Turnover Sheet X Setup N/A AFW 12 OOS Verify Liquid Rad Discharge and Chlorination lamicoids lined up to the 12 Train The Plant Abnormal Status Board for Surveillance Requirements Set CCP 12 boron concentration within 10 ppm of current boron concentration.

Copies of Procedures, Attachments; Appendixes; Foldout Pages; AR PK0101, PK0103, PK0416, PK0501,02,03,04, PK1301, OP O4, O28, AP 7, AP10, AP17, AP25, EOP E0, E0.1, ECA0.3, FRH.1 Annunciator Response Procedures and commonly used forms are in binders and NOT Marked up Provide Booth with copies of PK1301 and AP7 X 0 min Tools > Simple SBT Before crew takes the watch.

Use Simple SBT, Data Recorder File: sbt_sim.drb, min 960 iterations (30 sec).

Critical Task Specific Data Capture:

S3CT1: 8000B position and PRT parameters S3CT2: Feedwater iso, reg, and bypass valve positions; 10% steam dump valve positions; S/G feedflow; S/G pressures; CETCs.

X 0 min Lesson L181 NRCS3.lsn After SFM reports the crew has taken the watch, load session MALS, OVRs, etc.

by FILE or MANUALLY (below)

X Evt1: CCP 13 OC Trip Aux Watch reports burnt electrical smell in CCP 13 pump room.

(approx. 3 min after Turbine Watch reports no issues noted.

taking watch per lead examiner)

X Evt2: ASW Pp 11 ASW 11 shaft seizure and OC trip; ASW 12 autostart failure.

Shaft Seizure (once Evt1 TS addressed per lead examiner)

X Evt3: Intake Screen When contacted as Intake watch:

High DP (once Evt2 Report Kelp attack; All screen running but heavily loaded.

TS addressed per lead examiner)

X Evt4: CWPs Trip CWP 11 trips 30 seconds after FCV110A starts to open (boration for ramp)

(Major) (triggers 30 triggering programmed ramp.

secs after start of CWP 12 trips @ 1080 MW.

boration)

X Evt5: 4kV Bus F Diff 4kV Bus F Differential Trip - Loss of AFW 13 (part of Loss of Heat Sink).

(post trip)

(cont on next page)

L181 NRC ESD203 r1.docx Page 15 of 18 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions (cont)

X = manual entry required A TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION Evt6:PCV455C PORV fails 30% open.

partial opening (post trip)

Evt7 (TDAFW trip): When contacted, report FCV152 trip handle shattered.

(post trip)

L181 NRC ESD203 r1.docx Page 16 of 18 Rev 1

Diablo Canyon Power Plant Operations Shift Log Unit 1 Unit 1 Days at Power: 111 Days Operating Mode: 1 Gross Generation: 1187 MWe Power Level: 100% Net Generation: 1137 MWe Today - Dayshift Shift Manager Turnover:

PRA RISK STATUS NEXT SHIFT: Green GRID STATUS NEXT SHIFT: Normal AVERAGE RCS CALCULATED LEAKRATE: 0.01 gpm CONDENSER INLEAKAGE: < 0.01 gpd CONDENSER D/Ps: NW 5.7 SW 5.7 NE 5.7 SE 5.8 PSID MAIN GENERATOR H2 USAGE: 325 scfd / 327 scfd 5 day ave SPENT FUEL POOL: Temp = 80oF; Time to 200oF = 30 hrs using actual temp (F ID7A)

NEW EMERGENT WORK:

MDAFW 12 OOS due to low dP during routine surveillance test.

SHUTDOWN TECH SPECS / ECGS:

TS 3.7.5.B MDAFW 12, OOS due in 68 hours7.87037e-4 days <br />0.0189 hours <br />1.124339e-4 weeks <br />2.5874e-5 months <br />.

ECG ACTIONS THAT IF COMPLETION TIME NOT MET ECG 0.3 IS ENTERED:

None TURNOVER ITEMS:

MDAFW 12, estimated RTS is 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

PRIORITY ITEMS FOR NEXT SHIFT:

MDAFW 12 repair.

Shift Foreman Turnover 0B ANNUNCIATORS IN ALARM:

There are no unexpected alarms all current alarms are consistent with current mode and power level.

TURNOVER ITEMS:

U1: maintain 100% no one in containment.

U2: maintain 100%.

REACTIVITY MANAGEMENT:

Time in core life: _MOL_.

Power History: Steady State at 100% for past 3 days.

Boron concentration is _906 ppm_ from a sample taken 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago.

Control Rod Height: 231 steps on CBD.

Diluting the RCS approximately 25 gallons every 1.5 hrs.

The last dilution was completed _30 minutes ago.

CONDITIONAL SURVEILLANCES & INCREASED MONITORING:

None OTHER ABNORMAL PLANT STATUS None

Appendix D (rev 11) Scenario Outline Form ESD1 Facility: Diablo Canyon (PWR) Scenario No: 4 OpTest No: L181 NRC Examiners: Operators:

Initial Conditions: 75% Power, MOL with D/G 12 OOS Turnover: At 75% power for SCCW HX Clearance Event Malf Event Event Description No No. Type* (See Summary for Narrative Detail) 1 AB01ABV_E2_MTVIGAIN 65 cd='H_V4_176R_1 TS, C Overcurrent trip on E2 during Aux Building fan and H_V4_180L_1' delay=5 (BOP, swaps (OP H1:II, AR PK 1517, TS 3.7.12.B).

SRO) 2 XMT_CVC19_3 0.0 ramp=120 I (ATC, LT112 Fails Low (auto makeup) (OP AP19, AP SRO) 5).

3 MAL_RCS3B .07 TS, C 70 gpm RCS leak on Loop 2 (OP AP1, TS (ALL) 3.4.13.A).

4 MAL_SEI1 0.21 ramp=10 C (BOP, Seismic event causing Full Load Rejection (OP AP MAL_GEN4_3 TRIP delay=10 cd='jmlsei1' SRO) 2, AP25).

LOA_SYD6 (SYD7, SYD8, SYD16) OPEN delay=15 cd='jmlsei1' LOA_SYD16 Energized cd='jmlsei1' delay=15 5 DR04CND_HDP11_MTFSHEAR 1 C (ATC, Digital Feedwater controller failure requiring PMP_CND1_1 AS_IS SRO) reactor trip (OP AP2).

delIA PMP_CND1_1 2 delay=0 cd='V3_223S_3' 6 MAL_SYD2 0 cd='fnispr lt 5' delay=2 M (ALL) Loss of all A/C power.

MAL_EPS4E_2 DIFFERENTIAL cd='h_v4_217r_1' MAL_DEG1C_2 NO_RESET cd='H_V4_224R_1' 7 VLV_AFW7_1 1 C (BOP, TDAFW Pump fails to autostart - manual start SRO) required.

DelIA VLV_AFW7_1 2 cd='V3_219S_3'

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor L181 NRC ESD104 r2.docx Page 1 of 3 Rev 2

Appendix D (rev 11) Scenario Outline Form ESD1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) (from form ES3014) Actual Attributes

1. Total malfunctions (5-8) (Events 1,2,3,4,5,6,7) 7
2. Malfunctions after EOP entry (12) (Event 7) 1
3. Abnormal events (1-4) (Events 1,2,3,4,5) 5
4. Major transients (12) (Event 6) 1
5. EOPs entered/requiring substantive actions (1-2) (ECA0.0, ECA0.2) 2
6. EOP contingencies requiring substantive actions (0-2) (ECA0.0, ECA0.2) 2
7. Critical tasks (2-3)(See description below) 2 Critical Task Justification Reference (S4CT1) Energize at least one vital AC bus Failure to restore vital AC power from an available WCAP17711NP, CT24 prior to implementation of FLEX strategies source when available represents an unnecessary ECA0.0 Background (ECA0.0, step 10 RNO) associated with continuation of a degraded electrical condition and Document (HECA00BG),

entry into Extended Loss of AC Power Event unnecessarily complicates the mitigation strategy Rev. 3.

(ELAP) conditions (S4CT2) Establish flow from at least one Failure to manually start at least one WCAP17711NP, CT7 safety injection pump prior to transition high/intermediate head injection pump under the out of ECA0.2. postulated conditions constitutes misoperation or incorrect crew performance in which the crew does not prevent degraded core cooling capacity.

Per NUREG1021, Appendix D, if an operator or crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the postscenario review.

L181 NRC ESD104 r2.docx Page 2 of 3 Rev 2

SCENARIO

SUMMARY

- NRC #4

1. The crew performs a normal weekly fan swap for the Aux Building Ventilation System per OP H1:II, Auxiliary Building Safeguards Ventilation (ABVS) - Normal Operation, Section 6.1. Exhaust Fan E2 trips shortly after the swap bringing in AR PK1517, Aux & FHB Vent Pwr Failure. Exhaust Fan E1 restarts automatically and a field operator is dispatched to investigate. Shift Foreman enters TS 3.7.12.B, Auxiliary Building Ventilation System (ABVS) for one ABVS train inoperable (7 days).
2. Volume Control Tank (VCT) level channel LT112 fails low, causing a continuous (and erroneous) makeup signal. The crew diagnoses the level channel failure by comparing other VCT parameters, and by using OP AP19, Malfunction of the Reactor Makeup Control System. The makeup system is secured, and makeup is accomplished (if needed) using manual mode (or enabling the auto mode for short periods).

Crew may elect to use OP AP5, Malfunction of Eagle 21 Protection or Control Channel to take manual control of Makeup Control System.

3. A 70 gpm RCS leak develops, requiring entry in OP AP1, Excessive Reactor Coolant System Leakage.

The crew adjusts charging flow and eventually starts a second charging pump to stabilized pressurizer pressure. VCT level can be maintained at the current leak rate, however, and the crew determines a plant shutdown is required. Shift Foreman enters TS 3.4.13.A, RCS Operational Leakage (4 hrs).

4. A significant seismic event results in a full load rejection on Unit 1. The crew recognizes the condition based on numerous power level alarms and the ensuing secondary side transient. The crew monitors primary and secondary system responses, most notably rod control, steam dumps, and digital feedwater, to ensure all systems respond appropriately in automatic. Shift Foreman implements OP AP 2, Full Load Rejection to stabilize the plant.
5. During the ramp down, Digital Feedwater fails to manual and the Shift Foreman directs a Reactor trip.
6. Startup power is lost on the trip followed by a bus differential fault on vital 4kV bus H. Diesel Generator 13 trips and cannot be reset. The crew transitions to EOP ECA0.0, Loss of All Vital AC Power.
7. The turbine driven AFW pump fails to autostart requiring the crew to manually start the pump and dispatch field operators to throttle flow.
8. Grid Control Center informs the crew that 230kV start up power is not available, but 500 kV is available.

The crew performs actions to isolate RCP seal cooling.

9. Power is restored to vital 4kV buses F and G following the guidance of ECA0.0, Appendix DD (Backfeed from 500kV Power) (S4CT1) Energize at least one vital AC bus from prior to implementation of FLEX strategies.
10. The crew transitions to EOP ECA0.2, Loss of All AC Power with SI Required where they manually start safeguards equipment. The crew performs the final scenario critical task (S4CT2) Establish flow from at least one safety injection pump.

The scenario is terminated once injection flow is established.

L181 NRC ESD104 r2.docx Page 3 of 3 Rev 2

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 1 Page 1 of 16 Event

Description:

Perform Weekly Aux Building Supply and Exhaust Fan Swap Time Position Applicants Actions or Behavior (OP H1:II, "Auxiliary Building Safeguards Ventilation (ABVS) Normal Operation")

BOP Reads Caution regarding starting of fan shortly after shutdown.

Reads Note regarding Buildings and Safeguards mode.

(6.1.1) Notes fans have been off for at least five minutes prior to start.

(6.1.2) Places Exhaust Fan Select Switch to E2 and allows it to spring return to neutral.

Notes indicator light change (VB4).

(6.1.3) Places Supply Fan Select Switch to S32 and allows it to spring return to neutral.

Notes indicator light change (VB4).

(6.1.4) Notes correct fan operation indicated on AFHBVS Monitor (VB4).

Note: E2 trips 15 seconds after S32 is started.

(AR PK1517, "AUX & FHB VENT PWR FAILURE") if used, else N/A SRO/ATC Enters AR PK1517, "Aux & FHB Vent Pwr Failure" for input 276, Aux Bldg Exh Fan E2 UV or Lo Flo POV2.

SRO/BOP (2.2) Fan Low Flow or Fan UV.

Reads NOTE regarding AC control power supplies.

o (2.2.1) Checks that redundant exhaust fan train started automatically.

(2.2.1.a) Notes E1 restarts after slight delay.

(2.2.1.b) Checks for correct damper alignment.

(2.2.1.c) Dispatches an Operator to investigate and determine the cause of the fan failure.

(2.2.1.d) Notes not running in Safeguards Only mode.

o (2.2.22.2.4) N/A.

o (2.2.5) Refers to TS 3.7.12.B for one ABVS train inoperable. Required action:

Restore ABVS train to Operable status (7 days).

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 1 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 1 Page 2 of 16 Event

Description:

Perform Weekly Aux Building Supply and Exhaust Fan Swap (continued)

Time Position Applicants Actions or Behavior (AR PK1516, "Aux and FHB Vent Sys") if used, else N/A SRO/ATC Enters AR PK1516, "Aux & FHB Vent Sys" for input 311, AFHBVS Trouble POV2.

SRO/BOP Reads note regarding operation of Tricon HMI screens on VB4.

(2.1) AFHBVS POV Trouble Alarms.

o (2.2.1) Checks that redundant exhaust fan train started automatically.

o (2.1.2) Contacts I&C to investigate trouble alarms.

o (2.1.3) N/A o (2.1.4) May check for individual alarm input as follows:

(2.1.4.a) Selects Active Alarms screen on Tricon HMI (VB4).

(2.1.4.b) Refers to Attachment 2 for individual alarm description.

o (2.1.52.1.6) N/A o (2.1.7) Refers to TS 3.7.12.B for one ABVS train inoperable. Required action:

Restore ABVS train to Operable status (7 days).

(AR PK1622, "480V BUS 1H") if used, else N/A SRO/ATC Enters AR PK1622, "480V Bus 1H" for input 301, 480V Bus1H Mtrs TOL Trip.

SRO/BOP (2.3) Motor Thermal Overload:

o (2.3.1) Determines E2 is the load that tripped.

o (2.3.2) Verifies E1 started automatically.

o (2.3.3) May refer to OPS Policy B2, "Electrical Alarm Relay Responses," to address the overload.

Proceed to the next event once Tech Specs are addressed, per Lead Examiner

    • Critical Task L181 NRC ESD204 r1.docx Page 2 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 2 Page 3 of 16 Event

Description:

VCT Level Channel LT112 Fails Low (causes auto makeup)

Time Position Applicants Actions or Behavior ALL Diagnosis of makeup control failure is made by one or more of the following:

Automatic makeup is running, but VCT level shows normal (LT114) (PPC as L0112A, HSDP).

LT112 shows low level (0%), but VCT pressure shows normal, and CCP operation (suction) is normal (all on VB2).

Yokogawa recorder (L0112A) (VB2 upper left).

ATC Takes Makeup Control to STOP (on the makeup control HMI, CC2) (may be done before or during entry into AP).

SRO Implements OP AP19, "Malfunction of the Reactor Makeup Control System" or OP AP5, "Malfunction of Eagle 21 Protection or Control Channel".

(For OP AP19, "Malfunction of the Reactor Makeup Control System"), if entered, else N/A SRO/ATC (1.a) Ensures M/U set to correct mode (AUTO and stopped based on unwarranted makeup) (CC2).

(1.b) Determines auto makeup should NOT be selected to start due to undesired makeup operation.

SRO/BOP (2) Checks makeup system pumps and valves lineup up, and in AUTO (VB2, lower center).

ATC/BOP (3) Verifies VCT level channels OPERABLE:

o Observes discrepancy between LT112 (0%), and LT114 (normal level).

o May use VCT pressure and/or normal CCP operation to diagnose that LT112 has failed.

ALL (3 RNO) May refer to Appendix A, "Guide to Failed VCT Level Channel", step 1.b.1 to determine what effect the failed LT112 will have on makeup system operation.

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 3 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 2 Page 4 of 16 Event

Description:

VCT Level Channel LT112 Fails Low (causes auto makeup) (continued)

Time Position Applicants Actions or Behavior (OP AP19, "Malfunction of the Reactor Makeup Control System", continued)

ATC/BOP (4) Verifies CCP suction parameters are normal (CCP flow/amps/ pressure, VCT level/pressure; VB2 and CC2 meters) (as time permits).

SRO (5) Notifies Tech Maintenance to troubleshoot and repair (as time permits).

(For OP AP5, "Malfunction of Eagle 21 Protection or Control Channel") if entered, else N/A SRO/ATC (1) Confirms that Makeup Controller was NOT controlling properly in Auto and has been taken to manual (CC2).

o Refers to Attachment 5.2, "Process Control System Racks", for indications and controls affected.

SRO/BOP (2) Determines that the failure is not Eagle21 related (PK0601 and PK0603 are OFF).

SRO/ATC (3) Determines failure is not associated with a T channel (VB2).

(4) Determines Steam Dump valves are controlling properly.

SRO (5) Contacts I&C to investigate.

Reads caution regarding Eagle 21 design feature and notes it does not apply.

(6) Ensures affected channel is removed from service prior to performing maintenance.

(7) Uses Attachments 5.1 and 5.2 to determine affected indicators and evaluate TS/ECGs. Determines no TS impact.

Proceed to the next event once Makeup control system in STOP, per the lead examiner.

    • Critical Task L181 NRC ESD204 r1.docx Page 4 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 3 Page 5 of 16 Event

Description:

70 gpm RCS Leak on Loop 2 Time Position Applicants Actions or Behavior ALL Diagnoses RCS leak from one or more of the following:

Drain and/or Sump high level alarms (PK1501)

Pzr level lowering (PPC, CC2 recorder, VB2 meters)

Charging flow demand and/or low level deviation alarms (PK0521)

Containment parameters slowly rising (temp, press) (PPC, VB1 recorder, PAMS panels)

Note: Leak starts instantaneously at 70 gpm. The crew may raise charging by opening FCV128 and adjusting HCV142 (CC2) in order to maintain pressurizer level prior to entering OP AP1, "Excess Reactor Coolant System Leakage".

SRO Enters OP AP1, "Excess Reactor Coolant System Leakage".

(OP AP1, Excess Reactor Coolant System Leakage)

SRO/ATC (1.a) Determines pressurizer level and charging flow are NOT normal.

o Charging flow is elevated and pressurizer level is slowly lowering (CC2).

(1.a) Adjusts charging and seal flow to maintain pressurizer level.

o May adjust seal flows using HCV142 (CC2) to maintain 813 gpm.

o May raise charging in manual using master level controller (HC459D)(CC2) or flow controller (FCV128)(CC2).

Note: Monitoring Pressurizer level and charging flow NORMAL is a Continuous Action. Associated RNO steps are performed when crew reports applicable conditions exist (i.e. unable to maintain pressurizer level).

SRO/ATC (1.a) Determines pressurizer level is still lowering (Continuous Action to Monitor).

SRO/BOP (1.a.1 RNO) Starts second charging pump (VB2, Lower middle skirt).

SRO/ATC (1.a.2 RNO) Checks for continuing decrease in pressurizer level:

o Readjusts charging and seal flow (CC1).

o Determines pressurizer level has stabilized (PPC, VB2, CC2).

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 5 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 3 Page 6 of 16 Event

Description:

70 gpm RCS Leak on Loop 2 (continued)

Time Position Applicants Actions or Behavior (OP AP1, Excessive Reactor Coolant System Leakage, continued)

SRO/ATC (2) Checks RCS pressure greater than 2210 psig and stable (VB2) ( 22202250 psig).

(3) Determines RCS Makeup can keep up with leak.

o Makeup Control is in AUTO (CC2).

o VCT Level is stable (PPC, VB2 RCDR4 just below DRPI).

Note: Remainder of procedure focuses on identifying the actual leak location and is not part of the scenario design. The procedure does not direct review of Tech Specs until after the leak location has been identified and may need to be addressed as a follow up question.

SRO If not already completed, reviews T.S. 3.4.13.A, RCS Operational Leakage - RCS operational LEAKAGE not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE. Required actions: Reduce LEAKAGE to within limits within 4 hrs.

Proceed to the next event once Tech Specs are addressed, per Lead Examiner

    • Critical Task L181 NRC ESD204 r1.docx Page 6 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 4 Page 7 of 16 Event

Description:

Seismically Induced Full Load Rejection Time Position Applicants Actions or Behavior Note: Seismic event initiates load rejection; it is not intended that the crew respond in detail to the earthquake.

ALL Crew Diagnoses Earthquake from the following:

Physical shaking of room PK1524, "Seismic Instr System" Crew Diagnoses load rejection based on the following:

Generator load dropping Generator output breakers open.

Steam Dumps activated Rods stepping in SRO Implements OP AP2, "Full Load Rejection".

(OP AP2, "Full Load Rejection")

SRO Reads CAUTION regarding need for manual trip if deliberate operator action to stabilize the plant ON LINE is unlikely.

SRO/ATC (1) Verifies that control rods are inserting properly in AUTO (CC1).

(2) Verifies proper operation of steam dumps, Tave trending to Tref (VB3, red/green indicator lights; Tave/Tref from CC1 recorder/PPC).

SRO/BOP (3) Checks MFP suction adequate:

o (3.a) Notes standby Condensate/booster pump set did not autostart (VB3):

Takes Standby Select switch to Manual Manually starts standby pump set o (3.b) Determines MFP suction is NOT adequate (PPC, VB3 meter).

MFP suction should recover after standby Condensate/booster pump is started (4) Checks DFWCS in AUTO and controlling S/G levels (CC3 MFW HMI, VB3, PPC):

o (4.a) Determines MFW control and bypass valves in have failed to manual.

o (4.a RNO) Directs Reactor Trip.

    • Critical Task L181 NRC ESD204 r1.docx Page 7 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 5,7 Page 8 of 16 Event

Description:

Manual Reactor Trip Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection" )

SRO/ATC (1) Verifies reactor trip (trip bkrs open, rods on bottom prior to loss of bus F, NIs decreasing) (VB2, CC1).

(2) Verifies turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps).

SRO/BOP (3) Checks vital 4kV bus status (VB4, white lights on mimic buses).

o Reports all vital 4kV buses deenergized.

SRO Directs Transition to ECA0.0, "Loss of All Vital AC Power".

(ECA0.0, "Loss of All Vital AC Power")

SRO/ATC (1) Reverifies reactor trip; (trip bkrs open, rods on bottom prior to loss of bus F, NIs decreasing) (VB2, CC1).

(2) Reverifies turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps).

SRO Reads notes regarding CSF Status Trees being monitored for INFO only and need for radios.

SRO/ATC (3) Performs RCS isolation steps:

o (3a) Ensures letdown isolated (VB2):

Verifies 8149C closed.

May close LCV459/460.

o (3b) Checks Pzr PORVs closed (VB2).

o (3c) Checks Excess Letdown isolated (8166/8167, VB2 lower far right).

o (3d) Ensures NSSS sample valves closed (VB1 lower left):

Closes NSSS Pressurizer Liquid Sample Isolation Valves (9355A/B).

Closes NSSS RCS Sample Isolation Valves (9356A/B).

(continued on next page)

L181 NRC ESD204 r1.docx Page 8 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6,7 Page 9 of 16 Event

Description:

Loss of All A/C Power Time Position Applicants Actions or Behavior (ECA0.0, "Loss of All Vital AC Power", continued)

Note: Once started, TDAFW will require stationing of local operators to control the TDAFP LCVs.

SRO/BOP (4) Verifies AFW status.

o Checks AFW flow is not > 435 gpm (VB3 upper center meters, SPDS).

o May start TDAFW pump by opening FCV95 (VB4).

Note: Shift Foreman may authorize an attempted reset of the shutdown relay and DG start for D/G 13 or will dispatch field operators to walk down the diesel prior to attempting restoration. D/G 13 will not reset.

SRO/BOP (5) Attempts to restore power to any vital bus.

o (5.a) Attempts to start D/G 13.

Places D/G 13 Mode Select Switch in Manual (VB4).

Places D/G 13 Manual Mode Stop/Start Switch to Stop (VB4).

Depresses the bus F 4kV Auto Xfer Reset pushbutton (VB4).

Depresses D/G Shutdown Relay & Alarm Reset for D/G 13 (yellow lamicoid, just below associated diesel tachometer, VB4).

Checks for alarms that would prevent D/G 13 from starting.

Places D/G 13 Mode Select Switch back in Auto (VB4).

Notes D/G 13 fails to autostart.

Attempts manual start of D/G 13:

Places D/G 13 Mode Select Switch in Manual (VB4).

Places D/G 13 Manual Mode Stop/Start Switch to Start (VB4).

o (5.a RNO) May dispatch field operators to attempt local start of D/G 13.

Note: If the crew enquires about grid status, GCC reports 230kV has experienced significant damage. 500kV is available. Crew may also determine 500kV is available by checking Sync voltage on CC3.

SRO/BOP o (5.b RNO) Implements Appendix DD, "Backfeed from 500KV System" (see page 15).

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 9 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 10 of 16 Event

Description:

Loss of All A/C Power (continued)

Time Position Applicants Actions or Behavior (ECA0.0, "Loss of All Vital AC Power", continued)

Note: The Shift Foreman will continue on through ECA0.0, emphasizing step 6 (continuous action to check for any 4kV vital bus energized), while Appendix DD is implemented to restore power. Once 4kV power is restored, crew will exit ECA0.0 and enter ECA0.2, "Loss of All AC Power With SI Required" (see page 12).

SRO/ATC (7) Isolates RCP Seal Cooling:

o Reads note regarding RCP seal isolation prior to starting a CCP or CCW pump.

o (7.a) Directs field operators to close seal injection valves:

CVCS8382A, Filter 12 Outlet.

CVCS8382B, Filter 11 Outlet.

CVCS8387A, Filter Bypass.

o (7.b) Directs field operators to close CVCS8396A, Seal Return Filter Inlet Isol.

o (7.c) Directs field operators to close FCV357, RCP Therm Bar CCW Return Isol.

SRO/ATC (8) Controls Turbine driven AFW flow to limit the cooldown:

o (8.a) Checks S/G Level GREATER THAN 15% in at least one intact S/G.

o (8.b) Dispatches field operator to throttle LCVs locally.

o (8.c) Maintains S/G N/R level between 20%65%.

SRO Reads caution about resetting SI before loading 4kV loads if necessary.

Reads caution about safety hazard if bus is energized during load stripping.

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 10 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 11 of 16 Event

Description:

Loss of All A/C Power (continued)

Time Position Applicants Actions or Behavior (ECA0.0, "Loss of All Vital AC Power", continued)

SRO/ATC (9) Isolates safeguards loads from deenergized vital buses:

o Installs control switch interlocks on the following:

4KV Vital Bus F 4KV Vital Bus G 4KV Vital Bus H ASW Pump 11 ASW Pump 12 CCW Pump 13 CCW Pump 11 CCW Pump 12 CS Pump 12 SI Pump 11 CS Pump 11 SI Pump 12 CCP 11 RHR Pump 11 RHR Pump 12 AFW Pump 13 CCP 12 AFW Pump 12 o Places Standby Select switches to MANUAL (VB1):

ASW Pump 11 and 12 CCW Pump 11, 12, and 13 o Ensures all CFCU Speed Select switches in LOW (VB1) and dispatches operators to open all CFCU breakers.

CFCU No. 11 521F02 CFCU No. 14 521H01 CFCU No. 12 521F01 CFCU No. 15 521G02 CFCU No. 13 521G01 Note: On completion of Appendix DD, Shift Foreman will implement continuous action step 6 and go to step 28.

SRO/BOP (28) Determines at least one 4kV vital bus is energized.

SRO/ATC (29) Checks S/G pressure; maintains pressure using 10% steam dumps.

SRO/BOP Reads CAUTION regarding overloading capacity of power sources.

(30) Ensures following realigned/loaded on energized vital buses:

o 480 volt bus - energized.

o 125 V DC batteries and associated battery chargers.

SRO Reads NOTE regarding RCP seal cooling.

(31) Identifies ECA0.2, "Loss of All AC Power With SI Required" as the appropriate recovery procedure.

(continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 11 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 12 of 16 Event

Description:

Start Engineered Safeguards Systems Time Position Applicants Actions or Behavior (ECA0.2, "Loss of All Vital AC With SI Required")

SRO Reads CAUTION regarding CSF Status Trees being monitored for INFO only prior to the completion of step 11.

Reads NOTE regarding waiting for restoration of multiple buses before continuing on in the procedure.

Note: May use monitor light box test switch to view valve status.

SRO/ATC (1) Ensures SI RESET (status lights, VB1 and PK0821 out).

(2) Checks RWST level greater than 33%. (VB1)

(3) Manually aligns SI valves to establish injection alignment:

o (3.a) Checks Monitor Light Box A - White lights out (VB1).

o (3.b) Checks Monitor Light Box C - Some white lights ON (VB1).

Repositions the following per Appendix I, SI Valve Alignment for Injection Mode (VB2):

CHARGING INJECTION OUTLETS 8801 A&B Open CHARGING INJECTION INLETS 8801 A&B Open CHG TO REGEN HX STOP 8107 Closed CHG TO REGEN HX STOP 8108 Closed CHG PP SUCT FROM RWST 8805 A&B Open CHP PP SUCT FROM VCT LCV112 B&C Closed o (3.c) Ensures CCP recirc valves, 8105 and 8106 are OPEN.

(4) Checks RCP Thermal Barrier CCW Isolation status:

o (4.a) Checks all CCW pumps not running (VB1).

o (4.b) Notes/verifies FCV357 closed per earlier direction (VB1).

SRO/BOP (5) Manually loads Safeguards Equipment on vital 4kV buses F and G:

o (5.a) Checks vital 4Kv auto transfer relays reset - blue lights out (VB4).

SRO/ATC o (5.b) Ensures ASW pump standby select switches in MANUAL (VB1):

ASW Pump 11 ASW Pump 12 (continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 12 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 13 of 16 Event

Description:

Start Engineered Safeguards Systems, (continued)

Time Position Applicants Actions or Behavior (ECA0.2, "Loss of All Vital AC Power", continued)

SRO/ATC (5) Manually loads Safeguards Equipment on vital 4kV buses F and G (cont):

o (5.c) Ensures CCW pump standby select switches in MANUAL (VB1):

CCW Pump 11 CCW Pump 12 CCW Pump 13 o (5.d) Removes interlocks from ASW pump control switches and manually starts pumps (VB4):

ASW Pump 11 ASW Pump 12 o (5.e) Removes interlocks from CCW pump control switches (VB1):

CCW Pump 11 CCW Pump 12 CCW Pump 13 (may leave interlock due to 4kV bus H differential)

SRO/BOP (5.e.4) Ensures following valve alignments:

(5.e.4.a) Letdown orifice stop valve, 8149A, B, C: CLOSED.

(5.e.4.b) Excess letdown iso valves, 8166 or 8167: CLOSED.

(5.e.4.c) RCS and PZR sample isolation valves:

o 9354A/B CLOSED o 9355A/B CLOSED o 9356A/B CLOSED (continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 13 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 14 of 16 Event

Description:

ECA0.2, "Loss of All AC Power With SI Required", (continued)

Time Position Applicants Actions or Behavior Note: May elect to leave RHR Pump shutdown since RCS is above pump shutoff head.

SRO/ATC (5) Manually loads Safeguards Equipment on vital 4kV buses F and G:

(5.e.5) Manually starts ONE CCW pump.

o (5.f) Removes interlocks from RHR pump control switches and manually starts available pump (VB1):

RHR Pump 11 RHR Pump 12 (may leave interlock due to 4kV bus H differential) o (5.g) Removes interlocks from SI pump control switches and manually starts available pump (VB1): (S4CT2)**

SI Pump 11 SI Pump 12 (may leave interlock due to 4kV bus H differential)

    • (Critical Task) (S4CT2) Establish flow from at least one safety injection pump prior to transition out of ECA0.2.

The scenario may be terminated once Safety Injection flow is verified

    • Critical Task L181 NRC ESD204 r1.docx Page 14 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 15 of 16 Event

Description:

Loss of All A/C Power (continued) - Appendix DD, "Backfeed from 500KV System" Time Position Applicants Actions or Behavior BOP (1) Determines 500kV power is available:

o Checks Sycn bus volts approximately 120V (uses sync key on CB 532 or 632; CC3).

BOP (2) Ensures Main Generator Exciter Field Breaker - OPEN (CC3).

(3) Opens Motor Operated Disconnect (CC3).

(4) Cuts out Generator Protective Relay Toggle Switches (VB4):

o 62AMG1/62AMG11, Anti o 21G1, Main Gen Backup Motoring o 3XG1/3XG11, Sequential o 46G1, Negative Sequence o 87YG1, Differential o 81G1/T3, UF55HZ o 51RU, Unit Runback Fail Trip o 38G1, Turbine Thrust Bearing Wear o 94LSL1, Loss of System Load o 81G1/T2, UF57HZ o 40G1, Loss of Field o 81G1/T1, UF58HZ o 59G1, Overvoltage o OXP2\K3, Over Excitation o 59NG1, Neutral Running o 51E1, Exciter Overcurrent Overvoltage o 51STU1, Unit S/U Overcurrent o 78G1, Main Gen Out of Step BOP (5) Directs field operator to cutout the following Generator Protective Relay Switches in the back of Generator Relay Board RG Section 1 (128ft Cable Spreading Room):

o 62GSC3TCO, Low Flow and Run Back Failure Trip Cutout o 62GSC4TCO, Mn Gen Stator Amps Cutout o ANS2CXTCO, Stator Cooling Water Low Flow Condct Hi Trip Cutout o 62GSC5TCO, Stator Cooling Water Flow Greater than 60 min Trip Cutout (continued on next page)

    • Critical Task L181 NRC ESD204 r1.docx Page 15 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 4 Event No.: 6 Page 16 of 16 Event

Description:

Loss of All A/C Power - Appendix DD, "Backfeed from 500KV System" (continued)(CT)

Time Position Applicants Actions or Behavior BOP (6) Ensures the Gen Output Bkrs Reset Pushbutton (VB4) - Blue Light OFF.

(7) Resets Unit Trip Lockout Relays (VB4):

o 86G1 o 86G11 (8) Closes the 500kV output breakers (CC3):

o Inserts and takes sync switch for CB 532 to MAN SYN position.

Closes CB 532 o Takes sync switch for CB532 to OFF position and removes.

o Inserts and takes sync switch for CB 632 to MAN SYN position.

Closes CB 632 o Takes sync switch for CB 632 to OFF position and removes.

(9) Cuts out 4kV vital bus autotransfer to startup switches (VB4):

o Bus G o Bus F (10) Ensures the 4kV vital bus autotransfer relays are reset (VB4):

o Bus G Blue light off.

o Bus F - Blue light off.

(11) Contacts field operators to ensure safe conditions in the switchgear rooms for energizing 4kV vital buses:

o Breaker cubicles - doors closed.

o Personnel clear of 4kV vital buses.

(12) Ensures 4kV Bus F and G Startup Feeder breakers and D/G Feeder breakers are OPEN.

Note: Board Operator will update the crew prior to energizing the vital buses.

BOP (13) Closes 4kV Aux Feeder Breakers on available buses (VB4): (S4CT1)**

o Inserts and takes sync switch for Bus G, 52HG13 to CLOSE position Closes 52HG13, Aux Xfrm 12 4kV FDR to Bus G o Takes sync switch back to OFF and removes o Inserts and takes sync switch for Bus F, 52HF13 to CLOSE position Closes 52HF13, Aux Xfrm 12 4kV FDR to Bus F o Takes sync switch back to OFF and removes

    • (Critical Task) (S4CT1) Energize at least one vital AC bus from prior to implementation of FLEX strategies (ECA0.0, step 10 RNO) associated with entry into Extended Loss of AC Power Event (ELAP) conditions.

The scenario may be terminated once Safety Injection flow is verified.

    • Critical Task L181 NRC ESD204 r1.docx Page 16 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION X IC RESTORE IC11 75%; MOL, CB - See Turnover Sheet (Alt Use IC11 and swap ASW trains (12 in service w/11 shut down; may use Swap2ASWP2.lsn or perform manually)

X Setup N/A D/G 12 OOS; Verify ABVS supply fan S31 and exhaust fan E1 in service.

Check for OOS stickers from LT112 failure in prior run of scenario.

The Plant Abnormal Status Board for Surveillance Requirements STP I1C - Completed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> ago, due in 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

Copies of Procedures, Attachments; Appendixes; Foldout Pages; OP J2:V, PK0317, PK1121, AP1, AP2, AP5, AP19, EOP E0, ECA0.0, ECA 0.2 Annunciator Response Procedures and commonly used forms are in binders and NOT Marked up X 0 min Tools > Simple SBT Before crew takes the watch.

Use Simple SBT, Data Recorder File: sbt_sim.drb, min 960 iterations (30 sec).

Critical Task Specific Data Capture:

S4CT1: Vital 4kV Bus Voltage S4CT2: ECCS Injection Flow X 0 min Lesson L181 NRCS4.lsn After SFM reports the crew has taken the watch, load session MALS, OVRs, etc.

by FILE or MANUALLY (below)

X Evt1: E2 OC Trip E2 trips 15 seconds after S32 is started.

during fan swap If dispatched to check fan, report smell of burnt insulation in fan room.

(approx. 3 min after taking watch per lead examiner)

X Evt2: LT112 Fails Causes auto makeup.

Low (once Evt1 ECG addressed, per Lead Examiner)

X Evt3: RCS Leak Bottom of loop 2 cold leg.

(once Evt 2 auto makeup secured, per Lead Examiner)

X Evt4: Seismically Full Load Rejection following large seismic event.

induced Full Load Rejection (once Evt3 boration complete and TS addressed, per lead examiner)

X Evt5: Low MFP Low MFP Suction caused by Htr 2 drip pump shaft shear, OC trip of suction pressure and CBP 12, and standby CBP autostart failure (manual start works)

DFWC fails to manual.(Major) (DFW DFWCS fails to manual from PT 508A & B loss of pwr (2 of 3 PCS input control failure triggers off transmitters).

manual start of CBP Expected response is Manual Rx Trip; Turbine/Rx will auto trip if no action set) taken by crew.

(cont on next page)

L181 NRC ESD204 r1.docx Page 17 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions (cont)

X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION Evt6: Loss of All AC Bus H Differential and loss of Startup both triggered on Rx trip.

(Major) ) D/G 13 shutdown relay trigger on D/G 13 feeder breaker close.

When directed to walkdown D/G 13, report back no obvious issues identified.

Once crew enters ECA0.0, clear generator fault.

When GCC contacted, report 230 kV appears to have sustained significant damage but 500 kV is available.

Evt7 TDAFW Pump FCV95 fails to open in auto but can be opened manually in the C/R.

autostart failure (post trip)

L181 NRC ESD204 r1.docx Page 18 of 20 Rev 1

Diablo Canyon Power Plant Operations Shift Log Unit 1 Unit 1 Days at Power: 111 Days Operating Mode: 1 Gross Generation: 860 MWe Power Level: 75% Net Generation: 810 MWe Today - Dayshift Shift Manager Turnover:

PRA RISK STATUS NEXT SHIFT: Green GRID STATUS NEXT SHIFT: Normal AVERAGE RCS CALCULATED LEAKRATE: 0.01 gpm CONDENSER INLEAKAGE: < 0.01 gpd CONDENSER D/Ps: NW 5.7 SW 5.7 NE 5.7 SE 5.8 PSID MAIN GENERATOR H2 USAGE: 325 scfd / 327 scfd 5 day ave SPENT FUEL POOL: Temp = 80oF; Time to 200oF = 30 hrs using actual temp (F ID7A)

NEW EMERGENT WORK:

None SHUTDOWN TECH SPECS / ECGS:

D/G 12 Lube oil heater replacement. TS 3.8.1 Action B - due in 6 days ECG ACTIONS THAT IF COMPLETION TIME NOT MET ECG 0.3 IS ENTERED:

None TURNOVER ITEMS:

Unit is operating at 75% due to a SCCW Hx Clearance PRIORITY ITEMS FOR NEXT SHIFT:

Complete D/G 12 return to service and testing following repairs.

Perform swap of ABVS Supply and Exhaust Fans per OP H1:II, step 6.1.

ANNUNCIATORS IN ALARM:

There are no unexpected alarms all current alarms are consistent with current mode and power level.

Shift Foreman Turnover 0B TURNOVER ITEMS:

U1: maintain 75% no one in containment.

U2: maintain 100%.

REACTIVITY MANAGEMENT:

Time in core life: _MOL_.

Power History: Steady State at 75% for past 3 days.

Boron concentration is _966 ppm_ from a sample taken 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago.

Control Rod Height: 194 steps on CBD.

Diluting the RCS approximately 25 gallons every 1.5 hrs.

The last dilution was completed _30 minutes ago.

CONDITIONAL SURVEILLANCES & INCREASED MONITORING:

Perform STP I1C for D/G 12 OOS every 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

OTHER ABNORMAL PLANT STATUS None

Appendix D (rev 11) Scenario Outline Form ESD1 Facility: Diablo Canyon (PWR) Scenario No: 5 OpTest No: L181 NRC Examiners: Operators:

Initial Conditions: 100% Power, MOL with PT403 OOS Turnover: At 100% power with PT403 OOS Event Malf Event Type* Event Description No No. (See Summary for Narrative Detail) 1 None N (ATC, BOP) Swap to CCP 11 from CCP 13 per OP B1A:V, section 6.1 2 CC01CCW_CCP11_MTFSHEAR 1 TS, C (BOP, CCW Pp 11 Shaft Shear (AR PK0111; TS 3.7.7.A).

SRO) 3 MAL_PPL7J 1 TS, I (ALL) Eagle 21 DFP1 Halt in Rack 10 (OP AP5; TS 3.3.1.E,M; 3.3.2.D, L; 3.4.11 ).

4 PK1421_0829 1 C (ALL) Loss of Main Transformer Cooling (AR PK1421, AP 25) 5 MAL_SEI1 0.31 delay=0 ramp=15 M (ALL) Large seismic with no automatic or manual reactor MAL_PPL5A; PPL5B BOTH trip (ATWS).

6 MAL_RCS3C 10.0 cd='jmlsei1' M (ALL) SBLOCA following seismic; ramps in over 60 seconds.

delay=10 ramp=60 7 MAL_PPL1A FAILURE_TO_INIT C (BOP) Phase A - Train A and B fail to actuate requiring MAL_PPL1B FAILURE_TO_INIT manual alignment.

8 MAL_SYD2 0 cd='jpplsia' delay=15 C (ALL) Combination of electrical and mechanical failures PMP_SIS2_2 OVERLOAD_DEV_FAIL result in no high or intermediate injection along with cd='h_v4_218r_1' delay=3 degraded secondary side heat removal capabilities requiring manual starts of available charging pump PMP_CVC2_1 AS_IS safety injection pump.

BKR_EPS15 AS_IS BKR_EPS9_1 OVERCURRENT cd='H_V4_225R_1' MAL_AFW1 TRIP cd='h_v3_109m_1 gt 3000'

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor L181 NRC ESD105 r3.docx Page 1 of 4 Rev 3

Appendix D (rev 11) Scenario Outline Form ESD1 Target Quantitative Attributes (Per Scenario; See Section D.5.d) (from form ES3014) Actual Attributes

1. Total malfunctions (5-8) (Events 2,3,4,5,6,7,8) 7
2. Malfunctions after EOP entry (12) (Events 7,8) 2
3. Abnormal events (1-4) (Events 2,3,4) 3
4. Major transients (12) (Event 5,6) 2
5. EOPs entered/requiring substantive actions (1-2) (E1) 1
6. EOP contingencies requiring substantive actions (0-2) 0
7. Critical tasks (2-3)(See description below) 3 Critical Task Justification Reference (S5CT1) Trip the Reactor by manually de The safeguards systems that protect the plant Westinghouse Owners energizing 480V Buses 13D and 13E within during accidents are designed assuming that only Group WCAP17711NP 90 seconds of AR PK0411, Reactor Trip decay heat and pump heat are being added to the Calc G.2 Rev 5 (08151 Initiate coming into alarm. RCS. Failure to manually trip the reactor causes a 2169) challenge to the subcriticality critical safety OP1.ID2, Time Critical function beyond that irreparably introduced by the Operator Actions Rev 12, postulated conditions. #34.

(S5CT2) Manually close containment Failure to perform the critical task leads to an WCAP17711NP, CT11 isolation valves such that at least one valve unnecessary release of fission products to the is closed on each Phase A containment auxiliary building, increasing the potential for penetration before transitioning out of EOP release to the environment and reducing E0. accessibility to vital equipment within the auxiliary building (S5CT3) Start CCP 12 and SIP 12, so as to Failure to manually start available ECCS pumps WCAP17711NP, CT39 avoid a severe (Magenta) challenge to the under postulated conditions constitutes HFRC1BG Rev 3 Core Cooling critical status function. misoperation or incorrect crew performance in which the crew does not prevent "degraded emergency core cooling system (ECCS) capacity.

Per NUREG1021, Appendix D, if an operator or crew significantly deviates from or fails to follow procedures that affect the maintenance of basic safety functions, those actions may form the basis of a CT identified in the postscenario review.

L181 NRC ESD105 r3.docx Page 2 of 4 Rev 3

SCENARIO

SUMMARY

- NRC #5

1. Crew performs normal charging pump swap per OP B1A:V, CVCS - Transfer Charging Pumps, Section 6.1.
2. AR PK0111, CCW Pp 11 Recirc comes into alarm for FCV606, CCW Pump 11 Recirc Valve, open. Crew identifies low pump amps on VB1 and dispatches Nuclear Operator to investigate. Field reports no audible flow sound in spite of indications motor is running. CCW Pump 13 is started manually and CCW Pump 11 shutdown. TS 3.7.7.A, Vital Component Cooling Water (CCW) System, is entered for one loop of CCW inoperable (72 hrs).
3. Eagle 21 experiences a Digital Filter Processor (DFP) halt on rack 10. Associated indicators PI456, LI 460A, FI415, FI425, FI435, FI445 (VB2), and PR445, LR459 (CC2) fail asis as well as control channels for PORV 456 (PT456) and Pressurizer Level Control (LT460). Crew responds per OP AP5, Malfunction of Eagle 21 Protection or Control Channel. Shift Foreman reviews Tech Specs, entering:

TS 3.3.2.D, PC 456D Low Press SI (72 hrs).

TS 3.3.1.E, PC 456A High Press Trip (72 hrs).

TS 3.3.1.M, PC 456C Low Press Trip (72 hrs).

TS 3.3.1.M, LC 460A High Level Trip (72 hrs).

TS 3.3.1.M, FC415(425,435,445) RCS Loop 1 (2,3,4) Flow (72 hrs).

TS 3.3.2.L, PC456 B, P11 (1 hr).

TS 3.4.11.B1, B2, & B3 PC456E, to close & remove power from associated block valve (1 hr) and restore to operable (72 hrs).

4. Crew responds to AR PK1421, MAIN TRANSF. A nuclear operator is dispatched to investigate local alarms and reports back that NO cooling fans or oil pumps are running on the Main Bank C Transformer.

Shift Foreman enters OP AP25, Rapid Load Reduction or Shutdown and directs a 50 MW/min power reduction while Maintenance and field Operators attempt to restore transformer cooling.

5. A large earthquake (0.31 g) occurs during the ramp, but the reactor fails to trip automatically. The crew performs the immediate actions of EOP E0, Reactor Trip or Safety Injection and successfully trips the reactor by opening the breakers for 480 V buses 13D and 13E to deenergize the control rod drive mechanism (CRDM) allowing control rods to fully drop into the core (S5CT1) Trip the Reactor by manually deenergizing 480V Buses 13D and 13E.
6. A SBLOCA occurs as a result of the earthquake, but both trains of Phase A fail to actuate. The crew performs manual alignment of Phase A containment isolation valves per Appendix E, ESF Auto Actions, Secondary and Auxiliaries Status (S5CT2) Manually close containment isolation valves such that at least one valve is closed on each Phase A containment penetration.
7. Startup power is lost shortly after Safety Injection initiates and a combination of electrical and mechanical failures result in the loss of both ECCS charging pumps and safety injection pumps, with CCP 12 and SIP 12 capable of being started manually. Secondary heat removal is affected as well. The turbine driven AFW pump trips on overspeed and AFW pump 13 has no power due to a loss of 4kV bus F. The crew performs the critical task of starting the available ECCS pumps (S5CT3) Start CCP 12 and SIP 12 so as to avoid a severe (Magenta) challenge to the Core Cooling critical status function.

(continued)

L181 NRC ESD105 r3.docx Page 3 of 4 Rev 3

SCENARIO

SUMMARY

- NRC #5

8. The crew proceeds through E0, transitioning to E1, Loss of Reactor or Secondary Coolant, where they check for subsequent failures and determine the optimal procedure flow path for long term recovery.

The scenario is terminated once the crew begins evaluation of Plant Status in E1.

L181 NRC ESD105 r3.docx Page 4 of 4 Rev 3

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 1 Page 1 of 16 Event

Description:

Swap to CCP11 From CCP 13 per OP B1A:V, Section 6.1 Time Position Applicants Actions or Behavior BOP Reads NOTE regarding LTOP.

(6.1.1) Notes per Turnover Sheet, RP surveys and postings are complete.

ATC (6.1.2) Places HC459D in MANUAL (CC2).

BOP (6.1.3) Starts CCP 11 (VB2).

(6.1.4) Checks CCP 11 amps stable (VB2).

(6.1.5) Shuts down CCP 13 (VB2.)

ATC (6.1.6) Checks FI128 to verify acceptable charging flow with CCP 11 in service (CC2).

(6.1.7) Adjusts Pressurizer level to program band using HCV142 and HC459D (CC2).

(6.1.8) Adjusts RCP seal flow to 813 gpm using HCV142 and HC459D (CC2).

(6.1.9) Returns charging to AUTO once Pressurizer level is approximately at reference (CC2).

(6.1.10) N/A BOP (6.1.11) Records the date and current boron concentration for CCP 11 on the Abnormal Status Board.

Proceed to Next Event once seal flow adjusted, per Lead Examiner

    • Critical Task L181 NRC ESD205 r1.docx Page 1 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 2 Page 2 of 16 Event

Description:

CCW Pp 11 Shaft Shear Time Position Applicants Actions or Behavior Note: OP AP11, "Malfunction of Component Cooling Water System" may also be referenced for guidance on starting the standby CCW Pump, however, adequate guidance is provided in the AR PK.

ATC Observes PK0111, "CCW PP 11 RECIRC" alarming and informs the Shift Foreman (AR PK0111, "CCW PP 11, RECIRC")

SRO (2.1) Reads note describing alarm behavior alarm is enabled 1030 seconds after pump is started and disabled when the pump is shut down.

o Notes alarm is active when CCW Pp 11 amps fall below 44 amps.

BOP (2.1.1) Reports pump is running; motor current reading is approx 16 amps (VB1).

o May report CCW Header flow lower on all three headers (~ 40006000 gpm on each) (VB1).

SRO/BOP Reads note describing local reset of recirc valve.

(2.1.2) Dispatches Nuclear Operator to investigate.

Note: Nuclear Operator in the field will report the following: Recirc valve FCV606 is open, but there is no sound of flow in the adjacent piping. The pump is running, but sounds unusually high pitched.

SRO/BOP (2.1.3.a,b) Starts standby CCW Pp 13 and shuts down CCW Pp 11 (if not already done)(VB1).

(2.1.3.c) N/A May use OP F2:II, "Component Cooling Water System Changing Over Pumps and Common Components" for guidance on swapping CCW pumps.

SRO (2.1.3.d) Shift Foreman enters T.S. 3.7.7.A, Vital Component Cooling Water (CCW)

System for one loop of CCW inoperable. Required action: restore vital loop to operable status (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />).

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 2 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 2 Page 3 of 16 Event

Description:

CCW Pp 11 Shaft Shear (continued)

Time Position Applicants Actions or Behavior (OP AP11, "Malfunction of Component Cooling Water System, Section A - Loss of a CCW Pump/High CCW System Temp") if entered, else N/A.

Note: Guidance to start the standby CCW Pump is applicable once CCW Pump 11 has been shutdown.

SRO (1) Notes only (1) CCW pump is running, goes to RNO.

SRO/BOP (1 RNO) Starts CCW Pump 13:

o Places STANDBY SELECT switch in MAN (VB1).

o Takes CCW Pump 13 START/STOP switch to START.

o Goes to Step 4.

(4) Ensures ASW is supplying the inservice CCW Hx:

o Checks ASW Pp 11 inservice with normal amps (VB1).

Proceed to the next event once Tech Spec addressed, per the lead examiner

    • Critical Task L181 NRC ESD205 r1.docx Page 3 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 3 Page 4 of 16 Event

Description:

Eagle 21 DFP1 Halt in Rack 10 Time Position Applicants Actions or Behavior ATC Observes PK0601 (PPS CHANNEL SET FAILURE) and PK0604 (PPS TROUBLE) alarming and informs the SFM.

SRO Enters OP AP5, Malfunction of Eagle21 Protection or Control Channel (OP AP5, "Malfunction of Eagle21 Protection or Control Channel")

SRO/ATC (1) Ensures Primary and Secondary Control Systems Controlling Properly in AUTO.

SRO Reads notes prior to Step 2.

(2) Determines extent of Eagle 21 Instrument Failure.

o Identifies Protection Set 2 affected by PK0601 & PK0604 inputs.

o Dispatches operator to locally identify affected rack per Attachment 5.3.

o Identifies instruments affected by Rack 10 malfunction Attachment 5.1.

PT456, Pressurizer Pressure (PI456 - VB2)(PR455 CC2)

LT460, Pressurizer Level (LI460A - VB2)(LR459 - CC2)

FT415, RCS Loop 1 Flow (FI415 - VB2)

FT425, RCS Loop 2 Flow (FI425- VB2)

FT435, RCS Loop 3 Flow (FI435 - VB2)

FT445, RCS Loop 4 Flow (FI445 - VB2)

SRO/ATC (3) Rotates TR411 to channel other than Loop 2 (CC1).

SRO/BOP (4) Checks steam dumps NOT actuated:

o Steam dumps are closed, UI500 demand is zero, Dump Arming and Trip Signal lights are all out (VB3).

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 4 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 3 Page 5 of 16 Event

Description:

Eagle 21 DFP1 Halt in Rack 10 (continued)

Time Position Applicants Actions or Behavior SRO Reads NOTE regarding consequences of a rack failure.

(5) Notifies I&C to investigate.

(6) Notes the need to ensure affected channels are removed from service prior to maintenance.

BOP (7) Places OutofService stickers on affected indicators.

SRO (8) Shift Foreman review Tech Specs and enters the following:

o TS 3.3.2.D, PC 456D Low Press SI (72 hrs) o TS 3.3.1.E, PC 456A High Press Trip (72 hrs) o TS 3.3.1.M, PC 456C Low Press Trip (72 hrs) o TS 3.3.1.M, LC 460A High Level Trip (72 hrs) o TS 3.3.1.M, FC415(425,435,445) RCS Loop 1 (2,3,4) Flow (72 hrs) o TS 3.3.2.L, PC456B, P11 (1 hr) o TS 3.4.11.B1, B2, & B3 PC456 E, to close & remove power from associated PORV block valve (1 hr) and restore to operable (72 hrs)

SRO/BOP (8) Directs board operator to implement OP A4A:III, "Pressurizer - Shutdown and Clearing" to place PCV456 in close and close block valve 8000C, and dispatches Nuclear Operator to remove power.

Proceed to the next event once Tech Specs addressed, per the lead examiner

    • Critical Task L181 NRC ESD205 r1.docx Page 5 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 4 Page 6 of 16 Event

Description:

Loss of Main Transformer Cooling Time Position Applicants Actions or Behavior ATC Observes PK1421, "MAIN TRANSF", and informs the Shift Foreman.

(PK1421, "MAIN TRANSF")

SRO/ATC (1) Identifies input 829 - "Mn Bk Xfmr Annun and UV" for >90°C AND only 1 fan group running.

SRO/ATC (2.1.1, 2.1.2) Updates crew that AR PK contains the Rx Trip and Turbine Trip criteria.

(2.1.3) Dispatches Nuclear Operator to investigate and report any local alarms:

o Checks blue breaker trip lights OFF in each TQMxCx panel (6 panels total).

o Nuclear Operator will report back there are local alarms in for High Oil Temp and Low Oil Flow; notes Main Bank C has no fans running and winding temperature is currently 95oC.

SRO/BOP (2.1.4.a,b,c) When Nuclear Operator is directed to manually start the fans, reports fans did not start, and there are no oil pumps running.

(2.1.4.d) Contacts Maintenance to investigate.

SRO (2.1.6) Directs Shift Manager to contact GCC to report alarm is in due to cooling problem on Main Bank C (GCC receives local annunciator alarm when PK1421 goes into alarm).

(2.1.7) Determines alarm condition will not clear.

o (2.1.7.a) Notes alarm IS due to Main transformer bank high winding temperature and forced cooling cannot be restored.

Notes Reactor must be tripped, and E0 entered if winding temperature reaches 115oC and forced cooling has not been restored.

Updates crew that Unit will be ramped at 50 MW/min per OP AP25, "Rapid Load Reduction or Shutdown," until the Unit is off line or forced cooling is restored.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 6 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 4 Page 7 of 16 Event

Description:

Loss of Main Transformer Cooling (continued)

Time Position Applicants Actions or Behavior SRO Implements OP AP25, Rapid Load Reduction (OP AP25, "Rapid Load Reduction")

SRO Enters OP AP25, Rapid Load Reduction.

(1.a) Notes runback/programmed ramp is not in progress (may not vocalize, since this ramp is initiated by the crew).

SRO/BOP Commences ramp (guidance is also on lamicoid pegboard on CC3 or Shift Foreman will hand off Step 1 sheet to BOP):

o (1.b) MW and IMP feedbacks are placed in service (all on Triconex turbine HMI, CC3).

o (1.c) 60 MWe load target is entered into Triconex HMI.

o (1.d) Sets ramp rate to 50 mw/min.

o (1.e) Pushes GO.

o (1.f) Determines downpower is greater than 15%. May contact chemistry in advance or wait until 15% power change is complete.

ATC (2) Verifies that control rods are inserting properly in AUTO (CC1).

(3) Turns Pressurizer Backup heaters on (CC1).

(4) Checks charging adequate to prevent flashing in the letdown system; may take manual control to ensure adequate flow (CC2).

SRO/BOP (5) Ensures DFWCS is controlling S/G levels in AUTO (MFW control/bypass valves; MFPs all in AUTO) (CC2) (VB3).

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 7 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 4 Page 8 of 16 Event

Description:

Loss of Main Transformer Cooling (continued)

Time Position Applicants Actions or Behavior (OP AP25, "Rapid Load Reduction", continued)

Note: Major event of scenario is triggered by the boration flow control valve FCV110A going open following a 45 second delay.

SRO/ATC (6) Performs boration (the following guidance is on the boration checklist in the reactivity handbook):

o Presses STOP on M/U Ctrl HMI (CC2).

o Presses BORATE on HMI.

o Sets target gallons for boration verifies batch is reset.

o Sets boric acid flowrate.

o Presses START, and monitors boration.

o Once stopped, either returns to AUTO (presses AUTO, then START), or performs additional boration per the Shift Foreman(CC2).

SRO/BOP (7) Checks MFP suction pressure greater than 260 psig (VB3).

SRO/ATC (8) Checks Tavg trending to Tref (PPC, CC1).

(9) Checks Pressurizer pressure and level trending to programmed band (PPC, CC2).

Next event triggered automatically 45 seconds after boration commenced L181 NRC ESD205 r1.docx Page 8 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 5 Page 9 of 16 Event

Description:

Large seismic with no automatic or manual reactor trip (ATWS)

Time Position Applicants Actions or Behavior ALL ATWS is diagnosed from the following:

PK0411 REACTOR TRIP INITIATE (Record Time for Critical Task: _____________)

SRO Implements EOP E0, "Reactor Trip or Safety Injection".

(EOP E0, "Reactor Trip or Safety Injection")

Note: Attempt to manually trip the reactor may be done prior to entry into EOP E0 or as part of E0, step 1 RNO.

ALL Performs immediate actions:

(1) Ensure reactor trip:

o Identifies reactor is NOT tripped based on the following:

Rx Trip breakers did NOT open (VB2)

NIs are NOT lowering (CC1)

Rod bottom lights are NOT lit(VB2); moves to step 1 RNO ATC/BOP (1 RNO) Attempts Manual Reactor Trip o Tries manual reactor trip handles but is unsuccessful (CC1 or VB2).

o Opens 480V breakers 13D and 13E (VB5)(CT)** (Time Opened:__________)

o Recloses breakers 13D and 13E.

(Critical Task)(S5CT1) Trip the Reactor by manually deenergizing 480V Buses 13D and 13E within 90 seconds of PK0411, Reactor Trip Initiate coming into alarm.

SRO/ATC (1) Verifies reactor trip (trip bkrs open (VB2 upper left), rods on bottom (VB2 upper left DRPI panel), NIs decreasing (CC1 left)).

SRO/ATC (2) Verifies turbine trip (stop valves closed) (CC3 HMI or VB2 RPS indicator lamps).

SRO/BOP (3) Checks vital 4kv busses (VB4, vital busses G/H have white lights on mimic busses; bus F has no power).

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 9 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 6 Page 10 of 16 Event

Description:

Small Break LOCA (CT)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection") (continued)

SRO/ATC (4) Checks if SI actuated (PK0821 ON, also checks VB1 red train lights and/or train equipment to verify both trains actuated) (VB1 upper right, or CC2 right).

o May note loss of pumps due to bus F failure.

SRO (5) Directs App E implemented (usually to BOP)(see page 14) o Board manipulations are as follows:

Manually closes Phase A Containment Isolation Valves: (CT S5CT2)**

9356A/B (RCS Sample),

9355A/B (PZR Liquid Space Sample) (VB1, far left, lower skirt) 8045 (N2 Supply Isolation) (VB2, far right, upper) 8029 (PRT Primary Water) (VB2, far right, upper) 8100 and 8112 8152 FCV253, 255, 258, 500 (Train A)

FCV254, 256, 260, 501 (Train B)

FCV584 FCV633 8880 Starts CCP 12 and SIP 12 (S5CT3)**

Switches LCV12 to CONT ONLY (VB3).

Opens Main Feedwater Recirc Valves FCV53 & 54 (VB3).

Stops all but one CB Pp set.

Throttles RCP seal injection flows to normal if needed (FCV128, to 813 gpm each, CC2).

    • (Critical Task)(S5CT2) Manually close containment isolation valves such that at least one valve is closed on each Phase A containment penetration before transition out of EOP E0.
    • (Critical Task)(S5CT3) Start CCP 12 and SIP 12 pump so as to avoid a severe (Magenta) challenge to the Core Cooling critical status function.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 10 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 6,8 Page 11 of 16 Event

Description:

Small Break LOCA (continued)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection") (continued)

SRO/ATC (6) Checks RCS temperature stable or lowering to 547oF.

(7) Checks Pzr PORVs and Pzr Safeties and Spray Valves.

o Safeties closed (closed); no sonic flow, tailpipe temperature is elevated, but consistent with containment environment (VB2 - upper panel, far right).

o PORVs closed and block valves 8000A and 8000B are open. (VB2 - upper panel, far right).

8000C is closed and without power.

8000A is without power due to loss of bus F.

o Pzr Sprays closed (green lights on) (CC2).

SRO/ATC (8) Checks RCP trip criteria; o Notes RCPs already off due to loss of startup power (VB2).

SRO/ATC (9) Determines S/G are NOT faulted.

o No S/G lowering in an uncontrolled manner or completely depressurized.

SRO/ATC (10) Determines S/G are NOT ruptured:

o Checks RE71/72/73/74 and RE15R/19 recorders on VB2 (and PPC); (all normal) o PK1106/17/18 (all OFF).

o No levels rising in an unexpected manner.

o May request samples.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 11 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 6,8 Page 12 of 16 Event

Description:

Small Break LOCA (continued)

Time Position Applicants Actions or Behavior (EOP E0, "Reactor Trip or Safety Injection") (continued)

SRO/ALL (11) Checks RCS intact (only one valid abnormal reading needed to transition from E0):

o (11a) Determines containment pressure is NOT normal (VB1 meters, PPC).

o (11b) Determines containment sump levels NOT normal (VB1 meters, PAMS).

o (11c) Determines containment radiation is NOT normal (RM11, 02, 07 in alarm).

o (11 RNO) Places 2nd ASW/CCW HX in service (opens FCV603 and FCV431, VB1)

SRO Checks Critical Safety Function Status Trees and transitions to EOP E1, Loss of Reactor or Secondary Coolant (EOP E1, "Loss of Reactor or Secondary Coolant")

SRO/ATC (1) Rechecks RCP trip criteria, noting again pumps not running due to bus loss (VB2).

SRO/ALL (2 & 3) Rechecks for faulted/ruptured S/Gs:

o Faulted - checks all S/G pressures on VB3 (not uncontrolled drop/depressurized).

o Ruptured - checks RE71/72/73/74 and RE15R/19 recorders on VB2 (and PPC; no upward trends or spikes), and PK1106/17/18 (alarms not in); requests chemistry to sample S/Gs for activity (as follows, if done):

o Verifies phase A containment isolation reset (VB1) o Opens FCV584 (air to containment) (VB4, lower left) o Opens blowdown isolation valves inside containment (FCV760, 761, 762, 763) o Ensures Chemistry is sampling per CAP AP1.

SRO/ALL (4) Checks S/G levels:

o Intact S/Gs NR Level - GREATER THAN 15% [25%] (VB3).

o Controls feedflow to maintain NR S/G Level between 20% and 65%.

o Notes only able to feed S/Gs 11 and 12 due to equipment failures.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 12 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 6 Page 13 of 16 Event

Description:

Small Break LOCA (continued)

Time Position Applicants Actions or Behavior (EOP E1, "Loss of Reactor or Secondary Coolant") (continued)

SRO/ATC (5) Checks PORVs closed; block valves 8000A and 8000B are open (VB2 - upper panel, far right). May restore power to 8000C (5.a RNO) o 8000A is without power due to bus loss.

o 8000C is closed and without power.

SRO/ATC (6) Determines Containment Spray did not actuate and is not required.

(7) Determines ECCS flow should NOT be reduced.

o (a) RCS subcooling is less than 20oF (SCMM YI31, lower center VB2).

SRO/ATC Reads CAUTION regarding running RHR pump with cooling to associated heat exchanger.

(8) Determines RHR pump may be stopped:

o (a) Pressure is greater than 300 psig and slowly lowering. Goes to step (9) per RNO.

(9) Notes RCS Pressure is lowering and continues to step (10).

SRO/ATC (10) Checks if Diesel Generators should be stopped o (a) Checks for vital 4kV buses energized by offsite power; notes D/G powering buses G/H.

o (b) Resets SI (VB1) o (c) Leaves D/Gs running.

SRO/ALL (11) Evaluates Plant Status:

o (a) Verifies cold leg recirculation capability - notes power avail to both RHR pumps.

o (b) Checks Aux building radiation monitor - all are Normal.

o (c RNO) Opens CCW Outlet Valves from RHR Hxs, FCV364 and 365, to establish cooling to RHR pumps running on recirc. (VB2) o (d) Directs RO to Implement Appendix P, Monitor Light Box Verification (checks ECCS valve lineup).

o (e) Contacts Chemistry to sample the RCS and place H2 analyzers in service.

o (f) Checks Turbine status (oil pumps, coast down, etc).

o (g) Checks for alarms on Spent Fuel Pool level and temperature.

Once CTs S5CT2 and S5CT3 are complete, scenario may be terminated at any point past E1, step 7.

L181 NRC ESD205 r1.docx Page 13 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 7,8 Page 14 of 16 Event

Description:

(EOP E0, Appendix E) (continued) (CT)

Time Position Applicants Actions or Behavior (EOP E0, Appendix E)

BOP Implements App E (ESF Auto Actions, Secondary and Auxiliaries Status):

(1a) Checks no personnel in Containment (part of turnover; may not voice)

(1b) Announces trip/SI on PA system (2) Checks main generator - tripped (PK1401 ON, output bkrs open, and exciter field bkr open, CC3 right side)

(3 & 4) Checks Phase A and Containment Vent Isolation complete (VB1, Monitor Light Box B: red lights ON, white lights ON) o Identifies white lights associated with failed open Phase A Containment Isolation Valves.

o Manually closes Phase A Containment Isolation Valves: (CT)**

1. 9356A/B (RCS Sample),
2. 9355A/B (PZR Liquid Space Sample) (VB1, far left, lower skirt)
3. 8045 (N2 Supply Isolation) (VB2, far right, upper)
4. 8029 (PRT Primary Water) (VB2, far right, upper)
5. 8100 and 8112
6. 8152
7. FCV253, 255, 258, 500 (Train A)
8. FCV254, 256, 260, 501 (Train B)
9. FCV584
10. FCV633
11. 8880
    • (Critical Task)(S5CT2) Manually close containment isolation valves such that at least one valve is closed on each Phase A containment penetration before transition out of EOP E0.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 14 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 7,8 Page 15 of 16 Event

Description:

(EOP E0, Appendix E)(continued) (CT)

Time Position Applicants Actions or Behavior (EOP E0, "Appendix E", continued)

BOP (5) Verifies ESF (SI) actuation complete (SI Portion of Monitor Light Box C: red light ON, white lights some ON);

o Identifies white lights associated with ECCS pump failed autostarts and Bus F) o Starts CCP 12 and SIP 12 (CT)**

    • (S5CT3) Start CCP 12 and SIP 12 so as to avoid a severe (Magenta) challenge to the Core Cooling critical status function.

BOP (6) Verifies Feedwater isolation complete (F.W. Isolation and S.G. Level Portions of Monitor Light Box C: red lights ON, white lights ON (VB1).

o Determines all failures are related to loss of 4kV Bus F.

(7) Checks containment spray, Phase B - NOT required (Contmt Isol, Phase B portion of Monitor Light Box D: red lights are OFF); may also note containment pressure, while elevated, is well below actuation setpoint)

(8) Checks Main Steamline Isolate complete (Main Steam Isolation portion of Monitor Light Box D: red light OFF, white light, some ON)

BOP (9) Checks AFW status (AFW Pp 12 running, AFW Pp 13 lost from bus F) o Verifies either min of 435 gpm flow (VB3 center) or S/G level > 15% (VB3 center) o Notes only able to feed S/Gs 11 and 12 due to equipment failures.

(continued on next page)

    • Critical Task L181 NRC ESD205 r1.docx Page 15 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 OpTest No.: L181NRC Scenario No.: 5 Event No.: 7,8 Page 16 of 16 Event

Description:

(EOP E0, Appendix E) (continued)

Time Position Applicants Actions or Behavior (EOP E0, "Appendix E", continued)

BOP (10) Checks ECCS flows (charging injection (VB2 upper panel left), SI, RHR (both on VB1 upper panel);

o Identifies injection flow from both CCP 12 and SIP 12.

o Determines RHR pumps are running in recirc; RCS pressure currently above pump shutoff head. (VB1, middle center skirt)

(11) Reports ESF and AFW status to the Shift Foreman (Shift Foreman may direct operator to continue with Appendix E, or redirect to higher priority tasks)

BOP (12) Checks excess letdown - not in service (8166/8167 closed);

(13) Checks secondary systems (MFPs tripped (VB2, green lights ON) o Selects FCV53/54 to recirc.

o Stops all but one CB Pp set.

o Takes LCV12 control switch to CONT ONLY.

BOP (14) Checks proper operation of Aux Bldg and Control Rm vent systems (vent status light panel white lights)(VB4).

o Places both Unit 1 VENT TRAIN 1 BUS F and H MODE SELECT Switches to Mode 3 (VB4).

(15) Verifies available DGs running normally (freq (60), volts (120), speed (900))(VB4).

(16) Verifies vital batteries supplied by chargers (charger and bus volts)(VB5).

(17) Verifies MSRs reset (Triconex HMI)(CC3).

(18) Throttles RCP seal injection flows to normal if needed (FCV128, to 813 gpm each, CC2).

(19) Checks PK1104 NOT IN (SFP alarm).

(20) Notifies Shift Foreman of completion.

L181 NRC ESD205 r1.docx Page 16 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION X IC RESTORE IC10 100%; MOL, CB - See Turnover Sheet X Setup N/A PT403 OOS The Plant Abnormal Status Board for Surveillance Requirements Ensure Abnormal Status board reflects initial setup prior to pump swap.

Copies of Procedures, Attachments; Appendixes; Foldout Pages; OP BIA:V, AR PK0111, PK1421, OP AP5, AP11, AP25, EOP E0, E1 Annunciator Response Procedures and commonly used forms are in binders and NOT Marked up X 0 min Tools > Simple SBT Before crew takes the watch.

Use Simple SBT, Data Recorder File: sbt_sim.drb, min 960 iterations (30 sec).

Critical Task Specific Data Capture:

S5CT1: 13D & E position S5CT2: Phase A valve positions (see pg 13 for listing).

S5CT3: ECCS pump discharge pressure and amps; Charging Injection Flow FI917, and SI Flow FI918 and FI922 X 0 min Lesson L181 NRCS5.lsn After SFM reports the crew has taken the watch, load session MALS, OVRs, etc.

by FILE or MANUALLY (below)

X Evt1: Normal - Swap Normal plant evolution to swap from CCP 13 to CCP 11.

Charging Pumps (approx. 3 min after taking watch per lead examiner)

X Evt2: CCW 11 Shaft When dispatched to investigate, report back pump is running, but sounds Shear (once seal flow unusual - high pitched squealing noise. Recirc valve FCV606 is open, but there is adjusted after is no sound of water flowing in the adjacent pipe.

pump swap)

X Evt3: Eagle 21 DFP When dispatched to rack, provide crew with copy of completed AP5, Halt in Rack 10 (once Attachment 5.3 (using time compression)

Evt2 TS addressed per lead examiner)

X Evt4: Loss of Main When dispatched to Main Transformer, report back "local alarms for high oil Transformer Cooling temp and low oil flow; also note that Bank C has no fans running and winding (once Evt3 TS temperature is currently 95oC. If asked about TQMxCx panels, report back addressed) "the blue breaker trip lights are OFF".

When directed to manually start the fans, report "Fans did not start and there are no oil pumps running".

X Evt5: (Major) Seismic Seismic event is automatically triggered 45 seconds after boration flow control event ATWS valve FCV110A opens.

(triggers 45 seconds ATWS: 13D/E will work.

after FCV110A opens)

(continued on next page)

L181 NRC ESD205 r1.docx Page 17 of 20 Rev 1

Appendix D (rev 11) Required Operator Actions Form ESD2 Attachment 1 - Scenario Set-up & Booth Actions (cont)

X = manual entry required TIME LINE CONSOLE ENTRY SYMPTOMS/CUES/DESCRIPTION Evt6: (Major) SB Loca SM Loca in loop 3 cold leg.

(10 seconds after seismic)

Evt7: (Phase A, Train Phase A, Train A/B actuation failure.

A/B failure to init (post trip)

Evt8: Combination of Failures result in no high or intermediate head ECCS flow and only 1 mechanical/electrical MDAFW pump running.

failures resulting in potential ICC condition (post trip) If contacted regarding D/G 13, report (after delay) breaker mechanically jammed.

L181 NRC ESD205 r1.docx Page 18 of 20 Rev 1

Diablo Canyon Power Plant Operations Shift Log Unit 1 Unit 1 Days at Power: 111 Days Operating Mode: 1 Gross Generation: 1187 MWe Power Level: 100% Net Generation: 1137 MWe Today - Dayshift Shift Manager Turnover:

PRA RISK STATUS NEXT SHIFT: Green GRID STATUS NEXT SHIFT: Normal AVERAGE RCS CALCULATED LEAKRATE: 0.01 gpm CONDENSER INLEAKAGE: < 0.01 gpd CONDENSER D/Ps: NW 5.7 SW 5.7 NE 5.7 SE 5.8 PSID MAIN GENERATOR H2 USAGE: 325 scfd / 327 scfd 5 day ave SPENT FUEL POOL: Temp = 80oF; Time to 200oF = 30 hrs using actual temp (F ID7A)

NEW EMERGENT WORK:

None SHUTDOWN TECH SPECS / ECGS:

None ECG ACTIONS THAT IF COMPLETION TIME NOT MET ECG 0.3 IS ENTERED:

None TURNOVER ITEMS:

PT403 OOS for Calibration (TS 3.3.3.A); RTS next shift PRIORITY ITEMS FOR NEXT SHIFT:

Perform swap from CCP 13 to CCP 11 per OP B1A:V, Section 6.1. RP surveys and postings have been completed.

Shift Foreman Turnover 0B ANNUNCIATORS IN ALARM:

There are no unexpected alarms all current alarms are consistent with current mode and power level.

TURNOVER ITEMS:

U1: maintain 100% no one in containment.

U2: maintain 100%.

REACTIVITY MANAGEMENT:

Time in core life: _MOL_.

Power History: Steady State at 100% for past 3 days.

Boron concentration is _906 ppm_ from a sample taken 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago.

Control Rod Height: 231 steps on CBD.

Diluting the RCS approximately 25 gallons every 1.5 hrs.

The last dilution was completed _30 minutes ago.

CONDITIONAL SURVEILLANCES & INCREASED MONITORING:

None OTHER ABNORMAL PLANT STATUS None

ES-301 Transient and Event Checklist Form ES-301-5 Group 1 (U1, I1, R1)

Facility: Diablo Canyon Date of Exam: Feb 24, 2020 Operating Test Number: L181 A E Scenarios P V S5 S1 S3 S4 P E T M L N CREW CREW CREW CREW O I I T POSITION POSITION POSITION POSITION T N C A I A T S A B S A B S A B S A B L M N Y R T O R T O R T O R T O U T P O C P O C P O C P O C P M(*)

E R I U RX 1 1 1 1 0 RO NOR 0 1 1 1 SRO-I 1,2,3,5,6, I/C 2,3,4,6 7 10 4 4 2 SRO-U MAJ 5 4 2 2 2 1 TS 3,4 2 0 2 2 RX 1 1 1 1 0 RO NOR 0 1 1 1 SRO-I1 I/C 2,4,6 1,2,3,5,7 8 4 4 2 SRO-U MAJ 5 4 2 2 2 1 TS 1,2 2 0 2 2 RX 0 1 1 0 RO1 NOR 0 1 1 1 SRO-I I/C 2,3,4,6,7 1,3,5,7 9 4 4 2 SRO-U MAJ 5 4 2 2 2 1 TS 0 0 2 2 RX 1 1 0 RO2 NOR 1 1 1 SRO-I I/C 4 4 2 SRO-U 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 I/C malfunctions on a one for one 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 new reactor facility 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.

ES-301, Page 26 of 27 Rev 2

ES-301 Transient and Event Checklist Form ES-301-5 Group 2 (I2, I3, R2, R3)

Facility: Diablo Canyon Date of Exam: Feb 24, 2020 Operating Test Number: L181 A E Scenarios P V S5 S1 S3 S4 P E T M L N CREW CREW CREW CREW O I I T POSITION POSITION POSITION POSITION T N C A I A T S A B S A B S A B S A B L M N Y R T O R T O R T O R T O U T P O C P O C P O C P O C P M(*)

E R I U RX 1 1 1 1 0 RO NOR 1 1 1 1 1 SRO-I2 1,2,3,4,5, I/C 3,4,8 2,3,4,6 7 13 4 4 2 SRO-U MAJ 5,6 5 6 4 2 2 1 TS 3,4 1,3 4 0 2 2 RX 0 1 1 0 RO NOR 0 1 1 1 SRO-I3 I/C 2,3,4,8 1,2,3,5,7 2,3,5 12 4 4 2 SRO-U MAJ 5,6 4 6 4 2 2 1 TS 2,3 1,2 4 0 2 2 RX 1 1 1 1 0 RO2 NOR 0 1 1 1 SRO-I 1,2,3,5,6, I/C 2,4,6 7

1,3,4,7 13 4 4 2 SRO-U MAJ 5 4 6 3 2 2 1 TS 0 0 2 2 RX 0 1 1 0 RO3 NOR 1 1 1 1 1 SRO-I I/C 2,3,4,7,8 2,3,4,6,7 1,3,5,7 14 4 4 2 SRO-U MAJ 5,6 5 4 4 2 2 1 TS 0 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 I/C malfunctions on a one for one 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 new reactor facility 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.

ES-301, Page 26 of 27 Rev 2

ES-301 Transient and Event Checklist Form ES-301-5 Group 3 (I6, I7, R6, R4)

Facility: Diablo Canyon Date of Exam: Feb 24, 2020 Operating Test Number: L181 A E Scenarios P V S5 S1 S3 S4 P E T M L N CREW CREW CREW CREW O I I T POSITION POSITION POSITION POSITION T N C A I A T S A B S A B S A B S A B L M N Y R T O R T O R T O R T O U T P O C P O C P O C P O C P M(*)

E R I U RX 1 1 1 1 0 RO NOR 1 1 1 1 1 SRO-I6 1,2,3,4,5, I/C 3,4,8 2,3,4,6 7 13 4 4 2 SRO-U MAJ 5,6 5 6 4 2 2 1 TS 3,4 1,3 4 0 2 2 RX 0 1 1 0 RO NOR 0 1 1 1 SRO-I7 I/C 2,3,4,8 1,2,3,5,7 2,3,5 12 4 4 2 SRO-U MAJ 5,6 4 6 4 2 2 1 TS 2,3 1,2 4 0 2 2 RX 1 1 1 1 0 RO6 NOR 0 1 1 1 SRO-I 1,2,3,5,6, I/C 2,4,6 7

1,3,4,7 13 4 4 2 SRO-U MAJ 5 4 6 3 2 2 1 TS 0 0 2 2 RX 0 1 1 0 RO4 NOR 1 1 1 1 1 SRO-I I/C 2,3,4,7,8 2,3,4,6,7 1,3,5,7 14 4 4 2 SRO-U MAJ 5,6 5 4 4 2 2 1 TS 0 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 I/C malfunctions on a one for one 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 new reactor facility 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.

ES-301, Page 26 of 27 Rev 3

ES-301 Transient and Event Checklist Form ES-301-5 Group 4 (I4, I5, R5)

Facility: Diablo Canyon Date of Exam: Feb 24, 2020 Operating Test Number: L181 A E Scenarios P V S5 S1 S3 S4 P E T M L N CREW CREW CREW CREW O I I T POSITION POSITION POSITION POSITION T N C A I A T S A B S A B S A B S A B L M N Y R T O R T O R T O R T O U T P O C P O C P O C P O C P M(*)

E R I U RX 1 1 1 1 0 RO NOR 1 1 1 1 1 SRO-I4 1,2,3,4,5, I/C 3,4,8 2,3,4,6 7 13 4 4 2 SRO-U MAJ 5,6 5 6 4 2 2 1 TS 3,4 1,3 4 0 2 2 RX 0 1 1 0 RO NOR 0 1 1 1 SRO-I5 I/C 2,3,4,8 2,3,4,6,7 2,3,5 12 4 4 2 SRO-U MAJ 5,6 5 6 4 2 2 1 TS 2,3 2 0 2 2 RX 1 1 1 1 0 RO5 NOR 1 1 1 1 1 SRO-I I/C 2,3,4,7,8 2,4,6 1,3,4,7 12 4 4 2 SRO-U MAJ 5,6 5 6 4 2 2 1 TS 0 0 2 2 RX 0 1 1 0 RO7 NOR 0 1 1 1 SRO-I I/C 0 4 4 2 SRO-U MAJ 0 2 2 1 TS 0 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 I/C malfunctions on a one for one 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 new reactor facility 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.

ES-301, Page 26 of 27 Rev 3

ES-301 Competencies Checklist Form ES-301-6 Facility: DCPP Date of Examination: February 24, 2020 Operating Test No.: L181 GROUP I APPLICANTS RO RO RO-1 RO SRO-I SRO-I1 SRO-I SRO-I Competencies SRO-U1 SRO-U SRO-U SRO-U SCENARIO SCENARIO SCENARIO SCENARIO 5 1 3 4 5 1 3 4 1 2 3 4 1 2 3 4 Interpret/ Diagnose 2,3,4,5, 1,2,3,4, 6,7 5,6,7 1,2,3,4, 1,2,3,4, 5,6 5,6,7 2,3,4,5, 6,7 1,2,3,4, 5,6,7 Events and Conditions Comply With and Use 1,2,3,4, 1,2,3,4, 5,6,7 5,6,7 1,2,4,5, 1,2,3,4, 6 5,6,7 2,3,4,5, 6,7 1,2,3,4, 5,6,7 Procedures (1)

Operate Control 1,2,3,4, 5,6,7 1,2,5,6 2,3,4,5, 6,7 1,3,4,5, 7

Boards (2)

Communicate 1,2,3,4, 1,2,3,4, 5,6 5,6,7 1,2,3,4, 1,2,3,4, 5,6 5,6,7 2,3,4,5, 6,7 1,2,3,4, 5,6,7 and Interact Demonstrate 1,2,3,4, 5,6 1,2,3,4, 5,7 Supervisory Ability (3)

Comply With and 3,4 1,2 Use Tech Specs. (3)

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.)

ES-301, Page 27 of 27 Rev 1

ES-301 Competencies Checklist Form ES-301-6 Facility: DCPP Date of Examination: February 24, 2020 Operating Test No.: L181 GROUP II APPLICANTS RO RO RO-2 RO-3 SRO-I2 SRO-I3 SRO-I SRO-I Competencies SRO-U SRO-U SRO-U SRO-U SCENARIO SCENARIO SCENARIO SCENARIO 5 1 3 4 5 1 3 4 5 1 3 4 5 1 3 4 Interpret/ Diagnose 3,4,5,6, 2,3,4,5, 8 6,7 1,2,3,4, 2,3,4,5, 5,6,7 6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,3,4, 1,2,3,4, 1,2,3,4, 1,2,3,4, 2,3,4,5, 1,2,3,4, 5,6 5,6,7 6,7 5,6,7,8 6,7 5,6,7 Events and Conditions Comply With and Use 1,3,4,5, 1,2,3,4, 6,8 5,6,7 1,2,3,4, 1,2,3,4, 5,6,7 5,6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,4,5, 1,2,3,4, 1,3,4,6, 1,2,3,4, 2,3,4,5, 1,2,3,4, 6 5,6,7 7 5,6,7,8 6,7 5,6,7 Procedures (1)

Operate Control 1,3,4,5, 6,8 2,3,5,6 1,2,5,6 1,2,3,4, 5,6,7 1,3,4,6, 1,2,3,4, 2,3,4,5, 1,3,4,5, 7 5,6,7,8 6,7 7 Boards (2)

Communicate 1,3,4,5, 1,2,3,4, 6,8 5,6 1,2,3,4, 1,2,3,4, 5,6,7 5,6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,3,4, 1,2,3,4, 1,2,3,4, 1,2,3,4, 2,3,4,5, 1,2,3,4, 5,6 5,6,7 6,7 5,6,7,8 6,7 5,6,7 and Interact Demonstrate 1,2,3,4, 5,6 1,2,3,4, 2,3,4,5, 5,6,7 6,7,8 1,2,3,4, 5,7 Supervisory Ability (3)

Comply With and 3,4 1,3 2,3 1,2 Use Tech Specs. (3)

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.)

ES-301, Page 27 of 27 Rev 1

ES-301 Competencies Checklist Form ES-301-6 Facility: DCPP Date of Examination: February 24, 2020 Operating Test No.: L181 GROUP III APPLICANTS RO RO RO-6 RO-4 SRO-I6 SRO-I7 SRO-I SRO-I Competencies SRO-U SRO-U SRO-U SRO-U SCENARIO SCENARIO SCENARIO SCENARIO 5 1 3 4 5 1 3 4 5 1 3 4 5 1 3 4 Interpret/ Diagnose 3,4,5,6, 2,3,4,5, 8 6,7 1,2,3,4, 2,3,4,5, 5,6,7 6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,3,4, 1,2,3,4, 1,2,3,4, 1,2,3,4, 2,3,4,5, 1,2,3,4, 5,6 5,6,7 6,7 5,6,7,8 6,7 5,6,7 Events and Conditions Comply With and Use 1,3,4,5, 1,2,3,4, 6,8 5,6,7 1,2,3,4, 1,2,3,4, 5,6,7 5,6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,4,5, 1,2,3,4, 1,3,4,6, 1,2,3,4, 2,3,4,5, 1,2,3,4, 6 5,6,7 7 5,6,7,8 6,7 5,6,7 Procedures (1)

Operate Control 1,3,4,5, 6,8 2,3,5,6 1,2,5,6 1,2,3,4, 5,6,7 1,3,4,6, 1,2,3,4, 2,3,4,5, 1,3,4,5, 7 5,6,7,8 6,7 7 Boards (2)

Communicate 1,3,4,5, 1,2,3,4, 6,8 5,6 1,2,3,4, 1,2,3,4, 5,6,7 5,6,7,8 1,2,3,4, 2,3,5,6 5,6,7 1,2,3,4, 1,2,3,4, 1,2,3,4, 1,2,3,4, 2,3,4,5, 1,2,3,4, 5,6 5,6,7 6,7 5,6,7,8 6,7 5,6,7 and Interact Demonstrate 1,2,3,4, 5,6 1,2,3,4, 2,3,4,5, 5,6,7 6,7,8 1,2,3,4, 5,7 Supervisory Ability (3)

Comply With and 3,4 1,3 2,3 1,2 Use Tech Specs. (3)

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.)

ES-301, Page 27 of 27 Rev 2

ES-301 Competencies Checklist Form ES-301-6 Facility: DCPP Date of Examination: February 24, 2020 Operating Test No.: L181 GROUP IV APPLICANTS RO RO RO-5 RO SRO-I4 SRO-I5 SRO-I SRO-I Competencies SRO-U SRO-U SRO-U SRO-U SCENARIO SCENARIO SCENARIO SCENARIO 5 1 3 4 5 1 3 4 5 1 3 4 5 1 3 4 Interpret/ Diagnose 3,4,5,6, 2,3,4,5, 8 6,7 1,2,3,4, 2,3,4,5, 2,3,4,5, 5,6,7 6,7,8 6,7 2,3,5,6 1,2,3,4, 5,6,7,8 1,2,3,4, 5,6 1,2,3,4, 6,7 Events and Conditions Comply With and Use 1,3,4,5, 1,2,3,4, 6,8 5,6,7 1,2,3,4, 1,2,3,4, 2,3,4,5, 5,6,7 5,6,7,8 6,7 2,3,5,6 1,2,3,4, 5,6,7,8 1,2,4,5, 6

1,3,4,6, 7

Procedures (1)

Operate Control 1,3,4,5, 6,8 2,3,4,5, 6,7 2,3,5,6 1,2,3,4, 5,6,7,8 1,2,5,6 1,3,4,6, 7

Boards (2)

Communicate 1,3,4,5, 1,2,3,4, 6,8 5,6 1,2,3,4, 1,2,3,4, 2,3,4,5, 5,6,7 5,6,7,8 6,7 2,3,5,6 1,2,3,4, 5,6,7,8 1,2,3,4, 5,6 1,2,3,4, 6,7 and Interact Demonstrate 1,2,3,4, 5,6 1,2,3,4, 2,3,4,5, 5,6,7 6,7,8 Supervisory Ability (3)

Comply With and 3,4 1,3 2,3 Use Tech Specs. (3)

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.)

ES-301, Page 27 of 27 Rev 2