ML091811173

CW-2009-06-Final Operating Test

ML091811173
Person / Time
Site:	Callaway
Issue date:	06/30/2009
From:	Apger G Operations Branch IV
To:
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Download: ML091811173 (284)

Text

ES-301 Administrative Topics Outline Form ES-301-1 Rev 1 Facility: Callaway Date of Examination: 6/19/2009 Examination Level: RO Operating Test Number:

Administrative Topic Type Code* Describe activity to be performed (see Note) 015 A1.04 (3.5) Ability to predict and/or monitor changes in Conduct of Operations parameters to prevent exceeding design limits associated with operating the NIS controls P, R including Quadrant Power Tilt Ratio A1a JPM: Perform a QPTR Calculation 2.1.25 (3.9/4.2) Ability to interpret reference materials such as Conduct of Operations graphs, curves, tables, etc.

N, R RA2 JPM: Determine RV Venting Time (EOP ADD 33) 2.2.13 (4.1) Knowledge of tagging and clearance Equipment Control procedures.

D, R RA3 JPM: Tag out A Reactor Makeup Water Transfer Pump (PBL01A) 2.4.39 (3.9) Knowledge of RO responsibilities in emergency Emergency Procedures/Plan plan implementation.

M, R RA4 JPM: Visitor Control During an Event NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

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

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

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

NUREG-1021, Revision 9, Supplement 1

ES-301 Administrative Topics Outline Form ES-301-1 Rev 1 RO Admin JPM Summary A1a This is previously used JPM ILE-A001-RO. It was used on the 2005 NRC Exam, but the values provided will differ from those given in 2005. In the 2005 exam, the candidate was cued as to the value of the NI detector currents. During this exam the candidate will be given a set of values that reflect what is being seen in the plant. He will then use this data to calculate Quadrant Power Tilt Ratio using the most current Curve Book and the surveillance procedure. Therefore, the values calculated will differ from those on the 2005 exam.

RA2 This is a new JPM. The candidate is to determine the maximum RV Venting time using EOP Addendum 33. A marked up FR-I.3 will be provided.

RA3 This is bank JPM ILE-A012-RO. Requires the candidate to prepare Workers Protection Assurance (WPA) / tagout on a Reactor Makeup Water Transfer Pump.

RA4 This is a Modified JPM obtained from a Ft. Calhoun Station NRC exam and made to be Callaway specific. This JPM requires that the candidate, as a newly licensed Reactor Operator, state where to escort a visitor under his control while in the Protected area and then to state where he is required to report following the previous actions. This is in accordance with the Callaway Emergency Plan.

NUREG-1021, Revision 9, Supplement 1

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: A1a Rev 1 KSA NO: 015 A1.04 COMPLETION TIME: 15 MINUTES KSA RATING: 3.5/3.7 JOB TITLE: RO / SRO(I) REVISION: 2009 DUTY: NUCLEAR INSTRUMENTATION TASK TITLE: PERFORM A QPTR CALCULATION The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OSP-SE-00003, Quadrant Power Tilt Ratio, Revision 17 CURVE BOOK TABLE 11-1, Revision 215 TOOLS/EQUIPMENT: Procedures stated above, Calculator, Copy of detector currents page FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: A1a Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at MOL, 100% power with the indicated axial flux difference (AFD) equal to 0%. Control Room annunciators 78B, 78C, and 78F are not operable. All power range nuclear instruments are operable. The Control Room Plant Computer System is not available for use.

Initiating Cues: The Control Room Supervisor directs you to perform a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

Forward the data you have entered in OSP-SE-00003 to the Examiner.

TASK STANDARD: Upon completion of this JPM, the operator will have performed a manual QPTR calculation with a final QPTR tolerance of +/- 0.01.

START TIME:

STOP TIME:

PAGE 1 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. Obtain a verified working copy CANDIDATE OBTAINED A of OSP-SE-00003, QPTR COPY OF OSP-SE-00003, Comments:

Calculation. QUADRANT POWR TILT RATIO CALCULATION PROVIDE CANDIDATE WITH COPY OF OSP-SE-00003 and page with upper and lower detector currents S U

2. Review Precautions and Operator reviewed Precautions Limitations and Limitations Comments:

STEP 4.0 All Precautions and Limitations are satisfied.

S U

3. Review Prerequisites Operator reviewed Prerequisites Comments:

STEP 5.0 Prerequisites are satisfied.

S U

4. Record each power range Using the data sheet provided the upper current output on Operator located the correct upper Comments:

Attachment #1. and lower current meters for the power range detectors and STEP 6.2.1 recorded the values in the correct area of OSP-SE-00003, Attachment 1.

• CRITICAL STEP PAGE 2 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 5. Use Table 11.1 from the Operator located Table 11-1, AFD Calibration value Table, AFD = Comments:

Curve Book to obtain the 0%, to record power range upper current values for the upper and lower current values.

and lower detectors. AFD =

0% values should be used.

STEP 6.2.2 S U

• 6. Divide each upper and lower Operator divided each upper and lower detector current by its 100% Comments:

detector current by its 100%,

power, 0% AFD detector current 0% AFD power detector value and entered it as the current value and enter it in normalized detector current for the normalized detector each channel.

current for each channel.

The upper and lower calculated STEP 6.2.3 values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

• 7. Add the normalized upper Operator added up the normalized upper detector currents and Comments:

detector currents and divide divided by 4 to derive the upper by four (4) to derive the upper detector normalized current detector normalized current averages and recorded it in average and record it in Attachment #1.

Attachment #1.

The upper calculated values STEP 6.2.4 should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

• CRITICAL STEP PAGE 3 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 8. Add the normalized lower Operator added up the normalized lower detector currents and Comments:

detector currents and divide divided by 4 to derive the lower by four (4) to derive the lower detector normalized current detector normalized current averages and recorded it in averages and record it in Attachment #1.

Attachment #1.

The lower calculated values STEP 6.2.5 should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

9. The QPTR should be The operator calculated the calculated as two significant QPTR, to two (2) significant Comments:

digits to the right of the digits to the right of the decimal decimal point. point.

Note before 6.2.6 S U

• 10.Divide each upper normalized Operator divided each upper normalized detector current by the Comments:

detector current by the upper upper normalized detector normalized detector current average to obtain the power tilt average to obtain the power ratio for each upper channel.

tilt ration for each upper channel and RECORD on The Operator recorded this in Attachment 1 Attachment 1.

STEP 6.2.6 The upper calculated values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

• CRITICAL STEP PAGE 4 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 11.Divide each lower normalized Operator divided each lower normalized detector current by the Comments:

detector current by the lower lower normalized detector current normalized detector current average to obtain the power tilt average to obtain the power ratio for each lower channel.

tilt ratio for each lower channel and RECORD on The Operator recorded this in Attachment 1.

Attachment 1.

STEP 6.2.7 The upper calculated values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

12. IF the manual calculations do All QPTRs are less than 1.02, no NOT confirm a QPTR of action is required. The affected Comments:

greater than 1.02, DECLARE annunciators were identified as the Plant Computer Points inoperable on the Cue sheet.

and QPTR alarm INOPERABLE.

13. THE JPM IS COMPLETE RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 5 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

14. COMPARE CANDIDATES ATTACHMENT 1 WITH THE Comments:

ONE PROVIDED.

ENSURE THE QPTR DOES NOT EXCEED 1.02 FOR ANY CHANNEL.

• CRITICAL STEP PAGE 6 of 6

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at MOL, 100% power with the indicated axial flux difference (AFD) equal to 0%. Control Room annunciators 78B, 78C, and 78F are not operable. All power range nuclear instruments are operable. The Control Room Plant Computer System is not available for use.

Initiating Cues: The Control Room Supervisor directs you to perform a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

Forward the data you have entered in OSP-SE-00003 to the Examiner.

CALLAWAY PLANT ADMINISTRATIVE JOB PERFORMANCE MEASURE JPM NO: RA2 Rev 1 KSA NO: G2.1.25 JOB TITLE: RO KSA RATING: 3.9/4.2 DUTY: ADMINISTRATIVE REVISION: 2009 TASK TITLE: DETERMINE REACTOR VESSEL VENTING TIME 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

EOP ADDENDUM 33, Revision 001 TOOLS/EQUIPMENT: NONE FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: RA2 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: The crew is responding to plant conditions using FR-I.3, Response to Voids in the Reactor Vessel. The following conditions exist:

• Containment pressure is 2.8 psig.

• Containment Temperature is 167 °F.

• Containment Hydrogen Concentration is 2.3%.

• RCS Pressure is 1825 psig.

Initiating Cues: The CRS now directs you to determine RV Venting Time in accordance with EOP Addendum 33.

TASK STANDARD: RV Venting time is determined IAW EOP Addendum 33.

START TIME:

STOP TIME:

PAGE 1 of 3

ADMIN JPM NO: RA2 Rev 1 S U

1. PROVIDE CANDIDATE CANDIDATE REVIEWED WITH MATERIAL AND ADMIN JPM INITIAL Comments:

ALLOW TIME FOR CONDITIONS AND REVIEW OF WORK TO BE INITIATING CUES PERFORMED S U

• 2. DETERMINE CANDIDATE DETERMINED CONTAINMENT AIR CONTAINMENT AIR VOLUME Comments:

VOLUME AT STP = A IS BETWEEN 2.3 X 106 AND 2.336 X 106 FT3 STEP 1 S U

3. *CANDIDATE SHOULD CANDIDATE DETERMINED DETERMINE MAXIMUM THAT BETWEEN 1.6 X 104 Comments:

HYDROGEN VOLUME AND 1.635 X 104 FT3 CAN BE THAT CAN BE VENTED = VENTED B

STEP 2 PAGE 2 of 3

ADMIN JPM NO: RA2 Rev 1 S U

• 4. CANDIDATE SHOULD CANDIDATE DETERMINED DETERMINE HYDROGEN THAT HYDROGEN FLOW Comments:

FLOW RATE AS A RATE IS BETWEEN 9150 AND FUNCTION OF RCS 9250 FT3/MINUTE USING PRESSURE = C FIGURE 1 Step 3 S U

• 5. CANDIDATE SHOULD CANDIDATE DETERMINED DETERMINE MAXIMUM THAT THE MAXIMUM Comments:

VENTING TIME VENTING TIME IS BETWEEN 1.72 AND 1.79 MINUTES STEP 4 S U

6. THIS ADMIN JPM IS COMPLETE Comments:

RECORD STOP TIME ON PAGE 1 PAGE 3 of 3

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: The crew is responding to plant conditions using FR-I.3, Response to Voids in the Reactor Vessel. The following conditions exist:

• Containment Pressure is 2.8 psig.

• Containment Temperature is 167 °F.

• Containment Hydrogen Concentration is 2.3%.

• RCS Pressure is 1825 psig.

Initiating Cues: The CRS now directs you to determine RV Venting Time in accordance with EOP Addendum 33.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: RA3 Rev1 KSA NO: GEN2.1.18 COMPLETION TIME: 15 MINUTES KSA RATING: 4.1/4.3 JOB TITLE: RO REVISION: 2009 DUTY: ADMINISTRATIVE TASK TITLE: TAG OUT A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A)

The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

APA-ZZ-00310, ODP-ZZ-00310 TOOLS/EQUIPMENT: TAGOUT CONTINUATION SHEET, M-22BL01, E-23BL04 FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: RA3 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: THE A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) MUST BE TAGGED OUT TO REPLACE THE IMPELLER.

Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO DETERMINE THE FOLLOWING INFORMATION AND COMPLETE THE TAGOUT CONTINUATION SHEET PROVIDED:

• TYPE OF WORKMANS PROTECTION ASSURANCE REQUIRED

• APPROPRIATE TAGGING SEQUENCE

• COMPONENTS TO BE TAGGED

• TAGGED POSITIONS OF COMPONENTS INFORM THE CONTROL ROOM SUPERVISOR WHEN DONE.

NOTE TO EXAMINER: Have applicants identify the print numbers they need, then provide prints.

Notes: USE OF THE MAINFRAME COMPUTER IS NOT ALLOWED.

TASK STANDARD: UPON COMPLETION OF THE TASK, THE CANDIDATE WILL HAVE COMPLETED TAGOUT CONTINUATION SHEET FOR THE A RMWT PUMP WITH THE FOLLOWING TAGS IDENTIFIED: HOLD OFF TAG ON THE MCC BREAKER (OFF/OPEN), SUCTION VALVE (CLOSED), AND DISCHARGE VALVE (CLOSED), RECIRC LINE (CLOSED) AND DRAIN LINES (OPEN - CAP REMOVED). TAG SEQUENCE FOR LAST TWO TAGS IS CRITICAL.

START TIME:

STOP TIME:

PAGE 1 of 3

ADMIN JPM NO: RA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. PROVIDE CANDIDATE CANDIDATE REVIEWED WITH MATERIAL AND ADMIN JPM INITIAL Comments:

ALLOW HIM TO REVIEW CONDITIONS AND WORK TO BE INITIATING CUES.

PERFORMED STEPS MAY BE PERFORMED IN ANY ORDER S U 2.* DETERMINE TYPE OF CANDIDATE MAY REVIEW WPA REQUIRED FOR APA-ZZ-00310 TO ENSURE Comments:

TAGGING OUT 'A' TAGGING IS FOR HUMAN REACTOR MAKEUP PROTECTION, AND THE WATER XFR PUMP EQUIPMENT WILL NOT BE (PBL01A) IS A HOLD OFF OPERATED.

APA-ZZ-00310, STEP CANDIDATE DETERMINED A 4.1.1 HOLD OFF IS REQUIRED.

• CRITICAL STEP PAGE 2 of 3

ADMIN JPM NO: RA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 3.* CANDIDATE DETERMINED FOLLOWING TAGS ARE Comments:

REQUIRED:

• WPA TYPE: HOLD OFF BLHIS3 (MCB): PTL (WIP)

BLHS3 (LOCAL): PTL (WIP)

• PG19NCF5: OFF OR OPEN

• BLV0011: CLOSED

• BLV0013: CLOSED

• BLV0018: CLOSED

• BLV0081: OPEN / CR

• BLV0084: OPEN / CR TAG SEQUENCE IS CRITICAL PG19NCF5 TAGGED PRIOR TO BLV0011,13, 18 AND BLV0011,13, 18 TAGGED PRIOR TO OPENING DRAIN VALVES BLV0081 AND BLV0084.

S U

4. THIS ADMIN JPM IS COMPLETE Comments:

RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 3 of 3

TAGOUT CONTINUATION SHEET WPA TYPE: *HOLD OFF TAG SEQUENCE NUMBER TAGGED COMPONENT TAGGING POSITION 1 BLHIS3 PULL TO LOCK (WIP) 2 BLHS3 PULL TO LOCK (WIP) 3 *PG19NCF5 *OFF 4 *BLV0011 *CLOSED 5 *BLV0013 *CLOSED 6 *BLV0018 *CLOSED 7 *BLV0081 *OPEN / CAP REMOVED 8 *BLV0084 *OPEN /CAP REMOVED

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: THE A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) MUST BE TAGGED OUT TO REPLACE THE IMPELLER.

Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO DETERMINE THE FOLLOWING INFORMATION AND COMPLETE THE TAGOUT CONTINUATION SHEET PROVIDED:

• TYPE OF WORKMANS PROTECTION ASSURANCE REQUIRED

• APPROPRIATE TAGGING SEQUENCE

• COMPONENTS TO BE TAGGED

• TAGGED POSITIONS OF COMPONENTS INFORM THE CONTROL ROOM SUPERVISOR WHEN DONE.

Notes: USE OF THE MAINFRAME COMPUTER IS NOT ALLOWED.

TAGOUT CONTINUATION SHEET WPA TYPE:

TAG SEQUENCE NUMBER TAGGED COMPONENT TAGGING POSITION

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: RA4 Rev 1 KSA NO: GEN 2.4.39 COMPLETION TIME: 10 MINUTES KSA RATING: 3.9/3.8 JOB TITLE: RO REVISION: 2009 DUTY: ADMINISTRATIVE TASK TITLE: VISITOR CONTROL DURING AN EVENT The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

EIP-ZZ-00230, ACCOUNTABILITY, REVISION 30 EIP-ZZ-00102, EMERGENCY IMPLEMENTING ACTIONS, REVISION 42 TOOLS/EQUIPMENT:

FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: RA4 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: THE CALLAWAY PLANT IS OPERATING AT 100% POWER.

Initiating Cues: YOU ARE ESCORTING A PLANT VISITOR IN THE TURBINE BUILDING.

THE SHIFT MANAGER HAS JUST ANNOUNCED THAT A SITE AREA EMERGENCY (SAE) HAS BEEN DECLARED.

WRITE DOWN YOUR ACTIONS FOLLOWING THIS DECLARATION.

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE ENSURED THAT THE VISITOR HAS EXITED THE PROTECTED AREA .

ALSO, SINCE ASSEMBLY IS REQUIRED, THE OPERATOR WILL PROCEED TO THE OPERATIONS FIELD OFFICE/CONTROL ROOM.

START TIME:

STOP TIME:

PAGE 1 of 2

JPM NO: RA4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 1. Escort the visitor to Visitor is taken to the the Main Access Main Access Facility Comments:

Facility STEP 4.3.1.a S U

• 2. INSTRUCT visitors IF asked: The visitor is Visitor is instructed to to leave the site not authorized to leave the Comments:

following the remain on-site by the Facility/turned over to directions of SM/EC or Security Security Personnel.

Security personnel Coordinator/SSS.

unless authorized to remain by the SM/EC or Security Coordinator/SSS STEP 4.3.1.b S U

• 3. PROCEED to the IF asked: Inquire Operator informed you Field Office for where the Operator he will now go to the Comments further instructions would now proceed. Field Office/Control Room for further , Item #2 instruction.

S U

4. RECORD STOP TIME ON PAGE 1 Comments:

• CRITICAL STEP PAGE 2 of 2

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: THE CALLAWAY PLANT IS OPERATING AT 100% POWER.

Initiating Cues: YOU ARE ESCORTING A PLANT VISITOR IN THE TURBINE BUILDING.

THE SHIFT MANAGER HAS JUST ANNOUNCED THAT A SITE AREA EMERGENCY (SAE) HAS BEEN DECLARED.

WRITE DOWN YOUR ACTIONS FOLLOWING THIS DECLARATION.

ES-301 Administrative Topics Outline Form ES-301-1 Rev 1 Facility: Callaway Date of Examination: 6/19/2009 Examination Level: SRO Operating Test Number:

Administrative Topic Type Code* Describe activity to be performed (see Note) 015 A1.04 (3.5) Ability to predict and/or monitor changes in Conduct of Operations parameters to prevent exceeding design limits associated with operating the NIS controls including Quadrant Power Tilt Ratio A1a P, R JPM: Perform a QPTR Calculation 2.1.18 (3.8) Ability to make accurate, clear, and concise Conduct of Operations logs, records, status boards, and reports.

D, R SA2 JPM: Determine Reportability Requirements 2.2.13 (4.3) Knowledge of tagging and clearance Equipment Control procedures.

D, R SA3 JPM: Review WPA for A Reactor Makeup Water Transfer Pump 2.3.4 (3.7) Knowledge of radiation exposure limits under Radiation Control normal or emergency conditions.

N, R SA4 JPM: Select Volunteer for Emergency Exposure 2.4.41 (4.6) Knowledge of the emergency action level Emergency Procedures/Plan thresholds and classifications.

D, R SA5 JPM: Emergency Event Classification NOTE: All items (5 total) are required for SROs. RO applicants require only 4 items unless they are retaking only the administrative topics, when 5 are required.

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

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

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

NUREG-1021, Revision 9

ES-301 Administrative Topics Outline Form ES-301-1 Rev 1 SRO Admin JPM Summary A1a This is previously used JPM ILE-A001-RO. It was used on the 2005 NRC Exam, but the values provided will differ from those given in 2005. In the 2005 exam, the candidate was cued as to the value of the NI detector currents. During this exam the candidate will be given a set of values that reflect what is being seen in the plant. He will then use this data to calculate Quadrant Power Tilt Ratio using the most current Curve Book and the surveillance procedure. Therefore, the values calculated will differ from those on the 2005 exam.

SA2 This is bank JPM ILE-A025-SRO. Given a set of conditions, the SRO candidate will be required to inform the examiner of the time requirement and the agency requiring notification.

SA3 This is bank JPM ILE-A013-SRO. Given a copy of Workers Protection Assurance (WPA) on a Reactor Makeup Water Transfer the Pump, the SRO candidate will review the package for any apparent errors in its preparation.

SA4 This is a new JPM. The SRO candidate will be given a set of conditions and the appropriate procedures in an emergency radiological situation. The SRO candidate, acting as the Emergency Coordinator, will determine which volunteer is the most eligible to receive an emergency dose.

SA5 This is bank JPM ILE-A008-SRO. Given a set of conditions and a timeline of events, the SRO candidate will determine the correct Emergency Action level using the EAL charts provided.

NUREG-1021, Revision 9

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: A1a Rev 1 KSA NO: 015 A1.04 COMPLETION TIME: 15 MINUTES KSA RATING: 3.5/3.7 JOB TITLE: RO / SRO(I) REVISION: 2009 DUTY: NUCLEAR INSTRUMENTATION TASK TITLE: PERFORM A QPTR CALCULATION The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OSP-SE-00003, Quadrant Power Tilt Ratio, Revision 17 CURVE BOOK TABLE 11-1, Revision 215 TOOLS/EQUIPMENT: Procedures stated above, Calculator, Copy of detector currents page FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: A1a Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at MOL, 100% power with the indicated axial flux difference (AFD) equal to 0%. Control Room annunciators 78B, 78C, and 78F are not operable. All power range nuclear instruments are operable. The Control Room Plant Computer System is not available for use.

Initiating Cues: The Control Room Supervisor directs you to perform a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

Forward the data you have entered in OSP-SE-00003 to the Examiner.

TASK STANDARD: Upon completion of this JPM, the operator will have performed a manual QPTR calculation with a final QPTR tolerance of +/- 0.01.

START TIME:

STOP TIME:

PAGE 1 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. Obtain a verified working copy CANDIDATE OBTAINED A of OSP-SE-00003, QPTR COPY OF OSP-SE-00003, Comments:

Calculation. QUADRANT POWR TILT RATIO CALCULATION PROVIDE CANDIDATE WITH COPY OF OSP-SE-00003 and page with upper and lower detector currents S U

2. Review Precautions and Operator reviewed Precautions Limitations and Limitations Comments:

STEP 4.0 All Precautions and Limitations are satisfied.

S U

3. Review Prerequisites Operator reviewed Prerequisites Comments:

STEP 5.0 Prerequisites are satisfied.

S U

4. Record each power range Using the data sheet provided the upper current output on Operator located the correct upper Comments:

Attachment #1. and lower current meters for the power range detectors and STEP 6.2.1 recorded the values in the correct area of OSP-SE-00003, Attachment 1.

• CRITICAL STEP PAGE 2 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 5. Use Table 11.1 from the Operator located Table 11-1, AFD Calibration value Table, AFD = Comments:

Curve Book to obtain the 0%, to record power range upper current values for the upper and lower current values.

and lower detectors. AFD =

0% values should be used.

STEP 6.2.2 S U

• 6. Divide each upper and lower Operator divided each upper and lower detector current by its 100% Comments:

detector current by its 100%,

power, 0% AFD detector current 0% AFD power detector value and entered it as the current value and enter it in normalized detector current for the normalized detector each channel.

current for each channel.

The upper and lower calculated STEP 6.2.3 values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

• 7. Add the normalized upper Operator added up the normalized upper detector currents and Comments:

detector currents and divide divided by 4 to derive the upper by four (4) to derive the upper detector normalized current detector normalized current averages and recorded it in average and record it in Attachment #1.

Attachment #1.

The upper calculated values STEP 6.2.4 should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

• CRITICAL STEP PAGE 3 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 8. Add the normalized lower Operator added up the normalized lower detector currents and Comments:

detector currents and divide divided by 4 to derive the lower by four (4) to derive the lower detector normalized current detector normalized current averages and recorded it in averages and record it in Attachment #1.

Attachment #1.

The lower calculated values STEP 6.2.5 should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

9. The QPTR should be The operator calculated the calculated as two significant QPTR, to two (2) significant Comments:

digits to the right of the digits to the right of the decimal decimal point. point.

Note before 6.2.6 S U

• 10.Divide each upper normalized Operator divided each upper normalized detector current by the Comments:

detector current by the upper upper normalized detector normalized detector current average to obtain the power tilt average to obtain the power ratio for each upper channel.

tilt ration for each upper channel and RECORD on The Operator recorded this in Attachment 1 Attachment 1.

STEP 6.2.6 The upper calculated values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

• CRITICAL STEP PAGE 4 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 11.Divide each lower normalized Operator divided each lower normalized detector current by the Comments:

detector current by the lower lower normalized detector current normalized detector current average to obtain the power tilt average to obtain the power ratio for each lower channel.

tilt ratio for each lower channel and RECORD on The Operator recorded this in Attachment 1.

Attachment 1.

STEP 6.2.7 The upper calculated values should be as shown in the Attachment 1 KEY.

Values within +/- 0.01 on each calculation are acceptable.

S U

12. IF the manual calculations do All QPTRs are less than 1.02, no NOT confirm a QPTR of action is required. The affected Comments:

greater than 1.02, DECLARE annunciators were identified as the Plant Computer Points inoperable on the Cue sheet.

and QPTR alarm INOPERABLE.

13. THE JPM IS COMPLETE RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 5 of 6

ADMIN JPM NO: A1a Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

14. COMPARE CANDIDATES ATTACHMENT 1 WITH THE Comments:

ONE PROVIDED.

ENSURE THE QPTR DOES NOT EXCEED 1.02 FOR ANY CHANNEL.

• CRITICAL STEP PAGE 6 of 6

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at MOL, 100% power with the indicated axial flux difference (AFD) equal to 0%. Control Room annunciators 78B, 78C, and 78F are not operable. All power range nuclear instruments are operable. The Control Room Plant Computer System is not available for use.

Initiating Cues: The Control Room Supervisor directs you to perform a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

Forward the data you have entered in OSP-SE-00003 to the Examiner.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: SA2 Rev 1 KSA NO: GEN2.1.18 COMPLETION TIME: 15 MINUTES KSA RATING: 3.6/3.8 JOB TITLE: SRO REVISION: 2009 DUTY: ADMINISTRATIVE TASK TITLE: DETERMINE REPORTABILITY REQUIREMENTS The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES, REVISION 29 TOOLS/EQUIPMENT: Copy of APA-ZZ-00520 FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: SA2 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: THE CALLAWAY PLANT IS OPERATING AT 100% POWER. A MAIN STEAM LINE SAFETY VALVE ABV055 FAILS OPEN. THE EVENT RESULTS IN A REACTOR TRIP AND SAFETY INJECTION. ALL SYSTEMS RESPONDED AS DESIGNED.

RCS PRESSURE IS CURRENTLY AT 1550 PSIG. A STEAM GENERATOR PRESSURE IS 10 PSIG.

Initiating Cues: YOU ARE AN EXTRA SRO ON SHIFT PERFORMING CONTROL ROOM OBSERVATIONS. THE SHIFT MANAGER (SM) HAS DIRECTED YOU TO DETERMINE THE REPORTABILITY REQUIREMENTS FOR THIS EVENT PER APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES.

TYPE OF REPORT(S):

RECIPIENT OF REPORT(S):

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE DETERMINED THAT A 4 AND 8 HOUR REPORT IS REQUIRED TO BE MADE TO THE NRC OPERATIONS CENTER.

START TIME:

STOP TIME:

PAGE 1 of 2

JPM NO: SA2 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. OBTAIN A VERIFIED OPERATOR OBTAINED WORKING COPY OF APA- PROCEDURE COPY Comments:

ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES S U 2.* DETERMINE A 4 HOUR OPERATOR DETERMINED REPORT NEEDS TO BE A 4 HOUR REPORT Comments:

MADE TO THE NRC NEEDED TO BE MADE TO OPERATIONS CENTER THE NRC OPERATIONS CENTER Various methods to get this information were available in APA-ZZ-00520. ONE of the following was used:

• Attachment 1 Steps 5.c AND/OR 5.d

• Attachment 2, Step 25

• Attachment 3, Step 93

• Attachment 4, Sheets 2, 9, and 10

• CRITICAL STEP PAGE 2 of 2

JPM NO: SA2 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 3.* DETERMINE AN 8 HOUR OPERATOR DETERMINED REPORT NEEDS TO BE AN 8 HOUR REPORT Comments:

MADE TO THE NRC NEEDED TO BE MADE TO OPERATIONS CENTER THE NRC OPERATIONS CENTER Various methods to get this information were available in APA-ZZ-00520. ONE of the following was used:

• Attachment 1 Steps 6.c .1

• Attachment 2, Step 25

• Attachment 3, Step 93

• Attachment 4, Sheets 2

S U

4. RECORD STOP TIME ON PAGE 1 Comments:

• CRITICAL STEP PAGE 3 of 2

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: THE CALLAWAY PLANT IS OPERATING AT 100% POWER. A MAIN STEAM LINE SAFETY VALVE ABV055 FAILS OPEN. THE EVENT RESULTS IN A REACTOR TRIP AND SAFETY INJECTION. ALL SYSTEMS RESPONDED AS DESIGNED.

RCS PRESSURE IS CURRENTLY AT 1550 PSIG. A STEAM GENERATOR PRESSURE IS 10 PSIG.

Initiating Cues: YOU ARE AN EXTRA SRO ON SHIFT PERFORMING CONTROL ROOM OBSERVATIONS. THE SHIFT MANAGER (SM) HAS DIRECTED YOU TO DETERMINE THE REPORTABILITY REQUIREMENTS FOR THIS EVENT PER APA-ZZ-00520, REPORTING REQUIREMENTS AND RESPONSIBILITIES.

TYPE OF REPORT(S):

RECIPIENT OF REPORT(S):

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: SA3 Rev 1 KSA NO: GEN 2.2.13 COMPLETION TIME: 15 MINUTES KSA RATING: 4.1/4.3 JOB TITLE: SRO REVISION: 2009 DUTY: ADMINISTRATIVE TASK TITLE: REVIEW WPA FOR A REACTOR MAKEUP WATER TRANSFER PUMP The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

APA-ZZ-00310, ODP-ZZ-00310 TOOLS/EQUIPMENT: COMPLETED TAGOUT CONTINUATION SHEET, M-22BL01, E-23BL04 FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: SA3 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: THE REACTOR OPERATOR HAS PREPARED WPA TO REPLACE THE PUMP IMPELLER FOR THE A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) AND HAS GIVEN THE WPA TO YOU FOR REVIEW.

Initiating Cues: REVIEW THE WPA FOR A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) USING PRINTS PROVIDED.

INDICATE BELOW ANY ERRORS YOU FIND, AND MAKE ANY CORRECTIONS ON THE WPA.

Notes: USE OF THE MAINFRAME COMPUTER IS NOT ALLOWED.

TASK STANDARD: UPON COMPLETION OF THE TASK, THE CANDIDATE WILL HAVE DETERMINED:

(1) FOR TAG #3 PG20NDF5 IS AN INCORRECT COMPONENT, PG19NCF5 IS THE CORRECT COMPONENT, (2) FOR TAG #4, BLV0081 IS IN THE INCORRECT ORDER. OPENING THIS VALVE EARLY WOULD DRAIN ENTIRE SYSTEM (3) FOR TAG #6, BLV0026 IS ON THE WRONG RECIRC LINE, CORRECTED TO BLV0018 START TIME:

STOP TIME:

PAGE 1 of 6

ADMIN JPM NO: SA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. PROVIDE CANDIDATE CANDIDATE HAS REVIEW ED WITH THE TAGOUT ADMIN JPM INITIAL Comments:

CONTINUATION SHEET CONDITIONS, INITIATING AND ALLOW HIM TO CUES, AND TAGOUT REVIEW THE WORK TO CONTINUATION SHEET BE PERFORMED STEPS MAY BE PERFORMED IN ANY ORDER S U 2.* DETERMINE HOLD OFF CANDIDATE MAY HAVE IS THE CORRECT TYPE REVIEWED APA-ZZ-00310 TO Comments:

OF WPA ENSURE TAGGING IS FOR PERSONNEL PROTECTION, APA-ZZ-00310, STEP AND THE EQUIPMENT WILL 4.1.1 NOT BE OPERATED CANDIDATE HAS DETERMINED A HOLD OFF IS REQUIRED S U

3. DETERMINE CORRECT CANDIDATE HAS HANDSWITCHES TO BE DETERMINED Comments:

TAGGED FOR THE A HANDSWITCHES, BLHIS3 REACTOR MAKEUP (MCB) AND BLHS3 (LOCAL),

WATER TRANSFER SHOULD BE TAGGED TO PUMP (PBL01A) AND ITS PULL TO LOCK PER PRINT REQUIRED POSITION E-23BL04 PRINT E-23BL04 BLHS3 MAY BE CONSIDERED OPTIONAL SINCE THE CONTROL ROOM HANDSWITCH WAS TAGGED

• CRITICAL STEP PAGE 2 of 6

ADMIN JPM NO: SA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 4.* DETERMINE CORRECT CANDIDATE HAS BREAKER TO BE DETERMINED PG20NDF5 IS Comments:

TAGGED FOR THE A INCORRECT BREAKER FOR REACTOR MAKEUP THE A REACTOR MAKEUP WATER TRANSFER WATER TRANSFER PUMP PUMP (PBL01A) MOTOR MOTOR AND ITS REQUIRED POSITION NOTE: MAY NEED TO ASK A FOLLOW UP QUESTION TO PRINT E-23BL04 ENSURE CANDIDATE SUPPLIES EVALUATOR WITH CORRECT BREAKER S U 5.* DETERMINE CORRECT CANDIDATE HAS BREAKER TO BE DETERMINED THE POWER Comments:

TAGGED FOR THE A SUPPLY FOR PBL01A IS REACTOR MAKEUP PG19NCF5 AND WAS TRANSFER PUMP REQUIRED TO BE TAGGED (PBL01A) MOTOR AND TO THE OFF/OPEN POSITION ITS REQUIRED POSITION PRINT E-23BL04 S U 6.* DETERMINE VALVE CANDIDATE HAS ORDER IS INCORRECT DETERMINED BLV0081 IS Comments:

FOR BLV0081. THIS IS A TAGGED OPEN IN THE DRAIN VALVE TO BE WRONG SEQUENCE.

OPENED / CAP REMOVED PRIOR TO VALVE WAS RE-SEQUENCED THE SUCTION AND TO AFTER THE SUCTION, DISCHARGE BEING DISCHARGE, AND RECIRC ISOLATED. ARE CLOSED PRINT M-22BL01

• CRITICAL STEP PAGE 3 of 6

ADMIN JPM NO: SA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 7.* DETERMINE CORRECT CANDIDATE DETERMINED SUCTION VALVE TO BE BLV0011 IS THE CORRECT Comments:

TAGGED FOR THE A SUCTION VALVE AND WAS REACTOR MAKEUP REQUIRED TO BE TAGGED WATER TRANSFER CLOSED PUMP (PBL01A) AND ITS REQUIRED POSITION PRINT M-22BL01 S U 8.* DETERMINE CORRECT CANDIDATE DETERMINED DISCHARGE VALVE TO BLV0013 IS THE DISCHARGE Comments:

BE TAGGED FOR THE A VALVE AND WAS REQUIRED REACTOR MAKEUP TO BE TAGGED CLOSED WATER TRANSFER PUMP (PBL01A) AND ITS REQUIRED POSITION PRINT M-22BL01 S U 9.* DETERMINE CORRECT CANDIDATE DETERMINED RECIRC VALVE TO BE BLV0026 WAS THE WRONG Comments:

TAGGED FOR THE A RECIRC VALVE FOR THIS REACTOR MAKEUP TRAIN.

WATER TRANSFER PUMP (PBL01A) AND ITS CANDIDATE IDENTIFIED REQUIRED POSITION BLV0018 AS THE CORRECT RECIRC ISOLATION AND MADE CHANGES TO THE TAGOUT CONTINUATION PRINT M-22BL01 SHEET

• CRITICAL STEP PAGE 4 of 6

ADMIN JPM NO: SA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 10.* DETERMINE PUMP CANDIDATE DETERMINED CASING DRAIN VALVE BLV0081 WAS THE CORRECT Comments:

BLV0081 IS CORRECT CASING DRAIN VALVE AND VALVE AND SHOULD BE WAS TAGGED OPEN OR TAGGED OPEN/CAP OPEN/CAP REMOVED REMOVED AFTER THE PREVIOUS THREE VALVES WERE CLOSED PRINT M-22BL01 S U 11.* DETERMINE PUMP CANDIDATE DETERMINED DISCH DRAIN VALVE TO BLV0084 WAS THE PUMP Comments:

BE TAGGED FOR THE A DISCH DRAIN VALVE AND REACTOR MAKEUP WAS REQUIRED TO BE WATER TRANSFER TAGGED OPEN OR PUMP (PBL01A) AND ITS OPEN/CAP REMOVED REQUIRED POSITION PRINT M-22BL01 S U

14. THIS ADMIN JPM IS COMPLETE Comments:

RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 5 of 6

ADMIN JPM NO: SA3 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U KEY COMPARE CANDIDATES TAGOUT CONTINUATION Comments:

SHEET TO THE ATTACHED.

ENSURE THE FOLLOWING:

WPA WAS INCORRECT WITH THREE ERRORS FOUND COULD BE CORRECTED AS FOLLOWS:

TAG #3 WAS CORRECTED TO PG19NCF5 TAG #4 WAS RE-SEQUENCED TO BE PLACED BEFORE TAG #8 TAG #6 WAS CORRECTED TO BLV0018

• CRITICAL STEP PAGE 6 of 6

SA3 Rev 1 TAGOUT CONTINUATION SHEET KEY WPA TYPE: HOLD OFF TAG SEQUENCE NUMBER TAGGED COMPONENT TAGGING POSITION 1 BLHIS3 PULL TO LOCK (WIP) 2 BLHS3 PULL TO LOCK (WIP) 3 PG20NDF5 OPEN

• corrected to PG19NCF5 4* BLV0081 OPEN/ CAP REMOVED Tag #4 should be sequenced before Tag #8 5 BLV0011 CLOSED 6 BLV0026 CLOSED

• corrected to BLV0018 7 BLV0013 CLOSED 8 BLV0084 OPEN/CAP REMOVED

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: THE REACTOR OPERATOR HAS PREPARED WPA TO REPLACE THE PUMP IMPELLER FOR THE A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) AND HAS GIVEN THE WPA TO YOU FOR REVIEW.

Initiating Cues: REVIEW THE WPA FOR A REACTOR MAKEUP WATER TRANSFER PUMP (PBL01A) USING PRINTS PROVIDED.

INDICATE BELOW ANY ERRORS YOU FIND, AND MAKE ANY CORRECTIONS ON THE WPA.

Notes: USE OF THE MAINFRAME COMPUTER IS NOT ALLOWED.

TAGOUT CONTINUATION SHEET WPA TYPE: HOLD OFF TAG SEQUENCE NUMBER TAGGED COMPONENT TAGGING POSITION 1 BLHIS3 PULL TO LOCK (WIP) 2 BLHS3 PULL TO LOCK (WIP) 3 PG20NDF5 OPEN 4 BLV0081 OPEN/CAP REMOVED 5 BLV0011 CLOSED 6 BLV0026 CLOSED 7 BLV0013 CLOSED 8 BLV0084 OPEN/ CAP REMOVED

CALLAWAY PLANT ADMINISTRATIVE JOB PERFORMANCE MEASURE JPM NO: SA4 Rev 2 KSA NO: GEN 2.3.4 JOB TITLE: SRO KSA RATING: 3.2/3.7 DUTY: ADMINISTRATIVE REVISION: 2009 TASK TITLE: SELECT VOLUNTEER FOR EMERGENCY EXPOSURE 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB CLASSROOM X___

METHOD OF PERFORMANCE: SIMULATED PERFORMED X__

REFERENCES:

HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose, Rev 11 TOOLS/EQUIPMENT: Copy of HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: SA4 Rev 2 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions:

A LOCA has occurred. An operator has been seriously injured in the Train A Residual Heat Removal Pump Room.

Extremely high radiation levels require a volunteer to attempt a rescue. The Emergency Coordinator has authorized a volunteer to attempt this rescue. The estimated dose to the rescuer is 55 Rem.

Five individuals have volunteered to attempt a rescue of the injured operator.

The TSC has not been activated at this time.

Initiating Cues:

The Emergency Coordinator directs you to select a volunteer to attempt the rescue in accordance with HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose.

TASK STANDARD: Candidate selected Volunteer B to attempt the rescue of the injured operator in accordance with HDP-ZZ-01450.

START TIME:

STOP TIME:

PAGE 1 of 2

ADMIN JPM NO: SA4 Rev 2 TASK NUMBER - ELEMENT STANDARD SCORE S U

• 1. Candidate obtains copy of HDP- Candidate selected Volunteer B to ZZ-01450, Authorization To attempt the rescue of the injured Exceed Federal Occupational operator in accordance with HDP-ZZ- Comments:

Dose and list of volunteers 01450.

2. THIS ADMIN JPM IS COMPLETE RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 2 of 2

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions:

A LOCA has occurred. An operator has been seriously injured in the Train A Residual Heat Removal Pump Room.

Extremely high radiation levels require a volunteer to attempt a rescue. The Emergency Coordinator has authorized a volunteer to attempt this rescue. The estimated dose to the rescuer is 55 Rem.

Five individuals have volunteered to attempt a rescue of the injured operator.

The TSC has not been activated at this time.

Initiating Cues:

The Emergency Coordinator directs you to select a volunteer to attempt the rescue in accordance with HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose.

List of Volunteers

1. Volunteer A is a 50 year old male with a lifetime dose of 52.5 Rem

2. Volunteer B is a 45 year old male with a lifetime exposure of 22.5 Rem

3. Volunteer C is a 42 year old female that tells you she is pregnant

4. Volunteer D is a 36 year old male who has a prior emergency exposure at another utility

5. Volunteer E is a 35 year old female who is trying to start a family

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: SA5 Rev 1 KSA NO: GEN 2.4.41 COMPLETION TIME: 15 MINUTES KSA RATING: 2.9/4.6 JOB TITLE: SRO REVISION: 2009 DUTY: RADIOLOGICAL EMERGENCY RESPONSE TASK TITLE: CLASSIFY EMERGENCY EVENT PER EIP-ZZ-00101 The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT CLASSROOM X METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

EIP-ZZ-00101, CLASSIFICATION OF EMERGENCIES, ADDENDUM 1 TOOLS/EQUIPMENT: ADDENDUM 1 OF EIP-ZZ-00101, EAL CLASSIFICATION MATRIX FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

ADMIN JPM NO: SA5 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: SEE SHIFT MANAGER DAILY LOG SHEET PROVIDED FOR CURRENT PLANT CONDITIONS Initiating Cues: THE TIME IS NOW 0623 YOU ARE THE SHIFT MANAGER CLASSIFY THE EVENT BASED ON CURRENT CONDITIONS TO INCLUDE ALL CURRENT EMERGENCY ACTION LEVELS.

TASK STANDARD: UPON COMPLETION OF THIS TASK, THE CANDIDATE SHOULD DETERMINE AN ALERT EXISTS DUE TO EAL CA1.1 AND HA1.2.

START TIME:

STOP TIME:

PAGE 1 of 4

ADMIN JPM NO: SA5 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U

1. OBTAIN A COPY OF CANDIDATE OBTAINED A EIP-ZZ-00101, COPY OF EIP-ZZ-00101 Comments:

ADDENDUM 1, EAL ADDENDUM 1 CLASSIFICATION MATRIX PROVIDE CANDIDATE A COPY OF EIP-ZZ-00101 ADD 1 S U 2.* APPLY GROUP CA1 AND CANDIDATE DETERMINED DECLARE AN ALERT on THE FOLLOWING WAS Comments:

EAL CA1.1 APPLICABLE FROM GROUP CA1:

(APPLICABLE IN COLD CONDITIONS RCS < 200 °F) CA1.1.Loss of all offsite and onsite AC power to emergency buses NB01 and NB02 for > 15 min.

• CRITICAL STEP PAGE 2 of 4

ADMIN JPM NO: SA5 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE S U 3.* APPLY GROUP HA1 AND CANDIDATE DETERMINED DECLARE AN ALERT THE FOLLOWING WAS Comments:

BASED ON EAL HA1.2 APPLICABLE FROM GROUP 3H:

(APPLICABLE AT ALL TIMES) HA1 REPORT OF A NATURAL AND DESTRUCTIVE PHENOMENA AFFECTING PLANT VITAL AREA HA1.2 Tornado or high winds

>100 mph within protected Area boundary and resulting in visible damage to any Table H-1 plant structure/equipment or Control Room indication of degraded performance of these systems

4. THE JPM IS COMPLETE RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 3 of 4

ADMIN JPM NO: SA5 Rev 1 TASK NUMBER - ELEMENT STANDARD SCORE KEY CANDIDATE DECLARED AN ALERT WITH APPLICABLE EALS BEING CA1.1 AND HA1.2.

• CRITICAL STEP PAGE 4 of 4

ADMIN JPM NO: SA5 CALLAWAY PLANT DATE 06/18/09 SHIFT MANAGER DAILY LOG LINE TIME NO.

1 0000 Continued logs from log sheet dated 06/17/09. Core has been off-loaded to Spent Fuel Pool.

2 Callaway Plant is in NO MODE.

3 RCS has been drained to mid-loop to support work on letdown piping.

4 0115 Tagged out NB02 and NE02 for Bus cleaning and breaker PMs. Verified NO fuel movement in progress or planned for Spent Fuel Pool.

5 0345 Severe weather and tornado warning issued by National Weather Service entered OTO-ZZ-00012, Severe Weather.

6 0600 Tornado passes thru Callaway Plant causing a loss of switchyard, NB01 and damage to the ESW pump house.

7 0605 NE01 trips due to overheating due to loss of ESW.

8 0610 Maintenance informs the CRS that NB01 can be energized by 0930 via off-site power.

10 0612 Electrical maintenance informs the CRS that NB02 will be able to be energized via NE02 by 0840.

11 0615 HP reports radiation levels normal in Containment and Fuel Building.

12 13 14 15 16 17 18 19 20 21 22

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. You may use any approved reference materials normally available to you, unless directed otherwise. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Administrative Job Performance Measure will be satisfied.

Initial Conditions: SEE SHIFT MANAGER DAILY LOG SHEET PROVIDED FOR CURRENT PLANT CONDITIONS Initiating Cues: THE TIME IS NOW 0623 YOU ARE THE SHIFT MANAGER CLASSIFY THE EVENT BASED ON CURRENT CONDITIONS TO INCLUDE ALL CURRENT EMERGENCY ACTION LEVELS.

EAL CLASSIFICATION: _______________________

APPLICABLE EALS: __________________________

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 Facility: Callaway Date of Examination: 6/19/2009 Exam Level (circle one): RO (only)/SRO(I) / SRO (U) Operating Test No.:

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

Type Code* Safety Function System / JPM Title S1 001 Control Rod Drive System D, S 1 Perform Control Rod Partial Movement Test S2 004 Chemical and Volume Control System D, S 2 Remove Excess Letdown From Service S3 010 Pressurizer Pressure Control System N, S, A 3 Respond to a Master Pressure Controller Failure S4 059 Main Feedwater System M, S, L 4S Transfer S/G Level Control From Mn Feed Reg Byp to Mn Feed Reg Valves S5 026 Containment Spray System N, S, A, L, 5

Manually Actuate Containment Spray System EN S6 062 AC Electrical Distribution D, S, L 6 Energize / De-Energize Load Center NG01 S7 029 Containment Purge System N, S 8 Establish Containment Purge S8 015 Nuclear Instrumentation System D, S 7 Respond to a Failed Power Range Instrument In-Plant Systems@ (3 for RO; 3 for SRO-I; 3 or 2 for SRO-U)

P1 064 Emergency Diesel Generators D 6 NE01 Pre-start Checks P2 078 Instrument Air System D, A, E 8 Respond to Loss of Instrument Air P3 103 Containment System D, A, E, L, R 5 Locally Close Valves for CIS-A NUREG-1021, Revision 9, Supplement 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 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 4-6 ( 4 ) / 4-6 ( 4 ) / 2-3 ( 3 )

(C)ontrol room (D)irect from bank 9(7)/8(6)/4(3 )

(E)mergency or abnormal in-plant 1(2)/1(2)/1(2)

(EN)gineered safety feature - / - / 1(1)

(L)ow-Power / Shutdown 1(4)/1(4)/1(3)

(N)ew or (M)odified from bank including 1(A) 2(4)/2(4)/1(2 )

(P)revious 2 exams (randomly selected) 3(0)/3(0)/2(0)

(R)CA 1(1)/1(1)/1(1)

(S)imulator NUREG-1021, Revision 9, Supplement 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 JPM Summary S1 - Bank JPM URO-SSF01C05J, Perform Control Rod Partial Movement Test. This JPM has the candidate operate the Control Rod Drive System by inserting rods in Shutdown Bank A at least 12 steps and then returning them to the their previous position.

S2 - Bank JPM URO-SBG04C47J, Remove Excess Letdown From Service. This JPM starts with normal and excess letdown in service and requires the candidate to remove the excess letdown system from service and verify RCP Seal Water Leakoff is adequate.

S3 - NEW JPM - 010 Pressurizer Pressure Control System Failed Master Pressure Controller. This Alternate Path JPM starts with the plant at power. A boron equalization evolution is performed that requires the master pressure controller to be taken to manual and then back to auto. When the controller is taken back to auto it fails to a condition that causes the pressurizer spray valves to open. This will require the candidate to take manual control and close the spray valves.

S4 - Modified Bank JPM URO-SAE02C136J, Transfer S/G Level Control From Main Feed Regulating Bypass Valves to Main Feed Regulating Valve. This JPM starts at approximately 22% power. The candidate will be required to transfer to Main Feedwater Control on two of four S/Gs and stabilize level. This is a critical evolution during power ascension.

S5 - NEW JPM - 026 Containment Spray System, Manually Actuate Containment Spray System. This Alternate Path JPM starts with the Reactor tripped and containment pressure elevated due to two faulted SGs. Containment pressure exceeds the Containment Spray Actuation System setpoint, but Containment spray does not actuate.

The candidate will be given Attachment A of E-0, Reactor Trip or Safety Injection and told to complete Containment Spray verification.

S6 - Bank JPM URO-SNG1C82J, Energize / De-Energize Load Center NG01. This JPM starts with the plant in a Mode that allows all loads to be stripped from NG01. The candidate will de-energize NG01 and then re-energize the bus.

S7 - NEW JPM - 029 Containment Purge System, Re-establish Containment Purge After Isolation. This JPM has the candidate restore Containment Purge following an inadvertent Containment Purge Isolation. The candidate will end up re-establishing Containment Mini-purge to the containment.

S8 - Bank JPM URO-SSE03C126J, Respond to a Failed Power Range Instrument. This JPM will start at some at power initial condition. Power Range Channel N42 will fail high. The candidate will operate the Nuclear Instrumentation system at the back panels in order to defeat the affected channel.

P1 - Bank JPM EOS-SNE11048J, NE01 Pre-start Checks. This JPM has the candidate perform all of the local pre-start checks on the A Diesel Generator.

P2 - Bank JPM EOS-SKA11040J, Respond to Loss in Instrument Air. This Alternate Path JPM has the candidate simulate the local actions at the Air Compressors for a Loss of Instrument Air. When the candidate is verifying all of the compressors running, he is NUREG-1021, Revision 9, Supplement 1

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 informed that the B Air Compressor has zero oil pressure and is making excessive noise. This will require the candidate to stop the air compressor and close its discharge valve as an alternate path. The candidate will then inform the control room of this status.

P3 - Bank JPM URO-AEO05062J(A), Locally Close Valves for CIS-A. This Alternate Path JPM has the candidate simulate isolating valves Containment Isolation Valves in accordance with EOP Addendum 25. This JPM will take place inside the RCA. The alternate path comes when trying to isolate individual valves. The candidate will have to either manually isolate the air/motor operated valve or choose a valve upstream that can manually isolate the penetration.

NUREG-1021, Revision 9, Supplement 1

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S7 Rev 1 KSA NO: 029 K1.05 JOB TITLE: RO/SRO KSA RATING: 2.9/3.1 DUTY: PURGE SYSTEM OPERATION REVISION: 2009 TASK TITLE: ESTABLISH CONTAINMENT PURGE 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OTN-GT-00001, CONTAINMENT PURGE SYSTEM, REVISION 26 TOOLS/EQUIPMENT: Ensure MINIVENT Time Trend is on large display screen FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S7 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER. OUTSIDE TEMPERATURE IS 65F A CONTAINMENT ENTRY AT POWER IS REQUIRED.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO ESTABLISH CONTAINMENT MINI-PURGE IAW OTN-GT-00001, CONTAINMENT PURGE SYSTEM.

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR HAS RESTORED CONTAINMENT PURGE TO OPERATION.

Simulator instructions: Establish conditions at power with Mini Purge NOT in service.

START TIME:

STOP TIME:

PAGE 1 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED OPERATOR WORKING COPY OF OBTAINED Comments:

OTN-GT-00001, PROCEDURE COPY Containment Purge Once operator System obtains a copy of the procedure, give him a marked up copy RECORD START TIME ON PAGE 1 S U

2. PLACING MINI- OPERATOR PURGE SYSTEM IN REVIEWED THE Comments:

SERVICE PROCEDURE AND VERIFIED THAT ENSURE SECTION 5.1 SECTION 5.1 HAD HAS BEEN BEEN COMPLETED PERFORMED (MAY SPOT CHECK SECTION 5.1 TO Step 5.2.1 VERIFY)

S U

3. ENSURE SHUTDOWN PURGE OPERATOR SHUTDOWN PURGE IS NOT IN SERVICE VERIFIED THAT Comments:

SYSTEM NOT IN PURGE SUPPLY AND SERVICE EXHAUST FANS WERE SECURED Step 5.2.2 S U

4. NOTE: Minivent time Operator Read NOTE trend may be used Comments

• CRITICAL STEP PAGE 2 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

5. MONITOR THE OPERATOR FOLLOWING MONITORED Comments:

INSTRUMENTATION INSTRUMENTATION.

(MAY USE SDRE0041 (SDR0041H) ASSOCIATED PLANT COMPUTER POINTS)

SDRE0042 (SDR0042H)

GT PDI-40 (GTD0040)

Step 5.2.3 S U

6. RECORD After identifying OPERATOR CONTAINMENT containment pressure RECORDED Comments:

PRESSURE AS - CUE: CONTAINMENT READ ON GT PDI-40 PRESSURE FROM Another Operator has GT-PDI-40 Step 5.2.4 Recorded the pressure on the Gaseous Radwaste Release Permit S U

7. IF IN MODES 1-4 OR Once the operator OPERATOR WENT PREPARING TO locates the panels - TO BACK PANELS Comments:

ENTER MODE 4 CUE: SA036D & SA036E FROM MODE 5, ENSURE THE GTRT22 and GTRT33 VERIFIED THAT FOLLOWING ARE IN are in OPERATE with GTRT022 & 0033 OPERATE WITH the DO NOT WERE NOT CONTAINMENT BYPASS covers in BYPASSED AND DO PURGE IN place NOT BYPASS PROGRESS DO COVERS WERE IN NOT BYPASS PLACE COVERS IN PLACE GTRT0022 GTRT0033 Step 5.2.5

• CRITICAL STEP PAGE 3 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 8. USING GT HIS-20, OPERATOR START CGT02 STARTED CGT02 Comments:

Step 5.2.7 S U

• 9. USING GT HIS-11, OPERATOR OPENED OPEN GTHZ0011 GTHZ0011 Comments:

Step 5.2.8 S U

• 10. USING GT HIS-12, OPERATOR OPENED OPEN GTHZ0012 GTHZ0012 Comments:

Step 5.2.9 S U

• 11. USING GT HIS-28, OPERATOR OPENED OPEN GTHZ0028 GTHZ0028 Comments:

Step 5.2.10 S U

• 12. USING GT HIS-29, OPERATOR OPENED OPEN GTHZ0029 GTHZ0029 Comments:

Step 5.2.11

• CRITICAL STEP PAGE 4 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

13. RECORD DATE AND When the Operator OPERATOR TIME DAMPERS goes looking for the ENSURED GASEOUS Comments:

WERE OPENED ON Permit - CUE: RADWASTE THE GASEOUS RELEASE PERMIT IS RADWASTE Another Operator has ADDRESSED RELEASE PERMIT Recorded the time dampers were opened Step 5.2.12 on the Gaseous Radwaste Release Permit S U

14. NOTIFY RAD/CHEM OPERATOR TECHNICIAN NOTIFIED Comments:

(COUNT ROOM) OF RAD/CHEM TECH TIME OF PURGE INITIATION Step 5.2.13 S U

• 15. WHEN OPERATOR OPENED CONTAINMENT GTHZ0041 & Comments:

PRESSURE IS < GTHZ0042 10.0 IN. H2O, OPEN THE FOLLOWING USING GT HIS-41:

GTHZ0041 & GTHZ0042 Step 5.2.14

• CRITICAL STEP PAGE 5 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 16. WHEN OPERATOR OPENED CONTAINMENT GTHZ0026 & Comments:

PRESSURE IS < GTHZ0027 4.25 IN. H2O, OPEN THE FOLLOWING USING GT HIS-26 &

27:

GTHZ0026 & GTHZ0027 Step 5.2.15

17. CAUTION: SGT02, OPERATOR READ CTMT MINI PURGE CAUTION 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.

S U

• 18. USING GT HIS-23, OPERATOR START SGT02 STARTED SGT02 Comments:

USING GT HIS-23 Step 5.2.16

• CRITICAL STEP PAGE 6 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 19. USING GT HIS-5, OPERATOR OPENED OPEN GTHZ0005 GTHZ0005 USING GT Comments:

HIS-5 Step 5.2.17 S U

• 20. USING GT HIS-4, OPERATOR OPENED OPEN GTHZ0004 GTHZ0004 USING GT Comments:

HIS-4 Step 5.2.18 S U

21. MAINTAIN OPERATOR CONTAINMENT MONITORED Comments:

PRESSURE +41.5 CONTAINMENT TO -8.35 IN. H2O AS PRESSURE READ ON GT PDI-40, CTMT D/P, OR PLANT COMPUTER POINT GTD0040, CTMT-AUX BLD DIFF PRESS.

Step 5.2.19

• CRITICAL STEP PAGE 7 of 8

JPM NO: S7 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

22. JPM COMPLETE RECORD STOP TIME ON PAGE 1 Comments:

• CRITICAL STEP PAGE 8 of 8

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER. OUTSIDE TEMPERATURE IS 65F A CONTAINMENT ENTRY AT POWER IS REQUIRED.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO ESTABLISH CONTAINMENT MINI-PURGE IAW OTN-GT-00001, CONTAINMENT PURGE SYSTEM.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM No: S6 Rev 1 KSA No: 062A4.01 Job

Title:

RO / SRO KSA Rating: 3.3 / 3.1 Duty: Safety Related Elec. Gen. & Dist. (NG) Revision: 2009 Task

Title:

Operate the System - De-Energize / Energize Load Center NG01 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 X Plant Classroom Method of Performance: Simulated Performed X

References:

OTN-NG-00001, Class 1E 480 VAC Electrical System, R012 Tools / Equipment: None FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S6 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at 100% power. Electrical Maintenance is scheduled to clean load center NG01. Swing Charger NK25 is in service supplying NK01.

Initiating Cues: The Control Room Supervisor directs you to de-energize load center NG01 per OTN-NG-00001, Class 1E 480 VAC Electrical System.

You will be directed to energize NG01 when the cleaning activity is complete and the WPA is cleared.

Notes: Use IC-181 Ensure SFP Cooling Pump B is running Task Standard: Upon completion of this JPM, the operator will have de-energized and re-energized NG01 in accordance with OTN-NG-00001, Class 1E 480 VAC Electrical System.

Start Time: __________

Stop Time: __________

PAGE 1 of 5

JPM NO: S6 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. Obtain a verified Provide operator with Operator obtained working copy of procedure copy procedure copy Comments:

OTN-NG-00001 S U

2. Review the All Operator reviewed the Purpose, Precautions, Purpose, Comments:

Scope, Limitations, and Scope, Precautions, Prerequisites are Precautions, Limitations, and satisfied Limitations, and Prerequisites Prerequisites Sections 1.0 - 4.0 S U

3. CAUTION: Technical All Tech Specs have Operator read caution Specifications must been addressed. Comments:

be reviewed before de-energizing a 480V load center to prevent de-energizing equipment required by Limiting Conditions for Operation Section 5.5

• CRITICAL STEP PAGE 2 of 5

JPM NO: S6 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

4. Refer to Technical Operator ensured Steps 3.1 and 3.2 Specifications will Technical Comments:

AND ENSURE allow de-energizing Specifications allowed Technical NG01 de-energizing NG01 Specifications will allow de-energizing the selected load center Step 5.5.1 S U

5. ENSURE all loads All loads supplied by Operator ensured all supplied by the load NG01 are shut down loads supplied by Comments:

center to be de- NG01 were shut down energized are shut down Step 5.5.2 S U

• 6. If de-energizing NG HIS-9 indicates Operator opened NG01, OPEN the OPEN NG0101 Comments:

following breakers:

Using NG HIS-9, 480 V XNG01 TO LC NG01 BKR NG0101, OPEN NG0101 Step 5.5.3.a

• CRITICAL STEP PAGE 3 of 5

JPM NO: S6 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 7. Using NG HIS-1, NG HIS-1 indicates Operator opened 4.16 KV BUS NB01 TO OPEN NB0113 Comments:

XNG01 BKR NB0113, OPEN NB0113 __________________

NG01 cleaning is complete and the WPA is clear.

The CRS directs you to energize NG01 per Step 5.5.3.b OTN-NG-00001 S U

8. ENSURE NG0116, NG0116 is RACKED Operator contacted TIE BKR FOR NG01 IN and OPEN Operations Tech to Comments:

AND NG03, is ensure NG0116 was RACKED IN and RACKED IN and OPEN OPEN Step 5.1.1 S U

9. Using NG HIS-10, NG HIS-10 indicates Operator checked 480 V LC NG01/NG03 OPEN NG0116 was OPEN Comments:

TIE BKR NG0116, CHECK NG0116 is OPEN Step 5.1.2

• CRITICAL STEP PAGE 4 of 5

JPM NO: S6 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 10. Using NG HIS-1, 4.16 NG HIS-1 indicates Operator CLOSED KV BUS NB01 TO CLOSED NB0113 Comments:

XNG01 BKR NB0113, CLOSE NB0113 Step 5.1.3 S U

• 11. Using NG HIS-9, NG HIS-9 indicates Operator CLOSED 480 V XNG01 TO LC CLOSED NG0101 Comments:

NG01 BKR NG0101, CLOSE NG0101 Step 5.1.4 S U

12. At NG01, A TRAIN NG0106, Operator directed 480 VAC LC, NG0107, and Operations Technician Comments:

ENSURE the NG0108 are CLOSED to locally ensure following breakers are CLOSED: NG0106, The JPM is Complete NG0107, and NG0106 NG0108 were NG0107 __________________ CLOSED NG0108 Record Stop Time on Page 1 Step 5.1.5

• CRITICAL STEP PAGE 5 of 5

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is at 100% power. Electrical Maintenance is scheduled to clean load center NG01. Swing Charger NK25 is in service supplying NK01.

Initiating Cues: The Control Room Supervisor directs you to de-energize load center NG01 per OTN-NG-00001, Class 1E 480 VAC Electrical System.

You will be directed to energize NG01 when the cleaning activity is complete and the WPA is cleared.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S5 Rev 1 KSA NO: 026 A1.01 JOB TITLE: RO / SRO KSA RATING: 3.9/4.2 DUTY: Emergency Procedures REVISION: 2009 TASK TITLE: Manually Actuate Containment Spray 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

E-0, Reactor Trip or Safety Injection, REVISION 12 TOOLS/EQUIPMENT: Marked up Attachment A through Step A7 FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S5 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT WAS IN MODE 1 AT 100% POWER.

The unit experienced a Large Break LOCA.

Containment pressure is ~30 psig.

E-0, Attachment A is in progress.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO COMPLETE CONTAINMENT SPRAY VERIFICATION IN ACCORDANCE WITH E-0, ATTACHMENT A., STEP A8. INFORM THE CRS WHEN STEP A8 IS COMPLETE.

Task Standard: CONTAINMENT SPRAY IS ACTUATED IAW E-0, ATTACHMENT A.

Simulator: Reset to IC 180, No Cont. Spray Pumps running, verify containment pressure

>27 psig. Ensure Annunciators 59A and 59B are NOT LIT.

START TIME:

STOP TIME:

PAGE 1 of 5

JPM NO: S5 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED OPERATOR WORKING COPY OF OBTAINED Comments:

E-0, REACTOR TRIP PROCEDURE COPY OR SAFETY Once E-0 located INJECTION give operator a marked up copy of Attachment A RECORD START TIME ON PAGE 1 S U

• 2. Check if containment OPERATOR spray should be IDENTIFIED THAT Comments:

actuated: CONTAINMENT PRESSURE IS Check the Following: GREATER THAN 27 PSIG Check Containment Pressure greater than 27 psig OR GN PR-934 indicates containment pressure has been greater than 27 psig OR Annunciator 59A CSAS -

LIT OR Annunciator 59B CISB -

LIT Step A8 a

• CRITICAL STEP PAGE 2 of 5

JPM NO: S5 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 3. CONTAINMENT OPERATOR SPRAY PUMPS IDENTIFIED THAT Comments:

BOTH RUNNING NEITHER CONTAINMENT Step A8 b SPRAY PUMP IS RUNNING, WENT TO RNO S U

• 4. PERFORM THE OPERATOR FOLLOWING AS MANUALLY Comments:

NECESSARY: ACTUATED CONTAINMENT

1) MANUALLY ACTUATE SPRAY BY CSAS; OPERATING HANDSWITCHES SB HS-43 AND SB HS-45 SB HS-43 & SB HS-45 SB HS-44 AND SB HS-46 AND Step A8 b RNO 1)

SB HS-44 & SB HS-46 S U

• 5. ENSURE BOTH OPERATOR CONTAINMENT STARTED BOTH Comments:

SPRAY PUMPS ARE CONTAINMENT RUNNING SPRAY PUMPS MONITORED Step A8 b RNO 2) DISCHARGE PRESSURE AND FLOW

• CRITICAL STEP PAGE 3 of 5

JPM NO: S5 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

6. ESFAS STATUS OPERATOR PANELS CSAS IDENTIFIED THAT Comments:

SECTIONS: ALL WHITE LIGHTS ARE LIT ON SA066X SA066X WHITE LIGHTS AND Y

- ALL LIT SA066Y WHITE LIGHTS

- ALL LIT Step A8 c S U

7. ESFAS STATUS OPERATOR PANELS CISB IDENTIFIED THAT Comments:

SECTIONS: ALL WHITE LIGHTS LIT SA066X WHITE LIGHTS

- ALL LIT SA066Y WHITE LIGHTS

- ALL LIT Step A8 d S U

• 8. STOP ALL RCPs OPERATOR STOPPED ALL RCPS Comments:

Step A8 e

• CRITICAL STEP PAGE 4 of 5

JPM NO: S5 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

9. JPM COMPLETE RECORD STOP TIME ON PAGE 1 Comments:

• CRITICAL STEP PAGE 5 of 5

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT WAS IN MODE 1 AT 100% POWER.

The unit experienced a Large Break LOCA.

Containment pressure is ~30 psig.

E-0, Attachment A is in progress.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO COMPLETE CONTAINMENT SPRAY VERIFICATION IN ACCORDANCE WITH E-0, ATTACHMENT A., STEP A8. INFORM THE CRS WHEN STEP A8 IS COMPLETE.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S4 Rev 1 KSA NO: 059K1.04 JOB TITLE: RO / SRO KSA RATING: 3.4 / 3.4 DUTY: MAIN FEEDWATER REVISION: 2009 TASK TITLE: TRANSFER SG LVL CTRL FROM MFRV BYPASS VALVES TO MFRVs COMPLETION TIME: 25 MINUTES The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OTN-AE-00001, FEEDWATER SYSTEM, R048 TOOLS/EQUIPMENT: Marked-up procedure, Ensure B MFP controller is Nulled out. Shift A and B to Auto and resnap FACILITY REPRESENTATIVE: DATE:

CHIEF EXAMINER: DATE:

JPM NO: S4 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: The Callaway Plant is in Mode 1 at 22% Reactor Power. The Control Room Crew is performing a power ascension.

Initiating Cues: The Control Room Supervisor directs you to transfer Steam Generator Water Level Control from the MFRV Bypass Valves to the Main Feedwater Regulating Valves using OTN-AE-00001, Feedwater System, starting at Step 5.9.16.

The MFRVs have been unisolated and stroked in accordance with the procedure.

A and B valves have been completed by the previous shift.

Notes: IC - 6 MFRVs Unisolated Task Standard: Upon completion of this JPM, the operator will have transferred Steam Generator Water Level Control from the MFRV Bypass Valves to the MFRVs in accordance with OTN-AE-00001, Feedwater System, without causing a Feedwater Isolation Signal due to high or low Steam Generator water level.

START TIME:

STOP TIME:

PAGE 1 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. Obtain a Verified Provide operator with Operator obtained Working Copy of procedure copy procedure copy Comments:

OTN-AE-00001, Feedwater System S U

2. Review Precautions All Precautions and Operator reviewed and Limitations Limitations are Precautions and Comments:

satisfied Limitations Section 3.0 S U

3. Review Prerequisites There are no Prerequisites Comments:

Section 4.0

• CRITICAL STEP PAGE 2 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

4. NOTE: MFRVs Transfer the MFRVs Operator read note should be transferred separately Comments:

separately (Step 5.9.16) with reactor power stable at approximately 25%. However, if permitted by SM/CRS, the MFRVs may be transferred together in AUTO (Step 5.9.17).

MFRV Bypass choked flow occurs at approximately 600 psid.

Steps 5.9.16.a through 5.9.16.d may be performed in any order, but should be performed concurrently with permission of the SM/CRS.

Note prior to Step 5.9.16

• CRITICAL STEP PAGE 3 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 5*. IF MFRVs will be transferred Comments:

separately, PERFORM the following for SG C:

Ensure AE LK-570, Operator PLACED AE SG C MFW REG LK-570 in MAN BYPASS CTRL, in MANUAL While maintaining SG OPENED AE FK-530 level stable, OPEN and CLOSED AE LK-AE FK-530, SG C 570 in a controlled MFW REG VLV manner CTRL, and CLOSE AE LK-570, SG MFW REG BYPASS CTRL WHEN AE LK-570, PLACED AE FK-530 in SG C MFW REG AUTO and CHECKED BYPASS CTRL, is SG level and feed flow CLOSED, PLACE AE STABLE FK-530, SG C MFW REG VLV CTRL, in AUTO and CHECK SG level and feed flow STABLE Step 5.9.16.c

• CRITICAL STEP PAGE 4 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 6*. IF MFRVs will be transferred Comments:

separately, PERFORM the following for SG D:

Ensure AE LK-580, Operator PLACED AE SG A MFW REG LK-580 in MAN BYPASS CTRL, in MANUAL While maintaining SG OPENED AE FK-540 level stable, OPEN and CLOSED AE LK-AE FK-540, SG D 580 in a controlled MFW REG VLV manner CTRL, and CLOSE AE LK-580, SG MFW REG BYPASS CTRL WHEN AE LK-580, PLACED AE FK-540 in SG A MFW REG AUTO and CHECKED BYPASS CTRL, is SG level and feed flow CLOSED, PLACE AE STABLE FK-540, SG D MFW REG VLV CTRL, in AUTO and CHECK SG level and feed flow STABLE Step 5.9.16.d

• CRITICAL STEP PAGE 5 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

7. NOTE: Programmed Operator read note DP is 45 to 149 psid Comments:

for 0 to 100% power or 1.04 psid/%. 25%

power equates to approximately 70 psid S U

8. DECREASE DP on FW/STEAM HDR DP Operator FC SK-509A, MFP is 70 psid DECREASED DP on Comments:

TURBS MASTER FC SK-509A, MFP SPEED CTRL, to TURBS MASTER 70 psid as read on SPEED CTRL, to AE PDI-508, 70 psid as read on FW/STEAM HDR DP AE PDI-508 (2.8 on SET PT)

Step 5.9.16.e S U

9. CHECK MFRVs MFRVs are operating Operator CHECKED operate to maintain to maintain SG levels MFRVs operating to Comments:

SG levels maintain SG levels Step 5.9.16.f

• CRITICAL STEP PAGE 6 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

10. IF MFRVs will be This step is not Operator proceeded to transferred together applicable step 5.9.18 Comments:

in AUTO, PERFORM the following:

Step 5.9.17

• CRITICAL STEP PAGE 7 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

11. PLACE High Power Speed Control Circuit Comments:

in service as follows:

If MFP A is running:

MFP B is running Operator realized that PLACE FC SK-509B, MFP B is running and MFP TURB A SPEED goes to step 5.9.18.b.

CTRL, in MAN TURN FC PS-509, MFP DP CTRL SEL, to HI PWR PROG DP PLACE FC SK 509A, MFP TURBS MASTER SPEED CTRL, in MAN ADJUST FC SK-509A, MFP TURBS MASTER SPEED CTRL, to match output of FC SK-509B, MFP TURB A SPEED CTRL PLACE FC SK-509B, MFP TURB A SPEED CTRL, in AUTO Step 5.9.18.a

• CRITICAL STEP PAGE 8 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 12. PLACE High Power Speed Control Circuit Comments:

in service as follows:

If MFP B is running:

PLACE FC SK-509C, FC SK-509C is in MAN Operator PLACED MFP TURB B SPEED FC SK-509C in MAN CTRL, in MAN TURN FC PS-509, MFP DP CTRL SEL, FC PS-509 is in TURNED FC PS-509 to HI PWR PROG P HI PWR PROG P to HI PWR PROG P PLACE FC SK-509A, MFP TURBS FC SK-509A is in MAN PLACED FC SK-509A MASTER SPEED in MAN CTRL, in MAN ADJUST FC SK-509A, MFP FC SK-509A matches ADJUSTED TURBS MASTER output of FC SK-509C FC SK-509A to match SPEED CTRL, to output of match output of FC SK-509C FC SK-509C, MFP TURB C SPEED CTRL PLACE FC SK-509C, MFP TURB B SPEED FC SK-509C is in and PLACED CTRL, in AUTO AUTO FC SK-509C in AUTO Step 5.9.18.b

• CRITICAL STEP PAGE 9 of 10

JPM NO: S4 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

13. ENSURE AE PDI-508, Operator ENSURED AE PDI-508, FW/STEAM HDR P, AE PDI-508, Comments:

FW/STEAM HDR P, is set for existing FW/STEAM HDR P, is set for existing power level is set for existing power level power level Approximately 70 psid Step 5.9.18.c S U

• 14. PLACE FC SK-509A, FC SK-509A, MFP Operator PLACED MFP TURBS TURBS MASTER FC SK-509A, MFP Comments:

MASTER SPEED SPEED CTRL, is in TURBS MASTER CTRL, in AUTO AUTO SPEED CTRL, in AUTO Step 5.9.18.d S U

15. ENSURE AE PDI-508 is Operator ENSURED AE PDI-508, automatically AE PDI-508 is Comments:

FW/STEAM HDR P, maintaining Feed automatically is automatically Hdr/Steam Hdr P for maintaining Feed maintaining Feed existing plant Hdr/Steam Hdr P for Hdr/Steam Hdr P for conditions existing plant existing plant conditions conditions ________________

The JPM is Complete Step 5.9.19 Record Stop Time on Page 1

• CRITICAL STEP PAGE 10 of 10

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: The Callaway Plant is in Mode 1 at 22% Reactor Power. The Control Room Crew is performing a power ascension.

Initiating Cues: The Control Room Supervisor directs you to transfer Steam Generator Water Level Control from the MFRV Bypass Valves to the Main Feedwater Regulating Valves using OTN-AE-00001, Feedwater System, starting at Step 5.9.16.

The MFRVs have been unisolated and stroked in accordance with the procedure.

A and B valves have been completed by the previous shift.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S3 Rev. 1 KSA NO: 010 A3.02 REVISION: 2009 KSA RATING: 3.6/3.5 JOB TITLE: RO / SRO DUTY: PZR Pressure Control TASK TITLE: Respond to a Master Pressure Controller Failure COMPLETION TIME: 8 MINUTES The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OTG-ZZ-00004, Addendum 03, Planned Power Changes From Full Power REVISION 002 ODP-ZZ-00025, EOP/OTO USERS GUIDE TOOLS/EQUIPMENT:

FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S3 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER.

A PLANT SHUTDOWN HAS BEEN COMMENCED DUE TO A FAILED POWER SUPPLY IN CABINET SA036D.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO EQUALIZE RCS AND PRESSURIZER BORON CONCENTRATION USING OTG-ZZ-00004, ADDENDUM 03, STEPS 5.4.1.h through j.

Task Standard: Failed master pressure controller failure is addressed.

Simulator: Insert the following to fail the master pressure controller:

Insert malfunction BBPK0455A: Value = 1 Ramp = 1 minute Conditional = x02i58A eq true This will fail both spray valves open when BB PK-455A is returned to auto.

START TIME:

STOP TIME:

PAGE 1 of 3

JPM NO: S3 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED OPERATOR WORKING COPY OF OBTAINS Comments:

OTG-ZZ-00004, PROCEDURE COPY ADDENDUM 03, PLANNED POWER CHANGES FROM FULL POWER RECORD START TIME ON PAGE 1 S U

• 2. ENSURE AT LEAST OPERATOR PLACES ONE GROUP OF BB HIS-51A AND/OR Comments:

PRESSURIZER BB HIS-52A IN BACKUP HEATERS CLOSE ARE ENERGIZED (ONLY ONE SWITCH REQUIRED TO BE PLACED IN CLOSE)

Step 5.4.1.h S U

• 3. PLACE BB PK-455A OPERATOR PLACES IN MANUAL AND BB PK-455A IN Comments:

LOWER TO 40% MANUAL AND LOWERS TO 40%

Step 5.4.1.i

• CRITICAL STEP PAGE 2 of 3

JPM NO: S3 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 4. PLACE BB PK-455A OPERATOR PLACES IN AUTO BB PK-455A IN AUTO Comments:

Step 5.4.1.j S U

• 5. BOTH OPERATOR PRESSURIZER RECOGNIZES Comments:

SPRAY VALVES, SPRAY VALVES BBPCV0455B AND HAVE FAILED OPEN BBPCV0455C, FAIL AND CLOSES BOTH OPEN WHEN BB PK- SPRAY VALVES 455A IS PLACED PRIOR TO A INTO AUTO REACTOR TRIP BEING GENERATED ON LOW PRESSURIZER PRESSURE S U

6. JPM COMPLETE RECORD STOP TIME ON PAGE 1 Comments:

• CRITICAL STEP PAGE 3 of 3

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER.

A PLANT SHUTDOWN HAS BEEN COMMENCED DUE TO A FAILED POWER SUPPLY IN CABINET SA036D.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO EQUALIZE RCS AND PRESSURIZER BORON CONCENTRATION USING OTG-ZZ-00004, ADDENDUM 03, ADDENDUM 03, STEPS 5.4.1.h through j.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S2 Rev 1 KSA NO: 004A4.06 JOB TITLE: RO / SRO KSA RATING: 3.6/3.1 DUTY: CVCS REVISION: 2009 TASK TITLE: REMOVE EXCESS LETDOWN FROM SERVICE COMPLETION TIME: 8 MINUTES The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OTN-BG-00001, Add. 4, OPERATION OF CVCS LETDOWN, Rev. 7 TOOLS/EQUIPMENT: NONE FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S2 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1. NORMAL RCS LETDOWN WAS OUT OF SERVICE FOR MAINTENANCE AND HAS BEEN RESTORED PER OTN-BG-00001, CHEMICAL AND VOLUME CONTROL SYSTEM.

EXCESS LETDOWN IS STILL IN SERVICE.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO REMOVE EXCESS LETDOWN FROM SERVICE USING OTN-BG-00001, ADDENDUM 4, SECTION

5.5. Notes

INITIALIZE IC-117. This IC has Excess Letdown in service.

IF IC -117 will not load, use any at power IC and open B train Excess Letdown valves using BG-8153B and BG HIS 8154B.

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE SECURED CVCS EXCESS LETDOWN.

START TIME:

STOP TIME:

PAGE 1 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED PROVIDE OPERATOR WORKING COPY OF OPERATOR WITH OBTAINED Comments:

OTN-BG-00001, PROCEDURE COPY PROCEDURE COPY CHEMICAL AND VOLUME CONTROL SYSTEM S U

2. REVIEW ALL PRECAUTIONS, OPERATOR PRECAUTIONS AND LIMITATIONS AND REVIEWED Comments:

LIMITATIONS AND PREREQUISITES PRECAUTIONS, PREREQUISITES ARE SATISFIED LIMITATIONS AND PREREQUISITES SECTION 3 AND 4 S U

3. NOTE: ALL OPERATOR READ HANDSWITCHES NOTE Comments:

ARE LOCATED ON PANEL RL001 OR RL002 UNLESS OTHERWISE INDICATED.

• CRITICAL STEP PAGE 2 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

4. ENSURE THAT NORMAL LETDOWN OPERATOR MAY NORMAL LETDOWN IS IN SERVICE PER VERIFY NORMAL Comments:

HAS BEEN PLACED SECTION 5.4 LETDOWN IS IN INTO SERVICE PER SERVICE SECTION 5.4 NOTE: GIVEN IN ADDENDUM STEP INITIAL CONDITIONS 5.5.1 S U

• 5. USING BG HC-123, BG HC-123, EXCESS OPERATOR TURNED CLOSE BGHCV0123, LETDOWN HX EXCESS LETDOWN Comments:

EX LETDN HX OUT OUTLET FLOW HX OUTLET FLOW FLOW HV CONTROL SWITCH, CONTROL SWITCH, IS IN THE CLOSE BG HC-123, TO THE STEP 5.5.2 POSITION CLOSE POSITION S U

6. ENSURE BG HIS- THE RED LIGHT IS OPERATOR 8143, EXCESS LTDN ILLUMINATED ON ENSURED THAT THE Comments:

HX TO RCDT/SEAL BG HIS-8143, EXCESS LTDN HX WTR HX, IS IN THE EXCESS LTDN HX TO THE RCDT/SEAL VCT POSITION TO RCDT/SEAL WTR WTR HX, BG HIS-HX, CONTROL 8143, WAS IN VCT STEP 5.5.3 SWITCH POSITION

• CRITICAL STEP PAGE 3 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 7. CLOSE REACTOR COOLANT OPERATOR CLOSED BG HIS-8153B, TO EXCESS THE REACTOR Comments:

REACTOR LETDOWN HX, BG COOLANT TO COOLANT TO HIS-8153B, GREEN EXCESS LETDOWN EXCESS LETDOWN LIGHT ILLUMINATES HX, BG HIS-8153B HX VALVE AND RED LIGHT EXTINGUISHES STEP 5.5.4.b.1 NOTE: JPM STEPS 7 AND 8 MAY BE PERFORMED IN ANY ORDER S U

• 8. CLOSE BG HIS- REACTOR COOLANT OPERATOR CLOSED 8154B REACTOR TO EXCESS THE REACTOR Comments:

COOLANT TO LETDOWN HX, BG COOLANT TO EXCESS LETDOWN HIS-8154B, GREEN EXCESS LETDOWN HX VALVE LIGHT ILLUMINATES HX, BG HIS-8154B AND RED LIGHT STEP 5.5.4.b.2 EXTINGUISHES

• CRITICAL STEP PAGE 4 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

9. IF RCS PRESSURE RCP A through D OPERATOR IS BETWEEN 2220 SEAL WATER VERIFIED THAT RCP Comments:

PSIG AND 2250 LEAKOFF, BG FR- A SEAL WATER PSIG, ENSURE RCP 157, 156, 155, 154, LEAKOFF FLOW SEAL WATER INDICATES 3 GPM WAS 1-5 GPM ON BG LEAKOFF FLOW IS FR-157 1-5 GPM AS INDICATED ON BG FR-154 THROUGH BG FR-157 ON PANEL RL022 STEP 5.5.5 S U

10. IF RCS PRESSURE RCS PRESSURE IS RCS PRESSURE IS IS OUTSIDE THE WITHIN 2220 TO 2250 WITHIN NORMAL Comments:

RANGE OF 2220 PSIG RANGE, NO PSIG TO 2250 PSIG, OPERATOR ACTION ENSURE RCP SEAL WAS NECESSARY WATER LEAK-OFF IS ACCEPTABLE PER THE RCP SEAL LEAK-OFF CURVE IN OTN-BB-00003, REACTOR COOLANT PUMPS STEP 5.5.6

• CRITICAL STEP PAGE 5 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

11. INFORM RP AND RP AND CHEMISTRY OPERATOR CHEMISTRY THAT ACKNOWLEDGE INFORMED RP AND Comments:

EXCESS LETDOWN THAT EXCESS CHEMISTRY THAT HAS BEEN LETDOWN HAS EXCESS LETDOWN REMOVED FROM BEEN REMOVED HAD BEEN SERVICE FROM SERVICE REMOVED FROM SERVICE STEP 5.5.7 S U

12. NOTIFY CRS THAT CRS OPERATOR EXCESS LETDOWN ACKNOWLEDGES INFORMED CRS Comments:

HAS BEEN THAT EXCESS THAT EXCESS REMOVED FROM LETDOWN HAS LETDOWN HAD SERVICE BEEN REMOVED BEEN REMOVED FROM SERVICE FROM SERVICE S U

13. DIRECT THE OT TO OT IS DIRECTED TO OPERATOR PERFORM STEP PERFORM STEP DIRECTS OT TO Comments:

5.5.8 5.5.8 PERFORM STEP BG 8484 IS LOCKED OPEN BG 8482 IS LOCKED CLOSED VALVES ARE DOCUMENTED IN ODP-ZZ-00004

• CRITICAL STEP PAGE 6 of 7

JPM NO: S2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 7 of 7

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1. NORMAL RCS LETDOWN WAS OUT OF SERVICE FOR MAINTENANCE AND HAS BEEN RESTORED PER OTN-BG-00001, CHEMICAL AND VOLUME CONTROL SYSTEM.

EXCESS LETDOWN IS STILL IN SERVICE.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO REMOVE EXCESS LETDOWN FROM SERVICE USING OTN-BG-00001, ADDENDUM 4, SECTION 5.5.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S1 Rev 1 KSA NO: 001A4.03 REVISION: 2009 KSA RATING: 4.0 / 3.7 JOB TITLE: RO/SRO DUTY: CONTROL ROD DRIVE SYSTEM TASK TITLE: PERFORM CONTROL ROD PARTIAL MOVEMENT TEST COMPLETION TIME: 12 MINUTES The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OSP-SF-00002, CONTROL ROD PARTIAL MOVEMENT, R019 TOOLS/EQUIPMENT:

FACILITY REPRESENTATIVE: DATE:

CHIEF EXAMINER DATE:

JPM NO: S1 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1, 100% STEADY STATE POWER. THERE ARE NO SPECIAL PHYSICS TESTS IN PROGRESS, NO BORON CONCENTRATION CHANGES BEING MADE OR PLANNED, AND CONTROL RODS ARE IN A NORMAL CONFIGURATION.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO PERFORM CONTROL ROD PARTIAL MOVEMENT FOR ALL SHUTDOWN BANKS, PER OSP-SF-00002, SECTION 6.1.

START WITH SHUTDOWN BANK A AND PROCEED IN ALPHABETICAL ORDER.

Notes: USE ANY MODE 1 IC.

Task Standard: UPON COMPLETION OF THIS JPM, ALL SHUTDOWN BANK 'A' CONTROL RODS WILL HAVE BEEN INSERTED AT LEAST 10 STEPS INTO THE CORE AND RESTORED TO THEIR PRETEST POSITION.

START TIME:

STOP TIME:

PAGE 1 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED PROVIDE OPERATOR WORKING COPY OPERATOR WITH OBTAINED Comments:

OF OSP-SF-00002, PROCEDURE COPY PROCEDURE COPY CONTROL ROD PARTIAL MOVEMENT S U

2. REVIEW THE ALL PRECAUTIONS OPERATOR PRECAUTIONS AND AND LIMITATIONS REVIEWED THE Comments:

LIMITATIONS OF ARE SATISFIED PRECAUTIONS AND OSP-SF-00002 LIMITATIONS NOTE: IF ASKED, THE MONTHLY ROD POSITION TEST HAS NOT BEEN PERFORMED YET STEP 4.0 S U

3. REVIEW ALL PREREQUISITES OPERATOR PREREQUISITES ARE SATISFIED REVIEWED THE Comments:

OF OSP-SF-00002 PREREQUISITES STEP 5.0 PAGE 2 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

4. NOTE: OPERATOR READ NOTE Comments:

PLACEKEEPING FOR SECTION 6.1 THROUGH 6.4 IS PERFORMED ON APPLICABLE ATTACHMENTS A CABINET WITHOUT ANY GROUP SELECT LIGHT ILLUMINATED MAY INDICATE A BAD LIGHT BULB OR A BLOWN MULTIPLEXER FUSE. MOVING RODS WITHOUT THE CORRECT GROUP SELECT LIGHT ILLUMINATED COULD RESULT IN DROPPED OR MISPOSITIONED RODS.

PRIOR TO STEP 6.1 PAGE 3 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 5. PLACE SE HS-9, SE-HS-9 IS IN THE OPERATOR PLACED ROD BANK SBA POSITION SE HS-9 IN THE SBA Comments:

AUTO/MAN SEL, IN POSITION AND THE SHUTDOWN INITIALED BANK TO BE ATTACHMENT 1 TESTED AND INITIAL ATTACHMENT 1 STEP 6.1.1 S U

6. AT POWER WHEN CONTACTED OPERATOR CABINETS, ENSURE AS OPS TECH, CONTACTED OPS Comments:

THE PROPER REPORT GROUP TECH AND ENSURED LIGHTS ARE ON SELECT LIGHT C IS GROUP SELECT FOR THE ON AT POWER LIGHT C IS ON AT SELECTED BANK CABINETS 1AC AND POWER CABINETS AND INITIAL 2AC 1AC AND 2AC AND ATTACHMENT 1 INITIALED ATTACHMENT 1 STEP 6.1.2 S U

7. RECORD THE STEP COUNTERS OPERATOR SHUTDOWN BANK FOR SHUTDOWN RECORDED Comments:

STEP COUNTER BANK A INDICATE SHUTDOWN BANK A POSITION FOR THE 228 STEPS STEP COUNTER SELECTED BANK POSITION ON ON ATTACHMENT 1 ATTACHMENT 1 STEP 6.1.3 PAGE 4 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE

8. IF THE SELECTED STEP COUNTERS OPERATOR BANK IS PARKED AND DRPI FOR CONTINUED AT A FULLY SHUTDOWN BANK A PROCEDURE AT WITHDRAWN INDICATE STEP 6.1.5 POSITION OF 228 STEPS OTHER THAN 228 STEPS, INSERT OR WITHDRAW THE BANK TO 228 STEPS AS INDICATED BY THE STEP COUNTERS AND DIGITAL ROD POSITION INDICATION.

STEP 6.1.4 S U

9. RECORD SF074, SHUTDOWN BANK A OPERATOR DIGITAL ROD DRPI AND STEP RECORDED Comments:

POSITION COUNTERS SHUTDOWN BANK A INDICATION (DRPI) INDICATE 228 STEPS DRPI AND STEP AND SHUTDOWN COUNTER POSITION BANK STEP ON ATTACHMENT 1 COUNTER POSITION ON ATTACHMENT 1 STEP 6.1.5 PAGE 5 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 10. INSERT THE STEP COUNTERS OPERATOR SELECTED BANK FOR SHUTDOWN INSERTED Comments:

TWO STEPS PER BANK A INDICATE SHUTDOWN BANK A STEP COUNTER 226 STEPS TO 226 STEPS INDICATION (AFTER ROD MOVEMENT)

STEP 6.1.6 S U

• 11. WITHDRAW THE STEP COUNTERS OPERATOR SELECTED BANK FOR SHUTDOWN WITHDREW Comments:

TO 228 STEPS PER BANK A INDICATE SHUTDOWN BANK A STEP COUNTER 228 STEPS TO 228 STEPS INDICATION (AFTER ROD MOVEMENT)

STEP 6.1.7 S U

12. CHECK THAT NO NO ROD CONTROL OPERATOR ROD CONTROL ALARMS ARE CHECKED THAT NO Comments:

ALARMS ARE PRESENT ALARMS ARE PRESENT PRESENT STEP 6.1.8 PAGE 6 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 13. INSERT THE SHUTDOWN BANK A OPERATOR SELECTED BANK STEP COUNTERS INSERTED Comments:

AT LEAST 12 STEPS AND DRPI INDICATE SHUTDOWN BANK A AS INDICATED BY 216 STEPS TO AT LEAST 218 THE STEP STEPS COUNTERS AND (AFTER ROD DRPI MOVEMENT) (ACCEPTANCE CRITERIA OF 10 STEPS)

STEP 6.1.9 S U

14. RECORD DRPI AND SHUTDOWN BANK A OPERATOR SHUTDOWN BANK DRPI AND STEP RECORDED Comments:

STEP COUNTER COUNTERS SHUTDOWN BANK A POSITION FOR THE INDICATE 216 STEPS DRPI AND STEP SELECTED BANK COUNTER POSITION ON ATTACHMENT 1 ON ATTACHMENT 1 STEP 6.1.10 S U

• 15. RETURN SELECTED SHUTDOWN BANK A OPERATOR BANK TO THE STEP COUNTERS WITHDREW Comments:

POSITION AND DRPI INDICATE SHUTDOWN BANK A RECORDED IN 228 STEPS TO AT LEAST STEP 6.1.3 225 STEPS (AFTER ROD MOVEMENT)

STEP 6.1.11 PAGE 7 of 8

JPM NO: S1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

16. RECORD DRPI AND SHUTDOWN BANK A OPERATOR SHUTDOWN BANK DRPI AND STEP RECORDED Comments:

STEP COUNTER COUNTER INDICATE SHUTDOWN BANK A POSITION FOR THE 228 STEPS DRPI AND STEP SELECTED BANK COUNTER POSITION ON ATTACHMENT 1 ON ATTACHMENT 1 STEP 6.1.12

17. REPEAT STEPS THE CONTROL 6.1.1 THROUGH ROOM SUPERVISOR 6.1.12 AS INFORMS YOU THAT NECESSARY TO NO FURTHER TEST THE TESTING IS REMAINING REQUIRED SHUTDOWN BANKS _________________

THE JPM IS COMPLETE STEP 6.1.13 RECORD STOP TIME ON PAGE 1 PAGE 8 of 8

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1, 100% STEADY STATE POWER. THERE ARE NO SPECIAL PHYSICS TESTS IN PROGRESS, NO BORON CONCENTRATION CHANGES BEING MADE OR PLANNED, AND CONTROL RODS ARE IN A NORMAL CONFIGURATION.

Initiating Cues: THE CONTROL ROOM SUPERVISOR DIRECTS YOU TO PERFORM CONTROL ROD PARTIAL MOVEMENT FOR ALL SHUTDOWN BANKS, PER OSP-SF-00002, SECTION 6.1.

START WITH SHUTDOWN BANK A AND PROCEED IN ALPHABETICAL ORDER.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM No: P3 Rev 1 KSA No: 103A2.03 Job

Title:

RO / SRO KSA Rating: 3.5 / 3.8 Duty: Emergency Ops / Containment Isolation Revision: 2009 Task

Title:

Locally Close Valves for a CIS-A 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 X Classroom Method of Performance: Simulated X Performed

References:

EOP Addendum 25, CONTAINMENT ISOLATION PHASE A VALVES, R001 Tools/Equipment: Personal Protective Equipment Required Dosimetry and RWP FACILITY REPRESENTATIVE: Date:

CHIEF EXAMINER: Date:

JPM NO: P3 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: There has been a Station Blackout at the Callaway Plant. The Control Room Crew is performing the actions of Emergency Procedure ECA-0.0, Loss of All AC Power.

Initiating Cues: The Control Room Supervisor (CRS) directs you to isolate the following Train B valves using EOP Addendum 25, CONTAINMENT ISOLATION PHASE A VALVES:

BL HV-8047, Reactor Makeup Water Outside Ctmt Isolation LF HV-96, Ctmt Normal Sumps to Floor Drain Tank Outside Ctmt Isolation SJ HV-127, PZR/RCS Liquid Sample Outside Ctmt Isolation Close any valves that are out of position or close their manual isolations and inform the CRS when complete.

Note: All Operator Actions are to be simulated.

Task Standard: Upon completion of this JPM, the operator will have demonstrated the ability to ensure valves associated with penetrations 25, 32 and 93 are closed.

Start Time:

Stop Time:

Page 1 of 4

JPM NO: P3 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. Obtain a verified Provide operator with Operator obtained working copy of procedure copy procedure copy Comments:

EOP Addendum 25, CONTAINMENT ISOLATION PHASE A VALVES S U

2. Proceed to the South Operator proceeded to Piping Penetration the South Piping Comments:

Room (2000 Aux) Penetration Room (2000 Aux)

S U 3.* Ensure BL HV-8047, BL HV-8047 is Since there was NO Reactor Makeup STUCK OPEN Manual Actuator on Comments:

Water Outside Ctmt the Valve (Air Iso (P-25) After the Operator Operated) the locates and Operator closed the demonstrates the manual isolation:

ability to close the manual isolation valve BL V0035, Rx M/U Wtr BL V0035 - tell them it Outer Cntmt Iso is closed.

• Critical Step Page 2 of 4

JPM NO: P3 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 4.* Ensure LF FV-96, LF FV-96, is OPEN Operator determined Ctmt Norm Sumps to that LF FV-96 was out Comments:

Floor Dran Tk of position and Outside Iso (P-32) After operator demonstrated the demonstrates the ability to locally close it ability to locally close LF HV-96, provide the cue that the valve is closed S U

5. Proceed to the North Operator proceeded to Piping Penetration the North Piping Comments:

Room (2000 Aux) Penetration Room (2000 Aux)

S U 6.* Ensure SJ HV-127, SJ HV-127 is STUCK Since there was NO PZR/RCS Liquid OPEN Manual Actuator Comments:

Sample Outside Ctmt (Solenoid) on the Iso is closed (P-93) Valve the Operator closed the manual isolation:

SJ V0054, PASS HOT LEG SAMP OUT CTMT ISO VLVS DNSTRM ISO

• Critical Step Page 3 of 4

JPM NO: P3 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

7. Notify the CRS that The CRS Operator notified the steps assigned in acknowledges CRS that assigned Comments:

EOP Addendum 25 completion of steps of EOP are complete EOP Addendum 25 Addendum 25 were steps complete.

S U

8. The JPM is Complete Record Stop Time on Page 1 Comments:

• Critical Step Page 4 of 4

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: There has been a Station Blackout at the Callaway Plant. The Control Room Crew is performing the actions of Emergency Procedure ECA-0.0, Loss of All AC Power.

Initiating Cues: The Control Room Supervisor (CRS) directs you to isolate the following Train B valves using EOP Addendum 25, CONTAINMENT ISOLATION PHASE A VALVES:

BL HV-8047, Reactor Makeup Water Outside Ctmt Isolation LF HV-96, Ctmt Normal Sumps to Floor Drain Tank Outside Ctmt Isolation SJ HV-127, PZR/RCS Liquid Sample Outside Ctmt Isolation Close any valves that are out of position or close their manual isolations and inform the CRS when complete.

Note: All Operator Actions are to be simulated.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: P2 Rev 1 KSA NO: 065AK3.08 JOB TITLE: RO / SRO KSA RATING: 3.7/3.9 DUTY: INSTRUMENT AIR SYSTEM REVISION: 2009 TASK TITLE: RESPOND TO LOSS OF INSTRUMENT AIR 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT X CLASSROOM METHOD OF PERFORMANCE: SIMULATED X PERFORMED

REFERENCES:

OTO-KA-00001, ADD 1, TURBINE BUILDING LOSS OF INSTRUMENT AIR, REV 000.

TOOLS/EQUIPMENT: PPE FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: P2 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1. INSTRUMENT AIR PRESSURE IS 0 PSIG, LOSS OF INSTRUMENT AIR HAS JUST BEEN ANNOUNCED OVER THE GAITRONICS. YOU ARE AN EXTRA EQUIPMENT OPERATOR ON SHIFT.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO PERFORM OTO-KA-00001, ADD 1, TURBINE BUILDING LOSS OF INSTRUMENT AIR.

NOTIFY THE CRS WHEN THIS OTO ADDENDUM HAS BEEN COMPLETED.

Notes: ALL OPERATOR ACTIONS ARE TO BE SIMULATED.

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE TURNED OFF POWER TO BOTH AIR DRYERS AND MANUALLY ISOLATED THE SERVICE AIR HEADER WITH KAV0004.

START TIME:

STOP TIME:

PAGE 1 of 7

JPM NO: P2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED PROVIDE OPERATOR WORKING COPY OF OPERATOR WITH OBTAINED Comments:

OTO-KA-00001, COPY OF OTO-KA- PROCEDURE COPY ADD1, TURBINE 00001, ADD 1 BUILDING LOSS OF INSTRUMENT AIR (Located on a stantion between the A and B Air Compressors)

S U

2. REVIEW OPERATOR PRECAUTIONS AND REVIEWED THE Comments:

LIMITATION PRECAUTIONS AND ASSOCIATED WITH LIMITIATIONS IN OTO-KA-00001, SECTION 2 ADDENDUM 1 STEP 2.0 S U

3. ENSURE ALL AS THE OPERATOR OPERATOR AVAILABLE KA AIR CHECKS ALL CHECKED ALL AIR Comments:

COMPRESSORS COMPRESSORS COMPRESSORS ARE RUNNING INFORM THAT THE RUNNING COMP LOADED AND KAHS0003C MAIN DRIVE MOTOR RUNNING LIGHTS KAHS0002C ARE LIT ON ALL COMPRESSORS KAHS0001C STEP 3.1

• CRITICAL STEP PAGE 2 of 6

JPM NO: P2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 4*. IF SYSTEM INFORM OPERATOR OPERATOR CLOSED PRESSURE HAS THAT KAPV0011 IS KAV0004. Comments:

DROPPED BELOW OPEN 110 PSIG, THEN PERFORM THE WHEN OPERATOR FOLLOWING: DEMONSTRATES ABILITY TO CLOSE ENSURE KAPV0011 KAV0004, INFORM HAS THAT KAV0004 IS AUTOMATICALLY CLOSED CLOSED -OR-CLOSE KAV0004 STEP 3.2 S U

5. NOTE: THE DRYER OPERATOR READ TRAIN NOTE Comments:

INLET/OUTLET ISOLATION VALVES FAIL OPEN AT APPROXIMATELY 105 PSIG NOTE BEFORE STEP 3.3

• CRITICAL STEP PAGE 3 of 6

JPM NO: P2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 6*. IF A TOTAL LOSS Note: Instrument air OPERATOR OF INSTRUMENT pressure is 0 psig LOCATED THE AIR Comments:

AIR HAS (Given in initial DRYER OCCURRED, THEN conditions) HANDSWITCHES PERFORM THE AND TURNED THEM FOLLOWING: AS THE OPERATOR OFF TURNS OFF POWER TURN POWER OFF TO THE AIR DRYERS KAHS0359A TO BOTH AIR INFORM THEM THE DRYERS AND SWITCH HAS BEEN KAHS0359B PLACE THEM IN TURNED TO OFF THE FAIL SAFE AND THE POWER LINEUP: ON LIGHT IS OFF KAHS0359A KAHS0359B STEP 3.3.1 S U

7. VERIFY THE DRYER AS THE OPERATOR OPERATOR TRAIN LOCATES THE CHECKED THE Comments:

INLET/OUTLET DRYER FOLLOWING VALVES ISOLATION VALVES INLET/OUTLET FAILED OPEN:

AND THE A ISOLATION VALVES TOWER INLET AND A TOWER TRAIN A - KAFV0354, ISOLATION VALVES ISOLATIONS INFORM KAFV0355, HAVE FAILED THAT THEY ARE KAFV0344 OPEN: OPEN TRAIN B - KAFV0356, TRAIN A - KAFV0354, KAFV0357, KAFV0355, KAFV0346 KAFV0344 TRAIN B - KAFV0356, KAFV0357, KAFV0346 STEP 3.3.2

• CRITICAL STEP PAGE 4 of 6

JPM NO: P2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

8. NOTE: FAILURE OF OPERATOR READ THE DISCHARGE THE NOTE Comments:

CHECK VALVE WILL BE INDICATED BY FREQUENT UNLOAD AND LOADING CYCLES WHICH MAY CAUSE THE COMPRESSOR TO OVERHEAT AND TRIP.

NOTE BEFORE STEP 3.4 S U 9*. IF A PROBLEM HAND APPLICANT OPERATOR EXISTS WITH A CUE SHEET REALIZED AIR Comments:

PARTICULAR AIR COMPRESSOR COMPRESSOR If asked Oil Pressure CK01B MUST BE THEN STOP IT AND indicates 0 psig SHUTDOWN AND CLOSE THE DEPRESSED:

DISCHARGE VALVE ACKNOWLEDGE THE STOP KAHS0002D- STOP PUSBUTTON WAS PB DEPRESSED AND CLOSED ONCE THE DISCHARGE:

OPERATOR LOCATES AND KAV0210 -

STEP 3.4 SIMULATES COMPRESS AIR SYS CLOSING VALVE - AIR CMPSR B AIR STATE: DISCHARGE RCVR OUT ISO VALVE KAV210 IS CLOSED

• CRITICAL STEP PAGE 5 of 6

JPM NO: P2 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

10. ENSURE ALL KA AIR COMPRESSORS OPERATOR SYSTEM AIR A AND C ARE ENSURED THE A Comments:

COMPRESSORS RUNNING WITH AND C AIR ARE RUNNING COOLING WATER COMPRESSORS WITH COOLING SUPPLIED WERE RUNNING WATER SUPPLIED WITH COOLING THE PRIMARY WATER AVAILABLE.

OPERATOR HAS STEP 3.5 LOCALLY OPENED EFHV0043 AND EFHV0044 S U

11. NOTIFY THE CONTROL ROOM OPERATOR CONTROL ROOM ACKNOWLEDGES INFORMED THE Comments:

OF ALL AND REPLIES THAT CONTROL ROOM OF COMPONENT NO FURTHER THE FOLLOWING:

MANIPULATIONS ACTION IS PERFORMED IN REQUIRED KAV0004, THIS ADDENDUM COMPRESS AIR SYS SERV AIR SPLY STEP 3.6 KAPV0011 DNSTRM ISO - CLOSED BOTH AIR DRYERS POWERED OFF USING THE APPROPRIATE HANDSWITCH B AIR COMPRESSOR STOPPED DUE TO ZERO OIL PRESSURE AND EXCESSIVE NOISE THIS COMPLETES THE JPM RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 6 of 6

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1. INSTRUMENT AIR PRESSURE IS 0 PSIG, LOSS OF INSTRUMENT AIR HAS JUST BEEN ANNOUNCED OVER THE GAITRONICS. YOU ARE AN EXTRA EQUIPMENT OPERATOR ON SHIFT.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO PERFORM OTO-KA-00001, ADD 1, TURBINE BUILDING LOSS OF INSTRUMENT AIR.

NOTIFY THE CRS WHEN THIS OTO ADDENDUM HAS BEEN COMPLETED.

Notes: ALL OPERATOR ACTIONS ARE TO BE SIMULATED.

THE B AIR COMPRESSOR IS MAKING EXCESSIVE NOISE

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: P1 Rev 1 KSA NO: 064A4.01 JOB TITLE: RO / SRO KSA RATING:4.0/4.3 DUTY: SAFETY RELATED ELEC GEN & DIST (NE) REVISION: 2009 TASK TITLE: DIESEL GENERATOR PRE-START CHECKS ON NE01 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:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB PLANT X CLASSROOM METHOD OF PERFORMANCE: SIMULATED X PERFORMED

REFERENCES:

OTN-NE-0001A, STANDBY DIESEL GENERATOR SYSTEM - TRAIN A; REV. 26 TOOLS/EQUIPMENT: PPE FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: P1 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER. 'A' DIESEL GENERATOR WILL NEED TO BE RUN FOR ITS NORMAL SURVEILLANCE. THE AUXILIARY COMPONENTS HAVE BEEN ALIGNED AND NO OTHER CHECKLISTS FROM SECTION 5.1 OF OTN-NE-0001A, STANDBY DIESEL GENERATION SYSTEM-TRAIN A, NEED TO BE PERFORMED.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO PERFORM THE DIESEL GENERATOR PRE-START CHECKS ON NE01, PER OTN-NE-0001A, SECTION 5.2. INFORM THE CRS WHEN SECTION 5.2 HAS BEEN COMPLETED TO STEP 5.2.19 (RO ACTIONS).

Notes: ALL OPERATOR ACTIONS ARE TO BE SIMULATED.

Task Standard: UPON COMPLETION OF THIS JPM, THE OPERATOR WILL HAVE COMPLETED THE PRE-START CHECK ON NE01.

START TIME:

STOP TIME:

PAGE 1 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. OBTAIN A VERIFIED OPERATOR WORKING COPY OF OBTAINED Comments:

OTN-NE-0001A, PROCEDURE COPY STANDBY DIESEL GENERATOR SYSTEM - TRAIN A S U

2. REVIEW ALL PRECAUTIONS OPERATOR PRECAUTIONS AND AND LIMITATIONS REVIEWED THE Comments:

LIMITATIONS OF ARE SATISFIED PRECAUTIONS AND OTN-NE-0001A LIMITATIONS SECTION 3 S U

3. REVIEW THE ALL PREREQUISITES OPERATOR PREREQUISITES ARE SATISFIED REVIEWED THE Comments:

OF OTN-NE-0001A PREREQUISITES ASK IF THE SECTION 4 OPERATOR UNDERSTANDS THE PREREQUISITES AND INITIATING CUES

• CRITICAL STEP PAGE 2 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

4. REQUEST SM/CRS IF ASKED: ALL OPERATOR TO DETERMINE IF CHECKLISTS FROM UNDERSTOOD THAT Comments:

ANY CHECKLISTS SECTION 5.1 ARE ALL STANDBY FROM SECTION 5.1 COMPLETE ALIGNMENTS WERE NEED TO BE COMPLETE AS PERFORMED TO STATED IN THE RETURN INITIAL CONDITIONS COMPONENTS TO CUE SHEET NORMAL STANDBY ALIGNMENT STEP 5.2.1 S U NOTE: THE CONTROL UNDERSTAND THAT OPERATOR READ ROOM SHOULD BE THE OPERATOR AND UNDERSTOOD Comments:

INFORMED OF ANY MAY PERFORM NOTE ALARMS TO STEPS IN THIS DETERMINE SECTION IN ANY EFFECT ON DIESEL ORDER OPERATION STEPS IN THIS SECTION MAY BE PERFORMED IN ANY ORDER S U

5. AT LOCAL ALARM NO ALARMS OPERATOR LOOKED PANEL KJ121, AT PANEL KJ121 Comments:

CHECK FOR AND CHECKED FOR ALARMS AND ANY ALARMS NOTIFY RO STEP 5.2.2

• CRITICAL STEP PAGE 3 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

6. ENSURE JEHS0001B IS IN THE OPERATOR JEHS0001B, DG F.O. NORMAL POSITION VERIFIED Comments:

XFR PMP HAND JEHS0001B WAS IN SWITCH, IN THE SPRING NORMAL RETURN TO NORMAL POSITION STEP 5.2.3 S U

7. CHECK JELI0012B, POINT TO JELI0012B OPERATOR EMERG F.O. DAY AND INDICATE VERIFIED DG F.O. Comments:

TK A FUEL LEV IND LEVEL IS AT 4.0 FT DAY TK LEVEL B, INDICATES GREATER THAN 3.5 GREATER THAN OR FEET EQUAL TO 3.5 FEET.

STEP 5.2.4 S U

8. CHECK LOCAL INDICATED LEVEL IS OPERATOR GAUGE JELIT0005, AT 90% VERIFIED EMERG Comments:

EMERG F.O. STOR F.O. STOR TK A LEV TK A LEV IND (SE corner of room in INDICATED XTMR, INDICATES box) GREATER THAN 80%

GREATER THAN 80%

STEP 5.2.5

• CRITICAL STEP PAGE 4 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

9. CHECK THE FUEL AFTER SIMULATING / OPERATOR INJECTOR PUMPS DEMONSTRATING DEMONSTRATED Comments:

AS FOLLOWS: HOW THIS IS THE ABILITY TO ACCOMPLISHED ON CHECK THE FUEL

• MOVE THE ONE CYLINDER - INJECTOR PUMP CALIBRATED CYL STATE THAT ALL RACKS ON THE RIGHT MOVE FREELY SIDE OF EACH INJ TO THE RACK 30 MARK AND RET TO NORM

• CHECK EACH MOVES FREELY STEP 5.2.6 S U

10. ENSURE THE BOTH AIR OPERATOR FOLLOWING AIR COMPRESSOR LOCATED AND Comments:

COMPRESSOR SWITCHES ARE IN ENSURED AIR CONTROL AUTO COMPRESSOR SWITCHES IN AUTO CONTROL SWITCHES WERE IN

• KJHIS0002A AUTO

• KJHIS0002B

• KJHIS0002A STEP 5.2.7

• KJHIS0002B

• CRITICAL STEP PAGE 5 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

11. ENSURE THE BOTH STARTING AIR OPERATOR FOLLOWING RECEIVERS LOCATED AND Comments:

STARTING AIR INDICATE 650 PSIG VERIFIED STARTING RECEIVER AIR RECEIVER PRESSURES ARE PRESSURE GREATER THAN INDICATED > 610#

610 PSIG.

• KJPI0003A

• KJPI0003A

• KJPI0003B

• KJPI0003B STEP 5.2.8 S U

12. ENSURE LUBE OIL KJLI0031, LUBE OIL OPERATOR SUMP LEVEL WITH SUMP LEVEL LOCATED AND Comments:

EITHER OF THE INDICATES 95% VERIFIED FOLLOWING: APPROPRIATE LUBE OIL SUMP LEVEL

• KJLI0031 85% TO 100% IN GREEN BAND

• ENGINE CRANK CASE DIPSTICK INDICATES ABOVE THE FILL MARK STEP 5.2.9 NOTE KJ121 Annunciator 2D, LUBE OIL TEMP LOW, alarms at 116.5 °F and resets at approximately 126.5°F.

• CRITICAL STEP PAGE 6 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

13. ENSURE KJTISL0030 OPERATOR KJTISL0030, DG A INDICATES 130°F LOCATED AND THEN Comments:

L-O SMP LOW TEMP ENSURED IND SW, INDICATES KJTISL0030 BETWEEN 120°F INDICATED AND 140°F BETWEEN 120°F AND 140°F

• KJTISL0030 STEP 5.2.10 NOTE Failure to satisfy the prelube requirement does not render the diesel generator inoperable, and the diesel generator is operable during performance of a rocker arm prelube CAUTION If diesel or pre-lube pump have been run in preceding 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, another pre-lube should not be performed, to prevent possibility of excessive oil in the cylinders.

• CRITICAL STEP PAGE 7 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 14*. ENSURE ROCKER ATTACHMENT 2 HAS OPERATOR WENT ARM LUBRICATION BEEN FILLED OUT TO ATTACHMENT 2 Comments:

PER ATTACHMENT SHOWING THAT OF THE 2 IS PERFORMED ROCKER ARM PROCEDURE AND ONCE WITHIN 8 LUBRICATION WAS SAW THAT ROCKER HOURS BEFORE PERFORMED 3 ARM LUBRICATION STARTING ENGINE. HOURS AGO HAD BEEN PERFORMED LESS THAN 8 HOURS AGO AND DID NOT STEP 5.2.11 PERFORM ANOTHER PRE-LUBE.

S U

15. IF KJ121 ANN 3C, OPERATOR ROCKER OIL VERIFIED NO Comments:

RESERVOIR LEVEL ALARM.

HIGH IS IN ALARM, PERFORM THE FOLLOWING:

STEP 5.2.12 S U

16. ENSURE KJTI0060, KJTI0060 OPERATOR DG A JACKET WTR CURRENTLY READS: LOCATED KJTI0060 Comments:

SPLY & RTN TEMP AND SAW THAT IND, INDICATES 145°F from the engine TEMP WAS BETWEEN 135°F BETWEEN 135°F AND 167°F 140°F to the engine AND 167°F

• KJTI0060 STEP 5.2.13

• CRITICAL STEP PAGE 8 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

17. PERFORM THE KJLG0070 OPERATOR FOLLOWING TO INDICATES SIMULATED Comments:

INSPECT COOLANT APPROXIMATELY 10 OPENING ISOLATION LEVEL: INCHES VALVES: KJV0767A AND 068A:

UNISOLATE KJLG0070 AND VERIFIED LEVEL READ LEVEL AT GREATER THAN 3 GREATER THAN 3 INCHES INCHES. THEN RE-CLOSE THE THEN CLOSED ISOLATION VALVES VALVES TO KJLG0070 STEP 5.2.14 S U 18*. ENSURE THE LIMIT SWITCH IS OPERATOR FOLLOWING FOR NOT ENGAGED SHOWED THE Comments:

THE OVERSPEED EVALUATOR HOW TRIP/RESET KNOB TO VERIFY:

ON THE ENGINE THE SILVER KNOB

• SILVER KNOB IS WAS PULLED OUT PULLED OUT TO TO THE RESET RESET POSITION POSITION

• LIMIT SWITCH NOT THE LIMIT SWITCH ENGAGED WAS NOT ENGAGED STEP 5.2.15

• CRITICAL STEP PAGE 9 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U 19*. MOMENTARILY ACKNOWLEDGE OPERATOR PRESS KJHS0012, KJHS0012 HAS BEEN SIMULATED Comments:

DG A ENGINE DEPRESSED DEPRESSING SHUTDOWN RESET KJHS0012 STEP 5.2.16 S U

20. ENSURE EACH OF AS THE OPERATOR OPERATOR THE FOLLOWING LOCATES THESE, ENSURED THE Comments:

LOCKOUT RELAYS INFORM THEM THE LISTED LOCKOUT ARE RESET: LOCKOUT RELAYS RELAYS WERE ARE RESET RESET

• NE1071861DG, LOR1

• NE1071862DG, LOR2

• NE107130DG, UNIT S/D TARGET RLY STEP 5.2.17 S U 21*. MOMENTARILY THE EXCITER RESET OPERATOR PRESS NEHS0023, PUSHBUTTON HAS SIMULATED Comments:

EXCITER RESET, BEEN DEPRESSED DEPRESSING PUSHBUTTON. NEHS0023 STEP 5.2.18

• CRITICAL STEP PAGE 10 of 11

JPM NO: P1 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

22. NOTE: THE CONTROL ROOM OPERATOR READ REMAINING STEPS SUPERVISOR NOTE. Comments:

IN THIS SECTION ACKNOWLEDGES ARE PERFORMED OPERATOR AT MAIN CONTROL CONTACTED BOARDS RL015 OR CONTROL ROOM RL024. THIS JPM IS SUPERVISOR HE COMPLETE WAS DONE UP TO NOTE PRIOR TO STEP 5.2.19 STEP 5.2.19 RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 11 of 11

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: CALLAWAY PLANT IS IN MODE 1 AT 100% POWER. 'A' DIESEL GENERATOR WILL NEED TO BE RUN FOR ITS NORMAL SURVEILLANCE. THE AUXILIARY COMPONENTS HAVE BEEN ALIGNED AND NO OTHER CHECKLISTS FROM SECTION 5.1 OF THIS PROCEDURE NEED TO BE PERFORMED.

Initiating Cues: THE CONTROL ROOM SUPERVISOR (CRS) DIRECTS YOU TO PERFORM THE DIESEL GENERATOR PRE-START CHECKS ON NE01, PER OTN-NE-0001A, SECTION 5.2. INFORM THE CRS WHEN SECTION 5.2 HAS BEEN COMPLETED TO STEP 5.2.19 (RO ACTIONS).

Notes: ALL OPERATOR ACTIONS ARE TO BE SIMULATED.

CALLAWAY PLANT JOB PERFORMANCE MEASURE JPM NO: S8 Rev 1 KSA NO: 015 A4.03 JOB TITLE: RO KSA RATING: 3.8/3.9 DUTY: OFF NORMAL - NUCLEAR INST. REVISION: 2009 TASK TITLE: RESPOND TO A FAILED POWER RANGE INSTRUMENT COMPLETION TIME: 17 MINUTES The performance of this task was evaluated against the standards contained in this JPM and determined to be:

[ ] SATISFACTORY [ ] UNSATISFACTORY Reason, if UNSATISFACTORY:

EVALUATORS SIGNATURE: DATE:

TASK PERFORMER:

LOCATION OF PERFORMANCE:

CONTROL ROOM SIMULATOR/LAB X PLANT CLASSROOM METHOD OF PERFORMANCE: SIMULATED PERFORMED X

REFERENCES:

OTO-SE-00001, NUCLEAR INSTRUMENT MALFUNCTION, R018 TOOLS/EQUIPMENT:

FACILITY REPRESENTATIVE: // // DATE:

CHIEF EXAMINER: // // DATE:

JPM NO: S8 Rev 1 Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is in Mode 1. Power Range NIS channel N42 failed high.

The actions of OTO-SE-00001, Nuclear Instrument Malfunction, have been performed through step A4 of Attachment A.

Initiating Cues: The Control Room Supervisor (CRS) directs you to perform OTO-SE-00001, Attachment A, Power Range Instrument Malfunction, steps A5 through A9.

Inform the CRS when the Control Power fuses for the failed channel have been removed.

Notes: Use any Mode 1 IC above 50%, with the Main Feedwater Reg Valves in service.

Ensure Rod Control is in MANUAL Insert Malfunction (SE) SEN0042, Value = 200, with a 10 second ramp.

Task Standard: Upon Completion of this JPM, Power Range NIS channel N42 current comparator and rod stop inputs will be bypassed. The protective bistables for N42 will be tripped and the control power fuses removed.

START TIME:

STOP TIME:

PAGE 1 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

1. Obtain a verified Provide Operator with Operator obtained working copy of procedure copy procedure copy Comments:

OTO-SE-00001, Nuclear Instrument Malfunction Examiner Note:

JPM Steps 2 through 5 can be performed in any order S U

• 2. Bypass the The Upper Section Operator placed the malfunctioning switch on the Detector Upper Section switch, Comments:

channel by selecting Current Comparator on the Detector it on the following drawer is in the N42 Current Comparator switches: position drawer, in the N42 position Detector Current Comparator drawer:

Place Upper Section switch to the failed channel Step A5.a

• CRITICAL STEP PAGE 2 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 3. Detector Current The Lower Section Operator placed the Comparator drawer: switch on the Detector Lower Section switch, Comments:

Current Comparator on the Detector Place Lower Section drawer is in the N42 Current Comparator switch to the failed position drawer, in the N42 channel position Step A5.a S U

• 4. Detector Current The Rod Stop Bypass Operator placed the Comparator drawer: switch on the Detector Rod Stop Bypass Comments:

Current Comparator switch, on the Detector Place Rod Stop drawer is in the N42 Current Comparator Bypass switch to the position drawer, in the N42 failed channel position Step A5.a S U

• 5. Detector Current The Power Mismatch Operator placed the Comparator drawer: Bypass switch on the Power Mismatch Comments:

Detector Current Bypass switch, on the Place Power Comparator drawer is Detector Current Mismatch Bypass in the N42 position Comparator drawer, in switch to the failed the N42 position channel Step A5.a

• CRITICAL STEP PAGE 3 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 6. On the Comparator The Comparator Operator placed the and Rate drawer, Channel Defeat switch Comparator Channel Comments:

Place Comparator on the Comparator Defeat switch, on the Channel Defeat and Rate drawer is in Comparator and Rate switch to the failed the N42 position drawer, in the N42 channel position Step A5.b S U

7. Ensure the following 78A, PR CH DEV Operator ensured the Annunciators are 78B, UP DET FLUX following Annunciators Comments:

extinguished: DEV were extinguished:

78C, LO DET FLUX 78A, PR CH DEV DEV 78A, PR CH DEV 78B, UP DET FLUX 82A, PR ROD STOP 78B, UP DET FLUX DEV DEV 78C, LO DET FLUX are extinguished: 78C, LO DET FLUX DEV DEV 82A, PR ROD STOP 82A, PR ROD STOP Step A5.c S U

8. NOTE: Step A5 of Step A5 of this section Operator read note this section must be is complete. and ensured Step A5 Comments:

completed before of this section was continuing completed before continuing

• CRITICAL STEP PAGE 4 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

9. Check Rod Control - RCS Tavg/Tref are Operator PLACED In AUTO equal AND rods were Rod Control In AUTO Comments:

in AUTO prior to the RNO - When RCS event.

Tavg/Tref are equal AND rods were in AUTO prior to the event, THEN PLACE Rod Control in AUTO Step A6 S U

10. Check any SG level No SG level being Operator checked any being controlled by controlled by MFW SG level being Comments:

MFW REG VALVE REG VALVE BYPASS controlled by MFW BYPASS VALVES VALVES REG VALVE BYPASS VALVES and went to RNO - Go to Step A8 Step A8 Step A7 S U

11. Check Reactor Power Reactor Power is Operator checked

- Greater than 10% >10% Reactor Power - Comments:

Greater than 10%

Step A8

• CRITICAL STEP PAGE 5 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

12. Trip Protective The Control Room Operator went to Bistables per Supervisor directs you Attachment D Comments:

Attachment D, to perform Tripping PR Attachment D Protective Bistables, within the time limit specified in the applicable Technical Specification Step A9 S U

13. Check the failed Operator checked N42 Power Range Comments:

Channel:

____ N41

____ N42

____ N43

____ N44 Step D1 S U

14. Ensure no other No other Power Range Operator ensured no Power Range channels are in a other Power Range Comments:

channels are in a tripped condition channels were in a tripped condition tripped condition Step D2

• CRITICAL STEP PAGE 6 of 7

JPM NO: S8 Rev 1 TASK NUMBER - ELEMENT CUE STANDARD SCORE S U

• 15. REMOVE Control Control Power fuses Operator REMOVED Power fuses for the for N42 are removed Control Power fuses Comments:

failed channel for N42 Step D3 S U THE JPM IS COMPLETE Comments:

RECORD STOP TIME ON PAGE 1

• CRITICAL STEP PAGE 7 of 7

Read to Performer: I will explain the initial conditions, which steps to simulate or discuss, and provide initiating and subsequent cues. You may use any approved reference materials normally available to you. Make all written reports, oral reports, and log entries as if the evolution was actually being performed. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: Callaway Plant is in Mode 1. Power Range NIS channel N42 failed high.

The actions of OTO-SE-00001, Nuclear Instrument Malfunction, have been performed through step A4 of Attachment A.

Initiating Cues: The Control Room Supervisor (CRS) directs you to perform OTO-SE-00001, Attachment A, Power Range Instrument Malfunction, steps A5 through A9.

Inform the CRS when the Control Power fuses for the failed channel have been removed.

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 1 rev. 4 Op Test No.:

Examiners: Operators:

Initial Conditions: The following is the plant /equipment status:

• Operating at 100% steady state power

• MDAFP B OOS for an oil change. Scheduled for completion on the PM shift. (Activate Lesson al01b.lsn)

TS 3.7.5 Condition C, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Event Malf. No. Event Type* Event No. Description A N/A R (RO) Reduce Power to 95% for turbine valve testing N (SRO/BOP) 1 BBPT0455 I (RO) Pressurizer Pressure Channel Failure Low I-TS-SRO Insert Malfunction (BB) BBPT0455, Value= 1700 2 JEPS209L C (all) Loss of ESF Bus NB02 Insert Remote Function (NB) JEPS209L, Value= Trip 3 ABPV0001_1 C (BOP) A Atmospheric Steam Dump Fails Open C-TS- SRO Insert Malfunction (AB), ABV0001_1, Value = 1, ramp =

20s 4 BBTE421A1 I (RO, SRO) RCS Loop RTD Failure - High Insert Malfunction (BB) BBTE0421A1, Value = 650 5 SF006 C (all) Nuclear Power Generation Accident / ATWS Insert Malfunction (SF) SF006, Value = Both 6 EBB01C M (all) Steam Generator Tube Rupture Insert Malfunction (BB) EBB01C, Value= 250, time delay =

10 sec, ramp = 300 secs, conditional of jcrftr eq true 7 BG C (RO) CCP Auto Start Failure Insert Remote Function (BG) JLOASBI8_3, Value = Inhibit

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

Scenario Event Description NRC Scenario 1 rev. 4 Callaway 2009 NRC Scenario #1 This unit is at 100% steady state power. MDAFP B is out of service for scheduled maintenance.

Reduce power to 95% to perform turbine valve testing IAW OSP-AC-00003, Turbine Valve Stroke Test.

Pressurizer Pressure Channel 455 fails low. The crew should respond per OTO-BB-00006, Pressurizer Pressure Control Malfunction, defeat control system channel input and stabilize RCS pressure. I&C should be contacted to trip protective bistables and repair the failed channel.

A bus lockout occurs on NB02. The emergency diesel NE02 starts but the output breaker will not close due to the lockout condition. The crew should respond per OTO-NB-00002, Loss of Power to NB02. They will ensure reactor power <100%, throttle Auxiliary Feedwater flow, refer to Tech Specs and direct Electrical Maintenance to perform required testing and repairs.

After the plant is stabilized A SG Atmospheric Steam Dump fails open with a 20 sec.

ramp. The crew will respond using OTO-AB-00001, STEAM DUMP MALFUNCTION.

RCS Loop 2 Thot RTD fails high, resulting in an OTT trip signal. The reactor fails to trip automatically and manually. The crew should enter FR-S.1, Response to Nuclear Power Generation/ATWS. The reactor will be shutdown approximately two minutes after PG19 and PG20 feeder breakers are opened due to the rod drive MG set coast down.

10 seconds after the Reactor Trip, a Tube Rupture occurs on Steam Generator C. The tube rupture will ramp to 250 gpm resulting in a Safety Injection. The crew should complete FR-S.1 and transition to E-0, Rx Trip or Safety Injection. CCP A will fail to start automatically and will have to be started manually. The crew will then transition to E-3, Steam Generator Tube Rupture. The scenario is complete when RCS cooldown is commenced.

Scenario Event Description NRC Scenario 1 rev. 4 Critical Tasks:

Event #5 CT - Insert negative Reactivity into the core by at least one of the following methods before completing immediate actions steps of FR-S.1

• De-energize PG19 and PG20

• Insert Control Rods

• Establish emergency boration flow Event #7 CT - Establish flow from at least one high head ECCS pump before reporting E-0, Att.

A complete.

Event #6 CT - Isolate Feedwater flow into and steam flow from SG C before a transition to ECA-3.1 occurs.

References OTG-ZZ-00004 OTG-ZZ-00004, ADD 03 OSP-AC-00003 OTO-BB-00006 OTO-NB-00002 OTO-AB-00001 E-0 FR-S.1 E-3 EIP-ZZ-00101 CSF-1, Attachment A

Scenario Event Description NRC Scenario 1 rev. 4 Simulator Set Up Establish the initial conditions of IC-11, MOL 100%:

• RCS boron concentration 966 ppm

• CCP A 976 ppm minus 5 days

• CCP B 986 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• PZR pressure channel 455 selected for control

• CCW Train B supplying service loop

• Hang WPA on MDAFP B

======SCENARIO SETUP ITEMS===========

Remove MD AFP B from service

• Run lesson al01b.lsn Following Reactor Trip Steam Generator C Tube Leak of 400 gpm over 5 minutes

• Insert Malfunction (BB) EBB01C, Value= 400, time delay = 10 sec, ramp = 300 secs, conditional of jcrftr eq true Prevent Reactor Trip and Bypass breakers from opening in AUTO or MANUAL

• Insert Malfunction (SF) SF006, Value = Both CCP A Fails to start Automatically (can be started Manually)

• Insert Remote Function (BG) JLOASBI8_3, Value = Inhibit

========EVENT 1 ==============

PZR Pressure Channel 455 fails low

• Insert Malfunction (BB) BBPT0455, Value = 1700

=======EVENT 2 ===============

NB02 feeder breaker lockout

• Insert Remote Function (NB) JEPS209L, Value = trip

=======EVENT 3 ===============

A SG Atmospheric Steam Dump Failure OPEN with a 20 sec ramp

• Insert Malfunction (AB) ABPV0001_1, Value =1, ramp = 20 secs

=======EVENT 4 ===============

RCS loop 2 Thot RTD fails high

• Insert Malfunction (BB) BBTE0421A1, Value = 650

=======EVENT 5 PRELOADED===============

Prevent Reactor Trip and Bypass breakers from opening in AUTO or MANUAL (ATWS)

• Insert Malfunction (SF) SF006, Value = Both

=======EVENT 6 PRELOADED===============

Steam Generator C Tube Rupture

• Insert Malfunction (BB) EBB01C, Value= 250, time delay = 10 sec, ramp = 300 secs, conditional of jcrftr eq true

=======EVENT 7 PRELOADED===============

CCP A auto start failure (will start in Manual)

Insert Remote Function (BG) JLOASB18_3, Value = Inhibit

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # A Page 5 of 27 Event

Description:

Reduce Power Time Position Applicants Actions or Behavior Shortly after taking the watch, reduce power to 95% for turbine valve testing Indications Available:

OTG-ZZ-00004, Power Operation, Addendum 03 Power CRS (Step 5.2) Direct the power reduction in Section 5.2 Reduce (Step 5.2.1) Perform the following in any order to prepare for RO lowering power:

(Step 5.2.1a) If needed, prior to beginning a load reduction, CRS/RO Request I&C adjust NIS Power coarse gains.

STEP HAS BEEN COMPLETED (Step 5.2.1b) INITIATE Additional Actions Section 5.4 to CRS prepare for reducing power Addl CRS Section 5.4 Items are complete through step 5.4.1g Actions (Step 5.4.1e) PERFORM a Dilution/Boration Calculation for the RO anticipated change in power (Should be performed during turnover)

Power CRS/RO (Step 5.2.2) Initiate Power Reduction as follows Reduce (Step 5.2.2.a) BORATE the RCS as required to support RO lowering power to the desired final load.

(Step 5.2.2.b) ENSURE SE HS-9, ROD BANK AUTO/MAN RO SEL, is in MAN.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # A Page 6 of 27 Event

Description:

Reduce Power Time Position Applicants Actions or Behavior (Step 5.2.2.c) IF using MANUAL turbine control, INITIATE load BOP reduction by slowly turning LOAD LIMIT SET potentiometer counter-clockwise.

(Step 5.2.2.d) IF using AUTOMATIC turbine control, PERFORM the following:

Using EHC Panel DECREASE LOAD pushbutton, SLOWLY LOWER load until the following conditions are met:

• LOAD LIMIT LIMITING light OFF

• DECREASE LOADING RATE OFF light LIT

• LOADING RATE LIMIT %/MIN 1/2 light LIT BOP TURN LOAD LIMIT SET potentiometer fully clockwise.

SELECT DECREASE LOADING RATE ON SELECT desired loading rate.

• Use 0.05 for 3%/hr.

• Use 0.166 for 10%/hr.

• Use 1/2 for 30%/hr.

Using EHC Panel DECREASE LOAD pushbutton, INITIATE load reduction.

(Step 5.2.3) WHEN the desired power level is achieved PERFORM the following:

CREW

• Set Turbine Controls for steady state operation

• Borate/Dilute as needed to maintain power level

• Insert/withdraw rods as needed to maintain power level (Step 5.2.4) ENSURE annunciator 77A, REACT DEV, setpoint RO is 0.7°F.

If directed by the SRO to energize Pressurizer Heaters (Step 5.4.1.h) Using the following hand switches, ENSURE at least one group of Pressurizer Back-up Heaters is ENERGIZED to equalize RCS and Pressurizer boron RO concentrations.

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

• BB HIS-52A, PZR HTR B/U GROUP B, in CLOSE

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # A Page 7 of 27 Event

Description:

Reduce Power Time Position Applicants Actions or Behavior (Step 5.4.1.i) PLACE BB PK-455A, PZR PRESS MASTER RO CTRL, in MANUAL and LOWER to 40%.

(step 5.4.1.j) PLACE BB PK-455A, PZR PRESS MASTER RO CTRL, in AUTO.

(Step 5.4.1k) WHEN the difference between Boron RO Concentration in the pressurizer and the RCS is less than 50 ppm SECURE pressurizer back up heaters.

At the Discretion of the Lead Examiner Move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 1 Page 8 of 27 Event

Description:

Pressurizer Pressure Channel 455 Failure Low Time Position Applicants Actions or Behavior Upon Lead Examiner Cue, the Pressurizer Pressure Channel will fail low Booth Operator Instructions

• As Directed by the Lead Examiner

• Insert Malfunction (BB) BBPT0455, Value= 1700

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure.

• When contacted, respond as EDO. Acknowledge the channel failure and Tech Spec entry.

Indications Available:

33 C PZR PRESS LO HTRS ON 83 C RX PARTIAL TRIP OTO-BB-00006, Pressurizer Pressure Control Malfunction Implement OTO-BB-00006, Pressurizer Pressure Control CRS Malfunction (Step 1) Check Pressurizer Pressure Indicator - Failed BB PI-CRS/RO 455A (Step 2) Transfer Pressurizer Pressure Control Selector to CRS/RO Remove Failed Channel (455) from Control BB PS-455F (Step 3) Check Pressurizer Pressure CRS/RO Trending to or between 2225-2250 psig (Step 3 RNO) PLACE Pressurizer Pressure Master Controller RO in MANUAL: BB PK-455A, restore pressure to band Will restore to Auto when pressure in the control band

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 1 Page 9 of 27 Event

Description:

Pressurizer Pressure Channel 455 Failure Low Time Position Applicants Actions or Behavior (Step 4) Check P-11 in Correct State (not lit) Within One Hour (TS 3.3.2 Cond L)

CRS/RO

________ Current Time (Step 5) Select an Operable Channel for:

Pressure Recorder BB PS-455G CRS/RO OPDT/OTDT Temperature Recorder SC TS-411E DDA REP0 0480A, 481A, 482A, or 483A (Step 6) 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 (P 72hr) 3.3.2, Table 3.3.2-1 Item 1.d Cond D (SI 72hr)

CRS 3.3.2, Table 3.3.2-1 Item 8.b Cond L (ESFAS 1 hr) 3.3.2, Table 3.3.2-1 Item 9.b Cond D (SI 72hr)

Place Channel in Trip in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> CRS (Step 7) Record P-11 in Correct State in SS/CRS log (Step 8) Review Attachment A, Effects of Pressurizer Pressure CRS/RO Instrument Failure CRS (Step 9) Direct I&C to Trip Protective Bistables - Att. B CRS (Step 10) Place Inoperable Channel in the EOSL CRS (Step 11) Direct I&C to Repair Failed Channel At the Discretion of the Lead Examiner Move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 2 Page 10 of 27 Event

Description:

Loss of ESF Bus NB02 Lockout Time Position Applicants Actions or Behavior Loss of ESF Bus NB02 Booth Operator Instructions:

• Following an update brief by the crew or as directed by the Lead Examiner.

• Insert Remote Function (NB) JEPS209L, Value = Trip

• Act as Secondary EO and investigate the loss of NB02. Report an Instantaneous Overcurrent Trip and Lockout on the Normal Feeder Breaker.

• If requested to isolate CCW valves, then perform the following:

Insert Remote Function (EG) EGHV0016TASTEM, Value = 0 Insert Remote Function (EG) EGHV0054TASTEM, Value = 0

• If requested to manually stop the B Diesel Generator (NE02)

Insert Remote Function (KJ) JAUTODG2, Value = LOCAL/MANUAL Insert Remote Function (KJ) JSTOPDG2, Value = STOP

• Act as Emergency Duty Officer and acknowledge the OTO/TS entry

• Act as Electrical maintenance supervisor if requested to investigate the failure Indications Available:

21 A NB02 Bus Lockout 21 B NB02 Bus UV OTO-NB-00002, Loss of Power to NB02 CRS Implement OTO-NB-00002, Loss of Power to NB02 May choose to perform step 10 early as prudent action to CRS/BOP prevent overpower condition caused by cold Aux Feedwater addition. Prudent Action allowed per ODP-ZZ-00025.

(Step 1) Check 4160 VAC Bus NB02 - Deenergized CRS/RO 4.16 KV Bus NB02 light extinguished 4.16 KV Bus NB02 voltage indicates zero

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 2 Page 11 of 27 Event

Description:

Loss of ESF Bus NB02 Lockout Time Position Applicants Actions or Behavior (Step 2) Check Reactor Power - < 100%

CRS/RO If Not - Reduce Turbine load (Step 3) Check CCW Pump A or C - Running - NO CRS/BOP RNO - START CCW pump A or C (Step 4) Check CCW Service Loop Supplied From Train A CRS/BOP RNO Re-aligns CCW system for Service loop to be aligned (Step 4 RNO Actions)

Close both CCW Surge tank vent control valves HIS-9/10 Open CCW Train A Supply/Return valves HS-15 Open ESW train A to CCW HX A HIS-51 BOP Dispatch an operator to locally close the following valves:

EGHV0016 EGHV0054 When EGHV0016 and EGHV0054 are closed open both CCW Surge Tank Vent valves closed above CRS/RO (Step 5) Check CCW Aligned to RCPs (Step 6) Check RHR in service prior to event CRS/RO RNO - Go To Step 9 (Step 9) Check SG NR Level At or trending to 45 - 55%

CRS/BOP NOTE: TDAFP remains operable with discharge valves closed or throttled to control SG level after AFAS (Step 10) Check TDAFP - Secured CRS/BOP RNO - Throttle or close discharge valves as required

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 2 Page 12 of 27 Event

Description:

Loss of ESF Bus NB02 Lockout Time Position Applicants Actions or Behavior (Step 11) Check PZR Level CRS/RO At or trending to program level (Step 12) Check PZR Pressure CRS/RO At or trending to 2225 - 2250 psig (Step 13) Ensure the following NB02 loads shed ESW Pump B CCW Pump B/D CRS/BOP SI Pump B Ctmt Spray Pump B RHR Pump B CRS/BOP (Step 14) Open NB02 Normal and Alternate Feeder Breakers NOTE: Attachment B may be used as an aid CRS/BOP (Step 15) Check EDG B - Running NOTE: Attachments C & D may be used as an aid (Step 16) Check NB02 Emergency Supply Breaker - Closed CRS/BOP RNO - Applicant may direct the Ops Tech to stop EDG CRS/RO (Step 17) Check NCP or CCP A - Running CRS/RO (Step 18) Check RCP Seal Injection flow 8 - 13 gpm CRS/BOP (Step 19) Check Any Service Air Compressor - Running CRS/BOP (Step 20) Check PN08 Transferred to Emergency Source

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 2 Page 13 of 27 Event

Description:

Loss of ESF Bus NB02 Lockout Time Position Applicants Actions or Behavior CRS/BOP (Step 21) Check SFP Cooling Pump A - Running (Step 22) Check The Following - Running CRS/RO CR Air Conditioner A Class 1E Air Conditioner A (Step 23) Perform Contingency Actions of OTN-GK-00001, as CRS/RO time permits (Step 24) Check the following busses supplied from associated battery CRS/RO NK02 and NK04 PK02 and PK04 (Step 25) Perform the following to maintain battery life Contact system engineer CRS/RO Monitor battery load Cross-tie PK busses to functional charger CRS/RO (Step 26) Check Swing Charger NK26 - Available CRS/RO (Step 27)Transfer Swing Charger NK26 to Alt Pwr Supply CRS/RO (Step 28) Charge Batteries NK12 or NK14 (Step 29) Review Applicable Tech Specs - Attachment G CRS Tech Spec 3.8.1, AC Sources - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Tech Spec 3.8.4, DC Sources - 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> - most limiting CRS (Step 30) Perform Notifications per ODP-ZZ-00001, Add 13

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 2 Page 14 of 27 Event

Description:

Loss of ESF Bus NB02 Lockout Time Position Applicants Actions or Behavior (Step 31) Check ANN 21A - Extinguished CRS/RO RNO - Direct EM to repair faults At the Discretion of the Lead Examiner Move to the next Event at step 17

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 3 Page 15 of 27 Event

Description:

Atmospheric Steam Dump A Fails OPEN Time Position Applicants Actions or Behavior Following this, the controlling Steam Dump Valves fail open. The operator will respond in accordance with OTO-AB-00001, Steam Dump Malfunction. The operator will be required to close the valve manually to control and stop the cooldown.

Booth Operator Instructions:

• Following an update brief by the crew or As directed by the Lead Examiner

• Insert Malfunction (AB) ABPV0001_1, Value =1, ramp = 20 secs

• Act as Emergency Duty Officer and acknowledge the OTO/TS entry

• Act as I&C maintenance supervisor if requested to investigate the failure Indications Available:

ANN 109F SG PORV OPEN SG A Atmospheric Steam Dump Valve Indicates OPEN Pressurizer level decreases due to RCS cooldown Letdown may isolate on low Pressurizer level.

OTO-AB-00001, STEAM DUMP MALFUNCTION CRS Implement OTO-AB-00001, Steam Dump Malfunction RO (Step 1) CHECK Reactor Power - LESS THAN 100%

BOP (Step 2) CHECK At Least One SG ASD - FAILED OPEN (Step 3) Place affected SG ASD Controller in MANUAL and BOP Close the valve - AB PIC-1A BOP (Step 4) Notify Count Room Tech of Opening/Closing Times CRS (Step 5) GO TO Step 12 CRS (Step 12) INITIATE Actions to Repair the Failed Component.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 3 Page 16 of 27 Event

Description:

Atmospheric Steam Dump A Fails OPEN Time Position Applicants Actions or Behavior (Step 13) REVIEW Technical Specification 3.7.4, Condition A CRS Restore required ASD line to OPERABLE status within 7 days.

NOTE: Tech Spec associated with ASD Valves is valid for this condition.

CRS (Step 14) PLACE Inoperable Component In the EOSL.

(Step 15) RECORD Any Locked Valve Manipulations in the CRS Locked Valve Deviation Log Per ODP-ZZ-00004, Locked Component Control.

(Step 16) PERFORM Notifications Per ODP-ZZ-00001 CRS Addendum 13, Shift Manager Communications to Emergency Duty Officer.

CRS (Step 17) CHECK Failed Component Has Been Repaired.

(Step 17 RNO) WHEN the failed Component has been CRS repaired, THEN CONTINUE with this procedure.

At the Discretion of the Lead Examiner Move to next Event.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 17 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior After this, the RCS Thot RTD will fail and the rest of the events will sequence per timeline Booth Operator Instructions:

• Insert Malfunction (BB) BBTE0421A1, Value = 650

• When primary EO requested to locally open Reactor Trip Breakers Delete Malfunction SF006

• ON THE TRIP - Steam Generator Tube Rupture C, 250 gpm, 300 s ramp Insert Malfunction (BB) EBB01C, Value= 250, time delay = 10 sec, ramp = 300 secs, conditional of jcrftr eq true

• If asked to take radiation readings on the Main Steamlines, report that there is high radiation on 'C' steamline.

• If asked to isolate steam to TDAFP from SG C:

INSERT REMOTE FUNCTION (AB) ABV0087TASTEM, Value = 0

• Act as Emergency Duty Officer and acknowledge Site Emergency if and or when called Indications Available:

84B OTT RX TRIP (RED)

Implement E-0, Reactor Trip or Safety Injection CRS NOTE: Steps 1 through 4 are immediate actions.

E-0 (E-0, Step 1) Check Reactor Trip Rod Bottom Lights - All Lit Reactor Trip and Bypass Breakers - Open CRS/RO Neutron Flux - Lowering RNO - Manually Trip the Reactor.

If power > 5%, Go To FR-S.1, Response to Nuclear Power Generation/ATWS

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 18 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (FR-S.1 Steps) Implement CSF Status Tree Monitoring CAUTION: RCPs should NOT be tripped with reactor power CRS greater than 5%.

NOTE: Steps 1 and 2 are immediate action steps.

FR-S.1 (Step 1) Check Reactor Trip Rod Bottom Lights - All Lit Reactor Trip and Bypass Breakers - Open CRS/RO/

Neutron Flux - Lowering BOP RNO- Manually Trip the Reactor.

Insert Control Rods at the Maximum Rate Open supply breakers to PG19 and PG20 Critical Insert negative reactivity into the core by at least one of Task the following methods before completing immediate action steps of FR-S.1 CREW Deenergize PG19 and PG20 Insert Control Rods at the maximum rate Establish RCS emergency boration flow (Step 2) Check Turbine Trip CRS/BOP All Stop Valves - Closed RNO - Manually TRIP Turbine (Step 3) Check AFW Pumps Running CRS/BOP MDAFPs - Both running TDAFP - Running if necessary (Step 4) Initiate Emergency Boration of RCS At least one charging pump running Start boric acid transfer pumps Open BG HIS-8104 -NO POWER go to RNO CRS/RO Open BN HIS-112D and 112E Close BG HIS-112B and 112C Establish maximum charging flow

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 19 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 5) Check Containment Purge Isolation ESFAS status panel lit white for CPIS CRS/RO CAUTION: If an SI signal exists or occurs, Steps 1 through 10 of E-0, Reactor Trip or Safety Injection, should be performed, as manpower and time permits, while continuing with this procedure.

(Step 6) Check if the Following Trips Have Occurred Reactor Trip RNO - Locally trip breakers CRS/RO Will reclose the breakers for PG 19/20 if opened earlier Turbine Trip (Step 7) Check if the Reactor is Subcritical CRS/RO RNO - Go To Step 8 YES - Go To Step 16 (Step 8) Check Intact SG Levels NR level in at least one SG > 7% (25%)

CRS/BOP RNO - Check total feed flow > 527,000 lbm/hr Control SG level 7% (25%) - 52%

(Step 9) Check All Dilution Paths Isolated BG HS-25 set to OFF BG HIS-111A Closed CRS/RO BG HIS-27 set to OFF Zero flow on BG FI-385 Locally check BGV0183 Locked Closed Locally check BGV0187 Locked Closed

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 20 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 10) Check For Reactivity Addition From Uncontrolled RCS Cooldown RCS temperature lowering in uncontrolled manner CRS/RO Any SG pressure lowering in uncontrolled manner RNO- Stop any controlled cooldown Go to step 14 CRS/RO (Step 14) Check Core Exit TCs < 1200 °F (Step 15) Check Reactor Subcritical YES - Proceed with Step 16 RNO - Continue boration and return to step 4 CRS/RO CAUTION: Boration should continue to obtain adequate shutdown margin during subsequent actions.

CRS (Step 16) Return to procedure and step in effect (E-0, step 1)

(E-0) Implement E-0, Reactor Trip or Safety Injection, Step 1 CRS NOTE: Steps 1 and 2 are immediate action steps (Step 1) Check Reactor Trip Rod Bottom Lights - All lit CRS/RO Reactor Trip and Bypass Breakers - Open Neutron Flux - Lowering (Step 2) Check Turbine Trip CRS/BOP Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses At Least One Emergency Bus - Energized CRS/RO Both Emergency Buses - Energized (NB02 de-energized from earlier event should not attempt to restart EDG with lockout)

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 21 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 4) Check SI Status Actuated or Required Check both Trains of SI Actuated CRS/RO LOCA Sequencer ANN 30A - Lit LOCA Sequencer ANN 31A - Not Lit SB069 SI Actuate Red Light - Lit Solid (Step 5) Perform Attachment A, Automatic Action Verification, CRS/RO while continuing with this procedure E-0 Att A (Step A1) Check Charging Pumps - Both CCPs running BOP RNO - Start CCP A Stop NCP Critical Establish flow from at least one high head ECCS pump CREW Task before reporting E-0, Att. A complete.

BOP (Step A2) Check SI and RHR Pumps - All running BOP (Step A3) Check ECCS Flow - BIH flow indicated BOP (Step A4) Check ESW Pumps - Both Running (Step A5) Check CCW Alignment One pump running in each train Service loop supplied OPEN CCW To RHR HX valves BOP CLOSE SFP HX Outlet Valves STOP SFP Cooling Pumps Record time SFP Cooling Pump secured Monitor time CCW isolated to SFP HX (< 4 hrs)

BOP (Step A6) Check Ctmt Cooler Fans - Running in slow BOP (Step A7) Check Ctmt H2 Mixing Fans - Running slow

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 22 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior BOP (Step A8) Check if Containment Spray should be actuated BOP (Step A9) Check if Main Steamlines should be isolated (Step A10) Check ECCS Valves - Proper emergency BOP alignment as indicated on ESFAS status panel BOP (Step A11) Check CIS-A - ESFAS status panel BOP (Step A12) Check SG Blowdown Isolation - ESFAS panel (Step A13) Check Both Trains of Control Room Ventilation BOP Isolation - ESFAS status panel (Step A14) Check Containment Purge Isolation - ESFAS status BOP panel (Step A15) Notify CRS of failed equipment status, manual BOP actions taken, and attachment completion E-0 CRS/BOP (E-0 Step 6) Check Generator Output Breakers - Open (Step 7) Check Feedwater Isolation Main Feedwater Pumps - Tripped CRS/BOP Main Feedwater Reg Valves - Closed Main Feedwater Reg Bypass Valves - Closed Feedwater Isolation Valves - Closed (Step 8) Check AFW Pumps CRS/BOP MD AFW Pumps - Both Running (B no power)

TD AFW Pump - Running if Necessary

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 23 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 9) Check AFW Valves - Proper Alignment MD AFP Flow Control Valves - Throttled CRS/BOP TD AFP Flow Control Valves - Full Open AFW may be isolated to SG C per foldout page CRS/BOP (Step 10) Check Total AFW Flow > 355,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves PZR PORVs - Closed CRS/RO PZR PORVs - Both in AUTO PORV Block Valves - Both Open Normal PZR Spray Valves - Closed Note Seal Injection flow should be maintained to all RCPs (Step 12) Check if RCPs should be Stopped RCPs - Any Running CRS/RO ECCS Pumps - At least One Running RCS Pressure - Less than 1425 psig RNO - Go to step 13 (Step 13) Check RCS Temperatures CRS/RO RCPs Running - Tavg 557 Deg F No RCPs Running - Tcold 557 Deg F (Step 14) Check if any SG is Faulted Any SG pressure lowering uncontrollably CRS/BOP Any SG completely depressurized RNO - Go to step 15

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 24 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 15) Check if SG Tubes are Intact No SG NR level rising uncontrollably SG N16 radiation - Normal Condenser Air Removal radiation - Normal SG Blowdown and Sample radiation - Normal RNO - Go to E-3, Steam Generator Tube CRS/BOP Rupture NOTES:

Personnel should be available for sampling.

Seal injection flow should be maintained to RCPs.

Step 1 criterion applies until cooldown initiated.

E-3 (E-3 Step 1) Check if RCPs should be Stopped RCPs - any running CRS/RO ECCS Pumps - at least one running RCS Pressure - less than 1425 psig (Step 2) Identify Ruptured SG(s)

Unexpected rise in any SG NR level OR High radiation from any SG sample OR CRS/BOP High radiation from any SG steamline OR High radiation from any SG Blowdown line sample SG C is ruptured CAUTIONS:

-- If the TDAFP is the only available source of feed flow, steam supply to the TDAFP must be maintained from at least one SG

-- At least one SG must be maintained for RCS Cooldown

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 25 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior (Step 3) Isolate Flow From Ruptured SG(s)

Adjust ruptured SG ASD setpoint to 1160 psig Check ruptured SG ASD Closed Locally close ruptured SG TDAFP steam supply Check SG Blowdown Ctmt Iso Closed Close steamline low point drain Check if C-9 Interlock Lit Close MSIV - Fast close w/ EOP Addendum 35 Close All MSIV Bypass Valves CRS/BOP CAUTION: If any ruptured SG is faulted, feed flow to that SG should remain isolated during subsequent recovery actions unless needed for RCS cooldown AB PIC-3A Locally close ABV0087 BM HIS-3A AB HIS-7 SIM Simulator Operator Close ABV0087 OPER Insert Remote Function (AB) ABV0087TASTEM, Value = 0 (Step 4) Check Ruptured SG(s) Level NR level > 7% (25%)

Stop feed flow to ruptured SG CRS/BOP Close MDAFP flow control valve Close TDAFP flow control valve AL HK-11A AL HK-12A Critical Isolate feedwater flow into and steam flow from SG C CREW Task before a transition to ECA-3.1 occurs CAUTION: Major steam flow paths from the ruptured SG should be isolated before initiating RCS cooldown CRS/RO (Step 5) Check Ruptured SG(s) Pressure > 340 psig

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 rev. 4 Event # 4, 5, 6, and 7 Page 26 of 27 Event

Description:

RCS Thot RTD Failure, ATWS, SGTR, CCP Auto Start Failure Time Position Applicants Actions or Behavior CAUTION: If RCPs are NOT running, the following steps may cause a false CSF-1, Fig 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 (Step 6) Initiate RCS Cooldown Check RCS pressure < 1970 psig Block Steamline Pressure SI Determine required core exit temperature CRS/BOP Dump steam to condenser from intact SGs at max rate AB PK-507 manual at zero output AB US-500Z in STM PRESS position AB PK-507 adjusted for maximum Cooldown RNO - Manually or locally Dump Steam using ASDs END OF SCENARIO

OG RO OG BOP N TODAY RO BOP Shift Date Review/Complete Prior to Relieving the Watch:

• URO Logs

• Annunciator Test

• Plant Status Control Log

• Control Board Walkdown

• Standing/Night Orders

• Status Panel Horns A Train Protected Plant Status: Mode 1 Gross Gen Load: 1306 MWe Reactor Power: 100% Load Limit Pot 8.65 Rod movement: None Circ. Pump Setback: DISABLE Boration: 0 gallons Cation Bed Run: 20 min Dilution 80 gallons C/T valves: Normal Equipment OOS or WPA B MDAFP Out of Service for an oil change. Scheduled for completion on the PM shift Information Reduce Power to 95% for Main Turbine Valve testing.

Equipment Burdens and Workarounds Review/Complete After Relieving the Watch:

• CARs Applicable to Operations

• Indicating Lights/Chart Recorders

CRS WATCH RELIEF CHECKLIST Off-going Supervisor CR Supervisor Nights Today Name Shift Date Oncoming Supervisor review or perform the following:

• Control Board Walk

• Night Orders/Standing Orders

• EOSL Turnover Report down

• AUTO LOG

• Temp Mod Log / Plant Status Control Log

• WPA

• Shift Brief Items to Cover: New Night / Standing Orders, Work for the Shift & Dose (Budget vs. Actual)

RCS Makeup: RODS:

Cation Bed Run:

80 gal dilution D@ 215 20 min RCS: 966 ppm (sample) A CCP: 976 ppm B CCP: 986 ppm PROTECTED TRAIN: A CDF: 3.94 E-5 LERF: 5.62 E-7 Industrial Safety Focus Area: Ensure good Pre-Job Briefs are conducted OPS DOSE HUP Site Focus Area: Two Minute Drill - Keep the BIG Picture Actual: 1.6 mrem HUP OPS Focus Area: Precise Communications Budget: 13.0 mrem CURRENT ISSUES:

B MDAFP Out of Service for an oil change. Scheduled for completion on the PM shift.

Tech Spec 3.7.5, Condition C 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ONGOING ITEMS:

Reduce Power to 95% for Main Turbine Valve testing Review or complete after relieving the watch:

• CARS Applicable to Ops (CTSN 5468)

• Highlights of Weekly Schedule Oncoming Supervisor: ______________________________________ _____________________

Name Time Page 1 of 1 ODP-ZZ-00003

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 3 rev. 4 Op Test No.:

Examiners: Operators:

Initial Conditions: The following is the plant /equipment status:

• 100% steady state power

• CCW Pump A OOS. (Activate Lesson eg01a.lsn)

TS 3.7.7 Info Only Turnover:

Event Malf. No. Event Event No. Type* Description 1 ABPT0507 I (BOP, SRO) Steam Header Pressure Channel Failure Low Insert Malfunction (AB) ABPT0507, Value = 0, ramp = 60 secs 2 BBLT0460_1 I (RO) Pressurizer Level Channel 460 Failure Low I-TS-SRO Insert Malfunction BBLT0460_1, Value = 0, ramp = 15secs 3 JNN2XFR C-TS-SRO NN12 Inverter Trouble/Transfer Insert Remote Function (NN) JNN2XFR, Value = Bypass CVT 4 BBPCV0455 C (RO, SRO) Stuck Open PZR Spray Valve Imf (BB) BBPCV0455C_2, Value = 0.3 5 AB001_B M (All) Steam Line Break Inside Containment Insert Malfunction (AB) AB001_B, Value = 750000, ramp =

30 secs, condition of jcftr eq true 6 JINHBSLIS C (BOP, Steam Line Isolation Signal Failure SRO) Insert Remote Function (SB) JINHBSLIS, Value = Both

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

Scenario Event Description NRC Scenario 3 rev. 4 Callaway 2009 NRC Scenario #3 The plant is operating at 100%, steady state power. CCW Pump A is Out of service pump bearing replacement. A 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> pump run will take place following maintenance.

Main Steam header pressure transmitter ABPT507 fails low, resulting in lowering Main Feedwater Pump speed and lowering SG levels. The crew should identify the failure and take manual control of Main Feedwater Pump speed to stabilize SG levels in accordance with OTO-AB-00004, Steam Header/Feedwater Header Pressure Channel Failure.

Following the ABPT507 failure, Pressurizer Level Channel 460 fails low. The crew should respond per OTO-BG-00001, Pressurizer Level Control Malfunctions, and restore PZR level. Technical Specification 3.3.1 applies.

NN12 inverter will fail and transfer to the Bypass Constant Voltage Transformer.

Technical Specification 3.8.7 applies. The Control Room Supervisor should identify the TS requirement to restore the inverter to operable status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Pressurizer Spray valve BB PCV-455C fails to 30% open. After attempts to close the spray valve and restore Pressurizer Pressure using Pressurizer Backup Heaters, the crew should trip the reactor and secure RCPs B and D, since these supply spray flow.

Immediately upon the reactor trip, a steam line break occurs on SG B inside Containment. The crew should continue the actions of E-0, Reactor Trip or Safety Injection, following the Safety Injection.

The Main Steamline Isolation Valves will fail to automatically close in response to the Low Steam Line Pressure. The crew should manually isolate the Main Steamlines and complete the isolation of SG B in accordance with E-2, Faulted S/G Isolation.

The crew should then transition to ES-1.1, SI Termination. The scenario is complete when the Boron Injection Header is isolated.

Scenario Event Description NRC Scenario 3 rev. 4 Critical Tasks:

Event #7 CT - Fast close MSIVs before a severe challenge develops to either subcriticality or Integrity CSFs or before transition to ECA-2.1.

Event #6 CT - Isolate SG B before a transition out of E-2 MSIV Closed AFW Isolated from SG B References OTO-AB-00004 OTA-RK-00016 Addendum 26B OTO-NN-00001 OTO-BB-00006 OTO-BG-00001 E-0 E-2 ES-1.1 CSF-1, Attachment A EIP-ZZ-00101

Scenario Event Description NRC Scenario 3 rev. 4 Scenario Setup Guide:

Establish the initial conditions of IC-11, MOL 100% power:

• RCS boron concentration 966 ppm

• CCP A 976 ppm minus 5 days

• CCP B 986 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• CCW Pump A OOS. TS 3.7.7 Info Only

• ENSURE BB LT-460 is selected for Control

=======SCENARIO SETUP ITEMS==========

Remove CCW Pump A from service

• Run Lesson eg01a.lsn Steam Line Break inside containment actuates on Reactor Trip

• Insert Malfunction (AB) AB001_B, Value = 750000, ramp = 30 secs, condition = jcftr eq true Steam Line Isolation Signal Failure

• Insert Remote Function (SB) JINHBSLIS, Value = Both

=======EVENT 1 ===============

ABPT507 fails to 0 psig over 60 sec

• Insert Malfunction (AB) ABPT0507, Value = 0, ramp = 60 secs

=======EVENT 2 ===============

Pressurizer Level Channel 460 Fails Low over 15 secs

• Insert Malfunction BBLT0460_1, Value = 0, ramp = 15 secs

=======EVENT 3 ===============

NN12 Inverter Trouble/Transfer

• Insert Remote Function (NN) JNN2XFR, Value = Bypass CVT

=======EVENT 4 ===============

Stuck open PZR Spray Valve Insert Malfunction (BB) BBPCV0455C_2, Value =0.3

=======EVENT 5 PRELOADED===============

Steam Line Break inside containment actuates on Reactor Trip

• Insert Malfunction (AB) AB001_B, Value = 750000, ramp = 30 secs, condition = jcftr eq true

=======EVENT 6 PRELOADED===============

Steam Line Isolation Signal Failure

• Insert Remote Function (SB) JINHBSLI, Value = Both

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 1 Page 5 of 25 Event

Description:

Steam Header Pressure Channel Failure Low Time Position Applicants Actions or Behavior Upon Lead Examiner Cue Booth Operator Instructions

• T = 2 minutes

• Insert Malfunction (AB) ABPT0507, Value = 0, ramp = 60 secs

• When contacted, respond as I&C. Acknowledge the request to investigate the instrument failure.

• When contacted, respond as EDO. Acknowledge entry into the OTO.

Indications Available:

108 - 111 D SG FLOW MISMATCH OTO-AB-00004, Steam Header/Feedwater Header Pressure Channel Failure CRS Implement OTO-AB-00004 (Step 1) Check Steam HDR/FW Pressure Indicator - Indicating Significantly Different than existing Plant Conditions RO

• AB PI-507 (red needle)

• AB PI-507 (green needle)

(Step 2) CHECK Main feed Pump Speed - Changing Due to BOP Failed Channel (Step 3) Place GE Main Feed Pump Turbine control transfer switch in Manual BOP

• FC HIS-88

• FC HIS-188

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 1 Page 6 of 25 Event

Description:

Steam Header Pressure Channel Failure Low Time Position Applicants Actions or Behavior Note: Normal indication is not valid and DP must be determined by comparing Feed Pressure to the Steam Generator Pressure (Step 4) Control Main Feed Pump Turbine speed to restore BOP Programmed Feedwater D/P (Step 5) CHECK Steam Header Pressure Channel - Failed BOP AB PI-507 (red needle)

(Step 6) CHECK Steam Dump Control - In Steam Pressure Mode - NO BOP RNO - Place AB PK-507 in Manual. Demand at Zero Go to step 10 CRS (Step 10) Initiate Actions to Repair Failed Component CRS (Step 11) Perform Notifications to the EDO CRS (Step 12) Go To Appropriate Plant Procedure At the Discretion of the Lead Examiner Move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 2 Page 7 of 25 Event

Description:

Pressurizer Level Channel 460 Failure Low Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 20minutes

• Insert Malfunction (BB) BBLT0460_1, Value = 0, ramp = 15 secs

• When contacted, respond as I&C. Acknowledge the request to investigate the instrument/channel failure.

• When contacted, respond as EDO. Acknowledge entry into the OTO.

Indications Available:

ANN 32B, PZR 17% HTRS OFF LTDN ISO OTO-BG-00001, Pressurizer Level Control Malfunctions CRS Implement OTO-BG-00001, Pressurizer Level Control Malfunctions NOTE: Letdown isolates and Pressurizer control heaters will deenergize if the controlling level channel fails low.

(Step 1) Check For Failed Pressurizer Level Indicator (BB-LI-460 RO failed low)

(Step 2) Transfer Pressurizer Level Control Selector to Remove RO Failed Channel From Control (Step 3) Check Letdown - In Service RNO - Slowly close BG HC-182 Throttle BG FK-124 for 8-13gpm seal injection Ensure BG HC-182 is full closed Ensure BG HIS-8152 and 8160 are open RO Ensure BG HIS-459 and 460 are open Throttle BG HC-182 to establish 85-90 gpm Place BG PK-131 in manual and 75% open Open orifice isolation valves for desired flow Adjust BG PK-131 to obtain 300-350 psig Adjust charging flow to maintain PZR level

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 2 Page 8 of 25 Event

Description:

Pressurizer Level Channel 460 Failure Low Time Position Applicants Actions or Behavior (Step 4) Check PZR Heater Control Group C - On (NO)

RO RNO - Energize Pressurizer Heater Control Group C Figure 1, Programmed PZR Level, may be used to determine Note Pressurizer Level program control band RO (Step 5) Check PZR Level - Trending to or at program level (Step 6) Check Operable PZR Level Channel - USED FOR RO RECORDER (Step 7) Review Applicable Tech Specs, Attachment H CRS 3.3.1, Table 3.3.1-1 Item 9 Condition M, Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

CRS (Step 8) Review Attachment A, Effects of Failure CRS (Step 9) Perform Notifications per ODP-ZZ-00001, ADD 13 (Step 10) Direct I&C to Trip Protective Bistables - Attachment C for CRS LT-460 CRS (Step 11) Place BB LT-460 in the EOSL CRS (Step 12) Initiate Action to Repair BB LT-460 At the Discretion of the Lead Examiner Move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 3 Page 9 of 25 Event

Description:

NN12 Inverter Trouble/Transfer Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 10 minutes

• Insert Remote Function (NN) JNN2XFR, Value = Bypass CVT

• When contacted, respond as secondary OT. Report that the static transfer switch has transferred to the alternate supply and the P202 light is illuminated.

• In addition, there is a faint smell of something hot, but no smoke and no fire is present.

• The Inverter DC Input (B1) breaker and Inverter Output (B2) breaker are tripped. The Undervoltage on DC Input alarm is illuminated.

• If Work Control is contacted, report investigation and repair of NN12 will begin immediately.

• When as EDO. Acknowledge entry into the OTO and Tech Spec entry.

Indications Available:

26 B NN12 INV TRBL/XFR OTA-RK-00016, Addendum 26B BOP Implement OTA-RK-00016, Addendum 26B Add 26B (Step 3.1) Refer to OTO-NN-00001, Loss of Safety Related Inst CRS/RO Power OTO-NN (Step 1) Check the following Annunciators - Extinguished RO 25 A - 28 A, NN Bus UV CRS (Step 2) Exit this procedure CRS Return to OTA-RK-00016, Addendum 26B Add 26B (Step 3.2) IF NK02 bus voltage indicates zero volts, Refer to CRS/BOP OTO-NK-00002, Loss of Vital 125 VDC Bus - NO

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 3 Page 10 of 25 Event

Description:

NN12 Inverter Trouble/Transfer Time Position Applicants Actions or Behavior (Step 3.3) Check the following computer points to determine cause of the alarm CRS/BOP NNU0003A, 1E INV NN12 XFER TO ALT SPLY NNU0003B, 1E INV NN12 LOCAL TROUBLE (Step 3.4) If NNU0003A is in alarm, Direct OT to check the CRS/BOP static transfer switch transferred to bypass source (P202 lit)

(Step 3.5) If NNU0003B is in alarm, Direct OT to check local CRS/BOP alarms and reset as required CRS (Step 3.6) Refer to OTS-NN-00012 for additional information BOP (Step 3.7) Dispatch OT to investigate for abnormal conditions (Step 3.8) Refer to TS LCO 3.8.7, Condition A - Inverters -

CRS Operating Restore inverter to Operable within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> At the Discretion of the Lead Examiner Move to Events #4, 5, and 6.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 11 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior Booth Operator Instructions

• T = 45 minutes

• Insert Malfunction(BB) BBPCV0455C_2, Value =0.3

• When contacted, respond as EDO to acknowledge the Spray valve failure and plant trip.

Indications Available:

33 C PZR PRESS LO HTRS ON OTO-BB-00006, Pressurizer Pressure Control Malfunction Implement OTO-BB-00006, Pressurizer Pressure Control CRS Malfunction (Step 1) Check Pressurizer Pressure Indicator - Failed RO RNO - Go to step 17 RO (Step 17) Check Pressurizer Pressure less than 2235 psig (Step 18) Check Both Pressurizer Spray Valves - Closed RNO - Manually close the affected spray valve Energize backup heaters If pressure continues to lower, Manually Trip the Reactor RO Ensure the Main Turbine is Tripped If BB PCV-455C cannot be closed, Stop RCP B and RCP D Perform E-0, Rx Trip or SI If pressure continues to lower, stop all but 1 RCP

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 12 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior Booth Operator Instructions

• Immediately following Reactor Trip

• Insert Malfunction (AB) AB001_B, Value = 750000, ramp = 30 secs, condition =

jcftr eq true - SHOULD BE PRELOADED

• When contacted, respond as EDO to acknowledge the Spray valve failure and plant trip.

• If contacted as Chemistry acknowledge sampling SG

• If asked as Primary OT to close SG B steam supply to TDAFP, ABV0085 - use remote function (AB) ABV0085TASTEM, value = 0 Indications Available:

60 A/B CTMT SUMP LEV HI 88 F MANUAL RX TRIP E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection NOTE Steps 1 through 4 are immediate actions E-0 (Step 1) Check Reactor Trip Rod Bottom Lights - All Lit RO Reactor Trip and Bypass Breakers - Open Neutron Flux - Lowering (Step 2) Check Turbine Trip BOP Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses BOP At Least One Emergency Bus - Energized Both Emergency Buses - Energized

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 13 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior (Step 4) Check SI Status Actuated or Required Manually Actuate SI (If not actuated)

RO Check both Trains of SI Actuated LOCA Sequencer ANN 30A - Lit LOCA Sequencer ANN 31A - Lit SB069 SI Actuate Red Light - Lit Solid (Step 5) Perform Attachment A, Automatic Action RO/BOP Verification, while continuing with this procedure E-0 Att A (Step A1) Check Charging Pumps - Both CCPs running RO/BOP 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

• Red Train:

• EG HIS-21 or EG HIS-23

• Yellow Train:

• EG HIS-22 or EG HIS-24

• CCW Service Loop Supply and Return valves for one operating CCW pump - OPEN

• EG ZL-15 AND EG ZL-53 OR

• EG ZL-16 AND EG ZL-54

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 14 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior

• OPEN CCSW To RHR HX valves:

• EG HIS-101

• EG HIS-102

• CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EG HIS-101

• EG HIS-102

• CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EC HIS-11

• EC HIS-12

• STOP Spent Fuel Pool Cooling Pump(s):

• EC HIS-27

• EC HIS-28

• RECORD The Time Spent Fuel Pool Cooling Pump Secured

• MONITOR Time Since CCW Flow Isolated to SFP HX LESS THAN 4 HOURS (Step A6) CHECK Containment Cooler Fans - RUNNING IN RO/BOP SLOW SPEED

• GN HIS-9

• GN HIS-17

• GN HIS-5

• GN HIS-13 (Step A7) CHECK Containment Hydrogen Mixing Fans -

RO/BOP RUNNING IN SLOW SPEED

• GN HIS-2

• GN HIS-4

• GN HIS-1

• GN HIS-3

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 15 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior RO/BOP (Step A8) CHECK If Containment Spray should Be Actuated:

• CHECK the following:

• Containment pressure - GREATER THAN 27 PSIG OR

• GN PR-934 indicates containment pressure - HAS BEEN GREATER THAN 27 PSIG OR

• Annunciator 59A CSAS LIT OR

• Annunciator 59B CISB - LIT

• Containment Spray Pumps -

• EN HIS-3

• EN HIS-9

• ESFAS status panels CSAS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• ESFAS status panels CISB sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• ESFAS status panels CISB sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• STOP all RCPs RO/BOP (Step A9) CHECK If Main Steamlines Should Be Isolated:

• CHECK for any of the following:

• Containment pressure - GREATER THAN 17 PSIG OR

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 16 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior

• GN PR-934 indicates containment pressure - HAS BEEN GREATER THAN 17 PSIG OR

• Steamline pressure - LESS THAN 615 PSIG OR

• AB PR-514 or AB PR-535 indicates steamline pressure

- HAS BEEN LESS THAN 615 PSIG

• CHECK MSIVs and Bypass valves - CLOSED (Step A10) CHECK ECCS Valves - PROPER EMERGENCY RO/BOP ALIGNMENT

• ESFAS status panels SIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A11) CHECK Containment Isolation Phase A:

• ESFAS status panels CISA sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A12) CHECK SG Blowdown Isolation:

• ESFAS status panels SGBSIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation RO/BOP Isolation:

• ESFAS status panels CRVIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 17 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior RO/BOP (Step A14) CHECK Containment Purge Isolation:

• ESFAS status panels CPIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A14 RNO) Manually ACTUATE CPIS:

• SA HS-11

• SA HS-15 IF CPIS damper(s) are NOT closed, THEN manually CLOSE damper(s) as necessary RO/BOP (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

E-0, REACTOR TRIP OR SAFETY INJECTION E-0 (Step 6) Check Generator Output Breakers - Open BOP (Step 7) Check Feedwater Isolation Main Feedwater Pumps - Tripped BOP Main Feedwater Reg Valves - Closed Main Feedwater Reg Bypass Valves - Closed Feedwater Isolation Valves - Closed (Step 8) Check AFW Pumps BOP MD AFW Pumps - Both Running TD AFW Pump - Running if Necessary

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 18 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior (Step 9) Check AFW Valves - Proper Alignment MD AFP Flow Control Valves - Throttled BOP TD AFP Flow Control Valves - Full Open (AFW may be isolated to SG B per foldout page)

BOP (Step 10) Check Total AFW Flow > 355,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves PZR PORVs - Closed PZR PORVs - Both in AUTO RO PORV Block Valves - Both Open Normal PZR Spray Valves - Closed RNO - If BB PCV-455C cannot be closed, Stop RCP B and RCP D (Step 12) Check if RCPs should be Stopped RCPs - Any Running ECCS Pumps - At least One Running RO RCS Pressure - Less than 1425 psig YES - Stop all RCPs RNO - Go To Step 13 (Step 13) Check RCS Temperatures RO RCPs Running - Tavg 557 Deg F No RCPs Running - Tcold 557 Deg F (Step 14) Check if any SG is Faulted Any SG pressure lowering uncontrollably RO/BOP Any SG completely depressurized Go To E-2, Faulted SG Isolation

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 19 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior E-2, FAULTED STEAM GENERATOR ISOLATION Initiate CSF Monitoring CAUTION At least one SG must be maintained available for RCS cooldown CAUTION Any faulted SG or secondary break should remain isolated during subsequent recovery unless needed for RCS cooldown E-2 BOP/RO (Step 1) CHECK MSIVs and Bypass Valves - CLOSED Critical Fast close MSIVs before a severe challenge develops to Task CREW either subcriticality or Integrity CSFs or before transition to ECA-2.1 (Step 2) CHECK If Any SG Secondary Pressure Boundary Is BOP/RO Intact:

• CHECK pressures in all SGs - ANY STABLE OR RISING BOP/RO (Step 3) Identify Faulted Steam Generator:

• Check Pressures in all SGs:

• ANY SG PRESSURE LOWERING IN AN UNCONTROLLED MANNER OR

• ANY SG COMPLETELY DEPRESSURIZED BOP/RO (Step 4) ISOLATE Faulted SG(s):

• ISOLATE AFW flow to faulted SG(s):

• CLOSE associated MD AFP Flow Control Valve(s)

• AL HK-8A (SG A)

• AL HK-10A (SG B)

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 20 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior

• AL HK-12A (SG C)

• AL HK-6A (SG D)

• CHECK ASD from faulted SG(s) - CLOSED

• AB PIC-1A (SG A)

• AB PIC-2A (SG B)

• AB PIC-3A (SG C)

• AB PIC-4A (SG D)

• Locally CLOSE TDAFP Steam Supply From Main Steam Loop Manual Isolation valve from Faulted SG:

• ABV0085 (SG B)

BOOTH INSTRUCTOR NOTE: When directed by operator, Use Remote Function (AB) ABV0085TASTEM to close ABV0085.

• CHECK Main Feedwater valves to faulted SG(s) -

BOP/RO CLOSED BOP/RO CHECK Main Feedwater valves to faulted SG(s) CLOSED

• Main Feedwater Reg Valve:

• AE ZL-510 (SG A)

• AE ZL-520 (SG B)

• AE ZL-530 (SG C)

• AE ZL-540 (SG D)

• Main Feedwater Reg Bypass valve:

• AE ZL-550 (SG A)

• AE ZL-560 (SG B)

• AE ZL-570 (SG C)

• AE ZL-580 (SG D)

• Feedwater Isolation Valve:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 21 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior

• AE HIS-39(SG A)

• AE HIS-40 (SG B)

• AE HIS-41 (SG C)

• AE HIS-42 (SG D)

• CHECK SG Blowdown Containment Isolation Valve from faulted SG(s) - CLOSED

• BM HIS-1A (SG A)

• BM HIS-2A (SG B)

• BM HIS-3A (SG C)

• BM HIS-4A (SG D)

• CLOSE Steamline Low Point Drain valve from faulted SG(s):

• AB HIS-9 (SG A)

• AB HIS-8 (SG B)

• AB HIS-7 (SG C)

• AB HIS-10 (SG D)

Critical Isolate the Faulted Steam Generator Before Transition out Task of E-2.

CREW

• MSIV Closed

• AFW ISOLATED to SG B (Step 5) CHECK CST To AFP Suction Header Pressure -

BOP/RO GREATER THAN 2.75 PSIG NOTE Subsequent actions should NOT be delayed while awaiting SG sampling. Sampling of the SGs is repeated in E-1, Loss of Reactor or Secondary Coolant.

BOP/RO (Step 6) CHECK Secondary Radiation:

• PERFORM the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 22 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior

• 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.

• CHECK unisolated secondary radiation monitors:

• SG Sample radiation:

• SJL 026

• SG ASD radiation:

• AB RIC-111 (SG A)

• AB RIC-112 (SG B)

• AB RIC-113 (SG C)

• AB RIC-114 (SG D)

• Turbine Driven Auxiliary Feedwater Pump Exhaust radiation:

• FC RIC-385

• Secondary radiation - NORMAL RO (Step 7) Check if ECCS Flow Should Be reduced:

• RCS Subcooling - Greater Than 30oF.

• Secondary Heat Sink:

• NR Level in at least One SG > 7%

OR

• Total Feedflow to intact SGs > 355,000 lbm/hr.

• RCS Pressure - Stable or Rising.

• Pzr Level > 9%.

CAUTION If offsite power is lost after SI reset, manual actions may be required to restart safeguards equipment

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 3 rev. 4 Event # 4, 5, and 6 Page 23 of 25 Event

Description:

PZR Spray Valve Failure, Steam line Break I/S Cntmt, SLIS failure Time Position Applicants Actions or Behavior RO (Step 8) Reset SI

• SB HS-42A

• SB HS-43A RO (Step 9) Stop all but one CCP:

• BG HIS-1A OR

• BG HIS-2A CRS Go to ES-1.1, SI Termination, Step 3.

ES-1.1, SI Termination ES-1.1 RO (Step 3) Reset CIS-A and CIS-B BOP (Step 4) Establish Instrument Air to Containment RO (Step 5) Check RCS Pressure - Stable or Rising (Step 6) Isolate Boron Injection Header CCP - Suction aligned to RWST Reset CCP Recirc Valves BG HS-8110 and BG HS-8111 Check CCP Recirc Valves Open RO BG HIS-8110 and BG HIS-8111 Close BIH Inlet Valves EM HIS-8803A and EM HIS-8803B Close BIH Outlet Valves EM HIS-8801A and EM HIS-8801B Once the crew enters ES-1.1 Scenario is complete. - Freeze the Simulator

OG RO OG BOP N TODAY RO BOP Shift Date Review/Complete Prior to Relieving the Watch:

• URO Logs

• Annunciator Test

• Plant Status Control Log

• Control Board Walkdown

• Standing/Night Orders

• Status Panel Horns B Train Protected Plant Status: Mode 1 Gross Gen Load: 1306 MWe Reactor Power: 100% Load Limit Pot 8.65 Rod movement: None Circ. Pump Setback: DISABLE Boration: 0 gallons Cation Bed Run: 20 min Dilution 80 gallons C/T valves: Normal Equipment OOS or WPA A CCW Pump OOS for pump bearing replacement.

Information Maintain steady state power.

Equipment Burdens and Workarounds Review/Complete After Relieving the Watch:

• CARs Applicable to Operations

• Indicating Lights/Chart Recorders

CRS WATCH RELIEF CHECKLIST Off-going Supervisor CR Supervisor Nights Today Name Shift Date Oncoming Supervisor review or perform the following:

• Control Board Walk down

• Night Orders/Standing Orders

• EOSL Turnover Report

• AUTO LOG

• Temp Mod Log / Plant Status Control Log

• WPA

• Shift Brief Items to Cover: New Night / Standing Orders, Work for the Shift & Dose (Budget vs. Actual)

RCS Makeup: RODS:

Cation Bed Run:

80 gal dilution D@ 215 20 min RCS: 966 ppm (sample) A CCP: 976 ppm B CCP: 986 ppm PROTECTED TRAIN: B CDF: 4.03 E-5 LERF: 4.62 E-7 Industrial Safety Focus Area: Ensure good Pre-Job Briefs are OPS DOSE conducted HUP Site Focus Area: Two Minute Drill - Keep the BIG Picture Actual: 1.6 mrem HUP OPS Focus Area: Precise Communications Budget: 13.0 mrem CURRENT ISSUES:

A CCW Pump Out of Service for pump bearing replacement.

Tech Spec 3.7.7, Info Only ONGOING ITEMS:

Maintain Steady State Power Review or complete after relieving the watch:

• CARS Applicable to Ops (CTSN 5468)

• Highlights of Weekly Schedule Oncoming Supervisor: ______________________________________ _____________________

Name Time Page 1 of 1 ODP-ZZ-00003

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 4 rev. 4 Op Test No.:

Examiners: Operators:

Initial Conditions: The following is the plant /equipment status:

• 80% Power for last 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> due to Chemistry concerns

• PBG05B (B CCP) OOS for coupling lubrication and alignment check and oil change. Work should be complete in 4 to 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. (Actuate lesson bg01b.lsn)

TS 3.5.2, Cond A, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Turnover:

Event Malf. No. Event Type* Event No. Description A R (RO) Increase power to 100%

N (SRO/BOP) 1 AELT0551 I (BOP) SG Level Channel Failure to 75%

I - TS - SRO Insert Malfunction (AE) AELT0551, Value = 75 , ramp over 1 minute 2 BBPT0455 I (RO) Pressurizer Pressure Channel Failure High I - TS - SRO Insert Malfunction (BB) BBPT0455, Value = 2500, ramp over 10 secs 3 ACPT0506 I (All) Turbine Impulse (1st Stage) Pressure Channel Failure Insert Malfunction (AC) ACPT0506, Value = 0 4 EBB01B M (All) SG B Tube Leak/Rupture Insert Malfunction (BB) EBB01B, Value = 15 5 CEPV0013 C (BOP/SRO) Loss of Stator Cooling Water - Manual Turbine Trip Insert Malfunction (CE) CEPV0013_C, Value = True Modify Malfunction (BB) EBB01B, Value = 450, ramp over 300 secs 6 SA C (BOP) FWIV Auto Closure Failure (IN SETUP)

Insert Remote Function (SA) LOASAS10XX_2, Value =

Fail 7 EF C (BOP) ESW Pump Auto Start Failure (IN SETUP)

Insert Remote Function (EF) JLOASASBI8_11, Value =

Inhibit 8 AB002_B M (All) Faulted SG outside Containment w/existing SGTR Insert Malfunction (AB) AB002_B, Value = 750,000, ramp over 20 secs

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

Scenario Event Description NRC Scenario 4 rev. 4 Callaway 2009 NRC Scenario #SB The plant is at 80% power BOL and has been for the last 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for Chemistry cleanup.

Centrifugal Charging Pump B is out of service for preplanned maintenance. Work includes coupling lubrication and alignment check and oil change. Work should be completed in 4 to 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. Shift direction is to increase power to 100%. Once the dilution and power increase has begun, proceed with scenario.

A circuit card failure causes SG A controlling level channel to slowly fail to 75%. The crew should take actions per OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions. Tech Specs 3.3.1 should be applied and I&C contacted to trip bistables and troubleshoot.

Pressurizer Pressure Channel BB PT-455 fails high, causing spray valves to open and pressurizer heaters to turn off. The crew should respond per OTO-BB-00006, Pressurizer Pressure Control Malfunction, and stabilize pressurizer pressure.

Turbine Impulse Pressure Channel AC PI-506 fails low. The crew should respond per OTO-AC-00003, Turbine Impulse Pressure Channel Failure, select an operable channel for control, reset C-7, and place the Condenser Steam Dumps in the Steam Pressure mode. TS 3.1.1 requires a permissive check within one hour.

A Tube Leak initiates on Steam Generator B. The crew should respond in accordance with OTO-BB-00001, Steam Generator Tube Leak. The tube leak will start out at 15 gpm.

Main Turbine Stator cooling water pressure control valve CEPV0013 fails closed. Attempts will be made to restore stator cooling by starting a second pump, but this will not help. The crew should trip the Reactor and trip the turbine due to being greater than 50% power (P-9). The SG Tube Leak will now be modified to build up to a value of 450 gpm following the Reactor Trip.

During trip recovery it will be determined that the S/G Tube leak is greater than 50 gpm by observing SG B level rising more rapidly. A manual or automatic safety injection will occur.

When the LOCA sequencer actuates, ESW Pump A fails to automatically start. The crew should manually start the pump. SG B Feedwater Isolation Valve does not close when a FWIS occurs.

The crew should manually close the valve.

When Feed Flow is isolated to SG B per the foldout page, a non-isolable steam break develops on SG B outside containment. The crew should transition to E-2, Faulted Steam Generator Isolation, from the foldout page. They should later enter E-3 and then transition to ECA-3.1, SGTR with LOCA Subcooled Recovery Desired.

Scenario Event Description NRC Scenario 4 rev. 4 Critical Tasks:

Event #7 CT - Establish ESW Train A cooling before a transition from E-0 Event #8 CT - Isolate the Faulted Steam Generator before Transition out of E-2 References OTO-AE-00002 OTO-BB-00006 OTO-AC-00003 OTO-BB-00001 E-0 E-3 E-2 ECA-3.1 CSF-1, Attachment A

Scenario Event Description NRC Scenario 4 rev. 4 Scenario Setup Guide:

Establish the initial conditions of IC-2, BOL 80% power:

• RCS boron concentration 1143 ppm

• CCP A 1116 ppm minus 15 days

• CCP B 1128 ppm minus 5 days

• Rod Control Bank D 174 steps, Other banks 228 steps

• NIS indicates 80%

• AC PT-506 is Selected for Control

• SG level channel 551 selected for control

• Place WPA on CCP B

=======SCENARIO SETUP ITEMS==========

Remove CCP B from service

• Run lesson bg01b.lsn FWIV Auto Closure Failure

• Insert Remote Function (SA) LOASAS10XX_2, Value = Fail ESW Pump Auto Start Failure

• Insert Remote Function (EF) JLOASASBI8_11, Value = Inhibit

=======EVENT 1 ===============

SG level channel 551 fails to 75% over a 60 sec ramp

• Insert Malfunction (AE) AELT0551, Value = 75, ramp over 1 minute

=======EVENT 2 ===============

Pressurizer Pressure Channel Fails High BB PT0455

• Insert Malfunction (BB) BBPT0455, Value = 2500 over 10 secs

=======EVENT 3 ===============

st Turbine Impulse (1 Stage ) Pressure Channel Failure Low

• Insert Malfunction (AC) ACPT0506, Value = 0

=======EVENT 4 ===============

SG B tube leak, 15 gpm,

• Insert Malfunction (BB) EBB01B, Value = 15

=======EVENT 5===============

Stator Cooling Water Turbine Runback / SG Tube Rupture

• Insert Malfunction (CE) CEPV0013_C, Value = True

• Insert Malfunction (BB) EBB01B, Value = 450, ramp over 300 secs

=======EVENT 6 ==============

FWIV B auto closure failure (IN SETUP)

• Insert Remote Function (SA) LOASAS10XX_2, Value = Fail

=======EVENT 7 ===============

ESW Pump Auto Start Failure (IN SETUP)

• Insert Remote Function (EF) JLOASASBI8_11, Value = Inhibit

=======EVENT 8 ===============

SG B steam break outside containment

• Insert Malfunction (AB) AB002_B, Value = 750,000, ramped over 20 secs

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # A Page 5 of 33 Event

Description:

Power Increase Time Position Applicants Actions or Behavior OTG-ZZ-00004, Power Operation CRS Implement OTG-ZZ-00004, Power Operation Step 5.2.10 Perform a Pre-Job Brief of power ascension:

• General strategy for proceeding to 100% Power.

• Any items not completed as expected to this point.

CRS

• Applicable Precautions and Limitations

• MFP and MFRV control status Discuss the use of Optional Parameter Alarms as an aid to avoid undesired challenges to legal or system requirements CRS/BOP Initiate a load increase at 10% per hour loading rate Turbine Load Control Steps Step 5.2.5 At EHC Panel LOADING RATE LIMIT %/MIN, PERFORM the following:

1. CHECK EHC Panel, DECREASE LOADING RATE ON, push button light LIT.

2. SELECT desired loading rate.

• Use 0.05 for 3%/hr.

• Use 0.166 for 10%/hr.

3. Using EHC Panel, LOAD INCREASE, pushbutton, INITIATE raising load.

Dilution Steps OTN-BG-00002, Attachment 6

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # A Page 6 of 33 Event

Description:

Power Increase Time Position Applicants Actions or Behavior Place BG HS-26, RCS M/U CTRL, in Stop Place BG HS-25, RCS M/U CTRL SEL, in DIL Reset BG FY-111B, Combined M/U & BA Flow Totalizer, to 000 Ensure BG FY-111B is set to deliver the desired amount of makeup water Place BG HS-26, RCS M/U CTRL, in Run When the desired amount of water has been added, Place HS-26, RCS M/U CTRL, in Stop Place BG HS-25, RCS M/U CTRL SEL, in Auto Place HS-26, RCS M/U CTRL, in Run Rod Control Steps 5.7.2 & 5.7.3 ESTABLISH Manual Rod Control as follows:

a. CHECK auto rod motion NOT required

b. ENSURE SE HS-9, ROD BANK AUTO/MAN SEL, is in MAN.

c. Using SF HS-2, MAN ROD CTRL switch, INSERT or WITHDRAW Control Rods to the desired position.

d. MONITOR the following for effects of the rod motion:

• TAVG

• Pressurizer pressure

• Pressurizer level

• Reactor power

e. WHEN Manual Rod Control is no longer ESTABLISH Automatic Rod Control as follows:

a. CHECK Reactor power greater than 30%.

b. CHECK SF ZL-2A, ROD DIRECT lights, NOT LIT:

• Green IN light

• Red OUT light

c. CHECK SF ZL-2B, ROD DIRECT DEMAND lights, NOT LIT:

• Green IN light

• Red OUT light

d. CHECK TAVG within + 1degree F of TREF.

e. ENSURE SE HS-9, ROD BANK AUTO/MAN SEL, is in AUTO.

f. CHECK Rod Control for proper response.

RO/BOP Commence raising reactor power to 100%

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # A Page 7 of 33 Event

Description:

Power Increase Time Position Applicants Actions or Behavior RO Dilute the RCS or withdraw rods to enable the power increase When the crew has demonstrated the ability to raise power OR At the Discretion of the Lead Examiner Move to Event #1.

Appendix D Operator Action Form ES-D-2 Op Test No.: N07-1 Scenario # 4 rev. 4 Event # 1 Page 8 of 33 Event

Description:

Steam Generator Level Channel Failure to 75%

Time Position Applicants Actions or Behavior Booth Instructions:

Insert Malfunction (AE) AELT0551, Value = 75, ramped in over 1 minute Indications Available REACTOR PARTIAL TRIP, Annunciator 83C SG A LEV DEV, Annunciator 108C SG A LEV LO, Annunciator 108B OTO-AE-00002, Steam Generator Water Level Control Malfunction Implement OTO-AE-00002, Steam Generator level Control CRS Malfunction (Step 1) Check SG feedwater Flow instrument Indication -

BOP Normal (Step 2) Check SG Steam Flow Instrument Indications -

BOP Normal.

(Step 3) Check SG Level Instrument Indications - Normal (NO)

BOP Identifies that 551 has failed BOP RNO - Selects an operable channel (519)

BOP (Step 4) Check SG Pressure Instrument Indications - Normal (Step 5) Check SG NR Level within one of the following Trending to between 45-55%

BOP Or Between 45 - 55%

CRS/BOP (Step 6) Review Attachment A, Effects of Instrument Failure

Appendix D Operator Action Form ES-D-2 Op Test No.: N07-1 Scenario # 4 rev. 4 Event # 1 Page 9 of 33 Event

Description:

Steam Generator Level Channel Failure to 75%

Time Position Applicants Actions or Behavior (Step 7) ENSURE compliance with requirement for minimum operable channels and action statements.

T.S. 3.3.1 14 a/b - Condition E, Place channel in trip within 72 hrs CRS T.S. 3.3.2 5c - Condition I, Place channel in trip within 72 hrs T.S. 3.3.2 5e1/e2 - Condition D, Place channel in trip within 72 hrs T.S. 3.3.2 6d1/d2 - Condition D, Place channel in trip within 72 hrs Refer to T/S LCO 3.3.4 and T/S LCO 3.3.3 and ENSURE CRS compliance - Not applicable.

CRS (Step 8) Perform Notifications PER ODP-ZZ-00001 (Step 9) Direct I&C to Trip the Protective Bistables for the failed CRS Channel CRS (Step 10) Place the Inoperable Channel in the EOSL CRS (Step 11) Initiate actions to repair the failed component At the Discretion of the Lead Examiner Move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 2 Page 10 of 33 Event

Description:

Pressurizer Pressure Channel Failure High Time Position Applicants Actions or Behavior Booth Operator Instructions

• Insert Malfunction (BB) BBPT0455, Value =2500 over 10 secs

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure.

• When contacted, respond as EDO. Acknowledge the channel failure and Tech Spec entry.

PZR HIGH PRESSURE DEVIATION Annunciator 33B PZR PRESSURE LOW HEATERS ON Annunciator 33C REACTOR PARTIAL TRIP Annunciator 83C PT-455 indicates high OTO-BB-00006, Pressurizer Pressure Control Malfunction Implement OTO-BB-00006, Pressurizer Pressure Control CRS Malfunction RO Select an alternate channel (457/456)

RO Check PZR pressure 2200 - 2250 psig RO Check P-11 correct state (Not Lit)

RO Select recorder to valid channel CRS Direct I&C to trip the affected bistables Refer to Tech Specs

• 3.3.1, Condition E, M - Place Channel in trip in 72h CRS

• 3.3.2 Condition D, L - Verify interlock in req. state in 1 hr

• 3.3.4 Item 3 - Restore to Operable in 30 days At the Discretion of the Lead Examiner Move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 3 Page 11 of 33 Event

Description:

Turbine Impulse (1st Stage) Pressure Channel Failure Low Time Position Applicants Actions or Behavior Booth Operator Instructions

• Insert Malfunction (AC) ACPT0506, Value =0

• When contacted, respond as I&C. Acknowledge the request to trip bistables and investigate the channel failure.

• When contacted, respond as EDO. Acknowledge the channel failure and Tech Spec entry.

Indications Available:

PT-506 indication failing low Control Rods stepping in if in auto REACT DEV, Annunciator 77A OTO-AC-00003, Turbine Impulse Pressure Channel Failure Examiner Crew may enter OTO-SF-00001, Rod Control Malfunction and Note complete the immediate action steps then transition to OTO-AC-00003 Implement OTO-AC-00003, Turbine Impulse Pressure Channel CRS Failure RO Place Rod Control in MANUAL Identify the failed channel by comparing meter indications and RO/BOP identifying alarmed annunciators. (PT-506)

Select the alternate impulse pressure channel by utilizing the BOP Impulse Pressure selector switch AC PS-505Z This procedure is written assuming the plant is at power with the Steam Dumps in the Tavg Mode. Steps should be Note evaluated if the plant is at low power level and Steam Dumps are in the Steam Pressure Mode.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 3 Page 12 of 33 Event

Description:

Turbine Impulse (1st Stage) Pressure Channel Failure Low Time Position Applicants Actions or Behavior RO Check Tave within 1.5°F of Tref (When restored, then maintain)

Restore RCS Tavg to within 1,5F of Tref using any of the RO following: Adjust Control Rods Check Rod Control in AUTO RO

• Will place in AUTO if directed by SRO and Tave and Tref are matched Maintain Tavg at the corresponding Tref value for existing plant RO power. Ensure RX power is less than 3565 MWth.

Place the Steam Dump Interlock Selector switches (AB-HS-64 BOP and AB-HS-63) to the OFF/RESET position.

BOP Check C-7, Load Loss Stm Dump Armed - Extinguished - NO Perform the following:

BOP Place Steam Dump Select to Reset: US-500Z Ensure C-7, Load Loss Stm Dump Armed is extinguished Transfer Steam Dumps to the Steam Pressure Mode:

• Set the AB PK-507, Steam Header Pressure controller for BOP 7.28 turns (1092 psig)

• Place the Steam Dump Select to STEAM PRESS Place the Steam Dump Bypass Interlock switches to ON BOP HS-63/64

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 3 Page 13 of 33 Event

Description:

Turbine Impulse (1st Stage) Pressure Channel Failure Low Time Position Applicants Actions or Behavior Check the following permissives are in their correct state within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of the channel failure per Attachment B, permissives:

BOP

• P-7 (LIT)

• P-13 (LIT)

Direct an RO to Place SW12 for PT-506 at AMSAC RO/BOP Test/Bypass Panel and place SW11, Bypass toggle switch, to the right hand position Refer to T/S LCO 3.3.1 to ensure compliance with the CRS requirements for minimum channels.

• Condition T, Verify INTLK in required state for conditions RO Restore Rod Control to Manual if directed Note:

10 minutes after the failure, ATWS System Trouble Alarm, 83F, will annunciate. (No consequence)

At the Discretion of the Lead Examiner move to the next event.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 4 Page 14 of 33 Event

Description:

S/G Tube Leak/Rupture Time Position Applicants Actions or Behavior Booth Operator Instructions

• Insert Malfunction (BB) EBB01B, Value = 15

• When contacted, respond as Count Room Tech that the alarm is valid.

• When contacted, respond as EDO. Acknowledge the plant is at operation with a Steam Generator Tube Leak in B Steam Generator Indications Available:

PROCESS RAD HIHI, Annunciator 61A PROCESS RAD HI, Annunciator 61B OTO-BB-00001, SG Tube Leak Implement OTO-BB-00001, SG Tube Leak CRS NOTE: SGTL time trend available on the computer Check if Pressurizer level can be maintained.

RO Control Charging flow as necessary to maintain PZR level Check Pressurizer Level - Stable or Rising Check if VCT level can be maintained RO/BOP VCT level - Maintained greater than 5% by normal makeup Notify Chemistry to perform CTP-ZZZ-02590, Primary to CRS Secondary Leak Rate Determination Try to Identify the Affected S/G - Crew identifies B: S/G as the CREW affected by use of RM detectors

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 4 Page 15 of 33 Event

Description:

S/G Tube Leak/Rupture Time Position Applicants Actions or Behavior Determine the S/G Tube Leak Rate Determine leak size and rate of change using any of the following:

Trends of VCT level and PZR level RO Compare Charging and letdown flows Utilize GD SGTL or T4 SGTL Utilize GD SG17 Leak Rate less than 50 gpm CRS Check if plant should be shutdown At the Discretion of the Lead Examiner move to the next event.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5 Page 16 of 33 Event

Description:

Loss of Stator Cooling Water Time Position Applicants Actions or Behavior Booth Operator Instructions

• Insert Malfunction (CE) CEPV00013_C, Value = True

• When contacted, respond as Secondary Operations Technician and report the CEPV0013, Stator Cooling Water Supply Pressure Control Valve, is stuck closed and can not be opened.

Indications Available:

132 C GEN PROT RUNBACK CKT OTA-RK-00026, ADD 132C CRS Implement actions of OTA-RK-00026 ADD 132C Note: For High Outlet Temperature or Low Inlet Flow Conditions, further degradation will cause a Turbine Runback.

If the Turbine Runback doesnt restore conditions within certain time limit, a Turbine trip will occur BOP If a Turbine Runback occurs, Go To OTO-MA-00001 ENSURE Stator Cooling Water Pump RUNNING BOP Starts Second Pump, but Low Flow condition still exists Due to Reactor being at > 50% power directs Reactor and CRS Turbine Trip Booth Instructions: Following the Reactor Trip modify malfunction to increase tube leak to 450 gpm Insert Malfunction (BB) EBB01B, Value = 450, ramp over 300 secs Trip the Reactor and Perform E-0, Reactor Trip or Safety CREW Injection

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 17 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior Indications Available: 88 F MANUAL RX TRIP E-0, REACTOR TRIP OR SAFETY INJECTION E-0 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:

• All Turbine Stop valves - CLOSED BOP (Step 3) CHECK Power to AC Emergency Buses:

• AC emergency buses - AT LEAST ONE ENERGIZED

• NB01 OR

• NB02

• AC emergency buses - BOTH ENERGIZED RO/BOP (Step 4) CHECK SI Status:

• CHECK if SI is actuated:

• Any SI annunciator 88A through 88D - LIT OR

• SB069 SI Actuate RED light - LIT OR

• SB069 SI Actuate RED light - LIT OR

• LOCA Sequencer annunciators 30A or 31A - LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 18 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior RO/BOP (Step 4 RNO) 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 RO/BOP (Step 4) CHECK both Trains of SI - ACTUATED

• LOCA Sequencer annunciator 30A - LIT

• LOCA Sequencer annunciator 31A - LIT

• SB069 SI Actuate RED light - LIT SOLID (NOT blinking)

(Step 5) PERFORM Attachment A, Automatic Action RO/BOP Verification, While Continuing With This Procedure NOTE: The CRS will assign one board operator to perform Attachment A, while the other operator and the CRS continue in E-0.

E-0, RO/BOP (Step A1) CHECK Charging Pumps:

Att. A

• CCPs - BOTH RUNNING

• BG HIS-1A

• BG HIS-2A

• STOP NCP

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 19 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• BG HIS-3 RO/BOP (Step A2) CHECK SI And RHR Pumps:

• SI Pumps - BOTH RUNNING

• EM HIS-4

• EM HIS-5

• RHR Pumps BOTH RUNNING

• EJ HIS-1

• EJ HIS-2 RO/BOP (Step A3) CHECK ECCS Flow:

• CCPs to Boron Inj Header - FLOW INDICATED

• EM FI-917A

• EM FI-917B

• RCS pressure - LESS THAN 1700 PSIG RO/BOP (Step A3 RNO) Go To Step A4 RO/BOP (Step A4) CHECK ESW Pumps - BOTH RUNNING

• EF HIS-55A

• EF HIS-56A Critical Task Establish ESW Train A cooling before a transition CREW from E-0 RO/BOP (Step A5) CHECK CCW Alignment:

• CCW Pumps - ONE RUNNING IN EACH TRAIN

• Red Train:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 20 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• EG HIS-21 or EG HIS-23

• Yellow Train:

• EG HIS-22 or EG HIS-24

• CCW Service Loop Supply and Return valves for one operating CCW pump - OPEN

• EG ZL-15 AND EG ZL-53 OR

• EG ZL-16 AND EG ZL-54

• OPEN CCSW To RHR HX valves:

• EG HIS-101

• EG HIS-102

• CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EG HIS-101

• EG HIS-102

• CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EC HIS-11

• EC HIS-12

• STOP Spent Fuel Pool Cooling Pump(s):

• EC HIS-27

• EC HIS-28

• RECORD The Time Spent Fuel Pool Cooling Pump Secured

• MONITOR Time Since CCW Flow Isolated to SFP HX LESS THAN 4 HOURS (Step A6) CHECK Containment Cooler Fans - RUNNING IN RO/BOP SLOW SPEED

• GN HIS-9

• GN HIS-17

• GN HIS-5

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 21 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• GN HIS-13 (Step A7) CHECK Containment Hydrogen Mixing Fans -

RO/BOP RUNNING IN SLOW SPEED

• GN HIS-2

• GN HIS-4

• GN HIS-1

• GN HIS-3 RO/BOP (Step A8) CHECK If Containment Spray should Be Actuated:

• CHECK the following:

• Containment pressure - GREATER THAN 27 PSIG OR

• GN PR-934 indicates containment pressure - HAS BEEN GREATER THAN 27 PSIG OR

• Annunciator 59A CSAS LIT OR

• Annunciator 59B CISB - LIT

• Containment Spray Pumps -

• EN HIS-3

• EN HIS-9

• ESFAS status panels CSAS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• ESFAS status panels CISB sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• ESFAS status panels CISB sections:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 22 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

• STOP all RCPs RO/BOP (Step A9) CHECK If Main Steamlines Should Be Isolated:

• CHECK for any of the following:

• Containment pressure - GREATER THAN 17 PSIG OR

• GN PR-934 indicates containment pressure - HAS BEEN GREATER THAN 17 PSIG OR

• Steamline pressure - LESS THAN 615 PSIG OR

• AB PR-514 or AB PR-535 indicates steamline pressure

- HAS BEEN LESS THAN 615 PSIG

• CHECK MSIVs and Bypass valves - CLOSED (Step A10) CHECK ECCS Valves - PROPER EMERGENCY RO/BOP ALIGNMENT

• ESFAS status panels SIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A11) CHECK Containment Isolation Phase A:

• ESFAS status panels CISA sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A12) CHECK SG Blowdown Isolation:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 23 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• ESFAS status panels SGBSIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation RO/BOP Isolation:

• ESFAS status panels CRVIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT RO/BOP (Step A14) CHECK Containment Purge Isolation:

• ESFAS status panels CPIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT NOTE: All minipurge valves are still open. Valves inside Containment are stuck open, and only those outside can be manually closed.

RO/BOP (Step A14 RNO) Manually ACTUATE CPIS:

• SA HS-11

• SA HS-15 IF CPIS damper(s) are NOT closed, THEN manually CLOSE damper(s) as necessary RO/BOP (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 24 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior E-0 BOP/RO (Step 6) CHECK Generator Output Breakers - OPEN (contd)

• MA ZL-3A (V55)

• MA ZL-4A (V53)

BOP/RO (Step 7) CHECK Feedwater Isolation:

• Main Feedwater Pumps - TRIPPED

• Annunciator 120A, MFP A Trip - LIT

• Annunciator 123A, MFP B Trip - LIT

• Main Feedwater Reg Valves - CLOSED

• AE ZL-510 (SG A)

• AE ZL-520 (SG B)

• AE ZL-530 (SG C)

• AE ZL-540 (SG D)

• Main Feedwater Reg Bypass valves - CLOSED

• AE ZL-550 (SG A)

• AE ZL-560 (SG B)

• AE ZL-570 (SG C)

• AE ZL-580 (SG D)

• Feedwater Isolation Valves - CLOSED

• AE HIS-39 (SG A)

• AE HIS-39 (SG B)

• AE HIS-39 (SG C)

• AE HIS-39 (SG D)

BOP/RO (Step 8) CHECK AFW Pumps:

• MD AFW Pumps - BOTH RUNNING

• AL HIS-23A

• AL HIS-22A

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 25 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior START MD AFW Pump(s).

• TD AFW Pump - RUNNING IF NECESSARY (Step 9) CHECK AFW Valves - PROPER EMERGENCY BOP/RO ALIGNMENT

• MD AFP Flow Control Valves - THROTTLED

• AL HK-7A

• AL HK-9A

• AL HK-11A

• AL HK-5A

• TD AFP Flow Control Valves - FULL OPEN

• AL HK-8A

• AL HK-10A

• AL HK-12A

• AL HK-6A (Step 10) CHECK Total AFW Flow - GREATER THAN 355,000 BOP/RO LBM/HR BOP/RO (Step 11) CHECK PZR PORVs and Spray Valves:

• PZR PORVs - CLOSED

• BB HIS-455A

• BB HIS-456A

• PZR PORVs - BOTH IN AUTO

• BB HIS-455A

• BB HIS-456A

• PORV Block Valves - BOTH OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 26 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• BB HIS-8000A

• BB HIS-8000B

• Normal PZR Spray valves - CLOSED

• BB ZL-455B

• BB ZL-455C BOP/RO (Step 12) CHECK If RCPs Should Be Stopped:

• RCPs - ANY RUNNING

• ECCS pumps - AT LEAST ONE RUNNING

• CCP OR

• SI Pump

• RCS pressure - LESS THAN 1425 PSIG CRS (Step 12 RNO) Go To Step 13.

BOP/RO (Step 13) CHECK RCS Temperatures:

• Any RCP running - RCS TAVG STABLE AT 557°F OR TRENDING TO 557°F OR

• NO RCPs running - RCS COLD LEG TEMPERATURES STABLE AT 557°F OR TRENDING TO 557°F BOP/RO (Step 14) CHECK If Any SG Is Faulted:

• CHECK pressures in all SGs:

• ANY SG PRESSURE LOWERING IN AN UNCONTROLLED MANNER OR

• ANY SG COMPLETELY DEPRESSURIZED

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 27 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior (Step 14 RNO) Go To E-2, Faulted Steam Generator Isolation, CRS Step 1 NOTE: SG B is completely depressurized.

E-2, FAULTED STEAM GENERATOR ISOLATION E-2 BOP/RO (Step 1) CHECK MSIVs and Bypass Valves - CLOSED (Step 2) CHECK If Any SG Secondary Pressure Boundary Is BOP/RO Intact:

• CHECK pressures in all SGs - ANY STABLE OR RISING BOP/RO (Step 3) Identify Faulted Steam Generator:

• Check Pressures in all SGs:

• ANY SG PRESSURE LOWERING IN AN UNCONTROLLED MANNER OR

• ANY SG COMPLETELY DEPRESSURIZED BOP/RO (Step 4) ISOLATE Faulted SG(S):

• ISOLATE AFW flow to faulted SG(s):

• CLOSE associated MD AFP Flow Control Valve(s)

• AL HK-8A (SG A)

• AL HK-10A (SG B)

• AL HK-12A (SG C)

• AL HK-6A (SG D)

• CHECK ASD from faulted SG(s) - CLOSED

• AB PIC-1A (SG A)

• AB PIC-2A (SG B)

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 28 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• AB PIC-3A (SG C)

• AB PIC-4A (SG D)

• Locally CLOSE TDAFP Steam Supply From Main Steam Loop Manual Isolation valve from Faulted SG:

• ABV0085 (SG B)

BOOTH INSTRUCTOR NOTE: When directed by operator, Use IRF RABV085 to close ABV0085.

• CHECK Main Feedwater valves to faulted SG(s) -

CLOSED BOP/RO CHECK Main Feedwater valves to faulted SG(s) CLOSED

• Main Feedwater Reg Valve:

• AE ZL-510 (SG A)

• AE ZL-520 (SG B)

• AE ZL-530 (SG C)

• AE ZL-540 (SG D)

• Main Feedwater Reg Bypass valve:

• AE ZL-550 (SG A)

• AE ZL-560 (SG B)

• AE ZL-570 (SG C)

• AE ZL-580 (SG D)

• Feedwater Isolation Valve:

• AE HIS-39(SG A)

• AE HIS-40 (SG B)

• AE HIS-41 (SG C)

• AE HIS-42 (SG D)

• CHECK SG Blowdown Containment Isolation Valve from faulted SG(s) - CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 29 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• BM HIS-1A (SG A)

• BM HIS-2A (SG B)

• BM HIS-3A (SG C)

• BM HIS-4A (SG D)

• CLOSE Steamline Low Point Drain valve from faulted SG(s):

• AB HIS-9 (SG A)

• AB HIS-8 (SG B)

• AB HIS-7 (SG C)

• AB HIS-10 (SG D)

Critical Isolate the Faulted Steam Generator Before Transition out CREW Task of E-2 (Step 5) CHECK CST To AFP Suction Header Pressure -

BOP/RO GREATER THAN 2.75 PSIG BOP/RO (Step 6) CHECK Secondary Radiation:

• 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.

• CHECK unisolated secondary radiation monitors:

• SG Sample radiation:

• SJL 026

• SG ASD radiation:

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 30 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior

• AB RIC-111 (SG A)

• AB RIC-112 (SG B)

• AB RIC-113 (SG C)

• AB RIC-114 (SG D)

• Turbine Driven Auxiliary Feedwater Pump Exhaust radiation:

• FC RIC-385

• Secondary radiation - NORMAL (Step 6 RNO) Go to E-3, Steam Generator Tube Rupture, Step CRS 1.

E-3, STEAM GENERATOR TUBE RUPTURE CRS Transitions to E-3, Steam Generator Tube Rupture E-3 (Step 1) Check if RCPs should be stopped

• RCPs - any Running RO

• ECCS pumps - at least one Running

• RCS Pressure - Less than 1425 psig

• Stop all RCPs (Step 2) Identify the Ruptured SG(s)

• Unexpected rise in B SG BOP

• High radiation from B SG sample

• High radiation from B SG steamline

• High radiation from B SG blowdown line sample

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 4 rev. 4 Event # 5, 6, and 7 Page 31 of 33 Event

Description:

Steam Generator Tube Rupture/FWIV Auto Closure Failure/ESW Pump Auto Start Failure/Faulted - Ruptured S/G Time Position Applicants Actions or Behavior (Step 3) Isolate flow from ruptured Steam Generator BOP Should be isolated from steps taken in E-2 (Step 4) Check Ruptured SG(s) Level BOP Narrow Range level > 7% [25%] (NO)

Crew will not feed faulted & ruptured S/G (Step 5) Check Ruptured SG(s) Pressure - > 340 PSIG - NO RO RNO - GO TO ECA-3.1, SGTR With Loss of Reactor Coolant -

Subcooled Recovery Desired, Step 1.

At Examiner Discretion end the scenario

OG RO OG BOP N TODAY RO BOP Shift Date Review/Complete Prior to Relieving the Watch:

• URO Logs

• Annunciator Test

• Plant Status Control Log

• Control Board Walkdown

• Standing/Night Orders

• Status Panel Horns A Train Protected Plant Status: Mode 1 Gross Gen Load: 1024 MWe Reactor Power: 80% Load Limit Pot 8.65 Rod movement: None Circ. Pump Setback: DISABLE Boration: 10 gallons Cation Bed Run: 10 min Dilution 0 gallons C/T valves: Normal Equipment OOS or WPA PBG05B OOS for coupling lubrication/alignment check and oil change. Work should be complete in 4 to 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. TS 3.5.2, Condition A, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Information 80% Power for the last 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for secondary chemistry cleanup.

Raise Power to 100%

Equipment Burdens and Workarounds Review/Complete After Relieving the Watch:

• CARs Applicable to Operations

• Indicating Lights/Chart Recorders

CRS WATCH RELIEF CHECKLIST Off-going Supervisor CR Supervisor Nights Today Name Shift Date Oncoming Supervisor review or perform the following:

• Control Board Walk down

• Night Orders/Standing Orders

• EOSL Turnover Report

• AUTO LOG

• Temp Mod Log / Plant Status Control Log

• WPA

• Shift Brief Items to Cover: New Night / Standing Orders, Work for the Shift & Dose (Budget vs. Actual)

RCS Makeup: RODS:

Cation Bed Run:

10 gal boration D@ 174 10 min RCS: 1143 ppm (sample) A CCP: 1116 ppm B CCP: 1128 ppm PROTECTED TRAIN: A CDF: 3.72 E-5 LERF: 4.61 E-7 Industrial Safety Focus Area: Ensure good Pre-Job Briefs are conducted OPS DOSE HUP Site Focus Area: Two Minute Drill - Keep the BIG Picture Actual: 1.6 mrem HUP OPS Focus Area: Precise Communications Budget: 13.0 mrem CURRENT ISSUES:

PBG05B OOS for coupling lubrication/alignment check and oil change. Work should be complete in 4 to 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />.

TS 3.5.2, Condition A, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ONGOING ITEMS:

80% Power for the last 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for secondary chemistry cleanup.

Raise Power to 100%

Review or complete after relieving the watch:

• CARS Applicable to Ops (CTSN 5468)

• Highlights of Weekly Schedule Oncoming Supervisor: ______________________________________ _____________________

Name Time Page 1 of 1 ODP-ZZ-00003

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 2 rev. 4 Op Test No.:

Examiners: Operators:

Initial Conditions: The following is the plant/equipment status:

• 60% steady state power

• NE02 OOS (Activate Lesson ne01b.lsn)

• TS 3.8.1.B, This Date, 0500

• OSP-NE-00003, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> due in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />

• Ensure SG level channel 539 is selected for control Turnover: See Turnover Pages Event Malf. No. Event Type* Event No. Description A R (RO) Increase power to 75%

N (SRO/BOP) 1 PBG04 C (RO/SRO) Normal Charging Pump Trips Insert Malfunction (BG) PBG04, Value = True 2 AELT0539 I (BOP) Steam Generator Level Channel Fails High I-TS-SRO Insert Malfunction (AE) AELT0539, Value = 100, ramp=15 s 3 SFF06_DR C, (BOP/ Dropped Control Rod RO/SRO) Insert Malfunction (SF) SFF06_DR, Value = stationary C-TS-SRO gripper 4 BB002_A M (All) LOCA Insert Malfunction (BB) BB002_A, Value = 0-1300, Ramp in over 10 min.

5 JINHBSI C (RO, SRO) Automatic Safety Injection Failure Insert Remote Function (SB) JINHBSI, Value = Both 6 NEM8803B C (RO, SRO) BIH Valve Failure to Open Insert Remote Function (NG) NG04CKF2, Value = Tripped, Condition of jpplsia eq 1 Insert Remote Function (NG) NG01BDR4, Value = Tripped, Condition of jpplsia eq 1 7 PAL02_1 C (BOP, TDAFP Trip with MDAFP Auto Start Failure AL SRO) Insert Malfunction (AL) PAL02_1, Value = True Insert Remote Function (AL) JLOASBI8_1, Value = Inhibit

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

Scenario Event Description NRC Scenario 2 rev. 4 Callaway 2009 NRC Scenario #2 The crew takes the shift at 60% power with direction to increase power to 75%. Diesel Generator NE02 is out of service for preplanned maintenance. The crew should complete all control manipulations to increase power, including dilution and turbine controls. The crew should demonstrate the ability to monitor the power increase using diverse/redundant indications and conservative actions. Once the examiners are satisfied with the crew response the next event can be inserted.

Two minutes after power increase (dilution or rod withdrawal) has begun or when directed by the lead examiner, the Normal Charging Pump will trip. The crew will respond by shifting to the B CCP in accordance with OTO-BG-00001, Pressurizer Level Control Malfunction.

The controlling Steam Generator Level channel on SG C (AE LT-539) fails high. The crew should respond per OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions, identify the failed channel, select an operable channel, and stabilize SG C level.

Tech Specs 3.3.1 and 3.3.2 apply.

Approximately twelve (12) minutes into the scenario, Rod F-6 drops into the core causing RCS temperature, pressure, and pressurizer level to lower. The crew should respond per OTO-SF-0001, Rod Control Malfunctions. TS 3.2.4 for QPTR will apply requiring the crew to reduce power to less than 50%.

A small RCS leak then develops after Tech specs have been addressed, which will steadily increase in size to a maximum value of 1300 gpm. The crew should diagnose the RCS leak and respond per OTO-BB-00003, RCS Excessive Leakage. When it is determined that the leak exceeds 50 gpm, the reactor should be tripped.

The crew should respond to the reactor trip by entering E-0, Reactor Trip or Safety Injection.

When the determination is made that pressurizer pressure will not be maintained greater than 1849 psig, a manual Safety Injection should be initiated, since the AUTO SI was inhibited.

When the Safety Injection occurs, BIH inlet valve EM-HV-8803A and B fails to open due to the breaker opening. The crew should take action to re-close the breaker and open EM-HV-8803A and B.

While performing the actions of E-0, the crew should recognize the automatic start failure of MDAFP A and manually start the pump. The trip of the TDAFP should be identified and investigated.

The crew should perform the applicable actions of E-0 and at step 16, transition to E-1, Loss of Reactor or Secondary Coolant. CSF monitoring should commence when E-0 is exited.

The crew should perform the applicable actions of E-1 and at step 12, transition to ES-1.2, Post LOCA Cooldown and Depressurization. The scenario may be terminated when RCS cooldown is initiated.

Scenario Event Description NRC Scenario 2 rev. 4 Critical Tasks:

Event #5 CT - Manually actuate one train of SIS prior to reporting E-0, Attachment A complete.

Event #6 CT - Establish flow from at least one high head ECCS pump before transitioning out of E-0 Event #7 - Start MDAFP Pump A to establish total AFW flow rate greater than 355,000 lbm/hr to the SGs before transition out of E-0.

References OTO-BB-00002 OTO-AE-00002 OTO-SF-00001 OTO-BB-00003 E-0 E-1 ES-1.2 EIP-ZZ-00101 OTG-ZZ-00004

Scenario Event Description NRC Scenario 2 rev. 4 Simulator Set Up Establish the initial conditions of IC-3, BOL 60%:

• Ensure Rod Control is in AUTO

• Rod Control Bank D 160 steps, Other banks 228 steps

• RCS boron concentration 1207 ppm

• CCP A 1180 ppm minus 15 days

• CCP B 1192 ppm minus 5 days

• Place TIP tag on NE HIS-26, Pull to Lock

• Place TIP tag on KJ HS-108

• NE02 inoperable, TS 3.8.1.B, 72 Hours, OOS at 0500, this date

• OSP-NE-00003 due in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />,If desired provide marked up copy of OSP-NE-00003

• Ensure SG level channel 539 is selected for control

======SCENARIO SETUP ITEMS===========

Load the following LESSONS and REMOTE FUNCTION Click on Lesson Tab, Then under TRNGSIM/LOCA

• ne01b.lsn (PRELOAD)

• amdafpautofail.lsn(PRELOAD)

• autosifail.lsn (PRELOAD)

• Insert Remote Function (NG) NG04CKF2, Value = tripped, with CONDITION of jpplsia eq 1 (PRELOAD)

• Insert Remote Function (NG) NG01BDR4, Value = tripped, with CONDITION of jpplsia eq 1 (PRELOAD)

Insert Malfunction (AL) PAL02_1, Value = True, with a condition of jpplsia eq 1

========EVENT 1 ==============

Normal Charging Pump Trips Insert Malfunction (BG) PBG04, Value = True

========EVENT 2 ==============

Steam Generator Level Channel 539 Fails to 100% over 15 secs Insert Malfunction (AE) AELT0539, Value = 100, ramp = 15 sec

========EVENT 3 ==============

Rod F6 drops to bottom of core Insert Malfunction (SF) SFF06_DR, Value = stationary gripper

========EVENT 4 ==============

Loss of Coolant Accident (LOCA) of 1300 gpm over 10 minutes Insert Malfunction (BB) BB002_A, Value = 1300, ramp = 10 minutes

========EVENT 5 PRELOADED==============

Boron Injection Header Valve Failure (Breaker Opens)

Insert Remote Function (NG) NG04CKF2, Value = Tripped, Condition of jpplsia eq 1

========EVENT 6 PRELOADED==============

Automatic Safety Injection Failure (autosifail.lsn)

Insert Remote Function (SB) JINHBSI, Value = Both

========EVENT 7 PRELOADED==============

TDAFP Trip (pal02trip.lsn) with MDAFP Auto Start Failure (amdafpautofail.lsn)

Insert Malfunction (AL) PAL02_1, Value = True, with a condition of jpplsia eq 1 Insert Remote Function (AL) JLOASBI8_1, Value = Inhibit

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # A Page 5 of 26 Event

Description:

Power Increase Time Position Applicants Actions or Behavior Shortly after taking the watch, raise power to 75% IC should start them at step 5.2.9, with section 5.5 complete OTG-ZZ-00004, Power Operation Power (Step 5.2.9) Initiate raising power towards 75% and Perform CREW the following as power is raised:

Increase Turbine Load Control Steps Step 5.2.5 At EHC Panel LOADING RATE LIMIT %/MIN, PERFORM the following:

1. CHECK EHC Panel, DECREASE LOADING RATE ON, push button light LIT.

2. SELECT desired loading rate.

• Use 0.05 for 3%/hr.

• Use 0.166 for 10%/hr.

3. Using EHC Panel, LOAD INCREASE, pushbutton, INITIATE raising load.

Dilution Steps OTN-BG-00002, Attachment 6 Place BG HS-26, RCS M/U CTRL, in Stop Place BG HS-25, RCS M/U CTRL SEL, in DIL Reset BG FY-111B, Combined M/U & BA Flow Totalizer, to 000 Ensure BG FY-111B is set to deliver the desired amount of makeup water Place BG HS-26, RCS M/U CTRL, in Run When the desired amount of water has been added, Place HS-26, RCS M/U CTRL, in Stop Place BG HS-25, RCS M/U CTRL SEL, in Auto Place HS-26, RCS M/U CTRL, in Run Rod Control Steps 5.7.2 & 5.7.3

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # A Page 6 of 26 Event

Description:

Power Increase Time Position Applicants Actions or Behavior ESTABLISH Manual Rod Control as follows:

a. CHECK auto rod motion NOT required

b. ENSURE SE HS-9, ROD BANK AUTO/MAN SEL, is in MAN.

c. Using SF HS-2, MAN ROD CTRL switch, INSERT or WITHDRAW Control Rods to the desired position.

d. MONITOR the following for effects of the rod motion:

• TAVG

• Pressurizer pressure

• Pressurizer level

• Reactor power

e. WHEN Manual Rod Control is no longer ESTABLISH Automatic Rod Control as follows:

a. CHECK Reactor power greater than 30%.

b. CHECK SF ZL-2A, ROD DIRECT lights, NOT LIT:

• Green IN light

• Red OUT light

c. CHECK SF ZL-2B, ROD DIRECT DEMAND lights, NOT LIT:

• Green IN light

• Red OUT light

d. CHECK TAVG within + 1degree F of TREF.

e. ENSURE SE HS-9, ROD BANK AUTO/MAN SEL, is in AUTO.

f. CHECK Rod Control for proper response.

(Step 5.2.9c) As power is raised from 65 to 70% power, ENSURE that the Mini-flow Recirc Valve for the second MFP is BOP CLOSED in AUTOMATIC.

• AE FIC-2B, MFP A RECIRC CTRL

• AE FIC-lB, MFP B RECIRC CTRL (Step 5.2.9d) ENSURE CAPV0013, STM SEAL SYS AUX STM BOP SPLY PV, and CAPV0014A, STM SEAL SYS MN STM SPLY PV, are CLOSED.

(Step 5.2.9e) Prior to exceeding 75% power, IF available, INITIATE placing a fifth Condensate Demineralizer in service BOP per OTN-AK-01001, Condensate Demineralizer System DCS Normal Operation.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # A Page 7 of 26 Event

Description:

Power Increase Time Position Applicants Actions or Behavior Addl (Step 5.4.1c) Using one of the computer programs listed below, Actions PERFORM a Xenon Prediction for the anticipated change in CRS/RO power. [Ref: 6.2.5] PROVIDED (Step 5.4.1d) PERFORM a Dilution/Boration Calculation for the RO anticipated change in power. [Ref: 6.2.5, 6.2.17 and 6.2.19]

(Step 5.4.1e) REQUEST guidance from Reactor Engineering CRS for desired control rod positioning for optimum Axial Offset (AO) control.

(Step 5.4.1f) Using the following hand switches, ENSURE at least one group of Pressurizer Back-up Heaters is ENERGIZED to equalize RCS and Pressurizer boron RO concentrations.

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

• BB HIS-52A, PZR HTR B/U GROUP B, in CLOSE (Step 5.4.1g) PLACE BB PK-455A, PZR PRESS MASTER RO CTRL, in MANUAL and LOWER to 40%.

(Step 5.4.1h) PLACE BB PK-455A, PZR PRESS MASTER RO CTRL, in AUTO.

(Step 5.4.1i) If desired, raise annunciator 77A, REACT DEV, RO set point to 1.5°F At the Discretion of the Lead Examiner Move to Event #1.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # 1 Page 8 of 26 Event

Description:

Normal Charging Pump Trip Time Position Applicants Actions or Behavior After a Power Increase has been established to 65%. (The crew should complete all control manipulations to increase power, including dilution and turbine controls. The crew should demonstrate the ability to monitor the power increase using diverse/redundant indications and conservative actions. Once the examiners are satisfied with the crew response the next event can be inserted.)

Booth Operator Instructions:

• T = 2 minutes

• Insert Malfunction (BG) PBG04, Value = True

• When contacted, respond as Primary and/or Secondary Operator. Acknowledge the request to investigate the NCP Trip at the pump and breaker.

• Primary reports nothing abnormal at the pump

• Secondary reports TOC at NCP breaker

• When contacted, respond as EDO. Acknowledge the pump trip.

Indications Available:

Annunciator 41A, Seal Inj To RCP Lo Annunciator 42A, Chg Line Flow Hi/Lo OTO-BG-00001, Pressurizer Level Control Malfunction CRS Implement OTO-BG-00001, Pzr Level Control Malfunction Note: Letdown isolates and Pressurizer control heaters will deenergize if the controlling level channel fails low.

(Step 1) Check for failed Pressurizer Level Indicator - NO RNO - Perform the following:

RO

• Check Master Controller Malfunctioning - NO

• Go To Step 19

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # 1 Page 9 of 26 Event

Description:

Normal Charging Pump Trip Time Position Applicants Actions or Behavior Notes: Charging pumps that show signs of cavitation should be stopped and standby pumps should not be started without investigating.

The CCPs should not be run at less than 60 gpm total flow at anytime or less than 130 gpm total for greater than 30 minutes.

(Step 19) Check Charging Pumps - At least ONE Running -NO RNO - Perform the following:

• Ensure CCP Recirc Valves OPEN RO

• Start One CCP

• Ensure CCW pump is running in same train as pump started (Step 20) Check Charging Header Flow - indicates proper RO charging alignment

• EG FI-121A (Step 21) Maintain RCP Seal Injection Flow between 8 gpm and 13 gpm per RCP using Charging Header Back Pressure Control Valve RO

• BG HC-182 Note to examiners - use the chart recorders vs total flow BOP (Step 22) Check Instrument Air - In Service RO (Step 23) Check Letdown - In Service (Step 24) Check Letdown Relief Valve (BG8117) - NORMAL RO

• Letdown Relief to PRT Outlet Temp - BG TI-125

• Annunciator 39C, LTDN RLF TEMP HI- CLEAR

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # 1 Page 10 of 26 Event

Description:

Normal Charging Pump Trip Time Position Applicants Actions or Behavior (Step 25) Check Pressurizer Level RO At Program Level or Trending to Program Level (Step 26) Check RCS - Intact

• Containment Conditions - Normal RO

• Aux Building Conditions - Normal

• PRT Conditions - Normal

• Recycle Holdup Tank Levels - Normal (Step 27) Review applicable Tech Specs - Att H CRS None (Step 28) Perform Notifications Per ODP-ZZ-0001 Add 13 CRS Contact the EDO (Step 29) Check Any Charging Pump Started During the RO Performance of this Procedure (Step 30) Perform the Following:

Adjust RCS Tave as required Update Status Board with the boron concentration in the CRS/RO running charging pump Notify HP that area radiation levels may change in the affected charging pump room (Step 31) Go To Appropriate Plant procedure as directed by the RO/BOP Control Room Supervisor At the Discretion of the Lead Examiner Move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 Event # 2 Page 11 of 26 Event

Description:

SG C Level Channel Failure High Time Position Applicants Actions or Behavior Booth Operator Instructions:

• T = 12 minutes or when directed

• Insert Malfunction (AE) AELT0539, Value =100, ramp = 15 secs

• When contacted, respond as I&C. Acknowledge the request to investigate the channel failure.

• When contacted, respond as EDO. Acknowledge the channel failure and OTO entry.

Indications Available:

110 C SG C LEV DEV 110 D SG C FLOW MISMATCH OTO-AE-00002, Steam Generator Water Level Control Instrument Malfunctions Implement OTO-AE-00002, Steam Generator Water Level CRS Control Instrument Malfunctions (Step 1) Check SG Feedwater Flow Instrument Indications BOP Normal BOP (Step 2) Check SG Steam Flow Instrument Indications Normal (Step 3) Check SG Level Instrument Indications - Normal BOP RNO - Select SG Level Channel - Selector (AE LS-539C) to an operable channel BOP (Step 4) Check SG Pressure Instrument Indications - Normal

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 Event # 2 Page 12 of 26 Event

Description:

SG C Level Channel Failure High Time Position Applicants Actions or Behavior (Step 5) Check SG NR Level Within One of the Following:

BOP Trending to between 45% and 55%

Between 45% and 55%

CRS (Step 6) Review Attachment A, Effects of Instrument Failure (Step 7) Review Applicable Tech Specs, Attachment F T.S. 3.3.1 14 a/b - Condition E, Place channel in trip within 72 hrs T.S. 3.3.2 5c - Condition I, Place channel in trip within 72 hrs CRS T.S. 3.3.2 5e1/e2 - Condition D, Place channel in trip within 72 hrs T.S. 3.3.2 6d1/d2 - Condition D, Place channel in trip within 72 hrs CRS (Step 8) Perform Notifications per ODP-ZZ-00001, Add 13 CRS (Step 9) Direct I&C to Trip Protective Bistables - Att. B CRS (Step 10) Place AE LT-539 in the EOSL CRS (Step 11) Initiate Action to Repair AE LT-539 At the Discretion of the Lead Examiner Move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # 3 Page 13 of 26 Event

Description:

Dropped Control Rod (F-6)

Time Position Applicants Actions or Behavior Booth Operator Instructions:

• T = 18 minutes or when directed

• Insert Malfunction (SF) SFF06_DR, Value=Stationary Gripper When directed by the Lead Examiner enter EVENT #4, the LOCA

• Respond as the WWM if contacted about the dropped rod

• Respond as I&C if contacted about the dropped rod

• Respond as Reactor Engineering if contacted about the dropped rod

• Respond as the EDO if contacted about the dropped rod Indications Available:

65 D TREF TAUCT HI 78 A PR CHANNEL DEV 79 C CONTROL ROD DEV 80 C RPI ROD DEV 81 B RODS AT BOTTOM OTO-SF-00001, Rod Control Malfunctions CRS Implement OTO-SF-00001, Rod Control Malfunctions NOTE: Steps 1 through 6 are immediate action steps (Step 1) Check both of the following are met for indication of multiple dropped rods RO Ann 81A, TWO/MORE RODS AT BOTTOM - LIT Rod Bottom lights lit for greater than one rod RNO - Go To Step 3 (Step 3) Check Main Turbine Runback or Load Rejection in CRS/BOP 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.: Scenario # 2 rev. 4 Event # 3 Page 14 of 26 Event

Description:

Dropped Control Rod (F-6)

Time Position Applicants Actions or Behavior (Step 6) Check Control Rods Motion - Stopped RO 82B, OTDT Rod Stop 82C, OPDT Rod Stop (Step 7) Check Instruments Indications - Normal RCS Tavg HP Turbine First Stage Pressure RO Power Range Nuclear Instrument May use curve book to verify dropped rod position relative to NI (Step 8) Check Annunciator 79A, Rod Ctrl Urg Fail - Lit - NO RNO Maintain RCS Tavg/Tref Deviation within 1.5 °F

• Adjust Turbine Load RO

• Adjust RCS boron Concentration

• Adjust Control Rods Go To Step 10 (Step 10) Check Both of the Following Extinguished Annunciator 81B, Rod at Bottom CRS/RO All Rod Bottom Lights RNO - Go To Attachment A, Dropped/Misaligned Control Rod CRS Attachment A, Dropped/Misaligned Control Rod (Step A1) Check Reactor Power - Less Than 5%

CRS/RO RNO - Go To Step A3 CRS (Step A3) Contact I&C to Determine Reason for Dropped Rod (Step A4) Check Shutdown Margin Within COLR Limits within 1 CRS hour

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 rev. 4 Event # 3 Page 15 of 26 Event

Description:

Dropped Control Rod (F-6)

Time Position Applicants Actions or Behavior CRS (Step A5) Check AFD Within Curve Book Figure 1-1 Limits (Step A6) Check QPTR - Less than or equal to 1.02 REU1151 REU1152 REU1153 REU1154 REU1159 REU1160 REU1161 CRS/RO REU1162 RNO - T.S. 3.2.4 Condition A, Reduce Thermal Power > 3%

from RTP for each 1% of QPTR > 1.00%, 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after each QPTR determination T.S. 3.1.4 Condition B May call - T.S. 3.1.6 Condition B At the Discretion of the Lead Examiner Move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 16 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior Booth Operator Instructions:

• Respond as the EDO if contacted about the RCS/ LOCA

• Respond as the Primary Operator to investigate the loss of power to EMHV8803A and B, after three minutes report the breaker is tripped but there is no apparent problem with the breaker.

• If directed by the control room close the breaker by deleting and re-closing Remote Function (NG) NG04CKF2, value = Close, NG01BDR4, value = Close

• Respond as the secondary Operator if contacted to investigate the trip of the TDAFP, after 4 minutes report that the mechanical linkage is tripped, lube oil is all over the room and there appears to be a large oil leak on the pump.

• If contacted as maintenance, report that the TDAFP trip will be investigated

• IF contacted, respond as secondary operator and investigate the A MDAFP not starting and after 5 minutes report no obvious problems with the A MDAFP or its power supply breaker.

Indications Available:

32 C PZR LO LEV DEV 60 E/F CTMT SUMP LEV HI 61 A/B PROCESS RAD HI OTO-BB-00003, RCS Excessive Leakage CRS Implement OTO-BB-00003, RCS Excessive Leakage (Step 1) Check if Pressurizer Level can be maintained CRS/RO

• Control Charging flow as necessary to maintain level

• Check Pressurizer Level - STABLE OR RISING

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 17 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 1b RNO)

Perform the following:

Establish maximum charging flow from one pump If PZR level cannot be maintained, then perform the following:

RO Close letdown orifice Isolation valves to establish stable PZR level Close RHR cleanup to letdown HX Flow Control Valve If PZR level cannot be maintained, then Close RCS Letdown to Regen Hx Isolation Valves 459/460 (Step 2) Check Pressurizer Level - STABLE OR RISING - NO RO goes to RNO (Step 2 RNO)

If plant is in mode 1, 2, or 3 with SI accumulators aligned for injection, then perform the following:

RO Manually Trip the reactor When reactor trip is verified, then Actuate SI GO to E-0, Reactor Trip or Safety Injection E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection (Steps 1-4 are immediate action steps)

E-0 (Step 1) Check Reactor Trip Rod Bottom Lights - All lit RO Reactor Trip and Bypass Breakers - Open Neutron Flux - Lowering (Step 2) Check Turbine Trip BOP Turbine Stop Valves - Closed

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 18 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 3) Check Power to AC Emergency Buses BOP At least One Emergency Bus - Energized Both Emergency Buses - Energized (Step 4) Check SI Status Actuated or Required RO Manually actuate SI (SB HS-27/28)

Check LOCA Seq Ann 30A and 31A - Lit Check SB069, SI Actuate Red Light - Lit Solid Critical Manually actuate one train of SIS prior to transitioning out CREW Task of E-0.

(Step 5) Perform Attachment A, Automatic Action RO Verification while continuing with this procedure Att A (Step A1) Check Charging Pumps RO Both CCPs running (Step A2) Check SI and RHR Pumps RO All running (Step A3) Check ECCS Flow BIH flow indicated on EM FI-917A/B - NO RO RNO - Start CCPs or Align valves as necessary Dispatches Operator to open 8803 A/B Critical Establish flow from at least one high head ECCS pump CREW Task before reporting E-0, Attachment A Complete.

BOP (Step A4) Check ESW Pumps - Both Running

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 19 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step A5) Check CCW Alignment One pump running in each train Service loop being supplied BOP Open CCW to RHR Valves - EG HIS-101&102 Close SFPHX Outlet Valves - EC HIS-11&12 Stop SFP Cooling Pumps - EC HIS-27&28 Record & Monitor time that SFP cooling is isolated (Step A6) Check Containment Cooling Fans - Running in slow RO speed (Step A7) Check Hydrogen Mixing Fans - Running in slow RO speed RO (Step A8) Check if Containment Spray Should be Actuated RO/BOP (Step A9) Check if Main Steamlines Should be Isolated RO (Step A10) Check ECCS Valves - Proper Emergency Alignment RO (Step A11) Check CIS-A BOP (Step A12) Check SG Blowdown Isolation RO (Step A13) Check Both Trains CRVIS RO (Step A14) Check Containment Purge Isolation (Step A15) Notify CRS of completion and any manual actions RO taken

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 20 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior E-0 (Step 6) Check Generator Output Breakers - Open BOP MA ZL - 3A (V55)

MA ZL - 4A (V53)

(Step 7) Check Feedwater Isolation Main Feedwater Pumps - Tripped BOP Main Feedwater Reg Valves - Closed Main Feedwater Reg Bypass Valves - Closed Feedwater Isolation Valves - Closed (Step 8) Check AFW Pumps MD AFW Pumps - Both Running BOP RNO - Start MD AFW Pump (s)

TD AFW Pump - Running if Necessary Critical Start MD AFW Pump A to establish total AFW flow rate Task CREW greater than 355,000 lbm/hr to the SGs before transition out of E-0 (Step 9) Check AFW Valves-Proper Emergency Alignment BOP MD AFP Flow Control Valves - Throttled TD AFP Flow Control Valves - Full Open BOP (Step 10) Check Total AFW Flow-Greater than 355,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves PZR PORVs - Closed RO PZR PORVs - Both in Auto PORV Block Valves - Both Open Normal PZR Spray Valves - Both Closed Note Seal Injection flow should be maintained to all RCPs

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 21 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 12) Check if RCPs Should be Stopped RCPs - Any Running RO ECCS Pumps - At least one Running RCS Pressure - Less than 1425 PSIG Stop All RCPs (Step 13) Check RCS Temperatures RO RCPs Running - Tavg 557 Deg F No RCPs Running - Tcold 557 Deg F (Step 14) Check if any SG is Faulted RO No SG pressure lowering uncontrollably No SG completely depressurized (Step 15) Check if SG Tubes are Intact No narrow ranger level rising uncontrolled SG steamline N16 radiation - Normal RO Condenser air removal - Normal before isolation SG ASD radiation - Normal TDAFP exhaust - Normal (Step 16) Check if RCS is Intact Containment pressure - Normal RO Containment Normal Sump Level - Normal Containment Radiation - Normal before isolation RNO - Go to E-1, Loss of Reactor or Secondary Coolant CRS Commence CSF Status Tree monitoring E-1, Loss of Reactor or Secondary Coolant E-1 CRS Implement E-1, Loss of Reactor or Secondary Coolant

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 22 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 1) Check if RCPs should be Stopped RCPs - any running RO ECCS Pumps - at least one running RCS Pressure - less than 1425 psig Stop All RCPs (Step 2) Check if any SG is faulted Any SG pressure lowering uncontrollably BOP Any SG completely depressurized Check all Faulted SGs - Isolated (Step 3) Check Intact SG Levels BOP NR levels - greater than 7% (25%)

Control levels between 7% (25%) and 52%

(Step 4) Check Secondary Radiation - Normal Perform EOP Addendum 11, Restore SG sampling BOP Direct Chemistry to sample the Steam Generators Direct RP to survey steamlines Check unisolated secondary radiation monitors (Step 5) Check PZR PORVs and Block Valves Power to Block Valves - Available RO PZR PORVs - Closed Block Valves - Both Open (Step 6) Check if ECCS flow should be reduced RCS Subcooling - greater than 30ºF (50ºF)

One SG NR Level - greater than 7% (25%) OR RO Total AFW flow - greater than 355,000 lbm/hr RCS Pressure - Stable or rising PZR Level - greater than 9% (29%)

(Step 7) Check if Containment Spray Should be Stopped RO Spray pumps - running Determine number of required pumps (if required)

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 23 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 8) Check if RHR Pumps Should be Stopped Check RCS pressure - greater than 325 psig RO RCS Pressure - Stable or rising Stop RHR Pumps with suction aligned to RWST (Step 9) Check SG and RCS Pressures BOP All SG Pressures - stable or rising RCS Pressure - stable or lowering (Step 10) Check if Diesel Generators Should be Stopped Emergency Buses - Energized from offsite power BOP Perform EOP Addendum 8, Loading Equipment Stop any unloaded Diesel Generators (Step 11) Initiate Evaluation of Plant Status Check cold leg recirculation capability CRS/RO Check Aux Building radiation - normal Obtain samples Evaluate long term recovery capability (Step 12) Check if RCS Cooldown and Depressurization is CRS/RO Required - RCS Pressure - greater than 325 psig Go to ES-1.2, Post LOCA Cooldown and Depressurization CRS Implement ES-1.2 Post LOCA Cooldown and Depressurization ES-1.2 RO (Step 1) Reset SI RO (Step 2) Reset Containment Isolation Phase A and Phase B (Step 3) Establish Instrument Air to Containment Check EF HIS-43/44 - Open RO Start Air Compressor (s)

Open KA HS-29 RO (Step 4) Deenergize PZR Heater

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario 2 rev. 4 Event # 4, 5, 6, and 7 Page 24 of 26 Event

Description:

LOCA/Hi Head ECCS Isolated/Auto SI Failure/TDAFW Trip Time Position Applicants Actions or Behavior (Step 6) Check all AC Buses - Energized by Offsite Power NB01 BOP NB02 PA01 PA02 (Step 7) Check if RHR Pumps Should be Stopped Any RHR Pump running with suction aligned to the RWST RO RCS Pressure - Greater than 325 psig Stop RHR Pumps and Place in Standby (Step 8) Check Intact SG Levels BOP NR levels - greater than 7% (25%)

Control levels between 7% (25%) and 52%

(Step 9) Check if Condenser Air Removal Should be Returned to Normal Check Condenser Vacuum - Established Check MSIVs - any open BOP Open GE HIS-101/102 Open GE HIS-103/104 Start one Condenser Air Removal Fan Start desired number of condenser vacuum pumps (Step 10) Initiate RCS Cooldown to Cold Shutdown Check RCS pressure - less than 1970 psig Block Steamline Pressure SI, SB HS-9/10 Maintain cooldown rate (Tc) - less than 100ºF/HR CRS/RO Dump Steam to Condenser from intact SGs Condenser available (C-9 lit and MSIVs open)

Place AB PK-507 in manual and zero output Place AB US-500Z in STM PRESS position Adjust AB PK-507 to achiever desired cooldown rate Once the crew has commenced a Cooldown or at the Discretion of the Lead Examiner - Terminate Scenario

OG RO OG BOP N TODAY RO BOP Shift Date Review/Complete Prior to Relieving the Watch:

• URO Logs

• Annunciator Test

• Plant Status Control Log

• Control Board Walkdown

• Standing/Night Orders

• Status Panel Horns A Train Protected Plant Status: Mode 1 Gross Gen Load: 743 MWe Reactor Power: 60% Load Limit Pot 8.7 Rod movement: None Circ. Pump Setback: DISABLE Boration: 10 gallons Cation Bed Run: 10 min Dilution 0 gallons C/T valves: Normal Equipment OOS or WPA Diesel Generator NE02 is OOS for preplanned maintenance, OSP-NE-00003, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, due in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. NE02 was taken out of service at 0500 this morning.

Information Raise Reactor Power to 75%

Equipment Burdens and Workarounds Review/Complete After Relieving the Watch:

• CARs Applicable to Operations

• Indicating Lights/Chart Recorders

CRS WATCH RELIEF CHECKLIST Off-going Supervisor CR Supervisor Nights Today Name Shift Date Oncoming Supervisor review or perform the following:

• Control Board Walk down

• Night Orders/Standing Orders

• EOSL Turnover Report

• AUTO LOG

• Temp Mod Log / Plant Status Control Log

• WPA

• Shift Brief Items to Cover: New Night / Standing Orders, Work for the Shift & Dose (Budget vs. Actual)

RCS Makeup: RODS:

Cation Bed Run:

10 gal boration D@ 160 10 min RCS: 1207 ppm (sample) A CCP: 1180 ppm B CCP: 1192 ppm PROTECTED TRAIN: A CDF: 1.67 E-4 LERF: 5.43 E-7 Industrial Safety Focus Area: Ensure good Pre-Job Briefs are conducted OPS DOSE HUP Site Focus Area: Two Minute Drill - Keep the BIG Picture Actual: 1.6 mrem HUP OPS Focus Area: Precise Communications Budget: 13.0 mrem CURRENT ISSUES:

Diesel Generator B is OOS for preplanned maintenance Tech Spec 3.8.1, Condition B 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, entered at 0500 this morning OSP-NE-000003, 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> due in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> ONGOING ITEMS:

Power held @ 60% for 1 week to perform maintenance on A MFP due to control valve problem.

Repairs are completed, pump has been in service and stable for the last 4 days. Release to commence raising power Raise Power to 75% at 10%/hr Review or complete after relieving the watch:

• CARS Applicable to Ops (CTSN 5468)

• Highlights of Weekly Schedule Oncoming Supervisor: ______________________________________ _____________________

Name Time Page 1 of 1 ODP-ZZ-00003

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Callaway Date of Exam: 6/19/2009 Operating Test No.: Rev. 4 2009-1 A E Scenarios P V 1 4 3 BU T M P E O I L N T N CREW CREW CREW CREW I T POSITION POSITION POSITION POSITION A I C L M A T U N Y M(*)

T P S A B S A B S A B S A B R I U E R T O R T O R T O R T O O C P O C P O C P O C P RX 0 0 NOR A A 2 1 8 2 SROU-1 I/C 12 12 35 35 MAJ 6 48 3 1 TS 13 12 4 2 RX 0 0 NOR A A 2 1 8 2 SROU-2 I/C 12 12 35 35 MAJ 6 48 3 1 TS 13 12 4 2 RX A 1 1 NOR A 1 1 4

SROI-1 I/C 12 23 12 11 35 34 6

MAJ 6 48 5 4 2 TS 13 23 4 2 RX A 1 1 NOR A 1 1 4

SROI-2 I/C 12 12 9 45 35 7

MAJ 6 48 3 2 TS 12 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

NUREG 1021 Revision 9

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Callaway Date of Exam: 6/19/2009 Operating Test No.: Rev. 4 2009-1 A E Scenarios P V 1 4 3 BU T M P E O I L N T N CREW CREW CREW CREW I T POSITION POSITION POSITION POSITION A I C L M A T U N Y M(*)

T P S A B S A B S A B S A B R I U E R T O R T O R T O R T O O C P O C P O C P O C P RX 0 1 NOR A A 2 1 9 4 SROI-3 I/C 23 12 24 5 35 MAJ 6 48 5 4 2 TS 12 2 2 RX A 1 1 NOR A 1 1 4

SROI-4 I/C 12 23 6 35 MAJ 6 48 3 2 TS 13 2 2 RX A 1 1 NOR A 1 1 RO-1 I/C 12 13 10 45 56 4 7 7 MAJ 6 48 3 2 TS 0 RX A 1 1 NOR A 1 1 RO-2 I/C 12 13 10 45 56 4 7 7 MAJ 6 48 3 2 TS 0 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

NUREG 1021 Revision 9

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Callaway Date of Exam: 6/19/2009 Operating Test No.: Rev. 4 2009-1 A E Scenarios P V 1 4 3 BU T M P E O I L N T N CREW CREW CREW CREW I T POSITION POSITION POSITION POSITION A I C L M A T U N Y M(*)

T P S A B S A B S A B S A B R I U E R T O R T O R T O R T O O C P O C P O C P O C P RX A 1 1 NOR A 1 1 5 4 RO-3 I/C 23 23 5

MAJ 6 48 3 2 TS 0 RX A 1 1 NOR A 1 1 4

RO-4 I/C 23 23 5 5

MAJ 6 48 3 2 TS 0 RX A 1 1 NOR A 1 1 4

RO-5 I/C 12 13 16 12 45 56 7 7 MAJ 6 48 5 4 2 TS 0 RX NOR I/C MAJ TS Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

NUREG 1021 Revision 9

Callaway Proposed Simulator Exam Schedule SRO ATC BOP Scenario #

U1 R2 R3 1 U2 R1 R4 1 I1 R5 I3 1 I4 I2 SU 1 U1 R3 R2 4 U2 R4 R1 4 I3 I1 R5 4 I2 I4 SU 4 I1 I3 R5 3 Standby scenario used as needed

ES-301 Competencies Checklist Form ES-301-6 Facility: Callaway Date of Examination: 6/19/2009 Operating Test No.:

2009-1 APPLICANTS SRO RO BOP Competencies SCENARIO SCENARIO SCENARIO 1 4 3 2 1 4 3 2 1 4 3 2 Interpret/Diagnose 1, 2, 2-4, 2, 4, 1, 3- 1, 5, Events and 1-7 1-8 1-6 N/A 4-7 8 5 N/A 2-6 8 6 N/A Conditions Comply With and Use A, 1, A, 2, A, 1- A, 1- A, 2- 2, 4, A, 1, 1, 5, 1-6 N/A 2, 4- N/A 3, 5, N/A Procedures (1) 7 8 7

4, 8 5 6

3-8 6 Operate Control A, 1, A, 2, A, 2- 2, 4, A, 1, 1, 5, N/A N/A N/A N/A 2, 4- N/A 3, 5, N/A Boards (2) 7 4, 8 5 6

3-8 6 Communicate and A, 1, A, 1- A, 1- A, 2- 2, 4, A, 1- A, 1, 1, 5, 1-6 N/A 2, 4- N/A N/A Interact 7 8 7

4, 8 5 6 3-8 6 Demonstrate A, 1- A, 1-Supervisory Ability 7 8 1-6 N/A N/A N/A N/A N/A N/A N/A N/A N/A (3)

Comply With and Use 1, 3 1, 2 2, 3 N/A N/A N/A N/A N/A N/A N/A N/A N/A Tech. Specs. (3)

Instructions:

Circle the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant.

NUREG-1021, Revision 9