ML15007A511

2014-12 Final Operating Test Combined

ML15007A511
Person / Time
Site:	Callaway
Issue date:	12/17/2014
From:	Vincent Gaddy Operations Branch IV
To:	Union Electric Co
laura hurley
References
50-483/14-012
Download: ML15007A511 (271)

Text

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Facility: Callaway Date of Examination: 12/8/2014 Examination Level: RO Operating Test Number: 2014-1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.25 (3.9) Ability to interpret reference materials, such as Conduct of Operations graphs, curves, tables, etc.

R, M A1 JPM: Determine Time to Boil for a Loss of Shutdown Cooling 2.1.18 (3.6) Ability to make accurate, clear, and concise Conduct of Operations logs, records, status boards, and reports.

R, D A2 JPM: Complete RCS Inventory Balance 2.2.12 (3.7) Knowledge of surveillance procedures.

Equipment Control R, D, P*

A3 JPM: Review Pump Run Data and Determine if Acceptance Criteria are Met 2.3.14 (3.4) Knowledge of radiation or contamination Radiation Control hazards that may arise during normal, abnormal, R, M or emergency conditions or activities.

A4 JPM: Determine if Respirator Needs to be Worn NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

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

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

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

(S)imulator

• The JPMs from the last 2 exams were randomly selected by placing 8 slips of paper labeled A1.a 2011 through A4 2013 in a hardhat. A2 2011was drawn from the hardhat.

NUREG-1021, Revision 9

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 A1 This is a MODIFIED JPM. The parent JPM was used on the 2011 NRC SRO exam. The initial conditions (days after shutdown and RCS temperature) were changed. These changes result in different Figures being used for the time to boil determination. This results in the time to boil to change from the parent JPM. The applicant will be assigned the task of determining time to boil given a loss of RHR IAW OTO-EJ-00003, Loss of RHR While Operating at Reduced Inventory or Mid-Loop Conditions. Upon completion of this JPM the operator will have determined the Time to Boil for Condition 1 and Condition 2.

A2 This is a BANK JPM. The applicant will be assigned the task of determining the RCS leakage using OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation. Upon completion of the task the Candidate will have identified Total RCS leakage is approximately 0.6809 gpm, (range 0.680 to 0.681 gpm) Identified RCS Leakage is 0.0764 gpm, and Unidentified RCS Leakage is approximately 0.6045 gpm (range 0.604 to 0.605 gpm).

A3 This BANK JPM was used on the 2011 ILT NRC Exam. The applicant will be assigned the task of completing the calculations and determining if the Acceptance Criteria has been satisfied in accordance with OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST. Upon completion of this JPM the operator will have calculated pump flow and D/P, completed Attachment 4 of OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST, and determined that the acceptance criteria is met for the B Containment Spray Pump.

A4 This is a MODIFIED JPM. The parent JPM (Set 1 G1 A.3) has not been used on an NRC Exam administered at Callaway between 2004 and 2013. The initial conditions (dose rate and internal dose without a respirator) were changed. In the parent JPM airborne dose was given to the applicant. In the modified JPM the applicant must obtain the date from a survey map and convert from DAC to mrem. The applicant will be assigned the task of determining if personnel working on the Spent Fuel Pool rack should wear a respirator.

Upon completion of this JPM the operator will have calculated dose with and without a respirator and selected performing the job with a respirator.

NUREG-1021, Revision 9

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Facility: Callaway Date of Examination: 12/8/2014 Examination Level: SRO Operating Test Number: 2014 - 1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.18 (3.8) Ability to make accurate, clear, and concise Conduct of Operations logs, records, status boards, and reports.

R, N A5 JPM: Determine Reportability for a Required Shutdown 2.1.37 (4.6) Knowledge of procedures, guidelines, or Conduct of Operations limitations associated with reactivity R, D, P* management.

A6 JPM: Review ECP Calculation 2.2.40 (4.7) Ability to apply Technical Specifications for a Equipment Control system.

R, D A7 JPM: Determine Applicable Technical Specifications 2.3.14 (3.8) Knowledge of radiation or contamination Radiation Control hazards that may arise during normal, abnormal, R, M or emergency conditions or activities.

A8 JPM: Determine if Respirator Needs to be Worn 2.4.43 (3.8) Knowledge of emergency communications Emergency Procedures/Plan systems and techniques R or S, D A9 JPM: Make appropriate Offsite Notifications during an ALERT NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

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

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

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

• The JPMs from the last 2 exams (the 2013 re-exam was also included) were randomly selected by placing 15 slips of paper labeled A1.a 2011 through A4 2013R in a hardhat. A1.a 2013Rwas drawn from the hardhat.

Page 1 of 2

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 A5 This is a NEW JPM. The applicant will be assigned the task of determining the initial reportability requirements of a TS required shutdown per APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES. Upon completion of this JPM the operator will have determined that a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report is required to be made to the NRC Operation Center.

A6 This BANK JPM was used on the 2013 ILT NRC Re-Exam. The applicant will be assigned the task of reviewing and approving the completed Attachment 1 of OSP-SF-00005, Estimated Critical Position Calculation using the printouts and information provided by the Reactor engineer. Upon completion of this JPM, the Applicant will have identified the following errors in Attachment 1 of OSP-SF-00005 Estimated Critical Position Calculation:

1. Step 6.8.1 incorrect Anticipated RCS avg temp at startup

2. Step 6.12.2 incorrect Differential boron worth

3. Step 6.14.4 incorrect Maximum Rod Height A7 This is a BANK JPM. The applicant will be assigned the task of determining the impact of hanging a Hold Off tag on plant safety systems and identifying all applicable Technical Specifications Limiting Condition for Operation (LCO) entries that will apply. Upon completion of the JPM the candidate should determine that the applicable T/S are 3.7.4.A and 3.7.5.C.

A8 This is a MODIFIED JPM. The parent JPM (Set 1 G1 A.3) has not been used on an NRC Exam administered at Callaway between 2004 and 2013. The initial conditions (dose rate and internal dose without a respirator) were changed. In the parent JPM airborne dose was given to the applicant. In the modified JPM the applicant must obtain the date from a survey map and convert from DAC to mrem. The applicant will be assigned the task of determining if personnel working on the Spent Fuel Pool rack should wear a respirator.

Upon completion of this JPM the operator will have calculated dose with and without a respirator and selected performing the job with a respirator.

A9 This is a BANK JPM. The applicant will be assigned the task of determining the Emergency Event Classification, completing the Sentry Notification form, and performing the notification of off-site agencies within the allotted amount of time. Upon completion of this JPM the operator will have determined the event classification to be an Alert based on EAL HA-1.2, Tornado and damage to table H-1 system, within 15 minutes of start and completed the Sentry notification form and sent it within 15 minutes of the event classification time.

Page 2 of 2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A1 JPM Bank No: Set 2 G2 A.2 KSA No: 2.1.25 Revision Date: 11/18/2014 KSA Rating: 3.9 Job Title: URO/SRO Duty: ADMINISTRATIVE Task Title: Determine Time to Boil for a Loss of Shutdown Cooling Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTO-EJ-00003, Loss of RHR While Operating at Reduced Inventory or Mid-Loop Conditions, Rev. 009 OOA-BB-00003, Refuel Level Indications Tools / Equipment: None Page 1 of 5 JPM A1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Plant is in a refueling outage. The core was completely offloaded. Fuel reload with a blend of new and reused assemblies is complete. An FME concern was identified during refueling.

• The Plant has now been shutdown for 15 days

• The present RCS temperature is 180 degrees F

• The RCS has been drained down to 62.5 inches indicated on BBLI53A and BBLI53B

• The Plant Computer is unavailable Initiating Cues: The Shift Manager has requested you to determine the time to boil given OTO-EJ-00003, Loss of RHR while Operating at Reduced Inventory or Mid-Loop Conditions, and the following:

1. Using present plant conditions.

2. Three (3) days from now based on the following conditions:

• RCS level will be reduced to 14.5 inches on BBLI53A and BBLI53B

• RCS temperature will be lowered to 140 degrees F Task Standard: Condition 1, Time to Boil is determined to be 16 minutes (accept 16 to 17 minutes)

Condition 2, Time to Boil is determined to be 34 minutes (accept 33 to 34 minutes)

Start Time:

Stop Time:

Page 2 of 5 JPM A1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a copy of drawing Provide operator with Candidate obtained correct S U OOA-BB-00003, Refuel procedure OTO-EJ- procedure.

Level Indications, and a 00003 copy of OTO-EJ-00003, Comments:

Loss of RHR while Operating at Reduced Inventory or Mid-Loop

2. Determine using OOA- Operator determined S U BB-00003 that Condition condition 1 is Reduced 1 is REDUCED Inventory due to being less INVENTORY than 64 Comments:

3. Determine using OOA- Operator determined S U BB-00003 that Condition condition 2 is Mid-Loop due 2 is MID-LOOP to being at 14.5 Comments:

4. Determine using OTO- Operator determined: Figure S U EJ-00003, Step 4, that 4 is used for condition 1, Figure 4 is used for Reduced Inventory (Cold condition 1 Core)

Comments:

5. Determine using OTO- Operator determined: Figure S U EJ-00003, Step 4, that 3 is used for condition 2, Mid-Figure 3 is used for Loop (Cold Core) condition 2 Comments:

• 6. Determine time to boil Operator determines using S U for condition 1 is 16 Figure 4 time to boil for minutes condition 1 is 16 - 17 minutes Comments:

Page 3 of 5 JPM A1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 7. Determine time to boil Operator determines using S U for condition 2 is 34 Figure 3 time to boil for minutes. condition 2 is 33 to 34 minutes Comments:

8. JPM IS COMPLETE Record Stop time on page 2.

Page 4 of 5 JPM A1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Plant is in a refueling outage. The core was completely offloaded. Fuel reload with a blend of new and reused assemblies is complete. An FME concern was identified during refueling.

• The Plant has now been shutdown for 15 days

• The present RCS temperature is 180 degrees F

• The RCS has been drained down to 62.5 inches indicated on BBLI53A and BBLI53B

• The Plant Computer is unavailable Initiating Cues: The Shift Manager has requested you to determine the time to boil given OTO-EJ-00003, Loss of RHR while Operating at Reduced Inventory or Mid-Loop Conditions, and the following:

1. Using present plant conditions.

2. Three (3) days from now based on the following conditions:

• RCS level will be reduced to 14.5 inches on BBLI53A and BBLI53B

• RCS temperature will be lowered to 140 degrees F ANSWERS Present plant conditions ______________

Plant condition 3 days from now ______________

JPM A1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A2 JPM Bank No: URO-SBB-07-A014J KSA No: 2.1.18 Revision Date: 11/19/2014 KSA Rating: 3.6 Job Title: URO Duty: ADMINISTRATIVE Task Title: Complete RCS Inventory Balance Completion Time: 20 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation, REV. 03 Handouts Marked up copy of OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation, REV. 03 Tools / Equipment: Calculator Page 1 of 6 JPM A2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant has been operating at 100% steady state for the last 100 days.

• The Water Inventory Balance program on the PPC is not working

• A manual calculation using OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation is required

• All information has been recorded on Attachments 1 and 3 The Control Room Supervisor has directed you to determine the RCS leakage using Initiating Cues: OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation.

• The procedure has been completed up to Step 6.1.7.b

• Complete the calculation and inform the CRS when you are complete with the calculation.

Task Standard: Upon completion of the task the Candidate will have identified Total RCS leakage is approximately 0.6809 gpm, (range 0.680 to 0.681 gpm)

Identified RCS Leakage is 0.0764 gpm, and Unidentified RCS Leakage is approximately 0.6045 gpm (range 0.604 to 0.605 gpm).

Start Time:

Stop Time:

Page 2 of 6 JPM A2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD 1.

Review the procedure Provide operator with Candidate reviewed S U Marked up copy of procedure.

OSP-BB-00009 ADD 1, RCS Inventory Comments:

Balance Excessive Leakage or Manual Calculation 2.

Candidate fills in Candidate properly filled in Performer, Initial/PIN. Performer, Initial/PIN. and and Time/Date blocks on Time/Date blocks on Attachment 6. Attachment 6.

(SEE KEY) 3.

Determine change in Candidate determined there S U mass of water in the has been no change in mass RCDT. of water in the RCDT.

Comments:

Att 6, STEP 1.b (SEE KEY)

• 4.

Determine the change in Candidate filled in data on S U mass if water contained Attachment 6 from in the VCT. Attachment 3 and determined Li = 51% AND Lf= 43% and Comments:

Att 6, STEP 2.a and b performed calculation in step 2.b and determined change in mass of water contained in the VCT to be 1361.0318 lbm.

(range of 1361.031 to 1361.032 lbm) (3 decimal places rounded or cut-off)

(SEE KEY) 5.

Determine change in Candidate determined there S U mass of water in the has been no change in mass PZR. of water in the PZR.

Comments:

Att 6, STEP 3.b (SEE KEY)

Page 3 of 6 JPM A2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 6.

Determine change in Candidate determined there S U mass of water in the has been no change in mass PRT. of water in the PRT.

Comments:

Att 6, STEP 4.b (SEE KEY) 7.

Determine change in Candidate determined there mass of water in the RCS has been no change in mass LOOPS. of water in the RCS LOOPS.

Att 6, STEP 5.b (SEE KEY)

• 8.

Summarize RCS Candidate transferred data Leakages: from previous steps and calculated Total RCS Att 6, STEP 6.a Leakage as follows:

M(VCT) = 1361.0318 lbm M(PZR) = 0 lbm M(RCS) = 0 lbm 0.6809 gpm Toal RCS Leakage (range 0.680 to 0.681 gpm)

(3 decimal places rounded or cut-off)

(SEE KEY)

• 9.

Determine Identified RCS Candidate determined RCS Leakage. Identified Leakage is 0.0764.

Att 6, STEP 6.b This information is obtained from Att 1 (SEE KEY)

Page 4 of 6 JPM A2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 10.

Determine Unidentified Candidate determined RCS Leakage. Unidentified Leakage is 0.6045 gpm.

Att, STEP 6.c (range 0.604 to 0.605 gpm)

(3 decimal places rounded or cut-off)

(SEE KEY) 11.

Candidate notifies CRS Candidate notified CRS that S U that they have completed they have completed the the calculations. calculations.

Comments:

12. THIS ADMIN JPM IS COMPLETE Record Stop time on page 2.

Page 5 of 6 JPM A2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant has been operating at 100% steady state for the last 100 days.

• The Water Inventory Balance program on the PPC is not working

• A manual calculation using OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation is required

• All information has been recorded on Attachments 1 and 3 The Control Room Supervisor has directed you to determine the RCS leakage using Initiating Cues: OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation.

• The procedure has been completed up to Step 6.1.7.b

• Complete the calculation and inform the CRS when you are complete with the calculation.

JPM A2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A3 JPM Bank No: A3 Rev 1 KSA No: 2.2.12 Revision Date: 11/18/2014 KSA Rating: 3.7/4.1 Job Title: URO Duty: ADMINISTRATIVE Task Title: Review Pump Run Data and Determine if Acceptance Criteria are Met Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST, REVISION 44 Student Handouts Copy of OSP-EN-P001B, Attachment 4 filled in with field data.

Tools / Equipment: Calculator Page 1 of 5 JPM A3 09/14/2014 9:15 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The comprehensive pump test is being performed for PEN01B, Containment Spray Pump B, in accordance with OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST.

Field data for the surveillance has been recorded on Attachment 4, TRAIN B CONTAINMENT SPRAY PUMP COMPREHENSIVE TEST DATA SHEET.

Group B pump testing is not being performed for this surveillance.

Initiating Cues: You are an extra RO on shift. The Shift Manager (SM) has given you Attachment 4 to complete the calculations and determine if the Acceptance Criteria has been satisfied in accordance with OSP-EN-P001B.

Give your results to the SM when complete.

Task Standard: Upon completion of this JPM, the Applicant will have calculated pump flow and D/P, completed Attachment 4 of OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST, and determined that the acceptance criteria is met for the B Containment Spray Pump.

Start Time:

Stop Time:

Page 2 of 5 JPM A3 09/14/2014 9:15 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. OBTAIN A VERIFIED Provide the candidate OPERATOR OBTAINED S U WORKING COPY OF with a copy of PROCEDURE COPY OSP-EN-P001B, TRAIN ATTACHMENT 4 B CONTAINMENT FILLED IN WITH Comments:

SPRAY PUMP FIELD DATA INSERVICE TEST

• 2 CALCULATE ENFO0001 OPERATOR CALCULATES S U DIFFERENTIAL ENFO0001 DIFFERENTIAL PRESSURE AND PRESSURE AND RECORDS RECORD ON ON ATTACHMENT 4 Comments:

ATTACHMENT4 DIFFERENTIAL PRESSURE STEP 6.1.24.e.4 CALCULATED TO BE 197.9 PSID

• 3. USING EQUATION ON OPERATOR CONVERTS S U ATTACHMENT 4, ENFE0030 DIFFERENTIAL CONVERT ENFE0030 PRESSURE INTO GPM FLOW DIFFERENTIAL AND RECORDS ON Comments:

PRESSURE INTO GPM ATTACHMENT 4 FLOW AND RECORD ENFO0030 FLOW ON ATTACHMENT 4 CALCULATED TO BE 307.2 Step 6.1.24.e.6 GPM (range 307 to 308, depending on rounding)

• 4. USING EQUATION ON OPERATOR CONVERTS S U ATTACHMENT 4, ENFE0030 INCHES OF WATER CONVERT ENFE0030 COLUMN DIFFERENTIAL (H)

INCHES OF WATER INTO GPM FLOW AND Comments:

COLUMN RECORDS ON ATTACHMENT 4 DIFFERENTIAL (H)

ENFE0030 FLOW INTO GPM FLOW AND CALCULATED TO BE 2854.3 RECORD ON GPM ATTACHMENT 4 (range 2854 to 2855 depending Step 6.1.24.e.7 on rounding)

Page 3 of 5 JPM A3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 5. CALCULATE PUMP OPERATOR CALCULATES S U TOTAL FLOW BY PUMP TOTAL FLOW BY ADDING RECIRC LINE ADDING RECIRC LINE FLOW FLOW AND ENFO0001 AND ENFO0001 FLOW AND Comments:

FLOW AND RECORD RECORDS ON ATTACHMENT 4 ON ATTACHMENT 4 PUMP TOTAL FLOW Step 6.1.24.e.8 CALCULATED TO BE 3161.5 GPM (range 3161 to 3162 depending on rounding)

• 6. CALCULATE PUMP OPERATOR CALCULATES S U DIFFERENTIAL PUMP DIFFERENTIAL PRESSURE AND PRESSURE AND RECORDS RECORD ON ON ATTACHMENT 4 Comments:

ATTACHMENT 4 PUMP DIFFERENTIAL Step 6.1.24.e.11 PRESSURE CALCULATED TO BE 203.6 PSID (range 203 to 204 depending on rounding)

• 7. DETERMINE IF OPERATOR DETERMINES S U SURVEILLANCE THAT ACCEPTANCE CRITERIA RESULTS FROM IS MET ATTACHMENT 4 MEET Step 3.1: GROUP B PUMP Comments:

ACCEPTANCE TESTING NOT APPLICABLE CRITERIA FOR THIS SURVEILLANCE (GIVEN IN INITIAL CONDITIONS)

Step 3.2: ROOM COOLER AUTOMATICALLY STARTED WHEN PUMP WAS STARTED Step 3.3: PUMP TEST DATA IS NOT WITHIN THE REQUIRED ACTION RANGE

8. JPM COMPLETE Record Stop time on RECORD STOP TIME ON page 2. PAGE 2 Page 4 of 5 JPM A3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The comprehensive pump test is being performed for PEN01B, Containment Spray Pump B, in accordance with OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST.

Field data for the surveillance has been recorded on Attachment 4, TRAIN B CONTAINMENT SPRAY PUMP COMPREHENSIVE TEST DATA SHEET.

Group B pump testing is not being performed for this surveillance.

Initiating Cues: You are an extra RO on shift. The Shift Manager (SM) has given you Attachment 4 to complete the calculations and determine if the Acceptance Criteria has been satisfied in accordance with OSP-EN-P001B.

Give your results to the SM when complete.

Acceptance criteria met? YES or NO JPM A3

KEY Attachment 4 Train B Containment Spray Pump Comprehensive Test Data Sheet Sheet 1 of 1 Person (s) Performing (print) Initial/ PIN Date Started: TODAY Date Completed: TODAY Step 6.1.18 PEN01B start time: TODAY Step 6.1.20 SGL13B, AUX BLD CSP B RM CLR, started as required? (circle one) YES / NO Required Action Actual Alert Step Parameter Normal Range Range Baseline Value Range Low High ENFO00001 Press at 6.1.24.e.2 236.1 N/A N/A N/A N/A 200 ENV0108 (psig)

ENFO00001 Press at 6.1.24.e.3 38.2 N/A N/A N/A N/A 37.5 BNV0027 (psig)

Differential Pressure 6.1.24.e.4 197.9 N/A N/A N/A 162.5 across ENFO0001 (psid)

Recirc Line Inches Of Water Column 6.1.24.e.5 549.8 N/A N/A N/A N/A 550 Differential at ENFE0030 (INWC) 6.1.24.e.6 ENFO0001 Flow (gpm) 307.2 N/A N/A N/A N/A 278.4 Recirc Line Flow at 6.1.24.e.7 2854.3 N/A N/A N/A N/A 2854.8 ENFE0030 (gpm) 6.1.24.e.8 Total Pump Flow (gpm) 3161.5 3130 to 3190 N/A N/A N/A 3133.2 Disch Press Test Gauge 6.1.24.e.9 237.2 N/A N/A N/A N/A 238 at ENV0034 (psig)

Suct Press Test Gauge at 6.1.24.e.10 33.6 N/A N/A N/A N/A 31 ENV0033 (psig)

Pump Differential 186.3 to 6.1.24.e.11 203.6 192.5 to 213.2 < 186.3 > 213.2 207 Pressure (psid) < 192.5 Flow gpm = (21.84) (Differential Press across ENFO0001 psid)

Flow gpm = (121.73) (h INWC)

Step 7.7.2 Calculated Pump Spin-up Time: N/A ( 5 sec)

M & TE Data: ID Numbers GA2013 GAP2041OP Cal Due Dates: 3-15-15 4-5-15 Comments: _____________________________________________________________________________

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A4 JPM Bank No: Set 1 G1 A.3 KSA No: 2.3.14 Revision Date: 07/16/2014 KSA Rating: 3.4 / 3.8 Job Title: URO/SRO Duty: ADMINISTRATIVE Task Title: Determine if Respirator Needs to be Worn Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

HDP-ZZ-01200, RADIATION WORK PERMITS, rev 25 Handouts CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Survey Map 8765 (For Training Only)

RWP 300891 (For Training Only)

Tools / Equipment: Calculator Page 1 of 4 JPM A4 09/14/2014 9:42 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is replacing Spent Fuel Pool Racks. The old racks must be cleaned prior to shipping.

The old rack is drying out creating an Airborne Radioactivity Area.

Time to complete job without wearing a respirator is 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

If a respirator would be used, it would be an Air Supplied Delta suit with a Protection Factor (PF) of 5000.

The Efficiency Factor with an Air Supplied Delta suit respirator is 15% (x 1.15).

It has been determined that NO Engineering Controls will be used to lower dose on this task.

Initiating Cues: Complete CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Determine if personnel working on the Spent Fuel Pool rack should wear a respirator.

Task Standard: Candidate calculates dose with and without a respirator and selects performing the job without a respirator.

Start Time:

Stop Time:

Page 2 of 4 JPM A4 09/14/2014 9:42 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 1.

Candidate calculates Calculates dose without S U dose without a respirator as follows:

respirator.

External dose = (50 Comments:

mrem/hr x 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> = 200 mrem)

Internal dose = (2 DAC x 4hours x 2.5 mrem/DAC-hr = 20 mrem Total Dose - 220 mrem (See KEY)

• 2.

Candidate calculates Calculates dose without S U dose with a respirator. respirator as follows:

External dose = (1.15 (EF) Comments:

x 50 mrem/hr x 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> =

230 mrem)

Internal dose =((2 DAC x 4hours x 2.5 mrem/DAC-hr) / 5000) = 0.004 mrem Total Dose - 230 mrem (either 230 or 230.004 mrem is acceptable)

(See KEY)

• 3.

Candidates selects to Job should be done S U have the job completed without a respirator without a respirator.

Comments (See Key)

4. JPM IS COMPLETE RECORD STOP TIME S U ON PAGE 2.

Comments Page 3 of 4 JPM A4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is replacing Spent Fuel Pool Racks. The old racks must be cleaned prior to shipping.

The old rack is drying out creating an Airborne Radioactivity Area.

Time to complete job without wearing a respirator is 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

If a respirator would be used, it would be an Air Supplied Delta suit with a Protection Factor (PF) of 5000.

The Efficiency Factor with an Air Supplied Delta suit respirator is 15% (x 1.15).

It has been determined that NO Engineering Controls will be used to lower dose on this task.

Initiating Cues: Complete CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Determine if personnel working on the Spent Fuel Pool rack should wear a respirator.

JPM A4

Respiratory Protection / TEDE ALARA Evaluation Worksheet Part 1 - Task Information1 ALARA Package Number: #4857 RWP Number: 300891 Task

Description:

Fuel Rack Cleanup Total Person-Hrs: N/A Craft or Dept. Operations Work Location: Cask Washdown Pit Part 2 - Data and Assumptions2 Working Dose Rate: 50 mrem/hr DAC Fraction: 2 2 3 Contamination Level: 20000 dpm/100 cm Efficiency Factor (FF): 115%

Comments:

Part 3 - Calculations Individual Task Respirator Type Air Supplied Delta Suit Protection Factor (PF) 5000 4 Person-hrs x 50 mRem/hr = 200 mRem external DAC Fraction 2 x 4 Person-hrs x 2.5 mRem/DAC-hr = 20 mRem internal Without DAC Fraction x 4 Person-hrs x 2.5 mRem/DAC-hr = mRem internal Respirators Estimated Dose to Implement Engineering Controls = mRem Total Dose = 220 mRem TEDE 1.15 EF x 4 Person-hrs x 50 mRem/hr = 230 mRem external DAC Fraction 2 x 4 Person-hrs x 2.5 mRem/DAC-hr ÷ 5000 PF = 0.004 mRem internal With DAC Fraction x 4 Person-hrs x 2.5 mRem/DAC-hr ÷ 0 = mRem internal Respirators Estimated Dose to Implement Engineering Controls = mRem Total Dose = 230 mRem TEDE Part 4 - ALARA Recommendations Task should be performed: Without Respirators4 With Respirators As indicated below Comments Prepared by: Students name Date: Todays date RP Supervision Approval: Date:

1 When part of a larger job, limit task information, time, calculations, etc. to exact scope of the job that is being evaluated.

2 May be historical data (preferred) or estimated.

3 Use a default efficiency factor that increases task duration by 15% (x 1.15), unless data suggests a different value.

4 Ensure projected internal dose does not challenge individual dose margin. Perform in-vivo bioassay for tasks where respirators are not used and internal exposure is indicated.

HDP-ZZ-01200 CA2684 H140.0010 Page 1 of 1 06/30/2014

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A5 JPM Bank No: NEW KSA No: 2.1.18 Revision Date: 11/18/2014 KSA Rating: 3.8 Job Title: SRO Duty: ADMINISTRATIVE Task Title: Determine Reportability for a Required Shutdown Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES, REVISION 43 Tools / Equipment: None Page 1 of 4 JPM A5 09/14/2014 9:51 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: You are an extra SRO on shift An event has occurred, resulting in the following conditions:

The plant is at 99% rated thermal power.

The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Tech Spec time clock of T.S. 3.8.1.B has just expired for NE02 being inoperable.

A shutdown has been started, since it is required to be in MODE 3 in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Initiating Cues: You are an extra SRO on shift performing Control Room observations. The Shift Manager has directed you to determine the initial reportability requirements for this event per APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES.

Determine if any reportability is required, the shortest time requirement, and the agency requiring notification, if applicable.

Task Standard: The operator will have determined that a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report is required to be made to the NRC Operation Center.

Start Time:

Stop Time:

Page 2 of 4 JPM A5 09/14/2014 9:51 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Provide the candidate Candidate obtained correct S U copy of APA-ZZ-00520, with a copy of APA- procedure.

REPORTING ZZ-00520, REQUIREMENTS AND REPORTING Comments:

RESPONSIBILITIES REQUIREMENTS AND RESPONSIBILITIES

• 2 Determines a report is Determined a report is S U required per one of the required per one of the following: following:

Attachment 1, Step 5.b Attachment 1, Step 5 Comments:

OR OR Attachment 2, #25 Attachment 2, #25 OR OR Attachment 3, #96 Attachment 3, #96

• 3 Determines a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Determined a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report S U report is required is needed per Comments:

• 4 Determines the NRC Determined the NRC S U Operations Center is the Operations Center is the agency required to be agency required to be notified. notified.

Comments:

5. JPM IS COMPLETE Record Stop time on page 2.

Page 3 of 4 JPM A5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: You are an extra SRO on shift An event has occurred, resulting in the following conditions:

The plant is at 99% rated thermal power.

The 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Tech Spec time clock of T.S. 3.8.1.B has just expired for NE02 being inoperable.

A shutdown has been started, since it is required to be in MODE 3 in the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Initiating Cues: You are an extra SRO on shift performing Control Room observations. The Shift Manager has directed you to determine the initial reportability requirements for this event per APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES.

Determine if any reportability is required, the shortest time requirement, and the agency requiring notification, if applicable.

ANSWER Reportability is required per: __________________(list any applicable section of APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES OR state no reportability required)

Time Limit (if required):______________

Agency to be notified (if required):_______________

JPM A5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A6 JPM Bank No: RSA-1 rev1 KSA No: 2.1.37 Revision Date: 11/18/2014 KSA Rating: 4.6 Job Title: SRO Duty: ADMINISTRATIVE Task Title: Review ECP Calculation Completion Time: 20 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OSP-SF-00005 Estimated Critical Position Calculation Plant Curve Book Student Handouts OSP-SF-00005 Estimated Critical Position Calculation Curve Book Table 1-8 WINPCNDR Handouts Tools / Equipment: Calculator Page 1 of 5 JPM A6 09/14/2014 10:20 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant was shutdown for R19 on 4/8/13 at 0322.

The refueling outage is complete.

The Start-up is scheduled for 5/26/13 at 1200.

Reactor Engineering department has reported that the ECP program is not available and that the ECP will be calculated using Attachment 1 of OSP-SF-00005.

The Reactor Engineers have determined that the amount of negative reactivity to be:

-242.2 pcm for Step 6.9.3.

It is desired to calculate boron concentration for the ECP.

DATA from various computer programs XEPRED EFPD 0 PCNDR, section 7 BOL critical boron concentration 1421 ppm to control at HZP, ARO, (k=1.0)

Anticipated RCS Tavg at 557°F startup Initiating Cues: The Shift Manager has directed you to review and approve the completed Attachment 1 of OSP-SF-00005 Estimated Critical Position Calculation using the printouts and information provided by the Reactor engineer. Inform the Shift Manager of any issues with the calculation.

Task Standard: Upon completion of this JPM, the Applicant will have identified the following errors in Attachment 1 of OSP-SF-00005 Estimated Critical Position Calculation:

1. Step 6.8.1 incorrect Anticipated RCS avg temp at startup

2. Step 6.12.2 incorrect Differential boron worth

3. Step 6.14.4 incorrect Maximum Rod Height Start Time:

Stop Time:

Page 2 of 5 JPM A6 09/14/2014 10:20 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Provide the candidate S U with a copy of OSP-SF-00005 Estimated Critical Position Comments:

Calculation and the print outs from WinPCNDR

• 2 Candidate reviews Applicant identified the error and S U Attachment 1 of OSP-SF- informs the Shift Manager. See 00005 Estimated Critical KEY for correct data.

Position Calculation Critical steps of the Attachment Comments:

Wrong temperature in are marked on the KEY.

step 6.8.1 Error 1 incorrect Anticipated RCS avg temp at startup in Step 6.8.1 (additional errors are in the calculation due to this error being carried forward)

• 3. Candidate reviews Applicant identified the error and S U Attachment 1 of OSP-SF- informs the Shift Manager. See 00005 Estimated Critical KEY for correct data.

Position Calculation Critical steps of the Attachment Comments:

Wrong differential boron are marked on the KEY.

worth in step 6.12.2 Error 2 incorrect Differential boron worth in Step 6.12.2 (additional errors are in the calculation due to this error being carried forward)

• 4. Candidate reviews Applicant identified the error and S U Attachment 1 of OSP-SF- informs the Shift Manager. See 00005 Estimated Critical KEY for correct data.

Position Calculation Critical steps of the Attachment Comments:

Wrong Max rod height in are marked on the KEY.

step 6.14.4 Error 3 incorrect Maximum Rod Height in step 6.14.4 Page 3 of 5 JPM A6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

5. JPM IS COMPLETE Record Stop time on page 2.

Page 4 of 5 JPM A6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant was shutdown for R19 on 4/8/13 at 0322.

The refueling outage is complete.

The Start-up is scheduled for 5/26/13 at 1200.

Reactor Engineering department has reported that the ECP program is not available and that the ECP will be calculated using Attachment 1 of OSP-SF-00005.

The Reactor Engineers have determined that the amount of negative reactivity to be:

-242.2 pcm for Step 6.9.3.

It is desired to calculate boron concentration for the ECP.

DATA from various computer programs XEPRED EFPD 0 PCNDR, section 7 BOL critical boron concentration 1421 ppm to control at HZP, ARO, (k=1.0)

Anticipated RCS Tavg at 557°F startup Initiating Cues: The Shift Manager has directed you to review and approve the completed Attachment 1 of OSP-SF-00005 Estimated Critical Position Calculation using the printouts and information provided by the Reactor engineer. Inform the Shift Manager of any issues with the calculation.

JPM A6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A7 JPM Bank No: ILE-A034-SRO KSA No: 2.2.40 Revision Date: 11/18/2014 KSA Rating: 4.7 Job Title: SRO Duty: EQUIPMENT CONTROL Task Title: Determine Applicable Technical Specifications Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

Technical Specifications and Bases M-22KA05 drawing Student Handouts Tools / Equipment:

Page 1 of 4 JPM A7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: With the Callaway Plant at 100% power, tagging is being written to replace the relief valve upstream of KAV0662, SG A AFW CTRL/MS ATMS RELV VLVS KAPCV0200 DNSTRM ISO. As part of the tagging, KAV0662 will be closed with a Hold Off.

Initiating Cues: Identify all applicable Technical Specification Condition entries that will apply.

Task Standard: Upon completion of the JPM the candidate should determine that the applicable T/S are 3.7.4.A and 3.7.5.C.

Start Time:

Stop Time:

Page 2 of 4 JPM A7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Candidate reviews M- Candidate reviews print. S U 22KA05 to determine Candidate determines that impact of closing closing this valve will isolate KAV0662, SG A AFW nitrogen to the TDAFP control Comments:

CTRL/MS ATMS RELV valve and the Atmospheric VLVS KAPCV0200 Steam Dump.

DNSTRM ISO.

2 Candidate reviews Candidate determines that S U Technical Specifications closing KAV0662, SG A AFW and Bases to determine CTRL/MS ATMS RELV VLVS impact of isolating KAPCV0200 DNSTRM ISO Comments:

nitrogen to the makes ALHV008, TDAFP TO associated TDAFP flow S/G A HV, inoperable.

control valve.

3. Candidate reviews Candidate determines that S U Technical Specifications closing KAV0662, SG A AFW and Bases to determine CTRL/MS ATMS RELV VLVS impact of isolating KAPCV0200 DNSTRM ISO Comments:

nitrogen to the makes ABPV0001, Atmospheric associated Atmospheric Steam Dump, inoperable.

Steam Dump.

• 4. Candidate Identifies the Candidate determines the S U applicable Technical applicable T/S condition is Specifications 3.7.4.A for the Atmospheric Steam dump Valve.

Comments:

• 5 Candidate Identifies the Candidate determines the S U applicable Technical applicable T/S condition is Specifications 3.7.5.C for the Auxiliary Feedwater System.

Comments:

6. JPM COMPLETE Record Stop time on RECORD STOP TIME ON page 2. PAGE 2 Page 3 of 4 JPM A7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: With the Callaway Plant at 100% power, tagging is being written to replace the relief valve upstream of KAV0662, SG A AFW CTRL/MS ATMS RELV VLVS KAPCV0200 DNSTRM ISO. As part of the tagging, KAV0662 will be closed with a Hold Off.

Initiating Cues: Identify all applicable Technical Specification Condition entries that will apply.

Applicable Technical Specification(s): _________________________

JPM A7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A8 JPM Bank No: Set 1 G1 A.3 KSA No: 2.3.14 Revision Date: 07/16/2014 KSA Rating: 3.4 / 3.8 Job Title: URO/SRO Duty: ADMINISTRATIVE Task Title: Determine if Respirator Needs to be Worn Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

HDP-ZZ-01200, RADIATION WORK PERMITS, rev 25 Handouts CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Survey Map 8765 (For Training Only)

RWP 300891 (For Training Only)

Tools / Equipment: Calculator Page 1 of 4 JPM A8 09/14/2014 9:42 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is replacing Spent Fuel Pool Racks. The old racks must be cleaned prior to shipping.

The old rack is drying out creating an Airborne Radioactivity Area.

Time to complete job without wearing a respirator is 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

If a respirator would be used, it would be an Air Supplied Delta suit with a Protection Factor (PF) of 5000.

The Efficiency Factor with an Air Supplied Delta suit respirator is 15% (x 1.15).

It has been determined that NO Engineering Controls will be used to lower dose on this task.

Initiating Cues: Complete CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Determine if personnel working on the Spent Fuel Pool rack should wear a respirator.

Task Standard: Candidate calculates dose with and without a respirator and selects performing the job without a respirator.

Start Time:

Stop Time:

Page 2 of 4 JPM A8 09/14/2014 9:42 AM

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 1.

Candidate calculates Calculates dose without S U dose without a respirator as follows:

respirator.

External dose = (50 Comments:

mrem/hr x 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> = 200 mrem)

Internal dose = (2 DAC x 4hours x 2.5 mrem/DAC-hr = 20 mrem Total Dose - 220 mrem (See KEY)

• 2.

Candidate calculates Calculates dose without S U dose with a respirator. respirator as follows:

External dose = (1.15 (EF) Comments:

x 50 mrem/hr x 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> =

230 mrem)

Internal dose =((2 DAC x 4hours x 2.5 mrem/DAC-hr) / 5000) = 0.004 mrem Total Dose - 230 mrem (either 230 or 230.004 mrem is acceptable)

(See KEY)

• 3.

Candidates selects to Job should be done S U have the job completed without a respirator without a respirator.

Comments (See Key)

4. JPM IS COMPLETE RECORD STOP TIME S U ON PAGE 2.

Comments Page 3 of 4 JPM A8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is replacing Spent Fuel Pool Racks. The old racks must be cleaned prior to shipping.

The old rack is drying out creating an Airborne Radioactivity Area.

Time to complete job without wearing a respirator is 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

If a respirator would be used, it would be an Air Supplied Delta suit with a Protection Factor (PF) of 5000.

The Efficiency Factor with an Air Supplied Delta suit respirator is 15% (x 1.15).

It has been determined that NO Engineering Controls will be used to lower dose on this task.

Initiating Cues: Complete CA2684, Respiratory Protection / TEDE ALARA Evaluation Worksheet Determine if personnel working on the Spent Fuel Pool rack should wear a respirator.

JPM A8

Respiratory Protection / TEDE ALARA Evaluation Worksheet Part 1 - Task Information1 ALARA Package Number: #4857 RWP Number: 300891 Task

Description:

Fuel Rack Cleanup Total Person-Hrs: N/A Craft or Dept. Operations Work Location: Cask Washdown Pit Part 2 - Data and Assumptions2 Working Dose Rate: 50 mrem/hr DAC Fraction: 2 2 3 Contamination Level: 20000 dpm/100 cm Efficiency Factor (FF): 115%

Comments:

Part 3 - Calculations Individual Task Respirator Type Air Supplied Delta Suit Protection Factor (PF) 5000 4 Person-hrs x 50 mRem/hr = 200 mRem external DAC Fraction 2 x 4 Person-hrs x 2.5 mRem/DAC-hr = 20 mRem internal Without DAC Fraction x 4 Person-hrs x 2.5 mRem/DAC-hr = mRem internal Respirators Estimated Dose to Implement Engineering Controls = mRem Total Dose = 220 mRem TEDE 1.15 EF x 4 Person-hrs x 50 mRem/hr = 230 mRem external DAC Fraction 2 x 4 Person-hrs x 2.5 mRem/DAC-hr ÷ 5000 PF = 0.004 mRem internal With DAC Fraction x 4 Person-hrs x 2.5 mRem/DAC-hr ÷ 0 = mRem internal Respirators Estimated Dose to Implement Engineering Controls = mRem Total Dose = 230 mRem TEDE Part 4 - ALARA Recommendations Task should be performed: Without Respirators4 With Respirators As indicated below Comments Prepared by: Students name Date: Todays date RP Supervision Approval: Date:

1 When part of a larger job, limit task information, time, calculations, etc. to exact scope of the job that is being evaluated.

2 May be historical data (preferred) or estimated.

3 Use a default efficiency factor that increases task duration by 15% (x 1.15), unless data suggests a different value.

4 Ensure projected internal dose does not challenge individual dose margin. Perform in-vivo bioassay for tasks where respirators are not used and internal exposure is indicated.

HDP-ZZ-01200 CA2684 H140.0010 Page 1 of 1 06/30/2014

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A9 JPM Bank No: SRO-RER-02-A104J(TC) KSA No: 2.4.43 Revision Date: 11/18/2014 KSA Rating: 3.8 Job Title: SRO Duty: ADMINISTRATIVE Task Title: MAKE APPROPRIATE OFFSITE NOTIFICATIONS DURING AN ALERT Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

EIP-ZZ-00102, Emergency Implementing Actions EIP-ZZ-00212, Protective Action Recommendations Tools / Equipment: Copy of Procedures and Form CA2843 SENTRY Computer with printer Page 1 of 5 JPM A9

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE This JPM is TIME CRITICAL from the moment you acknowledge understanding of the Initiating Conditions and Initiating Cues.

Initial Conditions: Callaway is operating at 100% power when the following happens:

• 0800 - A sudden tornado strikes the switch yard causing a loss of all offsite power and a reactor trip

• MET tower data showed winds in excess of 100 mph

• 0803 - The RO notices that ALL the level instruments for the RWST read 0 Initiating Cues: You have been provided the combined EAL attachments and directed to determine the Emergency Event Classification and complete the Sentry Notification form and perform the notification of off-site agencies within the allotted amount of time.

This JPM is TIME CRITICAL Task Standard: Upon completion of this JPM the candidate will have determined the event classification to be an Alert based on EAL HA 1.2, Tornado and damage to table H-1 system, within 15 minutes of start and completed the Sentry notification form and sent it within 15 minutes of the event classification time. Total time not to exceed 30 minutes but the second 15 minute clock starts at the EAL classification time on Attachment 1.

Start Time:

Stop Time:

Page 2 of 5 JPM A9

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Candidate obtained S U copy of EIP-ZZ-00101, procedure copies Classification of Emergencies ADD 1 Wall Comments:

Charts and combined EAL attachments

2. NOTE: Initial Candidate read note S U classification should take place as soon as possible but NOT >15 Comments:

minutes after recognition of initiating conditions

• 3. Using the indications Candidate declared an Alert S U available and Attachment based on EAL HA 1.2, within 1, Emergency Action 15 minutes of start Levels, Shift Manager Comments:

DETERMINE the appropriate emergency classification: Time of declaration

________________

(start of new 15 min clock)

4. Notify facility personnel of Crew acknowledges Candidate announced to the S U EAL declaration EAL declaration crew the EAL declaration EIP-ZZ-00102 Att 5 flow Comments:

chart

5. Notify onsite personnel of Candidate sounded the S U EAL declaration emergency alarm and announced to the site the EIP-ZZ-00102 Att 5 flow EAL declaration Comments:

chart

6. Is the emergency an alert Yes Candidate determined this S U or higher was an Alert EIP-ZZ-00102 Att 5 flow Comments:

chart Page 3 of 5 JPM A9

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

7. Have SAS activate SAS acknowledges Candidate had SAS activate S U callout per KOA-ZZ- and activated callout callout using message #1 000200 using message #1 Comments:

EIP-ZZ-00102 Att 5 flow chart

8. Is emergency a general No Candidate determined this in S U emergency NOT a general emergency EIP-ZZ-00102 Att 5 flow Comments:

chart

• 9. Using Sentry Computer If asked : Candidate filled out the S U System fill out and send Sentry notification form an No release above the completed Sentry sent it within 15 minutes of normal operating limits notification form completing the EAL Comments:

classification EIP-ZZ-00102 Att 5 flow chart The JPM is complete Lines 2, 3, 4, and 5 on Sentry print out are critical Time sent

- see KEY ____________

nd (Printed form) (completion time of 2 15 min clock)

Page 4 of 5 JPM A9

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway is operating at 100% power when the following happens:

• 0800 - A sudden tornado strikes the switch yard causing a loss of all offsite power and a reactor trip

• MET tower data showed winds in excess of 100 mph

• 0803 - The RO notices that ALL the level instruments for the RWST read 0 Initiating Cues: You have been provided the combined EAL attachments and directed to determine the Emergency Event Classification and complete the Sentry Notification form and perform the notification of off-site agencies within the allotted amount of time.

This JPM is TIME CRITICAL JPM A9

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 Facility: ____Callaway_____________________ Date of Examination: _12/8/14_____

Exam Level: RO SRO-I SRO-U Operating Test No.: __2014-1____

@

Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)

System / JPM Title Type Code* Safety Function S1 004 CVCS (BG) / Perform a Dilution N, S 1 S2 006 ECCS (SB) / Initial RCS Depressurization and SI Block L, M, S 2 S3 010 Reactor Coolant System (BB) / Perform System Surveillance - D, P*, S 3 BBHV8000A Stroke Test S4 003 Reactor Coolant Pump System (BB) / Start Reactor Coolant Pump A, M, S 4P during RCS Natural Circulation Cooldown S5 026 Containment Spray (EN) / Align Containment Spray for Recirculation A, D, EN, S 5 S6 064 SR Elect Gen and Dist (NE) / Manually Start Diesel Generators A, M, S 6 S7 016 Non-Nuclear Instrumentation System (NN) / Selection of available N, S 7 Instrumentation S8 008 Component Cooling Water System (EG) / Respond to a loss of CCW A, D, S 8 to the RCPs

@

In-Plant Systems (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P1 068 Control Room Evacuation / Operate the PZR Heaters at the Aux E, M, R 3 Shutdown Panel P2 015 Reactor Coolant Pump Malfunction / Local RCP Seal Isolation A, D, E, R 4P P3 068 Control Room Evacuation / Locally Trip Reactor Trip and Bypass E, M, R 1 Breakers

@ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

• Type Codes Criteria for RO / SRO-I / SRO-U Page 1 of 4

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 (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 (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

• The JPMs from the last 2 exams were randomly selected by placing 22 slips of paper labeled a through k for the 2011 exam and S1 through P3 from the 2013 exam in a hardhat. Two of these items (S2 and P1) were drawn from the hardhat. S2 was used as S3 on this exam. P1 was originally used as P1 on this exam. P1 was replaced after NRC review of the originally submitted outline.

S1 This is a NEW JPM. The applicant will be assigned the task of diluting the RCS 100 gallons by performing a nominal 120 gpm dilution per OTN-BG-00002, Reactor Makeup Control and Boron Thermal Regeneration System. Upon completion of this JPM, the Applicant will have diluted the RCS 100 gallons (acceptable range 97 to 103 gallons).

S2 This is a MODIFIED JPM in a SHUTDOWN condition. The parent JPM (URO-NOP-06-C153J) has not been used on an NRC Exam administered at Callaway between 2004 and 2013. The last revision to this JPM was in 2005. The actions to perform this task are now covered by a different procedure. Additionally the method for lowering RCS pressure has been changed. The applicant will be assigned the task of depressurizing the RCS and blocking the SI signal, per OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block. Upon completion of this JPM, the applicant will have blocked both trains of Pressurizer Pressure and Steam Line Pressure Safety Injection without initiating a Safety Injection.

S3 This BANK JPM was used on the 2013 ILT NRC Exam. It was randomly selected using the method described above. The applicant will be assigned the task of performing the Stroke Time Test for BBHV8000A, RCS PZR OUT PWR OPER RLF HV, per OSP-BB-V0001, RCS Valve Inservice Test, Section 6.1. Upon completion of this JPM, the applicant will have completed the Stroke Time Test for BBHV8000A per OSP-BB-V0001 and reported to the CRS that the Acceptance Criteria was not satisfied.

Page 2 of 4

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 S4 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO-AEO C052J) has not been used on an NRC Exam administered at Callaway between 2004 and 2013.The parent JPM was not alternate path and the applicant was successful in starting the D RCP. The applicant will be assigned the task of starting D Reactor Coolant Pump in accordance with EOP Addendum 3, Starting An RCP.

The D RCP will not start and the applicant will then start the A (or B) RCP. Upon completion of this JPM, the operator will have started RCP A (or B) and secured the respective RCP Oil Lift pump.

S5 This is an ALTERNATE PATH, BANK JPM. The applicant will be assigned the task of completing the actions of ES-1.3, Transfer to Cold Leg Recirculation, Step 6.

Upon completion of this JPM, the applicant will have aligned the train B Containment Spray Pump to a recirculating lineup and secured the train A Containment Spray Pump.

S6 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO-AEO C174J(A)) was used on the 2011 NRC Exam administered at Callaway. The parent JPM had both EDGs start and the B ESW pump start. In the modified JPM the B ESW pump does not start and the NE02 (B EDG) must be secured. The applicant will be assigned the task of completing the actions of Step 5 of ECA-0.0, Loss of All AC Power. Upon completion of this JPM, the applicant will have manually started NE01 and manually started A ESW Pump prior to A DG auto trip.

S7 This is a NEW JPM. The applicant will be assigned the task of selecting the correct instrumentation in accordance with OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER. Upon completion of this JPM, the operator will have selected the proper instrumentation for SG Flow and Level and PZR pressure and level.

S8 This is an ALTERNATE PATH, TIME CRITICAL, BANK JPM. The applicant will be assigned the task of performing Attachment C of OTO-BB-00002, RCP Off-Normal to address a loss of CCW to the RCPs. Upon completion of this JPM, the operator will have restored CCW to Containment (within 10 minutes) and the RCPs.

P1 This is a MODIFIED JPM. The parent JPM (URO-AEO-02-P015J) was last used on the 2007 NRC Exam administered at Callaway. The JPM was used on the 2013 ILT NRC Exam. The parent JPM had the operator taking action to control SG water level, the modified JPM has the operator taking action to control PZR pressure. The operator will be assigned the task of performing OTO-ZZ-00001, Control Room Inaccessibility Attachment G, Control Room Supervisor (CRS) Actions Without A Fire. Upon completion of this JPM the Operator will have demonstrated the ability to control RCS temperature and PZR pressure from the Aux Shutdown Panel.

P2 This is an ALTERNATE PATH, BANK JPM. The operator will be assigned the task of locally isolating RCP Seals using EOP Addendum 22, Local RCP Seal Isolation.

Upon completion of this JPM, the operator will have successfully isolate RCP seals.

Page 3 of 4

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 P3 This is a MODIFIED JPM. The operator will be assigned the task of performing OTO-ZZ-00001, Control Room Inaccessibility Attachment A, Safe Shutdown Operator Actions with Fire. Upon completion of this JPM the operator will have isolated loads on MCC NG04C, placed class 1E electrical equipment A/C unit in ISO/RUN, aligned CCW and locally tripped both reactor trip breakers and bypass breakers.

Page 4 of 4

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 Facility: ____Callaway_____________________ Date of Examination: _12/8/14_____

Exam Level: RO SRO-I SRO-U Operating Test No.: __2014-1____

@

Control Room Systems (8 for RO); (7 for SRO-I); (2 or 3 for SRO-U, including 1 ESF)

System / JPM Title Type Code* Safety Function S1 004 CVCS (BG) / Perform a Dilution N, S 1 S2 006 ECCS (SB) / Initial RCS Depressurization and SI Block L, M, S 2 S3 010 Reactor Coolant System (BB) / Perform System Surveillance - D, P*, S 3 BBHV8000A Stroke Test S4 003 Reactor Coolant Pump System (BB) / Start Reactor Coolant Pump A, M, S 4P during RCS Natural Circulation Cooldown S5 026 Containment Spray (EN) / Align Containment Spray for Recirculation A, D, EN, S 5 S6 064 SR Elect Gen and Dist (NE) / Manually Start Diesel Generators A, M, S 6 S8 008 Component Cooling Water System (EG) / Respond to a loss of CCW A, D, S 8 to the RCPs

@

In-Plant Systems (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P1 068 Control Room Evacuation / Operate the PZR Heaters at the Aux E, M, R 3 Shutdown Panel P2 015 Reactor Coolant Pump Malfunction / Local RCP Seal Isolation A, D, E, R 4P P3 068 Control Room Evacuation / Locally Trip Reactor Trip and Bypass E, M, R 1 Breakers

@ All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all 5 SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

• Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature - / - / 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 Page 1 of 3

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2

• The JPMs from the last 2 exams were randomly selected by placing 22 slips of paper labeled a through k for the 2011 exam and S1 through P3 from the 2013 exam in a hardhat. Two of these items (S2 and P1) were drawn from the hardhat. S2 was used as S3 on this exam. P1 was originally used as P1 on this exam. P1 was replaced after NRC review of the originally submitted outline.

S1 This is a NEW JPM. The applicant will be assigned the task of diluting the RCS 100 gallons by performing a nominal 120 gpm dilution per OTN-BG-00002, Reactor Makeup Control and Boron Thermal Regeneration System. Upon completion of this JPM, the Applicant will have diluted the RCS 100 gallons (acceptable range 97 to 103 gallons).

S2 This is a MODIFIED JPM in a SHUTDOWN condition. The parent JPM (URO-NOP-06-C153J) has not been used on an NRC Exam administered at Callaway between 2004 and 2013. The last revision to this JPM was in 2005. The actions to perform this task are now covered by a different procedure. Additionally the method for lowering RCS pressure has been changed. The applicant will be assigned the task of depressurizing the RCS and blocking the SI signal, per OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block. Upon completion of this JPM, the applicant will have blocked both trains of Pressurizer Pressure and Steam Line Pressure Safety Injection without initiating a Safety Injection.

S3 This BANK JPM was used on the 2013 ILT NRC Exam. It was randomly selected using the method described above. The applicant will be assigned the task of performing the Stroke Time Test for BBHV8000A, RCS PZR OUT PWR OPER RLF HV, per OSP-BB-V0001, RCS Valve Inservice Test, Section 6.1. Upon completion of this JPM, the applicant will have completed the Stroke Time Test for BBHV8000A per OSP-BB-V0001 and reported to the CRS that the Acceptance Criteria was not satisfied.

S4 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO-AEO C052J) has not been used on an NRC Exam administered at Callaway between 2004 and 2013.The parent JPM was not alternate path and the applicant was successful in starting the D RCP. The applicant will be assigned the task of starting D Reactor Coolant Pump in accordance with EOP Addendum 3, Starting An RCP. The D RCP will not start and the applicant will then start the A (or B) RCP. Upon completion of this JPM, the operator will have started RCP A (or B) and secured the respective RCP Oil Lift pump.

S5 This is an ALTERNATE PATH, BANK JPM. The applicant will be assigned the task of completing the actions of ES-1.3, Transfer to Cold Leg Recirculation, Step

6. Upon completion of this JPM, the applicant will have aligned the train B Containment Spray Pump to a recirculating lineup and secured the train A Containment Spray Pump.

Page 2 of 3

ES-301 Control Room/In-Plant Systems Outline (Rev 2) Form ES-301-2 S6 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO-AEO C174J(A)) was used on the 2011 NRC Exam administered at Callaway. The parent JPM had both EDGs start and the B ESW pump start. In the modified JPM the B ESW pump does not start and the NE02 (B EDG) must be secured.

The applicant will be assigned the task of completing the actions of Step 5 of ECA-0.0, Loss of All AC Power. Upon completion of this JPM, the applicant will have manually started NE01 and manually started A ESW Pump prior to A DG auto trip.

S8 This is an ALTERNATE PATH, TIME CRITICAL, BANK JPM. The operator will be assigned the task of performing Attachment C of OTO-BB-00002, RCP Off-Normal to address a loss of CCW to the RCPs. Upon completion of this JPM, the operator will have restored CCW to Containment (within 10 minutes) and the RCPs.

P1 This is a MODIFIED JPM. The parent JPM (URO-AEO-02-P015J) was last used on the 2007 NRC Exam administered at Callaway. The JPM was used on the 2013 ILT NRC Exam. The parent JPM had the operator taking action to control SG water level, the modified JPM has the operator taking action to control PZR pressure. The operator will be assigned the task of performing OTO-ZZ-00001, Control Room Inaccessibility Attachment G, Control Room Supervisor (CRS)

Actions Without A Fire. Upon completion of this JPM the Operator will have demonstrated the ability to control RCS temperature and PZR pressure from the Aux Shutdown Panel.

P2 This is an ALTERNATE PATH, BANK JPM. The operator will be assigned the task of locally isolating RCP Seals using EOP Addendum 22, Local RCP Seal Isolation. Upon completion of this JPM, the operator will have successfully isolate RCP seals.

P3 This is a MODIFIED JPM. The operator will be assigned the task of performing OTO-ZZ-00001, Control Room Inaccessibility Attachment A, Safe Shutdown Operator Actions with Fire. Upon completion of this JPM the operator will have isolated loads on MCC NG04C, placed class 1E electrical equipment A/C unit in ISO/RUN, aligned CCW and locally tripped both reactor trip breakers and bypass breakers.

Page 3 of 3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P1 JPM No: URO-AEO-02-P015J - Modified KSA No: 068AA1.07 Revision Date: 11/19/2014 KSA Rating: 4.1/4.2 Job Title: URO Duty: Emergency operations Task Title: Operate the PZR Heaters at the Aux Shutdown Panel Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTO-ZZ-00001, Control room inaccessibility, Attachment G, Rev 39 Tools / Equipment: PPE Page 1 of 7 JPM P1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A reactor startup was in progress when a bomb was found in the control room.

The SM has directed a control room evacuation per OTO-ZZ-00001, Control room inaccessibility.

The reactor has been tripped and all rods have been verified fully inserted.

Initiating Cues: You are the BOP and have been directed to perform OTO-ZZ-00001, Control room inaccessibility, Att G with the CRS The SM has given you 2 sets of keys from the emergency break class case, two portable radios, an Emergency ED attached to the CRS Emergency Equipment Bag, a copy of OTO-ZZ-00001, Control Room Inaccessibility Att G, Control Room Supervisor (CRS) Actions Without A Fire, the Hard Hat with Mounted Illumination, and the "CRS" Sling Bag from the CRS equipment bag You exited the Control Room through SAS and are on your way to the next location listed in the procedure.

Notify the SM when you are maintaining the plant in stable Hot Standby conditions Note: Start this JPM in the RCA Task Standard: Upon completion of this JPM the Operator will have demonstrated the ability to control RCS temperature and PZR pressure from the Aux Shutdown Panel.

Start Time:

Stop Time:

Page 2 of 7 JPM P1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a copy of OTO- Operator obtained a S U ZZ-00001, Control room procedure copy inaccessibility Comments:

2. Obtain the following: Given in the initiating cue Operator reads cue sheet S U and knows he has the Two sets of keys in the items listed emergency break glass Comments:

cases, two portable radios, and the SM equipment bag Step G1

3. Exit control room with You have exited the Operator went to ASP S U BOP through SAS Control Room through SAS. Head to the next Step G2 location Comments:

4. Note: radio Operator read note S U transmissions allowed in all areas to the plants during this event Comments:

5. Inform the Control room Control room Operator informed the S U ASP is manned acknowledges control room ASP is manned Step G3 Comments:

6. Check reactor tripped SE NI-61X and 61Y Operator checked SE NI- S U show low and slowly 61X and 61Y for lowering Check neutron flux lowering flux lowering SE NI-61X and Comments:

61Y Step G4 Page 3 of 7 JPM P1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 7 Place the following SG All switches indicate Operator placed S U Aux Fw Xfr Ctrl Vlv remote AL HS-9 switches in local After demonstrating how AL HS-6 Comments:

AL HS-9 to place switches in local:

AL HS-8 AL HS-6 AL HS-9 AL HS-11 AL HS-8 AL HS-6 in local AL HS-11 AL HS-8 Step G5 AL HS-11 switches are in the local position

• 8. Place the following All switches indicate Operator placed S U switches in local remote FC HS-313 FC HS-313 After demonstrating how AL HS-12 Comments:

to place switches in local:

AL HS-12 AL HS-7 FC HS-313 AL HS-7 AL HS-5 AL HS-12 AL HS-5 AL HS-10 AL HS-7 AL HS-10 in local AL HS-5 Step G 6 AL HS-10 switches are in the local position

9. Check MD AFP running AL HIS-22B and 23B Operator verified both MD S U both have green lights AFP AL HIS-22B and 23B AL HIS-22B and 23B off and red lights on running Step G7 Comments:

Page 4 of 7 JPM P1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

10. Maintain SG WR level All SG levels at 63% Operator checked SG S U 59% to 69% using AFW WR and stable level.

Reg Vlv Ctrl Comments:

AL HK-5B AL HK-7B AL HK-9B AL HK-11B Step G8

11. Direct OT to check both OT reports Both main Operator directed OT to S U main feed pumps tripped feed pumps are check both main feed tripped pumps tripped Step G9 Comments:

12. Direct OT to check OT reports 'A' Operator checked only S U condensate pumps only condensate pump is one condensate pump one running the only pump running running Comments:

Step G10

• 13. Maintain RCS cold leg All switches indicate Operator placed all SG S U temperature at 557F remote steam dump ctrl switches in local Place SG steam dump After demonstrating how Comments:

Ctrl Xfr switches in local to place switches in local:

AB HS-1 AB HS-1 AB HS-3 AB HS-3 AB HS-2 AB HS-2 AB HS-4 AB HS-4 Step G 11.a switches are in the local position Page 5 of 7 JPM P1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

14. Maintain RCS cold leg RCS temperature Operator maintained RCS S U temperature at 557 F indicates 557 °F temperature at 557 F using the steam dumps Operator checked Comments:

AB PIC-1B

• BBTI-413X AB PIC-2B

• BBTI-423X AB PIC-3B

• BBTI-433X

• BBTI-443X AB PIC-4B Step G11.b

15. Maintain PZR level 25 to PZR level is 25% Operator maintained PZR S U 30% level at 25%

Step G12 Operator checked Comments:

• BBLI 459B

• BBLI 460B

• 16. Check PZR pressure PZR pressure is 2180 Operator manually S U 2225 to 2250 psig psig restored PZR with in band by cycling either:

Step G 13 After demonstrating how Comments:

to cycle any of the

• Pzr Htr B/U Group B following:

And/or

• CYCLE Pzr Htr B/U Group B

• Pzr Htr B/U Group A o BB HIS52B (RP 118B)

Operator checked BBPI

• CYCLE Pzr Htr B/U 455B Group A o BB HIS51B (RP 118A)

PZR pressure is 2240 psig and stable

17. Maintain plant is stable JPM is complete Operator maintained S U hot standby condition stable conditions Step G 14 Comments:

Page 6 of 7 JPM P1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A reactor startup was in progress when a bomb was found in the control room.

The SM has directed a control room evacuation per OTO-ZZ-00001, Control room inaccessibility.

The reactor has been tripped and all rods have been verified fully inserted.

Initiating Cues: You are the BOP and have been directed to perform OTO-ZZ-00001, Control room inaccessibility, Att G with the CRS The SM has given you 2 sets of keys from the emergency break class case, two portable radios, an Emergency ED attached to the CRS Emergency Equipment Bag, a copy of OTO-ZZ-00001, Control Room Inaccessibility Att G, Control Room Supervisor (CRS) Actions Without A Fire, the Hard Hat with Mounted Illumination, and the "CRS" Sling Bag from the CRS equipment bag You exited the Control Room through SAS and are on your way to the next location listed in the procedure.

Notify the SM when you are maintaining the plant in stable Hot Standby conditions JPM P1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P2 JPM No: EOS-AEO-05-P061J(A) KSA No: 017 AA1.07 Revision Date: 11/19/2014 KSA Rating: 3.5/3.4 Job Title: OT/URO/SRO Duty: Emergency Operations / Loss of All AC Power (ECA 0.0)

Task Title: Local RCP Seal Isolation Completion Time: 30 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

EOP Addendum 22, Local RCP Isolation, Rev. 002 Tools / Equipment: PPE, Dosimetry, and RWP Page 1 of 6 JPM P2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant has experienced a loss of all onsite and offsite power.

Operators are performing ECA 0.0, Loss of All AC Power, to restore power and stabilize plant conditions.

The Control Room Supervisor is at Step 8 of ECA-0.0.

Initiating Cues: CRS directs you to locally isolate RCP Seals using EOP Addendum 22, Local RCP Seal Isolation, inform the CRS when you are complete Task Standard: The operator will successfully isolate RCP seals.

Start Time:

Stop Time:

Page 2 of 6 JPM P2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Provide operator with Operator obtained S U copy of EOP Addendum procedure copy procedure copy 22, RCP SEAL ISOLATION Comments:

2. OPEN the following All handles pointing to Operator manually opened S U breakers on NG02B ON breakers:

(2026 AB South elect pen After operator NG02BCR1 room) demonstrates how to Comments:

NG02BHF1 NG02BCR1 (BGHV8100) open breakers NG02BHF1 (EGHV0133) Handle is in the OFF position EOP Add 22 Step 1

3. OPEN the following Handle pointing to Operator manually opened S U breaker on NG03C (2047 ON breaker:

AB North control room After operator NG03CKF3 HVAC room) demonstrates how to Comments:

NG03CKF3 (EGHV0061) open breaker EOP Add 22 Step 2 Handle is in the OFF position

• 4. Close the following to BGV0102 stem is Operator closed: S U ISOLATE RCP Seal down and no threads BGV0102 Injection (2000 AB, Filter showing Row): BGV0106 - WILL NOT BGV0106 stem is up Comments:

CLOSE - goes to RNO BGV0102, CVCS Seal and threads showing Column Wtr Inj Fltr A Out Iso After operator (Room 1306B) (Start of Alternate Path) demonstrates how to BGV0106, CVCS Seal close valve Wtr Inj Fltr B Out Iso BGV0106 will not turn (Rm 1306A)

(stuck)

EOP Add 22 Step 3 Page 3 of 6 JPM P2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

5. PERFORM the following: CUE OPERATOR: Operator started heading S U for the 2047 level of the OPEN the following Another Operator has Aux building to OPEN the Breakers on NG04C already opened the listed breakers (2047 AB South Control listed breakers Comments:

Room HVAC Room)

NG04CDF5 (BBHV8351A)

NG04CEF4 (BBHV8351B)

NG04CEF5 (BBHV8351C)

NG04CFF3 (BBHV8351D)

EOP Add 22 Step 3, RNO - a

• 6. CLOSE the following NOTE: DO NOT ALLOW Operator closed the S U valves (2000 AB South OPERATOR TO CROSS following valves by moving piping penetration room): CONTAMINATION the handwheel in the BOUNDARY clockwise direction:

BBHV8351A, RCP A Comments:

Seal Wtr Sply (Pen 41) NOTE: If operator states BBHV8351A he will go dress out to BBHV8351B, RCP B BBHV8351B close valves say Seal Wtr Sply (Pen 22)

BBHV8351C You are dressed out BBHV8351C, RCP C BBHV8351D Seal Wtr Sply (Pen 39) All valves position indicators are up BBHV8351D, RCP D Seal Wtr Sply (Pen 40) After operator demonstrates how to EOP Add 22 Step 3, close valves RNO - b Declutch levers have been depressed, the handwheels rotated clockwise until it stopped, and the indicators are down Page 4 of 6 JPM P2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 7. CLOSE the following BGHV8100 threads Operator closed S U valve: (2000 AB South indicator is up BGHV8100 piping penetration room):

After operator BGHV8100, Seal Water demonstrates how to Comments:

Return Containment close valve Isolation (Pen 24)

BGHV8100 declutch EOP Add 22 Step 4 lever has been depressed, the handwheel rotated clockwise until it stopped, and the indicator is down

• 8. CLOSE the following EGHV0061 and Operator closed the S U valves (2000 AB North EGHV0133 indicators following valves:

piping penetration room): are up EGHV0061 EGHV0061, RCP Thrm After operator Comments:

EGHV0133 Bar Outer CTMT Iso (Pen demonstrates how to

76) close valve EGHV0133, RCP Thrm EGHV0061 and Bar EGHV0061 Byp Iso EGHV0133 declutch (Pen 76) levers have been depressed, the EOP Add 22 Step 5 handwheels rotated clockwise until it stopped, and the indicators are down

9. Inform the CRS when The JPM is Complete Informed the CRS task is S U complete complete

________________

Comments:

Record Stop Time on Page 2 Page 5 of 6 JPM P2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant has experienced a loss of all onsite and offsite power.

Operators are performing ECA 0.0, Loss of All AC Power, to restore power and stabilize plant conditions.

The Control Room Supervisor is at Step 8 of ECA-0.0.

Initiating Cues: CRS directs you to locally isolate RCP Seals using EOP Addendum 22, Local RCP Seal Isolation, inform the CRS when you are complete JPM P2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P3 JPM Bank No: MODIFIED KSA No: 068AA1.14 URO-AEO-15-P028J Revision Date: 11/19/2014 KSA Rating: 4.2 / 4.4 Job Title: URO/SRO Duty: Control Room Inaccessibility Task Title: Locally Trip Reactor Trip and Bypass Breakers Completion Time: 20 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTO-ZZ-00001, Control Room Inaccessibility, Att A, Rev 40 Tools / Equipment: PPE Page 1 of 7 JPM P3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Control Room is being evacuated due to a fire Initiating Cues: The SM has directed you to perform OTO-ZZ-00001, Control Room Inaccessibility Att A Safe Shutdown Operator Actions with Fire up to and including step A15. Inform the SM when you have completed step A15.

The SM has given you the SSO keys from the emergency break class case, a portable radio, an Emergency ED attached to the SSO Emergency Equipment Bag, a copy of OTO-ZZ-00001, Control Room Inaccessibility Att A Safe Shutdown Operator Actions with Fire the Hard Hat with Mounted Illumination, and the "SSO" Sling Bag from the SSO equipment bag You exited the Control Room trough SAS and are on your way to the next location listed in the procedure.

Task Standard: Upon completion of this JPM the operator will have isolated loads on MCC NG04C, placed class 1E electrical equipment A/C unit in ISO/RUN, aligned CCW and locally tripped both reactor trip breakers and bypass breakers.

Start Time:

Stop Time:

Page 2 of 7 JPM P3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Note: To aid operators in Radio transmissions will Candidate read note S U identifying equipment be simulated during the covered by this performance of this JPM procedure, components have been marked by Comments:

placing yellow and black checkerboard tape on the components.

Radio transmissions is allowed in all plant areas during this event Att I contains a list of phone numbers

2. Obtain the following: Given in the initiating cue Candidate read cue sheet S U and knows they have the

• The "SSO" key ring items listed in the emergency break glass case Comments:

outside the Shift Manager's office.

• An Emergency ED attached to the SSO Emergency Equipment Bag.

• From The "SSO" Emergency Equipment Bag the Hard Hat with Mounted Illumination and the "SSO" Sling Bag.

Step A1

3. Exit control room through Given in the initiating cue Candidate read cue sheet S U SAS and knows they have exited control room Step A2 through SAS Comments:

Candidate went to The North HVAC Room Page 3 of 7 JPM P3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 4. OPEN The Following Breaker initially Candidate opened S U Breaker On NG03C: indicates ON NG03CEF4, Fdr Bkr To ALHV0036 CST To

• NG03CEF4, Fdr Bkr After demonstrating TDAFW Pmp Iso To ALHV0036 CST ability to open a breaker, Comments:

To TDAFW Pmp Iso The breaker indicates Step A3 OFF

5. Proceed to the South Candidate proceeded to S U HVAC Room (AB 2047 the South HVAC room Rm 1501)

Step A4 Comments:

• 6. OPEN The Following Breaker initially Candidates opened the S U Breakers On NG04C by indicates ON Following Breakers On using the handswitch on NG04C by using the After demonstrating the cubicle door: handswitch on the cubicle ability to open and locate door: Comments:

• NG04CNF3, Fdr Bkr the breaker by using the To EFHV0052 ESW handswitch on the

• NG04CNF3, Fdr Bkr To B CCW Hx Iso cubicle door: To EFHV0052 ESW

• NG04CKF1, Fdr Bkr To B CCW Hx Iso The breaker indicates To EGHV0054 CCW OFF

• NG04CKF1, Fdr Bkr Trn B Sply/Rtn Iso To EGHV0054 CCW

• NG04CKF2, Fdr Bkr Repeat for each breaker Trn B Sply/Rtn Iso To EMHV8803B

• NG04CKF2, Fdr Bkr Boron Inj Header To EMHV8803B Inlet Iso Vlv Boron Inj Header Inlet

• NG04CKF3, Fdr Bkr Iso Vlv To EMHV8801B

• NG04CKF3, Fdr Bkr Boron Inj Header To EMHV8801B Discharge Iso Valve Boron Inj Header

• NG04CJF3, Fdr Bkr Discharge Iso Valve To EGHV0016 CCW

• NG04CJF3, Fdr Bkr Trn B Sply/Rtn Iso To EGHV0016 CCW

• NG04CFF1, Fdr Bkr Trn B Sply/Rtn Iso To BGHV8105 Chg

• NG04CFF1, Fdr Bkr Hdr To Regen Hx To BGHV8105 Chg Outer Ctmt Iso Hdr To Regen Hx Outer Ctmt Iso Step A5 Page 4 of 7 JPM P3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 7. Place Class 1E electrical Local hand switch is Candidate placed local S U equipment A/C Unit B in ISO/RUN hand switch in ISO/RUN local hand switch in ISO/RUN (on EAST wall):

Comments:

• GKHS0103 Step A6

8. PROCEED To CCW Candidate PROCEEDED S U Pump A And CCW Train To CCW Pump A And A Heat Exchanger Room CCW Train A Heat (AB 2026 Rm 1406) Exchanger Room (AB 2026 Rm 1406) Comments:

Step A7

• 9. CLOSE ESW To CCW EGV0182 stem Candidate closed S U Trn A Iso: (Near the wall, indicates down EGV0182, ESW To CCW WEST of 'A' CCW Pump) Trn A Iso

• EGV0182 Comments:

Step A8

10. PROCEED To CCW Candidate proceeded To S U Pump B And CCW Train CCW Pump B And CCW B Heat Exchanger area Train B Heat Exchanger (AB 2026 Rm 1401) area (AB 2026 Rm 1401)

Comments:

Step A9

• 11. CLOSE ESW To CCW EGV0185 handwheel Candidate closed S U Trn B Iso: (SE Corner of stops turning and the EGV0185, ESW To CCW Room Behind HVAC) stem is down Trn B Iso

• EGV0185 Comments:

Step A10

• 12. In the CCW Pump B And EFHV0052 declutch Candidate opened S U CCW Train B Heat lever depressed, EFHV0052, ESW Trn B To Exchanger Room handwheel turned CCW Hx B Hv POSITION The Following counterclockwise until Valve: (South Wall it stopped, and the Comments:

Center) indicator shows open

• EFHV0052, ESW Trn B To CCW Hx B Hv -

OPEN Step A11 Page 5 of 7 JPM P3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 13. On The Plant West Wall, EGHV0054 declutch Candidate opened S U Manually OPEN lever depressed, EGHV0054, CCW TRN B EGHV0054, CCW TRN B handwheel turned SPLY ISO HV SPLY ISO HV (North of counterclockwise until

'B' CCW HX) it stopped, and the Comments:

indicator shows open Step A12

• 14. In The EAST/WEST EGHV0016 declutch Candidate opened S U Corridor Leading To The lever depressed, EGHV0016, CCW TRN B Rod Drive MG Set Room, handwheel turned RTN ISO Manually OPEN counterclockwise until EGHV0016, CCW TRN B it stopped, and the Comments:

RTN ISO indicator shows open Step A13

15. PROCEED To Rod Drive Candidate proceeded to S U MG Set Room (AB 2026 Rod Drive MG Set Room Rm 1403) (AB 2026 Rm 1403)

Step A14 Comments:

• 19. Perform the following: After pressing the TRIP Candidate opened both Rx S U button: trip and bypass breakers Locally trip both Rx trip breakers Open Both Rx trip breakers Locally trip both Rx trip are open Comments:

bypass breakers Open Both Rx trip bypass breakers are open Step A15

20. Inform the SM Att A SM acknowledges Candidate informs the SM S U through step A15 is he has completed step complete A15 JPM is complete Comments:

Page 6 of 7 JPM P3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Control Room is being evacuated due to a fire Initiating Cues: The SM has directed you to perform OTO-ZZ-00001, Control Room Inaccessibility Att A Safe Shutdown Operator Actions with Fire up to and including step A15. Inform the SM when you have completed step A15.

The SM has given you the SSO keys from the emergency break class case, a portable radio, an Emergency ED attached to the SSO Emergency Equipment Bag, a copy of OTO-ZZ-00001, Control Room Inaccessibility Att A Safe Shutdown Operator Actions with Fire the Hard Hat with Mounted Illumination, and the "SSO" Sling Bag from the SSO equipment bag You exited the Control Room trough SAS and are on your way to the next location listed in the procedure.

JPM P3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S1 JPM Bank No: New KSA No: 004A4.07 Revision Date: 11/19/2014 KSA Rating: 3.9 / 3.7 Job Title: URO/SRO Duty: CVCS Task Title: Perform a Dilution Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTN-BG-00002, REACTOR MAKEUP CONTROL AND BORON THERMAL REGENERATION SYSTEM, REV 45 Tools / Equipment: none Page 1 of 5 JPM S1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1 Initiating Cues: The Control Room Supervisor (CRS) directs you to dilute the RCS 100 gallons by performing a dilution per Attachment 6 of OTN-BG-00002, Reactor Makeup Control and Boron Thermal Regeneration System.

Note: Use IC 161 Task Standard: Upon completion of this JPM, the Applicant will have diluted the RCS 100 gallons (acceptable range 97 to 103 gallons)

Start Time:

Stop Time:

Page 2 of 5 JPM S1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Provide operator with Operator obtained S U copy of Attachment 6 of procedure copy procedure copy OTN-BG-00002 Comments:

2. Attachment 6 Dilute Operator read note S U Mode of RMCS NOTE: This attachment Comments:

provides direction for frequently performed, nominal 120 gpm dilutions

3. PLACE BG HS-26, RCS Operator PLACED BG HS- S U M/U CTRL, in STOP 26 in STOP Attachment 6 Step 1 BG HS-26 is in STOP Comments:

• 4. PLACE BG HS-25, RCS Operator PLACED BG HS- S U M/U CTRL SEL, in DIL 25 in DIL Attachment 6 Step 2 BG HS-25 is in DIL Comments:

5. RESET BG FY-111B, Operator RESET BG FY- S U COMBINED M/U & BA 111B, COMBINED M/U &

FLOW TOTALIZER, to BA FLOW TOTALIZER, to 000. 000. Comments:

Attachment 6 Step 3 BG FY-111B, COMBINED M/U & BA FLOW TOTALIZER, is set to 000.

Page 3 of 5 JPM S1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

6. NOTE: When setting BG Operator read note S U FY-111B, allowance should be made in the setpoint to compensate Comments:

for instrument inaccuracies and isolation valve closure times on total flow delivered. (Step 3.1.9 contains more information if required.)

• 7. ENSURE BG FY-111B is Operator SET S U set to deliver the desired BG FK-111B to deliver 100 amount of makeup water. gallons Comments:

Attachment 6 Step 4 BG FK-111B is set to 100 gallons (acceptable range 97 to 103 gallons)

• 8. PLACE BG HS-26, RCS Operator PLACED BG HS- S U M/U CTRL, in RUN 26 in RUN Attachment 6 Step 5 BG HS-26 is in RUN Comments:

9. WHEN the desired Operator PLACED BG HS- S U amount of water has 26, RCS M/U CTRL, in been added, PLACE BG STOP.

HS-26, RCS M/U CTRL, Comments:

BG HS-26 is in STOP in STOP.

Attachment 6 Step 6

10. IF required, PERFORM Operator PLACED BG HS- S U the following: 25, RCS M/U CTRL SEL, in AUTO and BG HS-26, PLACE BG HS-25, RCS RCS M/U CTRL, in RUN. Comments:

M/U CTRL SEL, in AUTO BG HS-25, RCS M/U PLACE BG HS-26, RCS CTRL SEL, is in AUTO M/U CTRL, in RUN.

BG HS-26, RCS M/U Attachment 6 Step 7.a CTRL, is in Normal after and b.

RUN.

11. JPM IS COMPLETE RECORD STOP TIME S U ON PAGE 2.

Comments:

Page 4 of 5 JPM S1

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1 Initiating Cues: The Control Room Supervisor (CRS) directs you to dilute the RCS 100 gallons by performing a dilution per Attachment 6 of OTN-BG-00002, Reactor Makeup Control and Boron Thermal Regeneration System.

JPM S1

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S2 MODIFIED JPM Bank No: URO-NOP-06-C153J KSA No: 006A4.09 Revision Date: 11/19/2014 KSA Rating: 4.1 / 4.2 Job Title: URO/SRO Duty: NORMAL OPERATIONS Task Title: Initial RCS Depressurization and SI Block Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block, Rev 8 Tools / Equipment:

Page 1 of 9 JPM S2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: CALLAWAY PLANT is in Mode 3, with RCS TAVE at 557°F and RCS pressure at 2050 psig.

A and D RCPs are in operation Initiating Cues: The Control Room Supervisor (CRS) directs you to depressurize the RCS and block the SI signal, per OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block OTG-ZZ-00006, Plant Cooldown Hot Standby to Cold Shutdown is in use and directs this action to take place.

Boron concentration is greater than required concentration to block SI below P-11 All Prerequisites are satisfied.

The BOP Operator is monitoring cooldown rate and SG levels Note: IC 162 Ensure turn on code OOA, BBP1002 is NOT active, does not have

• next to point ID. Do this again prior to resetting to next JPM.

Task Standard: Upon completion of this JPM, the Applicant will have blocked both trains of Pressurizer Pressure and Steam Line Pressure Safety Injection without initiating a Safety Injection.

Start Time:

Stop Time:

Page 2 of 9 JPM S2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Review OTG-ZZ-00006 Provide Operator with Operator reviewed OTG- S U Addendum 04, Initial marked up copy of ZZ-00006 Addendum 04, RCS Depressurization OTG-ZZ-00006 Initial RCS Comments:

and SI Block Addendum 04, Initial Depressurization and SI RCS Depressurization Block and SI Block

2. Review Precautions and IF ASKED, provide Operator reviewed S U Limitations. operator with a copy of Precautions and OTG-ZZ-00006, Plant Limitations.

Step 3.1 and .2 Comments:

Cooldown Hot Standby to Cold Shutdown

3. Review General Notes. IF ASKED, provide Operator reviewed S U operator with a copy of General Notes.

Step 3.3 OTG-ZZ-00006, Plant Comments:

Cooldown Hot Standby to Cold Shutdown

4. Review Prerequisites Operator reviewed S U Prerequisites Step 4 All prerequisites have Comments:

been initialed or signed

5. Continuous Actions Operator reviewed S U continuous action step Prior to blocking SI, and initialed Inititated MAINTAIN narrow range Comments:

line pressure between 1900 psig and 2250 psig.

Step 5.1.1 6 Continuous Actions Operator reviewed S U continuous action step After blocking SI, and initialed Inititated MAINTAIN narrow range Comments:

line pressure between 1700 psig and 1900 psig.

Step 5.1.2 Page 3 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

7. LOWER RCS pressure Operator ensured all S U towards 1900 psig as Pressurizer Backup follows: Heaters are energized Comments:

Using the following, ENSURE all Pressurizer Backup Heaters are energized to maximize spray flow:

• BB HIS-51A, PZR HTR B/U GROUP A, in CLOSE

• BB HIS-52A, PZR HTR B/U GROUP B, in CLOSE STEP 5.2.1.a

8. MONITOR pressure Operator monitored S U using the lowest reading pressure using the lowest Pressurizer Pressure reading Pressurizer Comments:

indicator: Pressure indicator

• BB PI-455A, PRESSURIZER PRESSURE

• BB PI-456, PRESSURIZER PRESSURE

• BB PI-457, PRESSURIZER PRESSURE

• BB PI-458, PRESSURIZER PRESSURE Step 5.2.1.b The Operator must use any one of the next 3 steps of the JPM to lower pressure.

Only the step that the Operator used is a Critical Step.

• 9. INITIATE Operator lowered S U depressurization by pressure.

performing one of the Operator adjusted the Comments:

following:

potentiometer for BB PK-Using BB PK-455A, PZR 455A, PZR PRESS PRESS MASTER CTRL, MASTER CTRL, in AUTO, in AUTO, slowly adjust to lower pressure.

the potentiometer to lower pressure.

Step 5.2.1.c.1 Page 4 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 10. Using BB PK-455A, PZR Operator lowered S U PRESS MASTER CTRL, pressure.

in MANUAL, slowly Operator used BB PK- Comments:

lower pressure.

455A, PZR PRESS Step 5.2.1.c.2 MASTER CTRL, in MANUAL, to lower pressure.

• 11. Using the Spray Valve Operator lowered S U Controller for an pressure.

operating RCS loop, in Operator used the Spray Comments:

MANUAL, slowly OPEN Valve Controller for an the Spray Valve.

operating RCS loop, in

• BB PK-455B, PZR MANUAL, slowly SPRAY LOOP 1 OPENED the Spray CTRL Valve.

• BB PK-455C, PZR SPRAY LOOP 2 CTRL Step 5.2.1.c.3

12. WHEN Pressurizer Operator maintained S U Pressure approaches pressure between 1900 psig, MAINTAIN 1900psig and 1910 psig.

Comments:

pressure between 1900 psig and 1910 psig.

Step 5.2.2

13. IF desired, ADJUST BB Operator may have S U PK-455A, PZR PRESS adjusted BB PK-455A, MASTER CTRL to the PZR PRESS MASTER Comments:

new set point AND CTRL to the new set point PLACE in AUTOMATIC. AND may have PLACED in AUTOMATIC.

Step 5.2.3 Candidate may refer to OOA-RL-00004 to determine that 2.5 turns are needed.

14. WHEN RCS boron Operator verified RCS S U concentration is equal to boron concentration is or greater than the equal to or greater than Comments:

required to block SI the required to block SI below P-11 per OSP-SF- below P-11 per OSP-SF-00001, Shutdown Margin 00001, Shutdown Margin Calculations, THEN Calculations, CONTINUE to next step.

Given in Cue STEP 5.2.4 Page 5 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

15. PERFORM the following Operator verified RCS S U to block SI: boron concentration is equal to or greater than ENSURE required boron Comments:

the required to block SI concentration for below P-11 per OSP-SF-blocking SI below P-11 00001, Shutdown Margin is met.

Calculations, Step 5.2.5.a Given in Cue

16. On SB069, CHECK Operator verified S U Permissive P-11 status PERMISSIVE P-11 light ON. STATUS LIGHT IS LIT Comments:

ON SB069 Step 5.2.5.b PERMISSIVE P-11 STATUS LIGHT IS LIT ON SB069

17. SET Operator Alarm for Operator set Operator S U BBP1002, AUCT HI PZR Alarm for BBP1002, PRESS, HI ALM at 1960 AUCT HI PZR PRESS, HI Comments:

psig. ALM at 1960 psig.

Step 5.2.5.c

• 18. BLOCK Pressurizer Operator momentarily S U Pressure SI by depressed SB HS-7, PZR momentarily depressing: PRESS SI TRN B Comments:

BLOC/UNBLOCK SB HS-7, PZR PRESS SI TRN B BLOC/UNBLOCK Step 5.2.5.d.1

• 19. BLOCK Pressurizer Operator momentarily S U Pressure SI by depressed SB HS-8, PZR momentarily depressing: PRESS SI TRN A Comments:

BLOC/UNBLOCK SB HS-8, PZR PRESS SI TRN A BLOC/UNBLOCK Step 5.2.5.d.2 Page 6 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

20. On SB069, CHECK Operator checked S U Pressurizer Pressure Pressurizer Pressure Safety Injection signal Safety Injection signal Comments:

blocked status lights blocked status lights Train Train A and Train B are A and Train B are ON ON Step 5.2.5.e

• 21 BLOCK Steamline Operator momentarily S U Pressure SI by depressed SB HS-9, momentarily depressing: STMLINE PRESS SI TRN Comments:

A BLOC/UNBLOCK SB HS-9, STMLINE PRESS SI TRN A BLOC/UNBLOCK Step 5.2.5.f.1

• 22. BLOCK Steamline Operator momentarily S U Pressure SI by depressed SB HS-10, momentarily depressing: STMLINE PRESS SI TRN Comments:

B BLOC/UNBLOCK SB HS-10, STMLINE PRESS SI TRN B BLOC/UNBLOCK Step 5.2.5.f.2

23. On SB069, CHECK the Operator checked the S U Steamline Steamline Isolation/Safety Isolation/Safety Injection Injection signal blocked Comments:

signal blocked status status lights Train A and lights Train A and Train Train B are on B are on Step 5.2.5.g

24. NOTIFY CRS/SM that Respond as CRS/SM The Operator NOTIFIED S U the Steam Line Isolation when notified that the the CRS/SM that the on high negative rate Steam Line Isolation on Steam Line Isolation on Comments:

(100 psig in 50 seconds) high negative rate (100 high negative rate (100 of steam pressure is now psig in 50 seconds) of psig in 50 seconds) of enabled. steam pressure is now steam pressure is now enabled. enabled.

Step 5.2.5.h Page 7 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

25. MONITOR Plant The Operator S U Computer screen MONITORED Plant HEATU or MODE3. Computer screen HEATU Comments:

or MODE3.

Step 5.2.6

26. MAINTAIN Pressurizer Operator lowered S U pressure below 1900 pressure below 1900 psig psig and above 1700 and above 1700 psig.

Comments:

psig.

Step 5.2.7

27. NOTE any exceptions to S U the execution of this procedure.

Comments:

Step 5.2.8

28. OBTAIN procedure THE CONTROL ROOM Operator informed CRS S U completion signature SUPERVISOR procedure is complete and from SM/CRS: ACKNOWLEDGES THE obtained SM/CRS Comments:

TASK IS COMPLETE signature.

Step 5.2.9

29. THE JPM IS RECORD STOP TIME S U COMPLETE ON PAGE 2 Comments:

Page 8 of 9 JPM S2

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: CALLAWAY PLANT is in Mode 3, with RCS TAVE at 557°F and RCS pressure at 2050 psig.

A and D RCPs are in operation Initiating Cues: The Control Room Supervisor (CRS) directs you to depressurize the RCS and block the SI signal, per OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block OTG-ZZ-00006, Plant Cooldown Hot Standby to Cold Shutdown is in use and directs this action to take place.

Boron concentration is greater than required concentration to block SI below P-11 All Prerequisites are satisfied.

The BOP Operator is monitoring cooldown rate and SG levels JPM S2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S3 JPM Bank No: URO-SBB-05-C077J(A) KSA No: 010A4.03 Revision Date: 11/19/2014 KSA Rating: 4.0 / 3.8 Job Title: URO/SRO Duty: Reactor Coolant Task Title: Perform System Surveillance -

BBHV8000A Stroke Test Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OSP-BB-V0001, RCS Valve Inservice Test, Rev 24 Tools / Equipment: Calibrated Stop Watch Page 1 of 7 JPM S3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1 Initiating Cues: The Control Room Supervisor (CRS) directs you to perform the Stroke Time Test for BBHV8000A, RCS PZR OUT PWR OPER RLF HV, per OSP-BB-V0001, RCS Valve Inservice Test, Section 6.1.

All Prerequisites are satisfied.

Note: Use IC 161

1. Select Engineering Mode

2. ME Schematics/BB/m22bb02_a (Pressurizer)

3. Right click on motor for bbhv8000a (located on top of Pressurizer) a) Select RT04RC_HV8000A_MCTCLOSE - Insert Selected Value to 25 AND b) Select RT04RC_HV8000A_MCTOPEN - Insert Selected Value to 25 Task Standard: Upon completion of this JPM, the Operator will have completed the Stroke Time Test for BBHV8000A per OSP-BB-V0001 and reported to the CRS that the Acceptance Criteria was not satisfied.

Start Time:

Stop Time:

Page 2 of 7 JPM S3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Provide Operator with Operator obtained working S U copy of OSP-BB-V0001 procedure copy copy of OSP-BB-V0001 Comments:

2. Review Acceptance Operator reviewed S U Criteria Acceptance Criteria per Attachment 1 Section 3.1 Comments:

3. Review Precautions and Operator reviewed S U Limitations Precautions and Limitations Section 4.0 Comments

4. Review Prerequisites Operator reviewed S U Prerequisites Section 5.0 Comments

5. NOTE: The local position Examiner Note: Operator read note S U indication is performed Given in initial cue that Given in initial cue that every refuel prior to Mode local position indication is local position indication is 4 startup. These steps Comments not required for this test. not required for this test.

may be omitted when performing this procedure in Mode 1, 2, or 3 on BBHV8000A.

Prior to 6.1

6. NOTE: If BBHV8000A, Operator read note S U RCS PZR Out Pwr Oper Rlf HV, is on its backseat for normal operations, the Comments stroke close time will be from the backseat position and not from the OPEN (limit switch) position.

Prior to 6.1.1 Page 3 of 7 JPM S3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

7. Using BB HIS-455A, PZR Operator ensured S U PORV, ensure BBPCV0455A was closed BBPCV0455A is closed BB HIS-455A green light is Comments Step 6.1.1 lit and the red light is not lit

8. Ensure BB HS-8000A, Operator ensured BB HS- S U TRN A Cold O/P 8000A BLOCK PB was Bloc/Arm, is in the depressed BLOCK position Comments Step 6.1.2

9. Record Initial Remote Operator recorded Initial S U Position of BB HIS- Remote Position of BB 8000A, PZR PORV Block HIS-8000A on Attachment Vlv, on Attachment 1 1 Comments Step 6.1.3 (OPEN is the initial position)

10. If Position Indication Operator N/Ad step and S U Testing is scheduled, proceeded to Step 6.1.5 perform the following:

Given in Initiating Cue that Comments Step 6.1.4 Position Indication Testing is not scheduled

• 11. Using BB HIS-8000A, Operator closed S U PZR PORV Block Vlv, BBHV8000A and close BBHV8000A and measured the elapsed measure the elapsed time between pushing the Comments time between pushing the close pushbutton and close pushbutton and when the open light went when the open light goes out out Measured stroke time was Step 6.1.5 ~25 seconds

12. Record Observed Stroke If Operator recognizes Operator recorded S U Time Closed for that the stroke time does Observed Stroke Time BBHV8000A, RCS PZR NOT meet acceptance Closed for BBHV8000A on Out Pwr Oper Rlf HV, on and indicates they would Attachment 1 Comments Attachment 1 stop the test, direct them (Observed stroke time to complete the test.

Step 6.1.6 should be ~25 sec)

Page 4 of 7 JPM S3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

13. RECORD Full Stroke Operator recorded Full S U Remote Position of BB Stroke Remote Position of HIS-8000A, PZR PORV Closed for BB HIS-8000A Block Vlv, on Attachment on Attachment 1 Comments 1

Step 6.1.7

14. If Position Indication Operator N/Ad step and S U Testing is scheduled, proceeded to Step 6.1.9 record the Full Stroke Given in Initiating Cue that Local Position of Comments Position Indication Testing BBHV8000A, RCS PZR is not scheduled Out Pwr Oper Rlf HV, on Attachment 1 Step 6.1.8

• 15. Using BB HIS-8000A, Operator opened S U PZR PORV Block Vlv, BBHV8000A and open BBHV8000A and measured the elapsed measure the elapsed time between pushing the Comments time between pushing the open pushbutton and open pushbutton and when the closed light went when the closed light out goes out BB HIS-8000A red light is Step 6.1.9 lit and the green light is not lit Measured stroke time was

~25 seconds

16. Record Observed Stroke Operator recorded S U Time open for Observed Stroke Time BBHV8000A, RCS PZR open for BBHV8000A on Out Pwr Oper Rlf HV, on Attachment 1 Comments Attachment 1 (Observed stroke time Step 6.1.10 should be ~25 sec)

Page 5 of 7 JPM S3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 17. Perform the following: If asked, Retest will Operator evaluated S U NOT be performed at Observed Stroke Time for

a. Evaluate Observed this time. BBHV8000A as exceeding Stroke Time against the maximum allowable Comments the Normal Stroke stroke time and NOT Time Range and the meeting acceptance Maximum Allowable criteria Stroke Time and determine if valve Operator notified SM/CRS retest is required for that valve stroke time did BBHV8000A NOT meet acceptance criteria

b. If Observed Stroke Time for BBHV8000A does NOT meet acceptance criteria, notify SM/CRS

c. If retest is required, perform the retest per CA2716, Valve Retest Instructions Step 6.1.11 Maximum Allowable Stoke Time = 20 sec

18. JPM IS COMPLETE RECORD STOP TIME S U ON PAGE 2.

Comments Page 6 of 7 JPM S3

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 3 Initiating Cues: The Control Room Supervisor (CRS) directs you to perform the Stroke Time Test for BBHV8000A, RCS PZR OUT PWR OPER RLF HV, per OSP-BB-V0001, RCS Valve Inservice Test, Section 6.1.

The local position indication is NOT required for this test.

BBHV8000A, RCS PZR OUT PWR OPER RLF HV, is NOT on its backseat.

All Prerequisites are satisfied.

JPM S3

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S4 JPM Bank No: URO-AEO-01-C052J KSA No: E09EA1.1 Revision Date: 11/19/2014 KSA Rating: 3.5 / 3.5 Job Title: URO/SRO Duty: Abnormal / Emergency Operations Task Title: Start Reactor Coolant Pump during RCS Natural Circulation Cooldown Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

EOP Addendum 3, Starting an RCP, R002 Tools / Equipment: None Page 1 of 11 JPM S4

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Callaway Plant experienced a Reactor Trip from full power.

A Switchyard fault resulted in the loss of the Startup Transformer.

The operating crew is performing the actions of ES-0.2, Natural Circulation Cooldown.

The PA Busses have been re-energized and the crew has returned to Step 1.

Initiating Cues: The Control Room Supervisor directs you to start Reactor Coolant Pump D in accordance with EOP Addendum 3, Starting An RCP.

Note:

Use IC-163 Trip the Reactor and All RCPs Insert Override Switch (BB) X21I118S, Value = 1 Task Standard: Upon completion of this JPM, the operator will have started RCP A (or B) and secured the respective RCP Oil Lift pump.

Start Time:

Stop Time:

Page 2 of 11 JPM S4

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a verified working Provide operator with Operator obtained S U copy of procedure copy procedure copy EOP Addendum 3, Starting An RCP Comments:

2. CAUTIONS: If RCP seal If asked - RCP seal Operator read caution S U cooling had previously cooling has NOT been been lost, the affected lost RCPs should NOT be Comments:

started prior to a status evaluation

3. NOTES: RCPs should be Operator read note S U run in order of priority to provide normal PZR spray: RCP D, RCP A or Comments:

RCP B, RCP C.

4. ESTABLISH conditions Operator ensured S U for starting an RCP in 13.8 KV Buses PA01 and order of priority: PA02 energized Comments:

13.8 KV Buses - 13.8 KV Buses PA01 and ENERGIZED PA02 are energized

• PA01

• PA02 Step 1.a

5. RCS pressure - Operator ensured RCS S U GREATER THAN 325 pressure is greater than PSIG 325 psig Comments:

Step 1.b RCS pressure is greater than 325 psig Page 3 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

6. Number 1 seal differential Operator ensured RCP D S U pressure - GREATER Number 1 seal differential THAN 200 PSID pressure is greater than 200 psid Comments:

• BB PI-150A BB PI-150A Step 1.c RCP D Number 1 seal differential pressure is greater than 200 psid

7. VCT pressure - Operator ensured VCT S U GREATER THAN 15 pressure is greater than 15 PSIG psig Comments:

Step 1.d VCT pressure is greater than 15 psig

8. RCP seal injection flow - Operator ensured RCP S U BETWEEN 6 GPM AND seal injection flow is 13 GPM PER RCP between 6 gpm and 13 gpm per RCP Comments:

• BG FR-157

• BG FR-156

• BG FR-157

• BG FR-155

• BG FR-156

• BG FR-154

• BG FR-155

• BG FR-154 Step 1.e RCP seal injection flow is between 6 gpm and 13 gpm per RCP

9. Number 1 seal leakoff Operator ensured Number S U flow - GREATER THAN 1 seal leakoff flow is OR EQUAL TO 0.2 GPM greater than or equal to 0.2 gpm Comments:

• BG FR-157

• BG FR-156

• BG FR-157

• BG FR-155

• BG FR-156

• BG FR-154

• BG FR-155

• BG FR-154 Step 1.f Number 1 seal leakoff flow is greater than or equal to 0.2 gpm Page 4 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

10. CCW To RCS Flow - Operator ensured CCW To S U INDICATED RCS Flow is indicated

• EG FI-128

• EG FI-128 Comments:

• EG FI-129

• EG FI-129 Step 1.g CCW To RCS Flow is indicated

11. RCP CCW system Operator ensured RCP S U annunciators - CLEAR CCW system annunciators are clear

• 52A, CCW Lo Comments:

• 70C, RCP A Th Bar

• 52A, CCW Lo

• 71C, RCP B Th Bar

• 70C, RCP A Th Bar

• 72C, RCP C Th Bar

• 71C, RCP B Th Bar

• 73C, RCP D Th Bar

• 72C, RCP C Th Bar

• 74C, RCP TB CCW

• 73C, RCP D Th Bar

• 74C, RCP TB CCW Step 1.h RCP CCW system annunciators are clear

12. START Oil Lift Pump for Operator started Lift Pump S U RCP to be started: for RCP D

• BB HIS-44

• BB HIS-44 Comments:

Step 1.i Lift Pump for RCP D has been started

13. Oil Lift Pump oil pressure Operator ensured RCP D S U interlock WHITE light - Oil Lift Pump oil pressure LIT interlock white light is lit Comments:

Step 1.j RCP D Oil Lift Pump oil pressure interlock white light is lit

14. NOTE: SI must be reset Operator read note S U prior to starting RCP C or RCP D to prevent potential shutdown Comments:

sequencer actuation on undervoltage of XNB02 Page 5 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

15. RESET SI If Necessary: Operator ensured SI is S U reset

• SB HS-42A

• SB HS-43A SI is reset Comments:

Step 2

16. START Desired RCP As The Lift Oil pump has Operator ensured RCP D S U Follows: been running for 2 oil lift pump has been minutes running greater than 2 CHECK associated oil lift minutes Comments:

pump - RUNNING GREATER THAN 2 MINUTES Step 3.a

17. START desired RCP: Operator started RCP D S U using BB HIS-40 BB HIS-40 (RCP D)

RCP D is NOT running Step 3.b Comments:

Alternate Path starts here

18. IF desired RCP can NOT If asked Implement Operator determined that S U be started, THEN procedure as written D RCP did not start and PERFORM the following: informed CRS and returned to Step 1 of the Comments:

TRY to establish procedure.

conditions and start another RCP in order of priority.

Return To Step 1.

Step 3.b.1) and 2) RNO

19. CAUTIONS: If RCP seal If asked - RCP seal Operator read caution S U cooling had previously cooling has NOT been been lost, the affected lost RCPs should NOT be Comments:

started prior to a status evaluation Page 6 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

20. NOTES: RCPs should be Operator read note and S U run in order of priority to determined the next RCP provide normal PZR to start is A RCP.

spray: RCP D, RCP A or Comments:

RCP B, RCP C.

21. ESTABLISH conditions Operator ensured S U for starting an RCP in 13.8 KV Buses PA01 and order of priority: PA02 energized Comments:

13.8 KV Buses - 13.8 KV Buses PA01 and ENERGIZED PA02 are energized

• PA01

• PA02 Step 1.a

22. RCS pressure - Operator ensured RCS S U GREATER THAN 325 pressure is greater than PSIG 325 psig Comments:

Step 1.b RCS pressure is greater than 325 psig

23. Number 1 seal differential Operator ensured RCP A S U pressure - GREATER Number 1 seal differential THAN 200 PSID pressure is greater than 200 psid Comments:

• BB PI-150A BB PI-153A Step 1.c RCP A Number 1 seal differential pressure is greater than 200 psid

24. VCT pressure - Operator ensured VCT S U GREATER THAN 15 pressure is greater than 15 PSIG psig Comments:

Step 1.d VCT pressure is greater than 15 psig Page 7 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

25. RCP seal injection flow - Operator ensured RCP S U BETWEEN 6 GPM AND seal injection flow is 13 GPM PER RCP between 6 gpm and 13 gpm per RCP Comments:

• BG FR-157

• BG FR-156

• BG FR-157

• BG FR-155

• BG FR-156

• BG FR-154

• BG FR-155

• BG FR-154 Step 1.e RCP seal injection flow is between 6 gpm and 13 gpm per RCP

26. Number 1 seal leakoff Operator ensured Number S U flow - GREATER THAN 1 seal leakoff flow is OR EQUAL TO 0.2 GPM greater than or equal to 0.2 gpm Comments:

• BG FR-157

• BG FR-156

• BG FR-157

• BG FR-155

• BG FR-156

• BG FR-154

• BG FR-155

• BG FR-154 Step 1.f Number 1 seal leakoff flow is greater than or equal to 0.2 gpm

27. CCW To RCS Flow - Operator ensured CCW To S U INDICATED RCS Flow is indicated

• EG FI-128

• EG FI-128 Comments:

• EG FI-129

• EG FI-129 Step 1.g CCW To RCS Flow is indicated

28. RCP CCW system Operator ensured RCP S U annunciators - CLEAR CCW system annunciators are clear

• 52A, CCW Lo Comments:

• 70C, RCP A Th Bar

• 52A, CCW Lo

• 71C, RCP B Th Bar

• 70C, RCP A Th Bar

• 72C, RCP C Th Bar

• 71C, RCP B Th Bar

• 73C, RCP D Th Bar

• 72C, RCP C Th Bar

• 74C, RCP TB CCW

• 73C, RCP D Th Bar

• 74C, RCP TB CCW Step 1.h RCP CCW system annunciators are clear Page 8 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 29. START Oil Lift Pump for Operator started Lift Pump S U RCP to be started: for RCP A (or B)

• BB HIS-41

• BB HIS-41 Comments:

• (BB HIS-42) * (BB HIS-42)

Step 1.i Lift Pump for RCP A (or B) has been started

30. Oil Lift Pump oil pressure Operator ensured RCP A S U interlock WHITE light - (or B) Oil Lift Pump oil LIT pressure interlock white light is lit Comments:

Step 1.j RCP A (or B) Oil Lift Pump oil pressure interlock white light is lit

31. NOTE: SI must be reset Operator read note S U prior to starting RCP C or RCP D to prevent potential shutdown Comments:

sequencer actuation on undervoltage of XNB02

32. RESET SI If Necessary: Operator ensured SI is S U reset

• SB HS-42A

• SB HS-43A SI is reset Comments:

Step 2 SI was reset when attempting to start RCP D, it does not need to be reset again

33. START Desired RCP As The Lift Oil pump has Operator ensured RCP A S U Follows: been running for 2 (or B) oil lift pump has minutes been running greater than CHECK associated oil lift 2 minutes Comments:

pump - RUNNING GREATER THAN 2 MINUTES Step 3.a Page 9 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 34. START desired RCP: Operator started RCP A S U (or B) using BB HIS-37 BB HIS-37 (RCP A)

(BB HIS-38)

(or BB HIS-38) (RCP B) Comments:

RCP A (or B) is running Step 3.b

35. CHECK RCP - Operator ensured RCP A S U RUNNING GREATER (or B) has been running THAN 1 MINUTE greater than 1 minute Comments:

Step 3.c

• 36. STOP Oil Lift Pump: Operator stopped Oil Lift S U Pumps:

• BB HIS-41 (RCP A)

• (or BB HIS-42) (RCP

• BB HIS-41 (RCP A)

Comments:

B) * (or BB HIS-42) (RCP B)

Report to CRS that RCP The JPM is Complete D did not start. RCP A (or

_________________

B) has been started.

Record Stop Time on Operator may request to Page 2 secure BB HIS 44 (RCP D) Lift oil pump. It is not required to secure this pump.

Page 10 of 11 JPM S4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Callaway Plant experienced a Reactor Trip from full power.

A Switchyard fault resulted in the loss of the Startup Transformer.

The operating crew is performing the actions of ES-0.2, Natural Circulation Cooldown.

The PA Busses have been re-energized and the crew has returned to Step 1.

Initiating Cues: The Control Room Supervisor directs you to start Reactor Coolant Pump D in accordance with EOP Addendum 3, Starting An RCP.

JPM S4

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S5 JPM Bank No: URO-SEN-04-C193J(A)(TC) KSA No: 026 A4.01 Revision Date: 11/19/2014 KSA Rating: 4.5 / 4.3 Job Title: URO/SRO Duty: CONTAINMENT SPRAY SYSTEM Task Title: ALIGN CONTAINMENT SPRAY FOR RECIRCULATION Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

ES-1.3, Transfer to Cold Leg Recirculation, Rev 011 Tools / Equipment: None Page 1 of 6 JPM S5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A Large Break LOCA has occurred inside Containment. The Crew has completed the actions of ES-1.3, Transfer to Cold Leg Recirculation, through Step 5.

RWST Level has decreased to less than 12%.

Initiating Cues: You are directed to complete the actions of ES-1.3, Transfer to Cold Leg Recirculation, Step 6.

Note:

1. Initialize using any Mode 1 - 3 IC. (IC-172)

2. Override switch (EN) x17I149o, value = 0

3. Insert a large break LOCA inside containment at a break size to initiate CSAS.

• Insert Malfunction (BB) BB001_D, Value = 75,000

4. Perform actions of ERGs through step 5 of ES 1.3.

5. Insert Plant Parameter (BN) TBN01TAZTLIL, Adjust the value until < 12%

6. Freeze simulator /make temporary IC with RWST level at 12% AND Annunciator 47B, RWST Lev LoLo 2

7. Put up SUMPBLK on screen Task Standard: Train B Containment Spray Pump is RUNNING in the RECIRCULATING LINEUP. Train A Containment Spray Pump is stopped.

Start Time:

Stop Time:

Page 2 of 6 JPM S5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD NOTE: Any pumps taking suction from the RWST should be stopped if RWST level lowers to 6%.

This note is prior to Step 3

1. OBTAIN A VERIFIED PROVIDE OPERATOR OPERATOR OBTAINED S U WORKING COPY OF WITH PROCEDURE PROCEDURE COPY ES-1.3, TRANSFER TO COPY COLD LEG Comments:

RECIRCULATION.

2. VERIFY OPERATOR VERIFIED S U CONTAINMENT SPRAY BOTH CONTAINMENT PUMPS ARE RUNNING. SPRAY PUMPS ARE RUNNING.

• EN HIS-3 Comments:

containment spray pumps

• EN-HIS-9 are indicating a red light Step 6.a on and green off with flow on EN-FI-5 and 11 indicating 1.6X106lbm/hr and pressure on EN-PI-10 and 4 indicating 215 psig

3. VERIFY RWST LEVEL OPERATOR CHECKED S U IS LESS THAN 12%. RWST LEVEL IS <12%.

Step 6.b RWST LEVEL INDICATORS AND/OR Comments ANNUNCIATOR 47B, RWST LEVEL LOLO 2 is lit.

• 4. RESET CSAS OPERATOR RESET S U CSAS USING SB HS-51

• SB HS-51 AND SB HS-54.

• SB HS-54 Both buttons have been Comments pressed and the red Step 6.c annunciator 59A is not lit Page 3 of 6 JPM S5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 5. OPEN Containment OPERATOR OPENED EN S U Recirc Sump To HIS-7 AND attempted to Containment Spray open EN HIS-1.

Pump valves:

EN HIS-7 indicates red Comments

• EN HIS1 light on green off

• EN HIS7 EN-HIS-1 indicates green Step 6.d light on red off (Alternate Path)

• 6. If any valve can NOT be EN-HIS-3 in PULL-TO-opened, LOCK.

THEN PLACE associated Containment spray pump Containment Spray A indicates green light on Pump in PULL-TO- red off and EN-PI-4 reads LOCK: 0 psig and EN-FI-5 reads 0 lbm/hr EN HIS-3 (EN HV-1)

Step 6.d RNO

7. MONITOR OPERATOR VERIFIED S U CONTAINMENT SPRAY CONTAINMENT SPRAY PUMP DISCHARGE PUMP FLOWS USING FLOW EN-FI-11.

Comments Step 6.e Flow as indicated on EN-FI-11 shows 1.6X106Lbm/hr

8. CLOSE RWST TO OPERATOR CLOSED BN S U CONTAINMENT SPRAY HIS-4.

PUMP VALVE BN HIS-4 BN-HIS-4 indicates green Step 6.e light on red off Comments

• 9. CLOSE RWST TO OPERATOR CLOSED BN S U CONTAINMENT SPRAY HIS-3.

PUMP VALVE BN HIS-3.

BN HIS-3 indicates green Step 6.e light on red off Comments Page 4 of 6 JPM S5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

10. START CONTAINMENT IF ASKED ABOUT OPERATOR VERIFIED S U SPRAY PUMPS AS STARTING PUMPS, NECESSARY NECESSARY PROVIDE FOLLOWING CONTAINMENT SPRAY CUE: PUMPS ARE RUNNING Step 6.f Comments CRS DIRECTS YOU TO MAINTAIN CURRENT PLANT CONDITIONS

11. JPM IS COMPLETE RECORD STOP TIME S U ON PAGE 1.

Comments Page 5 of 6 JPM S5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A Large Break LOCA has occurred inside Containment. The Crew has completed the actions of ES-1.3, Transfer to Cold Leg Recirculation, through Step 5.

RWST Level has decreased to less than 12%.

Initiating Cues: You are directed to complete the actions of ES-1.3, Transfer to Cold Leg Recirculation, Step 6.

JPM S5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S6 JPM Bank No: MODIFIED KSA No: 064A4.06 URO-AEO-05-C174J(A)

Revision Date: 11/19/2014 KSA Rating: 3.9/3.9 Job Title: URO/SRO Duty: SR Elect Gen and Dist (NE)

Task Title: MANUALLY START DIESEL GENERATORS Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

ECA-0.0, Loss of All AC Power, Rev. 19 Tools / Equipment: None Page 1 of 7 JPM S6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant was in Mode 3 at Normal Operating Pressure and Temperature when an improper switching order caused a loss of both NB buses.

The crew has completed ECA-0.0, Loss of All AC Power up to and including Step 4.

Initiating Cues: The Control Room Supervisor directs you to continue in the procedure by performing all applicable sections of Step 5 of ECA-0.0.

Inform the CRS when you have completed Step 5.

Note:

Using IC167 with rods withdrawn while keeping the Simulator in FREEZE

• Insert Remote Function (KJ) DGBLOCK_1, Value = True

• Insert Remote Function (KJ) DGBLOCK_2, Value = True

• Insert Remote Function (EF) PEF01A_1, Value = Block

• Insert Remote Function (EF) PEF01B_1, Value = Block

• Insert Remote Function (MD) N3PCB3B, Value = Open

• Insert Remote Function (PA) LOAPA201, Value = Trip

• Insert Overide Switch, X19I241S, Value = 1

• GO TO RUN

• Trip RX DURING the JPM Remotely secure the B when directed by the examiner.

Task Standard: Upon completion of this JPM, the operator will have manually started the A DG, re-energized NB01, and manually Start ESW Pump A prior to A DG auto trip.

Start Time:

Stop Time:

Page 2 of 7 JPM S6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a copy of ECA-0.0 Provide operator with Operator obtained S U procedure copy procedure copy and went to Step 5 of the procedure Comments:

2. TRY To Restore Power Operator observed that S U to Any AC Emergency neither DG A nor DG B is Bus running Comments:

Energize AC emergency Neither DGs are running bus with diesel generator: or indicate any voltage or frequency Check Both DGs Running - NO Step 5.a.1

• 3. Manually START DG(s) Operator Started Both S U DG(s) by depressing start Pushbuttons:

Step 5.a RNO 1)

Comments:

KJ HS-8A has been pushed

4. Manually START DG(s) Operator Started Both S U DG(s) by depressing start Pushbuttons:

Step 5.a RNO 1)

Comments:

KJ HS-108A has been pushed

5. CHECK AC emergency Operator observed that S U buses - AT LEAST ONE both NB Buses are ENERGIZED energized Comments:

• NB01 - YES Both buses are indicating voltage on NE-EI-1 and 2

• NB02 - YES of 4160 kv and frequency Step 5.a 2 on NE-SI-1 and 3 of 60 Hz Page 3 of 7 JPM S6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

6. CHECK AC emergency Operator determined that buses - AT LEAST ONE NB01 BUS and NB02 are ENERGIZED Energized.

NB01 - YES NB01 is indicating voltage on NE-EI-1 of 4160 kv and OR frequency on NE-SI-1 of NB02 - YES 60 Hz Step 5.b. NB02 is indicating voltage on NE-EI-2 of 4160 kv and frequency on NE-SI-3 of 60 Hz

7. CHECK ESW associated Operator verified: S U with energized AC A ESW Pump IS NOT emergency bus(es) -

running RUNNING Comments:

B ESW Pump IS NOT EF HIS-55A NOT running RUNNING A ESW pump has green EF HIS-56A NOT light on and no red light RUNNING and shows no flow or Step 5.c pressure B ESW pump has green light on and no red light and shows no flow or pressure Alternate path starts here

8. PERFORM the following: Operator verified: S U ENSURE ESW To UHS ESW to UHS valves are valves are OPEN both OPEN Comments:

• EF HIS-37 Both ESW valves indicate red light on and green light

• EF HIS-38 off Step 5.c RNO c.1 Page 4 of 7 JPM S6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 9. PERFORM the following: Operator started ESW S U Pump A using:

START ESW Pump(s) as necessary EF HIS-55A Comments:

Step 5.c RNO c.2 A ESW pump has red light on green off and indicating on EF-FI-53 6

11X10 lbm/hr and pressure on EF-PI-1 of 116 psig

10. PERFORM the following: Operator attempted to S U start ESW Pump B using:

START ESW Pump(s) as necessary EF HIS-56A Comments:

Step 5.c RNO c.2 B ESW pump has red light off green on and indicating on EF-FI-54 0 lbm/hr and pressure on EF-PI-2 of 0 psig

11. PERFORM the following: Operator verified that A S U DG is now running with IF any DG is running with appropriate cooling water NO cooling water THEN and B DG is running with Comments:

STOP affected DG(s)

NO cooling water Step 5.c RNO c.3 NOTE: Step 12 is only critical if the B DG was started in step 4 of the JPM. If the DG was not started step 13 is N/A and the applicant will not perform these actions.

12. IF any DG is running with Respond as the OT The operator has S U NO cooling water, THEN contacted to locally dispatched an OT to Place locally STOP affected secure the diesel. Use Master Transfer Switch to DG(s): proper 3 way LOC/MAN. (KJ HS-109) Comments:

communication repeating and STOPPED the Diesel.

a) Place Master back ONLY what the (KJ HS-108B)

Transfer Switch operator directs you to to LOC/MAN. The B DG has stopped do.

• KJ HS109 Operator may request to b) STOP the Diesel. open NB0211 prior to

• KJ HS108B stopping EDG per ODP-ZZ-00025 guidance Page 5 of 7 JPM S6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

13. Return To procedure and Acknowledge as the CRS Operator Completed Step S U step in effect and that Step 5 of ECA-0.0 is 5 of ECA-0.0 and reported IMPLEMENT Functional complete to the CRS actions that Restoration Procedures were necessary. Comments:

The JPM is Complete as necessary

__________________

Step 5.d Record Stop Time on Page 2 Page 6 of 7 JPM S6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant was in Mode 3 at Normal Operating Pressure and Temperature when an improper switching order caused a loss of both NB buses.

The crew has completed ECA-0.0, Loss of All AC Power up to and including Step 4.

Initiating Cues: The Control Room Supervisor directs you to continue in the procedure by performing all applicable sections of Step 5 of ECA-0.0.

Inform the CRS when you have completed Step 5.

JPM S6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S7 JPM Bank No: New KSA No: 016A4.01 Revision Date: 11/19/2014 KSA Rating: 2.9/2.8 Job Title: URO/SRO Duty: Instrumentation Task Title: Selection of available Instrumentation Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER, Rev. 33 Tools / Equipment: None Page 1 of 6 JPM S7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1.

A loss of power to NN01 has occurred Step 1 of OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER has been completed and the plant is stable Initiating Cues: The Control Room Supervisor directs you to perform Attachment A of OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER up to Step A7.

The BOP is monitoring and maintaining SG levels The RO is in monitoring and maintaining PZR level and pressure Note:

Using IC 169 (loss of NN01 with Step 1 of OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER complete and PZR and SGs stable Act at the RO and BOP to maintain PZR level and pressure and SG levels Task Standard: Upon completion of this JPM, the operator will have selected the proper instrumentation for SG Flow and Level and PZR pressure and level.

Start Time:

Stop Time:

Page 2 of 6 JPM S7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. Obtain a copy of Provide operator with Operator obtained S U Attachment A of OTO- procedure copy procedure copy.

NN-00001, LOSS OF SAFETY RELATED Comments:

INSTRUMENT POWER

2. ENSURE the following Operator ensured the S U components are NOT following components are selected: NOT selected Comments:

Step A1 NOTE: The Operator will select away from NN01 components on the following switches

• 3. SG A Operator selected away S U from AB FS512C AB FS512C AE LS519C Comments:

AE LS519C Step A1

4. SG B Operator selected away S U from AB FS522C AB FS522C AE LS529C Comments:

AE LS529C Step A1

• 5. SG C Operator selected away S U from AB FS532C AB FS532C AE LS539C Comments:

AE LS539C Step A1 Page 3 of 6 JPM S7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

6. SG D Operator selected away S U from AB FS542C AB FS542C AE LS549C Comments:

AE LS549C Step A1

• 7. Pressurizer Operator selected away S U from

• BB PS455F BB PS455F BB LS459D (NOT Comments:

critical) BB LS459D Step A1

• 8. Main Turbine Operator selected away S U from AC PS505Z AC PS505Z Step A1 Comments:

• 9. PRESS SELECT On Operator PRESSED S U STEAM FLOW and Level SELECT On STEAM for ALL Steam FLOW and Level for ALL Generators on AE SS Steam Generators on AE Comments:

500, SG Level Control SS500, SG Level Control Input Selection. Input Selection.

Step A2

• 10. PLACE BB TS411F, T Operator PLACED BB TS S U Defeat Switch in T411 411F, T Defeat Switch in position. T411 position.

Comments:

Step A3

• 11. PLACE BB TS412T, Operator PLACED BB TS S U Rod Control Tave Input 412T, Rod Control Tave Channel Defeat Switch in Input Channel Defeat T412 position. Switch in T412 position. Comments:

Step A4 Page 4 of 6 JPM S7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

• 12. ISOLATE letdown by Operator ISOLATED S U closing all Orifice letdown by closing all Isolation Valve(s): Orifice Isolation Valve(s):

Comments:

BG HIS8149AA (NOT BG HIS8149AA critical)

BG HIS8149BA BG HIS8149BA (NOT critical) BG HIS8149CA

• BG HIS8149CA

• 13. REDUCE Charging To Operator slowly CLOSED S U RCPs Seals Only By Charging Header Back Performing The Following Pressure Control valve:

Concurrently: Comments:

• BG HC182

• Slowly CLOSE Charging Header Operator manually Back Pressure THROTTLED appropriate Control valve: Charging Discharge Flow Control valve to maintain

• BG HC182 RCP seal injection flow

• Manually THROTTLE from 8 gpm to 13 gpm to appropriate Charging each RCP while reducing Discharge Flow charging flow:

Control valve to maintain RCP seal

• BG FK121 (CCP) injection flow from 8 gpm to 13 gpm to OR each RCP while

• BG FK124 (NCP) reducing charging flow: Operator ENSURED BG

• BG FK121 HC182 is full closed.

(CCP) The critical part of this step OR is that RCP seal injection flow is 8-13 gpm and BG

• BG FK124 HC-182 is closed at the (NCP) end of this step

• ENSURE BG HC 182 is full closed.

14. Report to CRS Acknowledge report Operator reported to CRS S U Attachment A is complete Attachment A is complete The JPM is Complete up to Step A7 up to Step A7

__________________ Comments:

Record Stop Time on Page 2 Page 5 of 6 JPM S7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1.

A loss of power to NN01 has occurred Step 1 of OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER has been completed and the plant is stable Initiating Cues: The Control Room Supervisor directs you to perform Attachment A of OTO-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER up to Step A7.

The BOP is monitoring and maintaining SG levels The RO is in monitoring and maintaining PZR level and pressure JPM S7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S8 JPM Bank No: URO-SBB-04-C159J(A) KSA No: 008 A4.01 Revision Date: 11/19/2014 KSA Rating: 3.3/3.1 Job Title: URO Duty: Component Cooling Water System (EG)

Task Title: RESPOND TO A LOSS OF CCW TO THE RCPS Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

Control Room Simulator/Lab Plant Classroom Method of Performance: Simulated Performed Alternate Path Time Critical RCA

References:

OTO-BB-00002, RCP OFF-NORMAL, REV. 031 Tools / Equipment: None Page 1 of 6 JPM S8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: CALLAWAY PLANT IS OPERATING AT 100% STEADY STATE POWER. AN INADVERTANT SIGNAL HAS CAUSED A LOSS OF COMPONENT COOLING WATER FLOW TO THE CONTAINMENT / REACTOR COOLANT PUMPS Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO PERFORM ATTACHMENT C OF OTO-BB-00002, RCP OFF-NORMAL TO ADDRESS THIS ISSUE.

Inform the CRS when CCW has been restored to the RCPs.

This is a Time Critical JPM Note:

USE IC 168, or any normal MODE 1 IC CLOSE THE FOLLOWING VALVES FROM THE CONTROL BOARD:

EG HIS-58 EG HIS-71 THEN Insert Override Switches (EG), X19I213C, Plant Tag EGHIS71_IC, Value = TRUE Override EG HV62 open to prevent closing on false hi flow, EGHV0062, Value=1 Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE RESTORED CCW TO CONTAINMENT (WITHIN 10 MINUTES) AND THE REACTOR COOLANT PUMPS Start Time:

Stop Time:

Page 2 of 6 JPM S8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

1. OBTAIN A VERIFIED PROVIDE PROCEDURE OPERATOR OBTAINED S U WORKING COPY OF COPY, IF REQUESTED PROCEDURE COPY and OTO-BB-00002, RCP reads NOTE OFF-NORMAL and reads Comments:

NOTE

2. CHECK RCP MOTOR IF ASKED - IT HAS OPERATOR CHECKED S U PARAMETERS MEET BEEN LESS THAN 10 ALL RCP MOTOR ALL OF THE MINUTES PARAMETERS MEET FOLLOWING: ALL OF THE Comments:

FOLLOWING:

• MOTOR BEARING TEMPS < 195 °F

• MOTOR BEARING

• MOTOR STATOR TEMPS < 195 °F WINDING TEMPS

• MOTOR STATOR ARE < 311 °F WINDING TEMPS

• CCW LOST TO RCP ARE < 311 °F MOTORS < 10 MIN

• CCW LOST TO RCP MOTORS < 10 MIN STEP C1

3. CHECK CCW FLOW TO OPERATOR CHECKED S U CONTAINMENT - NO CCW FLOW TO NORMAL OR HIGH FOR CONTAINMENT PLANT CONDITIONS: Comments:

• EG-FI-128

• EG-FI-129 STEP C2

• 4. RNO - ENSURE ALL OPERATOR CHECKED S U CCW TO THE PANEL AND CONTAINMENT INNER IDENTIFIED THAT EG AND OUTER HIS-58 AND EG HIS-71 Comments:

ISOLATION VALVES ARE CLOSED ARE OPEN:

EG HIS-58 AND EG HIS-

• EG HIS-58 71 SHOW GREEN LIGHT ON AND RED LIGHT OFF

• EG HIS-59 EG HIS-58 OPENED

• EG HIS-60 UPON TAKING THE

• EG HIS-71 VALVE TO OPEN

• EG HIS-61 EG HIS-71 WILL NOT OPEN

• EG HIS-62 This is the start of the RNO STEP C2.a. ALTERNATE PATH Page 3 of 6 JPM S8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

5. IF ANY VALVE(S) FAIL IF ASKED, EG HIS-71 OPERATOR IDENTIFIED S U TO OPEN, THEN OPEN CANNOT BE OPENED THAT EG HIS-71 THE ASSOCIATED LOCALLY CANNOT BE OPENED BYPASS VALVE USING AND OPENS THE Comments:

ATTACHMENT F, CCW BYPASS VALVE USING CNTMT ISOLATION ATTACHMENT F VALVES RNO STEP C2.b

6. PLACE Administrative Respond as the CRS that OPERATOR S U Controls for any OPEN administrative controls COMMUNICATED THAT Containment Isolation have been established. ADMINISTRATIVE CCW Bypass Valve: CONTROLS MUST BE Comments:

ESTABLISHED ATT F, STEP F1

• 7. Use The Tables Below OPERATOR LOCATED S U For Additional HANDSWITCH EG HIS-Containment Isolation 126A ON PANEL RL020.

CCW Valves Information: DEPRESSED THE NON- Comments:

ISO PUSHBUTTON EGHV0071 (EG HIS-71)

LOCATE HANDSWITCH Bypass EGHV0126 TIME CCW flow EG HIS-126 ON PANEL restored __________

Switch EG HIS-126 RL020. DEPRESSED THE OPEN PUSHBUTTON. (must be less than 10 Bypass Iso/Non Iso OBSERVE THE RED minutes since start of Switch EG HIS-126A LENS IS LIT. JPM)

ATT F, STEP F2 OBSERVED CCW FLOW TO CONTAINMENT

• 8. CHECK CCW Flow From Operator opened CCW S U RCPs OPEN Flow From RCPs

• BB HIS13

• BB HIS13 Comments:

• BB HIS14

• BB HIS14

• BB HIS15

• BB HIS15

• BB HIS16

• BB HIS16 STEP C3 Page 4 of 6 JPM S8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM TASK ELEMENT EXAMINER CUE PERFORMANCE SCORE STEP STANDARD

9. CHECK RCP Seal Operator CHECKED RCP S U Injection Flow Seal Injection Flow BETWEEN 8 GPM AND BETWEEN 8 GPM AND 13 GPM PER PUMP 13 GPM PER PUMP Comments:

• BG FR157

• BG FR157

• BG FR156

• BG FR156

• BG FR155

• BG FR155

• BG FR154

• BG FR154 Step C4

10. CHECK CCW Train Operator CHECKED CCW S U Supplying the RCPs Train Supplying the RCPs LESS THAN 105°F LESS THAN 105°F Comments:

• EG TI31

• EG TI31

• EG TI32

• EG TI32 Step C5

11. CONTINUE Monitoring Operator CONTINUED to S U RCP Parameters Monitoring RCP Parameters Step C6 Comments:

12. Report to CRS Actions ACKNOWLEDGE INFORMED THE CRS OF S U taken. The Operator REPORT ACTIONS could report CCW flow restored any time after Comments:

STEP 7 of the JPM. THE JPM IS COMPLETE Record time on page 2 Page 5 of 6 JPM S8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: CALLAWAY PLANT IS OPERATING AT 100% STEADY STATE POWER. AN INADVERTANT SIGNAL HAS CAUSED A LOSS OF COMPONENT COOLING WATER FLOW TO THE CONTAINMENT / REACTOR COOLANT PUMPS Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO PERFORM ATTACHMENT C OF OTO-BB-00002, RCP OFF-NORMAL TO ADDRESS THIS ISSUE.

Inform the CRS when CCW has been restored to the RCPs.

This is a Time Critical JPM JPM S8

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 1, Rev 1 Op-Test No.: 2014-1 Examiners: ____________________________ Operators: _____________________________

____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: 100%

Turnover: B CCP is tagged out for Breaker PMTs Eve Malf. No. Event Event nt Type* Description No.

SRO (I) 1 PT0456 PZR Pressure instrument Fails high (Tech Specs)

RO (I)

SRO (I) 2 ABFT0542 SG Steam Flow Inst Fails low BOP (I)

SRO (C) 3 SFB08_DR RO (C) Dropped rod (Tech Specs)

BOP (C)

SRO (M) 4 SF2CD2/2 RO (M) Multiple Dropped Rods / Rx Trip BOP (M)

SRO (M) 5 AB001_A RO (M) Steam Line Break inside containment BOP (M)

SRO (C) 6 SAS9XX_1, 2, 3, 4 MSIVs fail to close BOP (C)

PEN01A_2 and SRO (C) Containment Spray Pump Auto Start Failure and 7

EN08RL_420TVSP BOP (C) Containment Spray Pump Discharge Valve Failure

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 3

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 2

Scenario Event Description Callaway 2014 NRC Exam Scenario #1, rev. 1 The plant is at 100% with the B CCP tagged out After the crew takes the watch, the lower selected PZR Pressure Channel BB PT-456 fails high.

Annunciator PZR PRESS HI and RX PARTIAL TRIP will alarm to alert the operator of the malfunction.

The CRS should enter OTO-BB-00006, Pressurizer Pressure Control Malfunction, and transfer pressure control to remove the failed channel.

After the Technical Specifications from the previous event have been identified, a Steam Flow Channel on D S/G Fails Low. The crew will respond using, OTO AE 00002, Steam Generator Water Level Control Malfunctions and select SG steam flow channel selector to an operable channel on AB FS-542C and DFWCS.

After the crew has selected away from the failed channel, a dropped rod occurs as indicated by DRPI and Control Rod Alarms. The ROs will perform the immediate actions of OTO-SF-00001 to place rods in manual. The crew will establish conditions for rod recovery identify Technical Specifications and begin restoration. During rod recovery, additional control rods drop into the core. The operators will take immediate action to trip the reactor.

After the Reactor Trip, a Steam Line Break inside containment will occur. The MSIVs will fail to auto close. The crew will respond IAW E-0, Reactor Trip or Safety Injection, and transition to E-2, Faulted Steam Generator Isolation The A Containment Spray Pump fails to auto start and the B Containment Spray Pump discharge valve fails to open. The crew can manually start the A Containment Spray Pump and/or direct an OT to open EN-HV-12, CS PUMP B DISCH, in the field while performing the actions of E-0.

The crew will continue to perform the actions of E-2, and isolate the A SG, then transition to ES-1.1, SI Termination.

The scenario can be terminated after the transition to ES-1.1 occurs

Scenario Event Description Callaway 2014 NRC Exam Scenario #1, rev. 1 Critical Tasks:

Critical Tasks Isolate the faulted A SG before transition out of E-2 Manually actuate containment cooling by:

Starting the 'A' Containment Spray Pump EVENT 5 7 Safety Failure to isolate a faulted SG that can be isolated causes challenges to CSFs beyond If one train of containment spray is not actuated, the FSAR assumptions and results are significance those irreparably introduced by the postulated conditions. invalid. Because compliance with the assumptions of the FSAR is part of the facility Failure to isolate a faulted SG can result in challenges to the following CSFs: license condition, failure to manually actuate at least one train of containment spray

• Integrity under the scenario conditions and when it is possible to do so constitutes a violation of

• Subcriticality the license condition.

• Containment (if the break is inside containment)

Cueing Both of the following: Indication that containment cooling is required by Containment pressure either currently

• Steam pressure and flow rate indications that make it possible to identify A SG as or has been greater than 27 psig faulted Indication and/or annunciation that no train of containment spray has successfully AND actuated by both:

• Valve position and flow rate indication that AFW continues to be delivered to the

• A Containment Spray Pump not running faulted A SG

• B Containment Spray Pump discharge valve NOT open Performance

• ISOLATE AFW flow to faulted SG(s): Starting the 'A' Containment Spray Pump indicator o CLOSE associated MD AFP Flow Control Valve(s):

AL HK-7A (SG A) o CLOSE associated TD AFP Flow Control Valve(s):

AL HK-8A (SG A)

• CLOSE Steamline Low Point Drain valve from faulted SG(s):

o AB HIS-9 (SG A)

• FAST CLOSE all MSIVs and Bypass valves:

o AB HS79 o AB HS80 Performance Crew will observe the following: Indication that 'A' Containment Spray Pump is running feedback

• Any depressurization of intact SGs stops AND

• AFW flow rate indication to faulted SG of zero Containment pressure lowering Justification for before transition out of E-2 is in accordance with the PWR Owners Group Emergency before completion of Attachment A of E-0 is in accordance with the PWR Owners the chosen Response Guidelines. It allows enough time for the crew to take the correct action while Group Emergency Response Guidelines. It allows enough time for the crew to take the performance limit at the same time preventing avoidable adverse consequences. correct action while at the same time preventing avoidable adverse consequences.

PWR Owners CT-17 Isolate faulted SG CT-3 Manually actuate containment cooling Group Appendix

Scenario Event Description Callaway 2014 NRC Exam Scenario #1, rev. 1 References OTO-BG-00001, Pressurizer Level Control Malfunction OTO-AE-00002, Steam Generator Water Level Control Malfunctions OTO-SF-00001, Rod Control/Malfunctions E-0, Reactor Trip or Safety Injection E-2, Faulted Steam Generator Isolation ES-1.1, SI Termination Tech Spec 3.3.1.E & M for Reactor Trip System Instrumentation Tech Spec 3.3.2.D and L for Reactor Trip System Instrumentation Tech spec 3.1.4.B for Rod Group Alignment Limits ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. Main Steam Line Break Inside Containment (T(MSI))

a. Close MSIVs

b. Isolate Feedwater to the affected SG

Scenario Event Description Callaway 2014 NRC Exam Scenario #1, rev. 1 Scenario Setup Guide:

Establish the initial conditions of IC-10, MOL 100%:

• RCS boron concentration 752 ppm

• CCP A 765 ppm minus 5 days

• CCP B 775 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• ENSURE BB-PT-455 / BB-PT-456 is selected on BB-PS-455F

• B CCP is tagged out with breaker in P-T-L and tag on handswitch

=======SCENARIO PRELOADS / SETUP ITEMS==========

B CCP Tagged out due to Breaker PMTs.

• ME Schematics (BG) e23bg01b BG02NB0201_BKRTA_BKPOS, Value = 3 Steam Line Break inside containment / MSIV auto close failure (Event 5)

• Insert Malfunctions (AB)AB001_A/3600 klbm per hr, cond rec0009 le 1.0 (reactor trip)

• Insert Malfunction SAS9XX_1, 2, 3, 4 - Value = Enable Containment Spray Pump Auto Start Failure and / Containment Spray Pump Discharge Valve Failure (Event 6)

• Inhibit start of A Containment Spray Pump Auto Start o Insert Malfunction (EN) PEN01A_2, Value = 1

• Containment Spray Pump B Disch fails to open on CISB - Event 6 o Go To ME Schematics (EN) e23en03_b, click on 42 o relay in middle of page o Override open relay EN08RL_42oTVSP, Value = 0

======= EVENT 1 ============================

PZR Pressure Channel BB PT-456 fails high

• Insert Malfunction (BB) BBPT0456, Value = 2500

======= EVENT 2 ============================

D S/G Steam Flow Channel Failure ABFT0542

• Insert Malfunction (AB) ABFT0542, value = 0

======= EVENT 3 ============================

Dropped Rod

• Insert Malfunctions (SF) SF B08 = DR, Value = stationary gripper

=======EVENT 4 ==============================

Multiple Dropped Rods / Rx Trip

• Insert Malfunctions (SF) SF2CD2, Value = 2 rods

=======EVENT 5 PRELOADED============================

Steam Line Break inside containment

• See Preloads Above

=======EVENT 6 PRELOADED===============

Containment Spray Pump Auto Start Failure and / Containment Spray Pump Discharge Valve Failure

• See Preloads Above

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 1 Page 6 of 24 Event

Description:

PZR Pressure Channel BB PT-456 fails high Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 3 minutes or at the discretion of the Lead Examiner

• PZR Pressure Channel BB PT-456 fails high o Insert Malfunction/BB/PT0456/2500/Ramp Time 180 sec/Insert

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure.

• When contacted, respond as Duty Manager. Acknowledge the channel failure and Tech Spec entry.

Indications Available T=3 ANN 33 B PZR HI PRESS DEV ANN 83 C RX PARTIAL TRIP (delayed)

NOTE Crew members may take manual control of Pressurizer Pressure prior to OTO entry OTO-BB-00006, Pressurizer Pressure Control Malfunction Implement OTO-BB-00006, Pressurizer Pressure Control CRS Malfunction OTO-BB- (Step 1) Check Pressurizer Pressure Indicator - Failed, 00006 RO

• BB PI-456 (Step 2.a) CHECK Pressurizer Pressure:

RO

• Between 2225 psig and 2250 psig - YES (Step 3) IF Required TRANSFER Pressurizer Pressure Control RO Selector To Remove Failed Channel From Control:

• BB PS-455F (Step 4) CHECK Pressurizer Pressure Within One Of The Following:

RO

• Trending to between 2225 psig and 2250 psig OR

• Between 2225 psig and 2250 psig

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 1 Page 7 of 24 Event

Description:

PZR Pressure Channel BB PT-456 fails high Proc /Time Position Applicants Actions or Behavior (Step 5) WHEN Pressurizer Pressure Is Restored To Setpoint, PLACE Pressurizer Pressure In AUTO CONTROL RO a. Verify PZR Spray Valves in AUTO

b. PLACE PZR PRESS MASTER CTRL in AUTO

• BB PK-455A (Step 6) Check P-11 in Correct State Within One Hour of the BOP Pressurizer Pressure Failure (Step 7) Select an Operable Channel for:

• RCS Pressure Recorder BB PS-455G RO

• OPDT/OTDT Temperature Recorder SC TS-411E

• Computer Digital Readout Display: REP0481A, 482A or 483A (Step 8) Review Applicable Tech Specs, Attachment J

• 3.3.1, Table 3.3.1-1 Item 6 Cond E (OTDT 72hr)

• 3.3.1, Table 3.3.1-1 Item 8 Cond M, E (P 72hr)

CRS

• 3.3.2, Table 3.3.2-1 Item 1.d Cond D (SI 72hr)

• 3.3.2, Table 3.3.2-1 Item 8.b Cond L (P-11 1hr)

• 3.3.2, Table 3.3.2-1 Item 9 Cond D (PORV 72hr)

BOP (Step 9) Record Permissive P-11 is in Correct State in CR log (Step 10) REVIEW Attachment A, Effects of Pressurizer CRS Pressure Instrument Failure NOTE At Lead Examiners discretion move to the next Event CRS (Step 11) Direct I&C to Trip Protective Bistables - Att. B

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 2 Page 8 of 24 Event

Description:

D S/G Steam Flow Channel Failure ABFT0542 Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 20 minutes or at the discretion of the Lead Examiner

• D S/G Steam Flow Channel Failure ABFT0542

• Insert Malfunction (AB) ABFT0542, value = 0

• Act as I&C and acknowledge the failure of AB FT-542. Inform the CR that troubleshooting/repair will begin.

Indications Available:

T= 20 ANN 83 C RX PARTIAL TRIP (in already from previous malfunction)

ANN 111 D SG D FLOW MISMATCH ANN 111C SG D LEV DEV (possible if SG level goes out of band)

OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions Implement OTO-AE-00002, Steam Generator Water Level Control CRS Instrument Malfunctions OTO-AE- (Step 1) Check SG Water Level Control Instrument - NORMAL.

00002 RNO: SG D: AB LI-542 Take MANUAL Control of Affected SG MFRV or MFRV Bypass and MAINTAIN SG Level:

BOP

• SG D:

o AE FK540, SG D MFW REG VLV CTRL OR o AE LK580, SG D MFW REG BYPASS CTRL (Step 2) For the Failed Instrument, SELECT An Operable Channel:

• Select AB FS-542C to operable channel BOP

• On DFWCS, SELECT appropriate Level, FW Flow or Steam Flow on AE SS500

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 2 Page 9 of 24 Event

Description:

D S/G Steam Flow Channel Failure ABFT0542 Proc /Time Position Applicants Actions or Behavior (Step 3) RESTORE Affected SG NR Level to between 45% and BOP 55%

(Step 4) Return Affected SG MFRV or MFRV Bypass to AUTO Control:

• SG D:

BOP o AE FK540 OR o AE LK580 CRS (Step 5) Review Attachment A, Effects of Instrument Failure (Step 6) Review Applicable Tech Specs, Attachment F CRS

• None applicable CRS (Step 7) Perform Notifications per ODP-ZZ-00001, Add 13 NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 3 Page 10 of 24 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 30 minutes or at the discretion of the Lead Examiner

• Dropped Rod Cntrl Bank C1 Rod B8

• Insert Malfunctions (SF) SF B08 = DR, Value = stationary gripper

• When requested to investigate as I&C, wait 5 minutes and report that there is a blown fuse and it has been replaced

• When contacted as Reactor Engineering wait 5 minutes and report that there is no reason the rod cannot be recovered

• When contacted, respond as Duty Manager, acknowledge entry into the OTO Indications Available:

T= 30 ANN 79 C CONTROL ROD DEV ANN 80 C RPI ROD DEV ANN 81 B ROD AT BOTTOM (plus others)

OTO-SF 00001, Rod Control Malfunctions CRS Implement OTO-SF 00001, Rod Control Malfunctions NOTE Steps 1 through 6 are immediate action steps OTO-SF (Step 1) Check Both of the Following are Met for Indication of 00001 Multiple Dropped Rods RO ANN 81A, TWO/More Rods at Bottom Lit Rod Bottom lights lit for greater than one rod

• RNO Go to Step 3 (Step 3) Check Main Turbine Runback Or Load Reject - IN RO PROGRESS

• RNO Go to Step 5 (Step 5) Place Rod Control in Manual RO

• SE HS-9

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 3 Page 11 of 24 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior RO (Step 6) Check Control Rods Motion STOPPED RO (Step 7) Check Instrument Indication Normal (Step 8) Check Annunciator 79A LIT - NO:

RNO: Maintain RCS Tavg/Tref and go to Step 10 RO/BOP

• ADJUST Turbine load.

• ADJUST RCS boron concentration.

• ADJUST Control Rods.

(Step 10) Check Annunciator 81B and all Rod Bottom Lights RO Extinguished - NO:

RNO: Go to Attachment A (Step A1) Check Reactor Power less than 5% - NO:

RO RNO: Go to Step A3 CRS (Step A3) Contact I&C to determine reason for Dropped Rod (Step A4) CHECK Shutdown Margin Is Within The Limits Provided CRS In The COLR Within 1 Hour (Step A5) CHECK Axial Flux Difference (AFD) - WITHIN THE CRS LIMITS OF CURVE BOOK, FIGURE 1-1, AXIAL FLUX DIFFERENCE LIMITS CRS (Step A6) CHECK QPTR - LESS THAN OR EQUAL TO 1.02 (Step A7) Check Dropped Rod can be recovered in less than one CRS hour.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 3 Page 12 of 24 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior (Step A8) CONSIDER The Following Prior To Recovering The Rod:

• Length of time the rod has been misaligned CRS

• Power Level at which the realignment will be performed

• Rate of control rod movement during realignment

• Movement of other control rods to support realignment (Step A9) PERFORM Notifications Per ODP-ZZ-00001 Addendum CRS 13, Shift Manager Communications (Step A10) NOTIFY Reactor Engineering Prior To Attempting CRS Recovery Of The Control Rod (Step A11) CHECK Both Of The Following Are Met:

CRS

• Reason for dropped/misaligned rod has been identified

• Problem has been corrected

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 3 Page 13 of 24 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior (Step A12) PERFORM Attachment B, Dropped/Misaligned Rod CRS Recovery NOTE While some recovery actions of Attachment B may be performed, the intent is to proceed to the next event after the Technical Specification declaration. Therefore Attachment B actions are not listed here.

(Step A13) REVIEW Applicable Technical Specifications:

CRS

• 3.1.4.B for Rod Group Alignment Limits

• 3.2.4.A for QTPR (if QTPR >1.02)

NOTE Any time after the Technical Specifications have been identified and at Lead Examiners discretion, move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 14 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 45 minutes or at the discretion of the Lead Examiner

• Multiple Dropped Rods

• Insert Malfunctions (SF) SF2CD2, Value = 2 rods

• Preloaded malfunctions:

• Steam Line Break inside containment / MSIV auto close failure (Event 5)

• Containment Spray Pump Auto Start Failure and / Containment Spray Pump Discharge Valve Failure (Event 6)

• When contacted, respond as Duty manager, acknowledge entry into the EOP

• When contacted has OT to locally open EN-HV-12, wait 3 minutes and report that the valve will not open.

Indications Available:

T= 45 ANN 81 A TWO/More Rods at Bottom Lit OTO-SF 00001, Rod Control Malfunctions (Step 1) Check Both of the Following are Met for Indication of Multiple Dropped Rods RO

• ANN 81A, TWO/More Rods at Bottom Lit

• Rod Bottom lights lit for greater than one rod (Step 2) Perform the Following:

CRS

• Trip the reactor

• Go To E-0, Reactor Trip of Safety Injection E-0, Reactor Trip or Safety Injection E-0 CRS Implement E-0, Reactor Trip or Safety Injection

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 15 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior NOTE Steps 1 through 4 are immediate actions (Step 1) CHECK Reactor Trip - Yes

• Rod Bottom Lights - All Lit RO

• Reactor Trip and Bypass Breakers - Open

• Neutron Flux - Lowering (Step 2) CHECK Turbine Trip BOP

a. Turbine Stop Valves - Closed (Step 3) CHECK Power to AC Emergency Buses BOP a. At Least One Emergency Bus - Energized

b. Both Emergency Buses - Energized - YES (Step 4) CHECK SI Status

a. Check if SI is Actuated

b. Check both Trains of SI Actuated RO

• LOCA Sequencer ANN 30A - Lit

• LOCA Sequencer ANN 31A - Lit

• SB069 SI Actuate Red Light - Lit Solid (Step 5) Perform Attachment A, Automatic Action Verification, RO/BOP while continuing with this procedure (see page 22)

The following Critical Task actions are contained in NOTE Attachment A RO/BOP (Step A8 RNO) START the 'A' Containment Spray Pump Manually actuate containment cooling by:

Critical CREW Starting the 'A' Containment Spray Pump before completion of Task Attachment A of E-0

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 16 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step A9) CHECK If Main Steamlines Should Be Isolated: YES

• Containment pressure > 17 psig

• Steamline pressure - LESS THAN 615 PSIG B. Check MSIVs and Bypass valves CLOSED - NO RO/BOP b. FAST CLOSE all MSIVs and Bypass valves:

o AB HS79 o AB HS80 IF valve(s) will NOT fast close, THEN CLOSE MSIV(s) and bypass valves as necessary.

Critical CREW Isolate the faulted A SG before transition out of E-2 Task The crew may isolate the A SG at any time using the Foldout Page for E-0

• FAST CLOSE MSIVs.

• Manually CLOSE or locally ISOLATE any failed open NOTE CREW ASD(s).

• ISOLATE feed flow to faulted SG(s).

• MAINTAIN total feed flow greater than 285,000 lbm/Hr until narrow range level is greater than 7% [25%] in at least one SG.

E-0 (Step 6) CHECK Generator Output Breakers - Open BOP (cont'd)

(Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 17 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step 8) CHECK AFW Pumps RO a. MD AFW Pumps - Both Running

b. TD AFW Pump - Running (Step 9) CHECK AFW Valves - Proper Emergency Alignment

• MD AFP Flow Control Valves - Throttled RO

• TD AFP Flow Control Valves - FULL OPEN

• TD AFP Loop Steam Supply Valves - Both OPEN IF NECESSARY (Step 10) CHECK Total AFW Flow GREATER THAN 285,000 BOP LBM/HR (Step 11) Check PZR PORVs And Spray Valves:

a. PZR PORVs CLOSED RO b. PZR PORVs BOTH IN AUTO

c. PORV Block Valves BOTH OPEN

d. Normal PZR Spray valves CLOSED (Step 12) CHECK If RCPs Should Be Stopped:

a. RCPs ANY RUNNING - YES RO b. ECCS Pumps AT LEAST ONE RUNNING - YES

c. RCS pressure LESS THAN 1425 PSIG - YES

d. STOP all RCPs NOTE Temperature will be less than 557°F. The crew should have closed MSIVs by this time.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 18 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step 13) CHECK RCS Temperatures:

• NO RCPs running RCS COLD LEG TEMPERATURES STABLE AT 557°F OR TRENDING TO 557°F - NO RO THEN CONTROL total feed flow:

MAINTAIN total feed flow greater than 285,000 lbm/Hr until narrow range level is greater than 7% [25%] in at least one SG.

(Step 14) CHECK If Any SG Is Faulted: - YES CRS Go to E-2 Faulted Steam Generator Isolation, Step 1 E-2, Faulted Steam Generator Isolation E-2 CRS Implement E-2, Faulted Steam Generator Isolation (Step 1) CHECK MSIVs And Bypass FAST CLOSE all MSIVs and Valves - CLOSED (RNO) The MSIV may already have been closed by either E-0 foldout page or Attachment A of E-0 BOP FAST CLOSE all MSIVs and Bypass valves:

• AB HS-79

• AB HS-80 IF valve(s) will NOT fast close, THEN CLOSE MSIV(s) and bypass valves as necessary.

Critical CREW Isolate the faulted A SG before transition out of E-2 Task (Step 2) CHECK If Any SG Secondary Pressure Boundary Is Intact:

BOP

a. CHECK pressures in all SGs - ANY STABLE OR RISING - YES

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 19 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step 3) IDENTIFY Faulted SG(s): - Should identify the A SG as CRS the faulted SG (Step 4) ISOLATE Faulted SG(s):

a. ISOLATE AFW flow to faulted SG(s):

• CLOSE associated MD AFP Flow Control Valve(s):

o AL HK-7A (SG A)

• CLOSE associated TD AFP Flow Control Valve(s):

o AL HK-8A (SG A)

(May be isolated per the foldout page of E-0)

b. CHECK ASD from b. CLOSE valve(s) as faulted SG(s)-

CLOSED

• AB PIC-1A (SG A)

c. (not applicable)

d. CHECK Main Feedwater valves to faulted SG(s) - CLOSED BOP

• Main Feedwater Reg Valve:

o AE ZL-510 (SG A)

• Main Feedwater Reg Bypass valve:

o AE ZL-550 (SG A)

• Feedwater Isolation Valve:

o AE HIS-39 (SG A)

e. CHECK SG Blowdown Containment Isolation Valve from faulted SG(s) - CLOSED

• BM HIS-1A (SG A)

f. CLOSE Steamline Low Point Drain valve from faulted SG(s):

• AB HIS-9 (SG A)

Critical CREW Isolate the faulted A SG before transition out of E-2 Task (Step 5) CHECK CST To AFP Suction Header Pressure -

BOP GREATER THAN 2.75 PSIG - YES

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 20 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step 6) CHECK Secondary Radiation:

a. PERFORM the following:

• PERFORM EOP Addendum 11, Restoring SG Sampling After SI Actuation

• DIRECT Chemistry to periodically sample all SGs for activity

• DIRECT Radiation Protection to survey steamlines in Auxiliary Building Area 5 as necessary

b. CHECK unisolated secondary radiation monitors:

• SG Sample radiation:

o SJL 026 BOP

• SG ASD radiation:

o AB RIC-111 (SG A) o AB RIC-112 (SG B) o AB RIC-113 (SG C) o AB RIC-114 (SG D)

• Turbine Driven Auxiliary Feedwater Pump Exhaust radiation:

o FC RIC-385

c. Secondary radiation - NORMAL - YES

d. Levels in all SGs:

• NO SG LEVEL RISING IN AN UNCONTROLLED MANNER - YES

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 21 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step 7) CHECK If ECCS Flow Should Be Reduced:

a. RCS subcooling - GREATER THAN 30°F [50°F] - YES

b. Secondary heat sink:

• Narrow range level in at least one intact SG - GREATER THAN 7% [25%] - YES RO OR

• Total feed flow to intact SGs - GREATER THAN 285,000 LBM/HR - YES

c. RCS pressure - STABLE OR RISING - YES

d. PZR level - GREATER THAN 9% [29%]

(Step 8) RESET SI:

RO

• SB HS-42A

• SB HS-43A STOP All But One CCP:

• BG HIS-1A BOP OR

• BG HIS-2A CRS Go To ES-1.1, SI Termination, Step 3 NOTE At the Discretion of the Lead Examiner OR once the crew has transitioned to ES-1.1 - The Scenario can be STOPPED.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 22 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior Attachment A, Automatic Action Verification (Step A1) CHECK Charging Pumps - NO E-0 Att A RO/BOP CCP Pump B Out of Service RO/BOP (Step A2) CHECK SI and RHR Pumps - All running RO/BOP (Step A3) CHECK ECCS Flow - BIH flow indicated (Step A4) CHECK ESW Pumps - BOTH RUNNING RO/BOP

• EF HIS-55A

• EF HIS-56A (Step A5) CHECK CCW Alignment:

• CCW Pumps - ONE RUNNING IN EACH TRAIN

• CCW Service Loop Supply and Return valves for one operating CCW pump - OPEN RO/BOP

• OPEN CCW To RHR HX valves

• CLOSE Spent Fuel Pool HX CCW Outlet Valves

• STOP Spent Fuel Pool Cooling Pump(s)

• RECORD The Time Spent Fuel Pool Cooling Pump Secured (Step A6) CHECK Containment Cooler Fans - RUNNING IN RO/BOP SLOW SPEED (Step A7) CHECK Containment Hydrogen Mixing Fans -

RO/BOP RUNNING IN SLOW SPEED (Step A8) CHECK If Containment Spray should Be Actuated -

RO/BOP YES

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 23 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior RO/BOP (Step A8 RNO) START the 'A' Containment Spray Pump Manually actuate containment cooling by:

Critical CREW Starting the 'A' Containment Spray Pump before completion of Task Attachment A of E-0 (Step A9) CHECK If Main Steamlines Should Be Isolated: YES

• Containment pressure > 17 psig

• Steamline pressure - LESS THAN 615 PSIG B. Check MSIVs and Bypass valves CLOSED - NO RO/BOP b. FAST CLOSE all MSIVs and Bypass valves:

o AB HS79 o AB HS80 IF valve(s) will NOT fast close, THEN CLOSE MSIV(s) and bypass valves as necessary.

Critical CREW Isolate the faulted A SG before transition out of E-2 Task (Step A10) CHECK ECCS Valves - PROPER EMERGENCY RO/BOP ALIGNMENT (Step A11) CHECK Containment Isolation Phase A

a. ESFAS status panels CISA sections:

RO/BOP

• SA066X White lights - ALL LIT

• SA066Y White lights - ALL LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 1 rev 1 Event # 4, 5, 6, 7 Page 24 of 24 Event

Description:

Multiple Dropped Rods / Rx Trip / Steam Line Break inside containment /

MSIVs fail to close / Containment Spray Pump Auto Start Failure and Containment Spray Pump Discharge Valve Failure Proc /Time Position Applicants Actions or Behavior (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

RO/BOP

• SA066X White lights - ALL LIT

• SA066Y White lights - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation RO/BOP Isolation RO/BOP (Step A14) CHECK Containment Purge Isolation (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 2, rev. 1 Op-Test No.: 2014-1 Examiners: ____________________________ Operators: _____________________________

____________________________ _____________________________

____________________________ _____________________________

-8 Initial Conditions: 10 amps, Steady State Conditions.

Turnover: Startup is on hold due to an oil leak identified with NE02. NE02 is tagged out to work on the leak. It is unknown when it will be returned to service. On coming crew will be swapping Service Water Pumps for maintenance. The Outside OT has been briefed and is standing by to swap SW pumps.

Even Malf. No. Event Event t No. Type* Description 1 SRO (N) Start Service Water Pump C N/A BOP (N) Secure Service Water Pump A 2 SRO (C) RCS High Activity / Place 120 gpm Letdown in-service (Tech N/A RO (C) Spec) 3 SRO (I)

BBTE0421B Tavg Channel Failure - Loop 2 Tc fails high (Tech Spec)

RO (I) 4 SRO (C)

NB01_F Loss of NB01 (Tech Spec)

BOP (C) 5 SRO (C)

(SB) SB001 Reactor Trip RO (C) 6 SRO (M)

Lossofswitch RO (M) Loss of all AC Power yard.lsn BOP (M) 7 SRO (C)

PAL02_3 TDAFW fails to Auto Start BOP (C) 8 SRO (C)

PA50101_1 AEPs EDGs fail to Start BOP (C)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 3

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2

Scenario Event Description Callaway 2014 Scenario #2, rev. 0 The plant is operating at 10-8 amps, steady state power. NE02 is tagged out for an oil leak. It is unknown when it will be returned to service. On coming crew will be swapping Service Water Pumps for maintenance.

After the crew takes the watch, the crew will start C Service Water Pump and secure A Service Water Pump IAW OTN-EA-00001, Service Water System.

After the Service Water Pumps are swapped, a report from Chemistry indicates high activity in the RCS. The Crew will enter OTO-BB-00005, RCS High Activity and establish 120 gpm letdown flow IAW OTN-BG-00001 Addendum 04, Operation of CVCS Letdown. The CRS will evaluate Tech Spec 3.4.16.

After Tech Specs have been addressed for the RCS High Activity, Tcold Channel BB TE 421 B fails high. The crew will respond using OTO-BB-00004, RTD Channel Failure, and select an operable channel. The CRS will evaluate Tech Spec 3.3.1.

After the crew has addressed the Tcold Channel trip, NB01 will trip and lockout. The crew should enter OTO-NB-00001, Loss of Power to NB01. OTO-NB-00001 will direct the crew to secure NE01 and verify the electric plant line up.

After NE01 has been secured a Reactor Trip will occur. The crew should respond by entering E-0, Reactor Trip or Safety Injection. The crew will then transition to ES-0.1, Reactor Trip Response.

After the crew has transition to ES-0.1 and prior to Step 6 a Loss of Off Site Power will occur.

The crew will transition to ECA-0.0, Loss of All AC Power. The crew will manually start the TDAFW. When restoring power using EOP Addendum 39, Alternate Emergency Power Supply, the AEPs EDGs will not auto start and the operator must manually start the AEPs EDGs. After the AEPs EDGs are started power is restored to NB02.

The scenario can be terminated after power has been restored to NB02.

Scenario Event Description Callaway 2014 Scenario #2, rev. 0 Critical Tasks:

Critical Tasks Establish greater than 285,000 lbm/hr AFW flow rate to the SGs prior to SG dryout Energize at least one AC Emergency Bus prior to RCP seal degradation (greater than occurring. . (<10% WR on all SGs) 25 gpm per pump)

EVENT 6 7 Safety Failure to establish minimum AFW flow in this scenario is a violation of the basic In the scenario, failure to energize at least one ac emergency bus results in the significance objective of ECA-0.0 and of the assumptions of the analyses upon which ECA-0.0 is needless continuation of a situation in which the pumped ECCS capacity and the based. Without AFW flow, the SGs could not support any significant plant cooldown. emergency power capacity are both in a completely degraded status, as are all other Thus, the crew would lose the ability to delay the adverse consequences of core active safeguards requiring electrical power. Although the completely degraded status is uncovery. not due to the crew's action (was not initiated by operator error), continuation in the completely degraded status is a result of the crew's failure to energize at least one ac emergency bus.

Cueing Both of the following: Indication and/or annunciation that all ac emergency buses are de-energized

• Indication of Station Blackout

• Bus energized lamps extinguished AND

• Circuit breaker position

• Less than 285,000 lbm/hr AFW flow to the SGs

• Bus voltage

• EDG status Performance Manipulation of the: Manipulation of controls as required to energize at least one ac emergency bus from the indicator

• TDAFW Steam Supply valve(s): AEPS

• AB HIS5A (SG B)

• Using PBXY0001 CLOSE AEPS FDR BKR PB0502 TO NB0214

• AB HIS6A (SG C) o PB0502

• TDAFP Mechanical Trip/Throttle valve:

• CLOSE NB02 AEPS SUPPLY BKR NB0214

• FC HIS312A o NB HIS-68 Performance Crew will observe greater than 285,000 lbm/hr AFW flow to the SGs. Indication that NB02 is energized feedback

• NB02 Bus energized light

• NB02 bus voltage Justification for Without AFW flow, decay heat would open the SG safety valves and would rapidly Failure to perform the critical task also results in needless degradation of any barrier to the chosen deplete the SG inventory, leading to a loss of secondary heat sink, or SG dryout. Decay fission product release, specifically of the RCS barrier at the point of the RCP seals.

performance limit heat would then increase RCS temperature and pressure until the pressurizer PORVs Failure to perform the critical task means that RCS inventory lost through the RCP seals open, imposing a larger LOCA than RCP seal leakage. cannot be replaced. It also means that the RCP seals remain without cooling and gradually deteriorate. As the seals deteriorate the rate of RCS inventory loss increases.

25 gpm per pump is the limit used in Section 8.3A.3 CALLAWAY STATION BLACKOUT DURATION (Table 8.3A-1 Section D)

PWR Owners CT - 23, Establish AFW flow during SBO CT - 24, Energize at least one ac emergency bus Group Appendix

Scenario Event Description Callaway 2014 Scenario #2, rev. 0 References OTN-EA-00001, Service Water System OTO-BB-00005, RCS High Activity OTN-BG-00001 Addendum 04, Operation of CVCS Letdown OTO-BB-00004, RTD Channel Failure OTO-NB-00001, Loss of Power to NB01 E-0, Reactor Trip or Safety Injection ES-0.1, Reactor Trip Response ECA-0.0, Loss of All AC Power EOP Addendum 39, Alternate Emergency Power Supply PRA Systems, Events or Operator Actions

1. Station Blackout (T(1S))

a. Manually Operate TDAFW pump

b. AEPS used to power AC Bus

Scenario Event Description Callaway 2014 Scenario #2, rev. 0 Scenario Setup Guide:

-8 Establish the initial conditions of IC-164, MOL 10 amps:

• RCS boron concentration 1367 ppm

• CCP A 1372 ppm minus 2 days

• CCP B 1370 ppm minus 1 days

• Rod Control Bank D 105 steps, Other banks 228 steps

• NE02 is tagged out with breaker in P-T-L and tag on handswitch

• Ensure A and B SW pumps running with C SW pump in STBY

• Ensure A CCW pump is running, suppling the service loop

• NCP recirc should be open < 100 gpm

• SB-S701 A and B should be NORMAL

=======SCENARIO PRELOADS / SETUP ITEMS==========

Decay Heat

• Plant parameters, (BB) RRSPDDH - current 1 NE02 is tagged out for an LCO

• Remote Function (KJ) DGBLOCK_2, Block_Both

• Remote Function (KJ) KJHS0109, Local_Manual

• ME Schematic (NE) e23nell_b, NE15NB0211_BKRTA_BKPOS, Value=3 TDAFW failure to auto start

• Insert Remote Function (AL) PAL02_3, Value = 1 AEPS EDG fail to start

• Insert Malfunction (PA) PA50101_1, Value = 1

======= EVENT 1 ============================

Start Service Water Pump C and Secure Service Water Pump A No malfunction

======= EVENT 2 ============================

RCS High Activity / Place 120 gpm Letdown in-service No malfunction

=======EVENT 3 ============================

Tavg Channel Failure - Loop 2 Tc

• Insert Malfunction (BB) BBTE0421B, Value = 630

=======EVENT 4 ============================

Loss of NB01

• Insert Malfunction (NB) NB01_F, Value=Fault

=======EVENT 5 ======================

Reactor Trip

• Insert Malfunction (SB) SB001, Value=Enable

=======EVENT 6 PRELOADED=================

Loss of all AC Power

• Run lesson: All/Generic/lossofswitchyard.lsn

=======EVENT 7 PRELOADED=================

TDAFW fails to Auto Start SEE PRELOADS ABOVE

=======EVENT 8 PRELOADED=================

AEPS EDG fail to start SEE PRELOADS ABOVE

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 1 Page 6 of 38 Event

Description:

Start Service Water Pump C and Secure Service Water Pump A Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 0 minutes or at the discretion of the Lead Examiner

• Per the turnover the crew was directed to start C Service Water pump and secure A Service Water pump per OTN-EA-00001, Service Water System

• If contacted as the Outside OT to ensure service water pump oil sightglass is filled to the normal level indication wait 5 minutes and report The oil sightglass is filled to the normal level

• Respond as the Outside OT for:

o Step 5.3.1 to ENSURE switch for Service Water Pump to be started is RESET:

CSTEA2101C, CTRL STA FOR S.W. PUMP C Wait 1 minute and respond CSTEA2101C, CTRL STA FOR S.W. PUMP C is RESET o Step 5.3.2 OPEN the applicable Strainer Differential Pressure Switch Equalizing Valve:

VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE.

Wait 1 minute and respond VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE is OPEN o Step 5.3.2 CLOSE the applicable Strainer Differential Pressure Switch Equalizing Valve:

VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE.

Wait 1 minute and respond VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE is CLOSED o Step 5.4.8 IF any service water pumps are in NAS, ENSURE CSEA2102, SERV WTR PMPS AUTO BACK-UP SELECTOR SW, (on CPEA2107, SERVICE WATER VALVE CONTROL CABINET) is in AUTO.

Wait 1 minute and respond CSEA2102, SERV WTR PMPS AUTO BACK-UP SELECTOR SW is in AUTO.

• If contacted as the Outside OT to check is C SW pump is running normally wait 2 minutes and report C SW pump is running normally OTN-EA-00001, Service Water System Implement OTN-EA-00001, Service Water System to start C CRS Service Water pump and secure A Service Water pump OTN-EA- (Precautions and Limitations) CRS reviews Precautions and CRS 00001 Limitations CRS (Prerequisites) CRS reviews and verifies Prerequisites are met.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 1 Page 7 of 38 Event

Description:

Start Service Water Pump C and Secure Service Water Pump A Proc /Time Position Applicants Actions or Behavior (Section 5.3) Direct the BOP to start the C Service Water CRS pump using section 5.3 and secure A Service Water pump using section 5.4.

(CAUTION) Any Service Water Pump Lockout or Pump/Bus Lockout/Undervoltage will result in one of the following:

• Cause an auto start of an idle pump if in STANDBY, provided CSEA2102 is in AUTO.

• Prevent normal shutdown of a running pump.

(Step 5.3.1) ENSURE switch for Service Water Pump to be BOP started is RESET:

• CSTEA2101C, CTRL STA FOR S.W. PUMP C (Step 5.3.2) START a service water pump as follows:

a. OPEN the applicable Strainer Differential Pressure Switch Equalizing Valve:

• VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE.

b. Using the applicable switch below, START the desired BOP service water pump and ENSURE the associated discharge valve opens.

• PBHIS12303, SERV WATER PUMP C

c. CLOSE the applicable Strainer Differential Pressure Switch Equalizing Valve:

• VEA2168C, STRAINER DIFF PRESS SW PRESS EQUAL VALVE.

(Step 5.3.3) IF three service water pumps are operating, Go To BOP Section 5.4 to secure the selected pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 1 Page 8 of 38 Event

Description:

Start Service Water Pump C and Secure Service Water Pump A Proc /Time Position Applicants Actions or Behavior (Step 5.4.1) IF swapping Service Water Pumps, ENSURE the BOP replacement pump is started prior to securing the pump to be replaced.

(Step 5.4.2) ENSURE sufficient SW/ESW pumps are available BOP to maintain cooling to system loads.

(NOTE) Service Water provides lube water to the Circulating NOTE Water pumps.

BOP (5.4.3) This step is N/A (Caution) Any Service Water Pump Lockout or Pump/Bus Lockout/Undervoltage will result in one of the following:

• Cause an auto start of an idle pump if in STANDBY, provided CSEA2102 is in AUTO.

• Prevent normal shutdown of a running pump.

BOP (Step 5.4.4) This step is N/A (Step 5.4.5) Using the applicable switch below, SECURE the BOP desired Service Water Pump:

• PBHIS12104 , SERV WATER PUMP A (Step 5.4.6) CHECK SW/ESW component parameters to BOP ensure adequate cooling flow exists.

BOP (Step 5.4.7) This step is N/A

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 1 Page 9 of 38 Event

Description:

Start Service Water Pump C and Secure Service Water Pump A Proc /Time Position Applicants Actions or Behavior (Step 5.4.8) IF any service water pumps are in NAS, ENSURE CSEA2102, SERV WTR PMPS AUTO BACK-UP SELECTOR BOP SW, (on CPEA2107, SERVICE WATER VALVE CONTROL CABINET) is in AUTO.

BOP (Step 5.4.9) This step is N/A NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 2 Page 10 of 38 Event

Description:

RCS High Activity / Place 120 gpm Letdown in-service Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 15 minutes or at the discretion of the Lead Examiner

• Call Control room as Chemistry and inform the CRS that the RCS sample indicates 4 micro curies per gram of I-131with a rising trend.

• If crew does not enter OTO-BB-00005 within 5 minutes of receiving this report, call as the Shift Manager and prompt the crew to increase letdown to 120 gpm.

• Respond as Chemisrty

• Respond as RP

• Respond as Duty Manager Indications Available:

T= 15 Call from Chemistry Lab OTO-BB-00005, RCS Activity CRS Implement OTO-BB-00005, RCS Activity OTO-BB- (Step 1) MAXIMIZE Letdown Flow Through CVCS Letdown Mixed RO 00005 Bed Demineralizer Directs changing letdown from 75 gpm to 120 gpm per OTN-BG-CRS 00001 ADD 04, Operation of CVCS Letdown Step 5.6 OTN-BG-(Precautions and Limitations) CRS reviews Precautions and 00001 CRS Limitations ADD 04 CRS (Prerequisites) CRS reviews and verifies Prerequisites are met.

(NOTE) To prevent flashing at the Letdown orifices, letdown temperature must be maintained less than or equal to 350°F on BG TI-127, REGEN HX LTDN OUTLET TEMP.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 2 Page 11 of 38 Event

Description:

RCS High Activity / Place 120 gpm Letdown in-service Proc /Time Position Applicants Actions or Behavior (CAUTION) Changes in letdown temperature affect Core reactivity.

Therefore, when changing letdown flow rates, operation of BG TK-130, LTDN HX OUTLET TEMP CTRL, should be closely monitored such that letdown temperature per BG TI-130, LTDN HX OUTLET TEMP, is slowly changed following letdown flow changes.

A significant temperature rise at the Regenerative Hx. Outlet can cause leakage through BG8117, CVCS LTDN HDR PRESS RLF.

BOP (Step 5.6.1) INFORM Chemistry letdown flow is being changed.

(Step 5.6.2) ENSURE Pressurizer Backup Heaters are in Manual RO Heater Operation per OTN-BB-00005, Pressurizer And Pressurizer Pressure Control.

(Step 5.6.3) RAISE charging flow to 115 to 120 gpm using one of the following controllers:

RO

• IF NCP is in service, ADJUST BG FK-124, NCP DISCH FLOW CTRL (Step 5.6.4) IF NCP is in service, WHEN flow indicated at BG FI RO 0121A, CHG HDR FLOW, is greater than 100 gpm, CLOSE BGHV8109 using BG HIS 8109, NCP RECIRC VLV.

(Step 5.6.5) ADJUST BG HC-182, CHG HDR BACK PRESS CTRL, to maintain seal injection flow of approximately 8 gpm per pump, as indicated on:

BOP

• BG FR-154, RCP D SEAL LEAKOFF & INJ FLOW

• BG FR-155, RCP C SEAL LEAKOFF & INJ FLOW

• BG FR-156, RCP B SEAL LEAKOFF & INJ FLOW

• BG FR-157, RCP A SEAL LEAKOFF & INJ FLOW (Step 5.6.6) PLACE BG PK-131, LTDN HX OUTLET PRESS RO CTRL, in MANUAL and ADJUST output to control pressure on BG PI-131, LTDN HX OUTLET PRESS, at approximately 190 psig.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 2 Page 12 of 38 Event

Description:

RCS High Activity / Place 120 gpm Letdown in-service Proc /Time Position Applicants Actions or Behavior (Step 5.6.7) Using BG HIS-8149AA, LTDN ORIFICE A VLV, OPEN RO 45 gpm Letdown orifice.

(Step 5.6.8) MONITOR pressure at BG PI-131, LTDN HX OUTLET PRESS, and:

a. IF required, SLOWLY ADJUST BG PK-131, LTDN HX OUTLET PRESS CTRL, to control pressure at RO approximately 350 psig.

b. WHEN letdown flow and pressure have stabilized, AND BG PI-131 is reading 350 psig, PLACE BG PK-131 in AUTO.

RO (Step 5.6.9) CHECK BG TI-130, LTDN HX OUTLET TEMP.

(Step 5.6.10) IF required, slowly adjust potentiometer on BG TK-RO 130, LTDN HX TEMP CTRL (3.0 to 4.3 turns) to control temperature at 95°F to 115°F.

(Step 5.6.11) PLACE in MANUAL and ADJUST BB LK-459, PZR RO LEV MASTER CTRL, to obtain an output of 64 to 68 %.

(Step 5.6.12) IF NCP is in service, PLACE BG FK-121, CCP RO DISCH FLOW CTRL, in MANUAL and ADJUST to 25 % demand.

(Step 5.6.13) WHEN pressurizer level is being maintained at program level, PLACE the following in AUTO as required:

RO

• BG FK-121, CCP DISCH FLOW CTRL

• BG FK-124, NCP DISCH FLOW CTRL

• BB LK-459, PZR LEV MASTER CTRL (Step 5.6.14) RESTORE Pressurizer Backup Heaters to Automatic Heater Operation per RO OTN-BB-00005, Pressurizer And Pressurizer Pressure Control.

(NA due to Startup)

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 2 Page 13 of 38 Event

Description:

RCS High Activity / Place 120 gpm Letdown in-service Proc /Time Position Applicants Actions or Behavior OTO-BB- (Note) RCS coolant and seal injection filters D/P will rise if a crud 00005 burst has occurred.

BOP (Step 2) MONITOR D/P On RCS Coolant And Seal Injection Filters CRS (Step 3) DIRECT Chemistry To Sample RCS For Activity BOP (Step 4) NOTIFY Radiation Protection Of Rising RCS Activity (Step 5) DIRECT Chemistry To Determine If Decontamination Factor (DF) of CVCS Letdown Mixed Bed Demineralizer Is CRS Acceptable Per CDP-ZZ-00800, Callaway Resin Monitoring Program (Step 6) CHECK DF Of Inservice CVCS Letdown Mixed Bed BOP Demineralizer - ACCEPTABLE (Step 7) REVIEW Technical Specification 3.4.16 CRS TS 3.4.16 Condition A is applicable NOTE After 120 gpm letdown has been established, TS identified and at Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 3 Page 14 of 38 Event

Description:

Tavg Channel Failure - Loop 2 Tc (TS)

Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 25 minutes or at the discretion of the Lead Examiner Tavg Channel Failure - Loop 2 Tc (TS)

• Insert Malfunction (BB) BBTE0421B, Value = 630

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure. Tripping of Bistables will not be performed this shift.

• When contacted, respond as Duty Manager. Acknowledge entry into the OTO Indications Available:

T= 25 Ann 67B LOOP 2 T LO DEV Ann 66D LOOP 2 TAVG LO Ann 68D LOOP 3 TAVG LO Ann 69D LOOP 4 TAVG LO Ann 65C AUCT T AVG HI Ann 65E TREF/TAUCT LO (and others)

OTO-BB-00004, RTD Channel Failure CRS Implement OTO-BB-00004, RTD Channel Failure OTO-BB-RO (Step 1) Place Rod Control in Manual 00004 RO (Step 2) Check RCS Loop NR Tavg and Delta-T Indicator FAILED (Step 3) Select T and Tavg Channel Defeat switches to failed RO Channel

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 3 Page 15 of 38 Event

Description:

Tavg Channel Failure - Loop 2 Tc (TS)

Proc /Time Position Applicants Actions or Behavior (Step 4) Check RCS Tavg Within 1.5°F of Tref (potential RNO)

RESTORE RCS Tavg to within 1.0°F of Tref using any of the RO following:

• ADJUST Control Rods.

• ADJUST Turbine load.

• ADJUST RCS Boron concentration.

(Step 5) Check Rod Control in Auto (potential RNO)

RO WHEN RCS Tavg is stable within 1.0°F of Tref AND Shift Manager/Control Room Supervisor concurs, THEN PLACE Rod Control in Auto.

CRS (Step 6) Check PZR Level Trending to or At Program Level (Step 7) Select an Operable Channel for the OPT/OTT BOP Temperature recorder (Step 8) Review Attachment A for effects of RCS RTD Instrument RO failure (Step 9) Review Applicable Technical Specifications, Refer to CRS Attachment J TS 3.3.1 Cond E, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (Step 10) Direct I&C to Trip The Protective Bistables for the Failed CRS Channel within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of the Channel Failure.

CRS (Step 11) Place the Inoperable RCS NR RTD Channel in the EOSL CRS (Step 12) Initiate Actions to Repair the Failed Channel

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 3 Page 16 of 38 Event

Description:

Tavg Channel Failure - Loop 2 Tc (TS)

Proc /Time Position Applicants Actions or Behavior CRS (Step 13) Perform notifications per ODP-ZZ-00001, Add. 13 NOTE After the Technical Specification is identified and at Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 17 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 35 minutes or at the discretion of the Lead Examiner Loss of NB01

• Insert Malfunction (NB) NB01_F, Value=Fault

• When contacted, respond as Duty Manager as requested

• If contacted as the Secondary OT to investigate Loss of NB01 wait 5 minutes and respond NB01 and the feeder breaker are locked out and NB0112 has an instantaneous overcurrent

• If contacted as an OT to investigate TDAFP wait 3 minutes and respond The TDAFP appears normal

• If contacted as an OT to close, EGHV0015, CCW Train A Supply/Return Isolation (AB2026, RM1408) and EGHV0053, CCW Train A Supply Isolation (AB2026, RM1402), wait 5 minutes and report them closed

• When contacted as an OT to:

o PLACE NE01 Local Master Transfer Switch to LOCAL/MAN position and PRESS DG train A local STOP pushbutton to stop the EDG, wait 3 minutes and respond NE01 Local Master Transfer Switch is in LOCAL/MAN position and A DG has been stopped o Insert Remote KJ HS0009 local and KJ HS0008B Indications Available:

T=30 ANN 18A, NB01 Bus Lockout ANN 18B, NB01 Bus UV ANN 19A, XNB01 Xfmr Lockout ANN 19B, NB01 Bus Dgrd Volt Multiple other alarms OTO-NB-00001, Loss of Power to NB01 OTO-NB-CRS Implement OTO-NB-00001, Loss of Power to NB01 00001

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 18 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior (Step 1) CHECK 4160 VAC Bus NB01 DEENERGIZED

• 4.16 KV Bus NB01 light EXTINGUISHED BOP o NB ZL5

• 4.16 KV Bus NB01 Voltage indicates zero o NB EI1 (Note) The Auxiliary Feedwater Pump(s) remain operable with its discharge valves closed or throttled in order to maintain SG levels when started due to an AFAS. (RFR 010782A, RFR 010782C)

(Step 2) CHECK Turbine Driven Auxiliary Feedwater Pump BOP SECURED NOTE The TDAFW pump SHOULD have started. The crew should recognized this and continue on in the procedure.

(Step 3) CHECK Reactor Power LESS THAN 100%

• SE NI41B

• SE NI42B

• SE NI43B RO

• SE NI44B

• BB TI411A (T)

• BB TI421A (T)

• BB TI431A (T)

• BB TI441A (T)

(Note) RCPs that lose Seal Injection AND CCW To Thermal Barrier Heat Exchanger must have at least one restored within 6 minutes or the RCP MUST be secured.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 19 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior (Step 4) CHECK CCW Pump B Or D RUNNING - NO

• EG HIS22

• EG HIS24 RNO BOP START one of the following:

• CCW Pump B OR

• CCW Pump D (Step 5) CHECK CCW Service Loop Is Being Supplied From Train B: - NO

• EG ZL54 OPEN - NO

• EG ZL16 OPEN - NO RNO PERFORM The Following:

a. CLOSE both CCW Surge Tank Vent Control valves:

• EG HIS9

• EG HIS10

b. OPEN CCW Train B Supply/Return valves:

• EG HS16 BOP c. OPEN ESW Train B to CCW Hx B:

• EF HIS52

d. DISPATCH an operator to locally close the following valves:

• EGHV0015, CCW Train A Supply/Return Isolation (AB2026, RM1408)

• EGHV0053, CCW Train A Supply Isolation (AB2026, RM1402)

e. WHEN EGHV0015 and EGHV0053 are closed, THEN OPEN both CCW Surge Tank Vent Control Valves:

• EG HIS9

• EG HIS10 BOP (Step 6) CHECK If CCW aligned to the RCPs

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 20 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior (Step 7) CHECK RHR IN SERVICE PRIOR TO EVENT BOP RNO - Go To Step 10.

(Step 10) CHECK Steam Generator NR Level Within One Of The Following:

BOP

• Trending to between 45% and 55%

OR

• Between 45% and 55%

(Step 11) CHECK Pressurizer Level Within One Of The Following:

• Trending to Program Level RO OR

• At Program Level (Step 12) CHECK Pressurizer Pressure Within One Of The Following:

RO

• Trending to between 2220 psig and 2250 psig OR

• Between 2220 psig and 2250 psig

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 21 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior (Step 13) ENSURE the following 4160 VAC bus NB01 loads shed:

(LSELS actuation, handswitch light green):

• ESW Pump A:

o EF HIS55A

• CCW Pump A/C:

o EG HIS21 BOP o EG HIS23

• SI Pump A:

o EM HIS4

• Ctmt Spray Pump A:

o EN HIS3

• RHR Pump A:

o EJ HIS1 (Step 14) OPEN NB01 Normal And Alternate Feeder Breakers:

BOP

• NB HIS2, NB01 Normal Supply Breaker NB0112

• NB HIS3, NB01 Alternate Supply Breaker NB0109 (Note) Attachment B, Diesel Generator A Engine Shutdown Relay, may be used as an aid.

BOP (Step 15) CHECK EDG A RUNNING (Note)

• Attachment C, Requirements For Auto Closure Of NE01 Output Breaker, may be used as an aid.

• Attachment D, NE01 Output Breaker Trips, may be used as an aid.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 22 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior (Step 16) CHECK NB01 Emergency Supply Breaker CLOSED

• NE HIS25 RNO PERFORM the following:

a. N/A due to lockout

b. IF EDG A is running AND ESW flow cannot be established to EDG A, THEN PERFORM the following:

BOP

1) PLACE NE01 Local Master Transfer Switch to LOCAL/MAN position:

• KJ HS9

2) PRESS DG train A local STOP pushbutton to stop the EDG:

• KJ HS8B (Note) 'A' Train CCW pump handswitches are placed in PullToLock to prevent breaker cycling while NB01 is deenergized.

(Step 17) CHECK 4160 VAC Bus NB01 ENERGIZED RNO Perform the following:

Place 'A' CCW Train Pump handswitches in PullToLock until BOP power is restored to NB01

• EG HIS21

• EG HIS23 (Step 18) CHECK NCP Or CCP B RUNNING

• BG HIS3 (NCP)

RO OR

• BG HIS2A (CCP B)

(Step 19) CHECK RCP Seal Injection Flow BETWEEN 8 GPM BOP AND 13 GPM PER PUMP BOP (Step 20) CHECK Any Service Air Compressor RUNNING

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 4 Page 23 of 38 Event

Description:

Loss of NB01 Proc /Time Position Applicants Actions or Behavior Evaluate Tech Specs:

The most restrictive T.S. for this condition are either:

• 3.8.1.H, Three or more AC sources inoperable.

CRS

• H.1 Enter LCO 3.03 Immediately

• 3.7.5.E, Three AFW trains inoperable

• (The allowance of 3.8.1.B.2 provides 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> before 3 AFW pumps must be declared inoperable)

CUE Any time after NE01 is secured and at Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 5 Page 24 of 38 Event

Description:

Reactor Trip Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 50 minutes or at the discretion of the Lead Examiner Reactor Trip

• Insert Malfunction (SB) SB001, Value=Enable Loss of all AC (Inserted AFTER the entry into ES-0.1 and prior to step 6 of ES-0.1 or if the Crew attempt to transition to FR-H.1 and at the discretion of the Lead Evaluator)

• Run lesson: All/Generic/lossofswitchyard.lsn TDAFW Pump fails to AUTO Start

• PRELOADED

• When contacted, respond as Duty Manager.

• When contacted as Radiation Protection, respond as requested.

• When contacted as Chemistry, respond as requested.

• When contacted as the STA, respond as requested.

• When contacted as Transmission, respond It is unknown when power will be restored.

• When contacted as the Field Supervisor, respond as requested.

• When contacted as an OT to perform various EOP Addendums, respond as requested.

• When contacted as an OT to locally CLOSE CST Makeup to Hotwell Isolation, APV0012, wait 3 minutes and respond CST Makeup to Hotwell Isolation, APV0012 is CLOSED Indications Available:

T=50 All rod bottom lights lit E-0, Reactor Trip or Safety Injection E-0 CRS Implement E-0, Reactor Trip or Safety Injection Note Steps 1 through 4 are immediate actions.

(Step 1) CHECK Reactor Trip

• Rod Bottom Lights - All Lit RO

• Reactor Trip and Bypass Breakers - Open

• Neutron Flux - Lowering (Step 2) CHECK Turbine Trip BOP

a. Turbine Stop Valves - Closed

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 5 Page 25 of 38 Event

Description:

Reactor Trip Proc /Time Position Applicants Actions or Behavior E-0 (Step 3) CHECK Power to AC Emergency Buses BOP a. At Least One Emergency Bus - Energized

b. Both Emergency Buses - NO NOTE (Step 4) CHECK SI Status

a. Check if SI is Actuated - NO RO IF SI is NOT required, THEN Go To ES0.1, Reactor Trip Response, Step 1.

CRS Transitions to ES-0.1, Reactor Trip Response ES-0.1 (Step 1.a) CHECK RCS Temperature Control:

a. CHECK RCPs - ANY RUNNING - NO RNO

a. TRANSFER Condenser Steam Dump to Steam Pressure Mode:

1) Check Condenser AVAILABLE

• C9 interlocks LIT BOP

• MSIVs ANY OPEN

2) PLACE Steam Header Pressure Controller in MANUAL and ZERO OUTPUT:

• AB PK507

3) PLACE Steam Dump Select switch in STM PRESS position: (no action needed due to startup)

4) PLACE Steam Header Pressure Controller in AUTO:

• AB PK507 (Step 1.b) CHECK RCS temperature response - NORMAL RCS COLD LEG BOP TEMPERATURES STABLE AT OR TRENDING TO 557°F IF NO RCP RUNNING

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 5 Page 26 of 38 Event

Description:

Reactor Trip Proc /Time Position Applicants Actions or Behavior (Step 2) CHECK Status Of AC Buses:

a. CHECK Generator Output Breakers - OPEN

• MA ZL-3A (V55)

• MA ZL-4A (V53)

b. CHECK All AC Buses - ENERGIZED BY OFFSITE POWER

• PA01

• PA02

• NB01, (Locked out)

• NB02 RNO PERFORM the following:

BOP

1) ENSURE both PZR PORVs are in AUTO unless closed due to low PZR pressure:

• BB HIS-455A

• BB HIS-456A

2) ENSURE both PORV Block Valves are energized and OPEN unless closed to isolate an open PORV:

• BB HIS-8000A (NG01BBR3)

• BB HIS-8000B (NG02BDF1)

3) IF any AC emergency bus(es) are NOT energized by offsite power, THEN ENSURE DGs have assumed the following loads: (NA - NE02 tagged out and NB01 locked out)

(Step 3) CHECK PZR Pressure Control:

RO/BOP a. Pressure - GREATER THAN 1849 psig

b. Pressure - STABLE AT OR TRENDING TO 2235 PSIG

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 2 rev.0 Event # 5 Page 27 of 38 Event

Description:

Reactor Trip Proc /Time Position Applicants Actions or Behavior (Step 4) CHECK PZR Level Control:

a. PZR Level - GREATER THAN 17%

b. CHECK Instrument Air Supply Containment Isolation valve - OPEN RO

• KA HIS-29

c. CHECK charging - IN SERVICE

d. CHECK letdown - IN SERVICE

e. PZR level - TRENDING TO 25%

(Step 5) CHECK Shutdown Reactivity Status:

a. CHECK all control rods - FULLY INSERTED RO/ b. CHECK if uncontrolled RCS dilution - IN PROGRESS RNO Go to Step 6 CUE After completion of Step 5 and prior to Step 6 of ES-0.1 Run lesson: All/Generic/lossofswitchyard.lsn when directed by the Lead Evaluator

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 28 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior ECA-0.0, Loss of All AC Power Recognizes loss of all AC power though direct observation or CRS reports from RO and BOP. Transitions to ECA-0.0, Loss of All AC Power ECA-0.0 (Note)

• Steps 1 and 2 are immediate action steps.

• CSF status trees should be monitored for information only.

Functional Restoration Procedures should NOT be implemented.

(Step 1) CHECK Reactor Trip:

RO

• Reactor Trip and Bypass Breakers OPEN

• Neutron Flux LOWERING (Step 2) CHECK Turbine Trip:

BOP

a. All Turbine Stop valves CLOSED (Step 3) CHECK If RCS Is Isolated:

a. Letdown isolation valves CLOSED

1) Letdown Orifice Isolation valves:

• BG HIS8149AA RO

• BG HIS8149BA

• BG HIS8149CA

2) RCS Letdown to Regen HX valves:

• BG HIS459

• BG HIS460

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 29 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 3 continued) CHECK If RCS Is Isolated:

b. PZR PORVs CLOSED

• BB HIS455A

• BB HIS456A

c. RCS To Excess Letdown HX valves CLOSED

• BG HIS8153A

• BG HIS8154A RO/BOP

• BG HIS8153B

• BG HIS8154B

d. Reactor Head Vent Valves CLOSED

• BB HIS8001A

• BB HIS8002A

• BB HIS8001B

• BB HIS8002B (Step 4) CHECK AFW Flow GREATER THAN 285,000 LBM/HR RNO PERFORM the following:

a. CHECK TDAFW Pump running.

IF TDAFW Pump is NOT running, THEN START TDAFW Pump:

BOP a) OPEN AFP Turbine Loop Steam Supply valve(s):

• AB HIS5A (SG B)

• AB HIS6A (SG C) b) OPEN TDAFP Mechanical Trip/Throttle valve:

• FC HIS312A Critical Establish greater than 285,000 lbm/hr AFW flow rate to the CREW Task SGs prior to SG dryout occurring. (<10% WR on all SGs)

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 30 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 5) TRY To Restore Power to Any AC Emergency Bus:

a. ENERGIZE AC emergency bus with diesel generator: - NO

b. CHECK AC emergency buses AT LEAST ONE ENERGIZED - NO

c. CHECK ESW Pump associated with energized AC emergency bus(es) RUNNING RNO BOP d) IF NO AC emergency bus is energized, THEN PERFORM the following:

1. OPEN Control Room cabinet doors using EOP Addendum 20, Control Room Cabinet Door List.

CUE: Another operator will perform EOP Addendum 20.

2. Go To Step 6. OBSERVE CAUTIONS prior to Step 6.

(Caution)

• When power is restored to any AC emergency bus, recovery actions should continue starting with Step 24.

• If an SI signal exists or if an SI signal is actuated during this procedure, it should be reset to permit manual loading of equipment on AC emergency bus(es)

• An ESW pump should remain available (NOT locked out) to automatically load on its energized AC emergency bus to provide diesel generator cooling.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 31 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 6) PLACE Following Equipment Switches In PULLTOLOCK Position:

• CCPs:

o BG HIS1A o BG HIS2A

• SI Pumps:

o EM HIS4 o EM HIS5

• RHR Pumps:

o EJ HIS1 o EJ HIS2

• Containment Spray Pumps:

o EN HIS3 o EN HIS9

• CCW Pumps:

o EG HIS21 BOP o EG HIS22 o EG HIS23 o EG HIS24

• Containment Cooler Fans:

o GN HIS5 o GN HIS9 o GN HIS13 o GN HIS17

• Motor Driven AFW Pumps:

o AL HIS22A o AL HIS23A

• Control Room AC Unit:

o GK HIS29 o GK HIS40

• Class 1E Electrical Equipment Room AC Unit:

o GK HIS100 o GK HIS103

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 32 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 7) RESTORE AC Power:

a. CHECK if offsite power source AVAILABLE - NO

2. CONSULT Power Supervisor and Transmission Dispatcher for status and assistance in restoring an BOP offsite power source. IF offsite power is NOT available, THEN RESTORE power to one NB Bus using:

• EOP Addendum 39, Alternate Emergency Power Supply (page 33 of scenario)

(Step 8) Locally ISOLATE RCP Seals Using EOP Addendum 22, CRS Local RCP Seal Isolation (direct OT to perform this task)

(Step 9) CHECK If CST Is Isolated From Hotwell:

a. PLACE condenser hotwell level controllers in MANUAL and ZERO OUTPUT:

• Condensate Reject To CST Controller:

RO

• AD LIC79A

• Condenser Hotwell Makeup Level Controller:

• AD LIC79B

b. Locally CLOSE CST Makeup To Hotwell Isolation:

• APV0012

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 33 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 10) CHECK SG Status:

a. MSIVs and Bypass valves CLOSED

b. Main Feedwater Reg Valves - CLOSED

• AE ZL510 (SG A)

• AE ZL520 (SG B)

• AE ZL530 (SG C)

• AE ZL540 (SG D)

b. Main Feedwater Reg Bypass Valves - CLOSED

• AE ZL550 (SG A)

• AE ZL560 (SG B)

• AE ZL570 (SG C)

RO

• AE ZL580 (SG D)

c. Feedwater Isolation Valves - CLOSED

• AE HIS39 (SG A)

• AE HIS40 (SG B)

• AE HIS41 (SG C)

• AE HIS42 (SG D)

b. SG Blowdown Isolation valves - CLOSED

• BM HIS1A (SG A)

• BM HIS2A (SG B)

• BM HIS3A (SG C)

• BM HIS4A (SG D)

EOP Addendum 39, Alternate Emergency Power Supply Directs use of EOP Addendum 39, Alternate Emergency Power CRS Supply, to energize NB02 EOP (Caution) The Diesels from the Alternate Emergency Power ADD 39 Supply (AEPS) are designed to support only one AC Emergency Bus at a time. Central Electric Power Reform Substation may be able to supply power to both AC Emergency Buses depending on power reserves

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 34 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Note)

• Figure A, Alternate Emergency Power Supply One Line Diagram, is available for reference.

• Attachment F, AEPS Diesel Generator Alarms and Trips, is available for reference.

(Step 1) EVALUATE Plant Status To Determine Which AC CRS/BOP Emergency Bus To Energize: NB02 (Step 2) ALIGN AC Emergency Buses For Alternate Emergency Power Supply

a. PLACE NB01 Emergency Supply Breaker NB0111 in PULL-TO-LOCK

• NE HIS-25

b. PLACE NB01 Alternate Supply Breaker NB0109 in PULL-TO-LOCK

• NB HIS-3

c. PLACE NB01 Normal Supply Breaker NB0112 in PULL-TO-LOCK

• NB HIS-2

d. PLACE NB02 Normal Supply Breaker NB0209 in PULL-TO-LOCK BOP

• NB HIS-4

e. PLACE NB02 Alternate Supply Breaker NB0212 in PULL-TO-LOCK

• NB HIS-5

f. PLACE NB02 Emergency Supply Breaker NB0211 in PULL-TO-LOCK

• NE HIS-26

g. PLACE NB02 AEPS Supply Breaker NB0214 in PULL-TO-LOCK

• NB HIS-68

h. PLACE NB01 AEPS Supply Breaker NB0114 in PULL-TO-LOCK

• NB HIS-67

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 35 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step 3) PERFORM Applicable Attachment As Necessary:

b. NB02 BOP a) Attachment B, Energizing NB02 From Alternate Emergency Power Supply (AEPS), Step B1 (Step B1) CHECK PB05 - ENERGIZED

a. CHECK PB05 Energized by Central Electric Power Reform Substation - NO BOP RNO If PB05 does not have power Go To Attachment C, Placing Alternate Emergency Power Supply DGs on PA501 Bus, Step C1 (Step C1) Using PBXY0001 PLACE AEPS FDR BKR TO PA501 BOP VIA Central Electric Reform Feeder Breaker To XFMR - OPEN

• PA50101 (Step C2) Using PBXY0001 CHECK ALL AEPS D/G - RUNNING

• EDGPA5001, AEPS D/G #1 BOP

• EDGPA5002, AEPS D/G #2

• EDGPA5003, AEPS D/G #3

• EDGPA5004, AEPS D/G #4 (Step C3) Using PBXY0001 CHECK ALL Running AEPS D/G Output Breakers - CLOSED:

• PA50104, AEPS FDR BKR TO EDGPA5001 BOP

• PA50105, AEPS FDR BKR TO EDGPA5002

• PA50106, AEPS FDR BKR TO EDGPA5003

• PA50107, AEPS FDR BKR TO EDGPA5004

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 36 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step C4) Using PBXY0001 CHECK The Following Breakers -

CLOSED

a. Feeder Breaker PA50103, AEPS FDR BKR TO XFMR BOP XPB05

b. Feeder Breaker PB0501, AEPS FDR BKR To PB05 FROM PA50103 (Step C5) RETURN To Procedure Section And Step In Effect:

BOP

• Attachment B, Energizing NB02 From Alternate Emergency Power Supply (AEPS), Step B2 (Step B2) PLACE ESW PUMP B In PULL-TO-LOCK BOP

• EF HIS-56A (Step B3) Using PBXY0001 CLOSE AEPS FDR BKR PB0502 TO BOP NB0214

• PB0502 (NOTE) Handswitch NB HIS-68 must be held in the CLOSE position for a minimum of 3 seconds to allow the Undervoltage relay to reset (Step B4) CLOSE NB02 AEPS SUPPLY BKR NB0214 BOP

• NB HIS-68 Critical Energize at least one AC Emergency Bus prior to RCP seal CREW Task degradation (greater than 25 gpm per pump)

(Note) An AEPS DG at full load uses 139 gal/hr fuel. At this rate, the low fuel level alarm will be received in approximately 19 hours2.199074e-4 days <br />0.00528 hours <br />3.141534e-5 weeks <br />7.2295e-6 months <br /> and will be empty in 25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 37 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior (Step B5) MONITOR AEPS System Using PBXY0001:

• Watts BOP

• Amps

• Volts

• Fuel (DG only)

(Step B6) NOTIFY Jefferson City Oil To REFUEL AEPS DGs As Necessary:

BOP

• Contact information located in Call Out List (if on COOP power this call does not need to be made)

(Caution) To avoid tripping other NB02 loads 'B' ESW pump must be started first.

(Note) No loading restrictions apply if NB02 is energized by Central Electric Power Reform Substation.

(Step B7) CHECK NB02 Energized By Central Electric Power BOP Reform Substation Or A Minimum Of 3 AEPS DGs (Step B8) When Off-Site Power Is Available Restore Power To BOP NB02 Using Attachment E, Restore Normal Power To NB02, Step E1 CRS/BOP Return To Procedure and Step In Effect ECA-0.0 Loss of All AC Power Upon restoration of AC Power the CRS will direct a transition to CRS step 24 of ECA-0.0

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014 Scenario # 2 rev.0 Event # 6, 7, 8 Page 38 of 38 Event

Description:

Loss of All AC Power, TDAFW pump fail to start and AEPs EDG fail to start Proc /Time Position Applicants Actions or Behavior ECA-0.0 (Step 24) CHECK If AC Emergency Power Is Restored:

a. CHECK AC emergency buses AT LEAST ONE BOP ENERGIZED

• NB02 (Step 25) STABILIZE SG Pressures:

BOP a. Manually CONTROL SG ASDs to maintain existing SG pressures (Step 26) Check Following Equipment Loaded on Energized AC Emergency Bus:

• NB02:

o 480 Volt Buses:

NG02 breakers NB0213 and NG0201 NG04 breakers NB0210 and NG0401 o Battery Chargers:

BOP NK24 breaker NG0203 NK22 breaker NG0403 o Instrument and Control:

NN02 NN04 o Communications:

QF076 Emergency Supply Breaker PN0803 NOTE At the Discretion of the Lead Examiner OR once the crew has Re-Energized an AC Bus - The Scenario can be STOPPED.

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 3, Rev 1 Op-Test No.: 2014-1 Examiners: ____________________________ Operators: _____________________________

____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: 100%

Turnover: B CCP is tagged out for Breaker PMTs Even Malf. No. Event Event t No. Type* Description SRO (I) 1 SEN0044 RO (I) Nuclear Instrument Fails high. (Tech Specs)

BOP (I)

SRO (I) 2 AELT0519 SG Level Instrument Fails to 75% (Tech Specs)

BOP (I)

PAE01A_2 SRO (R) 3 PAE01A_3 RO (R) MFP Vibrations Forcing Downpower PAE01A_4 BOP (C)

SRO (C) 4 PAE0`A.1 RO (C) MFP Trip / Rx Trip BOP (C)

SRO (M) 5 SF006 RO (M) Reactor Trip Failure / ATWS BOP (M)

SRO (M) 6 TBB03 Pressurizer Steam Space Leak RO (M)

SIS_A SRO (C) 7 Automatic SI Actuation Failure Both Trains SIS_B RO (C)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 3

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2

Scenario Event Description Callaway 2014-1 NRC Scenario #3, rev. 1 The plant is steady at 100% power.

After the crew takes the watch, N44 will fail high. The crew will respond with OTO-SE-00001, Nuclear Instrument Malfunction, to select an operable channel and bypass the failed instrument.

The CRS will evaluate Tech Spec 3.3.1.

After the failed NI has been bypassed and the CRS has identified the applicable Tech Specs, Steam Generator A controlling level channel slowly fails to 75%. The crew will respond using OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions, to control SG level. The CRS will evaluate Tech Spec 3.3.1. and 3.3.2 After Tech Specs have been addressed, A MFP will develop vibrations. The crew will respond with OTO-MA-00008, Rapid Load Reduction to lower power to below 65%. The crew will lower turbine load and borate to lower power.

After the crew has lowered power 5 to 10 MWe and prior to reducing power less than 70%, A MFP will trip. The crew will respond IAW OTO-AE-00001, Feedwater System Malfunction and attempt to trip the reactor.

When the crew attempts to trip the reactor rods will not insert. The crew will respond by entering E-0, Reactor Trip or Safety Injection and transitioning to FR-S.1, Response to Nuclear Power Generation/ATWS. The crew will be able to successfully de-energize PG19 and 20, insert control rods, and emergency borate the RCS. After rods have been inserted and the reactor has been shutdown the crew will transition back to E-0, Reactor Trip or Safety Injection.

After the transition back to E-0, a leak in the PZR steam space develops. When the RCS depressurizes SI fails to automatically initiate. The crew will manually initiate SI and transition to E-1, Loss of Reactor or Secondary Coolant.

The scenario can be terminated after Step 5 of E-1.

Scenario Event Description Callaway 2014-1 NRC Scenario #3, rev. 1 Critical Tasks:

Critical Tasks Insert negative reactivity into the core by at least one of the following methods before Manually actuate at least one train of SIS-actuated safeguards equipment before dispatching operators to locally Trip the Reactor transition to E-1.

• Deenergize PG19 and PG20

• Insert Control Rods

• Establish emergency boration flow to the RCS EVENT 5 7 Safety In the scenario, failure to insert negative reactivity by one of the methods listed In the scenario, failure to manually actuate Sl results in a significant reduction of safety significance previously can result in the needless continuation of an extreme or a severe challenge margin beyond that irreparably introduced by the scenario. Failure to manually actuate to the subcriticality CSF. Although the challenge was not initiated by the crew (was not Sl in the scenario would be a violation of the facility license condition. Although the initiated by operator error), continuation of the challenge is a result of the crew's failure degraded status is not due to the crew's action, continuation in the degraded status to insert negative reactivity. would be a result of the crew's failure to manually actuate Sl.

Cueing Both of the following: Indication and/or annunciation that that Sl is required

• Indication of ATWS (the reactor is not tripped and that a manual reactor trip is not

• PRZR pressure or SG pressure less than Sl actuation setpoint effective) No indication or annunciation that Sl is actuated Performance Manipulation of controls in the control room as required to initiate the insertion of Manipulation of controls as required to actuate at least one train of Sl indicator negative reactivity into the core (at least one of the following)

• SB HS-27

• Open supply breakers to PG19 and PG20.

• SB HS-28 o PG HIS-16 and PG HIS-18

• Insert Control Rods at the Maximum Rate.

• ALIGN emergency boration flow path:

o Start boric acid transfer pumps BG HIS-5A and BG HIS-6A o OPEN Emergency Borate To Charging Pump Suction valve:

BG HIS-8104 Performance Crew will observe the following: Indication that both Trains of SI - Actuated feedback

• Indication of a negative SUR on the intermediate range of the excore NIS

• LOCA Sequencer annunciator 30A - Lit

• Indication of less than 5% power on the power range of the excore NIS

• LOCA Sequencer annunciator 30B - Lit

• SB069 SI Actuate Red Light - Lit SOLID (NOT blinking)

Justification for Local operator actions would result in reactor trip, which would shut down the reactor The crew has had ample opportunity to recognize the need for Sl and the fact that Sl the chosen faster than boration (and faster than rod insertion). However, it is anticipated that has not automatically actuated.

performance limit effecting the local actions will be time-consuming and that actions that can be Given the postulated plant conditions, transition from E-0 to ES-0.1 constitutes an error implemented from the control room should be given precedence. Thus, before in using the E-0 procedure. The crew is in the wrong procedure; however, the crew is dispatching operators to perform local actions to trip the reactor, the crew should allowed to recover from this error up through Step 3.a of ES-0.1.

perform or initiate performance of at least one of the three methods listed previously for The ERG network is designed to "catch" errors in procedure usage. Step 3.a is shutting down the reactor and providing shutdown margin. designed to get the crew back to E-0, if that is in fact where the crew should be. If the crew members pass through Step 3.a and remain in ES-0.1, they have missed the last step that would return them to the correct procedure.

PWR Owners CT- 52, Insert negative reactivity into the core CT-2, Manually actuate Sl Group Appendix

Scenario Event Description Callaway 2014-1 NRC Scenario #3, rev. 1 References OTO-SE-00001, Nuclear Instrument Malfunction OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions OTA-RK-00026 Add 120E, MFP A VIB ALERT OTO-MA-00008, Rapid Load Reduction OTO-AE-00001, Feedwater System Malfunction E-0, Reactor Trip or Safety Injection E-1, Loss of Primary or Secondary Reactor coolant FR-S.1, Response to Nuclear Power Generation/ATWS Tech Spec 3.3.1 for Reactor Trip System Instrumentation Tech spec 3.3.2 for ESFAS Instrumentation ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. ATWS from Loss of Main Feedwater (TAT2)

a. Manually open control rod drive motor generator breakers

b. Manually drive in control rods

2. LOCA (S(2 or 3))

a. Manually Initiate SI

Scenario Event Description Callaway 2014-1 NRC Scenario #3, rev. 1 Scenario Setup Guide:

Establish the initial conditions of IC-10, MOL 100% power:

• RCS boron concentration 756 ppm

• CCP A 760 ppm minus 3 days

• CCP B 765 ppm minus 7 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• B CCP is tagged out for Breaker PMTs

=======SCENARIO PRELOADS / SETUP ITEMS==========

Reactor Fails to Trip in Auto and Manual (Event 5)

• Insert Malfunction (SF) SF006, Value = Both_modes PZR steam leak (Event 6)

• Insert Malfunction (BB) TBB03, Value = 200, Ramp = 1 min, conditional rec0009 le 1.0 with a delay of 5 minutes SI Fails to Automatically Actuate (Event 7)

• Malfunctions (SB)SIS_A_Block_Auto, Value = Block

• Malfunctions (SB)SIS_B_Block_Auto, Value = Block

======= EVENT 1 ============================

N44 fails high

• Insert Malfunction (SE) SEN0044, Value = 120, Ramp = 10 sec

======= EVENT 2 ============================

Steam Generator A controlling level channel slowly fails to 75%

• Insert Malfunction (AE) AELT0519, Value = 65, ramp = 1 min

=======EVENT 3 ============================

Main Feed Pump Vibration- A MFP

• Insert Malfunctions

• (AE) PAE01A_2, Value = 0.042

• (AE) PAE01A_3, Value = 0.038

• (AE) PAE01A_4, Value = 0.03

=======EVENT 4 ============================

Main Feed Pump Trip- A MFP

• Insert Malfunction (AE) PAE01A_1, Value = Trip

=======EVENT 5 ============================

Reactor Fails to Trip in Auto and Manual SEE PRELOADS ABOVE

=======EVENT 6 PRELOADED=================

PZR steam leak SEE PRELOADS ABOVE

=======EVENT 7 PRELOADED===============

SI Fails to Automatically Actuate SEE PRELOADS ABOVE

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 1 Page 6 of 27 Event

Description:

NI Failure Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 0 minutes or at the discretion of the Lead Examiner

• Power Range channel N44 fails HIGH

• Insert Malfunction (SE) SEN0044, Value = 120, Ramp = 10 sec

• When contacted as the I&C supervisor to trip bistables, respond that you will brief a team and contact the control room when ready to trip bistables but it wont be this shift.

• When contacted, respond as WWM. Acknowledge that you will develop a work package to trouble shoot and repair the failed NI

• When contacted, respond as Duty Manager. Acknowledge entry into the OTO Indications Available:

T= 0 Ann 78A PR Channel Dev Ann 82A PR Over PWR Rod Stop Ann 83C RX Partial Trip OTO-SE-00001 OTO-SE-CRS Implement OTO-SE-00001, Nuclear Instrument Malfunction 00001 (Note) Crew could enter OTO-SF-00001 and return to the correct procedure OTO-SE- (Step 1) CHECK Power Range Nuclear Instruments -

00001, NORMAL Att A RNO

a. Ensure rod control is in manual RO

• SE HS-9

b. IF any MFW Reg Valve Bypass Valves are being used to feed a Steam Generator, THEN PERFORM the following:-NO

c. Go to ATT A for power range malfunction BOP (Step A1) Stop any main turbine load changes.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 1 Page 7 of 27 Event

Description:

NI Failure Proc /Time Position Applicants Actions or Behavior (Step A2) Maintain RCS Tavg within 1.5°F of Tref using manual control rods.

RNO Restore RCS Tavg to within 1.0°F of Tref using turbine load or adjusting RCS boration concentration.

• REDUCE Turbine load using the %/Min Loading Rate:

a. SLOWLY LOWER Load using the DECREASE LOAD pushbutton until all of the following are met:

Load Limit Limiting Light EXTINGUISHED RO/BOP Decrease Loading Rate "OFF" Light LIT Loading Rate Limit %/MIN "1/2" Light LIT

b. ROTATE Load Limit Set potentiometer fully clockwise

c. SELECT Decrease Loading Rate ON

d. SET Loading Rate Limit %/Min to desired value

e. LOWER load set MW toward desired load using the DECREASE LOAD pushbutton OR

• REDUCE Turbine the Load Limit Potentiometer load using (Step A3) Check the following permissives are in the correct state within one hour Of the Power Range Channel Failure per Attachment H, Permissives BOP

• P-7 LIT

• P-8 LIT

• P-9 LIT

• P-10 LIT (Step A4) Select an operable channel on NIS recorder RO

• SE NR-45

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 1 Page 8 of 27 Event

Description:

NI Failure Proc /Time Position Applicants Actions or Behavior (Step A5) Bypass the malfunctioning channel by selecting the affected channel on the following switches

a. On the detector current comparator drawer

• Place the upper section switch to the failed channel: PRN44

• Place the lower section switch to the failed channel: PRN44

• Place the rod stop bypass switch to the failed channel: Bypass PRN44 BOP

• Place the power mismatch bypass switch to the failed channel: Bypass PRN44

b. On the comparator and rate drawer place comparator channel defeat switch to the failed channel: N44

c. Ensure the following annunciators are out

• 78A

• 78B

• 78C

• 82A (Step A6) Check rod control in auto

• SE HS-9 RO RNO WHEN RCS Tavg is stable within 1.0°F of Tref AND Shift Manager/Control Room Supervisor concurs, THEN PLACE Rod Control in Auto.

(Step A7) Check any SG level being controlled by MFW REG BOP BYP VLV

• RNO go to step A8 RO (Step A8) Check reactor power greater than 10%

(Step A9) Trip protective bistables for the failed channel per BOP ATT D, Tripping Power Range Protective Bistables, within the Time Limit Specified in the Applicable Technical Specification

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 1 Page 9 of 27 Event

Description:

NI Failure Proc /Time Position Applicants Actions or Behavior NOTE Tripping of bistables would not be expected to be performed this shift.

(Step A10) Check reactor power meets one of the following RO

• Greater than 75%

CRS (Step A11) Verify QPTR every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> per OSP-SE-(Step A12) Record any of the following in the control room log CRS

• Permissives are in the correct state

• Any fuses that have been pulled .

CRS (Step A13) Place the inop channel in the EOSL (Step A14) Review applicable T. S.

CRS

• T.S. 3.3.1.D, E and S/T CRS (Step A15) DIRECT I&C To Repair Failed Channel NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 2 Page 10 of 27 Event

Description:

Steam Generator A controlling level channel slowly fails to 75%

Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 15 minutes or at the discretion of the Lead Examiner

• Steam Generator A controlling level channel slowly fails to 75%

• Insert Malfunction (AE) AELT0519, Value = 65, ramp = 1 min

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure. Tripping of Bistables will not be performed this shift.

• When contacted, respond as Duty Manager. Acknowledge entry into the OTO Indications Available:

T= 15 Ann 83C RX PARTIAL TRIP Ann 108C SG A LEV DEV Ann 108 D SG A FLOW MISMATCH OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions Implement OTO-AE-00002, Steam Generator Water Level Control CRS Instrument Malfunctions OTO-AE- (Step 1) Check SG Water Level Control Instrument 00002 RNO: SG A: AB LI-519 Take MANUAL Control of Affected SG MFRV or MFRV Bypass and MAINTAIN SG Level:

BOP

• SG A:

o AE FK510, SG A MFW REG VLV CTRL OR o AE LK550, SG A MFW REG BYPASS CTRL (Step 2) For the Failed Instrument, SELECT An Operable Channel:

• Select AB FS-512C to operable channel BOP

• On DFWCS, SELECT appropriate Level, FW Flow or Steam Flow on AE SS500 (Step 3) RESTORE Affected SG NR Level to between 45% and BOP 55%

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 2 Page 11 of 27 Event

Description:

Steam Generator A controlling level channel slowly fails to 75%

Proc /Time Position Applicants Actions or Behavior (Step 4) Return Affected SG MFRV or MFRV Bypass to AUTO Control:

• SG A:

BOP o AE FK510 OR o AE LK550, CRS (Step 5) Review Attachment A, Effects of Instrument Failure (Step 6) Review Applicable Tech Specs, Attachment F

• 3.3.1, Table 3.3.1-1 Items 14.a and 14.b Cond E 72 hr CRS

• 3.3.2, Table 3.3.2-1 Item 5.c and 5.e Cond D & I 72 hr

• 3.3.2, Table 3.3.2-1 Item 6.d Cond D 72 hr CRS (Step 7) Perform Notifications per ODP-ZZ-00001, Add 13 CRS (Step 8) Direct I&C to Trip Protective Bistables - Att. D NOTE Tripping of bistables would not be expected to be performed this shift.

CRS (Step 9) Place AB LI-519 in the EOSL CRS (Step 10) Initiate Action to Repair AB LI-519 NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 3 Page 12 of 27 Event

Description:

Main Feed Pump Vibration.

Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 25 minutes or at the discretion of the Lead Examiner Main Feed Pump Vibration- A MFP

• Insert Malfunctions (AE) PAE01A_2, Value = 0.042 (AE) PAE01A_3, Value = 0.038 (AE) PAE01A_4, Value = 0.03

• If contacted as an OT, wait 3 minutes and report nothing abnormal but the grating by the A MFP is vibrating more than B MFP is.

• If contacted as Engineering, recommend securing per normal shutdown procedure when plant conditions can support securing the pump.

• When contacted, respond as Duty Manager. Acknowledge entry into the OTO and power reduction.

Indications Available:

T= 25 Ann 120E MFP A VIB ALERT OTA-RK-00026 Add 120E CRS Implement OTA-RK-00026 Add 120E, MFP A VIB ALERT This alarm will re-flash when any input reaches its DANGER set point.

During steady-state, reaching the DANGER set point within the next 15 minutes is considered a Rapidly Degrading Condition.

NOTE Valid DANGER set points are normally accompanied by multiple alarms.

An alarm from computer point FCZE0394C, MFP A AXIAL POS, is common during transient conditions and pump shutdown.

OTA-RK-00026 (Step 3.1) MONITOR the vibration of the A MFP using the table at BOP Add the end of this Section.

120E

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 3 Page 13 of 27 Event

Description:

Main Feed Pump Vibration.

Proc /Time Position Applicants Actions or Behavior BOP (Step 3.2) VALIDATE the alarm condition by local observation (Step 3.4) IF monitoring indicates DANGER set point reached OR a Rapidly Degrading Condition (except for FCZE0394C, MFP A CRS AXIAL POS, during transient conditions), TRIP the A MFP and ENTER OTO-AE-00001, Feedwater System Malfunction.

(Step 3.5) IF monitoring indicates steady or a slowly degrading condition (except for FCZE0394C, MFP A AXIAL POS, during transient conditions), PERFORM the following:

CRS (Step 3.5.1.) REDUCE Reactor power to less than 65% per OTO-MA-00008, Rapid Load Reduction.

(Step 3.5.2.) CONTACT the system Engineering Duty Supervisor (EDS) for additional guidance OTO-MA-00008, Rapid Load Reduction OTO-MA- (Step 1) Place Rod Control In AUTO 00008 RO

a. SE HS-9 (Step 2) Manage Reactivity

a. Perform Reactivity Management Brief:

CRS

• Discuss Amount and Rate of Turbine Load Reduction

• Determine amount of boric acid needed (CAUTION)

• If using the Load Limit Potentiometer, unloading at greater than 50 MWe per minute may arm the Main Condenser Steam Dumps.

• If changing load reduction methods to the Load Limiter ENSURE Load Set is restored to AT SET LOAD prior to using the Load Limiter.

(NOTE) Steps 3 and 4 may be performed concurrently while continuing in this procedure

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 3 Page 14 of 27 Event

Description:

Main Feed Pump Vibration.

Proc /Time Position Applicants Actions or Behavior

1. (Step 3) REDUCE Turbine Load at Less than or Equal to 5% per Minute using any of the following:

• REDUCE Turbine load using the %/Min Loading Rate:

a. SLOWLY LOWER Load using the DECREASE LOAD pushbutton until all of the following are met:

Load Limit Limiting Light EXTINGUISHED Decrease Loading Rate "OFF" Light LIT CRS/BOP Loading Rate Limit %/MIN "1/2" Light LIT

b. ROTATE Load Limit Set potentiometer fully clockwise

c. SELECT Decrease Loading Rate ON

d. SET Loading Rate Limit %/Min to desired value

e. LOWER load set MW toward desired load using the DECREASE LOAD pushbutton OR

• REDUCE Turbine the Load Limit Potentiometer load using NOTE For step #4 of OTO-MA-00008, the candidate may either use OTO-MA-00008 step 4 or OTN-BG-00002, Attachment 8. The procedural actions to Borate from the VCT are the same and OTO-MA-00008 steps are listed below.

1. (Step 4) Borate From the BAST by performing any of the CRS/RO following:

• BORATE to the VCT:

RO #(Step 4a) Place BG HS-26, RCS M/U CTRL, in STOP RO #(Step 4b) Place BG HS-25, RCS M/U CTRL SEL, in BORATE

1. (Step 4c) Set Boric Acid Flow Controller, BG FK-110, to the RO desired flow rate RO #(Step 4d) Place BG FK-110 in AUTO

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 3 Page 15 of 27 Event

Description:

Main Feed Pump Vibration.

Proc /Time Position Applicants Actions or Behavior RO #(Step 4e) RESET BG FY110B, BA COUNTER, to 000

1. (Step 4f) SET BG FY110B for the desired gallons of boric RO acid to be added RO #(Step 4g) PLACE BG HS26 in RUN

1. (Step 4h) WHEN the desired boration is complete, THEN PLACE RO BG HS-26 in STOP RO #(Step 4i) repeat Boration as necessary (Step 5) Initiate Boron Equalization by performing the following:

a. ENERGIZE at least one group of Pressurizer Backup Heaters:

• B/U Group A BB HIS-51A

• B/U Group B BB HIS 52A RO

b. Place Pressurizer Pressure Master Controller in MAN:

• BB PK-455A

c. Lower Pressurizer Pressure Master controller output to 38% to 42%

d. Place Pressurizer Master Controller in AUTO (Step 6) Check MFP Turbine Speed Control - IN AUTO BOP

• FC SK-509B

• FC SK-509C Once the crew starts to reduce power using steps 1-6 of OTO-MA-00008, as proven by observation lowering load 5-10 MWe CUE AND prior to the crew reducing power <70%:

GO TO THE NEXT EVENT AS CUED BY LEAD EXAMINER

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 4 Page 16 of 27 Event

Description:

Main Feed Pump Trip Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 40 minutes or at the discretion of the Lead Examiner Main Feed Pump Trip- A MFP

• Insert Malfunction (AE) PAE01A_1, Value = Trip

• When contacted, respond as Duty Manager as requested Indications Available:

T=40 Ann 120A MFP A TRIP OTO-AE-00001, FEEDWATER SYSTEM MALFUNCTION Implement OTO-AE-00001, FEEDWATER SYSTEM CRS MALFUNCTION OTO-AE- (Step 1) PLACE Rod Control In AUTO:

00001 RO

• SE HS-9 BOP (Step 2) CHECK Main Feed Pump TRIPPED (Step 3) CHECK Reactor Power LESSTHAN 70%

RNO IF only one Main Feed pump is running, THEN PERFORM the RO following:

a. Manually TRIP the Reactor.

b. Go To E0, Reactor Trip Or Safety Injection.

CUE Go to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 17 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 45 minutes or at the discretion of the Lead Examiner

• If contacted as an OT to locally trip Rx trip breakers, wait 3 minutes, Delete Malfunction SF006, and report Rx Trip breakers have been locally tripped

• When contacted, respond as Duty Manager.

• When contacted as Radiation Protection, respond as requested.

• When contacted as Chemistry, respond as requested.

Indications Available:

T=45 Ann 86A LO FLOW & P8 RX TRIP Ann 108B SG A LEV LO Ann 109B SG B LEV LO Ann 110B SG C LEV LO Ann 111B SG D LEV LO E-0, Reactor Trip or Safety Injection E-0 CRS Implement E-0, Reactor Trip or Safety Injection Note Steps 1 through 4 are immediate actions.

(Step 1) CHECK Reactor Trip

• Rod Bottom Lights - NO

• Reactor Trip and Bypass Breakers - CLOSED RO

• Neutron Flux - Steady RNO If power > 5%, Go To FR-S.1, Response to Nuclear Power Generation/ATWS FR-S.1, Response to Nuclear Power Generation/ATWS FR-S.1 Implement FR-S.1, Response to Nuclear Power CRS Generation/ATWS

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 18 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior NOTE Steps 1 and 2 are immediate actions.

(Step 1) Check Reactor Trip:

RNO- Manually Trip the Reactor.

• SB HS-1

• SB HS-42 (BOP)

RO IF Reactor will NOT trip, THEN PERFORM the following:

a. Insert Control Rods at the Maximum Rate.

b. Open supply breakers to PG19 and PG20.

• PG HIS-16

• PG HIS-18 Critical Insert negative reactivity into the core by at least one of the Task following methods before dispatching operators to locally Trip the Reactor CREW

• Deenergize PG19 and PG20

• Insert Control Rods

• Establish emergency boration flow to the RCS (Step 2) CHECK Turbine Trip BOP

a. Turbine Stop Valves - Closed (Step 3) Check AFW Pumps Running BOP a. MDAFPs - Both running

b. TDAFP - Running if necessary

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 19 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 4) Initiate Emergency Boration of the RCS

a. At least one charging pump running

b. ALIGN emergency boration flow path:

1) Start boric acid transfer pumps

• BG HIS-5A

• BG HIS-6A RO 2) OPEN Emergency Borate To Charging Pump Suction valve:

• BG HIS-8104

3) Check Emergency Boration flow > 30 gpm

• BG FI-183A

4) Maintain charging flow > BG FI-183A flow

c. Check PZR pressure < 2335 psig (Step 5) Check Containment Purge Isolation ESFAS status panels CPIS sections:

• SA066X WHITE lights - ALL LIT RO/BOP

• SA066Y WHITE lights - ALL LIT RNO - Manually actuate CPIS

• SA HS-11

• SA HS-15 (Step 6) Check if the Following Trips Have Occurred

a. Reactor Trip RNO - Locally trip breakers

b. CLOSE supply breakers to PG19 and PG20:

RO/BOP

• PG HIS-16

• PG HIS-18

c. Turbine Trip

• All Turbine Stop valves - CLOSED (Step 7) Check if Reactor is Subcritical RO YES - GO TO STEP 16

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 20 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior RO (Step 16) Return To Procedure And Step In Effect E-0, Reactor Trip or Safety Injection E-0 CRS Implement E-0, Reactor Trip or Safety Injection NOTE Steps 1 through 4 are immediate actions.

Per ODP-ZZ-00025 since this is a return entry to E-0 the NOTE immediate actions are not required to be performed but they must be verified.

(Step 1) CHECK Reactor Trip

• Rod Bottom Lights - All Lit RO

• Reactor Trip and Bypass Breakers - Open

• Neutron Flux - Lowering (Step 2) Check Turbine Trip BOP

a. All Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses BOP a. AC emergency buses - At Least One Energized

• NB01 OR NB02

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 21 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 4) Check SI Status

a. Check if SI is actuated

• Any SI annunciator 88A through 88D - Lit OR

• SB069 SI Actuate Red Light - Lit OR

• LOCA Sequencer annunciators 30A or 31A - Lit RNO:

a. Check if SI is required

• PZR pressure less than or equal to 1849 PSIG OR RO

• Any SG pressure less than or equal to 615 PSIG OR

• Containment pressure greater than or equal to 3.5 PSIG If SI is required then manually actuate SI

• SB HS-27

• SB HS-28

b. Check both Trains of SI - Actuated

• LOCA Sequencer annunciator 30A - Lit

• LOCA Sequencer annunciator 30B - Lit

• SB069 SI Actuate Red Light - Lit SOLID (NOT blinking)

Note Depending on the time it takes the crew to complete FR-S.1 pressure may not have decreased enough to SI. If this is the case the crew will transition to ES-0.1 and perform the manual actuation of SI at Step 3 and return to E-0 Critical Manually actuate at least one train of SIS-actuated safeguards Task CREW equipment before transition to E-1.

(Step 5) Perform Attachment A, Automatic Action Verification, BOP/RO While Continuing With This Procedure (see page 26 of the scenario guide)

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 22 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 6) CHECK Generator Output Breakers - Open BOP (Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed (Step 8) CHECK AFW Pumps BOP a. MD AFW Pumps - Both Running - YES

b. TD AFW Pump - Running (Step 9) CHECK AFW Valves - Proper Emergency Alignment

• MD AFP Flow Control Valves - Throttled BOP

• TD AFP Flow Control Valves - FULL OPEN

• TD AFP Loop Steam Supply Valves - Both OPEN IF NECESSARY BOP (Step 10) CHECK Total AFW Flow - Greater than 285,000 lbm/hr (Step 11) CHECK PZR PORVs and Spray Valves

a. PZR PORVs - Closed BOP b. PZR PORVs - Both in AUTO

c. PORV Block Valves - Both Open

d. Normal PZR Spray Valves - Closed

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 23 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 12) CHECK if RCPs should be Stopped

a. RCPs - Any Running

b. ECCS Pumps - At least One Running BOP

c. RCS Pressure - Less than 1425 psig

d. Stop all RCPs The RCP may have already been secured per the fold-out page

1. (Step 13) CHECK RCS Temperatures BOP

• RCPs Running - Tavg 557 Deg F

• No RCPs Running - Tcold 557 Deg F (Step 14) CHECK if any SG is Faulted - NO

a. CHECK pressures in all SGs:

RO/BOP

• Any SG pressure lowering in an uncontrolled manner -

• Any SG completely depressurized RNO Go To Step 15 (Step 15) Check if SG Tubes are Intact:

• Levels in all SGs:

o No SG narrow range level rising in an uncontrolled manner

• SG Steam Line N16 radiation - Normal RO/BOP

• Condenser Air Removal radiation - Normal before Isolation

• SG Blowdown and Sample radiation - Normal before Isolation

• SG ASD radiation - Normal

• Turbine Driven Auxiliary Feedwater pump exhaust radiation - Normal

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 24 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 16) Check if RCS is Intact:

• Containment Pressure - Normal - NO RO/BOP

• Containment Normal Sump level - Normal - NO

• Containment radiation - Normal before Isolation - NO RNO Go to E-1, Loss of Reactor or Secondary Coolant, Step 1.

E-1, Loss of Reactor or Secondary Coolant CRS Transition to E-1, Loss of Reactor or Secondary Coolant E-1 (Step 1) Check if RCPs should be stopped:

a. RCPs - any running RO b. ECCS Pumps - At least One running

c. RCS pressure - Less than 1425 psig

d. Stop all RCPs (Step 2) Check if any SG is Faulted:

a. Check pressures in all SGs:

• Any SG pressure lowering in an uncontrolled BOP manner - NO

• Any SG completely depressurized - NO RNO Go to Step 3 (Step 3) Check Intact SG Levels:

a. Narrow range levels - Greater than 7% [25%]

BOP

b. Control feed flow to maintain narrow range levels between 7% [25%] and 52%

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 25 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step 4) Check secondary radiation - Normal

a. Perform the following:

• Perform EOP Addendum 11, Restoring SG sampling after SI actuation

• Direct Chemistry to sample all SGs for activity

• Direct Radiation Protection to survey steamlines in BOP Auxiliary building Area 5 as necessary

b. Check unisolated secondary radiation monitors:

• SG Sample radiation

• SG ASD radiation

• TDAFW Pump exhaust radiation

c. Secondary radiation - Normal (Step 5) Check PZR PORV and Block valves:

a. Power to Block Valves- available RO

b. PZR PORVs - Closed

c. Block Valves - Both Open (Step 6) Check if ECCS flow should be reduced: - NO

a. RCS subcooling - Greater than 30F [50F]

b. Secondary heat sink:

• Narrow range level in at least one intact SG-Greater than 7% [25%]

RO

• Total feed flow to intact SGs- Greater than 285,000 lbm/hr

c. RCS pressure - stable or rising

d. PZR level - Greater than 9% [29%]

RNO Go To Step 7 NOTE At the Discretion of the Lead Examiner - The Scenario can be STOPPED.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 26 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior Attachment A, Automatic Action Verification (Step A1) CHECK Charging Pumps - Both CCPs running - NO E-0 Att A RO/BOP CCP Pump B Out of Service RO/BOP (Step A2) CHECK SI and RHR Pumps - All running -

(Step A3) CHECK ECCS Flow - BIH flow indicated - NO RO/BOP CCP Pump B Out of Service (Step A4) CHECK ESW Pumps - BOTH RUNNING RO/BOP

• EF HIS-55A

• EF HIS-56A (Step A5) CHECK CCW Alignment:

• CCW Pumps - ONE RUNNING IN EACH TRAIN

• CCW Service Loop Supply and Return valves for one operating CCW pump - OPEN RO/BOP

• OPEN CCW To RHR HX valves

• CLOSE Spent Fuel Pool HX CCW Outlet Valves

• STOP Spent Fuel Pool Cooling Pump(s)

• RECORD The Time Spent Fuel Pool Cooling Pump Secured (Step A6) CHECK Containment Cooler Fans - RUNNING IN RO/BOP SLOW SPEED (Step A7) CHECK Containment Hydrogen Mixing Fans -

RO/BOP RUNNING IN SLOW SPEED RO/BOP (Step A8) CHECK If Containment Spray should Be Actuated - NO

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 3 rev 1 Event # 5, 6, 7 Page 27 of 27 Event

Description:

Reactor Trip Failure / ATWS / Pressurizer Steam Space Leak / Automatic SI Actuation Failure Both Trains Proc /Time Position Applicants Actions or Behavior (Step A9) CHECK If Main Steamlines Should Be Isolated:

RO/BOP

• Containment pressure > 17 psig

• Steamline pressure - LESS THAN 615 PSIG (Step A10) CHECK ECCS Valves - PROPER EMERGENCY RO/BOP ALIGNMENT (Step A11) CHECK Containment Isolation Phase A

a. ESFAS status panels CISA sections:

RO/BOP

• SA066X White lights - ALL LIT

• SA066Y White lights - ALL LIT (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

RO/BOP

• SA066X White lights - ALL LIT

• SA066Y White lights - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation RO/BOP Isolation (Step A14) CHECK Containment Purge Isolation:

a. ESFAS status panels CPIS sections:

RO/BOP

• SA066X White lights - ALL LIT

• SA066Y White lights - ALL LIT (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 4, Rev 1 Op-Test No.: 2014-1 Examiners: ____________________________ Operators: _____________________________

____________________________ _____________________________

____________________________ _____________________________

Initial Conditions: 80%

Turnover:

• Holding at 80% per Transmission Operations

• A MDAFWP is tagged out for Breaker PMTs

• Covers for containment purge in place on GTRT22 and GTRT33 Even Malf. No. Event Type* Event t No. Description SRO (N) 1 N/A Place Mini-Purge in service BOP (N)

WEIUBGTC013 SRO (C) 2 0TVSPNO LTDN HX Temp Cont Valve Controller Fails AUTO RO (C)

SRO (C) 3 (AB)PV004A D SG ASD Fails Open (Tech Specs)

BOP (C)

SRO (R)

(BB) 4 RO (R) SG Tube leak / Downpower (Tech Specs)

EBB01D BOP (C)

SRO (M)

(BB) 5 RO (M) SG Tube Rupture EBB01D BOP (M)

CPIS_A_BL OCK_AUTO SRO (C) 6 Mini-Purge Failure to isolate CPIS_B_BL BOP (C)

OCK_AUTO (BB)BBPCV0 SRO (C) 7 IA valve failure / PZR PORV Failure 455A RO (C)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 3

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 2

Scenario Event Description Callaway 2014 NRC Scenario #4, rev. 1 The plant is steady at 80% power steady state. A MDAFWP is tagged out for Breaker PMTs.

After the crew takes the watch, they will place Mini-Purge in service in IAW OTN-GT-00001, Containment Purge System, in preparation for Containment entry.

After the Mini-Purge system has been placed in service, the Letdown HX temperature control valve will closed. The crew will take actions IAW OTA-RK-00018 ADD 39B.

After the crew has addressed the letdown HX temperature control valve controller failure the SG D ASD fails open. The crew will respond IAW OTO-AB-00001, Steam Dump Malfunction. The crew will close the D ASD. The CRS will evaluate Tech Spec 3.7.4.A After Tech Specs have been evaluated, D SG will develop a tube leak. The crew will respond IAW OTO-BB-00003. The Crew will lower power and the CRS will evaluate Tech Spec 3.4.13, RCS Operational Leakage After the power reduction has been commenced, the tube leak will increase. The crew will trip the reactor due to the increased leak and respond IAW E-0, Reactor Trip or Safety Injection. The crew will identify that Mini-Purge failed to isolate. The crew will manually isolate Mini-Purge. The crew will transition to E-3, Steam Generator Tube Rupture and isolate the ruptured D SG Instrument Air cannot be restored to containment due to a valve failure, therefore normal pressurizer spray is NOT available. When the crew opens the PZR PORV to lower pressure the PORV will stick open. The crew will then have to close the PORV block valve.

The scenario can be terminated after the cooldown is in progress and the PORV has been isolated.

Scenario Event Description Callaway 2014 NRC Scenario #4, rev. 1 Critical Tasks:

Critical Tasks Isolate feedwater flow into and steam flow from the ruptured SG before a transition to Terminate the RCS depressurization by closing PORV block Valve prior to Loss of ECA-3.1 occurs. Subcooling.

EVENT 5 7 Safety Isolating the ruptured SG maintains a differential pressure between the ruptured SG and In the scenario, closing the block MOV constitutes a task that is essential to safety, significance the intact SGs. The differential pressure (250 psi) ensures that minimum RCS because its improper performance or omission by an operator will result in direct subcooling remains after RCS depressurization. adverse consequences or significant degradation in the mitigative capability of the plant.

In particular, the crew has failed to prevent degradation of any barrier to fission product release. In this case, the RCS fission product barrier can be restored to full integrity simply by closing the block MOV.

Cueing All of the following: All of the following:

• Indication and/or annunciation of SGTR in one SG

• Valve position indication and/or annunciation that the PRZR PORV is open, even o Increasing SG water level after attempts to close it manually from the control room o Radiation

• Indication and/or annunciation of decreasing RCS pressure

• Indication and/or annunciation of reactor trip

• Indication and/or annunciation consistent with the discharge of PRZR fluid to the

• Indication and/or annunciation of Sl PRT o PRT temperature, level, pressure o Tailpipe RTDs

• Valve position indication that the block MOV upstream of the stuck open PRZR PORV is open Performance Manipulation of controls as required to isolate the ruptured SG Manipulation of controls as required to close the block MOV for the stuck open PRZR indicator

• Close Steam line Low point Drain valve from ruptured SG PORV o AB HIS-10 (SG D)

• Close MSIV and MSIV bypass valve from ruptured SG o AB HIS-11 (SG D)

• Stop feed flow to ruptured SG o CLOSE AL HK-5A and AL HK-6A Performance Crew will observe the following: Valve position indication that the block MOV upstream of the stuck open PRZR PORV is feedback

• Indication of stable or increasing pressure in the ruptured SG closed

• Indication of decreasing or zero feedwater flow rate in the ruptured SG Justification for When the crew cannot maintain the 250 psi differential, the ERGs require a transition to prior to Loss of Subcooling. is in accordance with the PWR Owners Group Emergency the chosen contingency ERG ECA-3.1. This transition unnecessarily delays the sequence of actions Response Guidelines. The PWR Owners Group Emergency Response Guidelines performance limit leading to RCS depressurization and Sl termination. states: by completion of the first step in the ERG network that directs the crew to close the block MOV. If the crew does not close the block MOV in Step 17 of E-3, Step 18 directs the crew to close the PZR PORV Block Valve if RCS pressure is NOT RISING. If the crew does not close the valves and RCS pressure continues to lower, the crew is directed to transition to ECA-3.1 PWR Owners CT 18, Isolate the Ruptured SG. CT 10, Close PRZ PORV Block Valve.

Group Appendix

Scenario Event Description Callaway 2014 NRC Scenario #4, rev. 1 References OTN-GT-00001, Containment Purge System OTN-BG-00001 ADD 4, Operation of CVCS Letdown OTA-RK-00018, ADD 39B, Letdown Heat Exchanger Discharge Temperature High.

OTO-AB-00001, Steam Dump Malfunction OTO-BB-00001, Steam Generator Tube Leak OTO-MA-00008, Rapid Load Reduction OTN-BG-00002, Attachment 8, Borate Mode of RMCS Operation E-0, Reactor Trip or Safety Injection E-3, Steam Generator Tube Rupture Tech Spec 3.7.4.A, Atmospheric Steam Dump Valves (ASDs)

Tech Spec 3.4.13, RCS Operational Leakage ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. Steam Generator Tube Rupture (T(SG))

a. Isolate Ruptured Steam Generator

b. Cool Down and Depressurizes the RCS

Scenario Event Description Callaway 2014 NRC Scenario #4, rev. 1 Scenario Setup Guide:

Establish the initial conditions of IC-2, MOL 80% power:

• RCS boron concentration 958 ppm

• CCP A 968 ppm minus 2 days

• CCP B 973 ppm minus 5 days

• Rod Control Bank D 190 steps, Other banks 228 steps

• A MDAFWP is tagged out for Breaker PMT

=======SCENARIO PRELOADS / SETUP ITEMS====

A MDAFWP is tagged out

• Insert ME schematics (AL) e23al01a/AL01NB0105IA_BKPOS/Value = 3 Mini-Purge Failure to isolate (Inhibit CPIS Actuation with damper GT-HZ-11 stuck OPEN after CPIS manually actuated) (Event 6)

• Insert Malfunction (SB) CPIS_A_BLOCK_AUTO, Value = Block

• Insert Malfunction (SB) CPIS_B_BLOCK_AUTO, Value = Block

• Insert ME Schematic (GT) m22gt01_b, GTHZ0011_ATVFAILSP, Value = 1.0, cond HWX20O49R eq 1

• Insert ME Schematic (GT) m22gt01_b, GTHZ0012_ATVFAILSP, Value = 1.0, cond HWX20O52R eq 1

• Delete ME Schematic (GT) m22gt01_b, GTHZ0012_ATVFAILSP, Value = 1.0, cond X20I52C eq 1

PZR PORV Failure (Event 7)

• Malfunctions/BB/BBPCV0455A/100/cond=HWX21o149req1

• Malfunctions/BB/BBPCV0465A/100/cond=HWX21o150req1

• Override sw (KA) X24I32o Value=0

======= EVENT 1 ============================

• Place Mini-Purge in service

======= EVENT 2 ============================

LTDN HX Temp Cont Valve Fails Closed

• Insert ME schematics (EG) m22eg03, X8809d58s009 analog 053247, WEIUBGTC0130TVSPNO AUTO, Value = 1

======= EVENT 3 ============================

D SG ASD Fails Open

• Insert Malfunction (AB)PV0004A_1, ramp 30 sec, value 1

=======EVENT 4 ============================

D SG Tube leak / Downpower

• Insert Malfunction (BB) EBB01D, value=30, ramp 5 min

=======EVENT 5 ============================

D SG Tube Rupture / Reactor Trip

• Insert Malfunction (BB) EBB01D, value=400, ramp 10 min

=======EVENT 6 PRELOADED=================

Minipurge fails to isolate See preloads above

=======EVENT 7 PRELOADED=================

PZR PORV Failure See preloads above

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 1 Page 6 of 30 Event

Description:

Place Mini-Purge in service Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 0 minutes or at the discretion of the Lead Examiner

• Ensure crew has a copy of OTN-GT-00001, CONTAINMENT PURGE SYSTEM, and Gaseous Radwaste Release Permit.

• When contacted as the Rad/Chem Technician (Count Room) respond as directed.

Indications Available:

T= 0 OTN-GT-00001 OTN-GT- Implement OTN-GT-00001, CONTAINMENT PURGE CRS 00001 SYSTEM CRS (Section 3) Review Precautions and Limitations CRS (Section 4) Review Prerequisites (Note) Containment Mini-Purge is normally used in MODES 1 -

4 to reduce noble gas concentrations and establish conditions for containment entry. Mini-Purge may be placed in operation in CRS MODE 5, MODE 6 and No Mode when Shutdown Purge in not available.

Operation of Mini-Purge to Raise or Lower Containment pressure is normally performed using OTN-GT-00001 ADD01.

CRS (Step 5.2) Placing Mini-Purge System In Service.

(Step 5.2.1) ENSURE Section 5.1 has been performed. (Given CRS in turnover)

(Step 5.2.2) ENSURE Shutdown Purge System is NOT in CRS/BOP service.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 1 Page 7 of 30 Event

Description:

Place Mini-Purge in service Proc /Time Position Applicants Actions or Behavior BOP (NOTE) MINIVENT time trend may be used.

(Step 5.2.3) MONITOR the following instrumentation:

• SDRE0041, MANIPULATOR CRANE RAD MONITOR, or plant computer point SDR0041H, MANIP CRANE RAD MON BOP

• SDRE0042, CTMT BLDG RAD MONITOR, or plant computer point SDR0042H, CTMT BUILDING RAD

• GT PDI-40, CTMT DP, or plant computer point GTD0040, CTMT-AUX BLD DIFF PRESS (Step 5.2.4) RECORD containment pressure as read on GT PDI-40, CTMT DP, or plant computer point GTD0040, CTMT-BOP AUX BLD DIFF PRESS, on Gaseous Radwaste Release Permit.

(Step 5.2.5) IF in MODES 1 - 4 OR preparing to enter MODE 4 from MODE 5, ENSURE one of the following:

a. ENSURE the following are in OPERATE with CONTAINMENT PURGE IN PROGRESS DO NOT BYPASS covers in place over the switches:

1. GTRT22 (located on Drawer 7N168-1 in SA036D)

2. GTRT33 (located on Drawer 7N168-2 in SA036E)

BOP b. IF T/S 3.3.6 Action B was entered for GTRE22 and/or GTRE33, PERFORM the following:

1. ENSURE the following INOPERABLE rad monitor(s) is/are in BYPASS:

• GTRT22 (located on Drawer 7N168-1 in SA036D)

• GTRT33 (located on Drawer 7N168-2 in SA036E)

2. ENSURE Administrative Controls are in place in compliance with T/S 3.3.6 Required Action B.1.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 1 Page 8 of 30 Event

Description:

Place Mini-Purge in service Proc /Time Position Applicants Actions or Behavior BOP (Step 5.2.6) Step is N/A (Step 5.2.7) Using GT HIS-20, CTMT MINI PURGE EXH FAN BOP

& DAMPER, START CGT02.

(Step 5.2.8) Using GT HIS-11, CTMT MINI PURGE EXH BOP INNER CTMT ISO, OPEN GTHZ0011.

(Step 5.2.9) Using GT HIS-12, CTMT MINI PURGE EXH BOP OUTER CTMT ISO, OPEN GTHZ0012 (Step 5.2.10) Using GT HIS-28, CTMT PURGE EXH DAMPER, BOP OPEN GTHZ0028.

(Step 5.2.11) Using GT HIS-29, CTMT PURGE EXH DAMPER, BOP OPEN GTHZ0029.

(Step 5.2.12) RECORD date and time dampers were opened BOP on Gaseous Radwaste Release Permit.

(NOTE) It is permissible to continue with the remainder of this BOP section while Step 5.2.13 is in progress.

(Step 5.2.13) NOTIFY Rad/Chem Technician (Count Room) of BOP time of purge initiation.

(Step 5.2.14) WHEN containment pressure is less than 10.0 in.

H20, OPEN the following using GT HIS-41, CTMT MINI PURGE SPLY/EXH DAMPERS:

BOP

• GTHZ0041, CTMT MINI PURGE EXH INNER CTMT UPSTRM DMPR OPER

• GTHZ0042, CTMT MINI PURGE AIR SPLY INNER CTMT DNSTRM DMPR OPER

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 1 Page 9 of 30 Event

Description:

Place Mini-Purge in service Proc /Time Position Applicants Actions or Behavior (Step 5.2.15) WHEN containment pressure is less than 4.25 in.

H20 as read on GT PDI-40, CTMT DP, or plant computer point GTD0040, CTMT-AUX BLD DIFF PRESS, PERFORM the following:

BOP

• Using GT HIS-26, CTMT PURGE SYS AIR SPLY DAMPER, OPEN GTHZ0026.

• Using GT HIS-27, CTMT PURGE SYS AIR SPLY DAMPER, OPEN GTHZ0027.

(CAUTION) SGT02, CTMT MINI PURGE AIR SPLY UNIT, should be running anytime CGT02, CTMT MINI PURGE EXH BOP FAN, is running and Equipment Hatch is closed to prevent drawing excessive vacuum in Containment and creating a personnel hazard.

(Step 5.2.16) Using GT HIS-23, CTMT MINI PURGE AIR SPLY BOP UNIT, START SGT02.

(Step 5.2.17) Using GT HIS-5, CTMT MINI PURGE AIR SPLY BOP CTMT ISO, OPEN GTHZ0005.

(Step 5.2.18) Using GT HIS-4, CTMT MINI PURGE AIR SPLY BOP CTMT ISO, OPEN GTHZ0004.

(Step 5.2.19) MAINTAIN containment pressure +41.5 to -8.35 BOP in. H20 as read on GT PDI-40, CTMT DP, or plant computer point GTD0040, CTMT-AUX BLD DIFF PRESS.

NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 2 Page 10 of 30 Event

Description:

LTDN HX Temp Cont Valve Controller Fails.

Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 15 minutes or at the discretion of the Lead Examiner

• LTDN HX Temp Cont Valve Fails o Insert ME schematics (EG) m22eg03, X8809d58s009 analog 053247, WEIUBGTC0130TVSPNO AUTO, Value = 1

• When contacted as Primary Operator, respond as directed

• When contacted as the Duty Manager, acknowledge the failure.

Indications Available:

T= 15 Ann 39B LTDN HX DISCH TEMP HI Ann 39A LTDN HX TEMP HI DIVERT OTA-RK-00018 ADD 39B OTA-RK-Implement OTA-RK-00018 ADD 39B, Letdown Heat Exchanger 00018 CRS Discharge Temperature High.

ADD 39B (Note) If Letdown Hx outlet temperature reaches 137°F, letdown will automatically divert to the VCT.

Changing letdown temperature can affect Core reactivity due to boron concentration changes by the Letdown Demineralizers, (concentration raises on raising temperature and lowers on lowering temperature). Reactivity effects of letdown temperature changes are more noticeable at EOL than at BOL.

(Step 3.1) MONITOR the following:

RO

• BG TI-130, LTDN HX OUTLET TEMP

• BGTI-127, REGEN HX LTDN OUTLET TEMP (Step 3.2) IF letdown temperature exceeds 120°F, PERFORM the following for BGTK-130, LTDN HX OUTLET TEMP CTRL:

RO 3.2.1. CHECK output is at OR RAISING towards 100%.

3.2.2. IF required, TAKE MANUAL control and RAISE CCW flow to the Letdown Heat Exchanger.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 2 Page 11 of 30 Event

Description:

LTDN HX Temp Cont Valve Controller Fails.

Proc /Time Position Applicants Actions or Behavior (Step 3.3) IF letdown temperature exceeds 130°F, MANUALLY RO DIVERT letdown to the VCT using BG HIS-129, CVCS DEMIN INLET DIVERT VLV.

(Step 3.4) MONITOR the following:

RO

• BG FI-121A, CHG HDR FLOW

• BG FI-132, LTDN HX OUTLET FLOW (Step 3.5) IF a Charging and Letdown flow mismatch exists, RO ADJUST Charging and Letdown flows as necessary to lower BGTI-127, REGEN HX LTDN OUTLET TEMP.

(Note) High letdown temp may be due to abnormal CCW conditions, (indicated by one or more of the following):

• Improper operation of the SW/ESW temperature control valve for the affected CCW Hx

• CCW Pump Low Flow alarms (Windows 51C, 52C, 53C, or 54C)

• Inadequate CCW flow to the non-essential loop (may be indicated by Window 54F, CCW SEAL HX FLOW HILO)

(Step 3.6) CHECK CCW conditions from available indications, including the temperature of the CCW train supplying the non-BOP essential loop:

• EG TI-31, CCW HX A OUTLET TEMP

• EG TI-32, CCW HX B OUTLET TEMP (Step 3.7) IF CCW appears to be the problem, Refer To OTO-EG-BOP 00001, CCW System Malfunctions - NO (Note) Maximum RCP Seal Injection temperature, (BG TI-216, RCP SEAL WTR INJ TEMP), is:

• 135°F with RCS greater than 400°F

• 150°F with RCS less than 400°F

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 2 Page 12 of 30 Event

Description:

LTDN HX Temp Cont Valve Controller Fails.

Proc /Time Position Applicants Actions or Behavior (Step 3.8) IF letdown temperature cannot be reduced, PERFORM the following per OTN-BG-00001, Chemical And Volume Control RO System.

3.8.1. SECURE normal letdown.

3.8.2. ESTABLISH Excess letdown.

NOTE At Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 3 Page 13 of 30 Event

Description:

SG ASD Fails Open Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 25 minutes or at the discretion of the Lead Examiner

• D SG ASD fails open o Insert Malfunction (AB)PV004A_1, ramp 30 sec, value 1

• When contacted, respond as Duty Manager. Acknowledge entry into the T/S.

• When contacted, respond as the Count Room.

Indications Available:

T= 25 Ann 109F SG PORV Open OTOAB00001, STEAM DUMP MALFUNCTION Prior to entry in to the OTO procedure the BOP may check SG BOP pressure and close the SG ASD.

CRS Enters OTOAB00001, STEAM DUMP MALFUNCTION BOP (Step 1) CHECK Reactor Power LESS THAN 100%

BOP (Step 2) CHECK At Least One SG ASD FAILED OPEN (Step 3) PLACE The Affected SG ASD Controller In Manual And BOP CLOSE The Valve:

• AB PIC4A (SG D)

(Step 4) NOTIFY Count Room Technician Of Opening And Closing BOP Times Of The SG ASD BOP (Step 5) Go To Step 17 CRS (Step 17) INITIATE Actions To Repair The Failed Component

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 3 Page 14 of 30 Event

Description:

SG ASD Fails Open Proc /Time Position Applicants Actions or Behavior (Step 18) REVIEW Technical Specification CRS

• TS 3.7.4 Cond A is applicable CRS (Step 19) PLACE Inoperable Component In The EOSL (Step 21) PERFORM Notifications Per ODPZZ00001 Addendum CRS 13, Shift Manager Communications NOTE Any time after the Tech Specs have been identified and at Lead Examiners discretion move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 4 Page 15 of 30 Event

Description:

SG Tube Leak requiring a downpower Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions T = 35 minutes or at the discretion of the Lead Examiner

• Steam Generator D Tube Leak of 30 gpm o Insert Malfunction (BB) EBB01D, value=30, ramp 5 min

• When contacted, respond as Chemistry that you will perform CTP-ZZ-02590, Primary To Secondary Leakrate Determination

• When contacted, respond as Count Room Tech and inform the Control Room the higher than Normal Radiation readings from D Steam Generator are valid

• When contacted, respond as Duty Manager. Acknowledge entry into the OTO Indications Available:

T=35 Ann 61A, PROCESS RAD HIHI Ann 61B, PROCESS RAD HI OTO-BB-00001, SG Tube Leak OTO-BB- CRS Implement OTO-BB-00001, SG Tube Leak 00001 (Step 1) CHECK if PZR Level can be maintained - YES (eventually becomes - NO)

a. Control charging flow as necessary to maintain PZR level RO b. Check Pressurizer Level - Stable or Rising RNO

• ISOLATE letdown as necessary.

• RAISE charging flow as necessary.

(Step 2) CHECK if VCT Level Can be Maintained - YES RO a. VCT Level - Maintained Greater Than 5% by Normal Makeup

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 4 Page 16 of 30 Event

Description:

SG Tube Leak requiring a downpower Proc /Time Position Applicants Actions or Behavior (Step 3) Notify Chemistry to Perform CTP-ZZ-02590, Primary to CRS Secondary Leakrate Determination (Step 4) Try to identify Affected SG - "D" Steam Generator RO/BOP

• High radiation on N16 monitors at the RM-11 station (Step 5) Determine SG Tube Leak Rate RO/BOP a. Should calculate leak rate of 20 - 40 gpm

b. Leak rate - LESS THAN 50 GPM CRS The applicable TS is TS 3.4.13 Condition B NOTE (NOTE)

• The upper leak rate limit of 75 gpd requires plant shutdown independent of whether this limit is exceeded by a qualitatively confirmed leakage spike or progressively rising leakage.

• To avoid unnecessary shutdown, leakage should be qualitatively confirmed prior to declaration Action level 2 or 3. If a second radiation monitor is not available, actions should be based on the indications of the available monitor.

(Step 6) CHECK if Plant should be Shutdown

a. Using the table in this step determine appropriate actions CRS

• EPRI Action Level 3, > 75 gpd including confirmed spikes

• Perform Actions in Attachment D OTO-(Step D1.a) Initiate Step 7 and commence a controlled shutdown BB-CRS to Mode 3. Reduce power to < 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, and be in Mode

00001, 3 within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Att D (Step D1.a.1) Perform Applicable procedures as necessary CRS

a. OTO-MA-00008, Rapid Load Reduction

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 4 Page 17 of 30 Event

Description:

SG Tube Leak requiring a downpower Proc /Time Position Applicants Actions or Behavior OTO-MA-00008, Rapid Load Reduction OTO- (Step 1) Place Rod Control In AUTO MA- RO 00008 b. SE HS-9 (Step 2) Manage Reactivity

a. Perform Reactivity Management Brief:

CRS

• Discuss Amount and Rate of Turbine Load Reduction

• Determine amount of boric acid needed (CAUTION)

• If using the Load Limit Potentiometer, unloading at greater than 50 MWe per minute may arm the Main Condenser Steam Dumps.

• If changing load reduction methods to the Load Limiter ENSURE Load Set is restored to AT SET LOAD prior to using the Load Limiter.

(NOTE) Steps 3 and 4 may be performed concurrently while continuing in this procedure

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 4 Page 18 of 30 Event

Description:

SG Tube Leak requiring a downpower Proc /Time Position Applicants Actions or Behavior

1. (Step 3) REDUCE Turbine Load at Less than or Equal to 5% per Minute using any of the following:

• REDUCE Turbine load using the %/Min Loading Rate:

a. SLOWLY LOWER Load using the DECREASE LOAD pushbutton until all of the following are met:

Load Limit Limiting Light EXTINGUISHED Decrease Loading Rate "OFF" Light LIT CRS/BOP Loading Rate Limit %/MIN "1/2" Light LIT

b. ROTATE Load Limit Set potentiometer fully clockwise

c. SELECT Decrease Loading Rate ON

d. SET Loading Rate Limit %/Min to desired value

e. LOWER load set MW toward desired load using the DECREASE LOAD pushbutton OR

• REDUCE Turbine the Load Limit Potentiometer load using NOTE For step #4 of OTO-MA-00008, the candidate may either use OTO-MA-00008 step 4 or OTN-BG-00002, Attachment 8. The procedural actions to Borate from the VCT are the same and OTO-MA-00008 steps are listed below.

1. (Step 4) Borate From the BAST by performing any of the CRS/RO following:

• BORATE to the VCT:

RO #(Step 4a) Place BG HS-26, RCS M/U CTRL, in STOP RO #(Step 4b) Place BG HS-25, RCS M/U CTRL SEL, in BORATE

1. (Step 4c) Set Boric Acid Flow Controller, BG FK-110, to the RO desired flow rate RO #(Step 4d) Place BG FK-110 in AUTO RO #(Step 4e) RESET BG FY110B, BA COUNTER, to 000

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 4 Page 19 of 30 Event

Description:

SG Tube Leak requiring a downpower Proc /Time Position Applicants Actions or Behavior

1. (Step 4f) SET BG FY110B for the desired gallons of boric RO acid to be added RO #(Step 4g) PLACE BG HS26 in RUN

1. (Step 4h) WHEN the desired boration is complete, THEN PLACE RO BG HS-26 in STOP RO #(Step 4i) repeat Boration as necessary (Step 5) Initiate Boron Equalization by performing the following:

a. ENERGIZE at least one group of Pressurizer Backup Heaters:

• B/U Group A BB HIS-51A

• B/U Group B BB HIS 52A RO

b. Place Pressurizer Pressure Master Controller in MAN:

• BB PK-455A

c. Lower Pressurizer Pressure Master controller output to 38% to 42%

d. Place Pressurizer Master Controller in AUTO (Step 6) Check MFP Turbine Speed Control - IN AUTO BOP

• FC SK-509B

• FC SK-509C Once the crew starts the shutdown using steps 1-6 of OTO-MA-00008, as proven by observation lowering load 5-10 MWe:

CUE GO TO THE NEXT EVENT AS CUED BY LEAD EXAMINER

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 20 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 60 minutes or at the discretion of the Lead Examiner D SG Tube Rupture

• Insert Malfunction (BB) EBB01D, value=400, ramp 10 min

• When contacted to locally open KA HV 29, wait 3 minutes and report that valve cannot be opened locally, the handwheel spins freely.

• If contacted, respond as Count Room Tech and inform the Control Room the higher than Normal Radiation readings from Steam Generator D are valid

• When contacted, respond as Duty Manger. Acknowledge entry into the OTO Indications Available:

T=60 Ann 42A CHG LINE FLOW HILO Ann 32C PZR LO LEV DEV Ann 111C SG D LEV DEV OTO-BB-00001, Steam Generator Tube Leak (Continuous Action Step 1)

OTO-BB- #(Step 1) CHECK if PZR Level can be maintained 00001 a. Control charging flow as necessary to maintain PZR level

b. Check Pressurizer Level - Stable or Rising - NO RNO b. PERFORM the following:

1) Isolate letdown as necessary

2) RAISE charging flow as necessary

3) If PZR level can NOT be maintained greater than 6%,

THEN PERFORM the following:

a) Manually TRIP the reactor.

b) When reactor trip is verified, THEN ACTUATE SI.

c) Go To E-0, Reactor Trip Or Safety Injection, Step 1 E-0, Reactor Trip or Safety Injection

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 21 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior E-0 CRS Implement E-0, Reactor Trip or Safety Injection NOTE Steps 1 through 4 are immediate actions (Step 1) CHECK Reactor Trip

• Rod Bottom Lights - All Lit RO

• Reactor Trip and Bypass Breakers - Open

• Neutron Flux - Lowering (Step 2) CHECK Turbine Trip BOP

a. Turbine Stop Valves - Closed (Step 3) CHECK Power to AC Emergency Buses BOP a. At Least One Emergency Bus - Energized

b. Both Emergency Buses - Energized (Step 4) CHECK SI Status

a. Check if SI is Actuated

b. Check both Trains of SI Actuated RO

• LOCA Sequencer ANN 30A - Lit

• LOCA Sequencer ANN 31A - Lit

• SB069 SI Actuate Red Light - Lit Solid (Step 5) Perform Attachment A, Automatic Action Verification, RO/BOP while continuing with this procedure (See page 29 of scenario)

BOP (Step 6) CHECK Generator Output Breakers - Open

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 22 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior (Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed (Step 8) CHECK AFW Pumps

a. MD AFW Pumps - B Running (A MD AFW pump BOP tagged out)

b. TD AFW Pump - Running (Step 9) CHECK AFW Valves - Proper Emergency Alignment

• MD AFP Flow Control Valves - Throttled BOP

• TD AFP Flow Control Valves - FULL OPEN

• TD AFP Loop Steam Supply Valves - Both OPEN IF NECESSARY BOP (Step 10) CHECK Total AFW Flow > 285,000 lbm/hr (Step 11) CHECK PZR PORVs and Spray Valves

a. PZR PORVs - Closed BOP b. PZR PORVs - Both in AUTO

c. PORV Block Valves - Both Open

d. Normal PZR Spray Valves - Closed (Step 12) CHECK if RCPs should be Stopped

a. RCPs - Any Running BOP b. ECCS Pumps - At least One Running

c. RCS Pressure - Less than 1425 psig - NO RNO Go To Step 13

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 23 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior

1. (Step 13) CHECK RCS Temperatures BOP

• RCPs Running - Tavg 557 Deg F

• No RCPs Running - Tcold 557 Deg F (Step 14) CHECK if any SG is Faulted

a. CHECK pressures in all SGs:

RO/BOP

• Any SG pressure lowering in an uncontrolled manner -

• Any SG completely depressurized RNO - Go to Step 15 (Step 15) CHECK if SG Tubes are Intact

• Levels in all SGs - "D" NR Level is rising uncontrollably

• SG Steamline N16 radiation - Normal - NO

• Condenser Air Removal radiation - Normal before Isolation - NO RO/BOP

• SG Blowdown and Sample radiation - Normal before Isolation - NO

• SG ASD radiation - Normal

• Turbine Driven Aux Feedwater Pump Exhaust radiation -

normal GO TO E-3, Steam Generator Tube Rupture E-3, STEAM GENERATOR TUBE RUPTURE

• Personnel should be available for sampling during this procedure NOTE

• Seal Injection flow should be maintained to all RCPs

• Step 1 criteria applies until an operator controlled cooldown is initiated

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 24 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior E-3 (Step 1) CHECK if RCPs should be stopped

a. RCPs - Any Running RO b. ECCS Pumps - At Least one Running

c. RCS pressure - Less than 1425 PSIG - NO RNO Go To Step 2 (Step 2) Identify Ruptured SG(s)

• Unexpected rise in any SG narrow range level BOP

• High radiation from any SG sample

• High radiation from any SG steamline

• High radiation from any SG blowdown line sample (Step 3) Isolate Flow From Ruptured SG

a. Adjust ruptured SG ASD controller to 1160 PSIG

• AB PIC-4A (SG D)

b. Check ruptured SG ASD - closed

• AB PIC-4A (SG D)

c. N/A

d. CHECK SG Blowdown Containment Isolation Valve from BOP ruptured SG - CLOSED

• BM HIS-4A (SG D)

e. Close Steam line Low point Drain valve from ruptured SG

• AB HIS-10 (SG D)

f. Check if C-9 interlock is lit

g. Close MSIV and MSIV bypass valve from ruptured SG

• AB HIS-11 (SG D)

(Step 4) CHECK Ruptured SG level

a. Narrow range level > 7% [25%]

BOP b. Stop feed flow to ruptured SG CLOSE AL HK-5A and AL HK-6A (may have been closed per fold out pages)

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 25 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior Critical Isolate feedwater flow into and steam flow from the ruptured CREW Task SG before a transition to ECA-3.1 occurs.

RO/BOP (Step 5) CHECK Ruptured SG Pressure - > 340 psig If RCPs are NOT running, the following steps may cause a false CSF-1, Figure 4, Integrity Status Tree indication for the ruptured CAUTION loop. Disregard the ruptured loop T-cold indication until after performing Step 29 After the low steamline pressure SI signal is blocked, main NOTE steamline isolation will occur if the high steam pressure rate setpoint is exceeded.

(Step 6) Initiate RCS Cooldown

a. CHECK RCS pressure - < 1970 PSIG

b. Block Steamline Pressure SI

c. Determine required core exit temperature (based on table in E-3 and Lowest Ruptured SG Pressure

d. Dump steam to condenser from the intact SGs at maximum rate using steam dumps or ASDs BOP e. Core exit TCs - less than required temperature - NO RNO - WHEN core exit TCs are REQUIRED TEMPERATURE less than required temperature, THEN PERFORM Steps 6.f and 6.g. Continue with Steps 7 through 12 without delay while continuing with cooldown.

f. Stop the RCS cooldown

g. Maintain core exit TCs - Less than required Temperature (Step 7) Check Intact SG Levels:

a. Narrow Range levels - Greater than 7% [25%]

BOP

b. Control feed flow to maintain narrow range levels between 22% [26%] and 52%.

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 26 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior (Step 8) Check PZR PORVs and Block Valves

a. Power to Block Valves - Available BOP

b. PZR PORVs - CLOSED

c. Block Valves - Both Open RO (Step 9) Reset SI.

RO (Step 10) Reset Containment Isolation Phase A and Phase B EVENT 7 (Step 11) Establish Instrument Air to Containment:

a. Check if ESW to Air Compressor valves - OPEN

• EF HIS-43

• EF HIS-44

b. Start Air Compressor(s).

BOP

• KA HIS-3C

• KA HIS-2C

c. Open Instrument Air Supply Containment Isolation valve.

• KA HIS-29 RNO locally open the valve, continue with Step 12 CUE When contacted to locally open KA HV 29, wait 3 minutes and report that valve cannot be opened locally, the handwheel spins freely.

(Step 12) Check if RHR Pumps should be stopped:

a. RHR Pumps - Any running with suction aligned to RWST BOP

b. RCS Pressure - Greater than 325 psig

c. STOP RHR Pumps and Place in standby.

(Step 13) Check if RCS Cooldown should be stopped:

a. Core exit TCs - Less than required temperature RO

b. Stop RCS cooldown.

c. Maintain core exit TCs - Less than required temperature.

NOTE D RCP may exhibit signs of cavitation BOP (Step 14) Check Ruptured SG pressure - Stable or Rising

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 27 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior (Step 15) Check RCS Subcooling - Greater than 50 ºF [70 ºF]

• Containment Pressure - Normal RO

• Containment Normal Sump level - Normal

• Containment Radiation - Normal before isolation (Step 16) Depressurize RCS to Minimize Break Flow and Refill PZR:

RO

a. Normal PZR Spray - Available - NO RNO: Go to Step 17.

(Step 17) Depressurize RCS using PZR PORV to Minimize Break Flow and Refill PZR:

a. PZR PORV - At least One Available.

b. Open One PZR PORV until any of the following conditions are satisfied:

• Both of the following:

1) RCS pressure - Less than Ruptured SG Pressure RO

2) PZR level - Greater than 9% [29%]

OR

• PZR Level - Greater than 74% [64%]

OR

• RCS Subcooling - Less than 30°F [50°F]

c. Close PZR PORV.

RNO: Close associated Block Valve Critical Terminate the RCS depressurization by closing PORV block CREW Task Valve prior to Loss of Subcooling RO (Step 18) CHECK RCS Pressure - RISING

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 28 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior (Step 19) CHECK If ECCS Flow Should Be Terminated:

a. RCS subcooling - Greater Than 30F [50F]

b. Secondary heat sink:

• Narrow range level in at least one intact SG -

GREATER THAN 7% [25%]

RO OR

• Total feed flow to SG(s) - GREATER THAN 285,000 LBM/HR AVAILABLE

c. RCS pressure - STABLE OR RISING

d. PZR level - GREATER THAN 9% [29%]

NOTE Once the PORV block Valve has been closed in STEP 17 OR EVAL at the discretion of the Lead evaluator - The Scenario can be STOPPED

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 29 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior Attachment A, Automatic Action Verification E-0 Att A RO/BOP (Step A1) CHECK Charging Pumps - Both CCPs running RO/BOP (Step A2) CHECK SI and RHR Pumps - All running RO/BOP (Step A3) CHECK ECCS Flow - BIH flow indicated (Step A4) CHECK ESW Pumps - BOTH RUNNING RO/BOP

• EF HIS-55A

• EF HIS-56A (Step A5) CHECK CCW Alignment:

a. CCW Pumps - ONE RUNNING IN EACH TRAIN

b. CCW Service Loop Supply and Return valves for one operating CCW pump - OPEN RO/BOP c. OPEN CCW To RHR HX valves

d. CLOSE Spent Fuel Pool HX CCW Outlet Valves

e. STOP Spent Fuel Pool Cooling Pump(s)

f. RECORD The Time Spent Fuel Pool Cooling Pump Secured (Step A6) CHECK Containment Cooler Fans - RUNNING IN RO/BOP SLOW SPEED (Step A7) CHECK Containment Hydrogen Mixing Fans -

RO/BOP RUNNING IN SLOW SPEED RO/BOP (Step A8) CHECK If Containment Spray should Be Actuated - NO

Appendix D Operator Action Form ES-D-2 Op Test No.: 2014-1 Scenario # 4 rev 1 Event # 5, 6, 7 Page 30 of 30 Event

Description:

Steam Generator D Tube Rupture / Reactor Trip / Mini-Purge Failure to isolate / PZR PORV fails to close Proc /Time Position Applicants Actions or Behavior (Step A9) CHECK If Main Steamlines Should Be Isolated:

RO/BOP

• Containment pressure > 17 psig

• Steamline pressure - LESS THAN 615 PSIG (Step A10) CHECK ECCS Valves - PROPER EMERGENCY RO/BOP ALIGNMENT RO/BOP (Step A11) CHECK Containment Isolation Phase A RO/BOP (Step A12) CHECK SG Blowdown Isolation:

(Step A13) CHECK Both Trains of Control Room Ventilation RO/BOP Isolation (Step A14) CHECK Containment Purge Isolation

a. ESFAS status panels CPIS sections:

• SA066X WHITE lights ALL LIT - NO

• SA066Y WHITE lights ALL LIT - NO RNO Manually ACTUATE CPIS:

RO/BOP

• SA HS11 (Will NOT Close)

• SA HS15 IF CPIS damper(s) are NOT closed, THEN manually CLOSE damper(s) as necessary.

Manually close GT-HZ-12 (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

ES-301-5 Facility: Callaway Date of Exam: 12/08/2014 Operating Test No.: 2014-1 Crew A SRO-I: I1, I2, RO: R1 A E Scenarios P V 2 3 4 T M P E O I L N T N CREW POSITION CREW POSITION CREW POSITION I T A I C I1 I2 R1 I2 I1 R1 I1 R1 I2 L M A T U N Y M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 3 4 2 1 SRO-I NOR 1 1 2 1 (I1)

I/C 2,3,4, 2,3,6, 4 1,4,7 12 5,8 7 MAJ 6 5,6 5 4 2 TS 2,3,4 3,4 5 2 RX 3 1 1 SRO-I NOR 1 1 1 (I2)

I/C 1,2,4, 2,3,5 3,4,6 10 4 7

MAJ 6 5,6 5 4 2 TS 1,2 2 2 RX 4 1 1 RO NOR 1 1 1 (R1)

I/C 1,2,3, 9 4 4,7,8 2,7 4

MAJ 6 5 5 3 2 TS 0 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 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 Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 1 of 4

ES-301-5 Facility: Callaway Date of Exam: 12/08/2014 Operating Test No.: 2014-1 Crew B SRO-I: I3, I5 A E Scenarios P V 2 3 T M P E O I L N CREW POSITION CREW POSITION CREW POSITION T N I T A I C L M I5 I3 Surr I3 I5 Surr A T U ogat ogat N Y e e M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 3 1 1 SRO-I NOR 0* 1 (I3)

I/C 1,2,4 7 4 2,3,5

,7 MAJ 6 5,6 3 2 TS 1,2 2 2 RX 3 1 1 SRO-I NOR 1 1 1 (I5)

I/C 2,3,4, 8 4 1,4,7 5,8 MAJ 6 5,6 3 2 TS 2,3,4 3 2 RX NOR I/C MAJ TS RX NOR I/C MAJ TS 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 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 Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 2 of 4

ES-301-5 Facility: Callaway Date of Exam: 12/08/2014 Operating Test No.: 2014-1 Crew C SRO-I: I4, I6 A E Scenarios P V 2 3 T M P E O I L N CREW POSITION CREW POSITION CREW POSITION T N I T A I C L M I6 I4 Surro I4 I6 Surro A T U gate gate N Y M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 3 1 1 SRO-I NOR 0* 1 (I4)

I/C 1,2,4, 8 4 2,3,5 7

MAJ 6 5,6 3 2 TS 1,2 2 2 RX 3 1 1 SRO-I NOR 1 1 1 (I6)

I/C 2,3,4, 8 4 1,4,7 5,8 MAJ 6 5,6 3 2 TS 2,3,4 3 2 RX NOR I/C MAJ TS RX NOR I/C MAJ TS Instructions:

3. 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 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 Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

4. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 3 of 4

ES-301-5 Facility: Callaway Date of Exam: 12/08/2014 Operating Test No.: 2014-1 A E Scenarios P V 1 T M P E O I L N T N CREW CREW CREW CREW I T POSITION POSITION POSITION POSITION A I C L M A T U N Y M(*)

T P S A B S A B S A B S A B R I U E R T O R T O R T O R T O O C P O C P O C P O C P RX NOR SPARE I/C 1,2 1,3 2,6

,3, ,7 6,7 MAJ 4,5 4,5 4,5 TS 1,3 Instructions:

5. 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 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 Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

6. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

SRO ATC BOP Scenario 3 12/9/14 0730-0945 Crew B I3 I5 Surrogate 12/9/14 0945-1200 Crew C I4 I6 Surrogate 12/9/14 1230-1445 Crew A I2 I1 R1 Scenario 2 12/10/14 0730-0945 Crew C I6 I4 Surrogate 12/10/14 0945-1200 Crew B I5 I3 Surrogate 12/10/14 1230-1445 Crew A I1 I2 R1 Scenario 4 12/11/14 0730-0945 Crew A I1 R1 I2 Page 4 of 4

ES-301 Competencies Checklist Form ES-301-6 Facility: Date of Examination: Operating Test No.:

APPLICANTS RO RO SRO-I SRO-I SRO-U SRO-U Competencies SCENARIO SCENARIO 1* 2 3 4 1* 2 3 4 Interpret/Diagnose 1,2,3,4 3,4,5,6 1,2,3,4 2,3,4,5 1,2,3,4 3,4,5,6 1,2,3,4 2,3,4,5 Events and Conditions ,5,6,7 ,7,8 ,5,6,7 ,6,7 ,5,6,7 ,7,8 ,5,6,7 ,6,7 Comply With and 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 Use Procedures (1) ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 8 8 Operate Control 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 Boards (2) ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 8 8 Communicate 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 and Interact ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 8 8 Demonstrate 1,2,3,4 1,2,3,4 1,2,3,4 1,2,3,4 Supervisory Ability (3) ,5,6,7 ,5,6,7, ,5,6,7 ,5,6,7 8

Comply With and 1,3 2,3,4 1,2 3,4 Use Tech. Specs. (3)

Notes:

(1) Includes Technical Specification compliance for an RO.

(2) Optional for an SRO-U.

(3) Only applicable to SROs.

• Spare scenario 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.