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 NUREG-1021, Revision 9 Facility: Callaway Date of Examination:

12/8/2014 Examination Level

RO Operating Test Number:

2014-1 Administrative Topic (see Note) Type Code*

Describe activity to be performed Conduct of Operations A1 R, M 2.1.25 (3.9) Ability to interpret reference materials, such as graphs, curves, tables, etc.

JPM: Determine Time to Boil for a Loss of Shutdown Cooling Conduct of Operations A2 R , D 2.1.18 (3.6) Ability to make accurate, clear, and concise logs, records, status boards, and reports. JPM: Complete RCS Inventory Balance Equipment Control A 3 R, D , P* 2.2.12 (3.7

) Knowledge of surveillance procedures.

JPM: Review Pump Run Data and Determine if Acceptance Criteria are Met Radiation Control A 4 R, M 2.3.14 (3.4) Knowledge of radiation or contamination hazards that may arise during normal, abnormal, or emergency conditions or activities.

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 2011"was drawn from the hardhat.

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 NUREG-1021, Revision 9 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.

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Page 1 of 2 Facility: Callaway Date of Examination:

12/8/2014 Examination Level

S RO Operating Test Number:

2014 - 1 Administrative Topic (see Note) Type Code*

Describe activity to be performed Conduct of Operations A 5 R, N 2.1.18 (3.8)

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

JPM: Determine Reportability for a Required Shutdown Conduct of Operations A 6 R, D , P* 2.1.37 (4.6

) Knowledge of procedures, guidelines, or limitations associated with reactivity management.

JPM: Review ECP Calculation Equipment Control A 7 R , D 2.2.40 (4.7

) Ability to apply Technical Specifications for a system. JPM: Determine Applicable Technical Specifications Radiation Control A 8 R, M 2.3.14 (3.8

) Knowledge of radiation or contamination hazards that may arise during normal, abnormal, or emergency conditions or activities.

JPM: Determine if Respirator Needs to be Worn Emergency Procedures/Plan A 9 R or S, D 2.4.43 (3.8) Knowledge of emergency communications systems and techniques JPM: Make appropriate Offsite Notifications during a n 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 (N)ew or (M)odified from

• 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 2013R"was drawn from the hardhat.

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Page 2 of 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 5 JPM A1 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 5 JPM A1 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 5 JPM A1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a copy of drawing OOA-BB-00003, Refuel Level Indications, and a copy of OTO

-EJ-00003, Loss of RHR while Operating at Reduced Inventory or Mid

-Loop Provide operator with procedure OTO

-EJ-00003 Candidate obtained correct procedure. S U Comments: 2. Determine using OOA

-BB-00003 that Condition 1 is REDUCED INVENTORY Operator determined condition 1 is Reduced Inventory due to being less than 64" S U Comments: 3. Determine using OOA

-BB-00003 that Condition 2 is MID-LOOP Operator determined condition 2 is Mid

-Loop due to being at 14.5" S U Comments: 4. Determine using OTO-EJ-00003, Step 4, that Figure 4 is used for condition 1 Operator determined: Figure 4 is used for condition 1, Reduced Inventory (Cold Core) S U Comments: 5. Determine using OTO-EJ-00003, Step 4, that Figure 3 is used for condition 2 Operator determined: Figure 3 is used for condition 2, Mid

-Loop (Cold Core)

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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 5 JPM A1 *Critical Step

• 7. Determine time to boil for condition 2 is 34 minutes. Operator determines using Figure 3 time to boil for condition 2 is 33 to 34 minutes S U Comments: 8. JPM IS COMPLETE Record Stop time on page 2.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A1 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

ANSWER S Present plant conditions

______________

Plant condition 3 days from now

______________

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 6 JPM A2 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:

2 0 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-0000 9 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 6 JPM A2 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 Initiating Cues:

The Control Room Supervisor has directed you to determine the RCS leakage using 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 6 JPM A2 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Review the procedure Provide operator with Marked up copy of OSP-BB-00009 ADD 1, RCS Inventory Balance Excessive Leakage or Manual Calculation Candidate reviewed procedure.

S U Comments: 2. Candidate fills in "Performer, Initial/PIN. and Time/Date blocks on Attachment 6.

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

(SEE KEY) 3. Determine change in mass of water in the RCDT. Att 6, STEP 1.b Candidate determined there has been no change in mass of water in the RCDT.

(SEE KEY) S U Comments: *4. Determine the change in mass if water contained in the VCT.

Att 6, STEP 2.a and b Candidate filled in data on Attachment 6 from Attachment 3 and determined Li = 51% AND Lf= 43% and performed calculation in step 2.b and determined change in mas s 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) S U Comments: 5. Determine change in mass of water in the PZR. Att 6, STEP 3.b Candidate determined there has been no change in mass of water in the PZR.

(SEE KEY) S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 6 JPM A2 *Critical Step

6. Determine change in mass of water in the PRT. Att 6, STEP 4.b Candidate determined there has been no change in mass of water in the PRT.

(SEE KEY) S U Comments: 7. Determine change in mass of water in the RCS LOOPS. Att 6, STEP 5.b Candidate determined there has been no change in mass of water in the RCS LOOPS.

(SEE KEY) *8. Summarize RCS Leakages: Att 6, STEP 6.a Candidate transferred data from previous steps and calculated Total RCS 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 Leakage. Att 6, STEP 6.b Candidate determined RCS Identified Leakage is 0.0764.

This information is obtained from Att 1 (SEE KEY)

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 6 JPM A2 *Critical Step

• 10. Determine Unidentified RCS Leakage.

Att, STEP 6.c Candidate determine d Unidentified Leakage is 0.6045 gpm. (range 0.604 to 0.605 gpm) (3 decimal places rounded or cut-off) (SEE KEY) 11. Candidate notifies CRS that they have completed the calculations.

Candidate notified CRS that they have completed the calculations.

S U Comments: 12. THIS ADMIN JPM IS COMPLETE Record Stop time on page 2.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A2 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 Initiating Cues:

The Control Room Supervisor has directed you to determine the RCS leakage using 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 5 JPM A3 09/14/2014 9:15 AM 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 5 JPM A3 09/14/2014 9:15 AM 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 5 JPM A3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. OBTAIN A VERIFIED WORKING COPY OF OSP-EN-P001B, TRAIN B CONTAINMENT SPRAY PUMP INSERVICE TEST Provide the candidate with a copy of ATTACHMENT 4 FILLED IN WITH FIELD DATA OPERATOR OBTAIN ED PROCEDURE COPY S U Comments: *2 CALCULATE ENFO0001 DIFFERENTIAL PRESSURE AND RECORD ON ATTACHMENT4 STEP 6.1.24.e.4 OPERATOR CALCULATES ENFO0001 DIFFERENTIAL PRESSURE AND RECORDS ON ATTACHMENT 4 DIFFERENTIAL PRESSURE CALCULATED TO BE 197.9 PSID S U Comments: *3. USING EQUATION ON ATTACHMENT 4, CONVERT ENFE0030 DIFFERENTIAL PRESSURE INTO GPM FLOW AND RECORD ON ATTACHMENT 4 Step 6.1.24.e.6 OPERATOR CONVERTS ENFE0030 DIFFERENTIAL PRESSURE INTO GPM FLOW AND RECORDS ON ATTACHMENT 4 ENFO0030 FLOW CALCULATED TO BE 307.2 GPM (range 307 to 308, depending on rounding) S U Comments: *4. USING EQUATION ON ATTACHMENT 4, CONVERT ENFE0030 INCHES OF WATER COLUMN DIFFERENTIAL (H) INTO GPM FLOW AND RECORD ON ATTACHMENT 4 Step 6.1.24.e.7 OPERATOR CONVERTS ENFE0030 INCHES OF WATER COLUMN DIFFERENTIAL (H) INTO GPM FLOW AND RECORDS ON ATTACHMENT 4 ENFE0030 FLOW CALCULATED TO BE 2854.3 GPM (range 2854 to 2855 depending on rounding)

S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 5 JPM A3 *Critical Step

• 5. CALCULATE PUMP TOTAL FLOW BY ADDING RECIRC LINE FLOW AND ENFO0001 FLOW AND RECORD ON ATTACHMENT 4 Step 6.1.24.e.8 OPERATOR CALCULATES PUMP TOTAL FLOW BY ADDING RECIRC LINE FLOW AND ENFO0001 FLOW AND RECORDS ON ATTACHMENT 4 PUMP TOTAL FLOW CALCULATED TO BE 3161.5 GPM (range 3161 to 3162 depending on rounding)

S U Comments: *6. CALCULATE PUMP DIFFERENTIAL PRESSURE AND RECORD ON ATTACHMENT 4 Step 6.1.24.e.11 OPERATOR CALCULATES PUMP DIFFERENTIAL PRESSURE AND RECORDS ON ATTACHMENT 4 PUMP DIFFERENTIAL PRESSURE CALCULATED TO BE 203.6 PSID (range 203 to 204 depending on rounding) S U Comments: *7. DETERMINE IF SURVEILLANCE RESULTS FROM ATTACHMENT 4 MEET ACCEPTANCE CRITERIA OPERATOR DETERMINES THAT ACCEPTANCE CRITERIA IS MET Step 3.1: GROUP B PUMP TESTING NOT APPLICABLE 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 S U Comments: 8. JPM COMPLETE Record Stop time on page 2. RECORD STOP TIME ON PAGE 2 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A3 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 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 PEN01 B start time:

TODAY Step 6.1.20 SGL13B, AUX BLD CSP B RM CLR , started as required? (circle one)

YES / NO Step Parameter Actual Value Normal Range Alert Range Required Action Range Baseline Low High 6.1.24.e.2 ENFO00001 Press at ENV0108 (psig) 236.1 N/A N/A N/A N/A 200 6.1.24.e.3 ENFO00001 Press at BNV0027 (psig) 38.2 N/A N/A N/A N/A 37.5 6.1.24.e.4 Differential Pressure across ENFO0001 (psid) 197.9 N/A N/A N/A 162.5 6.1.24.e.5 Recirc Line Inches Of Water Column Differential at ENFE0030 (INWC) 549.8 N/A N/A N/A N/A 550 6.1.24.e.6 ENFO0001 Flow (gpm) 307.2 N/A N/A N/A N/A 278.4 6.1.24.e.7 Recirc Line Flow at ENFE0030 (gpm) 2854.3 N/A N/A N/A N/A 2854.8 6.1.24.e.8 Total Pump Flow (gpm

) 3161.5 3130 to 3190 N/A N/A N/A 3133.2 6.1.24.e.9 Disch Press Test Gauge at ENV0034 (psig) 237.2 N/A N/A N/A N/A 238 6.1.24.e.10 Suct Press Test Gauge at ENV0033 (psig) 33.6 N/A N/A N/A N/A 31 6.1.24.e.11 Pump Differential Pressure (psid) 203.6 192.5 to 213.2 186.3 to < 192.5 < 186.3 > 213.2 207 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:

3-15-1 5 4-5-1 5 Comments:

_____________________________________________________________________________

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 4 JPM A4 09/14/2014 9:42 AM 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 4 JPM A4 09/14/2014 9:42 AM 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 with out a respirator.

Start Time:

Stop Time:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 4 JPM A4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *1. Candidate calculates dose without a respirator.

Calculates dose without respirator as follows:

External dose = (50 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) x 4hours x 2.5 mrem/DAC

-hr = 20 mrem Total Dose

- 220 mrem (See KEY) S U Comments: *2. Candidate calculates dose with a respirator.

Calculates dose without respirator as follows:

External dose = (1.15 (EF) 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) (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) S U Comments: *3. Candidates selects t o have the job completed with out a respirator.

Job should be done with out a respirator (See Key) S U Comments 4. JPM IS COMPLETE RECORD STOP TIME ON PAGE 2. S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A4 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.

Respiratory Protection / TEDE ALARA Evaluation WorksheetHDP-ZZ-01200H140.0010Page 1 of 1CA268406/30/2014ALARA Package Number:RWP Number:Task

Description:

Total Person-Hrs:Work Location:Working Dose Rate:DAC Fraction:Contamination Level:Efficiency Factor 3 (FF):Comments:IndividualTaskRespirator TypeProtection Factor (PF) 4Person-hrs x 50mRem/hr=200mRem externalDAC Fraction 2 x 4Person-hrs x2.5mRem/DAC-hr

=20mRem internal DAC Fraction x 4Person-hrs x2.5mRem/DAC-hr

=mRem internal Estimated Dose to Implement Engineering Controls

=mRemTotal Dose

=220mRem TEDE1.15EF x 4Person-hrs x 50mRem/hr=230mRem externalDAC Fraction 2 x 4Person-hrs x2.5mRem/DAC-hr 5000 PF=0.004mRem internalDAC Fraction x 4Person-hrs x2.5mRem/DAC-hr 0=mRem internal Estimated Dose to Implement Engineering Controls

=mRemTotal Dose

=230mRem TEDETask should be performed: Without Respirators 4With RespiratorsAs indicated belowPrepared by:Students name Date:Todays dateRP 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.Part 4 - ALARA RecommendationsCommentsAir Supplied Delta Suit 5000With RespiratorsWithout RespiratorsPart 3 - Calculations 20000 dpm/100 cm 2 2 115%300891N/ACask Washdown Pit50 mrem/hrPart 1 - Task Information 1Part 2 - Data and Assumptions 2Craft or Dept.

1. 4857Fuel Rack CleanupOperations CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 4 JPM A5 09/14/2014 9:51 AM 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 A ND RESPONSIBILITIES, REVISION 43 Tools / Equipment:

None CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 4 JPM A5 09/14/2014 9:51 AM 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 4 JPM A5 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of APA

-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES Provide the candidate with a copy of APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES Candidate obtained correct procedure.

S U Comments: *2 Determines a report is required per one of the following:

Attachment 1, Step 5.b OR Attachment 2, #25 OR Attachment 3, #96 Determined a report is required per one of the following:

Attachment 1, Step 5 OR Attachment 2, #25 OR Attachment 3, #96 S U Comments: *3 Determines a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report is required Determined a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> report is needed per S U Comments: *4 Determines the NRC Operations Center is the agency required to be notified. Determined the NRC Operations Center is the agency required to be notified. S U Comments: 5. JPM IS COMPLETE Record Stop time on page 2.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A5 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):_______________

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 5 JPM A6 09/14/2014 10:20 AM 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 5 JPM A6 09/14/2014 10:20 AM 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 to control at HZP, ARO, (k=1.0) 1421 ppm Anticipated RCS Tavg at startup 557°F 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 5 JPM A6 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Provide the candidate with a copy of OSP

-SF-00005 "Estimated Critical Position Calculation" and the print outs from WinPCNDR S U Comments: *2 Candidate reviews Attachment 1 of OSP

-SF-00005 "Estimated Critical Position Calculation" Wrong temperature in step 6.8.1 Applicant identified the error and informs the Shift Manager. See KEY for correct data.

Critical steps of the Attachment are marked on the KEY.

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)

S U Comments: *3. Candidate reviews Attachment 1 of OSP

-SF-00005 "Estimated Critical Position Calculation" Wrong differential boron worth in step 6.12.2 Applicant identified the error and informs the Shift Manager. See KEY for correct data.

Critical steps of the Attachment are marked on the KEY.

Error 2 incorrect "Differential boron worth" in Step 6.12.2 (additional errors are in the calculation due to this error being carried forward) S U Comments: *4. Candidate reviews Attachment 1 of OSP

-SF-00005 "Estimated Critical Position Calculation" Wrong Max rod height in step 6.14.4 Applicant identified the error and informs the Shift Manager. See KEY for correct data.

Critical steps of the Attachment are marked on the KEY.

Error 3 incorrect "Maximum Rod Height" in step 6.14.4 S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 5 JPM A6 *Critical Step

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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A6 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 to control at HZP, ARO, (k=1.0) 1421 ppm Anticipated RCS Tavg at startup 557°F 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 4 JPM A7 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 4 JPM A7 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 4 JPM A7 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Candidate reviews M

-22KA05 to determine impact of closing KAV0662 , SG A AFW CTRL/MS ATMS RELV VLVS KAPCV0200 DNSTRM ISO

. Candidate reviews print.

Candidate determines that closing this valve will isolate nitrogen to the TDAFP control valve and the Atmospheric Steam Dump.

S U Comments: 2 Candidate reviews Technical Specifications and Bases to determine impact of isolating nitrogen to the associated TDAFP flow control valve. Candidate determines that closing KAV0662, SG A AFW CTRL/MS ATMS RELV VLVS KAPCV0200 DNSTRM ISO makes ALHV008, TDAFP TO S/G A HV, inoperable.

S U Comments: 3. Candidate reviews Technical Specifications and Bases to determine impact of isolating nitrogen to the associated Atmospheric Steam Dump.

Candidate determines that closing KAV0662, SG A AFW CTRL/MS ATMS RELV VLVS KAPCV0200 DNSTRM ISO makes ABPV0001, Atmospheric Steam Dump, inoperable.

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

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

. S U Comments: 6. JPM COMPLETE Record Stop time on page 2. RECORD STOP TIME ON PAGE 2 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A7 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): _________________________

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 4 JPM A8 09/14/2014 9:42 AM 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 4 JPM A8 09/14/2014 9:42 AM 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 with out a respirator.

Start Time:

Stop Time:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 4 JPM A8 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *1. Candidate calculates dose without a respirator.

Calculates dose without respirator as follows:

External dose = (50 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) x 4hours x 2.5 mrem/DAC

-hr = 20 mrem Total Dose

- 220 mrem (See KEY) S U Comments: *2. Candidate calculates dose with a respirator.

Calculates dose without respirator as follows:

External dose = (1.15 (EF) 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) (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) S U Comments: *3. Candidates selects t o have the job completed with out a respirator.

Job should be done with out a respirator (See Key) S U Comments 4. JPM IS COMPLETE RECORD STOP TIME ON PAGE 2. S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A8 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.

Respiratory Protection / TEDE ALARA Evaluation WorksheetHDP-ZZ-01200H140.0010Page 1 of 1CA268406/30/2014ALARA Package Number:RWP Number:Task

Description:

Total Person-Hrs:Work Location:Working Dose Rate:DAC Fraction:Contamination Level:Efficiency Factor 3 (FF):Comments:IndividualTaskRespirator TypeProtection Factor (PF) 4Person-hrs x 50mRem/hr=200mRem externalDAC Fraction 2 x 4Person-hrs x2.5mRem/DAC-hr

=20mRem internal DAC Fraction x 4Person-hrs x2.5mRem/DAC-hr

=mRem internal Estimated Dose to Implement Engineering Controls

=mRemTotal Dose

=220mRem TEDE1.15EF x 4Person-hrs x 50mRem/hr=230mRem externalDAC Fraction 2 x 4Person-hrs x2.5mRem/DAC-hr 5000 PF=0.004mRem internalDAC Fraction x 4Person-hrs x2.5mRem/DAC-hr 0=mRem internal Estimated Dose to Implement Engineering Controls

=mRemTotal Dose

=230mRem TEDETask should be performed: Without Respirators 4With RespiratorsAs indicated belowPrepared by:Students name Date:Todays dateRP 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.Part 4 - ALARA RecommendationsCommentsAir Supplied Delta Suit 5000With RespiratorsWithout RespiratorsPart 3 - Calculations 20000 dpm/100 cm 2 2 115%300891N/ACask Washdown Pit50 mrem/hrPart 1 - Task Information 1Part 2 - Data and Assumptions 2Craft or Dept.

1. 4857Fuel Rack CleanupOperations CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 5 JPM A 9 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 5 JPM A 9 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 a n 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 5 JPM A9 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of EIP

-ZZ-00101, Classification of Emergencies ADD 1 Wall Charts and combined EAL attachments Candidate obtained procedure copies S U Comments: 2. NOTE: Initial classification should take place as soon as possible but NOT >15 minutes after recognition of initiating conditions Candidate read note S U Comments: *3. Using the indications available and Attachment 1, Emergency Action Levels, Shift Manager DETERMINE the appropriate emergency classification:

Candidate declared a n Alert based on EAL HA 1.2, within 15 minutes of start S U Comments: Time of declaration

________________

(start of new 15 min clock) 4. Notify facility personnel of EAL declaration EIP-ZZ-00102 Att 5 flow chart Crew acknowledges EAL declaration Candidate announced to the crew the EAL declaration S U Comments: 5. Notify onsite personnel of EAL declaration EIP-ZZ-00102 Att 5 flow chart Candidate sounded the emergency alarm and announced to the site the EAL declaration S U Comments: 6. Is the emergency an alert or higher EIP-ZZ-00102 Att 5 flow chart Yes Candidate determined this was a n Alert S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 5 JPM A9 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 7. Have SAS activate callout per KOA

-ZZ-000200 EIP-ZZ-00102 Att 5 flow chart SAS acknowledges and activated callout using message #1 Candidate had SAS activate callout using message #1 S U Comments: 8. Is emergency a general emergency EIP-ZZ-00102 Att 5 flow chart No Candidate determined this in NOT a general emergency S U Comments: *9. Using Sentry Computer System fill out and send the completed Sentry notification form EIP-ZZ-00102 Att 5 flow chart If asked :

No release above normal operating limits The JPM is complete Candidate filled out the Sentry notification form an sent it within 15 minutes of completing the EAL classification Lines 2, 3, 4, and 5 on Sentry print out are critical

- see KEY (Printed form)

S U Comments: Time sent ____________

(completion time of 2 nd 15 min clock)

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM A9 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

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 1 of 4 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

- BBHV8000A Stroke Test D, P*, S 3 S4 003 Reactor Coolant Pump System (BB) / Start Reactor Coolant Pump during RCS Natural Circulation Cooldown A, M , S 4P 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 Instrumentation N, S 7 S8 008 Component Cooling Water System (EG) / Respond to a loss of CCW to the RCPs A, D, S 8 In-Plant Systems

@ (3 for RO); (3 for SRO

-I); (3 or 2 for SRO

-U) P 1 068 Control Room Evacuation / Operate the PZR Heaters at the Aux Shutdown Panel E, M, R 3 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 Breakers E, M, R 1 @ 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 ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 2 of 4 (A)lternate path (C)ontrol room (D)irect from bank (E)mergency or abnormal in

-plant (EN)gineered safety feature (L)ow-Power / Shutdown (N)ew or (M)odified from bank including 1(A)

(P)revious 2 exams (R)CA (S)imulator 4-6 / 4-6 / 2-3 - / - *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, th103 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.

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 3 of 4 S4 This is a n ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO

-AEO-01-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 startin g '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-05-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 Containmen t (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.

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 4 of 4 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.

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 1 of 3 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

- BBHV8000A Stroke Test D, P*, S 3 S4 003 Reactor Coolant Pump System (BB) / Start Reactor Coolant Pump during RCS Natural Circulation Cooldown A, M, S 4P 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 to the RCPs A, D, S 8 In-Plant Systems

@ (3 for RO); (3 for SRO

-I); (3 or 2 for SRO

-U) P 1 068 Control Room Evacuation / Operate the PZR Heaters at the Aux Shutdown Panel E, M, R 3 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 Breakers E, M, R 1 @ 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 (C)ontrol room (D)irect from bank (E)mergency or abnormal in

-plant (EN)gineered safety feature (L)ow-Power / Shutdown (N)ew or (M)odified from bank including 1(A)

(P)revious 2 exams (R)CA (S)imulator 4-6 / 4-6 / 2-3 - / -

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 2 of 3 *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 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-01-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.

ES-301 Control Room/In

-Plant Systems Outline (Rev 2) Form ES-301-2 Page 3 of 3 S6 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (URO

-AEO-05-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-P01 5J) 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 7 JPM P1 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 7 JPM P1 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 radio s, 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 t hrough 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 7 JPM P1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a copy of OTO

-ZZ-00001, Control room inaccessibility Operator obtained a procedure copy S U Comments: 2. Obtain the following:

Two sets of keys in the emergency break glass cases, two portable radios, and the SM equipment bag Step G1 Given in the initiating cue Operator reads cue sheet and knows he has the items listed S U Comments: 3. Exit control room with BOP through SAS Step G2 "You have exited the Control Room through SAS. Head to the next location" Operator went to ASP S U Comments: 4. Note: radio transmissions allowed in all areas to the plants during this event Operator read note S U Comments: 5. Inform the Control room ASP is manned Step G3 "Control room acknowledges

" Operator informed the control room ASP is manned S U Comments: 6. Check reactor tripped Check neutron flux lowering SE NI

-61X and 61Y Step G4 "SE NI-61X and 61Y show low and slowly lowering" Operator checked SE NI

-61X and 61Y for lowering flux S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 7 JPM P1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *7 Place the following SG Aux Fw Xfr Ctrl Vlv switches in local AL HS-9 AL HS-6 AL HS-8 AL HS-11 Step G5 "All switches indicate remote" After demonstrating how to place switches in local:

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

" Operator placed AL HS-9 AL HS-6 AL HS-8 AL HS-11 in local S U Comments: *8. Place the following switches in local FC HS-313 AL HS-12 AL HS-7 AL HS-5 AL HS-10 Step G 6 "All switches indicate remote" After demonstrating how to place switches in local:

"FC HS-313 AL HS-12 AL HS-7 AL HS-5 AL HS-10 switches are in the local position

" Operator placed FC HS-313 AL HS-12 AL HS-7 AL HS-5 AL HS-10 in local S U Comments: 9. Check MD AFP running AL HIS-22B and 23B Step G7 "AL HIS-22B and 23B both have green lights off and red lights on

" Operator verified both MD AFP AL HIS

-22B and 23B running S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 7 JPM P1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 10. Maintain SG WR level 59% to 69% using AFW Reg Vlv Ctrl AL HK-5B AL HK-7B AL HK-9B AL HK-11B Step G8 "All SG levels at 63

% WR and stable

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

U Comments: 12. Direct OT to check condensate pumps only one running Step G10 "OT reports 'A' condensate pump is the only pump running

" Operator checked only one condensate pump running S U Comments: *13. Maintain RCS cold leg temperature at 557F Place SG steam dump Ctrl Xfr switches in local AB HS-1 AB HS-3 AB HS-2 AB HS-4 Step G 11.a "All switches indicate remote" After demonstrating how to place switches in local:

"AB HS-1 AB HS-3 AB HS-2 AB HS-4 switches are in the local position

" Operator placed all SG steam dump ctrl switches in local S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 7 JPM P1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 14. Maintain RCS cold leg temperature at 557 F using the steam dumps AB PIC-1B AB PIC-2B AB PIC-3B AB PIC-4B Step G11.b "RCS temperature indicates 557

°F" Operator maintained RCS temperature at 557 F Operator checked BBTI-413X BBTI-423X BBTI-433X BBTI-443X S U Comments: 15. Maintain PZR level 25 to 30% Step G12 "PZR level is 25%

" Operator maintained PZR level at 25%

Operator checked BBLI 459B BBLI 460B S U Comments: *16. Check PZR pressure 2225 to 2250 psig Step G 13 "PZR pressure is 2180 psig" After demonstrating how to cycle any of the following:

CYCLE Pzr Htr B/U Group B o BB HIS52B (RP 118B) CYCLE Pzr Htr B/U Group A o BB HIS51B (RP 118A) "PZR pressure is 2240 psig and stable

" Operator manually restored PZR with in band by cycling either:

Pzr Htr B/U Group B And/or Pzr Htr B/U Group A Operator checked BBPI 455B S U Comments: 17. Maintain plant is stable hot standby condition Step G 14 JPM is complete Operator maintained stable conditions S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM P1 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 radio s, 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 t hrough 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 6 JPM P2 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 6 JPM P2 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 6 JPM P2 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of EOP Addendum 22, RCP SEAL ISOLATION Provide operator with procedure copy Operator obtained procedure copy S U Comments: 2. OPEN the following breakers on NG02B (2026 AB South elect pen room) NG02BCR1 (BGHV8100)

NG02BHF1 (EGHV0133)

EOP Add 22 Step 1 "All handles pointing to ON" After operator demonstrates how to open breakers "Handle is in the OFF position " Operator manually opened breakers: NG02BCR1 NG02BHF1 S U Comments: 3. OPEN the following breaker on NG03C (2047 AB North control room HVAC room)

NG03CKF3 (EGHV0061)

EOP Add 22 Step 2 "Handle pointing to ON" After operator demonstrates how to open breaker "Handle is in the OFF position" Operator manually opened breaker: NG03CKF3 S U Comments: *4. Close the following to ISOLATE RCP Seal Injection (2000 AB, Filter Row): BGV0102, CVCS Seal Wtr Inj Fltr A Out Iso (Room 1306B)

BGV0106, CVCS Seal Wtr Inj Fltr B Out Iso (Rm 1306A)

EOP Add 22 Step 3 "BGV0102 stem is down and no threads showing BGV0106 stem is up and threads showing

" After operator demonstrates how to close valve "BGV0106 will not turn (stuck)" Operator close d: BGV0102 BGV0106 - WILL NOT CLOSE - goes to RNO Column (Start of Alternate Path)

S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 6 JPM P2 *Critical Step

5. PERFORM the following:

OPEN the following Breakers on NG04C (2047 AB South Control Room HVAC Room)

NG04CDF5 (BBHV8351A)

NG04CEF4 (BBHV8351B)

NG04CEF5 (BBHV8351C)

NG04CFF3 (BBHV8351D)

EOP Add 22 Step 3, RNO - a CUE OPERATOR:

"Another Operator has already opened the listed breakers

" Operator started heading for the 2047 level of the Aux building to OPEN the listed breakers S U Comments: *6. CLOSE the following valves (2000 AB South piping penetration room):

BBHV8351A, RCP A Seal Wtr Sply (Pen 41)

BBHV8351B, RCP B Seal Wtr Sply (Pen 22)

BBHV8351C, RCP C Seal Wtr Sply (Pen 39)

BBHV8351D, RCP D Seal Wtr Sply (Pen 40)

EOP Add 22 Step 3, RNO - b NOTE: DO NOT ALLOW OPERATOR TO CROSS CONTAMINATION BOUNDARY NOTE: If operator states he will go dress out to close valves say "You are dressed out

" "All valves position indicators are up" After operator demonstrates how to close valve s "Declutch levers have been depressed, the handwheels rotated clockwise until it stopped, and the indicators are down" Operator close d the following valves by moving the handwheel in the clockwise direction:

BBHV8351A BBHV8351B BBHV8351C BBHV8351D S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 6 JPM P2 *Critical Step

• 7. CLOSE the following valve: (2000 AB South piping penetration room)

BGHV8100, Seal Water Return Containment Isolation (Pen 24)

EOP Add 22 Step 4 "BGHV8100 threads indicator is up

" After operator demonstrates how to close valve "BGHV8100 declutch lever has been depressed, the handwheel rotated clockwise until it stopped, and the indicator is down" Operator close d BGHV8100 S U Comments: *8. CLOSE the following valves (2000 AB North piping penetration room)

EGHV0061, RCP Thrm Bar Outer CTMT Iso (Pen

76) EGHV0133, RCP Thrm Bar EGHV0061 Byp Iso (Pen 76) EOP Add 22 Step 5 "EGHV0061 and EGHV0133 indicator s are up" After operator demonstrates how to close valve "EGHV0061 and EGHV0133 declutch levers have been depressed, the handwheel s rotated clockwise until it stopped, and the indicators are down" Operator close d the following valves

EGHV0061 EGHV0133 S U Comments: 9. Inform the CRS when complete The JPM is Complete

________________

Record Stop Time on Page 2 Informed the CRS task is complete S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM P2 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 7 JPM P3 P3 JPM Bank No: MODIFIED URO-AEO-15-P028J KSA No: 068AA1.14 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 7 JPM P3 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 th e 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 7 JPM P3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Note: To aid operators in identifying equipment covered by this procedure, components have been marked by 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 Radio transmissions will be simulated during the performance of this JPM Candidate read note S U Comments: 2. Obtain the following:

The "SSO" key ring in the emergency break glass case 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 Given in the initiating cue Candidate read cue sheet and knows t hey have the items listed S U Comments: 3. Exit control room through SAS Step A2 Given in the initiating cue Candidate read cue sheet and knows they have exit ed control room through SAS Candidate went to The North HVAC Room S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 7 JPM P3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *4. OPEN The Following Breaker On NG03C: NG03CEF4, Fdr Bkr To ALHV0036 CST To TDAFW Pmp Iso Step A3 "Breaker initially indicates ON" After demonstrating ability to open a breaker, "The breaker indicates OFF" Candidate opened NG03CEF4, Fdr Bkr To ALHV0036 CST To TDAFW Pmp Iso S U Comments: 5. Proceed to the South HVAC Room (AB 2047 Rm 1501) Step A4 Candidate proceeded to the South HVAC room S U Comments: *6. OPEN The Following Breakers On NG04C by using the handswitch on the cubicle door: NG04CNF3, Fdr Bkr To EFHV0052 ESW To B CCW Hx Iso NG04CKF1, Fdr Bkr To EGHV0054 CCW Trn B Sply/Rtn Iso NG04CKF2, Fdr Bkr To EMHV8803B Boron Inj Header Inlet Iso Vlv NG04CKF3, Fdr Bkr To EMHV8801B Boron Inj Header Discharge Iso Valve NG04CJF3, Fdr Bkr To EGHV0016 CCW Trn B Sply/Rtn Iso NG04CFF1, Fdr Bkr To BGHV8105 Chg Hdr To Regen Hx Outer Ctmt Iso Step A5 "Breaker initially indicates ON" After demonstrating ability to open and locate the breaker by using the handswitch on the cubicle door: "The breaker indicates OFF" Repeat for each breaker Candidates opened the Following Breakers On NG04C by using the handswitch on the cubicle door: NG04CNF3, Fdr Bkr To EFHV0052 ESW To B CCW Hx Iso NG04CKF1, Fdr Bkr To EGHV0054 CCW Trn B Sply/Rtn Iso NG04CKF2, Fdr Bkr To EMHV8803B Boron Inj Header Inlet Iso Vlv NG04CKF3, Fdr Bkr To EMHV8801B Boron Inj Header Discharge Iso Valve NG04CJF3, Fdr Bkr To EGHV0016 CCW Trn B Sply/Rtn Iso NG04CFF1, Fdr Bkr To BGHV8105 Chg Hdr To Regen Hx Outer Ctmt Iso S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 7 JPM P3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *7. Place Class 1E electrical equipment A/C Unit B local hand switch in ISO/RUN (on EAST wall):

GKHS0103 Step A6 "Local hand switch is in ISO/RUN

" Candidate placed local hand switch in ISO/RUN S U Comments: 8. PROCEED To CCW Pump A And CCW Train A Heat Exchanger Room (AB 2026 Rm 1406)

Step A7 Candidate PROCEED ED To CCW Pump A And CCW Train A Heat Exchanger Room (AB 2026 Rm 1406)

S U Comments: *9. CLOSE ESW To CCW Trn A Iso: (Near the wall, WEST of 'A' CCW Pump)

EGV0182 Step A8 "EGV0182 stem indicates down" Candidate closed EGV0182, ESW To CCW Trn A Iso S U Comments: 10. PROCEED To CCW Pump B And CCW Train B Heat Exchanger area (AB 2026 Rm 1401)

Step A9 Candidate proceeded To CCW Pump B And CCW Train B Heat Exchanger area (AB 2026 Rm 1401)

S U Comments: *11. CLOSE ESW To CCW Trn B Iso: (SE Corner of Room Behind HVAC) EGV0185 Step A10 "EGV0185 handwheel stops turning and the stem is down" Candidate closed EGV0185, ESW To CCW Trn B Iso S U Comments: *12. In the CCW Pump B And CCW Train B Heat Exchanger Room POSITION The Following Valve: (South Wall Center) EFHV0052, ESW Trn B To CCW Hx B Hv - OPEN Step A11 "EFHV0052 declutch lever depressed, handwheel turned counterclockwise until it stopped, and the indicator shows open" Candidate opened EFHV0052, ESW Trn B To CCW Hx B H v S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 7 JPM P3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *13. On The Plant West Wall, Manually OPEN EGHV0054, CCW TRN B SPLY ISO HV (North of 'B' CCW HX)

Step A12 "EGHV0054 declutch lever depressed, handwheel turned counterclockwise until it stopped, and the indicator shows open" Candidate opened EGHV0054, CCW TRN B SPLY ISO HV S U Comments: *14. In The EAST/WEST Corridor Leading To The Rod Drive MG Set Room, Manually OPEN EGHV0016, CCW TRN B RTN ISO Step A13 "EGHV0016 declutch lever depressed, handwheel turned counterclockwise until it stopped, and the indicator shows open" Candidate opened EGHV0016, CCW TRN B RTN ISO S U Comments: 15. PROCEED To Rod Drive MG Set Room (AB 2026 Rm 1403) Step A14 Candidate proceeded to Rod Drive MG Set Room (AB 2026 Rm 1403)

S U Comments: *19. Perform the following:

Locally trip both Rx trip breakers Open Locally trip both Rx trip bypass breakers Open Step A15 After pressing the TRIP button: "Both Rx trip breakers are open Both Rx trip bypass breakers are open

" Candidate opened both Rx trip and bypass breakers S U Comments: 20. Inform the SM Att A through step A15 is complete SM acknowledges JPM is complete Candidate informs the SM he has completed step A15 S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM P3 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 th e 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 5 JPM S1 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 5 JPM S1 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 5 JPM S1 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of Attachment 6 of OTN-BG-00002 Provide operator with procedure copy Operator obtained procedure copy S U Comments: 2. Attachment 6 "Dilute Mode of RMCS" NOTE: This attachment provides direction for frequently performed, nominal 120 gpm dilutions Operator read note S U Comments: 3. PLACE BG HS

-26, RCS M/U CTRL, in STOP Attachment 6 Step 1 Operator PLACED BG HS

-26 in STOP BG HS-26 is in STOP S

U Comments: *4. PLACE BG HS

-25, RCS M/U CTRL SEL, in DIL Attachment 6 Step 2 Operator PLACED BG HS

-25 in DIL BG HS-25 is in DIL S U Comments: 5. RESET BG FY

-111B, COMBINED M/U & BA FLOW TOTALIZER, to

000. Attachment 6 Step 3 Operator RESET BG FY-111B, COMBINED M/U &

BA FLOW TOTALIZER, to 000. BG FY-111B, COMBINED M/U & BA FLOW TOTALIZER, is set to 000. S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 5 JPM S1 *Critical Step

6. NOTE: When setting BG FY-111B, allowance should be made in the setpoint to compensate for instrument inaccuracies and isolation valve closure times on total flow delivered. (Step 3.1.9 contains more information if required.)

Operator read note S U Comments: *7. ENSURE BG FY

-111B is set to deliver the desired amount of makeup water.

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

S U Comments: *8. PLACE BG HS

-26, RCS M/U CTRL, in RUN Attachment 6 Step 5 Operator PLACED BG HS

-26 in RUN BG HS-26 is in RUN S U Comments: 9. WHEN the desired amount of water has been added, PLACE BG HS-26, RCS M/U CTRL, in STOP. Attachment 6 Step 6 Operator PLACED BG HS-26, RCS M/U CTRL, in STOP. BG HS-26 is in STOP S U Comments: 10. IF required, PERFORM the following:

PLACE BG HS

-25, RCS M/U CTRL SEL, in AUTO PLACE BG HS

-26, RCS M/U CTRL, in RUN.

Attachment 6 Step 7.a

and b. Operator PLACED BG HS-25, RCS M/U CTRL SEL, in AUTO and BG HS-26, RCS M/U CTRL, in RUN

. BG HS-25, RCS M/U CTRL SEL, is in AUTO BG HS-26, RCS M/U CTRL, is in Normal after RUN. S U Comments: 11. JPM IS COMPLETE RECORD STOP TIME ON PAGE 2. S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S1 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

.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 9 JPM S2 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 9 JPM S2 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 9 JPM S2 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Review OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block Provide Operator with marked up copy of OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block Operator review ed OTG-ZZ-00006 Addendum 04, Initial RCS Depressurization and SI Block S U Comments: 2. Review Precautions and Limitations.

Step 3.1 and .2 IF ASKED, provide operator with a copy of OTG-ZZ-00006, Plant Cooldown Hot Standby to Cold Shutdown Operator review ed Precautions and Limitations.

S U Comments: 3. Review General Notes.

Step 3.3 IF ASKED, provide operator with a copy of OTG-ZZ-00006, Plant Cooldown Hot Standby to Cold Shutdown Operator review ed General Notes.

S U Comments: 4. Review Prerequisites Step 4 Operator review ed Prerequisites All prerequisites have been initialed or signed S U Comments: 5. Continuous Actions Prior to blocking SI, MAINTAIN narrow range pressure between 1900 psig and 2250 psig.

Step 5.1.1 Operator reviewed continuous action step and initialed "Inititated" line S U Comments: 6 Continuous Actions After blocking SI, MAINTAIN narrow range pressure between 1700 psig and 1900 psig.

Step 5.1.2 Operator reviewed continuous action step and initialed "Inititated" line S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 9 JPM S2 *Critical Step

7. LOWER RCS pressure towards 1900 psig as follows: 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 Operator ensured all Pressurizer Backup Heaters are energized S U Comments: 8. MONITOR pressure using the lowest reading Pressurizer 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 Operator monitored pressure using the lowest reading Pressurizer Pressure indicator S U Comments: The Operator must use any one of the next 3 step s of the JPM to lower pressure. Only the step that the Operator used is a Critical Step.

• 9. INITIATE depressurization by performing one of the following:

Using BB PK

-455A, PZR PRESS MASTER CTRL, in AUTO, slowly adjust the potentiometer to lower pressure.

Step 5.2.1.c.1 Operator lowered pressure. Operator adjusted the potentiometer for BB PK-455A, PZR PRESS MASTER CTRL, in AUTO, to lower pressure.

S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 9 JPM S2 *Critical Step

• 10. Using BB PK

-455A, PZR PRESS MASTER CTRL, in MANUAL, slowly lower pressure.

Step 5.2.1.c.2 Operator lowered pressure. Operator used BB PK-455A , PZR PRESS MASTER CTRL, in MANUA L , to lower pressure. S U Comments: *11. Using the Spray Valve Controller for an operating RCS loop, in MANUAL, slowly OPEN the Spray Valve.

BB PK-455B, PZR SPRAY LOOP 1 CTRL BB PK-455C, PZR SPRAY LOOP 2 CTRL Step 5.2.1.c.3 Operator lowered pressure. Operator used the Spray Valve Controller for an operating RCS loop, in MANUAL, slowly OPEN ED the Spray Valve. S U Comments: 12. WHEN Pressurizer Pressure approaches 1900 psig, MAINTAIN pressure between 1900 psig and 1910 psig.

Step 5.2.2 Operator maintained pressure between 1900psig and 1910 psig.

S U Comments: 13. IF desired, ADJUST BB PK-455A, PZR PRESS MASTER CTRL to the new set point AND PLACE in AUTOMATIC.

Step 5.2.3 Operator may have adjusted BB PK-455A, PZR PRESS MASTER CTRL to the new set point AND may have PLACE D in AUTOMATIC.

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

S U Comments: 14. WHEN RCS boron concentration is equal to or greater than the required to block SI below P-11 per OSP

-SF-00001, Shutdown Margin Calculations, THEN CONTINUE to next step.

STEP 5.2.4 Operator verified RCS boron concentration is equal to or greater than the required to block SI below P-11 per OSP

-SF-00001, Shutdown Margin Calculations, Given in Cue S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 9 JPM S2 *Critical Step

15. PERFORM the following to block SI:

ENSURE required boron concentration for blocking SI below P

-11 is met. Step 5.2.5.a Operator verified RCS boron concentration is equal to or greater than the required to block SI below P-11 per OSP

-SF-00001, Shutdown Margin Calculations, Given in Cue S U Comments: 16. On SB069, CHECK Permissive P

-11 status light ON. Step 5.2.5.b Operator verified PERMISSIVE P

-11 STATUS LIGHT IS LIT ON SB069 PERMISSIVE P

-11 STATUS LIGHT IS LIT ON SB069 S U Comments: 17. SET Operator Alarm for BBP1002, AUCT HI PZR PRESS, HI ALM at 1960 psig. Step 5.2.5.c Operator set Operator Alarm for BBP1002, AUCT HI PZR PRESS, HI ALM at 1960 psig.

S U Comments: *18. BLOCK Pressurizer Pressure SI by momentarily depressing:

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

-7, PZR PRESS SI TRN B BLOC/UNBLOCK S U Comments: *19. BLOCK Pressurizer Pressure SI by momentarily depressing:

SB HS-8, PZR PRESS SI TRN A BLOC/UNBLOCK Step 5.2.5.d.2 Operator momentarily depressed SB HS-8, PZR PRESS SI TRN A BLOC/UNBLOCK S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 7 of 9 JPM S2 *Critical Step

20. On SB069, CHECK Pressurizer Pressure Safety Injection signal blocked status lights Train A and Train B are ON Step 5.2.5.e Operator checked Pressurizer Pressure Safety Injection signal blocked status lights Train A and Train B are ON S U Comments: *21 BLOCK Steamline Pressure SI by momentarily depressing:

SB HS-9, STMLINE PRESS SI TRN A BLOC/UNBLOCK Step 5.2.5.f.1 Operator momentarily depressed SB HS-9, STMLINE PRESS SI TRN A BLOC/UNBLOCK S U Comments: *22. BLOCK Steamline Pressure SI by momentarily depressing:

SB HS-10, STMLINE PRESS SI TRN B BLOC/UNBLOCK Step 5.2.5.f.2 Operator momentarily depressed SB HS-10, STMLINE PRESS SI TRN B BLOC/UNBLOCK S U Comments: 23. On SB069, CHECK the Steamline Isolation/Safety Injection signal blocked status lights Train A and Train B are on Step 5.2.5.g Operator checked the Steamline Isolation/Safety Injection signal blocked status lights Train A and Train B are on S U Comments: 24. NOTIFY CRS/SM that the Steam Line Isolation on high negative rate (100 psig in 50 seconds) of steam pressure is now enabled. Step 5.2.5.h Respond as CRS/SM when notified that the Steam Line Isolation on high negative rate (100 psig in 50 seconds) of steam pressure is now enabled. The Operator NOTIFIED the CRS/SM that the Steam Line Isolation on high negative rate (100 psig in 50 seconds) of steam pressure is now enabled. S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 8 of 9 JPM S2 *Critical Step

25. MONITOR Plant Computer screen HEATU or MODE3.

Step 5.2.6 The Operator MONITOR ED Plant Computer screen HEATU or MODE3. S U Comments: 26. MAINTAIN Pressurizer pressure below 1900 psig and above 1700 psig. Step 5.2.7 Operator lowered pressure below 1900 psig and above 1700 psig.

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

Step 5.2.8 S U Comments: 28. OBTAIN procedure completion signature from SM/CRS:

Step 5.2.9 THE CONTROL ROOM SUPERVISOR ACKNOWLEDGES THE TASK IS COMPLETE Operator informed CRS procedure is complete and obtained SM/CRS signature.

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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S2 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 7 JPM S3 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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 7 JPM S3 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 7 JPM S3 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of OSP-BB-V0001 Provide Operator with procedure copy Operator obtained working copy of OSP-BB-V0001 S U Comments: 2. Review Acceptance Criteria Section 3.1 Operator reviewed Acceptance Criteria per Attachment 1 S U Comments: 3. Review Precautions and Limitations Section 4.0 Operator reviewed Precautions and Limitations S U Comments 4. Review Prerequisites Section 5.0 Operator reviewed Prerequisites S U Comments 5. NOTE: The local position indication is performed every refuel prior to Mode 4 startup. These steps may be omitted whe n performing this procedure in Mode 1, 2, or 3 on BBHV8000A.

Prior to 6.1 Examiner Note:

Given in initial cue that local position indication is not required for this test.

Operator read note Given in initial cue that local position indication is not required for this test.

S U Comments 6. NOTE: If BBHV8000A, RCS PZR Out Pwr Oper Rlf HV, is on its backseat for normal operations, the stroke close time will be from the backseat position and not from the OPEN (limit switch) position. Prior to 6.1.1 Operator read note S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 7 JPM S3 *Critical Step

7. Using BB HIS

-455A, PZR PORV, ensure BBPCV0455A is closed Step 6.1.1 Operator ensured BBPCV0455A was closed BB HIS-455A green light is lit and the red light is not lit S U Comments 8. Ensure BB HS-8000A, TRN A Cold O/P Bloc/Arm, is in the BLOCK position Step 6.1.2 Operator ensured BB HS

-8000A BLOCK PB was depressed S U Comments 9. Record Initial Remote Position of BB HIS

-8000A, PZR PORV Block Vlv, on Attachment 1 Step 6.1.3 Operator recorded Initial Remote Position of BB HIS-8000A on Attachment 1 (OPEN is the initial position) S U Comments 10. If Position Indication Testing is scheduled, perform the following:

Step 6.1.4 Operator N/A'd step and proceeded to Step 6.1.5 Given in Initiating Cue that Position Indication Testing is not scheduled S U Comments *11. Using BB HIS

-8000A, PZR PORV Block Vlv, close BBHV8000A and measure the elapsed time between pushing the close pushbutton an d when the open light goes out Step 6.1.5 Operator closed BBHV8000A and measured the elapsed time between pushing the close pushbutton and when the open light went out Measured stroke time was

~25 seconds S U Comments 12. Record Observed Stroke Time Closed for BBHV8000A, RCS PZR Out Pwr Oper Rlf HV, on Attachment 1 Step 6.1.6 If Operator recognizes that the stroke time does NOT meet acceptance and indicates they would stop the test, direct them to complete the test.

Operato r recorded Observed Stroke Time Closed for BBHV8000A on Attachment 1 (Observed stroke time should be ~25 sec)

S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 7 JPM S3 *Critical Step

13. RECORD Full Stroke Remote Position of BB HIS-8000A, PZR PORV Block Vlv, on Attachment 1 Step 6.1.7 Operator recorded Full Stroke Remote Position of Closed for BB HIS-8000A on Attachment 1 S U Comments 14. If Position Indication Testing is scheduled, record the Full Stroke Local Position of BBHV8000A, RCS PZR Out Pwr Oper Rlf HV, on Attachment 1 Step 6.1.8 Operator N/A'd step and proceeded to Step 6.1.9 Given in Initiating Cue that Position Indication Testing is not scheduled S U Comments *15. Using BB HIS

-8000A, PZR PORV Block Vlv, open BBHV8000A and measure the elapsed time between pushing the open pushbutton and when the closed light goes out Step 6.1.9 Operator opened BBHV8000A and measured the elapsed time between pushing the open pushbutton and when the closed light went out BB HIS-8000A red light is lit and the green light is not lit Measured stroke time was ~25 seconds S U Comments 16. Record Observed Stroke Time open for BBHV8000A, RCS PZR Out Pwr Oper Rlf HV, on Attachment 1 Step 6.1.10 Operator recorded Observed Stroke Time open for BBHV8000A on Attachment 1 (Observed stroke time should be ~25 sec)

S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 7 JPM S3 *Critical Step

• 17. Perform the following:

a. Evaluate Observed Stroke Time against the Normal Stroke Time Range and the Maximum Allowable Stroke Time and determine if valve retest is required for BBHV8000A 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 If asked, "Retest will NOT be performed at this time.

" Operator evaluated Observed Stroke Time for BBHV8000A as exceeding the maximum allowable stroke time and NOT meeting acceptance criteria Operator notified SM/CRS that valve stroke time did NOT meet acceptance criteria S U Comments 18. JPM IS COMPLETE RECORD STOP TIME ON PAGE 2. S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S3 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 11 JPM S4 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:

1 5 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 11 JPM S4 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a verified working copy of EOP Addendum 3, Starting An RCP Provide operator with procedure copy Operator obtained procedure copy S U Comments: 2. CAUTIONS: If RCP seal cooling had previously been lost, the affected RCPs should NOT be started prior to a status evaluation If asked - "RCP seal cooling has NOT been lost" Operator read caution S U Comments: 3. NOTES: RCPs should be run in order of priority to provide normal PZR spray: RCP D, RCP A or RCP B, RCP C.

Operator read note S U Comments: 4. ESTABLISH conditions for starting an RCP in order of priority:

13.8 KV Buses

- ENERGIZED PA01 PA02 Step 1.a Operator ensured 13.8 KV Buses PA01 and PA02 energized 13.8 KV Buses PA01 and PA02 are energized S U Comments: 5. RCS pressure

- GREATER THAN 325 PSIG Step 1.b Operator ensured RCS pressure is greater than 325 psig RCS pressure is greater than 325 psig S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 6. Number 1 seal differential pressure - GREATER THAN 200 PSID BB PI-150A Step 1.c Operator ensured RCP D Number 1 seal differential pressure is greater than 200 psid BB PI-150A RCP D Number 1 seal differential pressure is greater than 200 psid S U Comments: 7. VCT pressure

- GREATER THAN 15 PSIG Step 1.d Operator ensured VCT pressure is greater than 15 psig VCT pressure is greater than 15 psig S U Comments: 8. RCP seal injection flow

- BETWEEN 6 GPM AND 13 GPM PER RCP BG FR-157 BG FR-156 BG FR-155 BG FR-154 Step 1.e Operator ensured RCP seal injection flow is between 6 gpm and 13 gpm per RCP BG FR-157 BG FR-156 BG FR-155 BG FR-154 RCP seal injection flow is between 6 gpm and 13 gpm per RCP S U Comments: 9. Number 1 seal leakoff flow - GREATER THAN OR EQUAL TO 0.2 GPM BG FR-157 BG FR-156 BG FR-155 BG FR-154 Step 1.f Operator ensured Number 1 seal leakoff flow is greater than or equal to 0.2 gpm BG FR-157 BG FR-156 BG FR-155 BG FR-154 Number 1 seal leakoff flow is greater than or equal to 0.2 gpm S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 10. CCW To RCS Flow

- INDICATED EG FI-128 EG FI-129 Step 1.g Operator ensured CCW To RCS Flow is indicated EG FI-128 EG FI-129 CCW To RCS Flow is indicated S U Comments: 11. RCP CCW system annunciators

- CLEAR 52A, CCW Lo 70C, RCP A Th Bar 71C, RCP B Th Bar 72C, RCP C Th Bar 73C, RCP D Th Bar 74C, RCP TB CCW Step 1.h Operator ensured RCP CCW system annunciators are clear 52A, CCW Lo 70C, RCP A Th Bar 71C, RCP B Th Bar 72C, RCP C Th Bar 73C, RCP D Th Bar 74C, RCP TB CCW RCP CCW system annunciators are clear S U Comments: 12. START Oil Lift Pump for RCP to be started:

BB HIS-44 Step 1.i Operator started Lift Pump for RCP D BB HIS-44 Lift Pump for RCP D has been started S U Comments: 13. Oil Lift Pump oil pressure interlock WHITE light

- LIT Step 1.j Operator ensured RCP D Oil Lift Pump oil pressure interlock white light is lit RCP D Oil Lift Pump oil pressure interlock white light is lit S U Comments: 14. NOTE: SI must be reset prior to starting RCP C or RCP D to prevent potential shutdown sequencer actuation on undervoltage of XNB02 Operator read note S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 15. RESET SI If Necessary:

SB HS-42A SB HS-43A Step 2 Operator ensured SI is reset SI is reset S U Comments: 16. START Desired RCP As Follows: CHECK associated oil lift pump - RUNNING GREATER THAN 2 MINUTES Step 3.a "The Lift Oil pump has been running for 2 minutes" Operator ensured RCP D oil lift pump has been running greater than 2 minutes S U Comments: 17. START desired RCP:

BB HIS-40 (RCP D)

Step 3.b Operator started RCP D using BB HIS

-40 RCP D is NOT running Alternate Path starts here S U Comments: 18. IF desired RCP can NOT be started, THEN PERFORM the following:

TRY to establish conditions and start another RCP in order of priority. Return To Step 1.

Step 3.b.1) and 2) RNO If asked "Implement procedure as written" Operator determined that 'D' RCP did not start and informed CRS and returned to Step 1 of the procedure.

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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 7 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 20. NOTES: RCPs should be run in order of priority to provide normal PZR spray: RCP D, RCP A or RCP B, RCP C.

Operator read note and determined the next RCP to start is 'A' RCP.

S U Comments: 21. ESTABLISH conditions for starting an RCP in order of priority:

13.8 KV Buses

- ENERGIZED PA01 PA02 Step 1.a Operator ensured 13.8 KV Buses PA01 and PA02 energized 13.8 KV Buses PA01 and PA02 are energized S U Comments: 22. RCS pressure - GREATER THAN 325 PSIG Step 1.b Operator ensured RCS pressure is greater than 325 psig RCS pressure is greater than 325 psig S U Comments: 23. Number 1 seal differential pressure - GREATER THAN 200 PSID BB PI-150A Step 1.c Operator ensured RCP A Number 1 seal differential pressure is greater than 200 psid BB PI-153A RCP A Number 1 seal differential pressure is greater than 200 psid S U Comments: 24. VCT pressure

- GREATER THAN 15 PSIG Step 1.d Operator ensured VCT pressure is greater than 15 psig VCT pressure is greater than 15 psig S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 8 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 25. RCP seal injection flow

- BETWEEN 6 GPM AND 13 GPM PER RCP BG FR-157 BG FR-156 BG FR-155 BG FR-154 Step 1.e Operator ensured RCP seal injection flow is between 6 gpm and 13 gpm per RCP BG FR-157 BG FR-156 BG FR-155 BG FR-154 RCP seal injection flow is between 6 gpm and 13 gpm per RCP S U Comments: 26. Number 1 seal leakoff flow - GREATER THAN OR EQUAL TO 0.2 GPM BG FR-157 BG FR-156 BG FR-155 BG FR-154 Step 1.f Operator ensured Number 1 seal leakoff flow is greater than or equal to 0.2 gpm BG FR-157 BG FR-156 BG FR-155 BG FR-154 Number 1 seal leakoff flow is greater than or equal to 0.2 gpm S U Comments: 27. CCW To RCS Flow

- INDICATED EG FI-128 EG FI-129 Step 1.g Operator ensured CCW To RCS Flow is indicated EG FI-128 EG FI-129 CCW To RCS Flow is indicated S U Comments: 28. RCP CCW system annunciators

- CLEAR 52A, CCW Lo 70C, RCP A Th Bar 71C, RCP B Th Bar 72C, RCP C Th Bar 73C, RCP D Th Bar 74C, RCP TB CCW Step 1.h Operator ensured RCP CCW system annunciators are clear 52A, CCW Lo 70C, RCP A Th Bar 71C, RCP B Th Bar 72C, RCP C Th Bar 73C, RCP D Th Bar 74C, RCP TB CCW RCP CCW system annunciators are clear S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 9 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *29. START Oil Lift Pump for RCP to be started:

BB HIS-41 (BB HIS-42) Step 1.i Operator started Lift Pump for RCP A (or B) BB HIS-41 (BB HIS-42) Lift Pump for RCP A (or B) has been started S U Comments: 30. Oil Lift Pump oil pressure interlock WHITE light

- LIT Step 1.j Operator ensured RCP A (or B) Oil Lift Pump oil pressure interlock white light is lit RCP A (or B) Oil Lift Pump oil pressure interlock white light is lit S U Comments: 31. NOTE: SI must be reset prior to starting RCP C or RCP D to prevent potential shutdown sequencer actuation on undervoltage of XNB02 Operator read note S U Comments: 32. RESET SI If Necessary:

SB HS-42A SB HS-43A Step 2 Operator ensured SI is reset SI is reset SI was reset when attempting to start RCP D, it does not need to be reset again S U Comments: 33. START Desired RCP As Follows: CHECK associated oil lift pump - RUNNING GREATER THAN 2 MINUTES Step 3.a "The Lift Oil pump has been running for 2 minutes" Operator ensured RCP A (or B) oil lift pump has been running greater than 2 minutes S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 10 of 11 JPM S4 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *34. START desired RCP:

BB HIS-37 (RCP A)

(or BB HIS

-38) (RCP B)

Step 3.b Operator started RCP A (or B) using BB HIS

-37 (BB HIS-38) RCP A (or B) is running S U Comments: 35. CHECK RCP

- RUNNING GREATER THAN 1 MINUTE Step 3.c Operator ensured RCP A (or B) has been running greater than 1 minute S U Comments: *36. STOP Oil Lift Pump:

BB HIS-41 (RCP A)

(or BB HIS

-42) (RCP B) Operator stopped Oil Lift Pumps: BB HIS-41 (RCP A)

(or BB HIS

-42) (RCP B) S U Comments: Report to CRS that RCP D did not start. RCP A (or B) has been started.

Operator may request to secure BB HIS 44 (RCP D) Lift oil pump. It is not required to secure this pump. The JPM is Complete

_________________

Record Stop Time on Page 2 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S4 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 6 JPM S5 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 6 JPM S5 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 6 JPM S5 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE NOTE: Any pumps taking suction from the RWST should be stopped if RWST level lowers to 6%. This not e is prior to Step 3 1. OBTAIN A VERIFIED WORKING COPY OF ES-1.3, TRANSFER TO COLD LEG RECIRCULATION.

PROVIDE OPERATOR WITH PROCEDURE COPY OPERATOR OBTAINED PROCEDURE COPY S U Comments: 2. VERIFY CONTAINMENT SPRAY PUMPS ARE RUNNING.

EN HIS-3 EN-HIS-9 Step 6.a OPERATOR VERIFIED BOTH CONTAINMENT SPRAY PUMPS ARE RUNNING. containment spray pumps are indicating a red light 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 S U Comments: 3. VERIFY RWST LEVEL IS LESS THAN 12%.

Step 6.b OPERATOR CHECKED RWST LEVEL IS <12%.

RWST LEVEL INDICATORS AND/OR ANNUNCIATOR 47B, RWST LEVEL LOLO 2 is lit. S U Comments *4. RESET CSAS SB HS-51 SB HS-54 Step 6.c OPERATOR RESET CSAS USING SB HS

-51 AND SB HS-54. Both buttons have been pressed and the red annunciator 59A is not lit S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 6 JPM S5 *Critical Step

• 5. OPEN Containment Recirc Sump To Containment Spray Pump valves:

EN HIS1 EN HIS7 Step 6.d OPERATOR OPENED EN HIS-7 AND attempted to open EN HIS

-1. EN HIS-7 indicates red light on green off EN-HIS-1 indicates green light on red off (Alternate Path)

S U Comments *6. If any valve can NOT be opened, THEN PLACE associated Containment Spray Pump in PULL

-TO-LOCK: EN HIS-3 (EN HV-1) Step 6.d RNO EN-HIS-3 in PULL-TO-LOCK. Containment spray pump 'A' indicates green light on red off and EN

-PI-4 reads 0 psig and EN

-FI-5 reads 0 lbm/hr 7. MONITOR CONTAINMENT SPRAY PUMP DISCHARGE FLOW Step 6.e OPERATOR VERIFIED CONTAINMENT SPRAY PUMP FLOWS USING EN-FI-11. Flow as indicated on EN

-FI-11 shows 1.6X106Lbm/hr S U Comments 8. CLOSE RWST TO CONTAINMENT SPRAY PUMP VALVE BN HIS

-4 Step 6.e OPERATOR CLOSED BN HIS-4. BN-HIS-4 indicates green light on red off S U Comments *9. CLOSE RWST TO CONTAINMENT SPRAY PUMP VALVE BN HIS-3. Step 6.e OPERATOR CLOSED BN HIS-3. BN HIS-3 indicates green light on red off S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 6 JPM S5 *Critical Step

10. START CONTAINMENT SPRAY PUMPS AS NECESSARY Step 6.f IF ASKED ABOUT STARTING PUMPS, PROVIDE FOLLOWING CUE: "CRS DIRECTS YOU TO MAINTAIN CURRENT PLANT CONDITIONS

" OPERATOR VERIFIED NECESSARY CONTAINMENT SPRAY PUMPS ARE RUNNING S U Comments 11. JPM IS COMPLETE RECORD STOP TIME ON PAGE 1.

S U Comments CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S5 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 7 JPM S6 S6 JPM Bank No: MODIFIED URO-AEO-05-C174J(A) KSA No: 064A4.06 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 7 JPM S6 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 7 JPM S6 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a copy of ECA-0.0 Provide operator with procedure copy Operator obtained procedure copy and went to Step 5 of the procedure S U Comments: 2. TRY To Restore Power to Any AC Emergency Bus Energize AC emergency bus with diesel generator:

Check Both DGs Running - NO Step 5.a.1 Operator observed that neither DG A nor DG B is running Neither DG's are running or indicate any voltage or frequency S U Comments: *3. Manually START DG(s)

Step 5.a RNO 1

) Operator Started Both DG(s) by depressing start Pushbuttons:

KJ HS-8A has been pushed S U Comments: 4. Manually START DG(s)

Step 5.a RNO 1

) Operator Started Both DG(s) by depressing start Pushbuttons:

KJ HS-108A has been pushed S U Comments: 5. CHECK AC emergency buses - AT LEAST ONE ENERGIZED NB01 - YES NB02 - YES Step 5.a 2 Operator observed that both NB Buses are energized Both buses are indicating voltage on NE-EI-1 and 2 of 4160 kv and frequency on NE-SI-1 and 3 of 60 Hz S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 7 JPM S6 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 6. CHECK AC emergency buses - AT LEAST ONE ENERGIZED NB01 - YES OR NB02 - YES Step 5.b. Operator determined that NB 01 BUS and NB02 are Energized. NB01 is indicating voltage on NE-EI-1 of 4160 kv and frequency on NE

-SI-1 of 60 Hz NB02 is indicating voltage on NE-EI-2 of 4160 kv and frequency on NE

-SI-3 of 60 Hz 7. CHECK ESW associated with energized AC emergency bus(es)

- RUNNING EF HIS-55A NOT RUNNING EF HIS-56A NOT RUNNING Step 5.c Operator verified:

"A" ESW Pump IS NOT running "B" ESW Pump IS NOT running 'A' ESW pump has green light on and no red light and shows no flow or pressure 'B' ESW pump has green light on and no red light and shows no flow or pressure Alternate path starts here S U Comments: 8. PERFORM the following:

ENSURE ESW To UHS valves are OPEN EF HIS-37 EF HIS-38 Step 5.c RNO c.1 Operator verified:

ESW to UHS valve s are both OPEN Both ESW valves indicate red light on and green light off S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 7 JPM S6 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *9. PERFORM the following:

START ESW Pump(s) as necessary Step 5.c RNO c.2 Operator started ESW Pump "A" using:

EF HIS-55A 'A' ESW pump has red light on green off and indicating on EF

-FI-53 11X10 6 lbm/hr and pressure on EF

-PI-1 of 116 psig S U Comments: 1 0. PERFORM the following:

START ESW Pump(s) as necessary Step 5.c RNO c.2 Operator attempted to start ESW Pump "B" using: EF HIS-56 A 'B' ESW pump has red light off green on a nd indicating on EF

-FI-54 0 lbm/hr and pressure on EF-PI-2 of 0 psig S U Comments: 1 1. PERFORM the following:

IF any DG is running with NO cooling water THEN STOP affected DG(s)

Step 5.c RNO c.3 Operator verified that 'A' DG is now running with appropriate cooling water and 'B' DG is running with NO cooling water S U Comments: 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.

1 2. IF any DG is running with NO cooling water, THEN locally STOP affected DG(s): a) Place Master Transfer Switch to LOC/MAN.

KJ HS109 b) STOP the Diesel.

KJ HS108B Respond as the OT contacted to locally secure the diesel. Use proper 3 way communication repeating back ONLY what the operator directs you to do. The operator has dispatched an OT to Place Master Transfer Switch to LOC/MAN. (KJ HS

-109) and STOPPED the Diesel. (KJ HS-108B) The 'B' DG has stopped Operator may request to open NB0211 prior to stopping EDG per ODP

-ZZ-00025 guidance S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 6 of 7 JPM S6 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1 3. Return To procedure and step in effect and IMPLEMENT Functional Restoration Procedures as necessary Step 5.d Acknowledge as the CRS that Step 5 of ECA

-0.0 is complete The JPM is Complete

__________________

Record Stop Time on Page 2 Operator Completed Step 5 of ECA-0.0 and reported to the CRS actions that were necessary.

S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S6 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.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 6 JPM S7 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 6 JPM S7 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 A 7. 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 6 JPM S7 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. Obtain a copy of Attachment A of OTO

-NN-00001, LOSS OF SAFETY RELATED INSTRUMENT POWER Provide operator with procedure copy Operator obtained procedure copy.

S U Comments: 2. ENSURE the following components are NOT selected: Step A1 Operator ensured the following components are NOT selected S U Comments: NOTE: The Operator will select away from NN01 components on the following switches

• 3. SG A AB FS512C AE LS519C Step A1 Operator selected away from AB FS512C AE LS519C S U Comments: 4. SG B AB FS522C AE LS529C Step A1 Operator selected away from AB FS522C AE LS529C S U Comments: *5. SG C AB FS532C AE LS539C Step A1 Operator selected away from AB FS532C AE LS539C S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 6 JPM S7 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 6. SG D AB FS542C AE LS549C Step A1 Operator selected away from AB FS542C AE LS549C S U Comments: *7. Pressurizer

• BB PS455F BB LS459D (NOT critical) Step A1 Operator selected away from BB PS455F BB LS459D S U Comments: *8. Main Turbine AC PS505Z Step A1 Operator selected away from AC PS505Z S U Comments: *9. PRESS SELECT On STEAM FLOW and Level for ALL Steam Generators on AE SS500, SG Level Control Input Selection.

Step A2 Operator PRESS ED SELECT On STEAM FLOW and Level for ALL Steam Generators on AE SS500, SG Level Control Input Selection.

S U Comments: *10. PLACE BB TS411F, T Defeat Switch in T411 position. Step A3 Operator PLACE D BB TS411F, T Defeat Switch in T411 position.

S U Comments: *11. PLACE BB TS412T, Rod Control Tave Input Channel Defeat Switch in T412 position.

Step A4 Operator PLACE D BB TS412T, Rod Control Tave Input Channel Defeat Switch in T412 position.

S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 6 JPM S7 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE *12. ISOLATE letdown by closing all Orifice Isolation Valve(s):

8149AA (NOT critical) 8149BA (NOT critical) *8149CA Operator ISOLATED letdown by closing all Orifice Isolation Valve(s):

8149AA 8149BA 8149CA S U Comments: *13. REDUCE Charging To RCPs Seals Only By Performing The Following Concurrently:

Slowly CLOSE Back Pressure Control valve: 182 appropriate Charging Discharge Flow Control valve to maintain RCP seal injection flow from 8 gpm to 13 gpm to each RCP while reducing charging flow: BG FK121 (CCP) OR BG FK124 (NCP) 182 is full closed.

Operator slowly CLOSE D Pressure Control valve:

182 Operator manually D appropriate Charging Discharge Flow Control valve to maintain RCP seal injection flow from 8 gpm to 13 gpm to each RCP while reducing charging flow:

BG FK121 (CCP) OR BG FK124 (NCP) Operator ENSURE D BG 182 is full closed.

The critical part of this step is that RCP seal injection flow is 8-13 gpm and BG -182 is closed at the end of this step S U Comments: 14. Report to CRS Attachment A is complete up to Step A 7 Acknowledge report The JPM is Complete

__________________

Record Stop Time on Page 2 Operator report ed to CRS Attachment A is complete up to Step A 7 S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S7 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 pressur e

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 1 of 6 JPM S8 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 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 2 of 6 JPM S8 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:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 3 of 6 JPM S8 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 1. OBTAIN A VERIFIED WORKING COPY OF OTO-BB-00002, RCP OFF-NORMAL and reads NOTE PROVIDE PROCEDURE COPY, IF REQUESTED OPERATOR OBTAINED PROCEDURE COPY and reads NOTE S U Comments: 2. CHECK RCP MOTOR PARAMETERS MEET ALL OF THE FOLLOWING:

MOTOR BEARING TEMPS < 195 F MOTOR STATOR WINDING TEMPS ARE < 311 F CCW LOST TO RCP MOTORS < 10 MIN STEP C1 IF ASKED - IT HAS BEEN LESS THAN 10 MINUTES OPERATOR CHECKED ALL RCP MOTOR PARAMETERS MEET ALL OF THE FOLLOWING:

MOTOR BEARING TEMPS < 195 °F MOTOR STATOR WINDING TEMPS ARE < 311 ° F CCW LOST TO RCP MOTORS < 10 MIN S U Comments: 3. CHECK CCW FLOW TO CONTAINMENT

- NORMAL OR HIGH FOR PLANT CONDITIONS:

EG-FI-128 EG-FI-129 STEP C2 OPERATOR CHECKED NO CCW FLOW TO CONTAINMENT S U Comments: *4. RNO - ENSURE ALL CCW TO CONTAINMENT INNER AND OUTER ISOLATION VALVES ARE OPEN: EG HIS-58 EG HIS-59 EG HIS-60 EG HIS-71 EG HIS-61 EG HIS-62 RNO STEP C2.a.

OPERATOR CHECKED THE PANEL AND IDENTIFIED THAT EG HIS-58 AND EG HIS

-71 ARE CLOSED EG HIS-58 AND EG HIS

-71 SHOW GREEN LIGHT ON AND RED LIGHT OFF EG HIS-58 OPENED UPON TAKING THE VALVE TO "OPEN" EG HIS-71 WILL NOT OPEN This is the start of the ALTERNATE PATH S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 4 of 6 JPM S8 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 5. IF ANY VALVE(S) FAIL TO OPEN, THEN OPEN THE ASSOCIATED BYPASS VALVE USING ATTACHMENT F, CCW CNTMT ISOLATION VALVES RNO STEP C2.b IF ASKED, EG HIS

-71 CANNOT BE OPENED LOCALLY OPERATOR IDENTIFIED THAT EG HIS

-71 CANNOT BE OPENED AND OPENS THE BYPASS VALVE USING ATTACHMENT F S U Comments: 6. PLACE Administrative

Controls for any OPEN Containment Isolation CCW Bypass Valve:

ATT F, STEP F1 Respond as the CRS that administrative controls have been established.

OPERATOR COMMUNICATED THAT ADMINISTRATIVE CONTROLS MUST BE ESTABLISHED S U Comments: *7. Use The Tables Below For Additional Containment Isolation CCW Valves Information:

EGHV0071 (EG HIS

-71) Bypass EGHV0126 Switch EG HIS

-126 Bypass Iso/Non Iso Switch EG HIS-126A ATT F, STEP F2 OPERATOR LOCATE D HANDSWITCH EG HIS

-126A ON PANEL RL020. DEPRESS ED THE NON-ISO PUSHBUTTON LOCATE HANDSWITCH EG HIS-126 ON PANEL RL020. DEPRESS ED THE OPEN PUSHBUTTON. OBSERVE THE RED LENS IS LIT.

OBSERVE D CCW FLOW TO CONTAINMENT S U Comments: TIME CCW flow restored __________

(must be less than 10 minutes since start of JPM) *8. CHECK CCW Flow From RCPs OPEN BB HIS13 BB HIS14 BB HIS15 BB HIS16 STEP C3 Operator opened CCW Flow From RCPs BB HIS13 BB HIS14 BB HIS15 BB HIS1 6 S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Page 5 of 6 JPM S8 *Critical Step JPM STEP TASK ELEMENT EXAMINER CUE PERFORMANCE STANDARD SCORE 9. CHECK RCP Seal Injection Flow BETWEEN 8 GPM AND 13 GPM PER PUMP BG FR157 BG FR156 BG FR155 BG FR154 Step C4 Operator CHECK ED RCP Seal Injection Flow BETWEEN 8 GPM AND 13 GPM PER PUMP BG FR157 BG FR156 BG FR155 BG FR154 S U Comments: 10. CHECK CCW Train Supplying the RCPs LESS THAN 105°F EG TI31 EG TI32 Step C5 Operator CHECKED CCW Train Supplying the RCPs LESS THAN 105°F EG TI31 EG TI32 S U Comments: 11. CONTINUE Monitoring RCP Parameters Step C6 Operator CONTINUED to Monitoring RCP Parameters S U Comments: 12. Report to CRS Actions taken. The Operator could report CCW flow restored any time after STEP 7 of the JPM.

ACKNOWLEDGE REPORT THE JPM IS COMPLETE Record time on page 2 INFORM ED THE CRS OF ACTIONS S U Comments:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE JPM S8 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

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 Event No. Malf. No. Event Type* Event Description 1 PT0456 SRO (I) RO (I) PZR Pressure instrument Fail s high (Tech Specs) 2 ABFT0542 SRO (I) BOP (I) SG Steam Flow Inst Fails low 3 SFB08_DR SRO (C) RO (C) BOP (C) Dropped rod (Tech Specs) 4 SF2CD2/2 SRO (M) RO (M) BOP (M) Multiple Dropped Rod s / Rx Trip 5 AB001_A SRO (M) RO (M) BOP (M) Steam Line Break inside containment 6 SAS9XX_1, 2, 3, 4 SRO (C) BOP (C) MSIVs fail to close 7 PEN01A_2 and EN08RL_420TVSP SRO (C) BOP (C) Containment Spray Pump Auto Start Failure and 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 rod s 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 significance Failure to isolate a faulted SG that can be isolated causes challenges to CSFs beyond those irreparably introduced by the postulated conditions.

Failure to isolate a faulted SG can result in challenges to the following CSFs:

Integrity Subcriticality Containment (if the break is inside containment)

If one train of containment spray is not actuated, the FSAR assumptions and results are invalid. Because compliance with the assumptions of the FSAR is part of the facility license condition, failure to manually actuate at least one train of containment spray under the scenario conditions and when it is possible to do so constitutes a violation of the license condition.

Cueing Both of the following:

Steam pressure and flow rate indications that make it possible to identify 'A' SG as faulted AND Valve position and flow rate indication that AFW continues to be delivered to the faulted 'A' SG Indication that containment cooling is required by Containment pressure either currently or has been greater than 27 psig Indication and/or annunciation that no train of containment spray has successfully actuated by both: 'A' Containment Spray Pump not running 'B' Containment Spray Pump discharge valve NOT open Performance indicator ISOLATE AFW flow to faulted SG(s):

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 Starting the 'A' Containment Spray Pump Performance feedback Crew will observe the following:

Any depressurization of intact SGs stops AFW flow rate indication to faulted SG of zero Indication that 'A' Containment Spray Pump is running AND Containment pressure lowering Justification for the chosen performance limit "before transition out of E

-2" is in accordance with the PWR Owners Group Emergency Response Guidelines. It allows enough time for the crew to take the correct action while at the same time preventing avoidable adverse consequences.

"before completion of Attachment A of E

-0" is in accordance with the PWR Owners Group Emergency Response Guidelines. It allows enough time for the crew to take the correct action while at the same time preventing avoidable adverse consequences.

PWR Owners Group Appendix CT-17 Isolate faulted SG CT-3 Manually actuate containment cooling

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 Guid e 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

-1 0 , MOL 100%: RCS boron concentration 752 ppm CCP A 7 65 ppm minus 5 days CCP B 7 75 ppm minus 15 days Rod Control Bank D 21 5 steps, Other banks 228 steps ENSURE BB-P T-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) e23 bg 01b 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 Rod s / 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 Applicant's 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 CRS Implement OTO-BB-00006, Pressurizer Pressure Control Malfunction OTO-BB-00006 RO (Step 1) Check Pressurizer Pressure Indicator

- Failed, BB PI-456 RO (Step 2.a) CHECK Pressurizer Pressure

Between 2225 psig and 2250 psig

- YES RO (Step 3) IF Required TRANSFER Pressurizer Pressure Control Selector To Remove Failed Channel From Control:

BB PS-455F RO (Step 4) CHECK Pressurizer Pressure Within One Of The Following:

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 Applicant's Actions or Behavior RO (Step 5) WHEN Pressurizer Pressure Is Restored To Setpoint, PLACE Pressurizer Pressure In AUTO CONTROL

a. Verify PZR Spray Valves in AUTO

b. PLACE PZR PRESS MASTER CTRL in AUTO BB PK-455A B O P (Step 6) Check P-11 in Correct State Within One Hour of the Pressurizer Pressure Failure RO (Step 7) Select an Operable Channel for:

RCS Pressure Recorder BB PS

-455G OPDT/OTDT Temperature Recorder SC TS

-411E Computer Digital Readout Display: REP0481A, 482A or 483A CRS (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) 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 CRS (Step 10) REVIEW Attachment A, Effects of Pressurizer Pressure Instrument Failure NOTE At Lead Examiner's 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 Applicant's 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) O TO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions CRS Implement OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions OTO-AE-00002 BOP (Step 1) Check SG Water Level Control Instrument

- NORMAL. RNO: SG D: AB LI-542 Take MANUAL Control of Affected SG MFRV or MFRV Bypass and MAINTAIN SG Level:

SG D: o AE FK540, SG D MFW REG VLV CTRL OR o AE LK580, SG D MFW REG BYPASS CTRL BOP (Step 2) For the Failed Instrument, SELECT An Operable Channel:

Select AB FS-542C to operable channel 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 Applicant's Actions or Behavior BOP (Step 3) RESTORE Affected SG NR Level to between 45% and 55% BOP (Step 4) Return Affected SG MFRV or MFRV Bypass to AUTO Control: SG D: o AE FK5 4 0 OR o AE LK5 8 0 CRS (Step 5) Review Attachment A, Effects of Instrument Failure CRS (Step 6) Review Applicable Tech Specs, Attachment F None applicable CRS (Step 7) Perform Notifications per ODP

-ZZ-00001, Add 13 NOTE At Lead Examiner's 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 Applicant's 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 00001 RO (Step 1) Check Both of the Following are Met for Indication of Multiple Dropped Rods ANN 81A, TWO/More Rods at Bottom Lit Rod Bottom lights lit for greater than one rod RNO Go to Step 3 RO (Step 3) Check Main Turbine Runback Or Load Reject

- IN PROGRESS RNO Go to Step 5 RO (Step 5) Place Rod Control in Manual 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 Applicant's Actions or Behavior RO (Step 6) Check Control Rods Motion STOPPED RO (Step 7) Check Instrument Indication Normal RO/BOP (Step 8) Check Annunciator 79A LIT

- NO: RNO: Maintain RCS Tavg/Tref and go to Step 10 ADJUST Turbine load.

ADJUST RCS boron concentration.

ADJUST Control Rods.

RO (Step 10) Check Annunciator 81B and all Rod Bottom Lights Extinguished

- NO: RNO: Go to Attachment 'A' RO (Step A1) Check Reactor Power less than 5%

- NO: RNO: Go to Step A3 CRS (Step A3) Contact I&C to determine reason for Dropped Rod CRS (Step A4) CHECK Shutdown Margin Is Within The Limits Provide d In The COLR Within 1 Hour CRS (Step A5) CHECK Axial Flux Difference (AFD)

- WITHIN THE LIMITS OF CURVE BOOK, FIGURE 1

-1, AXIAL FLUX DIFFERENCE LIMITS CRS (Step A6) CHECK QPTR

- LESS THAN OR EQUAL TO 1.02 CRS (Step A7) Check Dropped Rod can be recovered in less than one 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 Applicant's Actions or Behavior CRS (Step A8) CONSIDER The Following Prior To Recovering The Rod: Length of time the rod has been misaligned Power Level at which the realignment will be performed Rate of control rod movement during realignment Movement of other control rods to support realignment CRS (Step A9) PERFORM Notifications Per ODP

-ZZ-00001 Addendum 13, Shift Manager Communications CRS (Step A10) NOTIFY Reactor Engineering Prior To Attempting Recovery Of The Control Rod CRS (Step A11) CHECK Both Of The Following Are Met: 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 Applicant's Actions or Behavior CRS (Step A12) PERFORM Attachment B, Dropped/Misaligned Rod 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.

CRS (Step A13) REVIEW Applicable Technical Specifications:

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 Examiner's 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 Applicant's 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 RO (Step 1) Check Both of the Following are Met for Indication of Multiple Dropped Rods ANN 81A, TWO/More Rods at Bottom Lit Rod Bottom lights lit for greater than one rod CRS (Step 2) Perform the Following:

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 Applicant's Actions or Behavior NOTE Steps 1 through 4 are immediate actions RO (Step 1) CHECK Reactor Trip

- Yes Rod Bottom Lights

- All Lit Reactor Trip and Bypass Breakers

- Open Neutron Flux

- Lowering BOP (Step 2) CHECK Turbine Trip

a. Turbine Stop Valves

- Closed BOP (Step 3) CHECK Power to AC Emergency Buses

a. At Least One Emergency Bus

- Energized b. Both Emergency Buses

- Energized - YES RO (Step 4) CHECK SI Status a. Check if SI is Actuated

b. Check both Trains of SI Actuated LOCA Sequencer ANN 30A

- Lit LOCA Sequencer ANN 31A

- Lit SB069 SI Actuate Red Light

- Lit Solid RO/BOP (Step 5) Perform Attachment A, Automatic Action Verification, while continuing with this procedure (see page 22)

NOTE The following Critical Task actions are contained in Attachment 'A' RO/BOP (Step A8 RNO) START the 'A' Containment Spray Pump Critical Task CREW Manually actuate containment cooling by:

Starting the 'A' Containment Spray Pump before completion of 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 Applicant's Actions or Behavior RO/BOP (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 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 Task CREW Isolate the faulted 'A' SG before transition out of E

-2 NOTE CREW 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 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 (cont'd) BOP (Step 6) CHECK Generator Output Breakers

- Open BOP (Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps

- Tripped 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 Applicant's Actions or Behavior RO (Step 8) CHECK AFW Pumps a. MD AFW Pumps

- Both Running

b. TD AFW Pump

- Running RO (Step 9) CHECK AFW Valves

- Proper Emergency Alignment MD AFP Flow Control Valves

- Throttled 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 RO (Step 11)

Check PZR PORVs And Spray Valves:

a. PZR PORVs CLOSED b. PZR PORVs BOTH IN AUTO

c. PORV Block Valves BOTH OPEN d. Normal PZR Spray valves CLOSED RO (Step 12) CHECK If RCPs Should Be Stopped: a. RCPs ANY RUNNING

- YES 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 Applicant's Actions or Behavior RO (Step 13)

CHECK RCS Temperatures:

NO RCPs running RCS COLD LEG TEMPERATURES STABLE AT 557°F OR TRENDING TO 557°F

- NO 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.

CRS (Step 14) CHECK If Any SG Is Faulted:

- YES 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 BOP (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 f o ldout page or Attachment A of E

-0 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 Task CREW Isolate the faulted 'A' SG before transition out of E

-2 BOP (Step 2) CHECK If Any SG Secondary Pressure Boundary Is Intact: 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 Applicant's Actions or Behavior CRS (Step 3) IDENTIFY Faulted SG(s):

- Should identify the 'A' SG as the faulted SG BOP (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 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 Task CREW Isolate the faulted 'A' SG before transition out of E

-2 BOP (Step 5) CHECK CST To AFP Suction Header Pressure

- 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 Applicant's Actions or Behavior BOP (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 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 Applicant's Actions or Behavior RO (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 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%]

RO (Step 8) RESET SI: SB HS-42A SB HS-43A BOP STOP All But One CCP:

BG HIS-1A 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 Applicant's Actions or Behavior Attachment A , Automatic Action Verification E-0 Att A RO/BOP (Step A1) CHECK Charging Pumps

- NO 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 RO/BOP (Step A4) CHECK ESW Pumps

- BOTH RUNNING EF HIS-55A EF HIS-56A RO/BOP (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 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 RO/BOP (Step A6) CHECK Containment Cooler Fans

- RUNNING IN SLOW SPEED RO/BOP (Step A7) CHECK Containment Hydrogen Mixing Fans

- RUNNING IN SLOW SPEED RO/BOP (Step A8) CHECK If Containment Spray should Be Actuated

- 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 Applicant's Actions or Behavior RO/BOP (Step A8 RNO) START the 'A' Containment Spray Pump Critical Task CREW Manually actuate containment cooling by:

Starting the 'A' Containment Spray Pump before completion of Attachment A of E

-0 RO/BOP (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 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 Task CREW Isolate the faulted 'A' SG before transition out of E

-2 RO/BOP (Step A10) CHECK ECCS Valves

- PROPER EMERGENCY ALIGNMENT RO/BOP (Step A11) CHECK Containment Isolation Phase A

a. ESFAS status panels CISA sections:

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 Applicant's Actions or Behavior RO/BOP (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

SA066X White lights

- ALL LIT SA066Y White lights

- ALL LIT RO/BOP (Step A13) CHECK Both Trains of Control Room Ventilation Isolation RO/BOP (Step A14) CHECK Containment Purge Isolation RO/BOP (Step A15) NOTIFY CRS of the following:

Unanticipated Manual actions taken.

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:

_____________________________

____________________________

_____________________________

____________________________

_____________________________

Initial Conditions:

10-8 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.

Event No. Malf. No. Event Type* Event Description 1 N/A SRO (N) BOP (N) Start Service Water Pump

'C' Secure Service Water Pump 'A' 2 N/A SRO (C) RO (C) RCS High Activity / Place 120 gpm Letdown in

-service (Tech Spec) 3 BBTE0421B SRO (I) RO (I) Tavg Channel Failure

- Loop 2 Tc fails high (Tech Spec) 4 NB01_F SRO (C) BOP (C) Loss of NB01 (Tech Spec) 5 (SB) SB001 SRO (C) RO (C) Reactor Trip 6 Lossofswitchyard.lsn SRO (M) RO (M) BOP (M) Loss of all AC Power 7 PAL02_3 SRO (C) BOP (C) TDAFW fails to Auto Start 8 PA50101_1 SRO (C) BOP (C) AEPs EDGs fail to Start

• (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 occurring.

. (<10% WR on all SGs)

Energize at least one AC Emergency Bus prior to RCP seal degradation (greater than 25 gpm per pump)

EVENT 6 7 Safety significance Failure to establish minimum AFW flow in this scenario is a violation of the basic objective of ECA

-0.0 and of the assumptions of the analyses upon which ECA

-0.0 is based. Without AFW flow, the SGs could not support any significant plant cooldown. Thus, the crew would lose the ability to delay the adverse consequences of core uncovery. In the scenario, failure to energize at least one ac emergency bus results in the needless continuation of a situation in which the pumped ECCS capacity and the emergency power capacity are both in a completely degraded status, as are all other active safeguards requiring electrical power. Although the completely degraded status is not due to the crew's action (was not initiated by operator error), continuation in the completely degr aded status is a result of the crew's failure to energize at least one ac emergency bus.

Cueing Both of the following:

Indication of Station Blackout AND Less than 285,000 lbm/hr AFW flow to the SGs Indication and/or annunciation that all ac emergency buses are de

-energized Bus energized lamps extinguished Circuit breaker position Bus voltage EDG status Performance indicator Manipulation of the: TDAFW Steam Supply valve(s):

AB HIS5A (SG B) AB HIS6A (SG C) TDAFP Mechanical Trip/Throttle valve:

FC HIS312A Manipulation of controls as required to energize at least one ac emergency bus from the AEPS Using PBXY0001 CLOSE AEPS FDR BKR PB0502 TO NB0214 o PB0502 CLOSE NB02 AEPS SUPPLY BKR NB0214 o NB HIS-68 Performance feedback Crew will observe greater than 285,000 lbm/hr AFW flow to the SGs.

Indication that NB02 is energized NB02 Bus energized light NB02 bus voltage Justification for the chosen performance limit Without AFW flow, decay heat would open the SG safety valves and would rapidly deplete the SG inventory, leading to a loss of secondary heat sink, or SG dryout. Decay heat would then increase RCS temperature and pressure until the pressurizer PORVs open, imposing a larger LOCA than RCP seal leakage.

Failure to perform the critical task also results in needless degradation of any barrier to fission product release, specifically of the RCS barrier at the point of the RCP seals.

Failure to perform the critical task means that RCS inventory lost through the RCP seals cannot b e 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 Group Appendix CT - 23, Establish AFW flow during SBO CT - 24, Energize at least one ac emergency bus

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:

Establish the initial conditions of IC

-164, MOL 10

-8 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 Malf unction (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 Applicant's 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 CRS Implement OTN-EA-00001, Service Water System to start 'C' Service Water pump and secure 'A' Service Water pump OTN-EA-00001 CRS (Precautions and Limitations) CRS reviews Precautions and 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 Applicant's Actions or Behavior CRS (Section 5.3

) Direct the BOP to start the 'C' Service Water 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.

BOP (Step 5.3.1) ENSURE switch for Service Water Pump to be started is RESET:

CSTEA2101C, CTRL STA FOR S.W. PUMP C BOP (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 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.

BOP (Step 5.3.3) IF three service water pumps are operating, Go To 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 Applicant's Actions or Behavior BOP (Step 5.4.1) IF swapping Service Water Pumps, ENSURE the replacement pump is started prior to securing the pump to be replaced. BOP (Step 5.4.2) ENSURE sufficient SW/ESW pumps are availabl e to maintain cooling to system loads. NOTE (NOTE) Service Water provides lube water to the Circulating 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 BOP (Step 5.4.5) Using the applicable switch below, SECURE the desired Service Water Pump:

PBHIS12104 , SERV WATER PUMP A BOP (Step 5.4.6) CHECK SW/ESW component parameters to 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 Applicant's Actions or Behavior BOP (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.

BOP (Step 5.4.9) This step is N/A NOTE At Lead Examiner's 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 Applicant's Actions or Behavior Booth Operator Instructions T = 15 minutes or at the discretion of the Lead Examiner Call Control room as C hemistry 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 t he 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-00005 RO (Step 1) MAXIMIZE Letdown Flow Through CVCS Letdown Mixed Bed Demineralizer CRS Directs changing letdown from 75 gpm to 120 gpm per OTN

-BG-00001 ADD 04, Operation of CVCS Letdown Step 5.6 OTN-BG-00001 ADD 04 CRS (Precautions and Limitations) CRS reviews Precautions and Limitations 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 Applicant's 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 RL F. BOP (Step 5.6.1) INFORM Chemistry letdown flow is being changed.

RO (Step 5.6.2) ENSURE Pressurizer Backup Heaters are in Manual Heater Operation per OTN-BB-00005, Pressurizer And Pressurizer Pressure Control.

RO (Step 5.6.3) RAISE charging flow to 115 to 120 gpm using one of the following controllers:

IF NCP is in service, ADJUST BG FK

-124, NCP DISCH FLOW CTRL RO (Step 5.6.4) IF NCP is in service, WHEN flow indicated at BG FI 0121A, CHG HDR FLOW, is greater than 100 gpm, CLOSE BGHV8109 using BG HIS 8109, NCP RECIRC VLV.

BOP (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:

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 RO (Step 5.6.6) PLACE BG PK

-131, LTDN HX OUTLET PRESS 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 Applicant's Actions or Behavior RO (Step 5.6.7) Using BG HIS

-8149AA, LTDN ORIFICE A VLV, OPEN 45 gpm Letdown orifice.

RO (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 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.

RO (Step 5.6.10) IF required, slowly adjust potentiometer on BG TK-130, LTDN HX TEMP CTRL (3.0 to 4.3 turns) to control temperature at 95°F to 115°F.

RO (Step 5.6.11) PLACE in MANUAL and ADJUST BB LK

-459, PZR LEV MASTER CTRL, to obtain an output of 64 to 68 %. RO (Step 5.6.12) IF NCP is in service, PLACE BG FK

-121, CCP DISCH FLOW CTRL, in MANUAL and ADJUST to 25 % demand.

RO (Step 5.6.

13) WHEN pressurizer level is being maintained at program level, PLACE the following in AUTO as required:

BG FK-121, CCP DISCH FLOW CTRL BG FK-124, NCP DISCH FLOW CTRL BB LK-459, PZR LEV MASTER CTRL RO (Step 5.6.1

4) RESTORE Pressurizer Backup Heaters to Automatic Heater Operation per 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 Applicant's Actions or Behavior OTO-BB-00005 (Note) RCS coolant and seal injection filters D/P will rise if a crud 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 CRS (Step 5) DIRECT Chemistry To Determine If Decontamination Factor (DF) of CVCS Letdown Mixed Bed Demineralizer Is Acceptable Per CDP

-ZZ-00800, Callaway Resin Monitoring Program BOP (Step 6) CHECK DF Of Inservice CVCS Letdown Mixed Bed Demineralizer

- ACCEPTABLE CRS (Step 7) REVIEW Technical Specification 3.4.16 TS 3.4.16 Condition A is applicable NOTE After 120 gpm letdown has been established, TS identified

and at Lead Examiner's 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 Applicant's 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-00004 RO (Step 1) Place Rod Control in Manual RO (Step 2) Check RCS Loop NR Tavg and Delta

-T Indicator FAILED RO (Step 3) Select T and Tavg Channel Defeat switches to failed 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 Applicant's Actions or Behavior RO (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 following:

ADJUST Control Rods.

ADJUST Turbine load.

ADJUST RCS Boron concentration.

RO (Step 5) Check Rod Control in Auto (potential 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. CRS (Step 6) Check PZR Level Trending to or At Program Level BOP (Step 7) Select an Operable Channel for the OPT/OTT Temperature recorder RO (Step 8) Review Attachment A for effects of RCS RTD Instrument failure CRS (Step 9) Review Applicable Technical Specifications, Refer to 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 /> CRS (Step 10) Direct I&C to Trip The Protective Bistables for the Failed 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 Applicant's Actions or Behavior CRS (Step 13) Perform notifications per ODP-ZZ-00001, Add. 13 NOTE After the Technical Specification is identified and at Lead Examiner's 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 Applicant's 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-00001 CRS Implement OTO-NB-00001, Loss of Power to NB01

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 Applicant's Actions or Behavior BOP (Step 1) CHECK 4160 VAC Bus NB01 DEENERGIZED 4.16 KV Bus NB01 light EXTINGUISHED 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) BOP (Step 2) CHECK Turbine Driven Auxiliary Feedwater Pump SECURED NOTE The TDAFW pump SHOULD have started. The crew should recognized this and continue on in the procedure.

RO (Step 3) CHECK Reactor Power LESS THAN 100% SE NI41B SE NI42B SE NI43B SE NI44B BB TI BB TI BB TI BB TI (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 Applicant's Actions or Behavior BOP (Step 4) CHECK CCW Pump B Or D RUNNING - NO EG HIS22 EG HIS24 RNO START one of the following:

CCW Pump B OR CCW Pump D BOP (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 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 Applicant's Actions or Behavior BOP (Step 7) CHECK RHR IN SERVICE PRIOR TO EVENT RNO - Go To Step 10.

BOP (Step 10) CHECK Steam Generator NR Level Within One Of The Following:

Trending to between 45% and 55%

OR Between 45% and 55%

RO (Step 11) CHECK Pressurizer Level Within One Of The Following:

Trending to Program Level OR At Program Level RO (Step 12) CHECK Pressurizer Pressure Within One Of The Following:

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 Applicant's Actions or Behavior BOP (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 o EG HIS23 SI Pump A:

o EM HIS4 Ctmt Spray Pump A:

o EN HIS3 RHR Pump A:

o EJ HIS1 BOP (Step 14) OPEN NB01 Normal And Alternate Feeder Breakers:

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 Applicant's Actions or Behavior BOP (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:

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.

BOP (Step 17) CHECK 4160 VAC Bus NB01 ENERGIZED RNO Perform the following:

Place 'A' CCW Train Pump handswitches in PullToLock until power is restored to NB01 EG HIS21 EG HIS23 RO (Step 18) CHECK NCP Or CCP B RUNNING BG HIS3 (NCP) OR BG HIS2A (CCP B)

BOP (Step 19) CHECK RCP Seal Injection Flow BETWEEN 8 GPM 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 Applicant's Actions or Behavior CRS Evaluate Tech Specs:

The most restrictive T.S. for this condition are either:

3.8.1.H, Three or more AC sources inoperable.

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 pump s must be declared inoperable)

CUE Any time after NE01 is secured and at Lead Examiner's 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 Applicant's 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.

RO (Step 1) CHECK Reactor Trip Rod Bottom Lights

- All Lit Reactor Trip and Bypass Breakers - Open Neutron Flux

- Lowering BOP (Step 2) CHECK Turbine Trip

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 Applicant's Actions or Behavior E-0 BOP (Step 3) CHECK Power to AC Emergency Buses

a. At Least One Emergency Bus

- Energized b. Both Emergency Buses

- NO NOTE RO (Step 4) CHECK SI Status a. Check if SI is Actuated

- NO 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 BOP (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 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 BOP (Step 1.b) CHECK RCS temperature response

- NORMAL RCS COLD LEG 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 Applicant's Actions or Behavior BOP (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:

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) RO/BOP (Step 3) CHECK PZR Pressure Control:

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 Applicant's Actions or Behavior RO (Step 4) CHECK PZR Level Control: a. PZR Level

- GREATER THAN 17% b. CHECK Instrument Air Supply Containment Isolation valve - OPEN KA HIS-29 c. CHECK charging

- IN SERVICE d. CHECK letdown

- IN SERVICE

e. PZR level

- TRENDING TO 25% RO/ (Step 5) CHECK Shutdown Reactivity Status: a. CHECK all control rods

- FULLY INSERTED

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 Applicant's Actions or Behavior ECA-0.0, Loss of All AC Power CRS Recognizes loss of all AC power though direct observation or 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.

RO (Step 1) CHECK Reactor Trip:

Reactor Trip and Bypass Breakers OPEN Neutron Flux LOWERING BOP (Step 2) CHECK Turbine Trip:

a. All Turbine Stop valves CLOSED RO (Step 3) CHECK If RCS Is Isolated:

a. Letdown isolation valves CLOSED 1) Letdown Orifice Isolation valves:

BG HIS8149AA 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 Applicant's Actions or Behavior RO/BOP (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 BG HIS8153B BG HIS8154B d. Reactor Head Vent Valves CLOSED BB HIS8001A BB HIS8002A BB HIS8001B BB HIS8002B BOP (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: 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 Task CREW Establish greater than 285,000 lbm/hr AFW flow rate to the 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 Applicant's Actions or Behavior BOP (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 d) IF NO AC emergency bus is energized, THEN PERFORM the following:

1. OPEN Control Room cabinet doors using EOP Addendum 20, Contro l 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 Applicant's Actions or Behavior BOP (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 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 Applicant's Actions or Behavior BOP (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 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)

CRS (Step 8) Locally ISOLATE RCP Seals Using EOP Addendum 22, Local RCP Seal Isolation (direct OT to perform this task)

RO (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:

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 Applicant's Actions or Behavior RO (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)

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 CRS Directs use of EOP Addendum 39, Alternate Emergency Power Supply, to energize NB02 EOP ADD 39 (Caution)

The Diesels from the Alternate Emergency Power 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 Applicant's 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.

CRS/BOP (Step 1) EVALUATE Plant Status To Determine Which AC Emergency Bus To Energize:

NB02 BOP (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 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 Applicant's Actions or Behavior BOP (Step 3) PERFORM Applicable Attachment As Necessary:

b. NB02 a) Attachment B, Energizing NB02 From Alternate Emergency Power Supply (AEPS), Step B1 BOP (Step B1)

CHECK PB05

- ENERGIZED a. CHECK PB05 Energized by Central Electric Power Reform Substation

- NO RNO If PB05 does not have power Go To Attachment C, Placing Alternate Emergency Power Supply DGs on PA501 Bus, Step C1 BOP (Step C1)

Using PBXY0001 PLACE AEPS FDR BKR TO PA501 VIA Central Electric Reform Feeder Breaker To XFMR

- OPEN PA50101 BOP (Step C2) Using PBXY0001 CHECK ALL AEPS D/G - RUNNING EDGPA5001, AEPS D/G #1 EDGPA5002, AEPS D/G #2 EDGPA5003, AEPS D/G #3 EDGPA5004, AEPS D/G

1. 4 BOP (Step C3)

Using PBXY0001 CHECK ALL Running AEPS D/G Output Breakers - CLOSED: PA50104, AEPS FDR BKR TO EDGPA5001 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 Applicant's Actions or Behavior BOP (Step C4)

Using PBXY0001 CHECK The Following Breakers

- CLOSED a. Feeder Breaker PA50103, AEPS FDR BKR TO XFMR XPB05 b. Feeder Breaker PB0501, AEPS FDR BKR To PB05 FROM PA50103 BOP (Step C5)

RETURN To Procedure Section And Step In Effect:

Attachment B, Energizing NB02 From Alternate Emergency Power Supply (AEPS), Step B2 BOP (Step B2)

PLACE ESW PUMP B In PULL-TO-LOCK EF HIS-56A BOP (Step B3)

Using PBXY0001 CLOSE AEPS FDR BKR PB0502 TO 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 BOP (Step B4) CLOSE NB02 AEPS SUPPLY BKR NB0214 NB HIS-68 Critical Task CREW Energize at least one AC Emergency Bus prior to RCP seal 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 Applicant's Actions or Behavior BOP (Step B5) MONITOR AEPS System Using PBXY0001: Watts Amps Volts Fuel (DG only

) BOP (Step B6) NOTIFY Jefferson City Oil To REFUEL AEPS DGs As Necessary:

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.

BOP (Step B7) CHECK NB02 Energized By Central Electric Power Reform Substation Or A Minimum Of 3 AEPS DGs BOP (Step B8) When Off

-Site Power Is Available Restore Power To 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 CRS Upon restoration of AC Power the CRS will direct a transition to 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 Applicant's Actions or Behavior ECA-0.0 BOP (Step 24) CHECK If AC Emergency Power Is Restored:

a. CHECK AC emergency buses AT LEAST ONE ENERGIZED NB02 BOP (Step 25)

STABILIZE SG Pressures:

a. Manually CONTROL SG ASDs to maintain existing SG pressures BOP (Step 26) Check Following Equipment Loaded on Energized AC Emergency Bus:

NB02: o 480 Volt Buses:

NG02 breaker s NB0213 and NG0201 NG04 breakers NB0210 and NG0401 o Battery Chargers:

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 a n 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 Event No. Malf. No. Event Type* Event Description 1 SEN0044 SRO (I) RO (I) BOP (I) Nuclear Instrument Fails high. (Tech Specs) 2 AELT0519 SRO (I) BOP (I) SG Level Instrument Fails to 75% (Tech Specs) 3 PAE01A_2 PAE01A_3 PAE01A_4 SRO (R) RO (R) BOP (C) MFP Vibrations Forcing Downpower 4 PAE0`A.1 SRO (C) RO (C) BOP (C) MFP Trip / Rx Trip 5 SF006 SRO (M) RO (M) BOP (M) Reactor Trip Failure / ATWS 6 TBB03 SRO (M) RO (M) Pressurizer Steam Space Leak 7 SIS_A SIS_B SRO (C) RO (C) Automatic SI Actuation Failure Both Trains

• (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 th e 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 dispatching operators to locally Trip the Reactor Deenergize PG19 and PG20 Insert Control Rods Establish emergency boration flow to the RCS Manually actuate at least one train of SIS

-actuated safeguards equipment before transition to E

-1. EVENT 5 7 Safety significance In the scenario, failure to insert negative reactivity by one of the methods listed previously can result in the needless continuation of an extreme or a severe challenge to the subcriticality CSF. Although the challenge was not initiated by the crew (was not initiated by operator error), continuation of the challenge is a result of the crew's failure to insert negative reactivity.

In the scenario, failure to manually actuate Sl results in a significant reduction of safety margin beyond that irreparably introduced by the scenario. Failure to manually actuat e Sl in the scenario would be a violation of the facility license condition.

Although the degraded status is not due to the crew's action , continuation in the degraded status would be a result of the crew's failure to manually actuate Sl.

Cueing Both of the following:

Indication of ATWS (the reactor is not tripped and that a manual reactor trip is not effective) Indication and/or annunciation that that Sl is required PRZR pressure or SG pressure less than Sl actuation setpoint No indication or annunciation that Sl is actuated Performance indicator Manipulation of controls in the control room as required to initiate the insertion of negative reactivity into the core (at least one of the following)

Open supply breakers to PG19 and PG20.

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 Manipulation of controls as required to actuate at least one train of Sl SB HS-27 SB HS-28 Performance feedback Crew will observe the following:

Indication of a negative SUR on the intermediate range of the excore NIS Indication of less than 5% power on the power range of the excore NIS Indication that both Trains of SI

- Actuated LOCA Sequencer annunciator 30A

- Lit LOCA Sequencer annunciator 30B

- Lit SB069 SI Actuate Red Light

- Lit SOLID (NOT blinking)

Justification for the chosen performance limit Local operator actions would result in reactor trip, which would shut down the reactor faster than boration (and faster than rod insertion). However, it is anticipated that effecting the local actions will be time-consuming and that actions that can be implemented from the control room should be given precedence. Thus, before dispatching operators to perform local actions to trip the reactor, the crew should perform or initiate performance of at least one of the three methods listed previously for shutting down the reactor and providing shutdown margin.

The crew has had ample opportunity to recognize the need for Sl and the fact that Sl has not automatically actuated.

Given the postulated plant conditions, transition from E

-0 to ES-0.1 constitutes an error in using the E

-0 procedure. The crew is in the wrong procedure; however, the crew is allowed to recover from this error up through Step 3.a of ES

-0.1. The ERG network is designed to "catch" errors in procedure usage. Step 3.a is 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 Group Appendix CT- 52, Insert negative reactivity into the core CT-2, Manually actuate Sl

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 fail s 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 Applicant's 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 won't 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 A nn 83C RX Partial Trip OTO-SE-00001 OTO-SE-00001 CRS Implement OTO-SE-00001, Nuclear Instrument Malfunction (Note) Crew could enter OTO

-SF-00001 and return to the correct procedure OTO-SE-00001 , Att A RO (Step 1) CHECK Power Range Nuclear Instruments

- NORMAL RNO a. Ensure rod control is in manual 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 Applicant's Actions or Behavior RO/BOP (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 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 BOP (Step A3) Check the following permissives are in the correct state within one hour Of the Power Range Channel Failure per Attachment H, Permissives P-7 LIT P-8 LIT P-9 LIT P-10 LIT RO (Step A4) Select an operable channel on NIS recorder 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 Applicant's Actions or Behavior BOP (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 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 RO (Step A6) Check rod control in auto SE HS-9 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.

BOP (Step A7) Check any SG level being controlled by MFW REG BYP VLV RNO go to step A8 RO (Step A8) Check reactor power greater than 10%

BOP (Step A9) Trip protective bistables for the failed channel per ATT D , Tripping Power Range Protective Bistables, w ithin 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 Applicant's Actions or Behavior NOTE Tripping of bistables would not be expected to be performed this shift.

RO (Step A10) Check reactor power meets one of the following 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- CRS (Step A12) Record any of the following in the control room log Permissives are in the correct state Any fuses that have been pulled

. CRS (Step A13) Place the inop channel in the EOSL CRS (Step A14) Review applicable T. S.

T.S. 3.3.1.D, E and S/T CRS (Step A15)

DIRECT I&C To Repair Failed Channel NOTE At Lead Examiner's 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 fail s to 75% Proc /Time Position Applicant's 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 83 C RX PARTIAL TRIP Ann 108C SG A LEV DEV Ann 108 D SG A FLOW MISMATCH O TO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions CRS Implement OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions OTO-AE-00002 BOP (Step 1) Check SG Water Level Control Instrument RNO: SG A: AB LI-519 Take MANUAL Control of Affected SG MFRV or MFRV Bypass and MAINTAIN SG Level:

SG A: o AE FK510, SG A MFW REG VLV CTRL OR o AE LK550, SG A MFW REG BYPASS CTRL BOP (Step 2) For the Failed Instrument, SELECT An Operable Channel:

Select AB FS

-512C to operable channel On DFWCS, SELECT appropriate Level, FW Flow or Steam Flow on AE SS500 BOP (Step 3) RESTORE Affected SG NR Level to between 45% and 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 fail s to 75% Proc /Time Position Applicant's Actions or Behavior BOP (Step 4) Return Affected SG MFRV or MFRV Bypass to AUTO Control: SG A: o AE FK510 OR o AE LK550, CRS (Step 5) Review Attachment A, Effects of Instrument Failure CRS (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 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 Examiner's 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 Applicant's 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 A nn 120E MFP A VIB ALERT OTA-RK-00026 Add 120E CRS Implement OTA-RK-00026 Add 120E , MFP A VIB ALERT NOTE 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.

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 Add 120E BOP (Step 3.1) MONITOR the vibration of the A MFP using the table at the end of this Section.

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 Applicant's Actions or Behavior BOP (Step 3.2) VALIDATE the alarm condition by local observation CRS (Step 3.4) IF monitoring indicates DANGER set point reached OR a Rapidly Degrading Condition (except for FCZE0394C, MFP A AXIAL POS, during transient conditions), TRIP the A MFP and ENTER OTO-AE-00001, Feedwater System Malfunction.

CRS (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:

(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-00008 RO (Step 1) Place Rod Control In AUTO

a. SE HS-9 CRS (Step 2) Manage Reactivity

a. Perform Reactivity Management Brief:

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 Applicant's Actions or Behavior CRS/BOP #(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 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.

CRS/RO #(Step 4) Borate From the BAST by performing any of the 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 RO #(Step 4 c) Set Boric Acid Flow Controller, BG FK-110, to the desired flow rate RO #(Step 4 d) 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 Applicant's Actions or Behavior RO #(Step 4 e) RESET BG FY110B, BA COUNTER, to 000 RO #(Step 4 f) SET BG FY110B for the desired gallons of boric acid to be added RO #(Step 4 g) PLACE BG HS26 in RUN RO #(Step 4 h) WHEN the desired boration is complete, THEN PLACE BG HS-26 in STOP RO #(Step 4 i) repeat Boration as necessary RO (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

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 BOP (Step 6) Check MFP Turbine Speed Control

- IN AUTO FC SK-509B FC SK-509C CUE Once the crew starts to reduce power using steps 1

-6 of OTO-MA-00008, as proven by observation lowering load 5

-10 MWe 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 Applicant's 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 A nn 120A MFP A TRIP OTO-AE-00001 , FEEDWATER SYSTEM MALFUNCTION CRS Implement OTO-AE-00001, FEEDWATER SYSTEM MALFUNCTION OTO-AE-00001 RO (Step 1) PLACE Rod Control In AUTO:

SE HS-9 BOP (Step 2) CHECK Main Feed Pump TRIPPED RO (Step 3) CHECK Reactor Power LESSTHAN 70% RNO IF only one Main Feed pump is running, THEN PERFORM the 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 Applicant's Actions or Behavior Booth Operator Instructions T = 4 5 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=4 5 A nn 86A LO FLOW & P8 RX TRIP Ann 10 8 B 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.

RO (Step 1) CHECK Reactor Trip Rod Bottom Lights

- NO Reactor Trip and Bypass Breakers

- CLOSED 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 CRS Implement FR-S.1, Response to Nuclear Power 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 Applicant's Actions or Behavior NOTE Steps 1 and 2 are immediate actions.

RO (Step 1) Check Reactor Trip

RNO- Manually Trip the Reactor.

SB HS-1 SB HS-42 (BOP) 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 Task CREW Insert negative reactivity into the core by at least one of the following methods before dispatching operators to locally Trip the Reactor Deenergize PG19 and PG20 Insert Control Rods Establish emergency boration flow to the RCS BOP (Step 2) CHECK Turbine Trip

a. Turbine Stop Valves

- Closed BOP (Step 3) Check AFW Pumps Running

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 Applicant's Actions or Behavior RO (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 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 RO/BOP (Step 5) Check Containment Purge Isolation ESFAS status panels CPIS sections: SA066X WHITE lights

- ALL LIT SA066Y WHITE lights

- ALL LIT RNO - Manually actuate CPIS SA HS-11 SA HS-15 RO/BOP (Step 6) Check if the Following Trips Have Occurred

a. Reactor Trip RNO - Locally trip breakers

b. CLOSE supply breakers to PG19 and PG20:

PG HIS-16 PG HIS-18 c. Turbine Trip All Turbine Stop valves - CLOSED RO (Step 7) Check if Reactor is Subcritical 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 Applicant's 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.

NOTE Per ODP-ZZ-00025 since this is a return entry to E

-0 the immediate actions are not required to be performed but they must be verified.

RO (Step 1) CHECK Reactor Trip Rod Bottom Lights

- All Lit Reactor Trip and Bypass Breakers

- Open Neutron Flux

- Lowering BOP (Step 2) Check Turbine Trip

a. All Turbine Stop Valves

- Closed BOP (Step 3) Check Power to AC Emergency Buses

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 Applicant's Actions or Behavior RO (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 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 Task CREW Manually actuate at least one train of SIS

-actuated safeguards equipment before transition to E

-1. BOP/RO (Step 5) Perform Attachment A, Automatic Action Verification, 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 Applicant's Actions or Behavior BOP (Step 6) CHECK Generator Output Breakers

- Open BOP (Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps

- Tripped b. Main Feedwater Reg Valves

- Closed c. Main Feedwater Reg Bypass Valves

- Closed d. Feedwater Isolation Valves

- Closed BOP (Step 8) CHECK AFW Pumps a. MD AFW Pumps

- Both Running

- YES b. TD AFW Pump

- Running BOP (Step 9) CHECK AFW Valves

- Proper Emergency Alignment MD AFP Flow Control Valves

- Throttled 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 BOP (Step 11) CHECK PZR PORVs and Spray Valves

a. PZR PORVs

- Closed 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 Applicant's Actions or Behavior BOP (Step 12) CHECK if RCPs should be Stopped

a. RCPs - Any Running

b. ECCS Pumps

- At least One Running

c. RCS Pressure

- Less than 1425 psig

d. Stop all RCPs The RCP may have already been secured per the fold-out page BOP #(Step 13) CHECK RCS Temperatures RCPs Running

- Tavg 557 Deg F No RCPs Running

- Tcold 557 Deg F RO/BOP (Step 14) CHECK if any SG is Faulted

- NO a. CHECK pressures in all SGs:

Any SG pressure lowering in an uncontrolled manner

- Any SG completely depressurized RNO Go To Step 15 RO/BOP (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 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 Applicant's Actions or Behavior RO/BOP (Step 16) Check if RCS is Intact: Containment Pressure

- Normal - NO 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 RO (Step 1) Check if RCPs should be stopped:

a. RCPs - any running

b. ECCS Pumps

- At least One running

c. RCS pressure

- Less than 1425 psig

d. Stop all RCPs BOP (Step 2) Check if any SG is Faulted: a. Check pressures in all SGs:

Any SG pressure lowering in an uncontrolled manner - NO Any SG completely depressurized

- NO RNO Go to Step 3 BOP (Step 3) Check Intact SG Levels:

a. Narrow range levels

- Greater than 7% [25%]

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 Applicant's Actions or Behavior BOP (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 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 RO (Step 5) Check PZR PORV and Block valves:

a. Power to Block Valves

- available b. PZR PORVs

- Closed c. Block Valves

- Both Open RO (Step 6) Check if ECCS flow should be reduced:

- NO a. RCS subcooling

- b. Secondary heat sink:

Narrow range level in at least one intact SG

-Greater than 7% [25%]

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 Applicant's Actions or Behavior Attachment A, Automatic Action Verification E-0 Att A RO/BOP (Step A1) CHECK Charging Pumps

- Both CCPs running

- NO 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

- NO CCP Pump "B" Out of Service RO/BOP (Step A4) CHECK ESW Pumps

- BOTH RUNNING EF HIS-55A EF HIS-56A RO/BOP (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 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 RO/BOP (Step A6) CHECK Containment Cooler Fans - RUNNING IN SLOW SPEED RO/BOP (Step A7) CHECK Containment Hydrogen Mixing Fans

- 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 Applicant's Actions or Behavior RO/BOP (Step A9) CHECK If Main Steamlines Should Be Isolated:

Containment pressure > 17 psig Steamline pressure

- LESS THAN 615 PSIG RO/BOP (Step A10) CHECK ECCS Valves

- PROPER EMERGENCY ALIGNMENT RO/BOP (Step A11) CHECK Containment Isolation Phase A

a. ESFAS status panels CISA sections:

SA066X White lights

- ALL LIT SA066Y White lights

- ALL LIT RO/BOP (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

SA066X White lights

- ALL LIT SA066Y White lights

- ALL LIT RO/BOP (Step A13) CHECK Both Trains of Control Room Ventilation Isolation RO/BOP (Step A14) CHECK Containment Purge Isolation

a. ESFAS status panels CPIS sections:

SA066X White lights

- ALL LIT SA066Y White lights

- ALL LIT RO/BOP (Step A15) NOTIFY CRS of the following:

Unanticipated Manual actions taken.

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 B reaker PMTs Covers for containment purge in place on GTRT22 and GTRT33 Event No. Malf. No. Event Type* Event Description 1 N/A SRO (N) BOP (N) Place Mini

-Purge in service 2 WEIUBGTC0130TVSPNO AUTO SRO (C) RO (C) LTDN HX Temp Cont Valve Controller Fails 3 (AB)PV004A SRO (C) BOP (C) 'D' SG ASD Fails Open (Tech Specs

) 4 (BB) EBB01D SRO (R) RO (R) BOP (C) SG Tube leak / Downpower (Tech Specs

) 5 (BB)

EBB01D SRO (M) RO (M) BOP (M) SG Tube Rupture 6 CPIS_A_BL OCK_AUTO CPIS_B_BLOCK_AUTO SRO (C) BOP (C) Mini-Purge Failure to isolate 7 (BB)BBPCV0455A SRO (C) RO (C) IA valve failure / PZR PORV 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) 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 ECA-3.1 occurs.

Terminate the RCS depressurization by closing PORV block Valve prior to Loss of Subcooling

. EVENT 5 7 Safety significance Isolating the ruptured SG maintains a differential pressure between the ruptured SG and the intact SGs. The differential pressure (250 psi) ensures that minimum RCS subcooling remains after RCS depressurization.

In the scenario, closing the block MOV constitutes a task that is essential to safety, because its improper performance or omission by an operator will result in direct 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:

Indication and/or annunciation of SGTR in one SG o Increasing SG water level o Radiation Indication and/or annunciation of reactor trip Indication and/or annunciation of Sl All of the following:

Valve position indication and/or annunciation that the PRZR PORV is open, even after attempts to close it manually from the control room Indication and/or annunciation of decreasing RCS pressure Indication and/or annunciation consistent with the discharge of PRZR fluid to the 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 indicator Manipulation of controls as required to isolate the ruptured SG Close Steam line Low point Drain valve from ruptured SG 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 Manipulation of controls as required to close the block MOV for the stuck open PRZR PORV Performance feedback Crew will observe the following:

Indication of stable or increasing pressure in the ruptured SG Indication of decreasing or zero feedwater flow rate in the ruptured SG Valve position indication that the block MOV upstream of the stuck open PRZR PORV is closed Justification for the chosen performance limit When the crew cannot maintain the 250 psi differential, the ERGs require a transition to contingency ERG ECA

-3.1. This transition unnecessarily delays the sequence of actions leading to RCS depressurization and Sl termination.

"prior to Loss of Subcooling.

" is in accordance with the PWR Owners Group Emergency Response Guidelines.

The PWR Owners Group Emergency Response Guidelines 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 Group Appendix CT 18, Isolate the Ruptured SG.

CT 10, Close PRZ PORV Block Valve.

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

/1 00/cond=HWX21o149req1 Malfunctions/BB/BBPCV0465A/1 00/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)PV0 0 04 A_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 Applicant's 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-00001 CRS Implement OTN-GT-00001, CONTAINMENT PURGE SYSTEM CRS (Section 3) Review Precautions and Limitations CRS (Section 4)

Review Prerequisites CRS (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 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

. CRS (Step 5.2.1) ENSURE Section 5.1 has been performed.

(Given in turnover)

CRS/BOP (Step 5.2.2

) ENSURE Shutdown Purge System is NOT in 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 Applicant's Actions or Behavior BOP (NOTE) MINIVENT time trend may be used.

BOP (Step 5.2.3) MONITOR the following instrumentation:

SDRE0041, MANIPULATOR CRANE RAD MONITOR, or plant computer point SDR0041H, MANIP CRANE RAD MON 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 BOP (Step 5.2.4) RECORD containment pressure as read on GT PDI-40, CTMT DP, or plant computer point GTD0040, CTMT

-AUX BLD DIFF PRESS, on Gaseous Radwaste Release Permit. BOP (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) 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 Applicant's Actions or Behavior BOP (Step 5.2.6)

Step is N/A BOP (Step 5.2.7) Using GT HIS

-20, CTMT MINI PURGE EXH FAN & DAMPER, START CGT02.

BOP (Step 5.2.8)

Using GT HIS

-11, CTMT MINI PURGE EXH INNER CTMT ISO, OPEN GTHZ0011.

BOP (Step 5.2.9) Using GT HIS

-12, CTMT MINI PURGE EXH OUTER CTMT ISO, OPEN GTHZ0012 BOP (Step 5.2.10) Using GT HIS

-28, CTMT PURGE EXH DAMPER, OPEN GTHZ0028.

BOP (Step 5.2.11) Using GT HIS

-29, CTMT PURGE EXH DAMPER, OPEN GTHZ0029.

BOP (Step 5.2.12) RECORD date and time dampers were ope ned on Gaseous Radwaste Release Permit. BOP (NOTE) It is permissible to continue with the remainder of this section while Step 5.2.13 is in progress.

BOP (Step 5.2.13) NOTIFY Rad/Chem Technician (Count Room) of time of purge initiation.

BOP (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:

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 Applicant's Actions or Behavior BOP (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:

Using GT HIS

-26, CTMT PURGE SYS AIR SPLY DAMPER, OPEN GTHZ0026.

Using GT HIS

-27, CTMT PURGE SYS AIR SPLY DAMPER, OPEN GTHZ0027.

BOP (CAUTION) SGT02, CTMT MINI PURGE AIR SPLY UNIT, should be running anytime CGT02, CTMT MINI PURGE EXH FAN, is running and Equipment Hatch is closed to prevent drawing excessive vacuum in Containment and creating a personnel hazard.

BOP (Step 5.2.16) Using GT HIS

-23, CTMT MINI PURGE AIR SPLY UNIT, START SGT02.

BOP (Step 5.2.17) Using GT HIS

-5, CTMT MINI PURGE AIR SPLY CTMT ISO, OPEN GTHZ0005.

BOP (Step 5.2.18) Using GT HIS

-4, CTMT MINI PURGE AIR SPLY CTMT ISO, OPEN GTHZ0004.

BOP (Step 5.2.19) MAINTAIN containment pressure +41.5 to

-8.3 5 in. H20 as read on GT PDI

-40, CTMT DP, or plant computer point GTD0040, CTMT

-AUX BLD DIFF PRESS.

NOTE At Lead Examiner's 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 Applicant's 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-00018 ADD 39B CRS Implement OTA-RK-00018 ADD 39B , Letdown Heat Exchanger Discharge Temperature High

. (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.

RO (Step 3.1) MONITOR the following:

BG TI-130, LTDN HX OUTLET TEMP BGTI-127, REGEN HX LTDN OUTLET TEMP RO (Step 3.2) IF letdown temperature exceeds 120°F, PERFORM the following for BGTK

-130, LTDN HX OUTLET TEMP CTRL:

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 Applicant's Actions or Behavior RO (Step 3.3) IF letdown temperature exceeds 130°F, MANUALLY DIVERT letdown to the VCT using BG HIS-129, CVCS DEMIN INLET DIVERT VLV.

RO (Step 3.4) MONITOR the following:

BG FI-121A, CHG HDR FLOW BG FI-132, LTDN HX OUTLET FLOW RO (Step 3.5) IF a Charging and Letdown flow mismatch exists, 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)

BOP (Step 3.6) CHECK CCW conditions from available indications, including the temperature of the CCW train supplying the non

-essential loop:

EG TI-31, CCW HX A OUTLET TEMP EG TI-32, CCW HX B OUTLET TEMP BOP (Step 3.7) IF CCW appears to be the problem, Refer To OTO

-EG-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 Applicant's Actions or Behavior RO (Step 3.8) IF letdown temperature cannot be reduced, PERFORM the following per OTN

-BG-00001, Chemical And Volume Control System. 3.8.1. SECURE normal letdown.

3.8.2. ESTABLISH

Excess letdown.

NOTE At Lead Examiner's 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 Applicant's Actions or Behavior Booth Operator Instructions T = 2 5 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= 2 5 Ann 109F SG PORV Open OTOAB00001, STEAM DUMP MALFUNCTION BOP Prior to entry in to the OTO procedure the BOP may check SG 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 BOP (Step 3) PLACE The Affected SG ASD Controller In Manual And CLOSE The Valve:

AB PIC4A (SG D) BOP (Step 4) NOTIFY Count Room Technician Of Opening And Closing 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 Applicant's Actions or Behavior CRS (Step 18) REVIEW Technical Specification TS 3.7.4 Cond A is applicable CRS (Step 19) PLACE Inoperable Component In The EOSL CRS (Step 21) PERFORM Notifications Per ODPZZ00001 Addendum 13, Shift Manager Communications NOTE Any time after the Tech Specs have been identified and a t Lead Examiner's 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 Applicant's 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 A nn 61A, PROCESS RAD HIHI Ann 61B, PROCESS RAD HI OTO-BB-00001, SG Tube Leak OTO-BB-00001 CRS Implement OTO-BB-00001, SG Tube Leak RO (Step 1) CHECK if PZR Level can be maintained

- YES (eventually becomes

- NO) a. Control charging flow as necessary to maintain PZR level

b. Check Pressurizer Level

- Stable or Rising RNO ISOLATE letdown as necessary.

RAISE charging flow as necessary.

RO (Step 2) CHECK if VCT Level Can be Maintained

- YES 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 Applicant's Actions or Behavior CRS (Step 3) Notify Chemistry to Perform CTP

-ZZ-02590, Primary to Secondary Leakrate Determination RO/BOP (Step 4) Try to identify Affected SG

- "D" Steam Generator High radiation on N16 monitors at the RM

-11 station RO/BOP (Step 5) Determine SG Tube Leak Rate

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.

CRS (Step 6) CHECK if Plant should be Shutdown

a. Using the table in this step determine appropriate actions EPRI Action Level 3, > 75 gpd including confirmed spikes Perform Actions in Attachment D OTO-BB-00001, Att D CRS (Step D1.a) Initiate Step 7 and commence a controlled shutdown 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 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 /> CRS (Step D1.a.1) Perform Applicable procedures as necessary

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 Applicant's Actions or Behavior OTO-MA-00008, Rapid Load Reduction OTO-MA-00008 RO (Step 1) Place Rod Control In AUTO

b. SE HS-9 CRS (Step 2) Manage Reactivity

a. Perform Reactivity Management Brief:

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 Applicant's Actions or Behavior CRS/BOP #(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 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.

CRS/RO #(Step 4) Borate From the BAST by performing any of the 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 RO #(Step 4 c) Set Boric Acid Flow Controller, BG FK

-110, to the desired flow rate RO #(Step 4 d) Place BG FK

-110 in AUTO RO #(Step 4 e) 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 Applicant's Actions or Behavior RO #(Step 4 f) SET BG FY110B for the desired gallons of boric acid to be added RO #(Step 4 g) PLACE BG HS26 in RUN RO #(Step 4 h) WHEN the desired boration is complete, THEN PLACE BG HS-26 in STOP RO #(Step 4 i) repeat Boration as necessary RO (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

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 BOP (Step 6) Check MFP Turbine Speed Control

- IN AUTO FC SK-509B FC SK-509C CUE Once the crew starts the shutdown using steps 1

-6 of OTO-MA-00008, as proven by observation lowering load 5

-10 MWe: 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 Applicant's 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-00001 #(Step 1) CHECK if PZR Level can be maintained

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 Applicant's Actions or Behavior E-0 CRS Implement E

-0, Reactor Trip or Safety Injection NOTE Steps 1 through 4 are immediate actions RO (Step 1) CHECK Reactor Trip Rod Bottom Lights

- All Lit Reactor Trip and Bypass Breakers

- Open Neutron Flux

- Lowering BOP (Step 2) CHECK Turbine Trip

a. Turbine Stop Valves

- Closed BOP (Step 3) CHECK Power to AC Emergency Buses

a. At Least One Emergency Bus

- Energized b. Both Emergency Buses

- Energized RO (Step 4) CHECK SI Status a. Check if SI is Actuated

b. Check both Trains of SI Actuated LOCA Sequencer ANN 30A

- Lit LOCA Sequencer ANN 31A

- Lit SB069 SI Actuate Red Light

- Lit Solid RO/BOP (Step 5) Perform Attachment A, Automatic Action Verification, 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 Applicant's Actions or Behavior BOP (Step 7) CHECK Feedwater Isolation

a. Main Feedwater Pumps

- Tripped b. Main Feedwater Reg Valves

- Closed c. Main Feedwater Reg Bypass Valves

- Closed d. Feedwater Isolation Valves

- Closed BOP (Step 8) CHECK AFW Pumps a. MD AFW Pumps

- B Running (A MD AFW pump tagged out)

b. TD AFW Pump

- Running BOP (Step 9) CHECK AFW Valves

- Proper Emergency Alignment MD AFP Flow Control Valves

- Throttled 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 BOP (Step 11) CHECK PZR PORVs and Spray Valves

a. PZR PORVs

- Closed b. PZR PORVs

- Both in AUTO

c. PORV Block Valves

- Both Open d. Normal PZR Spray Valves

- Closed BOP (Step 12) CHECK if RCPs should be Stopped

a. RCPs - Any Running 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 Applicant's Actions or Behavior BOP #(Step 13) CHECK RCS Temperatures RCPs Running

- Tavg 557 Deg F No RCPs Running

- Tcold 557 Deg F RO/BOP (Step 14) CHECK if any SG is Faulted

a. CHECK pressures in all SGs:

Any SG pressure lowering in an uncontrolled manner

- Any SG completely depressurized RNO - Go to Step 15 RO/BOP (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 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 NOTE Personnel should be available for sampling during this procedure 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 Applicant's Actions or Behavior E-3 RO (Step 1) CHECK if RCPs should be stopped

a. RCPs - Any Running

b. ECCS Pumps

- At Least one Running

c. RCS pressure

- Less than 1425 PSIG

- NO RNO Go To Step 2 BOP (Step 2) Identify Ruptured SG(s)

Unexpected rise in any SG narrow range level High radiation from any SG sample High radiation from any SG steamline High radiation from any SG blowdown line sample BOP (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 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) BOP (Step 4) CHECK Ruptured SG level

a. Narrow range level > 7% [25%]

b. Stop feed flow to ruptured SG CLOSE AL HK

-5A and AL HK

-6 A (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 Applicant's Actions or Behavior Critical Task CREW Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA

-3.1 occurs.

RO/BOP (Step 5) CHECK Ruptured SG Pressure

- > 340 psig CAUTION If RCPs are NOT running, the following steps may cause a false CSF-1, Figure 4, Integrity Status Tree indication for the ruptured loop. Disregard the ruptured loop T

-cold indication until after performing Step 29 NOTE After the low steamline pressure SI signal is blocked, main steamline isolation will occur if the high steam pressure rate setpoint is exceeded.

BOP (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

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 BOP (Step 7) Check Intact SG Levels:

a. Narrow Range levels

- Greater than 7% [25%]

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 Applicant's Actions or Behavior BOP (Step 8) Check PZR PORVs and Block Valves

a. Power to Block Valves

- Available 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 BOP (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).

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. BOP (Step 12) Check if RHR Pumps should be stopped:

a. RHR Pumps

- Any running with suction aligned to RWST

b. RCS Pressure

- Greater than 325 psig

c. STOP RHR Pumps and Place in standby.

RO (Step 13) Check if RCS Cooldown should be stopped:

a. Core exit TCs

- Less than required temperature

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 Applicant's Actions or Behavior RO (Step 15)

Check RCS Subcooling

- Greater than 50 ºF [70 ºF]

Containment Pressure

- Normal Containment Normal Sump level

- Normal Containment Radiation

- Normal before isolation RO (Step 16)

Depressurize RCS to Minimize Break Flow and Refill PZR: a. Normal PZR Spray

- Available

- NO RNO: Go to Step 17.

RO (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 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 Task CREW Terminate the RCS depressurization by closing PORV block 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 Applicant's Actions or Behavior RO (Step 19)

CHECK If ECCS Flow Should Be Terminated:

a. RCS subcooling

- b. Secondary heat sink: Narrow range level in at least one intact SG

- GREATER THAN 7% [25%]

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 EVAL Once the PORV block Valve has been closed in STEP 17 OR at the discretion of the Lead evaluato r - 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 Applicant's 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 RO/BOP (Step A4) CHECK ESW Pumps

- BOTH RUNNING EF HIS-55A EF HIS-56A RO/BOP (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 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 RO/BOP (Step A6) CHECK Containment Cooler Fans

- RUNNING IN SLOW SPEED RO/BOP (Step A7) CHECK Containment Hydrogen Mixing Fans

- 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 Applicant's Actions or Behavior RO/BOP (Step A9) CHECK If Main Steamlines Should Be Isolated:

Containment pressure > 17 psig Steamline pressure

- LESS THAN 615 PSIG RO/BOP (Step A10) CHECK ECCS Valves

- PROPER EMERGENCY ALIGNMENT RO/BOP (Step A11) CHECK Containment Isolation Phase A RO/BOP (Step A12) CHECK SG Blowdown Isolation:

RO/BOP (Step A13) CHECK Both Trains of Control Room Ventilation Isolation RO/BOP (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:

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 RO/BOP (Step A15) NOTIFY CRS of the following:

Unanticipated Manual actions taken.

Failed Equipment status Attachment A, Automatic Action Verification, completed.

ES-301-5 Page 1 of 4 Facility: Callaway Date of Exam:

12/08/20 1 4 Operating Test No.:

2014-1 Crew A SRO-I: I1, I2, RO:

R1 A P P L I C A N T E V

E N T T Y P E Scenarios 2 3 4 T O T A L M I N I M U M(*) CREW POSITION CREW POSITION CREW POSITION I1 I2 R1 I2 I1 R1 I1 R1 I2 S R O A T C B O P S R O A T C B O P S R O A T C B O P R I U SRO-I (I1) RX 3 4 2 1 NOR 1 1 2 1 I/C 2,3,4, 5 ,8 1,4,7 2,3,6, 7 12 4 MAJ 6 5,6 5 4 2 TS 2,3,4 3,4 5 2 SRO-I (I2) RX 3 1 1 NOR 1 1 1 I/C 2,3,5 1,2,4 , 7 3,4,6 10 4 MAJ 6 5,6 5 4 2 TS 1,2 2 2 RO (R1) RX 4 1 1 NOR 1 1 1 I/C 4,7,8 1,2,3, 4 2 ,7 9 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 applicant's competence count toward the minimum requirements specified for the applicant's license level in the right

-hand columns.

ES-301-5 Page 2 of 4 Facility: Callaway Date of Exam:

12/08/20 14 Operating Test No.:

2014-1 Crew B SRO-I: I3, I5 A P P L I C A N T E V

E N T T Y P E Scenarios 2 3 T O T A L M I N I M U M(*) CREW POSITION CREW POSITION CREW POSITION I5 I3 Surr ogat e I3 I5 Surr ogat e S R O A T C B O P S R O A T C B O P S R O A T C B O P R I U SRO-I (I3) RX 3 1 1 NOR 0* 1 I/C 2,3,5 1,2,4 ,7 7 4 MAJ 6 5,6 3 2 TS 1,2 2 2 SRO-I (I5) RX 3 1 1 NOR 1 1 1 I/C 2,3,4,5,8 1,4,7 8 4 MAJ 6 5,6 3 2 TS 2,3,4 3 2 RX NOR I/C MAJ TS RX NO R 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 applicant's competence count toward the minimum requirements specified for the applicant's license level in the right

-hand columns.

ES-301-5 Page 3 of 4 Facility: Callaway Date of Exam:

12/08/20 14 Operating Test No.:

2014-1 Crew C SRO-I: I4, I6 A P P L I C A N T E V

E N T T Y P E Scenarios 2 3 T O T A L M I N I M U M(*) CREW POSITION CREW POSITION CREW POSITION I6 I4 Surrogate I4 I6 Surrogate S R O A T C B O P S R O A T C B O P S R O A T C B O P R I U SRO-I (I4) RX 3 1 1 NOR 0* 1 I/C 2,3,5 1,2,4, 7 8 4 MAJ 6 5,6 3 2 TS 1,2 2 2 SRO-I (I6) RX 3 1 1 NOR 1 1 1 I/C 2,3,4,5,8 1,4,7 8 4 MAJ 6 5,6 3 2 TS 2,3,4 3 2 RX NO R 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 applicant's competence count toward the minimum requirements specified for the applicant's license level in the right

-hand columns.

ES-301-5 Page 4 of 4 Facility: Callaway Date of Exam:

12/08/20 14 Operating Test No.:

2014-1 A P P L I C A N T E V

E N T T Y P E Scenarios 1 T O T A L M I N I M U M(*) CREW POSITION CREW POSITION CREW POSITION CREW POSITION S R O A T C B O P S R O A T C B O P S R O A T C B O P S R O A T C B O P R I U SPARE RX NOR I/C 1, 2 ,3 ,6,7 1,3 2 ,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) b ut 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 applicant's competence count toward the minimum requirements specified for the applicant's 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 I 4 I6 Surrogate 12/9/14 1230-1445 Crew A I 2 I1 R1 Scenario 2 12/10/14 0730-0945 Crew C I 6 I4 Surrogate 12/10/14 0945-1200 Crew B I 5 I 3 Surrogate 12/10/14 1230-1445 Crew A I1 I2 R1 Scenario 4 12/11/14 0730-0945 Crew A I1 R1 I2 ES-301 Competencies Checklist Form ES-301-6 Facility: Date of Examination:

Operating Test No.:

Competencies APPLICANTS RO SRO-I SRO-U RO SRO-I SRO-U SCENARIO SCENARIO 1* 2 3 4 1* 2 3 4 Interpret/Diagnose Events and Conditions 1,2,3,4,5,6,7 3,4,5,6 ,7 ,8 1,2,3,4,5,6,7 2,3,4,5,6,7 1,2,3,4,5,6,7 3,4,5,6 ,7 ,8 1,2,3,4,5,6,7 2,3,4,5,6,7 Comply With and Use Procedures (1) 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 Operate Control Boards (2) 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 Communicate and Interact 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 Demonstrate Supervisory Ability (3) 1,2,3,4,5,6,7 1,2,3,4,5,6,7 , 8 1,2,3,4,5,6,7 1,2,3,4,5,6,7 Comply With and Use Tech. Specs. (3) 1,3 2,3 ,4 1,2 3,4 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.