ML16158A475

2016-06 Final Operating Test

ML16158A475
Person / Time
Site:	Callaway
Issue date:	06/01/2016
From:	Vincent Gaddy Operations Branch IV
To:
References
Download: ML16158A475 (257)

Text

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Facility: Callaway Date of Examination: 5/23/2016 Examination Level: RO Operating Test Number: 2016-1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.37 (4.3) Knowledge of procedures, guidelines, or Conduct of Operations limitations associated with reactivity R, D management A1 JPM: Perform a QPTR Calculation 2.1.25 (3.9) Ability to interpret reference materials such as Conduct of Operations graphs, curves, tables, etc.

R, M A2 JPM: Determine RV Venting Time (EOP ADD 33) 2.2.37 (3.6) Ability to determine operability and/or availability Equipment Control of safety related equipment.

R, D, P A3 JPM: Determine Amperage Limits for 480 VAC Safety Related busses.

2.3.7 (3.5) Ability to comply with radiation work permit Radiation Control requirements during normal or abnormal R, M conditions.

A4 JPM: Determine entry requirements for the RCA.

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

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

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

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

• The JPMs from the 2013 exam were randomly selected by placing 4 slips of paper labeled A1.a 2013 through A4 2013 in a hardhat. A2 2013was drawn from the hardhat.

NUREG-1021, Revision 10 Page 1 of 2

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 A1 This is a BANK JPM. The parent JPM (URO-SSE-04-A100J) was last used on an ILT NRC Exam administered at Callaway in 2009. Upon completion of this JPM, the applicant will have performed a manual QPTR calculation with a final QPTR tolerance of

+/- 0.01.

A2 This is a MODIFIED JPM. The parent JPM was used on the 2009 ILT NRC exam. The candidate is to determine the maximum RV Venting time using EOP Addendum 33.

Upon completion of this JPM, the applicant will have determined RV Venting time to be between 1.72 and 1.84 minutes.

A3 This BANK JPM was used on the 2013 ILT NRC Exam. The applicant will review planned maintenance which requires load centers NG01 and NG03 to be cross-connected. The applicant will be required to determine what equipment can be started on the cross-connected load centers without overloading the buses. Upon completion of this JPM, the applicant reported that the following equipment could be started: CGM01A, DG Vent Sply Fan A, SGK04A, Ctrl Rm A/C Unit A, PEC01A, Fuel Pool Clg Pmp A.

A4 This is a MODIFIED JPM from the 2013 Palo Verde ILT NRC Exam. This JPM requires the RO to review given conditions and determine RWP to be used, required dosimetry.

Dose and dose rate alarm, protective clothing required, and required RP briefing or authorization for the task will be performed; in accordance with APA-ZZ-01004, Radiological Work standards, and HDP-ZZ-01500, Radiological Postings. Upon completion of the JPM the applicant will have identified the following:

RWP to be used 160501ROUTINE Required Dosimetry OSLD and Electronic Dosimeter Dose Alarm 11 mRem Dose Rate Alarm 100 mRem Full set of Protective Clothing in Contaminated Areas.

Protective Clothing OR Requirements Partial PC's allowed for tours, inspections, and work below grating as allowed by RP.

Required RP briefing and/or Contact RP for Survey Prior to Entry (CRP) authorization NUREG-1021, Revision 10 Page 2 of 2

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 Facility: Callaway Date of Examination: 5/23/2016 Examination Level: SRO Operating Test Number: 2016 - 1 Administrative Topic Type Code* Describe activity to be performed (see Note) 2.1.37 (4.6) Knowledge of procedures, guidelines, or Conduct of Operations limitations associated with reactivity R, M management A5 JPM: Review a QPTR Calculation 2.1.25 (4.2) Ability to interpret reference materials such as Conduct of Operations graphs, curves, tables, etc R, M A6 JPM: Determine RV Venting Time (EOP ADD 33) 2.2.37 (4.6) Ability to determine operability and/or availability Equipment Control of safety related equipment R, D, P A7 JPM: Determine Amperage Limits for 480 VAC Safety Related busses 2.3.4 (3.7) Knowledge of radiation exposure limits under Radiation Control normal or emergency conditions R, M A8 JPM: Select Volunteer for Emergency Exposure 2.4.44 (4.4) Make a Protective Action Recommendation Emergency Procedures/Plan R, M JPM: Determine the Protective Action A9 Recommendation (PAR)

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)

• No JPMs from the last 2 SRO exams (including the 2013 re-exam) were selected for this exam. JPM A7 was on the 2013 RO exam. This JPMs was randomly selected by placing 4 slips of paper labeled A1.a 2013 through A4 2013 in a hardhat. A2 2013was drawn from the hardhat.

NUREG-1021, Revision 10 Page 1 of 2

ES-301 Administrative Topics Outline Form ES-301-1 Rev 2 A5 This is a MODIFIED JPM. The parent JPM (SRO-MAS-04-A006J) has not been used on an NRC Exam administered at Callaway between 2004 and 2014. Upon completion of this JPM, the applicant will have reviewed a manual QPTR calculation with a final QPTR tolerance of +/- 0.01 and determined that N44 Lower detector is greater than 1.02 and entered T/S 3.2.4.A, and entered the data on Attachment 2.

A6 This is a MODIFIED JPM. The parent JPM (RA2) was used on the 2009 ILT NRC exam.

The candidate is to determine the maximum RV Venting time using EOP Addendum 33.

Upon completion of this JPM, the applicant will have determined RV Venting time to be between 1.72 and 1.84 minutes.

A7 This BANK JPM was used on the 2013 ILT NRC Exam. The applicant will review planned maintenance which requires load centers NG01 and NG03 to be cross-connected. The applicant will be required to determine what equipment can be started on the cross-connected load centers without overloading the buses. Upon completion of this JPM, the Applicant reported that the following equipment could be started: CGM01A, DG Vent Sply Fan A, SGK04A, Ctrl Rm A/C Unit A, PEC01A, Fuel Pool Clg Pmp A A8 This is a MODIFIED JPM. The parent JPM (SRO-RER-03-A203J) was used on the 2009 ILT NRC exam. The applicant will be given a set of conditions and the appropriate procedures in an emergency radiological situation need to determine which volunteer may receive and emergency exposure. Upon completion of this JPM, Candidate selected Volunteer #5 to attempt the rescue of the injured operator in accordance with HDP-ZZ-01450 and completed Section 1 of CA0276 correctly in accordance with the KEY.

A9 This is a MODIFIED JPM. The parent JPM (SRO-RER-02-A031J(TC)) was used on the 2011 ILT NRC exam. The applicant will be assigned the task of determining the Protective Action Recommendation (PAR) within the allotted amount of time. Upon completion of this JPM the applicant will have identified the PAR as Evacuate 2 Mile Radius and 10 miles downwind (Sectors G, H, J).

NUREG-1021, Revision 10 Page 2 of 2

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A1 JPM No: URO-SSE-04-A100J KSA No: 2.1.37 Revision Date: 04/20/2016 KSA Rating: 4.3 Job

Title:

URO/SRO Duty: Nuclear Instrumentation Task

Title:

Perform a QPTR Calculation Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OSP-SE-00003, .QUADRANT POWER TILT RATIO, REVISION 22 CURVE BOOK TABLE 11-1, REVISION 257 Tools / Equipment: Calculator Page 1 of 6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 Cue: The Control Room Supervisor directs you to perform a QPTR calculation and complete Attachment 1 of OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

CHANNEL Itop Ibottom N41 185.8 195.2 N42 163.2 190.8 N43 191.6 198.3 N44 188.2 191.3 Provide completed Attachment 1of OSP-SE-00003 to the Examiner.

Curve Book Table 11-1 has been provided Task Standard: Upon completion of this JPM, the applicant will have performed a manual QPTR calculation with a final QPTR tolerance of +/- 0.01.

Start Time:

Stop Time:

Page 2 of 6

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

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

POWR TILT RATIO CALCULATION PROVIDE CANDIDATE WITH COPY OF OSP-SE-00003 and Table 11-1

2. Review Precautions and If asked All Precautions Applicant reviewed S U Limitations and Limitations are Precautions and satisfied. Limitations Comments:

STEP 4.0

3. Review Prerequisites If asked Prerequisites Applicant reviewed S U are satisfied. Prerequisites STEP 5.0 Comments:

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

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

• 5. Use Table 11.1 from the Applicant used Table 11-1, S U Curve Book to obtain the AFD Calibration value current values for the Table, AFD = 0%, to Comments:

upper and lower record power range upper detectors. AFD = 0% and lower current values.

values should be used.

SEE KEY STEP 6.2.2 Page 3 of 6

• Critical Step

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

• 6. Divide each upper and Applicant divided each S U lower detector current by upper and lower detector its 100%, 0% AFD power current by its 100% power, Comments:

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

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

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

• 7. Add the normalized Applicant added up the S U upper detector currents normalized upper detector and divide by four (4) to currents and divided by 4 Comments:

derive the upper detector to derive the upper normalized current detector normalized average and record it in current averages and Attachment #1. recorded it in Attachment

1. 1.

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

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

• 8. Add the normalized lower Applicant added up the S U detector currents and normalized lower detector divide by four (4) to currents and divided by 4 Comments:

derive the lower detector to derive the lower normalized current detector normalized averages and record it in current averages and Attachment #1. recorded it in Attachment

1. 1.

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

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

Page 4 of 6

• Critical Step

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

9. NOTE: The QPTR should The applicant calculated S U be calculated as two the QPTR, to two (2) significant digits to the significant digits to the Comments:

right of the decimal point. right of the decimal point.

Note before 6.2.6

• 10. Divide each upper Applicant divided each S U normalized detector upper normalized detector current by the upper current by the upper Comments:

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

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

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

• 11. Divide each lower Applicant divided each S U normalized detector lower normalized detector current by the lower current by the lower Comments:

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

RECORD on Attachment

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

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

12. THE JPM IS COMPLETE Page 5 of 6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 Cue: The Control Room Supervisor directs you to perform a QPTR calculation and complete Attachment 1 of OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

CHANNEL Itop Ibottom N41 185.8 195.2 N42 163.2 190.8 N43 191.6 198.3 N44 188.2 191.3 Provide completed Attachment 1of OSP-SE-00003 to the Examiner.

Curve Book Table 11-1 has been provided

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A2 JPM Bank No: RA2 2009 ILT NRC Exam KSA No: 2.1.25 Revision Date: 02/13/2016 KSA Rating: 3.9 Job

Title:

URO/SRO Duty: Administrative Task

Title:

Determine Reactor Vessel Venting Tims Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

EOP Addendum 33, Determine Reactor Vessel Venting Time, Rev 1 Tools / Equipment: Calculator Page 1 of 4

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 3.8 psig.

• Containment Temperature is 167°F.

• Containment Hydrogen Concentration is 2.3%.

• RCS Pressure is 1925 psig.

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

Task Standard: Upon completion of this JPM, the applicant will have determined RV Venting time to be between 1.72 and 1.84 minutes.

Start Time:

Stop Time:

Page 2 of 4

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

1. S U PROVIDE CANDIDATE CANDIDATE REVIEWED WITH MATERIAL AND ADMIN JPM INITIAL ALLOW TIME FOR CONDITIONS AND Comments:

REVIEW OF WORK TO INITIATING CUES BE PERFORMED

• 2. S U DETERMINE See KEY CANDIDATE CONTAINMENT AIR DETERMINED VOLUME AT STP = A CONTAINMENT AIR Comments:

VOLUME IS BETWEEN STEP 1 2.4 X 106 AND 2.5 X 106 FT3

• 3. S U CANDIDATE SHOULD See KEY CANDIDATE DETERMINE MAXIMUM DETERMINED THAT HYDROGEN VOLUME BETWEEN 16800 AND Comments THAT CAN BE VENTED 1.7500 FT3 CAN BE

=B VENTED STEP 2

• 4. S U CANDIDATE SHOULD See KEY CANDIDATE DETERMINE DETERMINED THAT HYDROGEN FLOW HYDROGEN FLOW RATE Comments RATE AS A FUNCTION IS BETWEEN 9500 AND OF RCS PRESSURE = C 9750 FT3/MINUTE USING FIGURE 1 Step 3

• 5. S U CANDIDATE SHOULD See KEY CANDIDATE DETERMINE MAXIMUM DETERMINED THAT THE VENTING TIME MAXIMUM VENTING Comments TIME IS BETWEEN 1.72 STEP 4 AND 1.84 MINUTES

6. JPM IS COMPLETE S U Comments Page 3 of 4

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 3.8 psig.

• Containment Temperature is 167°F.

• Containment Hydrogen Concentration is 2.3%.

• RCS Pressure is 1925 psig.

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

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A3 JPM Bank No: A3, Rev 2 from the 2013 ILT NRC KSA No: 2.2.37 exam Revision Date: 02/13/2016 KSA Rating: 3.6 Job

Title:

URO/SRO Duty: Administrative Task

Title:

Ability to determine operability and/or availability of safety related equipment: Determine amperage limits for 480 VAC safety related busses when cross-connecting for maintenance.

Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTN-NG-00001, Class 1E 480 VAC Electrical System, Rev 16 Tools / Equipment: none Page 1 of 8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is at 100% power.

NG01 local ammeter indicates 712 amps.

NG03 local ammeter indicates 344 amps.

The following Train A equipment is NOT in service:

• DG Vent Supply Fan A, CGM01A

• Air Compressor A, CKA01A

• Fuel Pool Clg Pump A, PEC01A

• CR A/C Unit A, SGK04A Initiating Cues: The Control Room Supervisor (CRS) directs you to prepare to cross-connect Load Centers NG01 and NG03 for maintenance to replace Load Center NG01 feeder breaker, NG0101.

Prior to cross-connecting NG01 and NG03, the CRS wants to know which individual equipment not currently in service could be started after the load centers are cross-connected.

Provide your answer on the cue sheet below:

Task Standard: Upon completion of this JPM, the Applicant reported that the following equipment could be started:

CGM01A, DG Vent Sply Fan A SGK04A, Ctrl Rm A/C Unit A PEC01A, Fuel Pool Clg Pmp A Start Time:

Stop Time:

Page 2 of 8

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

JPM refers to OTN-NG-00001, Section 5.10. This section will not be performed by the Applicant but does contain information that the Applicant will need to perform the assigned task. Though not expected to be performed by the Applicant, Section 5.10 steps will be contained in JPM A3.

1. S U Applicant providedd working copy of OTN-NG-00001 Comments:

2. S U Refers to Section 5.10, Applicant referred to Cross-Connecting Load Section 5.10, Cross-Centers NG01 And Connecting Load Centers Comments:

NG03 NG01 And NG03 Page 3 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

3. S U The following cautions If asked if the impact of Applicant read caution apply when cross- starting current on and understood that total connecting load center cycling loads has been amperage drawn by both Comments NG01 and NG03, due to considered, respond load centers shall not transformer and power that engineering has exceed 1200 amps on supply limitations: reviewed starting local ammeters

• Cross Tie Breaker current for NG01 and NG0116 is only NG03 loads and allowed to be closed determined that it has to repair failed or no impact on degraded limitations for current equipment loading when cross

• Closing NG0116 connecting NG01 and makes all 4 NG03.

degraded bus voltage channels for NB01 inoperable per T/S B 3.8.9, and requires entry into T/S ACT 3.3.5.B.1 and T/S ACT 3.8.1.F

• Total amperage drawn by both load centers shall not exceed 1200 amps on local ammeters

• Total allowed load of 1200 amps includes cycling loads

• No major loads should be added without referring to Attachment 1 to account for additional load Caution prior to Step 5.10.1

4. S U Initiate an EOSL item Step will not be performed for inoperability of all 4 channels for Bus NB01 Comments degraded voltage with reference to applicable T/S:

Step 5.10.1 Page 4 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

5. S U Check load centers Given in Initiating Cue NG01 and NG03 are energized Comments Step 5.10.2

6. S U Using local ammeters, Local ammeter values ensure combined total given in Initiating Cue load amperage for Comments NG01 and NG03 is less than 1200 amps Step 5.10.3

7. S U The bus transfer is a Note not read due to not break-before-make being applicable to operation which will assigned task Comments cause a momentary power loss of approximately 8 to 10 cycles. Alarms may actuate and breakers may trip. Attachment 1 provides load lists to determine effects on plant operation.

Note prior to Step 5.10.4

8. S U If removing the NG01 Step is not applicable feeder from service, perform the following:

Comments Step 5.10.4

9. S U If removing the NG03 Step is not applicable feeder from service, perform the following:

Comments Step 5.10.5 Page 5 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

10. S U Check loads on NG01 Step is not applicable and NG03 for breaker trips than may have Comments occurred during the transfer Step 5.10.6

11. S U Using local ammeters, Step is not applicable check combined total load amperage for Comments NG01 and NG03 is less than 1200 amps Step 5.10.7

12. S U If necessary to start Applicant determined loads on NG01 or loads that could be NG03, ensure toal load started - see JPM Step Comments will not exceed 1200 15 amps, by referring to Attachment 1 Step 5.10.8

13. S U If necessary, start loads Step is not applicable on NG01 and NG03 Comments Step 5.10.9

14. S U Refers to Attachment 1, Applicant referred to Load Centers NG01 & Attachment 1, Load NG03 Loads Centers NG01 & NG03 Comments Loads Page 6 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 15. S U Using Att 1 and Applicant determined that provided cues, CGM01A, SGK04A and determines what PEC01A can be started Comments equipment can be but that CKA01A could started on NG01 and not be started, as based NG03 after they are on the following cross-connected calculations:

Current amperage on both busses is 712 + 344

= 1056 (Provided in cue)

Margin for starting additional equipment is 1200 - 1056 = 144 Amperage for equipment not running would be:

• DG Vent Supply Fan A, CGM01A -

Acceptable

• Air Compressor A, CKA01A - Not Acceptable

• Fuel Pool Clg Pump A, PEC01A -

Acceptable

• CR A/C Unit A, SGK04A -

Acceptable Acceptable equipment to start would be CGM01A OR PEC01A OR SGK04A.

Information is provided to the CRS (Examiner)

16. JPM IS COMPLETE S U Comments Page 7 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is at 100% power.

NG01 local ammeter indicates 712 amps.

NG03 local ammeter indicates 344 amps.

The following Train A equipment is NOT in service:

• DG Vent Supply Fan A, CGM01A

• Air Compressor A, CKA01A

• Fuel Pool Clg Pump A, PEC01A

• CR A/C Unit A, SGK04A Initiating Cues: The Control Room Supervisor (CRS) directs you to prepare to cross-connect Load Centers NG01 and NG03 for maintenance to replace Load Center NG01 feeder breaker, NG0101.

Prior to cross-connecting NG01 and NG03, the CRS wants to know which individual equipment not currently in service could be started after the load centers are cross-connected.

Provide your answer on the cue sheet below:

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A4 JPM Bank No: Based on PVNGS 2013 KSA No: 2.3.7 Revision Date: 03/08/2016 KSA Rating: 3.5 Job

Title:

URO/SRO Duty: Radiation Exposure Control Task

Title:

Determine entry requirements for in the RCA 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:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

RWP 160501ROUTINE HDP-ZZ-01500, RADIOLOGICAL POSTINGS Survey CA-M-20160203-2, CA-M-20160308-1 Tools / Equipment: none Page 1 of 5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: In room 1322 below the platform grating, a label needs to be replaced on penetration P39 Initiating Cues: Using the survey map and RWPs provided determine the following:

1. RWP to be used

2. Required Dosimetry

3. Dose Alarm

4. Dose Rate Alarm

5. Protective Clothing Requirements

6. Required RP briefing and/or authorization Task Standard: Upon completion of the JPM the applicant will have identified the following:

RWP to be used 160501ROUTINE Required Dosimetry OSLD and Electronic Dosimeter Dose Alarm 11 mRem Dose Rate Alarm 100 mRem Full set of Protective Clothing in Contaminated Areas.

Protective Clothing OR Requirements Partial PC's allowed for tours, inspections, and work below grating as allowed by RP.

Required RP briefing and/or Contact RP for Survey Prior to Entry (CRP) authorization Start Time:

Stop Time:

Page 2 of 5

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

• 1. S U Applicant determined Applicant determines RWP 160501ROUTINE is RWP to be used to be used Comments:

• 2. S U Applicant determined Applicant determines OSLD and Electronic required Dosimetry Dosimeter is required Comments:

• 3. S U Applicant determines Applicant determined Dose Alarm Dose Alarm is 11 mRem Comments:

• 4. S U Applicant determined Applicant determines Dose Rate Alarm 100 Dose Rate Alarm mRem Comments

• 5. Applicant determined S U Protective Clothing Requirements are Full set of Protective Clothing in Comments Applicant determines Contaminated Areas.

Protective Clothing OR Requirements Partial PC's allowed for tours, inspections, and work below grating as allowed by RP.

• 6. S U Applicant determined the Applicant determines need Contact RP for Required RP briefing Survey Prior to Entry and/or authorization Comments (CRP)

7. JPM IS COMPLETE Page 3 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE KEY RWP to be used 160501ROUTINE Required Dosimetry OSLD and Electronic Dosimeter Dose Alarm 11 mRem Dose Rate Alarm 100 mRem Full set of Protective Clothing in Contaminated Areas.

Protective Clothing OR Requirements Partial PC's allowed for tours, inspections, and work below grating as allowed by RP.

Required RP briefing and/or Contact RP for Survey Prior to Entry (CRP) authorization KEY Page 4 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: In room 1322 below the platform grating, a label needs to be replaced on penetration P39 Initiating Cues: Using the survey map and RWPs provided determine the following:

1. RWP to be used

2. Required Dosimetry

3. Dose Alarm

4. Dose Rate Alarm

5. Protective Clothing Requirements

6. Required RP briefing and/or authorization Provide answers below RWP to be used Required Dosimetry Dose Alarm Dose Rate Alarm Protective Clothing Requirements Required RP briefing and/or authorization

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A5 JPM No: SRO-MAS-04-A006J KSA No: 2.1.37 Revision Date: 02/13/2016 KSA Rating: 4.6 Job

Title:

URO/SRO Duty: Nuclear Instrumentation Task

Title:

Review a QPTR Calculation Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OSP-SE-00003, .QUADRANT POWER TILT RATIO, REVISION 22 CURVE BOOK TABLE 11-1, REVISION 257 Tools / Equipment: Calculator Page 1 of 7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 Cue: The RO has performed a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

The RO has submitted the results to you for a second check.

CHANNEL Itop Ibottom N41 185.8 195.2 N42 163.2 190.8 N43 191.6 198.3 N44 188.2 196.1 Perform the second check of the ROs calculations and complete section 6.2 of OSP-SE-00003 Submit the data you have entered in OSP-SE-00003 to the Examiner.

Curve Book Table 11-1 has been provided Task Standard: Upon completion of this JPM, the applicant will have reviewed a manual QPTR calculation with a final QPTR tolerance of +/- 0.01 and determined that N44 Lower detector is greater than 1.02 and entered T/S 3.2.4.A, and entered the data on Attachment 2.

Start Time:

Stop Time:

Page 2 of 7

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

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

POWR TILT RATIO CALCULATION PROVIDE CANDIDATE WITH COPY OF OSP-SE-00003 and Table 11-1

2. Review Precautions and If asked All Precautions Applicant reviewed S U Limitations and Limitations are Precautions and satisfied. Limitations Comments:

STEP 4.0

3. Review Prerequisites If asked Prerequisites Applicant reviewed S U are satisfied. Prerequisites STEP 5.0 Comments:

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

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

• 5. Use Table 11.1 from the Applicant used Table 11-1, S U Curve Book to obtain the AFD Calibration value current values for the Table, AFD = 0%, to Comments:

upper and lower record power range upper detectors. AFD = 0% and lower current values.

values should be used.

Applicant identified Lower STEP 6.2.2 Detector N44 100%

Detector Current was recorded incorrectly as 193.4 instead of 192.7 SEE KEY Page 3 of 7

• Critical Step

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

• 6. Divide each upper and Applicant divided each S U lower detector current by upper and lower detector its 100%, 0% AFD power current by its 100% power, Comments:

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

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

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

Applicant identified Lower Detector N44 Normalized Detector Current was calculated incorrectly

7. Add the normalized Applicant added up the S U upper detector currents normalized upper detector and divide by four (4) to currents and divided by 4 Comments:

derive the upper detector to derive the upper normalized current detector normalized average and record it in current averages and Attachment #1. recorded it in Attachment

1. 1.

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

Values within +/- 0.001 on each calculation are acceptable.

Page 4 of 7

• Critical Step

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

• 8. Add the normalized lower Applicant added up the S U detector currents and normalized lower detector divide by four (4) to currents and divided by 4 Comments:

derive the lower detector to derive the lower normalized current detector normalized averages and record it in current averages and Attachment #1. recorded it in Attachment

1. 1.

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

Values within +/- 0.001 on each calculation are acceptable.

Applicant identified Lower Detector Average Normalized Current was calculated incorrectly

9. NOTE: The QPTR should The applicant calculated S U be calculated as two the QPTR, to two (2) significant digits to the significant digits to the Comments:

right of the decimal point. right of the decimal point.

Note before 6.2.6

10. Divide each upper Applicant divided each S U normalized detector upper normalized detector current by the upper current by the upper Comments:

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

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

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

Page 5 of 7

• Critical Step

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

• 11. Divide each lower Applicant divided each S U normalized detector lower normalized detector current by the lower current by the lower Comments:

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

RECORD on Attachment

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

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

Applicant identified Lower Detector N44 Power Tilt Ratio was calculated incorrectly

12. IF the manual QPTR N44 Lower is S U calculations do NOT Greater than 1.02. The confirm a QPTR of Applicant should N/A this Comments:

greater than 1.02, step.

DECLARE the Plant Computer Points and QPTR alarm INOPERABLE.

STEP 6.2.8

• 13. If any channel of QPTR Applicant determines that S U is greater than 1.02, N44 Lower QPTR is Refer to T/S Action greater than 1.02, referred Comments:

3.2.4.A and INITIATE to T/S Action 3.2.4.A and Attachment 2. INITIATED Attachment 2.

STEP 6.2.9 Applicant RECORDED highest QPTR of 1.03 and Rx Power of 100% on Attachment 2. See KEY

14. THE JPM IS COMPLETE Page 6 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 Cue: The RO has performed a QPTR calculation per OSP-SE-00003, Quadrant Power Tilt Ratio Calculation, using the NI detector currents provided.

The RO has submitted the results to you for a second check.

CHANNEL Itop Ibottom N41 185.8 195.2 N42 163.2 190.8 N43 191.6 198.3 N44 188.2 196.1 Perform the second check of the ROs calculations and complete section 6.2 of OSP-SE-00003 Submit the data you have entered in OSP-SE-00003 to the Examiner.

Curve Book Table 11-1 has been provided

A6 See RO A2 A7 See RO A3 CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A8 JPM No: SRO-RER-03-A203J KSA No: GEN 2.3.4 Revision Date: 02/15/2016 KSA Rating: 3.7 Job

Title:

SRO Duty: Administrative Task

Title:

SELECT VOLUNTEER FOR EMERGENCY EXPOSURE Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose, Rev 11 CA0276, Authorization to Exceed Federal Occupational Radiation Dose Limits Page 1 of 6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A LOCA has occurred.

An operator has a life threatening injury in the Train A Residual Heat Removal Pump Room.

Extremely high radiation levels require a volunteer to attempt a rescue to extract the injured operator from the RHR pump room.

The estimated dose to the rescuer is 55 Rem.

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

None of the volunteers have previously ever received a dose in excess of 10CFR20.1201 limits Initiating Cues: Select the best volunteer to attempt the rescue in accordance with HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose.

Complete Section 1 of CA0276, Authorization To Exceed Federal Occupational Dose Limits Task Upon completion of this JPM, Candidate selected Volunteer #5 to attempt the Standard: rescue of the injured operator in accordance with HDP-ZZ-01450 and completed Section 1 of CA0276 correctly in accordance with the KEY Start Time:

Stop Time:

Page 2 of 6

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

1. Operator obtains copy of Operator obtained copy of S U HDP-ZZ-01450, HDP-ZZ-01450, Authorization To Exceed Authorization To Exceed Federal Occupational Federal Occupational Comments:

Dose, CA0276, Dose, CA0276, Authorization To Exceed Authorization To Exceed Federal Occupational Federal Occupational Dose Limits, and list of Dose Limits, and list of volunteers volunteers

• 2. Operator reviews data Operator selected mike S U and selects volunteer Adams (Volunteer #5) from the list of volunteers Comments:

• 3. Completes Section 1 Operator completed S U CA0276 correctly Section 1CA0276 in accordance with the KEY (required items are circled) Comments:

Record stop time on S U Page 2 The JPM is complete Comments:

Page 3 of 6

• Critical Step

Authorization to Exceed Federal Occupational Radiation Dose Limits KEY

1. Name: Mike Adams ID (SSN, PPN): 56789 Age (years): 60 Estimated lifetime whole body dose (rem TEDE) provided by worker: 59.1 Has worker ever received a dose in excess of 10CFR20.1201 limits? YES NO Purpose of task: Accident Mitigation Personnel Safety Life Saving Task to be performed and justification for dose in excess of the limits of 10cfr20.1201 (attach additional pages if needed):

Attempt a rescue to extract the injured operator from the RHR pump room.

2. ATTESTATION:

I am aware of the risks involved in receiving a dose within the authorized limits and I have not previously received a dose in excess of the federal limits. For life saving dose limits above the Category 2 limits, I certify that I have volunteered.

Signature PIN Date WOMEN ONLY:

I have read and understand the potential effects on the fetus/embryo from doses in excess of the Occupational Dose Limits of 10CFR20.1201, and I voluntarily accept this assignment. I understand that I am encouraged to not volunteer for this task, and that there will be no repercussions if I elect to not volunteer.

Signature PIN Date

3. AUTHORIZATION:

The above individual is authorized to receive a dose in excess of the limits of 10CFR20.1201 within the following limits:

Category 1 - Life Saving Category 2 - Accident Mitigation/Personnel or Public Safety 100 rem DDE (guideline) 10 rem DDE 30 rem LDE 100 rem SDE 100 rem TODE APPROVED BY: Sr. Vice President Generation and Chief Nuclear Officer Vice President-Nuclear Operations Emergency Coordinator Recovery Manager Signature PIN Date Page 4 of 6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A LOCA has occurred.

An operator has a life threatening injury in the Train A Residual Heat Removal Pump Room.

Extremely high radiation levels require a volunteer to attempt a rescue to extract the injured operator from the RHR pump room.

The estimated dose to the rescuer is 55 Rem.

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

None of the volunteers have previously ever received a dose in excess of 10CFR20.1201 limits Initiating Cues: Select the best volunteer to attempt the rescue in accordance with HDP-ZZ-01450, Authorization To Exceed Federal Occupational Dose.

Complete Section 1 of CA0276, Authorization To Exceed Federal Occupational Dose Limits

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE List of Volunteers

1. Abe Ross (PPN 12345) is a 50 year old male with a lifetime dose of 54.5 Rem

2. Sue Smith (PPN 23456) is a 45 year old female with a lifetime exposure of 46.5 Rem

3. Cindy Jones (PPN 34567) is a 42 year old female with a lifetime exposure of 44.0 Rem

4. Jim Jay (PPN 45678) is a 36 year old male with a lifetime exposure of 44.0 Rem

5. Mike Adams (PPN 56789) is a 60 year old male with a lifetime dose of 59.1 Rem

6. Margo Rodriguez (PPN 67890) is a 22 year old female with a lifetime exposure of 29.5 Rem

7. Halley Faust (PPN 78901) is a 25 year old female with a lifetime exposure of 26.0 Rem

8. Nate Russell (PPN 89012) is a 63 year old male with a lifetime exposure of 64.0 Rem

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE A9 JPM Bank No: SRO-RER-02-A031(TC) KSA No: 2.4.44 Revision Date: 03/17/2016 KSA Rating: 4.4 Job

Title:

SRO Duty: ADMINISTRATIVE Task

Title:

MAKE PROTECTIVE ACTION RECOMMENDATION DURING A GENERAL EMERGENCY (TIME CRITICAL)

Completion Time: Less than 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

EIP-ZZ-00212, Protective Action Recommendations Rev 28 Tools / Equipment: None (Sentry computer use is NOT allowed during this JPM)

Page 1 of 5

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

Callaway Plant has been shutdown following a Reactor Trip due to indications of failed fuel and a Large Beak LOCA.

A minipurge was in progress when the LOCA occurred, and the minipurge Containment Outlet Isolation Valves could not be closed. Because of this, an on-going release to the atmosphere is occurring from the Containment. Attempts to control the release have failed and it is not known when the release will be terminated.

A General Emergency has been declared due to EAL FG1.1, Loss of any two barriers AND loss or potential loss of a third barrier.

• Containment radiation on GT RE-59 and GT RE-60 indicate 1.02E+05 Rem/hr.

• There are no indications of travel conditions that would present an extreme hazard during any recommended evacuation.

• Wind speed is 5 mph heading from 337°

• The Dose Assessment Technician has informed you there is a RELEASE ABOVE NORMAL OPERATING LIMITS with dose readings at the site boundary of 0.2 rem TEDE and 0.5 CDE Thyroid.

The SENTRY Computer is NOT working Initiating Make the Initial Protective Action Recommendation (PAR) based on the above conditions including Cues: affected sectors.

Task Standard: Upon completion of this JPM the applicant will have identified the PAR as Evacuate 2 Mile Radius and 10 miles downwind (Sectors G, H, J).

Start Time:

Stop Time:

Page 2 of 5

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

1. S U OPERATOR MAY USE Applicant reviewed copies THE EIP PROCEDURES of the various required procedures.

Comments:

2. Applicant will have S U Determine PAR determined this is a Rapidly Progressing accident Comments:

• 3. Applicant determined S U Determine PAR EVACUATE 2 mile radius and 10 miles downwind due to no impediments Comments:

• 4 Applicant determined the S U Include affected sectors affected sectors are G, H, and J using the table on page 6 of EIP-ZZ-00212 Comments:

4. JPM IS COMPLETE JPM must be S U completed within 15 minutes from the time the applicant Comments acknowledged the cues Page 3 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE KEY PAR: Evacuate 2 mile radius and 10 miles downwind, affected sectors are G, H, and J Page 4 of 5

• Critical Step

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

Callaway Plant has been shutdown following a Reactor Trip due to indications of failed fuel and a Large Beak LOCA.

A minipurge was in progress when the LOCA occurred, and the minipurge Containment Outlet Isolation Valves could not be closed. Because of this, an on-going release to the atmosphere is occurring from the Containment. Attempts to control the release have failed and it is not known when the release will be terminated.

A General Emergency has been declared due to EAL FG1.1, Loss of any two barriers AND loss or potential loss of a third barrier.

The Control Room Communicator arrived and made the correct Emergency Announcement using Attachment 1, of EIP-ZZ-00102 (provided).

• Containment radiation on GT RE-59 and GT RE-60 indicate 1.02E+05 Rem/hr.

• There are no indications of travel conditions that would present an extreme hazard during any recommended evacuation.

• Wind speed is 5 mph heading from 337°

• The Dose Assessment Technician has informed you there is a RELEASE ABOVE NORMAL OPERATING LIMITS with dose readings at the site boundary of 0.2 rem TEDE and 0.5 CDE Thyroid.

The SENTRY Computer is NOT working Initiating Cues: Make the Initial Protective Action Recommendation (PAR) based on the above conditions including affected sectors and document below.

PAR: __________________________________

(include affected sectors)

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 2 Facility: __Callaway___________________________ Date of Examination: _5/23/2016___

Exam Level: RO SRO-I SRO-U Operating Test No.: __2016-1_______

Control Room Systems:* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive System (SF) / Perform Control Rod D, S 1 Partial Movement Test S2 004 CVCS (BG) / Swap From the NCP to 'B' CCP A, D, S 2 S3 010 Pressurizer Pressure Control System (BB) / Respond to A, D, S 3 a Master Pressure Controller Failure S4 059 Main Feedwater System (AE) / Transfer Steam A, N, S 4S Generator Water Level Control S5 005 Residual Heat Removal System (EJ) / Transfer to Hot A, D, L, EN, S 4P Leg Recirculation S6 062 A.C. Electrical Distribution (PA) / Perform Operational D, P1, S 6 Testing of the Alternate Emergency Power Source S7 015 Nuclear Instrumentation System (SE) / Respond to a D, S 7 Failed Power Range Instrument S8 Containment Purge System (GT) / Remove Shutdown Purge N, L, S 8 System From Service In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P1 006 Emergency Core Cooling System (EP) / Secure Safety D, L 2 Injection Accumulators P2 035 Main and Reheat Steam System (AB) / Isolate a Failed A, M, E, R 4S Open Atmospheric Steam Dump P3 062 AC Electrical Distribution System (NN) / Transfer NN01 M 6 from Manual Bypass to Normal

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

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

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 2 A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 1 / 1 / 1 (control room system)

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

(R)CA 1/1/1 (S)imulator Note 1. The JPMs from the 2013 exam were randomly selected by placing 11 slips of paper labeled S1 through P3 in a hardhat. S6 was drawn from the hardhat.

S1 This is a BANK JPM. The JPM (URO-SSF-01-C005J) was used on the 2009 ILT NRC Exam. The applicant will be assigned the task of performing control rod partial movement for all shutdown banks, per OSP-SF-00002, Control Rod Partial Movement, beginning at step 6.1 Upon completion of this JPM, the applicant will have inserted all shutdown bank A control rods at least 12 steps into the core and restored them to their pretest position per procedural requirements.

S2 This is an ALTERNATE PATH, BANK JPM. The JPM (URO-SBG-02-C160J (A))

has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.The applicant will perform the actions of OTN-BG-00001, Addendum 1 to shift from the NCP to the B CCP. After the B CCP is started and during the transition from the NCP flow controller to the B CCP flow controller, the B CCP will Trip, requiring the applicant to restore charging flow. Upon completion of this JPM the applicant will have restored charging flow to normal.

S3 This is an ALTERNATE PATH, BANK JPM. The JPM (URO-SBB-04-C166J(A))

was used on the 2009 ILT NRC Exam. The applicant will be directed to to equalize RCS and Pressurizer Boron Concentration using OTG-ZZ-00004, Addendum 03. When the master pressure controller is taken to AUTO the PZR spray valves fail open requiring the applicant to manually close the spray valves.

Upon completion of this JPM, the master pressure controller failure has been addressed prior to a Reactor Trip being generated on low pressurizer pressure.

Page 2 of 4

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 2 S4 This is an ALTERNATE PATH, NEW JPM. The applicant will be assigned the task transferring Steam Generator Water Level Control from the MFRV Bypass Valves to the Main Feedwater Regulating Valves using OTN-AE-00001, Feedwater System. During the transfer the D MFRV will not open. The applicant will abort the automatic valve transfer and manually maintain SGWL. Upon completion of this JPM, the applicant will have transferred Steam Generator Water Level Control from the MFRV Bypass Valves to the MFRVs for SG A, B, and C and taken manual control of SG D water level without causing a Reactor Trip or Feedwater Isolation Signal due to high or low Steam Generator water level.

S5 This is an ALTERNATE PATH, The JPM (URO-AEO-02-C201J(A)) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.

The simulator will be set up following a large Loss of Coolant Accident. The applicant will be directed to transfer the Emergency Core Cooling System to the recirculation mode in accordance with ES-1.4, Transfer to Hot Leg Recirculation.

During performance, the applicant determines that HV8840 will not open and must use the alternate line up to achieve hot leg recirc. Upon completion of this JPM, the applicant will have aligned SI pumps to inject into the RCS hot legs.

S6 This is a BANK JPM that was used on the 2013 ILT NRC Exam (S6 on 2013 exam). It was randomly selected using the method described above. The applicant will be assigned the task of performing an online test of Alternate Emergency Power Source Diesel Generator #4 from the Control Room. Upon completion of this JPM, the applicant will have started AEPS Diesel Generator

1. 4, taken readings and secured the diesel.

S7 This is a BANK JPM. The JPM (URO-SSE-03-C126J) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will perform the actions of OTO-SE-00001, Nuclear Instrument Malfunction, Attachment A to bypass the Power Range NIS Channel N41 current comparator and rod stop inputs. Upon Completion of this JPM, Power Range NIS channel N41 current comparator and rod stop inputs will be bypassed.

S8 This is a NEW JPM. The applicant will perform the actions of OTN-GT-00001, Containment Purge System, to remove containment shutdown purge from service. Upon completion of this JPM, the applicant will have removed containment shutdown purge from service IAW OTN-GT-00001.

P1 This is a BANK JPM. The JPM (RO-SRO Au j) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will be assigned the task of locally securing Safety Injection accumulators per OTG-ZZ-00006, Addendum. Upon completion of this JPM, the applicant will have closed the SI Accumulator Outlet Isolation Valves and opened the feeder breakers to the SI accumulator outlet isolation valves.

Page 3 of 4

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 2 P2 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (EOP-SAB08077J(A)) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will be assigned the task of locally closing Atmospheric Steam Dumps, AB PV-3 AND AB PV-4. Upon completion of this JPM, the applicant will have closed AB PV-3 and isolated AB PV-4. AB PV-3 was closed by isolating Air/N2 from the valve. AB PV-4 was isolated by closing the manual isolation valve, ABV0007.

P3 This is a MODIFIED JPM. The parent JPM (EOS-SNN-03-P010J) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.

The applicant will be assigned the task of transferring NN01 to the normal power source per OTN-NN-00001. Upon completion of this JPM the applicant will have transferred NN01 to the normal power supply (inverter and NK01) without a loss of voltage.

Page 4 of 4

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 Facility: __Callaway___________________________ Date of Examination: _5/23/2016___

Exam Level: RO SRO-I SRO-U Operating Test No.: __2016-1_______

Control Room Systems:* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S1 001 Control Rod Drive System (SF) / Perform Control Rod D, S 1 Partial Movement Test S2 004 CVCS (BG) / Swap From the NCP to 'B' CCP A, D, S 2 S3 010 Pressurizer Pressure Control System (BB) / Respond to A, D, S 3 a Master Pressure Controller Failure S4 059 Main Feedwater System (AE) / Transfer Steam A, N, S 4S Generator Water Level Control S5 005 Residual Heat Removal System (EJ) / Transfer to Hot A, D, L, EN, S 4P Leg Recirculation S6 062 A.C. Electrical Distribution (PA) / Perform Operational D, P1, S 6 Testing of the Alternate Emergency Power Source S7 015 Nuclear Instrumentation System (SE) / Respond to a D, S 7 Failed Power Range Instrument In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P1 006 Emergency Core Cooling System (EP) / Secure Safety D, L, R 2 Injection Accumulators P2 035 Main and Reheat Steam System (AB) / Isolate a Failed A, M, E, R 4S Open Atmospheric Steam Dump P3 062 AC Electrical Distribution System (NN) / Transfer NN01 M 6 from Manual Bypass to Normal

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

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

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 1 / 1 / 1 (control room system)

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

(R)CA 1/1/1 (S)imulator Note 1. The JPMs from the 2013 exam were randomly selected by placing 11 slips of paper labeled S1 through P3 in a hardhat. S6 was drawn from the hardhat.

S1 This is a BANK JPM. The JPM (URO-SSF-01-C005J) was used on the 2009 ILT NRC Exam. The applicant will be assigned the task of performing control rod partial movement for all shutdown banks, per OSP-SF-00002, Control Rod Partial Movement, beginning at step 6.1 Upon completion of this JPM, the applicant will have inserted all shutdown bank A control rods at least 12 steps into the core and restored them to their pretest position per procedural requirements.

S2 This is an ALTERNATE PATH, BANK JPM. The JPM (URO-SBG-02-C160J (A))

has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.The applicant will perform the actions of OTN-BG-00001, Addendum 1 to shift from the NCP to the B CCP. After the B CCP is started and during the transition from the NCP flow controller to the B CCP flow controller, the B CCP will Trip, requiring the applicant to restore charging flow. Upon completion of this JPM the applicant will have restored charging flow to normal.

S3 This is an ALTERNATE PATH, BANK JPM. The JPM (URO-SBB-04-C166J(A))

was used on the 2009 ILT NRC Exam. The applicant will be directed to to equalize RCS and Pressurizer Boron Concentration using OTG-ZZ-00004, Addendum 03. When the master pressure controller is taken to AUTO the PZR spray valves fail open requiring the applicant to manually close the spray valves.

Upon completion of this JPM, the master pressure controller failure has been addressed prior to a Reactor Trip being generated on low pressurizer pressure.

Page 2 of 4

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 S4 This is an ALTERNATE PATH, NEW JPM. The applicant will be assigned the task transferring Steam Generator Water Level Control from the MFRV Bypass Valves to the Main Feedwater Regulating Valves using OTN-AE-00001, Feedwater System. During the transfer the D MFRV will not open. The applicant will abort the automatic valve transfer and manually maintain SGWL. Upon completion of this JPM, the applicant will have transferred Steam Generator Water Level Control from the MFRV Bypass Valves to the MFRVs for SG A, B, and C and taken manual control of SG D water level without causing a Reactor Trip or Feedwater Isolation Signal due to high or low Steam Generator water level.

S5 This is an ALTERNATE PATH, The JPM (URO-AEO-02-C201J(A)) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.

The simulator will be set up following a large Loss of Coolant Accident. The applicant will be directed to transfer the Emergency Core Cooling System to the recirculation mode in accordance with ES-1.4, Transfer to Hot Leg Recirculation.

During performance, the applicant determines that HV8840 will not open and must use the alternate line up to achieve hot leg recirc. Upon completion of this JPM, the applicant will have aligned SI pumps to inject into the RCS hot legs.

S6 This is a BANK JPM that was used on the 2013 ILT NRC Exam (S6 on 2013 exam). It was randomly selected using the method described above. The applicant will be assigned the task of performing an online test of Alternate Emergency Power Source Diesel Generator #4 from the Control Room. Upon completion of this JPM, the applicant will have started AEPS Diesel Generator

1. 4, taken readings and secured the diesel.

S7 This is a BANK JPM. The JPM (URO-SSE-03-C126J) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will perform the actions of OTO-SE-00001, Nuclear Instrument Malfunction, Attachment A to bypass the Power Range NIS Channel N41 current comparator and rod stop inputs. Upon Completion of this JPM, Power Range NIS channel N41 current comparator and rod stop inputs will be bypassed.

P1 This is a BANK JPM. The JPM (RO-SRO Au j) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will be assigned the task of locally securing Safety Injection accumulators per OTG-ZZ-00006, Addendum 06. Upon completion of this JPM, the applicant will have closed the SI Accumulator Outlet Isolation Valves and opened the feeder breakers to the SI accumulator outlet isolation valves.

Page 3 of 4

ES-301 Control Room/In-Plant Systems Outline Form ES-301-2 Rev 1 P2 This is an ALTERNATE PATH, MODIFIED JPM. The parent JPM (EOP-SAB08077J(A)) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014. The applicant will be assigned the task of locally closing Atmospheric Steam Dumps, AB PV-1 AND AB PV-4. Upon completion of this JPM, the Applicant will have closed AB PV-1 and isolated AB PV-4. AB PV-1 was closed by isolating Air/N2 from the valve. AB PV-4 was isolated by closing the manual isolation valve, ABV0007.

P3 This is a MODIFIED JPM. The parent JPM (EOS-SNN-03-P010J) has not been used on an NRC ILT Exam administered at Callaway between 2004 and 2014.

The applicant will be assigned the task of transferring NN01 to the normal power source per OTN-NN-00001. Upon completion of this JPM the applicant will have transferred NN01 to the normal power supply (inverter and NK01) without a loss of voltage.

Page 4 of 4

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S1 JPM Bank No: URO-SSF-01-C005J KSA No: 001A4.03 Revision Date: 04/27/2016 KSA Rating: 4.0 / 3.7 Job

Title:

URO/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:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OSP-SF-00002, CONTROL ROD PARTIAL MOVEMENT Rev 22 Tools / Equipment: none Page 1 of 7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 normal configuration.

Initiating Cues: The CRS has directed you to perform control rod partial movement for shutdown bank A, per OSP-SF-00002, Control Rod Partial Movement, beginning at step 6.1 The Primary OT has been briefed and is at the power cabinets.

Note: Use any MODE 1 IC Task Standard: Upon completion of this JPM all shutdown bank A control rods will have been inserted at least 12 steps into the core and restored to their pretest position per procedural requirements.

Start Time:

Stop Time:

Page 2 of 7

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

1. Provide applicant with Applicant obtained S U procedure copy procedure copy Comments:

2. Review Precautions and Precautions and Applicant reviewed S U Limitations Limitations are satisfied Precautions and Limitations Section 4.0 NOTE: If asked, the Comments:

monthly rod position test has not been performed yet.

3. Review Prerequisites Prerequisites are Applicant reviewed S U satisfied Prerequisites Section 5.0 If asked Comments The CRS has Key #149 for the Rod Control Cabinets, replacement neon bulbs for Group Select, Group Hold and Power ON, and replacement 28 VDC bulbs for the failure lamps (Urgent and P.S.)

and the Group cycling lamp

4. NOTE: A cabinet without Applicant read note S U any Group Select Light illuminated may indicate a bad light bulb OR a Comments blown multiplexer fuse.

Moving rods without the correct Group Select Light illuminated could result in dropped or mispositioned rods.

Note prior to Step 6.1 Page 3 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 5. PLACE SE HS-9, ROD Applicant PLACED SE S U BANK AUTO/MAN SEL, HS-9, ROD BANK in the Shutdown Bank to AUTO/MAN SEL, in the be tested and INITIAL Shutdown Bank A position Comments Attachment 1. and INITIALED Attachment 1.

Step 6.1.1

6. At Power Cabinets, Respond as the Primary Applicant ENSURED the S U ENSURE the proper OT: proper lights (Group Select lights are on for the Light C) are on for the At Power Cabinet 1AC selected bank and selected bank and Comments and 2AC, Group Select INITIAL Attachment 1: INITIALED Attachment 1:

Light C is ON Step 6.1.2

7. RECORD the Shutdown Applicant RECORDED the S U Bank Step Counter Shutdown Bank Step position for the selected Counter position for the bank on Attachment 1. selected bank on Comments Attachment 1.

Step 6.1.3

8. IF the selected bank is Applicant IDENTIFIES the S U parked at a fully selected bank is parked at withdrawn position of a fully withdrawn position other than 228 steps, of 228 steps, and does not Comments INSERT or WITHDRAW move the rods at this step the bank to 228 steps as indicated by the step counters and Digital Rod Position Indication.

Step 6.1.4

9. RECORD SF 074, ROD Applicant RECORDED SF S U POS INDICATION 074, ROD POS (DRPI) and Shutdown INDICATION (DRPI) and Bank Step Counter Shutdown Bank Step Comments positions on Attachment Counter positions on

1. Attachment 1.

Step 6.1.5

• 10. INSERT the selected Applicant INSERTED the S U bank two (2) steps per selected bank two (2) step counter indication. steps per step counter indication. Comments Step 6.1.6 Page 4 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 11. WITHDRAW the selected Applicant WITHDREW the S U bank to 228 steps per selected bank to 228 step counter indication. steps per step counter indication. Comments Step 6.1.7

12. CHECK that no rod Applicant CHECKED that S U control alarms are no rod control alarms are present. present.

Comments Step 6.1.8

• 13. INSERT the selected Annunciator 79C will Applicant INSERTED the S U bank 10 steps and alarm during this step. selected bank 10 steps CHECK that DRPI is This information is given and CHECK that DRPI is indicating properly. in the Precautions and indicating properly. Comments Limitation Step 4.6 Step 6.1.9

• 14. INSERT the selected Applicant INSERTED the S U bank at least two (2) selected bank at least two more steps as indicated (2) more steps as by the step counters and indicated by the step Comments DRPI. counters and DRPI.

Step 6.1.10

15. RECORD DRPI and Applicant RECORDED S U Shutdown Bank Step DRPI and Shutdown Bank Counter positions for the Step Counter positions for selected bank on the selected bank on Comments Attachment 1. Attachment 1.

Step 6.1.11

• 16. RETURN selected bank Applicant RETURNED S U to the position recorded selected bank to the at Step 6.1.3. position recorded at Step 6.1.3. Comments Step 6.1.12 Page 5 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

17. RECORD DRPI and Applicant RECORDED S U Shutdown Bank Step DRPI and Shutdown Bank Counter positions for Step Counter positions for selected bank and selected bank and INITIAL Comments INITIAL on Attachment 1. on Attachment 1.

Step 6.1.13

18. REPEAT steps 6.1.1 Only testing Shutdown Applicant reported to the S U through 6.1.13 as Bank A per the CUE CRS that Shutdown Bank necessary to test the A has been tested remaining Shutdown Comments Step 6.1.14 Banks.

Step 6.1.14

19. JPM IS COMPLETE RECORD STOP TIME ON PAGE 2.

Page 6 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 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 normal configuration.

Initiating Cues: The CRS has directed you to perform control rod partial movement for shutdown bank A, per OSP-SF-00002, Control Rod Partial Movement, beginning at step 6.1 The Primary OT has been briefed and is at the power cabinets.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S2 JPM No: URO-SBG-02-C160J(A) KSA No: 004A4.08 Revision Date: 04/02/2014 KSA Rating: 3.8 / 3.4 Job

Title:

URO/SRO Duty: CVCS Task

Title:

Swap from the NCP to B CCP Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTN-BG-00001 ADD 1, Shifting from the NCP to One of the CCPs Rev 11 Tools / Equipment: none Page 1 of 9

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The NCP is running with 75 GPM letdown flow.

Preparations have been made to tag out the NCP.

Initiating Cues: The CRS has directed you to place the B CCP in service and secure the NCP per OTN-BG-00001 ADD 1, Shifting from the NCP to one of the CCPs, and beginning at step 5.1. Inform the CRS when complete.

The boron concentration when the B CCP was run last week was 5 PPM higher than the existing boron concentration.

An OT has been briefed and is standing by to perform local actions Notes: USE IC-10, ENSURE THE NCP AND B CCW ARE RUNNING. ENSURE LETDOWN FLOW IS 75 GPM AND BG HV-8111 IS OPEN (B CCP MINIFLOW).

AFTER the applicant has performed Step 5.1.3 (JPM step 8) and lowered CCP discharge flow control to minimum:

• Insert Malfunction (BG) PBG05B, Value = Trip; condition HWX01D148M GE 0.30 (This will trip the B CCP after flow is increased)

Task Standard: Upon completion of this JPM the applicant will have restored charging flow to normal Start Time:

Stop Time:

Page 2 of 9

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

1. OBTAIN A VERIFIED APPLICANT OBTAINED S U WORKING COPY OF PROCEDURE COPY OTN-BG-00001 ADD 1, Shifting from the NCP to one of the CCPs Comments:

2. REVIEW ALL PRECAUTIONS APPLICANT REVIEWED S U PRECAUTIONS AND AND LIMITATIONS ARE PRECAUTIONS AND LIMITATIONS SATISFIED LIMITATIONS SECTIONS 3.1 AND 3.2 Comments:

3. REVIEW GENERAL APPLICANT REVIEWED S U NOTES APPLICABLE GENERAL NOTES SECTION 3.3 Comments:

4. REVIEW ALL PREREQUISITE APPLICANT REVIEWED S U PREREQUISITES CONDITIONS ARE PREREQUISITE SATISFIED CONDITIONS SECTION 4.0 Comments:

5. NOTE: ALL HAND APPLICANT READ S U SWITCHES NOTE.

REFERENCED IN THIS Comments:

SECTION ARE LOCATED ON RL001 OR RL002 UNLESS NOTED OTHERWISE.

TRANSFERRING CHARGING PUMPS WILL CAUSE AREA RADIATION LEVELS TO CHANGE IN BOTH PUMP ROOMS.

NOTE PRIOR TO STEP5.1.1 Page 3 of 9

• Critical Step

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

6. NOTIFY RP THAT B RP ACKNOWLEDGES APPLICANT INFORMED S U CCP WILL BE STARTED RP THAT B CCP WILL AND THE NCP WILL BE BE STARTED AND NCP SECURED. WILL BE SECURED Comments:

STEP 5.1.1

7. ENSURE B CCP IS APPLICANT VERIFIED B S U SUPPLIED BY B CCW CCW TRAIN IS IN TRAIN IN SERVICE SERVICE STEP 5.1.2 Comments:

• 8. PLACE BG FK-121, CCP APPLICANT PLACED BG S U DISCH FLOW CTRL, IN FK-121, CCP DISCH MANUAL AND SET AT FLOW CTRL, IN MINIMUM FLOW MANUAL AND SET TO MINIMUM FLOW.

Comments:

STEP 5.1.3 BG FK-121 MANUAL LIGHT COMES ON AND AUTO LIGHT GOES OFF.

9. CAUTION: APPLICANT READ S U The CCPs should NOT CAUTION.

be run at less than 130 Comments:

gpm, (including recirc flow), for more than 30 minutes.

The CCPs should NOT be run at less than 60 gpm. The CCP recirculation valves ensure 60 gpm recirc to the VCT. [Ref: 6.2.7].

CAUTION PRIOR TO STEP 5.1.4 Page 4 of 9

• Critical Step

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

10. CHECK THE APPLICANT VERIFIED S U CHARGING PUMP BG HV-8111 IS OPEN BY RECIRCULATION VERIFYING BG HIS-8111 VALVE FOR THE PUMP RED LIGHT IS ON AND TO BE STARTED IS GREEN LIGHT IS OFF Comments:

OPEN:

BG HIS-8111, CCP B RECIRC VLV STEP 5.1.4

11. PLACE THE AUXILIARY APPLICANT STARTED S U LUBE OIL PUMP B CCP AUXILIARY HANDSWITCH FOR LUBE OIL PUMP THE CCP TO BE STARTED IN AUTO BG HIS-2AX RED LIGHT Comments:

AND ENSURE THE RUN IS ON AND GREEN LIGHT IS ON. LIGHT GOES OFF BG HIS-2AX, CCP B AUX L-O PUMP STEP 5.1.5

12. NOTE: IT IS Cue 5 MINUTES HAS APPLICANT READS S U RECOMMENDED THAT ELAPSED NOTE AND STATES THE AUXILIARY LUBE THEY WILL WAIT 5 OIL PUMP BE MINUTES BEFORE ALLOWED TO RUN STARTING THE CCP Comments:

FOR AT LEAST 5 MINUTES PRIOR TO STARTING THE ASSOCIATED CCP.

NOTE PRIOR TO STEP5.1.6

• 13. START B CCP USING APPLICANT STARTED S U BG HIS-2A B CCP PLACING BG HIS-2A TO RUN.

STEP 5.1.6 BG HIS-2A RED LIGHT Comments:

GOES ON AND GREEN LIGHT GOES OFF Page 5 of 9

• Critical Step

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

14. Locally VERIFY that the When the applicant APPLICANT VERIFIED S U Room Cooler has started contacts an OT to locally SGL12B, AUX BLD CCP for the CCP that was verify that the room B RM CLR IS IN started. cooler has started: SERVICE Comments:

SGL12B, AUX BLD CCP CUE: SGL12B, AUX B RM CLR, for CCP B BLD CCP B RM CLR has started.

STEP 5.1.7 NOTE: STEP 5.1.8 IS NOT REQUIRED

15. IF THIS ADDENDUM APPLICANT S U WAS ENTERED FROM DETERMINES THIS SECTION FOR STEP IS NOT CHARGING PUMP APPLICABLE.

BREAKER NB0104 OR Comments:

NB0201 OPERABILITY CHECK IN OTN-BG-00001, CHEMICAL AND VOLUME CONTROL SYSTEM, CHECK THE CCP BREAKER CLOSED PROPERLY STEP 5.1.8

16. NOTE: If the Aux Lube APPLICANT READ S U Oil Pump remains in NOTE.

service following the next step, the system engineer should be Comments:

notified.

17. VERIFY 'B' AUXILIARY APPLICANT VERIFIED 'B' S U LUBE OIL PUMP AUX LUBE OIL PUMP HANDSWITCH BG HIS- HAS STOPPED WITH 2AX RED LIGHT HAS HANDSWITCH BG HIS-GONE OUT AND STOP 2AX Comments:

LIGHT HAS LIT BG HIS-2AX GREEN STEP 5.1.9 LIGHT IS ON AND RED LIGHT IS OFF Page 6 of 9

• Critical Step

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

• 18. PLACE THE NCP FLOW APPLICANT PLACED BG S U CONTROLLER, BG FK-124 IN MANUAL FK-124 IN MANUAL and observes BG FK-124 MANUAL LIGHT STEP 5.1.10 COMES ON AND AUTO Comments:

LIGHT GOES OFF

19. NOTE: IF BGHV8109, APPLICANT READ S U NCP RECIRC VLV, is NOTE.

closed and flow through the NCP drops below 100 gpm, Annunciator Comments:

Window 41F, NCP FLOW HI/LO, will alarm.

IF flow through the NCP drops below 65 gpm, Annunciator Window 41F, NCP FLOW HI/LO, will reflash and BGHV8109, NCP RECIRC VLV, will open.

BGHV8109, NCP RECIRC VLV, is opened when lowering NCP flow to prevent a transient in seal injection flow.

Steps 5.1.11 through 5.1.13 should be performed together to enable transfer of the pumps.

20. WHEN FLOW APPLICANT ENSURED S U THROUGH THE NCP IS BGHV8109 WAS OPEN LESS THAN 100 GPM, AS INDICATED BY ANNUNCIATOR Comments:

WINDOW 41F, USE BG HIS-8109, NCP RECIRC VLV AND OPEN BGHV8109.

STEP 5.1.11 Page 7 of 9

• Critical Step

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

21. RAISE CCP flow using WHEN BG FK-124, NCP APPLICANT RAISED S U BG FK-121, CCP DISCH DISCH FLOW CTRL CCP flow using BG FK-FLOW CTRL, while HAS BEEN ADJUSTED 121, CCP DISCH FLOW LOWERING NCP flow TO LOWER NCP FLOW, CTRL, and LOWERED using BG FK-124, NCP NCP flow using BG FK- Comments:

DISCH FLOW CTRL, to Start of Alternate path 124, NCP DISCH FLOW maintain a constant CTRL charging flow as Simulator operator indicated on BG FI-121A, verifies the conditional ANNOUNCED THAT B CHG HDR FLOW. STEP malfunction to trip the CCP HAS TRIPPED 5.1.12 B CCP is inserted.

• 22. ADJUST BG FK-124 IF the applicant asks the APPLICANT INCREASED S U AND BG HC-182 AS CRS what to do, respond NCP FLOW USING BG REQUIRED TO What actions do you FK-124 MAINTAIN THE recommend? After the FOLLOWING: applicant describes the Comments:

actions they will take

• SEAL INJ FLOW 8- state Take the actions 13 GPM / RCP you have described

• CHARGING FLOW (Do not tell the applicant MAINTAINING what to do. Agree with STABLE PZR whatever actions the applicant describes)

Note: At this point the Applicant will stop performing steps of OTN-BG-00001 ADD1

23. INFORM THE THE CONTROL ROOM APPLICANT INFORMED S U CONTROL ROOM SUPERVISOR THE CONTROL ROOM SUPERVISOR THE NCP ACKNOWLEDGES SUPERVISOR THE NCP HAS BEEN RESTORED HAS BEEN RESTORED TO SERVICE THE JPM IS TO SERVICE Comments:

COMPLETE Page 8 of 9

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The NCP is running with 75 GPM letdown flow.

Preparations have been made to tag out the NCP.

Initiating Cues: The CRS has directed you to place the B CCP in service and secure the NCP per OTN-BG-00001 ADD 1, Shifting from the NCP to one of the CCPs, and beginning at step 5.1. Inform the CRS when complete.

The boron concentration when the B CCP was run last week was 5 PPM higher than the existing boron concentration.

An OT has been briefed and is standing by to perform local actions

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S3 JPM No: URO-SBB-04-C166J(A) KSA No: 010A4.01 Revision Date: 03/09/2016 KSA Rating: 3.7 / 3.5 Job

Title:

URO/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:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTG-ZZ-00004, Addendum 03, Planned Power Changes From Full Power Revision 008 Tools / Equipment: None Page 1 of 5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1 at 100% Power.

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.1 through 3.

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

INSERT the malfunction AFTER the controller is taken to MANUAL.

• Insert malfunction BBPC0455A_1, Value = 10 o Ramp = 30 seconds o Conditional = hwx02o58A eq 1 (This will fail both spray valves open when BB PK-455A is returned to auto.)

Task Standard: Upon completion of this JPM, the master pressure controller failure has been addressed prior to a Reactor Trip being generated on low pressurizer pressure.

Start Time:

Stop Time:

Page 2 of 5

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

1. OBTAIN A VERIFIED APPLICANT OBTAINED S U WORKING COPY OF PROCEDURE COPY OTG-ZZ-00004, Addendum 03 Comments:

2. REVIEW APPLICANT REVIEWED S U PRECAUTIONS AND PRECAUTIONS AND LIMITATIONS LIMITATIONS SECTION 3 Comments:

3. REVIEW APPLICANT REVIEWED S U PREREQUISITES PREREQUISITES SECTION 4 Comments:

S U

• 4.

ENSURE AT LEAST PZR BACKUP HEATERS OPERATOR PLACED BB ONE GROUP OF ARE ENERGIZED HIS-51A AND/OR BB HIS- Comments:

PRESSURIZER 52A IN CLOSE BACKUP HEATERS ARE ENERGIZED (ONLY ONE SWITCH REQUIRED TO BE Step 5.4.1.h.1 PLACED IN CLOSE)

S U

• 5.

PLACE BB PK-455A IN OPERATOR PLACED BB MANUAL AND LOWER PK-455A IN MANUAL Comments:

TO 40% AND LOWERS TO 40%

Step 5.4.1.h.2 S U

• 6.

PLACE BB PK-455A IN OPERATOR PLACED BB AUTO PK-455A IN AUTO Comments:

Start of ALTERNATE PATH Step 5.4.1.h.3 Page 3 of 5

• Critical Step

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

• 7.

BOTH PRESSURIZER OPERATOR SPRAY VALVES, RECOGNIZED SPRAY Comments:

BBPCV0455B AND VALVES HAVE FAILED BBPCV0455C, FAIL OPEN AND CLOSES OPEN WHEN BOTH SPRAY VALVES BB PK-455A IS PLACED PRIOR TO A REACTOR INTO AUTO TRIP BEING GENERATED ON LOW PRESSURIZER PRESSURE This can be accomplished by using either the Master Controller or taking the individual spray valves to manual and closing the valves S U 8.

JPM COMPLETE Comments:

Page 4 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1 at 100% Power.

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.1 through 3.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S4 JPM Bank No: N/A KSA No: 059A2.12 Revision Date: 04/27/2016 KSA Rating: 3.1 / 3.4 Job

Title:

URO/SRO Duty: Main feedwater Task

Title:

Transferring from MFRV Bypass Valves to MFRVs- AUTOMATIC METHOD with valve failure Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTN-AE-00001, FEEDWATER SYSTEM Rev 54 Tools / Equipment: none Page 1 of 8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Callaway Plant is in Mode 1 at 22-25% 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, Section 5.10.

Steps 5.10.1 through 5.10.15 of OTN-AE-00001 have been completed.

An OT is at the MFRVs.

Note: Use Any IC (IC 5) approx. 22-25% power with Bypass FRV's in service

• Insert Malfunction AEFCV0540_A , Value = 0.0 (prevents the D MFRV from opening)

Task Standard: Upon completion of this JPM, the applicant will have transferred Steam Generator Water Level Control from the MFRV Bypass Valves to the MFRVs for SG A, B, and C and taken manual control of SG D water level without causing a Reactor Trip or Feedwater Isolation Signal due to high or low Steam Generator water level.

Start Time:

Stop Time:

Page 2 of 8

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

1. Provide Applicant with Applicant obtained S U procedure copy procedure copy Comments:

2. Review Precautions and All Precautions and Applicant reviewed S U Limitations Limitations are satisfied Precautions and Limitations Section 3.0 Comments:

3. Review Prerequisites There are no S U Prerequisites Section 4.0 Comments

4. NOTE: Attachment 1 Applicant read note S U contains a list of plant computer points that may be used to monitor low Comments range feed/steam flows or SG levels.

Steps 5.10.1 through 5.10.15 can be performed at any power level.

Note prior to Step 5.10.1 NOTE The initiating cues staes steps 5.10.1 through 5.10.15 have been completed

5. NOTE: MFRV Bypass Applicant read note S U choked flow occurs at approximately 600 psid.

Comments Note prior to Step 5.10.16

6. VERIFY FC SK-509A, Applicant verified FC SK- S U MFP TURBS MASTER 509A is in AUTO SPEED CTRL is in AUTO Comments Step 5.10.16 Page 3 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

7. VERIFY operating MFP Applicant verified AE SK- S U Turbine Speed Control is 509B is in AUTO in AUTO Applicant verified AE SK-Comments

• A MFP - AE SK- 509C is in MANUAL 509B

• B MFP - AE SK-509C Step 5.10.17

8. NOTE: To abort an Applicant read note S U AUTOMATIC Valve Transfer, PLACE the affected Steam Comments:

Generators MFRV/

MFRBV valve controller in MANUAL and HOLD until both MFRV and MFRBV valve controllers MANUAL buttons are lit and not blinking. The non-affected Steam Generator valve transfers will continue.

To stop/reset the 720-second automatic valve transfer timer, place ALL MFRV/MFRBV controllers in MANUAL.

An AUTOMATIC valve transfer will be again possible when all permissives are satisfied.

Refer to Attachment 3 for a list of Automatic Valve Transfer Permissives.

Note prior to Step 5.10.18

9. Caution: If any AUTO Applicant read caution S U Sequence Step does not complete as expected, then take MANUAL Comments Control as needed and complete remaining transfer functions per section 5.10, Transferring from MFRV Bypass Valves to MFRVs -

MANUAL METHOD Caution prior to Step 5.10.18 Page 4 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

10. IF MFRVs will be CUE CRS directs Applicant does not perform S U transferred separately, transfer AUTO transfer steps 5.10.25 through perform steps 5.10.25 to be performed 5.10.28.

through 5.10.28 for simultaneously instead Comments AUTO transfer of of separately INDIVIDUAL Steam Generator Control Valves.

Step 5.10.18

11. ENSURE SG Level Applicant ensured SG S U Control Valve Selection Level Control Valve AE SS-500A XFR Selection AE SS-500A Buttons are ENABLED XFR Buttons are Comments ENABLED

• SG A

• SG B

• SG A

• SG C

• SG B

• SG D

• SG C

• ALL SGs

• SG D

• ALL SGs Step 5.10.19

12. ENSURE MFP DELTA P Applicant ensured MFP S U Control Selector FC PS- DELTA P Control Selector 509 is in LOW POWER FC PS-509 is in LOW and the XFR Button is POWER and the XFR Comments ENABLED. Button is ENABLED.

Step 5.10.20

• 13. ACTUATE ALL Steam Applicant actuated ALL S U Generators XFR button Steam Generators XFR on SG Level Control button on SG Level Valve Selector, AE SS- Control Valve Selector, AE Comments 500A. SS-500A.

Step 5.10.21 Page 5 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

14. VERIFY the following This is the start of the Applicant verified the S U sequence occurs: Alternate Path. The following sequence:

applicant should

a. AE SS-500A, SG a. AE SS-500A, SG recognize that the D Comments:

Level Control Valve Level Control Valve MFRV does not start to Selection, each SG Selection, each SG open XFR button GREYS XFR button GREYS out. out.

b. ALL SG MFRV and b. ALL SG MFRV and MFRV Bypass Valves MFRV Bypass Valves controllers controllers AUTO/MAN indicators AUTO/MAN indicators begin FLASHING begin FLASHING

c. ALL MFRV Bypass c. ALL MFRV Bypass Valves begin Valves begin CLOSING CLOSING

d. ALL MFRVs begin d. ALL MFRVs begin OPENING OPENING Step 5.10.22 (partial)

• 15. PLACE the D Steam Applicant PLACED the D S U Generators MFRV/ Steam Generators MFRV/

MFRBV valve controller MFRBV valve controller in in MANUAL and HOLD MANUAL and HOLD until Comments:

until both MFRV and both MFRV and MFRBV MFRBV valve controllers valve controllers MANUAL MANUAL buttons are lit buttons are lit and not and not blinking. The A, blinking.

B, and C Steam Generator valve transfers will continue.

Note prior to Step 5.10.18

• 16 If any AUTO Sequence Applicant took manual S U Step does not complete control of D SG level and as expected or is did not allow a SG terminated by operator isolation signal to develop. Comments:

action, then take MANUAL Control as needed and complete remaining transfer functions for the D Steam Generator(s)per section 5.11, Transferring from MFRV Bypass Valves to MFRVs -

MANUAL METHOD.

Caution prior to Step 5.10.18 Page 6 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

17. VERIFY the following Applicant verified the S U sequence occurs: following sequence for the A, B, and C SGs

e. WHEN MFRV Bypass Comments:

Valves CLOSE, e. WHEN MFRV Bypass MFRV Bypass Valve Valves CLOSE, MFRV controllers transfers Bypass Valve to MANUAL controllers transfers to

f. WHEN MFRV Bypass MANUAL Valves CLOSED, f. WHEN MFRV Bypass MFRV Valve Valves CLOSED, controllers transfer to MFRV Valve controllers AUTOMATIC transfer to

g. FC PS-509 MFP AUTOMATIC DELTA P Control Steps g thru k will not Selector, HIGH Power occur due to aborted and LOW Power both transfer FLASHING.

h. FC SK-509A, Feed Pump Master Control, DELTA P Setpoint LOWERS to HIGH Power Program Setpoint.

i. MFP in OPERATION Speed Lowering.

j. FC SK-509A, Feed Pump Master Control, DELTA P LOWERING.

k. The FC PS-509 MFP DELTA P Control Selector HIGH POWER light comes ON, and LOW POWER light goes OFF, When DELTA P reaches approximately 3-5 psid of the High Power Program setpoint.

Step 5.10.22

18. The JPM is complete THIS JPM IS Applicant informed CRS S U after the applicant has COMPLETE that the A, B, and C transferred the A, B, FRVs have transferred and C SGs to the and that the D SG level is Comments MFRVs and the D SG being manually controlled level is being manually using the MFRV Bypass controlled valve due to the D MFRV not opening.

Page 7 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The Callaway Plant is in Mode 1 at 22-25% 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, Section 5.10.

Steps 5.10.1 through 5.10.15 of OTN-AE-00001 have been completed.

An OT is at the MFRVs.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S5 JPM No: URO-AEO-02-C201J(A) KSA No: 011EA1.13 Revision Date: 06/03/2015 KSA Rating: 4.1 / 4.2 Job

Title:

URO/SRO Duty: EMERGENCY ACTIONS Task

Title:

TRANSFER TO HOT LEG RECIRCULATION - No RHR Flow Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

ES-1.4, TRANSFER TO HOT LEG RECIRCULATION, REVISION 9 Tools / Equipment: None Page 1 of 9

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: THE PLANT HAS EXPERIENCED A LARGE BREAK LOCA.

TRANSFER TO COLD LEG RECIRC WAS COMPLETED APPROXIMATELY 12 HOURS AGO.

IT HAS NOW BEEN 13 HOURS SINCE EVENT INITIATION.

Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO TRANSFER TO HOT LEG RECIRC PER ES-1.4, TRANSFER TO HOT LEG RECIRCULATION INFORM THE CONTROL ROOM SUPERVISOR WHEN STEP 2 OF ES-1.4 HAS BEEN COMPLETED.

Notes:

1. SELECT A MODE 2 OR ABOVE IC. (IC 169 contains step 2 thru 5 inserted below)

2. Insert a large RCS leak

• MALFUNCTION (BB) BB001_B, Value = 75000, ramp 10 sec

3. CHANGE PARAMETER RWST LEVEL TO 16%

• (BN) TBN01TAZTLIL, Value = 16%

4. SWAP ECCS TO COLD LEG RECIRC PER ES-1.3

5. FRZ SIMULATOR UNTIL READY TO PERFORM JPM

6. Secured containment spray

7. Fail HV8840 closed

• ME Schematic (EJ) m22ej01, select valve HV8840, Fail to specified position, EJHV8840_MTVFAILSP, value = 0 Task Standard: UPON COMPLETION OF THIS JPM, THE APPLICANT WILL HAVE ALIGNED SI PUMPS TO INJECT INTO THE RCS HOT LEGS.

Start Time:

Stop Time:

Page 2 of 9

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

1. Provide Applicant with APPLICANT OBTAINED S U Procedure copy PROCEDURE COPY Comments:

2. Check NG02 APPLICANT CHECKED S U ENERGIZED NG02 IS ENERGIZED STEP 1.a NG HIS-12 RED LIGHT IS Comments:

ON AND GREEN LIGHT IS OFF

3. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT SWITCH for HIS-8809BA IN NON ISO EJ HIS-8809B, IN NON NON ISO LIGHT COMES ISO POSITION Comments:

ON FOR EJ HIS 8809BA

• EJ HIS-8809BA STEP 1.b.1)

4. CLOSE RHR TO APPLICANT S U ACCUMULATOR DEPRESSED CLOSE INJECTION LOOPS 3 PUSHBUTTON FOR RHR AND 4 valve TO ACCUMULATOR Comments:

INJECTION LOOPS 3

• EJ HIS-8809B AND 4, EJ HIS-8809B STEP 1.b.2) EJ HIS 8809B GREEN LIGHT GOES ON AND RED LIGHT GOES OFF

5. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT for, EJ HIS- HIS-8809BA IN ISO 8809B, IN ISO NON ISO LIGHT GOES POSITION Comments:

OFF FOR EJ HIS-8809BA

• EJ HIS-8809BA STEP 1.b.3)

Page 3 of 9

• Critical Step

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

6. OPEN RHR TRAIN 'B' APPLICANT S U HOT LEG RECIRC DEPRESSED OPEN VALVE PUSHBUTTON FOR RHR TRAIN 'B' HOT LEG Comments:

• EJ HV-8716B RECIRC VALVE, EJ STEP 1.c HIS-8716B EJ HIS-8716B RED LIGHT GOES ON AND GREEN LIGHT GOES OFF

7. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT SWITCH, EJ HIS-8840A IN NON ISO HIS-8840, IN NON ISO NON ISO LIGHT COMES POSITION Comments:

ON FOR EJ HIS 8840A

• EJ HIS-8840A STEP 1.d.1)

8. OPEN RHR HOT LEG START OF ALTERNATE APPLICANT S U RECIRC VALVE PATH DEPRESSED RHR HOT EJ HV-8840 AND LEG RECIRC VALVE EJ ENSURE RHR FLOW HIS-8840 OPEN Comments:

ON EJ FI-988 PUSHBUTTON STEP 1.d.2 EJ HIS-8840 RED LIGHT DOES NOT GO ON AND GREEN LIGHT STAYS ON EJ FI-988 INDICATES 0 GPM

• 9. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT SWITCH, EJ HIS-8840A IN ISO HIS-8840, IN ISO NON ISO LIGHT GOES POSITION Comments:

OFF FOR EJ HIS 8840A

• EJ HIS-8840A STEP 1.d.2) RNO 2)a)

• 10. CLOSE RHR TRAIN 'B' APPLICANT S U HOT LEG RECIRC DEPRESSED CLOSE VALVE PUSHBUTTON FOR RHR TRAIN 'B' HOT LEG Comments:

• EJ HV-8716B RECIRC VALVE, EJ STEP 1.d.2) RNO 2)b) HIS-8716B EJ HIS-8716B RED LIGHT GOES OFF AND GREEN LIGHT GOES ON Page 4 of 9

• Critical Step

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

• 11. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT for, EJ HIS- HIS-8809BA IN NON ISO 8809B, IN NON ISO NON ISO LIGHT COMES POSITION Comments:

ON FOR EJ HIS-8809BA

• EJ HIS-8809BA STEP 1.d.2) RNO 2)c)1.

• 12. OPEN RHR TO APPLICANT S U ACCUMULATOR DEPRESSED OPEN INJECTION LOOPS 3 PUSHBUTTON FOR RHR AND 4 valve TO ACCUMULATOR Comments:

INJECTION LOOPS 3

• EJ HIS-8809B AND 4, EJ HIS-8809B STEP 1.d.2) RNO 2)c)2. EJ HIS 8809B GREEN LIGHT GOES OFF AND RED LIGHT GOES ON

• 13. PLACE POWER APPLICANT PLACED EJ S U LOCKOUT for, EJ HIS- HIS-8809BA IN ISO 8809B, IN ISO NON ISO LIGHT GOES POSITION Comments:

OFF FOR EJ HIS-8809BA

• EJ HIS-8809BA STEP 1.d.2) RNO 2)c)3.

14. Go To Step 2. APPLICANT S U PROCEEDED to STEP 2 STEP 1.d.2) RNO 2)d)

Comments:

• 15. STOP SI PUMP 'A': APPLICANT STOPPED 'A' S U SI PUMP USING EM

• EM HIS-4 HIS-4 STEP 2.a Comments:

THE GREEN LIGHT GOES ON AND THE RED LIGHT GOES OFF ON EM HIS 4 DISCHARGE PRESSURE AND FLOW DECAY TO 0 Page 5 of 9

• Critical Step

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

• 16. CLOSE SI PUMP 'A' APPLICANT S U DISCHARGE TO COLD DEPRESSED CLOSE LEG INJECTION VALVE: PUSHBUTTON EM HIS-8821A, SI PUMP 'A' Comments:

• EM HV-8821A DISCHARGE TO COLD STEP 2.b LEG INJECTION EM HIS-8821A GREEN LIGHT GOES ON AND FOUR (4) SECONDS LATER, THE RED LIGHT GOES OFF

• 17. PLACE POWER APPLICANT PLACED EM S U LOCKOUT SWITCH HIS-8802AA IN NON ISO FOR EM HIS-8802A IN NON ISO LIGHT COMES NON ISO POSITION Comments:

ON FOR EM HIS 8802AA

• EM HIS-8802AA STEP 2.c.1)

• 18. OPEN SI PUMP 'A' APPLICANT S U DISCHARGE TO HOT DEPRESSED OPEN LEG INJECTION VALVE: PUSHBUTTON EM HIS-8802A, SI PUMP 'A' Comments:

• EM HV-8802A DISCHARGE TO HOT STEP 2.c.2) LEG INJECTION EM HIS-8802A RED LIGHT GOES ON AND THE GREEN LIGHT GOES OFF

19. PLACE POWER APPLICANT PLACED S U LOCKOUT SWITCH, EM EM HIS-8802AA IN ISO HIS-8802A IN ISO NON ISO LIGHT GOES POSITION: Comments:

OFF FOR EM HIS 8802AA

• EM HIS-8802AA STEP 2.c.3)

Page 6 of 9

• Critical Step

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

• 20. START SI PUMP 'A': APPLICANT STARTED 'A' S U SI PUMP USING EM

• EM HIS-4 HIS-4 STEP 2.d Comments:

RED LIGHT GOES ON AND GREEN LIGHT GOES OFF FOR EM HIS 4

DISCHARGE PRESS AND FLOW RETURN TO PREVIOUS VALUES

• 21. STOP SI PUMP 'B': APPLICANT STOPPED 'B' S U SI PUMP USING EM

• EM HIS-5 HIS-5 STEP 2.e Comments:

THE GREEN LIGHT GOES ON AND THE RED LIGHT GOES OFF FOR EM HIS 5 DISCHARGE PRESS AND FLOW DECAY TO 0

• 22. CLOSE SI PUMP 'B' APPLICANT CLOSED 'B' S U DISCHARGE TO COLD DISCHARGE TO COLD LEG INJECTION VALVE LEG INJECTION USING EM HIS-8821B Comments:

• EM HV-8821B EM HIS-8821B GREEN STEP 2.f LIGHT GOES ON AND FOUR (4) SECONDS LATER, THE RED LIGHT GOES OFF

• 23. PLACE POWER APPLICANT PLACED EM S U LOCKOUT FOR EM HIS-8802BA IN NON ISO HIS-8802B, IN NON ISO NON ISO LIGHT COMES POSITION Comments:

ON FOR EM HIS 8802BA STEP 2.g.1)

• 24. OPEN SI PUMP 'B' APPLICANT OPENED SI S U DISCHARGE TO HOT PUMP 'B' DISCHARGE LEG INJECTION VALVE: TO HOT LEG INJECTION USING EM HIS-8802B Comments:

• EM HV-8802B, EM HIS 8802B RED STEP 2.g.2) LIGHT GOES ON AND THE GREEN LIGHT GOES OFF Page 7 of 9

• Critical Step

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

25. PLACE POWER APPLICANT PLACED EM S U LOCKOUT SWITCH HIS-8802BA IN ISO FOR EM HIS-8802B, IN NON ISO LIGHT GOES ISO POSITION: Comments:

OFF FOR EM HIS 8802BA

• EM HIS-8802BA STEP 2.g.3)

• 26. START SI PUMP 'B': APPLICANT STARTED 'B' S U SI PUMP USING EM

• EM HIS-5 HIS-5 STEP 2.h Comments:

EM HIS-5 RED LIGHT GOES ON AND GREEN LIGHT GOES OFF DISCHARGE PRESS AND FLOW RETURN TO PREVIOUS VALUES

28. INFORM THE CONTROL RESPOND as the CRS APPLICANT REPORTED S U ROOM SUPERVISOR TO CRS STEP 2 IS WHEN STEP 2 OF ES- COMPLETE.

1.4 HAS BEEN Comments:

COMPLETED Page 8 of 9

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: THE PLANT HAS EXPERIENCED A LARGE BREAK LOCA.

TRANSFER TO COLD LEG RECIRC WAS COMPLETED APPROXIMATELY 12 HOURS AGO.

IT HAS NOW BEEN 13 HOURS SINCE EVENT INITIATION.

Initiating Cues: THE CONTROL ROOM SUPERVISOR HAS DIRECTED YOU TO TRANSFER TO HOT LEG RECIRC PER ES-1.4, TRANSFER TO HOT LEG RECIRCULATION INFORM THE CONTROL ROOM SUPERVISOR WHEN STEP 2 OF ES-1.4 HAS BEEN COMPLETED.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S6 JPM Bank No: Sim S6, Rev 1 KSA No: 062K1.04 Revision Date: 02/05/2016 KSA Rating: 3.7 / 4.2 Job

Title:

URO/SRO Duty: Station Blackout Task

Title:

Perform Operational Testing of the Alternate Emergency Power Source Completion Time: 15 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTS-PA-00001, Operation And Testing Of The Alternate Emergency Power Source, Rev 19 Tools / Equipment: none Page 1 of 8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is at 100% power Initiating Cues: The Control Room Supervisor (CRS) directs you to perform an offline test of EDGPA5004, AEPS Diesel Generator #4, in accordance with OTS-PA-00001, Operation And Testing Of The Alternate Emergency Power Source, Section 5.6.

The CRS directs you to take one (1) set of readings on Attachment 5 and then secure EDGPA5004.

The Outside OT has been briefed and is at EDGPA5004 to assist in the diesel test.

All Precautions and Limitiations and Prerequisites are satisfied.

All pre-start checks per sections 5.1 and 5.2 are complete Note: Use any IC that has AEPS available Task Standard: Upon completion of this JPM, the applicant will have started AEPS Diesel Generator #4, taken readings and secured the diesel Start Time:

Stop Time:

Page 2 of 8

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

1. S U Provide applicant with Applicant obtained working procedure copy copy of OTS-PA-00001 Comments:

2. S U Review Precautions and Applicant reviewed Limitations Precautions and Comments:

Limitations

3. S U Review Prerequisites Applicant reviewed Prerequisites Comments:

4. S U Diesels are operated Applicant read note from PBXY0001, AEPS COMPUTER Comments:

INTERFACE, in the Control Room. Similar controls are available on the Master HMI (PA50102 cubicle) in the PA501 building. The local control panel on the switchgear requires Key Tag 263 (individual key number 0) to place it in service.

Sections 5.3 through 5.6 may be performed concurrently.

Prior to 5.6.1

5. S U Check Pre-start checks Examiner Cue: Applicant checked that have been performed pre-start checks were Pre-start checks are complete Comments:

Step 5.6.1 complete Page 3 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 6. S U On the Main Screen on Applicant pressed icon for PBXY0001, press icon PA50107 on PBXY0001 for PA50107 for AEPS Comments:

Diesel Generator #4 Generator #4 EDGPA5004 Control Panel is now Step 5.6.2 displayed

7. S U Check the diesel status Applicant checked status lights are green under the lights were green under alarm monitoring section the alarm monitoring Comments:

of the pop-up screen. section of the pop-up Any status light not green screen must be evaluated by the CRS prior to continuing.

Step 5.6.3

• 8. S U START EDGPA5004, Applicant pressed the AEPS DIESEL button Off Line Gen Test GENERATOR 4, by Start in the pop-up Comments:

performing the following: window

a. In the pop-up window, PRESS the button Off Line Gen Test Start.

Step 5.6.4a

• 9. S U START EDGPA5004, Applicant pressed the AEPS DIESEL button Yes Start GENERATOR 4, by Generator in the Comments:

performing the following: confirmation pop-up window

b. In the confirmation pop-up window, PRESS Yes Start Generator to start the diesel.

Step 5.6.4b Page 4 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

10. S U Check the diesel started Applicant checked that the diesel started Comments:

Step 5.6.5 Engine speed indicates approximately1800 RPM and MegaWatts indicate 0 MW

11. S U Locally check the Examiner Cue: Applicant contacted the ventilation dampers have Outside Operations opened The OT reports the Technician (OOT) to verify Comments:

ventilation dampers are the ventilation dampers Step 5.6.6 open were open

12. S U Check diesel parameters Applicant checked diesel come into normal range parameters came into per Attachment 5 normal range Comments:

Step 5.6.7 All Attachment 5 parameters are within their normal range Page 5 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 13. S U Record readings on Examiner Cue: Applicant recorded 1 set of Attachment 5 at 15 Attachment 5 readings as minute intervals directed in Initiating Cues Comments:

You are directed to take the Attachment 5 Step 5.6.8 readings from Panel Indications are PBXY0001 in the Control approximately:

Room Oil Press 57 Water Temp 140 (will trend up the longer the JPM last)

Battery Volt 26 Engine RPM 1800 Volts A 13.8 Volts B 13.8 Volts C 13.8 Hz 60.0 Amps A 0 or NA Amps B 0 or NA Amps C 0 or NA KiloWatts 0 or NA KiloVars 0 or NA Power Factor 0 or NA

14. S U NOTE: AEPS diesels go Applicant read note and into a 5-minute cooldown caution period after Stop Comments:

command is given. A Cool Down Time Left timer shows the time remaining in the 5-minute period (in seconds).

CAUTION: The 286 relay must be reset prior to shutting down any of the remaining diesels to ensure a minimum of three diesels remain functional at all times.

Prior to 5.6.9 Page 6 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 15. S U Press the button Applicant pressed the Generator Normal Stop button Generator Normal Stop Comments:

Step 5.6.9

• 16. S U Confirm the command by Applicant confirmed the pressing the button Yes command by pressing the Stop Generator button Yes Stop Comments:

Generator Step 5.6.10

17. S U After the 5-minute Examiner Cue After the 5-minute cooldown period, CHECK cooldown period, the the diesel STOPPED. The 5 minute applicant CHECKED the Comments:

cooldown is complete diesel STOPPED.

Step 5.6.11 and the diesel has stopped 18.

IF the 286 Lockout Relay Examiner Cue Applicant checked IF the is tripped, PERFORM 286 Lockout Relay is Section 5.11 of this The 286 Lockout Relay tripped, procedure. is NOT tripped Step 5.6.12 19 S U The JPM is complete Comments:

Page 7 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is at 100% power Initiating Cues: The Control Room Supervisor (CRS) directs you to perform an offline test of EDGPA5004, AEPS Diesel Generator #4, in accordance with OTS-PA-00001, Operation And Testing Of The Alternate Emergency Power Source, Section 5.6.

The CRS directs you to take one (1) set of readings on Attachment 5 and then secure EDGPA5004.

The Outside OT has been briefed and is at EDGPA5004 to assist in the diesel test.

All Precautions and Limitiations and Prerequisites are satisfied.

All pre-start checks per sections 5.1 and 5.2 are complete

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S7 JPM No: URO-SSE-03-C126J KSA No: 015A4.03 Revision Date: 02/06/2016 KSA Rating: 3.8/3.9 Job

Title:

URO Duty: Off Normal Nuclear Instrumentation Task

Title:

Respond to a failed power range instrument Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTO-SE-00001, Nuclear Instrument Malfunction, Rev 25 Tools / Equipment: None Page 1 of 5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1. Power Range NIS channel N41 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 directs you to perform step 5 of OTO-SE-00001, Attachment 'A', Power Range Instrument Malfunction.

Note:

Use any full power IC (IC 10)

Verify:

• Main Feedwater Reg Valves in service.

• Rod Control is in Manual

• Insert malfunction (SE)SEN0041, value = 200, ramp = 10 seconds Task Standard: Upon Completion of this JPM, Power Range NIS channel N41 current comparator and rod stop inputs will be bypassed.

Start Time:

Stop Time:

Page 2 of 5

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

1. Obtain a verified copy of Applicant obtained a copy S U OTO-SE-00001, Nuclear of procedure Instrument Malfunction Comments:

• 2. Bypass the Applicant placed the S U malfunctioning channel Upper Section switch, on by selecting it on the the Detector Current following switches: Comparator drawer, in the Comments:

N41 position Detector Current Comparator drawer: The Upper Section switch on the Detector Current Place Upper Section Comparator drawer is in switch to the failed the N41 position channel Step A5.a

• 3. Detector Current Applicant placed the S U Comparator drawer: Lower Section switch, on the Detector Current Place Lower Section Comparator drawer, in the Comments:

switch to the failed N41 position channel The Lower Section switch Step A5.a on the Detector Current Comparator drawer is in the N41 position

• 4. Detector Current Applicant placed the Rod S U Comparator drawer: Stop Bypass switch, on the Detector Current Place Rod Stop Bypass Comparator drawer, in the Comments:

switch to the failed N41 position channel The Rod Stop Bypass Step A5.a switch on the Detector Current Comparator drawer is in the N41 position Page 3 of 5

• Critical Step

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

• 5. Detector Current Applicant placed the S U Comparator drawer: Power Mismatch Bypass switch, on the Detector Place Power Mismatch Current Comparator Comments:

Bypass switch to the drawer, in the N41 position failed channel The Power Mismatch Step A5.a Bypass switch on the Detector Current Comparator drawer is in the N41 position

• 6. On the Comparator and Applicant placed the S U Rate drawer, Place Comparator Channel Comparator Channel Defeat switch, on the Defeat switch to the Comparator and Rate Comments:

failed channel drawer, in the N41 position Step A5.b The Comparator Channel Defeat switch on the Comparator and Rate drawer is in the N41 position

7. Ensure the following Applicant ensured the S U Annunciators are following Annunciators are extinguished: extinguished:

Comments:

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

THE JPM IS COMPLETE S U Comments:

Page 4 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 1. Power Range NIS channel N41 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 directs you to perform step 5 of OTO-SE-00001, Attachment 'A', Power Range Instrument Malfunction.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE S8 JPM No: NEW KSA No: 029G2.1.29 Revision Date: 02/06/2016 KSA Rating: 4.1 / 4.0 Job

Title:

URO/SRO Duty: CTMT Purge System Task

Title:

Remove Shutdown Purge System from Service Completion Time: 11 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTN-GT-00001, Containment Purge System, Rev 31 Tools / Equipment: None Page 1 of 7

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is in Mode 5.

The Containment Equipment Hatch is closed.

The Control Room Supervisor (CRS) has the Gaseous Rad Release Permit.

The maintenance activities inside containment and core alterations have been Initiating Cues:

completed.

The CRS directs you to remove Shutdown Purge from service in accordance with OTN-GT-00001, Containment Purge System, Section 5.5 through step 5.5.7 and inform the CRS date and time dampers were closed.

Notes: Use any Mode 5 or 6 (IC 23).

Remove Mini Purge from service IAW OTN-GT-00001, Section 5.3 Place Shutdown Purge in service IAW OTN-GT-00001, Section 5.4 Place the GT system on display Task Standard: Upon completion of this JPM, the Applicant will have removed Shutdown Purge from service IAW OTN-GT-00001.

Start Time:

Stop Time:

Page 2 of 7

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

1. Obtain a verified working Provide applicant with Applicant obtained working S U copy of OTN-GT-00001 procedure copy copy of OTN-GT-00001 Comments:

2. Review Precautions and Applicant reviewed S U Limitations Precautions and Limitations Section 3.0 Comments:

3. Review Prerequisites If asked: Applicant reviewed S U Prerequisites Scaffolding is available for the valves Section 4.0 Comments:

listed in step 4.2

4. If containment equipment Applicant read step and S U hatch is open during core determined that it was N/A alterations and mini- for the given initial purge exhaust must be conditions and went to Comments:

secured, perform one of Step 5.5.2 the following:

Step 5.1.1

• 5. IF Equipment Hatch is Applicant closed S U CLOSED, PERFORM the GTHZ0007 using GT HIS-Comments:

following: 7, CTMT S/D PURGE AIR SPLY CTMT ISO

a. Using GT HIS-7, CTMT S/D GT HIS-7 green light is lit PURGE AIR and the red light is not lit SPLY CTMT ISO, CLOSE GTHZ0007.

Step 5.5.2.a Page 3 of 7

• Critical Step

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

• 6. IF Equipment Hatch is Applicant closed S U CLOSED, PERFORM the GTHZ0006 using GT HIS-Comments:

following: 6, CTMT S/D PURGE AIR SPLY CTMT ISO

b. Using GT HIS-6, CTMT S/D GT HIS-6 green light is lit PURGE AIR and the red light is not lit SPLY CTMT ISO, CLOSE GTHZ0006.

Step 5.5.2.b

• 7. IF Equipment Hatch is Applicant stopped SGT01 S U CLOSED, PERFORM the using GT HIS-1, CTMT Comments:

following: S/D PURGE AIR SPLY UNIT

c. Using GT HIS-1, CTMT S/D GT HIS-1 green light is lit PURGE AIR and the red light is not lit SPLY UNIT, STOP SGT01.

Step 5.5.2.c

• 8. IF Equipment Hatch is H indicates the Applicant closed S U CLOSED, PERFORM the switch must be held GTHZ0026 using GT HIS-Comments:

following: 26, CTMT PURGE SYS AIR SPLY DAMPER

d. Using GT HIS-26, CTMT GT HIS-26 green light is lit PURGE SYS AIR and the red light is not lit SPLY DAMPER, CLOSE GTHZ0026.

Step 5.5.2.d

• 9. IF Equipment Hatch is H indicates the Applicant closed S U CLOSED, PERFORM the switch must be held GTHZ0027 using GT HIS-Comments:

following: 27, CTMT PURGE SYS AIR SPLY DAMPER

e. Using GT HIS-27, CTMT PURGE SYS AIR GT HIS-27 green light is lit SPLY DAMPER, CLOSE and the red light is not lit GTHZ0027.

Step 5.5.2.e Page 4 of 7

• Critical Step

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

• 10. Using GT HIS-34, CTMT Applicant stoped CGT01 S U S/D PURGE EXH FAN & using Using GT HIS-34, Comments:

DAMPER, STOP CGT01 CTMT S/D PURGE EXH FAN & DAMPER Step 5.5.3 GT HIS-34 green light is lit and the red light is not lit

• 11. Using GT HIS-8, CTMT Applicant closed S U S/D PURGE EXH INNER GTHZ0008 GT HIS-8, CTMT ISO, CLOSE CTMT S/D PURGE EXH GTHZ0008 INNER CTMT ISO Comments:

Step 5.5.4 GT HIS-8 green light is lit and the red light is not lit

• 12. Using GT HIS-9, CTMT Applicant closed S U S/D PURGE EXH GTHZ0009 using GT HIS-OUTER CTMT ISO, 9, CTMT S/D PURGE CLOSE GTHZ0009 EXH OUTER CTMT ISO Comments:

Step 5.5.5 GT HIS-9 green light is lit and the red light is not lit

• 13. Using GT HIS-28, CTMT H indicates the Applicant closed S U PURGE EXH DAMPER, switch must be held GTHZ0028 using GT HIS-close GTHZ0028 28, CTMT PURGE EXH DAMPER Comments:

Step 5.5.6 GT HIS-28 green light is lit and the red light is not lit

• 14. Using GT HIS-29, CTMT H indicates the Applicant closed S U PURGE EXH DAMPER, switch must be held GTHZ0029 using GT HIS-CLOSE GTHZ0029 29, CTMT PURGE EXH DAMPER Comments:

Step 5.5.7 GT HIS-29 green light is lit and the red light is not lit

15. Record date and time CRS acknowledges Applicant informed CRS of S U dampers were closed on date and time dampers Gaseous Rad Release were closed Permit and Control Room Comments:

Log Step 5.5.8 Page 5 of 7

• Critical Step

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

16. Informs CRS Shutdown THE JPM IS COMPLETE Applicant informed CRS S U Purge has been removed Shutdown Purge has been from service in removed from service in accordance with OTN- accordance with OTN-GT- Comments:

GT-00001, Containment 00001, Containment Purge Purge System, Section System, Section 5.5 5.5 through step 5.5.11. through step 5.5.7.

Page 6 of 7

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: The plant is in Mode 5.

The Containment Equipment Hatch is closed.

The Control Room Supervisor (CRS) has the Gaseous Rad Release Permit.

The maintenance activities inside containment and core alterations have been Initiating Cues:

completed.

The CRS directs you to remove Shutdown Purge from service in accordance with OTN-GT-00001, Containment Purge System, Section 5.5 through step 5.5.7 and inform the CRS date and time dampers were closed.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P1 JPM Bank No: RO-SRO Au j KSA No: 006 A4.02 Revision Date: 02/06/2016 KSA Rating: 4.0*/3.8 Job

Title:

URO/SRO Duty: ECCS Task

Title:

Secure Safety Injection Accumulators Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTG-ZZ-00006, Addendum 06, Securing Safety Injection Accumulator, Rev 4 Tools / Equipment: PPE Page 1 of 6

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 4.

A Plant Cooldown using OTG-ZZ-00006, Plant Cooldown Ht Standby to Cold Shutdown is in progress RCS pressure is 900 psig Initiating Cues: The Control Room Supervisor directs you to secure the Safety Injection Accumulators per OTG-ZZ-00006, Addendum 06.

The CRS has given you key PA40 An RO is standing by in the control room to close the SI Accumulator Outlet Valves Task Standard: Upon completion of this JPM, the applicant will have closed the SI Accumulator Outlet Isolation Valves and opened the feeder breakers to the SI accumulator outlet isolation valves.

Start Time:

Stop Time:

Page 2 of 6

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

1. Obtain a verified working Provide Applicant with Applicant obtained S U copy of OTG-ZZ-00006, procedure copy procedure copy Addendum 06 Comments:

2. Review the Purpose, Applicant reviewed the S U Scope, and Purpose, Scope, and Prerequisites. Prerequisites. Comments:

Sections 1.0, 2.0, and 4.0

3. MAINTAIN Continuous Applicant reviewed step. S U Actions per OTG-ZZ-00006, Plant Cooldown (step was initial by CRS) Comments:

Hot Standby to Cold Shutdown.

Step 5.1

4. Ensure RCS pressure is Given in cue Applicant contacted the S U below 1000 psig. control room to verify RCS pressure Comments:

Step 5.2.1

• 5. Locally REMOVE locks As each breaker is Applicant demonstrated S U from the following identified and operation is the ability to locate and breakers and CLOSE the described, respond that operate the below Comments:

breaker: the breaker is in the breakers operated position

• NG01BGF3,

• NG01BGF3, FDR FDR BKR TO BKR TO EPHV8808A SI EPHV8808A SI ACC A OUT ISO ACC A OUT ISO

• NG01BGF2,

• NG01BGF2, FDR FDR BKR TO BKR TO EPHV8808C SI EPHV8808C SI ACC C OUT ISO ACC C OUT ISO

• NG02BGF3,

• NG02BGF3, FDR FDR BKR TO BKR TO EPHV8808B SI EPHV8808B SI ACC B OUT ISO ACC B OUT ISO

• NG02BHF2, FDR

• NG02BHF2, FDR BKR TO BKR TO EPHV8808D SI EPHV8808D SI ACC D OUT ISO ACC D OUT ISO Step 5.2.2 Page 3 of 6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

• 6. Using the following hand Respond as the RO in Applicant contacted the S U switches, CLOSE the SI the Control Room Control Room and directed Accumulator Outlet them to close the below Comments:

Isolation Valves: EP HIS-8808A, ACCUM switches:

TANK A OUTLET VLV

• EP HIS-8808A,

• EP HIS-8808A, ACCUM TANK A EP HIS-8808B, ACCUM ACCUM TANK A OUTLET VLV TANK B OUTLET VLV OUTLET VLV

• EP HIS-8808B,

• EP HIS-8808B, ACCUM TANK B EP HIS-8808C, ACCUM ACCUM TANK B OUTLET VLV TANK C OUTLET VLV OUTLET VLV

• EP HIS-8808C,

• EP HIS-8808C, ACCUM TANK C ACCUM TANK C AND OUTLET VLV OUTLET VLV

• EP HIS-8808D,

• EP HIS-8808D, ACCUM TANK D EP HIS-8808D, ACCUM ACCUM TANK D OUTLET VLV TANK D OUTLET VLV OUTLET VLV Step 5.2.3 Are closed

• 7. Locally OPEN the As each breaker is Applicant demonstrated S U following breakers and identified and operation is the ability to locate and LOCK them open: described, respond that operate the below Comments:

the breaker is in the breakers

• NG01BGF3, operated position FDR BKR TO

• NG01BGF3, FDR EPHV8808A SI BKR TO ACC A OUT ISO EPHV8808A SI

• NG01BGF2, ACC A OUT ISO FDR BKR TO

• NG01BGF2, FDR EPHV8808C SI BKR TO ACC C OUT ISO EPHV8808C SI

• NG02BGF3, ACC C OUT ISO FDR BKR TO

• NG02BGF3, FDR EPHV8808B SI BKR TO ACC B OUT ISO EPHV8808B SI

• NG02BHF2, FDR ACC B OUT ISO BKR TO

• NG02BHF2, FDR EPHV8808D SI BKR TO ACC D OUT ISO EPHV8808D SI ACC D OUT ISO Step 5.2.4

8. INDEPENDENTLY Inform the Applicant that Applicant informed CRS S U VERIFY each breaker in another operator will breakers need to be IVed.

Step 5.2.4 is locked complete the Comments:

open. independent verification.

Step 5.2.5 Page 4 of 6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

9. NOTE any exceptions to Applicant informed CRS S U the execution of this there were no exceptions procedure AND return to to the procedure Comments OTG-ZZ-00006, Plant Cooldown Hot Standby to Cold Shutdown.

Step 5.2.6 10 OBTAIN procedure Applicant informed CRS S U completion signature the procedure is complete from SM/CRS: Comments Step 5.2.7

13. JPM IS COMPLETE S U Comments Page 5 of 6

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: Callaway Plant is in Mode 4.

A Plant Cooldown using OTG-ZZ-00006, Plant Cooldown Ht Standby to Cold Shutdown is in progress RCS pressure is 900 psig Initiating Cues: The Control Room Supervisor directs you to secure the Safety Injection Accumulators per OTG-ZZ-00006, Addendum 06.

The CRS has given you key PA40 An RO is standing by in the control room to close the SI Accumulator Outlet Valves

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P2 JPM No: EOP-SAB08077J(A) KSA No: 041A2.02 Revision Date: 02/06/2016 KSA Rating: 3.6 / 3.9 Job

Title:

OT/URO/SRO Duty: Main Steam System Task

Title:

Isolate a Failed Open Atmospheric Steam Dump Completion Time: 10 minutes The performance of this task was evaluated against the standards contained in this JPM and determined to be:

SATISFACTORY UNSATISFACTORY Reason, if UNSATISFACTORY:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTO-AB-00001, Steam Dump Malfunction, Rev 18 Tools / Equipment: PPE Page 1 of 5

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A Reactor trip occurred from 100% power.

The crew has entered E-2, Faulted Steam Generator Isolation, due to Atmospheric Steam Dumps, AB PV-1 AND AB PV-4, failing open.

The valves cannot be closed from the Control Room.

Initiating Cues: The Control Room Supervisor (CRS) directs you to go to Area 5 and close AB PV-1 and AB PV-4.

Close AB PV-1 (SG A) first, then AB PV-4 (SG D) using Step 3 RNO of OTO-AB-00001, Steam Dump Malfunction.

Inform the CRS when both valves are closed.

Task Standard: Upon completion of this JPM, the Applicant will have closed AB PV-1 and isolated AB PV-4. AB PV-1 was closed by isolating Air/N2 from the valve.

AB PV-4 was isolated by closing the manual isolation valve, ABV0007.

Start Time:

Stop Time:

Page 2 of 5

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

• 1. Close the Air/N2 Isolation ABV0733 is in the Applicant closed ABV0733 S U Valve for the affected SG position you described ASD: Comments:

• ABV0733 (SG A)

Step 3 RNO a.

• 2. Open the Air/N2 Drain ABV0734 is in the Applicant opened S U Valve for the affected SG position you described ABV0734 ASD: Comments:

AB PV-1 indicates

• ABV0734 (SG A) closed and steam flow can NOT be heard Step 3 RNO b. through the ASD May contact the control room at this time

3. Close the Air/N2 Isolation ABV0739 is in the Applicant closed ABV0739 S U Valve for the affected SG position you described ASD: Comments:

• ABV0739 (SG D)

Step 3 RNO a.

4. Open the Air/N2 Drain ABV0740 is in the Applicant opened S U Valve for the affected SG position you described ABV0740 ASD: Comments:

AB PV-4 indicates

• ABV0740 (SG D) open and steam flow can be heard through Step 3 RNO b. the ASD The next step is the start of the alternate path. The student must recognize that AB-PV-4 is NOT closed and take additional actions to close the valve Page 3 of 5

• Critical Step

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

• 5. If the SG ASD is not After ABV0007 is Applicant determined AB S U closed, then unlock and unlocked and closed: PV-4 is NOT closed and close the manual unlocked and closed Comments:

ABV0007 is in the isolation valve for the ABV0007.

position you affected SG ASD:

described

• ABV0007 (SG D)

After ABV0007 is closed Step 3 RNO steam flow can NOT be heard through the ASD May contact the control room at this time

6. Notify CRS that AB PV-1 CRS acknowledges Applicant notified CRS S U and 4 have been that AB PV-1 was closed closed/isolated and AB PV-4 had been Comments:

manually isolated

7. THE JPM IS S U COMPLETE Comments:

Page 4 of 5

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: A Reactor trip occurred from 100% power.

The crew has entered E-2, Faulted Steam Generator Isolation, due to Atmospheric Steam Dumps, AB PV-1 AND AB PV-4, failing open.

The valves cannot be closed from the Control Room.

Initiating Cues: The Control Room Supervisor (CRS) directs you to go to Area 5 and close AB PV-1 and AB PV-4.

Close AB PV-1 (SG A) first, then AB PV-4 (SG D) using Step 3 RNO of OTO-AB-00001, Steam Dump Malfunction.

Inform the CRS when both valves are closed.

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE P3 JPM Bank No: EOS-SNN-03-P010J KSA No: 062A4.01 Revision Date: 02/06/2016 KSA Rating: 3.3 / 3.1 Job

Title:

OT/URO/SRO Duty: SAFETY RELATED ELEC AND DIST (NN)

Task

Title:

SHIFT AN INSTRUMENT BUS FROM ALTERNATE TO NORMAL POWER 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:

Evaluator Signature: Date:

Task Performer:

Location of Performance:

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

References:

OTN-NN-00001, 120V VITAL AC INST. POWER - CLASS 1E (NN), REV 19 Tools / Equipment: PPE Page 1 of 8

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: THE PLANT IS IN MODE 6. INSTRUMENT BUS NN01 IS BEING SUPPLIED BY ITS MANUAL BYPASS SOURCE NG01A FOR MAINTENANCE ON INVERTER NN11.

INVERTER NN11 MAINTENANCE IS COMPLETE. A CREW BRIEFING HAS BEEN CONDUCTED FOR THE RESTORATION.

Initiating Cues: YOU HAVE BEEN DIRECTED TO TRANSFER NN01 TO THE NORMAL POWER SOURCE FROM THE MANUAL BYPASS SOURCE, PER OTN-NN-00001, SECTION 5.4 and 5.5.

Task Standard: Upon completion of this JPM the applicant will have transferred NN01 to the normal power supply (inverter and NK01) without a loss of voltage.

Start Time:

Stop Time:

Page 2 of 8

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

1. Provide Applicant with Applicant obtained S U procedure copy procedure copy Comments:

2. Review Scope, Precautions and Applicant reviewed Scope, S U Precautions and Prerequisites are Precautions and Prerequisites satisfied Prerequisites Comments:

Section 2.0, 3.0, and 4.0

3. NOTE: This section Applicant read note S U places the Static Transfer Switch in service bypassing the inverter. Comments Performance of this section should result in a bumpless transfer of power to the NN01 Bus.

No voltage loss should occur.

Note prior to Step 5.4.1

4. NOTIFY the Control Respond as the Control Applicant NOTIFIED the S U Room that power to Room Control Room that power NN01 will be transferred to NN01 will be transferred and Step 3.7 should be and Step 3.7 should be Comments reviewed for T/S reviewed for T/S applicability. applicability Step 5.4.1

5. At NN11, CHECK S1, After the applicant Applicant CHECKED S1, S U MANUAL BYPASS correctly locates S1 at MANUAL BYPASS SWITCH, in BYPASS NN11 and describes the SWITCH, in BYPASS SOURCE. MANUAL BYPASS SOURCE. Comments SWITCH position Step 5.4.2 S1, MANUAL BYPASS SWITCH, is in BYPASS SOURCE.

Page 3 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

6. At NN11, CHECK the After the applicant Applicant, CHECKED the S U following breakers are correctly describes how following breakers are CLOSED: to check the breakers CLOSED:

closed Comments

• B1, DC INPUT

• B1, DC INPUT

• B2, INVERTER B1, DC INPUT

• B2, INVERTER OUTPUT B2, INVERTER OUTPUT OUTPUT

• B3, BYPASS

• B3, BYPASS SOURCE INPUT B3, BYPASS SOURCE SOURCE INPUT TO STATIC INPUT TO STATIC TO STATIC SWITCH SWITCH SWITCH

• B4, BYPASS B4, BYPASS SOURCE

• B4, BYPASS SOURCE INPUT INPUT TO MBS SOURCE INPUT TO MBS TO MBS

• B800, BYPASS B800, BYPASS CVT

• B800, BYPASS CVT INPUT INPUT CVT INPUT Step 5.4.3 Are CLOSED

7. NOTE: On NN11, the IN Applicant read note S U SYNC amber light (P11) is on when the Normal Power Supply from the Comments inverter and the Alternate Power Supply from NG01ABR1 are both available and in sync.

Note prior to Step 5.4.4

8. At NN11, CHECK the IN The IN SYNC light Applicant CHECKED the S U SYNC light (P11) is on. (P11) is ON IN SYNC light (P11) is on.

Step 5.4.4 Comments

• 9. IF the BYPASS SOURCE After the applicant Applicant PRESSED S U SUPPLYING LOAD red locates the BYPASS S202, BYPASS SOURCE light (P202), is off at SOURCE SUPPLYING SUPPLYING LOAD and NN11: LOAD red light (P202), at CHECKED the BYPASS Comments NN11 SOURCE SUPPLYING

a. PRESS S202, LOAD red light (P202) is BYPASS The BYPASS SOURCE on.

SOURCE SUPPLYING LOAD red SUPPLYING light (P202), at NN11 is LOAD. OFF

b. CHECK the After the applicant BYPASS presses the S202, SOURCE BYPASS SOURCE SUPPLYING SUPPLYING LOAD LOAD red light (P202) is on. the BYPASS SOURCE SUPPLYING LOAD red Step 5.4.5 light (P202) is on.

Page 4 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE 10 CAUTION: The IN SYNC If the applicant re-checks Applicant read caution S U light (P11) must be on the IN-Sync light, The before shifting the IN SYNC light (P11) is Manual Bypass Switch to ON Comments:

NORMAL SOURCE.

• 11. At NN11, PLACE S1, After the applicant moves Applicant PLACED S1, S U MANUAL BYPASS the S1 switch MANUAL BYPASS SWITCH, in NORMAL SWITCH, in NORMAL S1, MANUAL BYPASS SOURCE. SOURCE. Comments SWITCH is in NORMAL Step 5.4.6 SOURCE.

12. INFORM the Control Respond as the Control Applicant INFORMED the S U Room that NN01 is Room Control Room that NN01 is supplied by the alternate supplied by the alternate power source power source Comments (NG01ABR1) via the (NG01ABR1) via the Static Static Transfer Switch. Transfer Switch.

Step 5.4.7

13. IF it is desired to transfer Applicant transitioned to S U NN01 from Alternate to Section 5.5 Normal, PERFORM Section 5.5. Comments Step 5.4.8

14. NOTE: This section Applicant read note S U places inverter NN11 in service from the normal power source (NK01) and Comments:

transfers NN01 to the inverter output.

Performance of this section should result in a bumpless transfer of power to the NN01 Bus.

No voltage loss should occur.

Note prior to Step 5.5.1

15. NOTIFY the Control Respond as the Control Applicant NOTIFIED the S U Room that power to Room Control Room that power NN01 will be transferred to NN01 will be transferred and Step 3.7 should be and Step 3.7 should be Comments:

reviewed for T/S reviewed for T/S applicability. applicability.

Step 5.5.1 Page 5 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

16. IF S1, MANUAL BYPASS Applicant determined S U SWITCH, is in BYPASS these step were just SOURCE, PERFORM completed Section 5.4. Comments:

Step 5.5.2

17. At NN11, CHECK the After the applicant Applicant CHECKED the S U following breakers describes how they following breakers CLOSED: would check breakers CLOSED:

closed Comments:

• B1, DC INPUT

• B1, DC INPUT

• B2, INVERTER B1, DC INPUT and B2,

• B2, INVERTER OUTPUT INVERTER OUTPUT are OUTPUT closed Step 5.5.3

18. NOTE: The BYPASS Applicant read note S U SOURCE SUPPLYING LOAD red light (P202) indicates that the Comments:

alternate power source (NG01ABR1) is in service.

Note prior to Step 5.5.4

19. At NN11, CHECK the BYPASS SOURCE Applicant CHECKED the S U BYPASS SOURCE SUPPLYING LOAD red BYPASS SOURCE SUPPLYING LOAD red light (P202) is on. SUPPLYING LOAD red light (P202) is on. light (P202) is on. Comments:

Step 5.5.4

20. At NN11, CHECK the INVERTER Applicant CHECKED the S U INVERTER SUPPLYING SUPPLYING LOAD INVERTER SUPPLYING LOAD amber light (P201) amber light (P201) is LOAD amber light (P201) is off. off. is off. Comments:

Step 5.5.5

21. NOTE: On NN11, the IN Applicant read note S U SYNC amber light (P11) is on when the Normal Power Supply from the Comments:

inverter and the Alternate Power Supply from NG01ABR1 are both available and in sync.

NOTE: prior to Step 5.5.6

22. At NN11, CHECK the IN IN SYNC light (P11) is Applicant CHECKED the S U SYNC light (P11) is on. on. IN SYNC light (P11) is on.

Step 5.5.6 Comments:

Page 6 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE

23. CAUTION: The IN SYNC Applicant read caution S U Light (P11) must be on to operate the Static Transfer Switch. Comments:

Caution prior to Step 5.5.7

• 24. At NN11, PRESS S201, After the applicant Applicant PRESSED S U INVERTER TO LOAD. describes how they S201, INVERTER TO would press PRESS LOAD.

Step 5.5.7 S201, INVERTER TO Comments:

LOAD S201 has been pressed

25. At NN11, CHECK the After the applicant Applicant CHECKED the S U following: describes how they following:

would check the lights

a. The INVERTER a. The INVERTER Comments:

SUPPLYING The INVERTER SUPPLYING LOAD amber SUPPLYING LOAD LOAD amber light light (P201) is on. amber light (P201) is on (P201) is on.

b. The BYPASS and the BYPASS b. The BYPASS SOURCE SOURCE SUPPLYING SOURCE SUPPLYING LOAD red light (P202) SUPPLYING LOAD red light is off. LOAD red light (P202) is off. (P202) is off.

Step 5.5.8

26. At NN11, PRESS After the applicant Applicant PRESSED S U NN11S2, ALARM describes how they NN11S2, ALARM RESET.

RESET. would reset the alarm Comments:

Step 5.5.9 NN11S2, ALARM RESET has been pressed

27. NOTIFY the Control Respond as the Control Applicant NOTIFIED the S U Room: Room Control Room:

a. To check that JPM IS COMPLETE a. To check that Comments:

Annunciator 25B, Annunciator 25B, NN11 INV NN11 INV TRBL/XFER, is TRBL/XFER, is off. off.

b. That Inverter b. That Inverter NN11 is supplied NN11 is supplied by the normal by the normal power source power source (NK0111). (NK0111).

Step 5.5.10 Page 7 of 8

• Critical Step

CALLAWAY ENERGY CENTER JOB PERFORMANCE MEASURE Initial Conditions: THE PLANT IS IN MODE 6. INSTRUMENT BUS NN01 IS BEING SUPPLIED BY ITS MANUAL BYPASS SOURCE NG01A FOR MAINTENANCE ON INVERTER NN11.

INVERTER NN11 MAINTENANCE IS COMPLETE. A CREW BRIEFING HAS BEEN CONDUCTED FOR THE RESTORATION.

Initiating Cues: YOU HAVE BEEN DIRECTED TO TRANSFER NN01 TO THE NORMAL POWER SOURCE FROM THE MANUAL BYPASS SOURCE, PER OTN-NN-00001, SECTION 5.4 and 5.5.

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 1, Rev 1 Op-Test No.: 2016-1 Examiners: ____________________________ Operators: _____________________________

Initial Conditions: 100%

Turnover: Centrifugal Charging Pump B was taken Out of Service 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago to replace a shaft seal. The applicable Tech Spec is 3.5.2 A (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />). The Balance of Plant (BOP) is directed to shift the CCW service loop from A Train to B Train and swap Fuel Pool Cooling.

Even Malf. No. Event Event t No. Type* Description Shift CCW service loop from A Train to B Train 1 NA BOP (N)

OTN-EG-00001, Component Cooling Water System Pressurizer Level Transmitter BB LT-459 Fails Low SRO (I) 2 BBLT459 OTO-BG-00001, Pressurizer Level Control Malfunction RO (I)

(Tech Spec 3.3.1)

A S/G Steam Pressure Channel PT-514 Fails Low SRO (I) OTO-AE-00002, Steam Generator Water Level Control 3 ABPT0514 BOP (I) Malfunctions (Tech Spec 3.3.2)

SRO (C) B CCW Pump Trip / D CCW Pump Failure to Auto Start 4 PEG01B_1 BOP (C) OTO-EG-00001, CCW System Malfunction SRO (R) Loss of Instrument Air to Containment 5 KAL03 RO (C)

BOP (R) OTO-KA-0001, Partial or Total Loss of Instrument Air SRO (M) RCS Leak - LOCA 6 BB002_C RO (M)

BOP (M) E-1, Loss of Reactor or Secondary Coolant LOCA Sequencer Train A Failure SRO (C) 7 NF039A_1 E-0, Reactor Trip or Safety Injection, Attachment A, Automatic BOP (C)

Action Verification

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 1

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 2 Page 1 of 36

Scenario Event Description Callaway 2016-1 NRC Scenario #1, rev. 1 The plant is stable at 100%. Centrifugal Charging Pump B was taken Out of Service 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ago to replace a shaft seal. The applicable Tech Spec is 3.5.2 A (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />). The Balance of Plant (BOP) is directed to shift the CCW service loop from A Train to B Train.

After the CCW service loop has been swapped, Pressurizer Level Channel BB LT-459 fails low, resulting in a loss of letdown. The crew will respond IAW OTO-BG-00001, Pressurizer Level Control Malfunction, select an operable pressurizer level channel and restore letdown to service. Tech Spec 3.3.1 applies.

After Tech Specs have been addressed, Steam Generator A Pressure Channel 514 fails low.

This causes a feedwater flow reduction and a lowering SG level. The crew should respond per OTO-AE-00002, Steam Generator Water Level Control Malfunctions, select an operable channel for control, and stabilize SG level. Tech Spec 3.3.2 applies.

After Tech Specs have been addressed, the B CCW pump trips due to breaker failure, and the D CCW pump fails to start automatically. The crew should respond per OTO-EG-00001, CCW System Malfunction, and start the D CCW pump manually. The CRS should review Tech Spec 3.7.7 for "B" CCW Train and determine it is not applicable When plant conditions are stable, the crew will experience a failure of instrument air in CTMT.

The initial indication will be a loss of letdown. The crew may respond with OTO-BG-00001, Pressurizer Level Control Malfunction. When it is recognized that a loss of air to containment has occurred the crew should then enter OTO-KA-0001, Partial or Total Loss of Instrument Air, to respond to the loss of air inside CTMT. The crew will begin a rapid down power per OTO-KA-00001, Attachment A. When a sufficient downpower (MWe < 1200 or as directed by the NRC Chief Examiner) is achieved, the scenario continues with the next event.

Once Turbine Load is reduced, a leak in the RCS develops which will be seen by the crew as PZR level lowering and containment pressure rising. The crew may enter OTO-BB-00003, RCS Excessive Leakage, prior to determining the need to trip the reactor. The crew will manually trip the reactor based on these plant conditions. The crew should enter E-0, Reactor Trip or Safety Injection.

The A train of the LOCA sequencer fails to actuate. This will be indicated to the crew by the A CCP, SI pump, and RHR pump not stating. The crew should manually start these pumps in accordance with E-0, Reactor Trip or Safety Injection, Attachment A.

The crew will transition to E-1, Loss of Reactor or Secondary Coolant. The crew will then stop all RCPs within 5 minutes of meeting the RCP trip criteria. This action may be completed in E-0 per the foldout page or per step 12.

The scenario will end after the crew has performed E-1 and is preparing to transition to ES-1.2, Post LOCA Cooldown and Depressurization Page 2 of 36

Scenario Critical Tasks Callaway 2016-1 NRC Scenario #1, rev. 1 Critical Tasks:

Critical Tasks Trip all RCPs within 5 minutes of meeting RCP trip criteria. Establish flow from 'A' CCP within 5 minutes of meeting RCP trip criteria EVENT 7 8 Safety Failure to trip the RCPs under the postulated plant conditions leads to core uncovery The acceptable results obtained in the FSAR analysis of a small-break LOCA are significance and to fuel cladding temperatures in excess of 2200°F, which is the limit specified in the predicated on the assumption of minimum ECCS pumped injection. The analysis ECCS acceptance criteria. Thus, failure to perform the task represents misoperation or assumes that a minimum pumped ECCS flow rate, which varies with RCS pressure, is incorrect crew performance in which the crew has failed to prevent degradation of...{the injected into the core. The flow rate values assumed for minimum pumped injection are fuel cladding} ...barrier to fission product release and which leads to violation of the based on operation of one each of the following ECCS pumps: Charging/SI pump (HP facility license condition. plants only), high-head SI pump, and low-head SI pump. Operation of this minimum required complement of ECCS injection pumps is consistent with the FSAR assumption that only minimum safeguards are actuated. Because compliance with the assumptions of the FSAR is part of the facility license condition, failure to perform the critical task (under the postulated plant conditions) constitutes a violation of the license condition.

Cueing Indications of a SBLOCA Indication and/or annunciation that Charging/SI pump injection is required AND

• SI actuation Indication and/or annunciation of safety injection

• RCS pressure below the shutoff head of the Charging/SI pump AND Indication and/or annunciation that no Charging/SI pump is injecting into the core Indication and/or annunciation that only one train of actuates

• Control switch indication that the circuit breakers or contactors for both AND Charging/SI pumps are open Indication that RCS pressure

• All Charging/SI pump discharge pressure indicators read zero

• All flow rate indicators for Charging/SI pump injection read zero Performance Manipulation of controls as required to trip all RCPs Manipulation of controls in the control room as required to start the 'A' CCP indicator

• RCP breaker position lights indicate breaker open Performance Indication that all RCPs are stopped: Indication and/or annunciation that the A CCP is injecting feedback

• RCP breaker position lights Flow rate indication of injection from the A CCP

• RCP flow decreasing

• RCP motor amps decreasing Justification for In a letter to the NRC titled Justification of the Manual RCP Trip for Small Break LOCA This allows enough time for the crew to take the correct action while at the same time the chosen Events (OG-117, March 1984) (also known as the Sheppard letter), the WOG provided preventing avoidable adverse consequences of a small-break LOCA.

performance limit the required assurance based on the results of the analyses performed in conjunction with WCAP-9584. The WOG showed that for all Westinghouse plants, more than two minutes were available between onset of the trip criteria and depletion of RCS inventory to the critical inventory. In fact, additional analyses sponsored by the WOG in connection with OG-117 conservatively showed that manual RCP trip could be delayed for five minutes beyond the onset of the RCP trip criteria without incurring any adverse consequence.

PWR Owners CT- 16, Manually Trip RCPS CT-6, Establish flow from at least one Charging/SI pump Group Appendix Page 3 of 36

Scenario Procedure References Callaway 2016-1 NRC Scenario #1, rev. 1 References OTN-EG-00001,Component Cooling Water System OTN-EC-00001, Fuel Pol Cooling and Cleanup System OTO-BG-00001, Pressurizer Level Control Malfunction OTO-AE-00002, Steam Generator Water Level Control Malfunctions OTO-EG-00001, CCW System Malfunction OTO-KA-00001, Partial or Total Loss of Instrument Air OTO-BB-00003, RCS Excessive Leakage E-0, Reactor Trip or Safety Injection E-1, Loss of Reactor or Secondary Coolant Tech Spec 3.3.1 Tech Spec 3.3.2 ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. Small LOCA (S(2))

a. Manually start one CCP Page 4 of 36

Scenario Setup Guide Callaway 2016-1 NRC Scenario #1, rev. 1 Scenario #1 Setup Guide:

Establish the initial conditions of IC-10, MOL 100% power: (may set an exam specific IC

• RCS boron concentration 857 ppm

• CCP A 862 ppm minus 5 days

• CCP B 863 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• CCP B Handswitch / WPA tags hanging

• ENSURE CCW Service Loop is aligned to A CCW Train and A SFP and Fuel Pool Cleanup is secured.

• ENSURE BB-LT-459 is selected on BB-LS459D and E on (both controller and recorder)

=======SCENARIO PRELOADS / SETUP ITEMS==========

Tag Out B CCP

• ME Schematics (BG) e23bg01b, insert BG02NB0201_BKRTA_BKPOS 3 D CCW Pump Auto Start Failure (Event 5)

• Insert Malfunction (EG) PEG01D_A, Value = Inhibit LOCA Sequencer Train A Fails to Actuate (Event 8)

• Insert Malfunction(NF) NF039A_1, Value = Step0_fail_to_Start

======= EVENT 1 ============================

Shift CCW service loop from A Train to B Train

======= EVENT 2 ============================

Pressurizer Level Channel BB LT-459 fails Low

• Insert Malfunction (BB) BBLT0459, Value= 466.1

=======EVENT 3 ============================

Steam Pressure Channel Fails Low

• Insert Malfunction (AB) ABPT0514, value = 0, ramp = 20 sec

=======EVENT 4 ============================

B CCW Pump Trip / D CCW Pump Auto Start Failure:

• Insert Malfunction (EG) PEG01B_1, Value = Trip

• SEE PRELOADS ABOVE

=======EVENT 5 ============================

Loss of Instrument Air to Containment

• Insert Malfunction (KA) KAL03, Value = 525, Ramp = 30 sec

=======EVENT 6=============================

RCS Leak - LOCA

• Insert Malfunction (BB) BB002_C, Value = 2000, ramp = 1 min

=======EVENT 7 PRELOADED===============

LOCA Sequencer Train A Fails to Actuate

• SEE PRELOADS ABOVE Page 5 of 36

Scenario#1 Simulator Lesson Plan Callaway 2016-1 NRC Scenario #1, rev. 1 Page 6 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 1 Page 7 of 36 Event

Description:

Shift CCW service loop from A Train to B Train Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Respond as Primary OT that you have been briefed and are standing by

• When asked ECV0010, FUEL POOL COOL PMP B SUCT ISO is OPEN

• If asked ECFI0018B, FUEL POOL COOLING PUMP B DISCH FLOW indicates 1.7 x 106 lbm/hr

• When directed to STOP the Spent Fuel Pool Pump Room Cooler for the pump that was secured, report back after 2 minutes report back A SFP Cooling pump room cooler has been stopped (no simulator operator actions are required)

• Respond as Chemistry when informed that CCW Train B is in service Shift CCW service loop IAW OTN-EG-00001 Indications Available OTN-EG-00001, Section 5.6 OTN-EG- (Step 5.6.1) ENSURE that SW/ESW cooling water is in service to the B 00001 BOP CCW Heat Exchanger with EF HIS-52, ESW TRN B TO CCW HX B, open.

BOP (Step 5.6.2.a) Ensure B CCW surge tank level is > 50%

(Step 5.6.2.b) Using the following, DETERMINE the pump with the least BOP run time on the major equipment log:

B CCW was directed in the turnover sheet BOP (Step 5.6.2.c) Start CCW pump B using EG HIS-22 (Step 5.6.3)

a. Using EG HIS-9, CCW SURGE TANK A VENT VLV, CLOSE EGRV0009.

b. Using EG HIS-10, CCW SURGE TANK B VENT VLV, CLOSE EGRV0010.

c. Using EG HS-16, CCW TRN B SPLY/RETURN VLVS, OPEN BOP EGHV0016 and EGHV0054.

d. Using EG HS-15, CCW TRN A SPLY/RETURN VLVS, CLOSE EGHV0015 and EGHV0053.

e. Using EG HIS-9, CCW SURGE TANK A VENT VLV, OPEN EGRV0009.

f. Using EG HIS-10, CCW SURGE TANK B VENT VLV, OPEN EGRV0010.

Page 7 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 1 Page 8 of 36 Event

Description:

Shift CCW service loop from A Train to B Train Proc /Time Position Applicants Actions or Behavior OTN-EG- (Step 5.6.4) Using EC HIS-12, SFP HX B CCW OUTLET VLV, BOP 00001 THROTTLE ECHV0012 as needed to clear flow alarms.

CRS Direct transition to OTN-EC-00001, Section 5.3 OTN-EC-00001, Section 5.3 OTN-EC- (Step 5.3.1) IF Refuel Pool cleanup is in progress, PERFORM Section 00001 for Swapping Refuel Pool Purification Trains in OTN-EC-00001 ADD 4, BOP Refuel Pool Cleanup Operations.

Step is NA (Step 5.3.2) RECORD currently running Trains of Fuel Pool Cooling and, if its in service, Fuel Pool Cleanup:

BOP

____________ Fuel Pool Cooling Train

____________ Fuel Pool Cleanup Train (Step 5.3.3) ENSURE a Component Cooling Water pump is RUNNING BOP to support oncoming train of SFP cooling.

(Step 5.3.4) IF in service, STOP running Fuel Pool Cleanup Pump(s):

BOP Step is NA (Step 5.3.5) IF SFP Cleanup was in service, ENSURE in-service Fuel BOP Pool Cleanup Pump ISO valve is CLOSED:

Step is NA (Step 5.3.6) ENSURE suction valve is OPEN for oncoming Fuel Pool BOP Cooling Pump:

• ECV0010, FUEL POOL COOL PMP B SUCT ISO (Step 5.3.7) Using applicable switch below, START oncoming Fuel Pool BOP Cooling Pump:

• EC HIS-28, SFP COOL PUMP B Page 8 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 1 Page 9 of 36 Event

Description:

Shift CCW service loop from A Train to B Train Proc /Time Position Applicants Actions or Behavior OTN-EC- (Step 5.3.8) Using applicable switch, STOP off-going Fuel Pool Cooling 00001 BOP Pump:

• EC HIS-27, SFP COOL PUMP A (Step 5.3.9) IF desired to place SFP Cleanup in service, OPEN SFP BOP Cleanup Pump isolation valve to in-service SFP cooling train:

Step is NA (Step 5.3.10) IF required, THROTTLE valve in oncoming train to obtain flow between 1.65 x 106 and 1.95 x 106 lbm/hr, on indicator shown:

BOP

• ECV0018, FUEL POOL HX B TO SFP ISO, (using ECFI0018B, FUEL POOL COOLING PUMP B DISCH FLOW IND)

(Step 5.3.11) IF it is desired to place a Fuel Pool Cleanup pump in service, PERFORM OTN-EC-00001 ADD 1, Spent Fuel Pool Cleanup BOP Operations, Fuel Pool Cleanup Step is NA (Step 5.3.12) Using the applicable pushbutton, STOP off-going Spent Fuel Pool Pump Room Cooler:

BOP

• GGHS0080, START/STOP PUSHBUTTON FOR SGG04A (At NG03CKF1, FDR BKR TO SGG04A SFP COOL PMP RM COOLER)

CRS Direct transition back to OTN-EG-00001, Section 5.3 OTN-EG-00001, Section 5.6 OTN-EG- (Step 5.6.5) IF NOT required for the safety loop loads (CCP, SFP, SI, 00001 RHR), using the applicable switch below, STOP the running train A CCW BOP pump and ENSURE the handswitches are in AUTO:

• EG HIS-21, CCW PUMP A BOP (Step 5.6.6) Inform Chemistry that CCW Train B is in service Page 9 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 1 Page 10 of 36 Event

Description:

Shift CCW service loop from A Train to B Train Proc /Time Position Applicants Actions or Behavior (Step 5.6.7) As necessary for coarse adjustment, using EG HIS-BOP 102, CCW TO RHR HX B, THROTTLE EGHV0102 to maintain annunciator 75D, SFP TEMP HI, clear.

(Step 5.6.8) ENSURE the CCW Heat Exchanger being removed BOP from service is either in the winter or summer alignment as appropriate per Step 3.2.10.

NOTE At Lead Examiners discretion move to the next Event after the A CCW pump is secured Page 10 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 2 Page 11 of 36 Event

Description:

Pressurizer Level Transmitter BB LT-459 Fails Low(Tech Spec) and restore Letdown Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 2: (Pressurizer Level Channel BB LT-459 fails Low_

• Malfunction (BB) BBLT0459, Value= 466.1

• When contacted, respond as I&C. Acknowledge the request to investigate the instrument/channel failure.

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO Indications Available ANN 32B, PZR 17% HTRS OFF LTDN ISO ANN 32C, PZR LO LEV DEV ANN 39E, LTDN HX DISCH FLOW HILO ANN 41F, NCP FLOW HILO OTO-BG-00001, Pressurizer Level Control Malfunction CRS Implement OTO-BG-00001, Pressurizer Level Control Malfunction OTO-BG- (Step 1) CHECK Charging Pumps - At Least One Running 00001 RO

• NCP is running Step 1 is an immediate action step (Step 2) Verify at least ONE method of RCP Seal Cooling to All RCPs in progress RO

• Seal Injection

• CCW to Thermal Barrier Heat Exchanger (Step 3) CHECK for Failed Pressurizer Level Indicator RO

• BB-LI-459A is failed LOW Page 11 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 2 Page 12 of 36 Event

Description:

Pressurizer Level Transmitter BB LT-459 Fails Low(Tech Spec) and restore Letdown Proc /Time Position Applicants Actions or Behavior OTO-BG- (Step 4) Check Pressurizer Level 00001

• Trending to Program Level RO OR

• At Program Level (Step 4 RNO) Perform the following:

a. STABILIZE Pressurizer Level:

• Place Pressurizer Level Master Controller in MANUAL

• BB LK-459 RO OR

• Manually THROTTLE appropriate Charging Discharge Flow Control valve for the running charging pump:

o BG FK-124 (NCP)

b. RESTORE Pressurizer level to Program Level (Step 5) Transfer Pressurizer Level Control Selector to Remove RO Failed Channel from Control

• BB LS-459D to L461/L469 position (Step 6) CHECK Pressurizer Heater Control Group C - ON RO

• BB HIS-50 Page 12 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 2 Page 13 of 36 Event

Description:

Pressurizer Level Transmitter BB LT-459 Fails Low(Tech Spec) and restore Letdown Proc /Time Position Applicants Actions or Behavior OTO-BG- (Step 7) CHECK Letdown - IN SERVICE - NO 00001 (Step 7 RNO) Perform the following:

a. Slowly Close Charging Header Back Pressure Control Valve while THROTTLING appropriate charging Discharge Valve to maintain 8-13 gpm to RCP seals

• BG HC-182

• BG FK-124 (NCP)

b. Ensure BG HC-182 is CLOSED

c. Restore Letdown as follows:

1) Ensure Letdown Containment Isolation Valves are OPEN

• BG HIS-8152

• BG HIS-8160

2) OPEN RCS Letdown to Regen Heat Exchanger Valves

• BG HIS-459

• BG HIS-460

3) Establish 85 gpm to 90 gpm Charging Header Flow while maintaining seal injection flow RO

• BG HC-182

• BG FK-134 (NCP)

4) PLACE Letdown Hx Outlet Pressure Controller in Manual and RAISE setpoint to greater than 75% open:

• BG PK-131

5) OPEN Orifice Isolation Valve(s) to establish desired letdown flow:

• BG HIS-8149AA

• BG HIS 8149BA

• BG HIS 8149CA

6) ADJUST Letdown Hx Outlet Press Controller to maintain between 300 psig and 350 psig and PLACE in Automatic:

• BG PK-131

7) ADJUST Charging flow to maintain Pressurizer Level.

8) WHEN Pressurizer Level is at program level and the PZR LEV MASTER CTRL output has been adjusted per OTN-BG-00001, ADD04, Operation of CVCS Letdown,

1) THEN Place Charging control in AUTO.

Page 13 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 2 Page 14 of 36 Event

Description:

Pressurizer Level Transmitter BB LT-459 Fails Low(Tech Spec) and restore Letdown Proc /Time Position Applicants Actions or Behavior OTO-BG- #(Step 8) CHECK Pressurizer Level Trending to or at Program RO 00001 Level (Step 9) WHEN Pressurizer Level Is At Program Level:

• PLACE Pressurizer Level Master Controller in AUTO o BB LK-459 OR

• PLACE Charging Discharge Flow Control valve for the running charging pump in AUTO o BG FK-124 (NCP)

(Step 10) CHECK Operable Pressurizer Level Channel - USED RO FOR RECORDER

• BB LS-459E (Step 11) Review Applicable Technical Specifications

• TS 3.3.1, Cond A CRS

• TS 3.3.1, Item 9 Cond M o Place channel in trip within 72 hrs (Step 12) Review Attachment A, Effects of Pressurizer Level CRS Instrument Failure (Step 13) Perform Notifications Per ODP-ZZ-00001 Addendum 13, CRS Shift Manager Communications NOTE At Lead Examiners discretion move to the next Event any time after Letdown is restored and TS have been identified Page 14 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 3 Page 15 of 36 Event

Description:

A S/G Steam Pressure Channel PT-514 Fails Low (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 3 (A S/G Steam Pressure Channel PT-514 Fails Low) o Malfunction (AB) ABPT0514, Value = 0, ramp = 20 secs

• When contacted, respond as I&C. Acknowledge the request to investigate the instrument/channel failure.

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available ANN 108D, SG A FLOW MISMATCH ANN 83C, RX Partial Trip OTO-AE-00002, Steam Generator Water Level Control Malfunctions CRS Implement OTO-AE-00002, SG Water Level Control Malfunctions OTO-AE- (Step 1) CHECK SG Water Level Control Instruments NORMAL 00002 BOP

• SG A:

o AB PI514A / AB PI515A - NO (Step 1 RNO) Take MANUAL Control of Affected SG MFRV or MFRV Bypass and MAINTAIN SG Level:

BOP

• SG A:

o AE FK510, SG A MFW REG VLV CTRL (Step 2) For The Failed Instrument, SELECT An Operable Channel:

BOP

• SG A: AB FS513C

• On DFWCS, SELECT appropriate Steam Flow on AE SS500 (changes grey to white)

Page 15 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 3 Page 16 of 36 Event

Description:

A S/G Steam Pressure Channel PT-514 Fails Low (Tech Spec)

Proc /Time Position Applicants Actions or Behavior (Step 3) RESTORE Affected SG NR Level to between 45% and BOP 55%

OTO-AE- (Step 4) RETURN Affected SG MFRV to Automatic 00002 BOP

• SG A: AE FK510 (Step 5) Review Attachment A, Effects of Instrument Failure CRS Steam Press Transmitter AB PT-514 compensates Steam Flow Transmitter AB FT-512 (Step 6) Review Applicable Tech Specs-Refer to Attachment F

• TS 3.3.2, Condition A

• TS 3.3.2, Item 1.e, Condition D CRS o 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to place channel in trip

• TS 3.3.2, Item 4.e, Condition D o 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to place channel in trip CRS (Step 7) Perform Notifications per ODP-ZZ-00001 Addendum 13 CRS (Step 8) Direct I&C to trip bistables for failed channel CRS (Step 9) Place inoperable channel in EOSL CRS (Step 10) Initiate actions to repair failed channel NOTE At Lead Examiners discretion move to the next Event Page 16 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 4 Page 17 of 36 Event

Description:

B CCW Pump Trip / D CCW Pump Failure to Auto Start Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 4 (B CCW Pump Trip / D CCW Pump Failure to Auto Start) o Malfunction (EG) PEG01B_1, Value = Trip o (PRELOADED) Insert Malfunction (EG) PEG01D_A, Value = Inhibit

• When contacted as an OT to B CCW pump, wait 5 minutes and report back It is warm to the touch

• When contacted as an OT to go to NB02 to check out the B CCW pump breaker wait 5 minutes and report back The breaker for the B CCW pump overcurrent trip flag dropped

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available ANN 52A, CCW TO RCP FLOW LOW ANN 53B, CCW Pmp B/D Press Lo ANN 54F, CCW SEAL HEAT EXCHANGER FLOW HIGH/LOW AND Other annunciator OTO-EG-00001, CCW SYSTEM MALFUNCTION An applicant may start the D CCW pump using the guidance in ODP-ZZ-00001, OPERATIONS DEPARTMENT - CODE OF CONDUCT, Section 4.5, Prudent Operator Action to manually start a component that failed to automatically function as designed then enter OTO-EG-00001, CCW SYSTEM MALFUNCTION CRS OTO-EG-00001, CCW SYSTEM MALFUNCTION Page 17 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 4 Page 18 of 36 Event

Description:

B CCW Pump Trip / D CCW Pump Failure to Auto Start Proc /Time Position Applicants Actions or Behavior OTO-EG- (Step 1) CHECK One CCW Pump Running For Each Operating 00001 Train:

• Train B:

o EG HIS-22 (CCW Pump B) - NO BOP o EG HIS-24 (CCW Pump D) - NO (Step 1 RNO) PERFORM the following:

ENSURE at least one CCW pump running in each operating train.

Starts EG HIS-24 (CCW Pump D)

(Step 2) CHECK CCW Flow - REDUCED OR LOST - NO BOP (Step 2 RNO) Go to step 8 OTO-EG- (Step 8) CHECK CCW Surge Tank Level(s) - LOWERING - NO 00001 BOP (Step 8 RNO) Go to step 13 (Step 13) REVIEW Technical Specifications 3.6.3 and 3.7.7 - Not CRS Applicable CRS (Step 14) Perform Notifications per ODP-ZZ-00001 Addendum 13 NOTE At Lead Examiners discretion move to the next Event Page 18 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 19 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 5 (Loss of Instrument Air to Containment) o Malfunction (KA) KAL03, Value = 525, Ramp = 30 sec

• If contacted as an OT to check out the IA compressors or dryers wait 5 minutes and report back IA compressors and air dryers appear to be working properly

• If contacted as an OT or FS to check for IA leaks wait 5 minutes and report back I have not identified any IA leaks (wherever you were directed to look)

• If asked if the Fuel Building gated is installed respond that it is not.

• If contacted as SM to reduce load, concur with the load reduction

• If contacted as SM to establish Excess Letdown, concur with establishing excess letdown

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

• Respond as the following when informed of power reduction. (no other response needed) o Power Dispatcher o Chemistry o Count Room Technician o Radiation Protection o Radwaste Indications Available ANN 39E, LETDOWN HEAT EXCHANGER DISCHARGE FLOW HIGH OR LOW Letdown Isolates OTO-KA-00001, Partial or Total Loss of Instrument Air CRS OTO-KA-00001, Partial or Total Loss of Instrument Air Page 19 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 20 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step 1) ANNOUNCE Message Notifying Personnel Of The 00001 Following:

BOP

• Loss of Instrument Air

• Anyone using Instrument Air or Service Air to secure and notify the Control Room (Step 2) DISPATCH Ops Tech To Perform Any Of The Following BOP As Applicable:

CRS (Step 3) CHECK Reactor Power - LESS THAN 80% - NO (Step 3 RNO) IF plant conditions cannot be maintained AND the Shift Manager concurs, THEN REDUCE Reactor Power to less CRS than 80% using Attachment A, Load Reduction.

Continue with Step 5. (OTO-KA-00001 Step 5 is on page 24 of scenario guide)

(Step A1) PLACE Rod Control In AUTO:

RO

• SE HS-9 (Step A2) MANAGE Reactivity:

PERFORM Reactivity Management Brief:

CRS

• DISCUSS Amount And Rate of Turbine Load reduction

• DETERMINE amount of boric acid needed Page 20 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 21 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step A3) REDUCE Turbine Load At Less Than Or Equal To 5%

00001 Per Minute Using Any Of The Following:

• REDUCE Turbine load using the %/Min Loading Rate:

a. SLOWLY LOWER Load using the DECREASE LOAD pushbutton until all of the following are met:

Load Limit Limiting Light - EXTINGUISHED Decrease Loading Rate "OFF" Light - LIT Loading Rate Limit %/MIN "1/2" Light - LIT BOP b. ROTATE Load Limit Set potentiometer fully clockwise

c. SELECT Decrease Loading Rate - ON

d. SET Loading Rate Limit %/Min to desired value

e. LOWER load set MW toward desired load using the DECREASE LOAD pushbutton OR

• REDUCE Turbine load using the Load Limit Potentiometer Page 21 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 22 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step A4) BORATE From The BAST By Performing Any Of The 00001 Following:

• BORATE using OTN-BG-00002 Attachment 8 OR

• BORATE to the VCT:

a. PLACE RCS Makeup Control in STOP:

BG HS-26

b. PLACE RCS Makeup Control Selector in BORATE:

BG HS-25

c. SET Boric Acid Flow Controller to the desired flow rate RO BG FK-110

d. PLACE BG FK-110 in AUTO

e. RESET Boric Acid Counter to 000:

BG FY-110B

f. SET BG FY-110B for the desired gallons of boric acid to be added

g. PLACE BG HS-26 in RUN

h. WHEN desired boration is complete, THEN PLACE BG HS-26 in STOP

i. REPEAT Boration as necessary OR Page 22 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 23 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step A4 continued) BORATE From The BAST By Performing Any 00001 Of The Following:

OR

• BORATE using Emergency Boration:

a. START at least one Boric Acid Transfer Pump:

BG HIS-5A BG HIS-6A

b. OPEN Emergency Borate To Charging Pump Suction:

BG HIS-8104

c. CHECK Emergency Borate Flowrate - GREATER THAN 30 GPM BG FI-183A

d. WHEN desired boration is complete, THEN:

1) CLOSE Emergency Borate to Charging Pump Suction:

o BG HIS-8104

2) STOP Boric Acid Transfer Pumps:

o BG HIS-5A o BG HIS-6A

e. REPEAT Boration as necessary OTN-BG- (Attachment 8) Borate Mode of RMCS Operation 00002, 1. Place BG HS-26 , RCS M/U CTRL, in STOP Att. 8

2. Place BG HS-25, RCS M/U CTRL SEL, in BOR

3. RESET BG FY-110B, BA Counter, to 000

4. ENSURE BG-FY-110B is set to deliver the desired amount of boron RO 5. Place BG HS-26, RCS M/U CTRL, in RUN

6. When the desired amount of borated water has been added, PLACE BG HS-26, RCS M/U CTRL, in STOP.

7. If required, PERFORM the following:

a. Place BG HS-25, RCS M/U CTRL SEL, in AUTO

b. Place BG HS-26, RCS M/U CTRL, in RUN Page 23 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 24 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step A5) IF Instrument Air Is Available To Pressurizer Spray 00001 Valves, THEN INITIATE Boron Equalization By Performing the RO Following:

IA is not available (Step A6) NOTIFY The Power Dispatcher Of The Following:

• Load reduction is in progress CRS

• Rate of load reduction

• Amount of load reduction (Step A7) NOTIFY The Following Departments That Load Reduction Is In Progress And The Rate Of Load Reduction:

• Chemistry CRS

• Count Room Technician

• Radiation Protection

• Radwaste (Step A8) CHECK Rod Control System Responding To RCS Tavg/Tref Deviation By Ensuring One Of The Following:

• Control Rods are inserting AND RCS Tavg trending to RO within 3°F of Tref OR

• RCS Tavg within 3°F of Tref CRS (Step 5) CHECK Letdown - ISOLATED CRS (Step 6) CHECK Instrument Air Available In Auxiliary Building Page 24 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 5 Page 25 of 36 Event

Description:

Loss of Instrument Air to Containment Proc /Time Position Applicants Actions or Behavior OTO-KA- (Step 7) REDUCE Charging To RCPs Seals Only By Performing 00001 The Following Concurrently:

a. Slowly CLOSE Charging Header Back Pressure Control valve:

• BG HC-182

b. THROTTLE appropriate charging pump discharge flow RO control valve to maintain RCP seal injection flow between 8 gpm and 13 gpm per pump while reducing charging flow:

• BG FK-124 (NCP)

OR

• BG FK-121 (CCP)

c. CHECK BG HC-182 - FULL CLOSED (Step 8) CHECK Pressurizer Level Within One Of The Following:

• Trending to Program Level RO OR

• At Program Level NOTE After load has been reduced to approximately 1200 MWe or at Lead Examiners discretion move to the next Event Page 25 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 26 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 6 (RCS Leak - LOCA) o Malfunction (BB) BB002_C, Value = 2000, ramp = 1 min, o Event 7 is preloaded (LOCA Sequencer Train A Failure) o (Preloaded) Malfunction(NF) NF039A_1, Value = Step0_fail_to_Start

• If contacted as an OT or FS to perform EOP ADD 8 acknowledge request (no simulator booth operator actions need to be taken)

• Respond as Chemistry when directed to sample SGs

• Respond as RP when directed to perform surveys Indications Available ANN 60E, CTMT Sump A/B Lev Hi ANN 60F, CTMT Sump C/D Lev Hi OTO-BB-00003, RCS Excessive Leakage OTO-BB-CRS Implement OTO-BB-00003, RCS Excessive Leakage 00003 RO (Step 1) Check if PZR level can be maintained (Step 2) Check PZR level stable or rising - NO (Step 2 RNO)

RO a. Manually Trip the Reactor

b. When reactor trip is verified, Then actuate SI

c. Got to E-0 E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection Page 26 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 27 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior 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

a. Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses

a. AC Emergency Buses - At Least One Energized

• NB01 BOP OR

• NB02

b. AC Emergency Buses - BOTH Energized (Step 4) Check SI Status:

a. CHECK if SI is actuated:

• Any SI annunciator 88A through 88D LIT OR

• SB069 SI Actuate RED light LIT OR RO

• LOCA Sequencer annunciators 30A or 31A LIT

b. 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 Verification, RO/BOP while continuing with this procedure (Step A1) Check Charging Pumps - Both CCPs running - NO RO/BOP (Step A1 RNO) START A CCP Page 27 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 28 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior CRITICAL Establish flow from 'A' CCP within 5 minutes of meeting TASK RCP trip criteria (RCS pressure LESS THAN 1425 PSIG)

RO/BOP Time RCS pressure less than 1425 psig: __________

Time A CCP started: __________

E-0 Att A (Step A2) Check SI and RHR Pumps - All running - NO RO/BOP (Step 2A RNO) Start the A SI and RHR pumps (Step A3) Check ECCS Flow

a. CCPs To Boron Inj Header FLOW INDICATED

• EM FI917A

• EM FI917B

b. RCS pressure LESS THAN 1700 PSIG (at this time RO/BOP pressure might be below 1700 psig. If it the applicant will contine with the step, if not the applicant will go to step A4)

c. SI Pump Discharge FLOW INDICATED

d. RCS pressure LESS THAN 325 PSIG - NO Go To Step A4.

(Step A4) CHECK ESW Pumps - BOTH RUNNING - NO RO/BOP (Step 3A RNO) Start A ESW pump Page 28 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 29 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A5) CHECK CCW Alignment:

a. 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

b. 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

c. OPEN CCSW To RHR HX valves:

RO/BOP

• EG HIS-101

• EG HIS-102

d. CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EC HIS-11

• EC HIS-12

e. STOP Spent Fuel Pool Cooling Pump(s):

• EC HIS-27

• EC HIS-28

f. RECORD The Time Spent Fuel Pool Cooling Pump Secured

g. MONITOR Time Since CCW Flow Isolated to SFP HX LESS THAN 4 HOURS (Step A6) CHECK Containment Cooler Fans - RUNNING IN SLOW SPEED

• GN HIS-9

• GN HIS-17

• GN HIS NO RO/BOP

• GN HIS NO (Step A6 RNO) PLACE Containment CoolerFan Speed Selector switch(es) in SLOW and start:

• GN HS5

• GN HS13 Page 29 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 30 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A7) CHECK Containment Hydrogen Mixing Fans -

RUNNING IN SLOW SPEED

• GN HIS-2 RO/BOP

• GN HIS-4

• GN HIS-1

• GN HIS-3 (Step A8) CHECK If Containment Spray should Be Actuated:

a. 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 RO/BOP

• Annunciator 59B CISB - LIT

b. Containment Spray Pumps -

• EN HIS-3

• EN HIS-9

c. ESFAS status panels CSAS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

d. ESFAS status panels CISB sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT

e. STOP all RCPs CRITICAL Trip all RCPs within 5 minutes of meeting RCP trip criteria TASK (RCS pressure LESS THAN 1425 PSIG)

RO/BOP Time RCS pressure less than 1425 psig: __________

Time RCPs tripped: ____________

Page 30 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 31 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A9) CHECK If Main Steamlines Should Be Isolated:

a. CHECK for any of the following:

• Containment pressure - GREATER THAN 17 PSIG OR

• GN PR-934 indicates containment pressure -

RO/BOP 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

b. CHECK MSIVs and Bypass valves - CLOSED (Step A10) CHECK ECCS Valves - PROPER EMERGENCY ALIGNMENT

a. ESFAS status panels SIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT - NO due to B CCP tagged out (Step A11) CHECK Containment Isolation Phase A:

a. ESFAS status panels CISA sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT Page 31 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 32 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A13) CHECK Both Trains of Control Room Ventilation Isolation:

RO/BOP a. ESFAS status panels CRVIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A14) CHECK Containment Purge Isolation:

a. ESFAS status panels CPIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

E-0, REACTOR TRIP OR SAFETY INJECTION E-0 BOP (Step 6) Check Generator Output Breakers - Open (Step 7) Check Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed (Step 8) Check AFW Pumps BOP a. MD AFW Pumps - Both Running

b. TD AFW Pump - Running if Necessary (Step 9) Check AFW Valves - Proper Alignment BOP

• MD AFP Flow Control Valves - Throttled

• TD AFP Flow Control Valves - Full Open Page 32 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 33 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 BOP (Step 10) Check Total AFW Flow > 285,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves

a. PZR PORVs - Closed RO b. PZR PORVs - Both in AUTO

c. PORV Block Valves - Both Open

d. Normal PZR Spray Valves - Closed (Step 12) Check if RCPs should be Stopped

a. RCPs - Any Running RO b. ECCS Pumps - At least One Running

c. RCS Pressure - Less than 1425 psig YES

d. Stop all RCPs CRITICAL Trip all RCPs within 5 minutes of meeting RCP trip criteria TASK (RCS pressure LESS THAN 1425 PSIG)

RO/BOP Time RCS pressure less than 1425 psig: __________

Time RCPs tripped: ____________

(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:

a. CHECK pressures in all SGs:

RO/BOP

• Any SG pressure lowering uncontrollably

• Any SG completely depressurized Page 33 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 34 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-0 (Step 15) Check if SG Tubes are intact:

• Levels in all SGs - none rising in uncontrolled manner

• SG Steamline N16 radiation - Normal BOP

• Condenser air removal radiation - Normal

• SG blowdown and sample radiation - Normal

• SG ASD radiation - Normal

• TDAFW pump exhaust radiation - Normal (Step 16) Check if RCS is Intact

• Containment pressure - Normal - NO RO/BOP

• Containment normal sump level - Normal - NO

• Containment radiation - Normal - NO RNO - Go to E-1, Loss of Reactor or Secondary Coolant E-1, LOSS OF REACTOR OR SECONDARY COOLANT Initiate CSF Monitoring E-1 (Step 1) Check if RCPs should be stopped:

RO/BOP Any running- NO RNO - Go To Step 2. OBSERVE NOTE prior to Step 2.

BOP (Step 2) Check if any SG is Faulted - NO (Step 3) Check intact SG levels BOP a. Narrow range levels greater than 7% [25%]

b. Control feed flow to maintain levels between 7% and 52%

Page 34 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 35 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-1 (Step 4) Check secondary radiation - Normal

a. Perform the following:

• Perform EOP Addendum 11

• Direct Chem to periodically sample all SGs for activity

• Direct RP to survey steamlines in Area 5 as necessary BOP

b. Check unisolated secondary radiation monitors:

• SG sample radiation

• SG ASD radiation

• TDAFW pump exhaust radiation

c. Secondary radiation - Normal (Step 5) Check PZR PORVs and block valves:

a. Power to block valves - Available BOP/RO

b. PZR PORVs - Closed

c. Block valves - Both Open (Step 6) Check is ECCS flow should be reduced:

a. RCS subcooling - greater than 30°

b. Secondary heat sink:

BOP/RO

• Narrow range level in at least on SG greater than 7%

• Total feed flow to SGs greater than 285,000 lbm/hr

c. RCS pressure - stable or rising RNO - Go to Step 7 (Step 7) Check if Containment Spray should be stopped:

BOP/RO (NOT IN SERVICE)

RNO - Go to Step 8 (Step 8) Check if RHR pumps should be stopped:

a. Check RCS pressure:

BOP/RO

1) Greater than 325 psig RNO - Go To Step 10 Page 35 of 36

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 1 rev.1 Event # 6 and 7 Page 36 of 36 Event

Description:

RCS Leak - LOCA / LOCA Sequencer Train A Failure Proc /Time Position Applicants Actions or Behavior E-1 (Step 10) Check if Diesel Generators should be stopped:

a. AC emergency buses - energized by offsite power BOP/RO b. Reset SI if necessary

c. Perform EOP Addendum 8

d. Stop any unloaded DG and place in standby BOP/RO (Step 11) Check Ultimate Heat Sink - Normal - YES (Step 12) Initiate evaluation of plant status

a. Check Cold Leg recirculation capability

• Train A - Available - YES

• Train B - Available - Yes BOP/RO b. CHECK Auxiliary Building radiation NORMAL -YES

c. OBTAIN samples:

d. EVALUATE plant equipment for long term recovery as necessary:

e. START additional plant equipment to assist in recovery as directed by SM/CRS (Step 13) CHECK If RCS Cooldown And Depressurization Is Required:

CRS a. RCS pressure GREATER THAN 325 PSIG

b. Go To ES1.2, Post LOCA Cooldown And Depressurization, Step 1 The scenario can be terminated at the discretion of the Lead Examiner Page 36 of 36

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 2, Rev 1 Op-Test No.: 2016-1 Examiners: ____________________________ Operators: _____________________________

Initial Conditions: 100%

Turnover: Maintain current plant conditions. Perform Control Valve Partial Stroke Test on CV-1 in accordance with OSP-AC-00003, Turbine Control Valve Stroke Test Even Malf. No. Event Event t No. Type* Description Perform Control Valve Partial Stroke Test on CV-1 1 NA BOP (N)

OSP-AC-00003, Turbine Control Valve Stroke Test SRO (I) First Stage Turbine Pressure Indicator Failure 2 ACPT0505 RO (R) OTO-AC-00003, Turbine Impulse Pressure Channel Failure BOP (I) (Tech Spec 3.3.1)

Loss of DRPI (Rod M-4)

SRO (I) OTA-RK-00022, ADD 80A Rod Position Indication Urgent 3 M04_DA RO (I) Alarm (Tech Spec 3.1.7)

SRO (C) B Failure MFP Speed Failure 4 FCSI0132 BOP (C) OTO-AE-00001, Feedwater System Malfunctions SRO (C) C RCP High Vibration 5 CRCPV2 RO (C) OTO-BB-00002, RCP Off Normal SRO (M) Nuclear Power Generation / ATWS 6 SF006 RO (M) FR-S.1, Response to Nuclear Power Generation / ATWS BOP (M)

SRO (C) S/G C ASD Sticks Open 7 SA075A BOP (C) E-2, Faulted Steam Generator Isolation

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 1

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Page 1 of 33

Scenario Event Description Callaway 2016-1 NRC Scenario #2, rev. 1 The plant is stable at 100%. The Balance of Plant (BOP) is directed to perform Control Valve Partial Stroke Test on CV-1 in accordance with Section 6.2, OSP-AC-00003, Turbine Control Valve Stroke Test.

After Turbine Control Valve testing is complete, Turbine First Stage Pressure Indicator AC PI-505 fails low. This causes the control rods to step in. The crew should respond per OTO-AC-00003, Turbine Impulse Pressure Channel Failure, take manual control of control rods, select and operable turbine first stage pressure channel, and restore RCS Tavg to within 1°F of Tref and returns rod control to AUTO. Tech Spec 3.3.1 applies.

After Tech Specs have been addressed, DRPI for rod M-4 will fail. The crew will be alerted to the failure by annunciator 80A and 80B. The crew should take actions per OTA-RK-00022 Addendum 80A to place rod control in Manual and record RCS Tavg once per hour. Technical Specification 3.1.7 applies.

After Tech Specs have been addressed, 'B' MFP speed probes fails over 5 minutes. The crew should respond per OTO-AE-00001, Feedwater System Malfunctions, and take manual control of the B MFP restore SG NR level to between 45 and 55%.

After SG level has been returned to between 45% and 55%, a mechanical failure causes C RCP vibrations to rise rapidly above the immediate trip setpoint. This will drive the crew to enter OTO-BB-00002, RCP Off Normal. The crew will recognize the need to immediately trip the Reactor and the C RCP. When the crew attempts to trip the reactor it will NOT trip. The crew should enter E-0 and transition to FR-S.1, Response to Nuclear Power Generation / ATWS, at step 1 of E-0. The C RCP should NOT be tripped until Reactor power is Less than 5%.

During the performance of FR-S.1, rods will drop into the core after PG19 and PG20 feeder breakers are opened to deenergize the rod drive MG sets. The crew will return to E-0 and continue with the recovery.

During FR-S.1, the C S/G ASD will Fail to Close after opening during the ATWS. An SI will occur and the crew will continue through E-0. The crew will isolate steam flow from and feed flow to the C S/G per fold out page of E-0. The ASD will NOT be able to be manually closed from the Control Room and Local Operator action will be required to close the isolation valve for the ASD. The crew will transition to E-2, Faulted Steam Generator, and then transition to ES-1.1, SI Termination. The scenario may be terminated after the crew determines they will transition to ES-1.1, SI Termination Page 2 of 33

Scenario Critical Tasks Callaway 2016-1 NRC Scenario #2, rev. 1 Critical Tasks:

Critical Tasks Insert negative reactivity into the core by at least one of the following methods before Isolate feed flow to C Steam Generator prior to:

dispatching operators to locally Trip the Reactor Intermediate Range having a positive SUR

• Deenergize PG19 and PG20 OR

• Insert Control Rods Obtaining an INTEGRITY RED or Orange Path

• Establish emergency boration flow to the RCS EVENT 6 7 Safety In the scenario, failure to insert negative reactivity by one of the methods listed Failure to isolate a faulted SG that can be isolated causes challenges to CSFs beyond significance previously can result in the needless continuation of an extreme or a severe challenge those irreparably introduced by the postulated conditions.

to the subcriticality CSF. Although the challenge was not initiated by the crew (was not Failure to isolate a faulted SG can result in challenges to the following CSFs:

initiated by operator error), continuation of the challenge is a result of the crew's failure

• Integrity to insert negative reactivity.

• Subcriticality Cueing In the scenario, failure to insert negative reactivity by one of the methods listed Both of the following:

previously can result in the needless continuation of an extreme or a severe challenge

• Steam pressure and flow rate indications that make it possible to identify C SG as to the subcriticality CSF. Although the challenge was not initiated by the crew (was not faulted initiated by operator error), continuation of the challenge is a result of the crew's failure AND to insert negative reactivity.

• Valve position and flow rate indication that AFW continues to be delivered to the faulted C SG Performance Manipulation of controls in the control room as required to initiate the insertion of ISOLATE AFW flow to faulted SG(s):

indicator negative reactivity into the core (at least one of the following)

• CLOSE associated MD AFP Flow Control Valve(s):

• Open supply breakers to PG19 and PG20. o AL HK-11A (SG C) o PG HIS-16 and PG HIS-18

• CLOSE associated TD AFP Flow Control Valve(s):

• Insert Control Rods at the Maximum Rate. o AL HK-12A (SG C)

• ALIGN emergency boration flow path:

• FAST CLOSE all MSIVs and Bypass valves:

o Start boric acid transfer pumps o AB HS79 BG HIS-5A and BG HIS-6A o AB HS80 o OPEN Emergency Borate To Charging Pump Suction valve:

BG HIS-8104 Performance Crew will observe the following: Crew will observe the following:

feedback

• Indication of a negative SUR on the intermediate range of the excore NIS

• Any depressurization of intact SGs stops

• Indication of less than 5% power on the power range of the excore NIS

• AFW flow rate indication to faulted SG of zero Justification for Local operator actions would result in reactor trip, which would shut down the reactor before transition out of E-2 is in accordance with the PWR Owners Group Emergency the chosen faster than boration (and faster than rod insertion). However, it is anticipated that Response Guidelines. It allows enough time for the crew to take the correct action while performance limit effecting the local actions will be time-consuming and that actions that can be at the same time preventing avoidable adverse consequences.

implemented from the control room should be given precedence. Thus, before dispatching operators to perform local actions to trip the reactor, the crew should perform or initiate performance of at least one of the three methods listed previously for shutting down the reactor and providing shutdown margin.

PWR Owners CT- 52, Insert negative reactivity into the core CT-17 Isolate faulted SG Group Appendix Page 3 of 33

Scenario Procedure References Callaway 2016-1 NRC Scenario #2, rev. 1 References OSP-AC-00003, Turbine Control Valve Stroke Test OTN-BB-00005, Pressurizer and Pressurizer Pressure Control OTO-SF-00001, Rod Control Malfunctions OTO-AC-00003, Turbine Impulse Pressure Channel Failure OTA-RK-00022 Addendum 80A, Rod Position Indication Urgent Alarm OTO-AE-00001, Feedwater System Malfunction OTO-BB-00002, RCP Off Normal OTO-AB-00001, Steam Dump Malfunction E-0, Reactor Trip or Safety Injection E-2, Faulted Steam Generator Isolation FR-S.1, Response to Nuclear Power Generation / ATWS Tech Spec 3.3.2 Tech spec 3.1.7 ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. ATWS TAT3

a. Manual Control Rod Insertion Page 4 of 33

Scenario Setup Guide Callaway 2016-1 NRC Scenario #2, rev. 1 Scenario #2 Setup Guide:

Establish the initial conditions of IC-10, MOL 100% power:

• RCS boron concentration 862 ppm

• CCP A 863 ppm minus 5 days

• CCP B 865 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

=======SCENARIO PRELOADS / SETUP ITEMS==========

ATWS (Event 6):

• Insert Malfunction (SF) SF006, value = Both_modes S/G C ASD Sticks Open (Event 7):

• Insert Malfunction (AB) ABPV0003A_2, Value = 1.0, Condition = HWX06O39R eq 1

======= EVENT 1 ============================

Perform Control Valve Partial Stroke Test

=======EVENT 2 ============================

First Stage Turbine Pressure Indicator Failure

• Insert Malfunction (AC) ACPT0505, value = 0, ramp = 0 min

=======EVENT 3 ============================

Loss of DRPI (Rod M-4)

• Insert Malfunction (SF) M04_DA, value = True

• Insert Malfunction (SF) M04_DB, value = True

=======EVENT 4 ============================

B Failure MFP Speed Failure

• Insert Malfunction (FC) FCSI0132ATVSP, Value = 0, ramp = 5 min

• Insert Malfunction (FC) FCSI0132BTVSP, Value = 0, ramp = 5 min

• Insert Malfunction (FC) FCSI0132CTVSP, Value = 0, ramp = 5 min

=======EVENT 5 ============================

C RCP High Vibration

• Insert Malfunction (BB) CRCPV1_3, value = 5, ramp = 1 min

• Insert Malfunction (BB) CRCPV2_3, value = 20, ramp = 1 min

=======EVENT 6=============================

Nuclear Power Generation / ATWS

• SEE PRELOADS ABOVE

=======EVENT 7 PRELOADED===============

S/G C ASD Sticks Open

• SEE PRELOADS ABOVE Page 5 of 33

Scenario#2 Simulator Lesson Plan Callaway 2016-1 NRC Scenario #2, rev. 1 Page 6 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 1 Page 7 of 33 Event

Description:

Perform Control Valve Partial Stroke Test on CV-1 Proc /Time Position Applicants Actions or Behavior Booth Operator Perform the following communications/role playing as requested

• Respond as Chemistry if contacted PZR backup heaters are being operated

• Respond as the Power Dispatcher when notified that CV testing will be performed/completed

• Respond as an OT that you are standing by to observe CV stroking

• Respond as an extra RO that at SB029B, TRAIN A SSPS LOGIC CABINET, the Multiplexer Test switch is in the A+B position (this panel is in the back of the control room and not modeled in the simulator)

• Respond as OT if asked if CV-1 stroked smoothly CV-1 stroked smoothly Perform Control Valve Partial Stoke Test on CV-1 in accordance with Section 6.2., OSP-AC-00003, Turbine Control Valve Stroke Test.

Indications Available Perform Control Valve Partial Stroke Test on CV-1 Determines that to perform a partial stroke test of CV-1 the crew must perform Section 6.2 of OSP-AC-00003, Turbine Control Valve Stroke CRS Test. To prepare for this test the crew will also have to perform section 5.1 of OTN-BB-00005,Pressurizer and Pressurizer Pressure Control OTN-BB- Implement OTN-BB-00005,Pressurizer and Pressurizer Pressure Control CRS 00005 Section 5.1 (Step 5.1.1) ENSURE one OR both of the following in the CLOSED position:

RO

• BB HIS-51A, PZR HTR B/U GROUP A

• BB HIS-52A, PZR HTR B/U GROUP B (Step 5.1.2) ENSURE BB PK-455A, PZR PRESS MASTER CTRL, in RO MANUAL and LOWER to 40%.

(Step 5.1.3) ENSURE BB PK-455A, PZR PERSS MASTER CTRL, in RO AUTO.

Page 7 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 1 Page 8 of 33 Event

Description:

Perform Control Valve Partial Stroke Test on CV-1 Proc /Time Position Applicants Actions or Behavior (Step 5.1.4) IF the Pressurizer backup heaters will be operated for an RO extended period of time (greater than 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />), INFORM Chemistry as increased Pressurizer spray may reduce RCS Hydrogen concentration OSP-AC-00003,Turbine Control Valve Stroke Test OSP-AC- (Step 6.2.1.) Preparations 00003 a. CHECK the following CV position meters are approximately equal:

• CV-1

• CV-2

• CV-3

b. At SB069, REACTOR PARTIAL TRIP STATUS PANEL, CHECK the status lights are NOT energized:

• TURB AUTO STOP 63 AST 1 for CV-1

• TURB AUTO STOP 63 AST 2 for CV-2

• TURB AUTO STOP 63 AST 3 for CV-3

c. In SB029B, TRAIN A SSPS LOGIC CABINET, IF Multiplexer Test switch is in any position other than A+B, CONTACT I&C prior to proceeding.

d. PERFORM the following:

BOP 1. ENSURE the turbine is OFF the limiter of load set as follows:

a) RECORD Load Limit Set potentiometer setting.

b) Using EHC Panel DECREASE LOAD pushbutton, SLOWLY LOWER load until the following conditions are met:

• LOAD LIMIT LIMITING light is off

• DECREASE LOADING RATE OFF light is lit

• LOADING RATE LIMIT %/MIN 1/2 light is lit

2. TURN LOAD LIMIT SET potentiometer fully clockwise.

3. Using DECREASE LOADING RATE ON pushbutton, PRESS ON.

e. CHECK LOAD LIMIT panel light is NOT illuminated.

f. ESTABLISH communications between the URO (BOP) and the Local Observer.

Page 8 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 1 Page 9 of 33 Event

Description:

Perform Control Valve Partial Stroke Test on CV-1 Proc /Time Position Applicants Actions or Behavior OSP-AC- (Step 6.2.2) Control Valve 1 00003 a. RECORD turbine load. __________ MWe

b. RECORD the NO. 1 valve position from position meter.

c. PERFORM the following to test CV-1:

• MONITOR turbine load decrease.

NOTE: Steps 6.2.2.c.2 through 6.2.2.c.4 may be performed concurrently.

• PRESS and HOLD the CV-1 TEST pushbutton.

• OBSERVE CV-1 strokes smoothly.

• WHEN the NO. 1 valve position meter indicates approximately 20% travel in the closed direction, RELEASE the CV-1 TEST pushbutton.

d. RECORD lowest turbine load. __________ MWe BOP e. CHECK that CV-1 returns to the position recorded in Step 6.2.2.b.

f. RECORD on Attachment 2 whether the following Acceptance Criteria have been met for CV-1:

• Stroked approximately 20% in the closed direction

• Stroked smoothly

g. CHECK the following CV position meters are approximately equal and RECORD on Attachment 2:

• CV-1

• CV-2

• CV-3

h. CALCULATE turbine load decrease.

__________ - __________ = __________ MWe Step 6.2.2.a Step 6.2.2.d BOP (Step 7) Restoration (Step 7.2) IF Partial Stroke Testing was performed, RECORD the following on Attachment 2:

BOP 7.2.1. Turbine load.

7.2.2. Largest turbine load decrease (Step 6.2.2.h, 6.2.3.h, 6.2.4.h).

7.2.3. Surveillance results.

Page 9 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 1 Page 10 of 33 Event

Description:

Perform Control Valve Partial Stroke Test on CV-1 Proc /Time Position Applicants Actions or Behavior OSP-AC- (Step 7.3) IF desired, to place the turbine on the load set limiter, 00003 PERFORM the following:

7.3.1. At LOAD MONITORING section, ENSURE AT SET LOAD light is lit.

BOP 7.3.2. Slowly TURN the LOAD LIMIT SET potentiometer Counter Clockwise until the LOAD LIMIT LIMITING light is ON.

7.3.3. CHECK all LOADING RATE LIMIT % / MIN lights are off.

7.3.4. Using LOAD SELECTOR INCREASE LOAD pushbutton, INCREASE load until LOAD SET MW indication stops increasing.

(Step 7.4) As needed, ADJUST Turbine load per OTG-ZZ-00004, Power BOP Operation.

CRS (Step 7.5) NOTIFY Power Dispatcher that testing has been completed.

(Step 7.6) IF energized per Step 5.9, RESTORE back-up heaters per CRS Automatic Heater Operation section of OTN-BB-00005, Pressurizer And Pressurizer Pressure Control.

OTN-BB-00005, Pressurizer And Pressurizer Pressure Control OTN-BB- (Step 5.2.1) ENSURE the following heaters in AUTO:

00005 RO

• BB HIS-51A, PZR HTR B/U GROUP A

• BB HIS-52A, PZR HTR B/U GROUP B (Step 5.2.2) ENSURE BB HIS-50, PZR HTR CTRL GROUP C, in NORMAL AFTER CLOSE (Step 5.2.3) Using MANUAL control, RAISE BB PK-455A, PZR PRESS MASTER CTRL, to 50%.

(Step 5.2.4) ENSURE BB PK-455A, PZR PRESS MASTER CTRL, in AUTO.

Page 10 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 1 Page 11 of 33 Event

Description:

Perform Control Valve Partial Stroke Test on CV-1 Proc /Time Position Applicants Actions or Behavior OSP-AC-00003,Turbine Control Valve Stroke Test OSP-AC- (Step 7.7) PLACE control rods in mode of control as required per BOP 00003 SM/CRS.

CRS (Step 7.8) SEND copies of test data sheets to AC system engineer.

NOTE At Lead Examiners discretion move to the next Event Page 11 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 2 Page 12 of 33 Event

Description:

First Stage Turbine Pressure Indicator Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 2: First Stage Turbine Pressure Indicator Failure o Malfunction (AB) ABPT0505, value = 0, ramp = 0 sec

• When contacted, respond as DUTY MANAGER. Acknowledge the channel failure, OTO entry, and Tech Spec entry.

Indications Available ANN 65E, T REF / T AUCT LO ANN 77A, REACT DEV OTO-SF-00001, Rod Control Malfunctions OTO-SF-CRS Implement OTO-SF-00001, Rod Control Malfunctions 00001 (Step 1) CHECK Both Of The Following Are Met For Indication Of RO Multiple Dropped Rods: - NO Step 1 RNO Go To Step 3.

(Step 3) CHECK Main Turbine Runback Or. Load Reject - IN RO PROGRESS Step 3 RNO Go To Step 5 (Step 5) PLACE Rod Control in MANUAL:

RO

• SE HS-9 RO (Step 6) CHECK Control Rods Motion - STOPPED (Step 7) CHECK Instruments Indications - NORMAL

b. HP Turbine First Stage Pressure RO

• AC PI-505 Step 7.b RNO Go To OTO-AC-00003, Turbine Impulse Pressure Channel Failure.

Page 12 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 2 Page 13 of 33 Event

Description:

First Stage Turbine Pressure Indicator Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior OTO-AC-00003, TURBINE IMPULSE PRESSURE CHANNEL FAILURE Implement OTO-AC-00003, TURBINE IMPULSE PRESSURE CHANNEL CRS FAILURE OTO-AC- (Step 1) PLACE Rod Control in MANUAL:

RO 00003

• SE HS9 (Step 2) CHECK HP Turbine First Stage Pressure Indicator FAILED BOP

• AC PI505

• AC PI506 (Step 3) SELECT HP Turbine First Stage Pressure Selector To Operable BOP

• AC PS505Z RO (Step 4) CHECK RCS Tavg Within 1.5°F Of Tref (Step 5) CHECK Rod Control IN AUTO RO

• SE HS9 At this time the crew may determine that they are going to return rods to their original position prior to continuing with the procedure (Step 6) PLACE Steam Dump Bypass Interlock Switches To OFF/RESET:

BOP

• AB HS63

• AB HS64 (Step 7) CHECK The Following Permissives Are In The Correct State Within One Hour Of The Channel Failure Per Attachment B, Permissives:

BOP

• P7

• P13 Page 13 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 2 Page 14 of 33 Event

Description:

First Stage Turbine Pressure Indicator Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior (Step 8) Review Applicable Tech Specs, Attachment C

• 3.3.1, Cond A

• 3.3.1, Table 3.3.1-1 Item 18.b Cond T CRS o 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to Verify interlock is in required state for existing conditions

• 3.3.1, Table 3.3.1-1 Item 18.f Cond T o 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to Verify interlock is in required state for existing conditions (Step 9) REVIEW Attachment A, Effects of Turbine Impulse Pressure CRS Instrument Failure (Step 10) Place Inoperable Turbine Impulse Pressure Channel in the CRS EOSL NOTE The AMSAC Test/Bypass panel is not modeled in the simulator (Step 11) At AMSAC Test/Bypass Panel, (SS001), PLACE Turbine Impulse Pressure Channel In The Proper Condition For AMSAC:

a. PLACE SW12, Operating Bypass switch, to the position associated with failed pressure channel:

BOP

• PTI 1 (PT505)

• PTI 2 (PT506)

b. CHECK Reactor Power GREATER THAN OR EQUAL TO 40%

c. PLACE SW11, Operating Bypass toggle switch, to the right hand position (Step 12) RECORD Permissives Are In The Correct State In The Control CRS Room Log CRS (Step 13) Initiate Action to Repair the failed component (Step 14) PERFORM Notifications Per ODPZZ00001 Addendum 13, CRS Shift Manager Communications NOTE At Lead Examiners discretion move to the next Event after Control Rods are in AUTO Page 14 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 3 Page 15 of 33 Event

Description:

Loss of DRPI (Rod M-4) (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 3: Loss of DRPI (Rod M-4) o Malfunction (SF) M04_DA, value = True o Malfunction (SF) M04_DB, value = True

• When contacted, respond as I&C. Acknowledge the request to investigate the instrument/channel failure.

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the Tech Spec Indications Available ANN 79C, PR LOWER DETECTOR FLUX DEV ANN 80A, ROD POSITION INDICATION URGENT ALARM ANN 80B, ROD POSITION INDICATION NON-URGENT ALARM ANN 80C, ROD POSITION INDICATION ROD DEVIATION OTA-RK-00022, ADD 80A Rod Position Indication Urgent Alarm OTA-RK- Implements OTA-RK-00022, ADD 80A Rod Position Indication Urgent CRS 00022 Alarm (Step 3.1) ENSURE SE HS-9, ROD BANK AUTO/MAN SEL is in BOP MANUAL.

BOP (Step 3.2) STOP any evolutions that would require Control Rod motion.

BOP (Step 3.3) 3.3. MONITOR and RECORD RCS Tavg once per hour.

BOP (Step 3.4) REQUEST I&C Department to investigate.

OTA-RK- (Step 3.5) Refer To T/S 3.1.7, FSAR 16.1.3.1 and FSAR 16.3.3.8.

00022

• 3.1.7 Cond A o 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> to Verify the position of the rods with inoperable CRS position indicators indirectly by using core power distribution measurement information.

OR o Reduce THERMAL POWER to 50% RTP.

Page 15 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 3 Page 16 of 33 Event

Description:

Loss of DRPI (Rod M-4) (Tech Spec)

Proc /Time Position Applicants Actions or Behavior OTO-SF-00001, ROD CONTROL MALFUNCTIONS (Crew might not enter this OTO)

OTO-SF-CRS Implements OTO-SF-00001, ROD CONTROL MALFUNCTIONS 00001 (Step 1) CHECK Both Of The Following Are Met For Indication Of Multiple Dropped Rods:

RO

• Annunciator 81A, Two/More Rods At Bottom - LIT - NO

• Rod Bottom lights for greater than one rod - LIT - NO RNO Go To Step 3.

(Step 3) CHECK Main Turbine Runback Or Load Reject - IN PROGRESS BOP - NO RNO Go To Step 5.

(Step 5) PLACE Rod Control in MANUAL:

RO

• SE HS-9 RO (Step 6) CHECK Control Rods Motion STOPPED RO (Step 7) CHECK Instruments Indications - NORMAL OTO-SF- (Step 8) CHECK Annunciator 79A, Rod Ctrl Urg Fail - LIT - NO 00001 RNO - PERFORM The Following:

a. MAINTAIN RCS Tavg/Tref Deviation Within 1.5°F Using Any Of The Following:

RO

• ADJUST Turbine load.

• ADJUST RCS boron concentration.

• ADJUST Control Rods.

b. Go To Step 10.

Page 16 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 3 Page 17 of 33 Event

Description:

Loss of DRPI (Rod M-4) (Tech Spec)

Proc /Time Position Applicants Actions or Behavior (Step 10) CHECK Both Of The Following Are - EXTINGUISHED RO

• Annunciator 81B, Rod At Bottom

• All Rod Bottom lights RO (Step 11) CHECK Rods Misaligned - LESS THAN 12 STEPS (Step 12) CHECK Rods Status - OPERABLE PER Technical Specification RO 3.1.4 (Step 13) DIRECT I&C To Perform ITM-ZZ-0015, Rod Control CRS Troubleshooting Guidelines (Step 14) REVIEW Applicable Technical Specifications:

CRS

• Refer To Attachment C,Technical Specifications (Step 15)

CRS PERFORM Notifications Per ODP-ZZ-00001 Addendum 13, Shift Manager Communications NOTE At Lead Examiners discretion move to the next Event Page 17 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 4 Page 18 of 33 Event

Description:

B Failure MFP Speed Failure Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 4: B Failure MFP Speed Failure o Malfunction (FC) FCSI0132ATVSP, Value = 0, ramp = 5 min o Malfunction (FC) FCSI0132BTVSP, Value = 0, ramp = 5 min o Malfunction (FC) FCSI0132CTVSP, Value = 0, ramp = 5 min

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available SG levels rising B MFP Speed indication goes to zero OTO-AE-00001, FEEDWATER SYSTEM MALFUNCTION Implements OTO-AE-00001, FEEDWATER SYSTEM CRS MALFUNCTION (Step 1) CHECK BOTH MFP Tripped - NO BOP RNO - Go to Step 2 (Step 2) CHECK ONE MFP Tripped - NO BOP RNO - Go to Step 10 (Step 10) Maintain MFP Suction Pressure Greater Than The BOP Following:

• 240 psig BOP (Step 11) Check DFWCS Operator Station on RL005 Available Page 18 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 4 Page 19 of 33 Event

Description:

B Failure MFP Speed Failure Proc /Time Position Applicants Actions or Behavior (Step 12) Check Running Main Feed Pumps Speed - MEETS BOTH of the Following:

• Controlling in AUTO - NO

• Stable - NO BOP RNO - Perform the Following:

a. Place the affected MFP Turbine Speed Control in Manual

• FC SK-509C

b. Manually CONTROL MFP speed to restore SG NR level between 45% and 55%

BOP (Step 13) Check if MFW Reg Valves - In Service BOP (Step 14) Check MFW Reg Valves - Controlling in AUTO The team will continue in OTO-AE-00001, FEEDWATER SYSTEM MALFUNCTION. After SG level is stable and the B MFP is being controlled in Manual the evaluation can continue with the next event.

NOTE At Lead Examiners discretion move to the next Event Page 19 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 5 Page 20 of 33 Event

Description:

C RCP High Vibration Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 5: C RCP High Vibration o Malfunction (BB) CRCPV1_3, value = 5 o Malfunction (BB) CRCPV2, value = 20

• Act as DUTY MANAGER and acknowledge the OTO entry

• Act as Power Dispatch to acknowledge load reduction.

Indications Available 70A RCP VIB DANGER 70B RCP VIB / SYS ALERT OTO-BB-00002, RCP OFF-NORMAL CRS Implement OTO-BB-00002, RCP OFF-NORMAL OTO-BB-RO (Step 1) Check All RCPs - Running 00002 (Step 2) Go to one of the following attachments:

CRS

• Attachment A, RCP High Vibration OTO-BB-00002, Attachment A, RCP High Vibration Step A1)Check RCP Vibration Level:

• All RCPs vibration on the frame - less than 5 mils

• All RCPs vibration on the shaft - less than 20 mils BOP RNO: Perform one of the following:

• IF reactor power is greater than or equal to 48%(P-8 Lit), Then Go to Attachment D, RCP and Reactor Trip.

OTO-BB-00002, Attachment D, RCP and Reactor Trip Page 20 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 5 Page 21 of 33 Event

Description:

C RCP High Vibration Proc /Time Position Applicants Actions or Behavior CRS Implement OTO-BB-00002, Attachment D, RCP and Reactor Trip RO (Step D1) Manually Trip the Reactor.

(Step D2) Verify the Reactor has tripped. - NO RO The C RCP should NOT be tripped at this time. After the reactor is tripped the team will need to complete OTO-BB-00002, Attachment D, RCP and Reactor Trip actions NOTE The applicants will transition to E-0/FR-S.1 at this time RO (Step D3) Trip the affected RCP CRS (Step D4) Perform E-0, while continuing in the procedure RO (Step D5) Check RCP A - Running RO (Step D6) Check RCP B - Running RO (Step D7) Defeat Tavg and T for idle RCS Loop (Step D8) Check No. 1 Seal Leakoff Flow was less than 6 gpm RO prior to securing the RCP Step D8 RNO Close BB HIS-8141C CRS Step (D10) Return to step in effect Page 21 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 22 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior Booth Operator

• Event 6: ATWS (PRELOADED):

o Malfunction (SF) SF006, value = Both_modes

• Event 7: S/G C ASD Sticks Open (PRELOADED):

o Malfunction (AB) ABPV0003A_2, value = 1.0, Condition = HWX06O39R eq 1

• Act as Primary OT and Locally Open the Reactor Trip Breakers. After being dispatched, wait 3 minutes o Delete Malfunction (SF) SF006, value = Both_modes.

o Report to Control Room when complete.

• After 5 minutes report that you are attempting to isolate S/G C ASD. Wait 1 minute and report that bleeding Air to the ASD failed and the Manual Isolation is galled and very difficult to operate. You are getting a tool to aid with operation of the valve.

• After the crew makes the transition to E-2, then Isolate S/G C ASD.

o Insert Event Local Isolate SG C ASD.

Remote (AB) ABPV0029, value = 0, ramp = 2 minutes o Report to Control Room when complete.

• If directed to locally close ABV0087 wait 5 minutes the close ABV0087 o Insert Event Close ABV0087 Remote (AB) ABV0087, value = 0, ramp = 2 minutes o Report to Control Room when complete.

E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection E-0 (Step 1) Check Reactor Trip

• Rod Bottom Lights - All Lit - NO

• Reactor Trip and Bypass Breakers - Open RO

• Neutron Flux - Lowering - NO RNO: Manually Trip Reactor. If Reactor power is greater than or equal to 5% or Intermediate Range SUR is positive, Then Go To FR-S.1, Response to Nuclear Power Generation /

ATWS Step 1.

Page 22 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 23 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior FR-S.1, Response to Nuclear Power Generation / ATWS Implement FR-S.1, Response to Nuclear Power Generation /

CRS ATWS FR-S.1 CAUTION: RCPs should NOT be tripped with reactor power greater than 5%.

CRS NOTE: Steps 1 and 2 are immediate action steps.

(Step 1) Check Reactor Trip

• Rod Bottom Lights - All Lit

• Reactor Trip and Bypass Breakers - Open RO

• Neutron Flux - Lowering 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 dispatching operators to locally Trip the Reactor

• Deenergize PG19 and PG20

• Insert Control Rods

• Establish emergency boration flow to the RCS (Step 2) Check Turbine Trip RO/BOP

• All Stop Valves - Closed RNO - Manually TRIP Turbine (Step 3) Check AFW Pumps Running RO/BOP

• MDAFPs - Both running

• TDAFP - Running if necessary Page 23 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 24 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior FR-S.1 (Step 4) Initiate Emergency Boration of RCS

a. At least one charging pump running

b. ALIGN emergency boration flow path:

1) Start boric acid transfer pumps RO/BOP 2) Open BG HIS 8104

3) Check Emergency Boration Flow - Greater Than 30 GPM

4) Maintain charging Flow greater than boration flow

c. Check PZR Oressure less than 2335 psig (Step 5) Check Containment Purge Isolation

a. ESFAS status panels CPIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• A066Y WHITE lights - ALL LIT (Step 6) Check if the Following Trips Have Occurred

a. Reactor Trip RO/BOP RNO - Locally trip reactor trip breakers

b. Close Supply Breakers to PG19 and PG20

c. Turbine Trip (Step 7) Check if the Reactor is Subcritical RO/BOP YES - Go To Step 16 CRS (Step 16) Return to procedure and step in effect (E-0, step 1)

E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection Page 24 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 25 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior 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

a. Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses

a. AC Emergency Buses - At Least One Energized

• NB01 BOP OR

• NB02

b. AC Emergency Buses - BOTH Energized (Step 4) Check SI Status:

a. CHECK if SI is actuated:

• Any SI annunciator 88A through 88D LIT OR

• SB069 SI Actuate RED light LIT OR RO

• LOCA Sequencer annunciators 30A or 31A LIT

b. 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 Verification, RO/BOP while continuing with this procedure E-0 Att A RO/BOP (Step A1) Check Charging Pumps - Both CCPs running RO/BOP (Step A2) Check SI and RHR Pumps - All running Page 25 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 26 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A3) Check ECCS Flow

a. CCPs To Boron Inj Header FLOW INDICATED

• EM FI917A

• EM FI917B

b. RCS pressure LESS THAN 1700 PSIG (at this time RO/BOP pressure might be below 1700 psig. If it the applicant will contine with the step, if not the applicant will go to step A4)

c. SI Pump Discharge FLOW INDICATED

d. RCS pressure LESS THAN 325 PSIG - NO Go To Step A4.

RO/BOP (Step A4) CHECK ESW Pumps - BOTH RUNNING Page 26 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 27 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A5) CHECK CCW Alignment:

a. 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

b. 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

c. OPEN CCSW To RHR HX valves:

RO/BOP

• EG HIS-101

• EG HIS-102

d. CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EC HIS-11

• EC HIS-12

e. STOP Spent Fuel Pool Cooling Pump(s):

• EC HIS-27

• EC HIS-28

f. RECORD The Time Spent Fuel Pool Cooling Pump Secured

g. MONITOR Time Since CCW Flow Isolated to SFP HX LESS THAN 4 HOURS (Step A6) CHECK Containment Cooler Fans - RUNNING IN SLOW SPEED

• GN HIS-9 RO/BOP

• GN HIS-17

• GN HIS-5

• GN HIS-13 Page 27 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 28 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A7) CHECK Containment Hydrogen Mixing Fans -

RUNNING IN SLOW SPEED

• GN HIS-2 RO/BOP

• GN HIS-4

• GN HIS-1

• GN HIS-3 (Step A8) CHECK If Containment Spray should Be Actuated:

a. CHECK the following:

• Containment pressure - GREATER THAN 27 PSIG OR

• GN PR-934 indicates containment pressure -

RO/BOP HAS BEEN GREATER THAN 27 PSIG OR

• Annunciator 59A CSAS LIT OR

• Annunciator 59B CISB - LIT (Step A8.a RNO) Go To Step A9 (Step A9) CHECK If Main Steamlines Should Be Isolated:

a. CHECK for any of the following:

• Containment pressure - GREATER THAN 17 PSIG OR

• GN PR-934 indicates containment pressure -

RO/BOP 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

b. CHECK MSIVs and Bypass valves - CLOSED Page 28 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 29 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A10) CHECK ECCS Valves - PROPER EMERGENCY ALIGNMENT RO/BOP a. ESFAS status panels SIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A11) CHECK Containment Isolation Phase A:

a. ESFAS status panels CISA sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation Isolation:

RO/BOP a. ESFAS status panels CRVIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A14) CHECK Containment Purge Isolation:

a. ESFAS status panels CPIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

Page 29 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 30 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0, REACTOR TRIP OR SAFETY INJECTION E-0 BOP (Step 6) Check Generator Output Breakers - Open (Step 7) Check Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed (Step 8) Check AFW Pumps BOP a. MD AFW Pumps - Both Running

b. TD AFW Pump - Running if Necessary (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 C per foldout page BOP (Step 10) Check Total AFW Flow > 285,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves

a. PZR PORVs - Closed RO b. PZR PORVs - Both in AUTO

c. PORV Block Valves - Both Open

d. Normal PZR Spray Valves - Closed (Step 12) Check if RCPs should be Stopped

a. RCPs - Any Running RO b. ECCS Pumps - At least One Running

c. RCS Pressure - Less than 1425 psig RNO - Go to Step 13 Page 30 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 31 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-0 (Step 13) Check RCS Temperatures RO

• RCPs Running - Tavg 557 Deg F (Step 14) Check if any SG is Faulted:

a. CHECK pressures in all SGs:

RO/BOP

• Any SG pressure lowering uncontrollably

• Any SG completely depressurized Go to E-2, Faulted Steam Generator Isolation, Step 1.

E-2, Faulted Steam Generator Isolation Implement E-2, Faulted Steam Generator Isolation, Initiate CSF CRS Monitoring E-2 RO/BOP (Step 1) Check MSIVs and Bypass Valves - Closed (Step 2) Check if any SG Secondary Pressure Boundary is BOP Intact (Step 3) Identify Faulted SG(s)

Any SG pressure lowering uncontrollably BOP Any SG completely depressurized Identifies C as faulted SG Page 31 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 32 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-2 (Step 4) Isolate Faulted SG(s)

• Isolate AFW flow (AL HK-11A and AL HK-12A)

• Check ASD closed (AB PIC-3A)

RNO: Close valve as necessary. If valves cannot be closed, then locally close or isolate valves.

BOP

• Locally close TDAFP steam supply (ABV0087)

• Check MFRV closed (AE ZL-530)

• Check MFRBV closed (AE ZL-570)

• Check MFIV closed (AE HIS-41)

• Check SGBD CTMT iso valve closed (BM HIS-3A)

• Close Steamline Low Point Drain valve (AB HIS-7)

NOTE The CT may be performed on foldout page of E-0 Critical Isolate feed flow to C Steam Generator prior to Task RO/BOP developing a RED or ORANGE path to either Integrity or Subcriticality CSF (Step 5) Check CST to AFP Suction Header Pressure -

BOP/RO Greater than 2.75 psig (Step 6) Check Secondary Radiation

• Perform EOP Addendum 11, Restore SG sampling

• Direct Chem. to sample All SGs BOP/RO

• Direct RP to survey steamlines Check unisolated secondary rad monitors Secondary Radiation - Normal Level in all SGs (Step 7) Check If ECCS Flow Should be Reduced

a. RCS Subcooling > 30 Deg F [50 Deg F]

b. Secondary heat sink:

BOP/RO

• NR level in one SG > 5% [25%] OR

• Total AFW low > 285,000 lbm/hr

c. RCS Pressure stable or rising

d. PZR level > 9% [29%]

Page 32 of 33

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 2 rev.1 Event # 6 and 7 Page 33 of 33 Event

Description:

Nuclear Power Generation / ATWS - S/G C ASD Sticks Open Proc /Time Position Applicants Actions or Behavior E-2 BOP/RO (Step 8) Reset SI BOP/RO (Step 9)Stop All But One CCP BOP/RO (Step 10) Go To ES-1.1, SI Termination, Step 3 The scenario can be terminated at the discretion of the Lead Examiner Page 33 of 33

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 3, Rev 1 Op-Test No.: 2016-1 Examiners: ____________________________ Operators: _____________________________

Initial Conditions: 100%

Turnover: The A MD Auxiliary Feedpump has been out of service for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. Work is scheduled to complete next shift.

Eve Malf. No. Event Event nt Type* Description No.

RTD Fails High SRO (I) 1 BBTE0411A1 OTO-BB-00004, RCS RTD Channel Failures RO (I)

(Tech Spec 3.3.1)

Stator Cooling Pump Trip with AUTO Start Failure SRO (C) 2 PCE01A OTA-RK-00026 Add 132C, Generator Protection Runback BOP (C)

Circuit SRO (R)

Partial Loss of Condenser Vacuum 3 EAD05A BOP (R)

OTO-AD-00001, Loss of Condenser Vacuum RO (R)

Dropped rod SRO (C) 4 SF/SFB08_DR OTO-SF-00001, Rod Control Malfunctions RO (C)

(Tech Specs 3.1.4)

SRO (M) Large Steam Line Rupture in Turbine Building with B MSIV AB003 5 RO (M) failing open 9XX_2 & 6 E-2, Faulted S/G Isolation BOP (M)

MD AFP B trips 2 minutes after starting and TDAFP fails to PAL02_3 SRO (C) 6 automatically start PAL01B_1 BOP (C)

E-0, Reactor Trip or Safety Injection

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 6

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 2 Page 1 of 32

Scenario Event Description Callaway 2016-1 NRC Scenario #3, rev. 1 The plant is steady at 100% power. The A MD Auxiliary Feedpump is tagged out for maintenance and will not be returned until next shift.

Once the crew takes the watch, the Loop 1 Hot Leg RTD will fail high causing the control rods to drive in. The Reactor Operator will take manual control of the control rods and respond in accordance with OTO-BB-00004, RCS RTD Channel Failures. Tech Specification 3.3.1 applies.

After Tech Specs have been addressed, the running SCW Pump trips and the standby pump does not auto-start. A turbine runback begins as indicated by load reduction & annunciator 132C. The crew will take action to start the standby SCW Pump (prudent action, OTA directed, or OTO-MA-00001 directed). OTO-MA-00001, Turbine Load Rejection, will be entered with actions taken to stabilize the plant and initiate recovery.

When plant conditions are stable, a partial loss of Condenser vacuum will occur. The crew will perform actions per OTO-AD-00001, Loss of Condenser Vacuum. The crew will commence a down power in an attempt to restore vacuum. When a sufficient downpower (approximately 50 MWe) is achieved, the scenario continues with the next event.

While the crew is lowering power, a dropped rod occurs as indicated by DRPI and Control Rod Alarms. The ROs will perform the immediate actions of OTO-SF-00001 to place rods in manual.

The crew will establish conditions for rod recovery, identify Technical Specifications and begin restoration. Tech Specification Once the crew has addressed the dropped control and addressed Tech Specs, a steam leak develops in the Turbine Building which will be seen by the crew as RCS pressure and temperature rapidly lower. The crew may Manually trip the reactor based on these plant conditions. The crew should enter E-0, Reactor Trip or Safety Injection.

The automatic steamline isolation fails to occur. The crew should manually initiate MSLIS. The B Main Steamline Isolation Valve remains open. The crew should make efforts to complete the isolation of SG B in accordance with E-2, Faulted S/G Isolation, but the B SG cannot be isolated.

The B MDAFP starts normally and then trips after running for 2 minutes. The TDAFP must be started manually due to malfunction inserted during the setup. The crew will then restore adequate feed to the intact Steam Generators.

The scenario will end after the crew has completed E-2 and starts to transition to ES-1.1, SI Termination Page 2 of 32

Scenario Critical Tasks Callaway 2016-1 NRC Scenario #3, rev. 1 Critical Tasks:

Critical Tasks Manually actuate main steamline isolation before a severe (ORANGE path) challenge Establish 285,000 lbm/hr to the intact SGs before intact SG level indicates less than develops to either the subcriticality or the integrity CSF or before transition to ECA-2.1 10% WR (whichever happens first)

EVENT 5 6 Safety Failure to isolate the SGs from the steamline break such that all SGs are allowed to Under the postulated plant conditions, failure to manually establish the minimum significance blow down uncontrollably significantly worsens the power excursion. This worsening of required AFW flow rate (when it is possible to do so) results in a significant reduction of the power excursion is unnecessary; it could be prevented simply by closing the MSIVs safety margin beyond that irreparably introduced by the scenario. Finally, failure to manually actuate AFW under the postulated conditions is a violation of the facility license condition.

Cueing Indication that main steamline isolation is required Indication and/or annunciation that SI is actuated AND AND Indication that main steamline isolation has not actuated automatically Indication and/or annunciation that the AFW flow rate is less than the minimum required

• MSIVs indicate open

• Total AFW flow rate indicates less than the minimum required

• Indication of uncontrolled depressurization of all SGs

• Control switch indication that the circuit breakers or contactors for the motor-driven AFW pumps are open

• Control switch indication that the steam supply valves to the turbine-driven AFW pump are closed Performance Manipulation of controls as required to manually actuate steamline isolation Manipulation of controls in the control room as required to establish the minimum indicator MSIVs undergo fast-closure required AFW flow rate to the SGs MSIVs (except B) indicate closed Performance Crew will observe the following: Indication that at least the minimum required AFW flow rate is being delivered to the feedback

• Steam flow indication from all SGs except B decreases to zero SGs

• All SGs except B stop depressurizing SG levels increasing

• RCS cooldown rate slows Justification for Uncontrolled depressurization of all SGs causes an excessive rate of RCS cooldown, The acceptable results obtained in the FSAR analyses are predicated on the the chosen well beyond the conditions typically analyzed in the FSAR. The excessive cooldown rate assumption that, at the very least, one train of safeguards actuates. If AFW flow performance limit creates large thermal stresses in the reactor pressure vessel and causes rapid insertion commensurate with minimum safeguards actuation is not established, the FSAR of a large amount of positive reactivity. Thus, failure to close the MSIVs under the assumptions and results are invalid. Because compliance with the assumptions of the postulated conditions can result in challenges to the following CSFs: FSAR is part of the facility license condition, failure to manually establish at least the

• Integrity minimum required AFW flow rate (under the postulated conditions and when it is

• Subcriticality possible to do so) constitutes a violation of the license condition.

PWR Owners CT- 12, Manually actuate main steamline isolation CT-4, Establish AFW flow to SGs Group Appendix Page 3 of 32

Scenario Procedure References Callaway 2016-1 NRC Scenario #3, rev. 1 References OTO-SF-00001, Rod Control Malfunctions OTO-BB-00004, RCS RTD Channel Failures OTA-RK-00026 Add 132C, Generator Protection Runback Circuit OTO-MA-00001, Turbine Load Rejection OTO-AD-00001, Loss of Condenser Vacuum E-0, Reactor Trip or Safety Injection E-2, Faulted S/G Isolation Tech Spec 3.3.1 for Reactor Trip System Instrumentation Tech spec 3.3.2 for ESFAS Instrumentation ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. Main Steam Line Break Outside Containment (T(MSI))

a. MSIV Closure

b. AFW Pump Start Page 4 of 32

Scenario Setup Guide Callaway 2016-1 NRC Scenario #3, rev. 1 Scenario #3 Setup Guide:

Establish the initial conditions of IC-10, MOL 100% power:

• RCS boron concentration 862 ppm

• CCP A 863 ppm minus 5 days

• CCP B 865 ppm minus 15 days

• Rod Control Bank D 215 steps, Other banks 228 steps

• A MD Auxiliary Feedpump is tagged out for maintenance

=======SCENARIO PRELOADS / SETUP ITEMS==========

Remove from Service and then place Tags on A MDAFP

• (Preloaded) Insert ME Schematic (AL) e23al01a AL01NB0105TA_BKPOS, value =3 Stator Cooling Pump AUTO Start Failure (Event 2)

• (Preloaded) Insert ME Schematic (CE) m22ce01, CEPS0002TFASIS, value = 1

• (Preloaded) Insert ME Schematic (CE) e23ce05, CE05RL_63_C57TVSP, value = 0 MSIVs dot not auto close and B MSIV fails open (Event 6)

• Insert Malfunction (SA) SAS9XX_1, value = Enable,

• Insert Malfunction (SA) SAS9XX_2, value = Enable,

• Insert Malfunction (SA) SAS9XX_3, value = Enable,

• Insert Malfunction (SA) SAS9XX_4, value = Enable

• Insert Malfunction (SA) SAS9XX_6, value = Enable

• Insert Remote Function (AB) ABHV0017_AuxM, value = Connected MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start (Event 7)

• Insert Remote Function (AL) PAL02_3, value = TRUE

• Insert Malfunction (AL) PAL01B_1, value = Trip, Condition = rec0009 eq 1, Delay = 2 min

======= EVENT 1 ============================

RTD Fails High

• Insert Malfunction (BB) BBTE411A1, value = 650, ramp = 10 sec

======= EVENT 2 ============================

Stator Cooling Pump Trip with AUTO Start Failure

• Insert Malfunction (CE) PCE01A, value = Trip

• SEE PRELOADS ABOVE

=======EVENT 3 ============================

Partial Loss of Condenser Vacuum

• Insert Malfunction (AD) EAD05, value = 75

=======EVENT 4 ============================

Dropped Rod

• Insert Malfunction (SF) SFB08_DR, value = stationary_gripper

=======EVENT 5 PRELOADED=================

Large Steam Line Rupture in Turbine Building with B MSIV failing open

• Insert Malfunction (AB) AB003, value = 6000, ramp = 60 secs

• SEE PRELOADS ABOVE

=======EVENT 6 PRELOADED===============

MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start

• SEE PRELOADS ABOVE Page 5 of 32

Scenario Simulator Lesson Plan Callaway 2016-1 NRC Scenario #3, rev. 1 Page 6 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 1 Page 7 of 32 Event

Description:

RTD Fails High (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 1 (RTD Fails High ) (At the discretion of the Lead Examiner) o Malfunction (BB) BBTE0411A1, Value = 650, Ramp = 10 sec

• When contacted, respond as I&C. Acknowledge the request to trip bistables and to investigate the instrument/channel failure.

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available ANN 65C, AUCT T AVG HI ANN 65E, T REF / T AUCT LO ANN 82B, OTT ROD STOP ANN 82C, OPT ROD STOP ANN 83C, RX PARTIAL TRIP OTO-SF-00001, Rod Control Malfunctions OTO-SF-CRS Implement OTO-SF-00001, Rod Control Malfunctions 00001 (Step 1) CHECK Both Of The Following Are Met For Indication Of RO Multiple Dropped Rods: - NO Step 1 RNO Go To Step 3.

(Step 3) CHECK Main Turbine Runback Or. Load Reject - IN RO PROGRESS Step 3 RNO Go To Step 5 (Step 5) PLACE Rod Control in MANUAL:

RO

• SE HS-9 RO (Step 6) CHECK Control Rods Motion - STOPPED Page 7 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 1 Page 8 of 32 Event

Description:

RTD Fails High (Tech Spec)

Proc /Time Position Applicants Actions or Behavior OTO-SF- (Step 7) CHECK Instruments Indications - NORMAL 00001 b. RCS Tavg:

RO

• BB TI-412 Step 7.b RNO Go To OTO-BB-00004, RCS RTD Channel Failures.

OTO-BB-00004, RCS RTD Channel Failures CRS Implement OTO-BB-00004, RCS RTD Channel Failures OTO-BB- (Step 1) Place rod control in manual RO 00004

• SE HS-9 (Step 2) CHECK RCS loop NR Tavg and Delta-T indicator - failed RO

• Loop 1: BB TI-412 (Tavg) - failed high

• Loop 1 BB TI-411A (T) - failed high (Step 3) Select T and Tavg channel defeat switches to failed channel:

• BB TS-411F, T Defeat Switch - Select to T411 RO

• BB TS-412T, Rod Control Tave Input Channel Defeat Switch -

Select to T412

1. (Step 4 and Step 4 RNO) Check RCS Tavg within 1.5°F of Tref RNO Restore RCS Tavg to within 1.5°F of Tref using any of the following:

RO

• Adjust control rods

• Adjust turbine load

• Adjust RCS boron concentration NOTE RNO may or may not have to be performed dependent on how quickly rods are placed in manual IAW Step 1 (Step 5) CHECK rod control - IN AUTO RO

• SE HS-9 Page 8 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 1 Page 9 of 32 Event

Description:

RTD Fails High (Tech Spec)

Proc /Time Position Applicants Actions or Behavior OTO-BB- (Step 6) CHECK pressurizer level within one of the following:

00004 RO

• Trending to program level OR

• At Program Level (Step 7) Select an operable channel for the OPDT/OTDT temperature BOP recorder:

• SC TS-411E CRS (Step 8) Review Attachment A, Effects Of RCS RTD Instrument Failure (Step 9) Review Applicable Technical Specifications: Att J

• 3.3.1, Cond A

• 3.3.1, Table 3.3.1-1, Item 6, Cond E CRS

• 3.3.1, Table 3.3.1-1, Item 7, Cond E o 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 /> OR Be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> CRS (Step 10) Direct I&C to trip bistables NOTE At Lead Examiners discretion move to the next Event Page 9 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 2 Page 10 of 32 Event

Description:

Stator Cooling Pump Trip with AUTO Start Failure Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 2 (Stator Cooling Pump Trip with AUTO Start Failure) o Malfunction (CE) PCE01A, value = Trip o (Preloaded) Insert ME Schematic (CE) m22ce01, CEPS0002TFASIS, value = 1 o (Preloaded) Insert ME Schematic (CE) e23ce05, CE05RL_63_C57TVSP, value =

0

• When contacted as an OT to A SCW pump, wait 5 minutes and report back It is warm to the touch

• When contacted as an OT to go to PG13 to check out the A SCW pump breaker wait 5 minutes and report back The breaker for the A SCW pump is the tripped free position and indicates overcurrent

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available 132C Generator Protection Runback Circuit 83C RX PARTIAL TRIP OTA-RK-00026, Add 132C, Generator Protection Runback Circuit Implement OTA-RK-00026, Add 132C, Generator Protection Runback CRS Circuit OTA-RK-(Step 3.1) IF a Turbine Runback occurs, Go To OTO-MA-00001, Turbine 00026, BOP Runback.

Add 132C BOP (Step 3.2) ENSURE Stator Cooling Pump RUNNING (Step 3.3) Using EA HIS-1, SERVICE WTR FROM STATOR WTR BOP COOLERS, ENSURE EAHV0001 is OPEN.

(Step 3.4) DETERMINE the cause of the alarm using the Computer BOP Points listed in the table below.

Page 10 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 2 Page 11 of 32 Event

Description:

Stator Cooling Pump Trip with AUTO Start Failure Proc /Time Position Applicants Actions or Behavior OTA-RK- (Step 3.5) DISPATCH an operator to the local panels to determine if the 00026, CRS cause is an alarm on CE129A or a loss of DC power (DC SUPPLY light Add 132C on CC128A).

(Step 6) MAINTAIN Generator Load below the limits of Curve Book Figure CRS 10.7, Main Generator Load vs SCW Flow.

OTO-MA-00001, Turbine Load Rejection OTO-MA-CRS Implement OTO- MA-00001, Turbine Load Rejection 00001 RO (Step 1) Place Rod Control in AUTO (Step 2) Check Rod control System Responding to RCS Tavg/Tref Deviation by ensuring on of the following:

RO Control Rods are inserting and RCS Tavg trending to within 5°F of Tref OR RCS Tavg within 5°F of Tref (Step 3) Check Stator Cooling Status Inlet Pressure - Greater than 50 PSIG BOP RNO - If Stator Cooling water pressure is low, Then START standby Stator Cooling Water Pump CE HIS-2 (Step 4) Check both 82B and 82 extinguished RO (they are extinguished from the previous event)

BOP (Step 5) Check all Circ Water Pumps running (Step 6) Check Turbine control responding correctly (runback should stop BOP when standby stator cooling water pump started)

Page 11 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 2 Page 12 of 32 Event

Description:

Stator Cooling Pump Trip with AUTO Start Failure Proc /Time Position Applicants Actions or Behavior OTO-MA- (Step 7) Check Stator Cooling Water inlet pressure less than 50 psig 00001 BOP RNO - Go to step 19 BOP (Step 19) Maintain Main Generator MVARS BOP (Step 20) Check HP Heater bypass valve closed (Step 21) If turbine steam admission valve failure occurred BOP RNO - Go to step 22 RO (Step 22) Check if Rod Control should be placed in Manual BOP (Step 23) Check Main Generator Load Stable (Step 24) Check C-7, Load Loss Stm Dump Armed - LIT BOP RNO - Go to Step 26 (Step 26) Determine if Turbine Setback has occurred BOP RNO - go to step 28 RO (Step 28) Check Annunciator 81C extinguished and AFD within limits CRS (Step 29) Review Tech Specs - NONE NOTE At Lead Examiners discretion move to the next Event Page 12 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 13 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 3 (Partial Loss of Condenser Vacuum) o Malfunction(AD) EAD05, Value = 75

• When contacted, respond as Operations Tech to investigate the cause of the Loss of Vacuum.

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available Automatic Starting of Standby Condenser Vacuum Pump Rising Main Condenser Backpressure Unexplained lowering in Main Turbine Load ANN 106C COND HOTWELL LEV HI (potential)

OTO-AD-00001, Loss of Condenser Vacuum CRS Implement OTO-AD-00001, Loss of Condenser Vacuum OTO-AD- (Step 1) Check Main Condenser Backpressure - LESS THAN 7.5 inches BOP 00001 HGA - YES Note: Attachment A, Diagnostic Actions, contains actions which may be performed for slow moving events.

(Step 2) Refer to Attachment A, Diagnostic Actions, As Time permits to BOP Perform Actions (Step 3) Check Main condenser Backpressure - greater than 4.0 inches HGA BOP

a. Obtain permission from the SM/CRS

b. Place DA HS-113, Circ WTR Pump Turb Setback, to ENABLE BOP (Step 4) Check Main Condenser Backpressure - Deteriorating or Stable Page 13 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 14 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior RO (Step 5) Place Rod Control in AUTO OTO-AD- (Step 6) Manage Reactivity 00001 CREW Perform a Reactivity Management Brief (Step 7) REDUCE Turbine Load At Less Than Or Equal To 5% Per Minute Using Any Of The Following:

• REDUCE Turbine load using the %/Min Loading Rate:

a. SLOWLY LOWER Load using the DECREASE LOAD pushbutton until all of the following are met:

Load Limit Limiting Light - EXTINGUISHED Decrease Loading Rate "OFF" Light - LIT Loading Rate Limit %/MIN "1/2" Light - LIT BOP

b. ROTATE Load Limit Set potentiometer fully clockwise

c. SELECT Decrease Loading Rate - ON

d. SET Loading Rate Limit %/Min to desired value

e. LOWER load set MW toward desired load using the DECREASE LOAD pushbutton OR

• REDUCE Turbine load using the Load Limit Potentiometer Page 14 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 15 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior OTO-AD- (Step 8) BORATE From The BAST By Performing Any Of The Following:

00001

• BORATE using OTN-BG-00002 Attachment 8 OR

• BORATE to the VCT:

a. PLACE RCS Makeup Control in STOP:

BG HS-26

b. PLACE RCS Makeup Control Selector in BORATE:

BG HS-25

c. SET Boric Acid Flow Controller to the desired flow rate BG FK-110 RO d. PLACE BG FK-110 in AUTO

e. RESET Boric Acid Counter to 000:

BG FY-110B

f. SET BG FY-110B for the desired gallons of boric acid to be added

g. PLACE BG HS-26 in RUN

h. WHEN desired boration is complete, THEN PLACE BG HS-26 in STOP

i. REPEAT Boration as necessary OR Page 15 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 16 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior (Step 8 continued) BORATE From The BAST By Performing Any Of The Following:

OR

• BORATE using Emergency Boration:

a. START at least one Boric Acid Transfer Pump:

BG HIS-5A BG HIS-6A

b. OPEN Emergency Borate To Charging Pump Suction:

BG HIS-8104

c. CHECK Emergency Borate Flowrate - GREATER THAN 30 GPM BG FI-183A

d. WHEN desired boration is complete, THEN:

1) CLOSE Emergency Borate to Charging Pump Suction:

o BG HIS-8104

2) STOP Boric Acid Transfer Pumps:

o BG HIS-5A o BG HIS-6A

e. REPEAT Boration as necessary OTN-BG- (Attachment 8) Borate Mode of RMCS Operation 00002, 1. Place BG HS-26 , RCS M/U CTRL, in STOP Att. 8

2. Place BG HS-25, RCS M/U CTRL SEL, in BOR

3. RESET BG FY-110B, BA Counter, to 000

4. ENSURE BG-FY-110B is set to deliver the desired amount of boron RO

5. Place BG HS-26, RCS M/U CTRL, in RUN

6. When the desired amount of borated water has been added, PLACE BG HS-26, RCS M/U CTRL, in STOP.

7. If required, PERFORM the following:

a. Place BG HS-25, RCS M/U CTRL SEL, in AUTO

b. Place BG HS-26, RCS M/U CTRL, in RUN Page 16 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 17 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior OTO-AD- (Step 9) INITIATE Boron Equalization By Performing the Following:

00001 a. ENERGIZE at least one group of Pressurizer Backup Heaters:

• B/U Group A BB HIS-51A

• B/U Group B BB HIS-52A RO b. PLACE the Pressurizer Pressure Master Controller in MAN:

• BB PK-455A

c. LOWER Pressurizer Pressure Master Controller output to 38% to 42%

d. PLACE the Pressurizer Pressure Master Controller in AUTO BOP (Step 10) Check MFP Turbine Speed Control - In AUTO (Step 11) NOTIFY The Power Dispatcher Of The Following:

• Load reduction is in progress CRS

• Rate of load reduction

• Amount of load reduction (Step 12) NOTIFY The Following Departments That Load Reduction Is In Progress And The Rate Of Load Reduction:

• Chemistry CRS

• Count Room Technician

• Radiation Protection

• Radwaste (Step 13) CHECK Rod Control System Responding To RCS Tavg/Tref Deviation By Ensuring One Of The Following:

• Control Rods are inserting AND RCS Tavg trending to within 3°F RO of Tref OR

• RCS Tavg within 3°F of Tref (Step 14) If possible Perform a Rapid Downpower NIS PR adjustment BOP while reducing power using OSP-SE-00004, NIS Power Range Heat Balance RO (Step 15) Check if Rod Control should be in MANUAL Page 17 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 3 Page 18 of 32 Event

Description:

Partial Loss of Condenser Vacuum Proc /Time Position Applicants Actions or Behavior OTO-AD-CRS (Step 16) Perfom additional Actions As Necessary for Power Reduction 00001 NOTE After load has been reduced approximately 50 MWe or at Lead Examiners discretion move to the next Event Page 18 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 4 Page 19 of 32 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 4 (Dropped Rod Cntrl Bank C1 Rod B8)

• Malfunctions/SF/SFB08_DR/Stationary Gripper/Insert

• When directed to delete dropped rod malfunction delete SFB08_DR from Instructor Action Summary

• When requested to investigate as I&C, wait 5 minutes and report that there is a blown fuse and it has been replaced

• When contacted as Reactor Engineering wait 5 minutes and report that there is no reason the rod cannot be recovered

• When requested to investigate as the OPS TECH, report that B light on 1AC and 2AC cabinets are lit.

• When contacted, hold AUTO/MAN switch for the P-A Converter in MAN:

o P/A Converter o ENG MODE ME Schematics/SF/x6064d95s001(P/A converter)/ Click on P/A converter/Manual Signal=1/Insert o Report to the Control Room that the AUTO/MAN switch is in Manual.

• When contacted, return the AUTO/MAN switch to AUTO:

o P/A Converter o ENG MODE ME Schematics/SF/x6064d95s001(P/A converter)/ Click on P/A converter/Auto Signal=1/Insert o Report to the Control Room that the AUTO/MAN switch is in AUTO.

• When contacted, respond as Duty Manager, acknowledge entry into the OTO Indications Available:

ANN 79 C CONTROL ROD DEV ANN 80 C RPI ROD DEV ANN 81 B ROD 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 Page 19 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 4 Page 20 of 32 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior OTO-SF (Step 1) Check Both of the Following are Met for Indication of Multiple 00001 Dropped Rods RO ANN 81A, TWO/More Rods at Bottom Lit Rod Bottom lights lit for greater than one rod

• RNO G0 to Step 3 (Step 3) Check Main Turbine Runback Or Load Reject - IN PROGRESS RO

• RNO Go to Step 5 (Step 5) Place Rod Control in Manual RO

• SE HS-9 RO (Step 6) Check Control Rods Motion STOPPED RO (Step 7) Check Instrument Indication Normal (Step 8) Check Annunciator 79A LIT - NO:

RNO: Maintain RCS Tavg/Tref and go to Step 10 RO/BOP

• ADJUST Turbine load.

• ADJUST RCS boron concentration.

• ADJUST Control Rods.

(Step 10) Check Annunciator 81B and all Rod Bottom Lights Extinguished RO - NO:

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

RO RNO: Go to Step A3 CRS (Step A3) Contact I&C to determine reason for Dropped Rod (Step A4) CHECK Shutdown Margin Is Within The Limits Provided In The CRS COLR Within 1 Hour Page 20 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 4 Page 21 of 32 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior (Step A5) CHECK Axial Flux Difference (AFD) - WITHIN THE LIMITS OF CRS CURVE BOOK, FIGURE 1-1, AXIAL FLUX DIFFERENCE LIMITS NOTE Depending on the amount of the downpower from the previous event QPTR could be either above or below 1.02 (Step A6) CHECK QPTR - LESS THAN OR EQUAL TO 1.02 CRS If YES the crew continues with step A7 If NO TS 3.2.4 Cond A applies and the crew will reduce power NOTE If QPTR is greater than 1.02 continue with scenario (go to next event and follow up on TS 3.1.4.B after the scenario)

CRS (Step A7) Check Dropped Rod can be recovered in less than one hour.

(Step A8) CONSIDER The Following Prior To Recovering The Rod:

• Length of time the rod has been misaligned CRS

• Power Level at which the realignment will be performed

• Rate of control rod movement during realignment

• Movement of other control rods to support realignment (Step A9) PERFORM Notifications Per ODP-ZZ-00001 Addendum 13, CRS Shift Manager Communications (Step A10) NOTIFY Reactor Engineering Prior To Attempting Recovery CRS Of The Control Rod (Step A11) CHECK Both Of The Following Are Met:

CRS

• Reason for dropped/misaligned rod has been identified

• Problem has been corrected CRS (Step A12) PERFORM Attachment B, Dropped/Misaligned Rod Recovery NOTE While some recovery actions of Attachment B may be performed, the intent is proceed to the next event after the Technical Specification declaration. Therefore Attachment B actions are not listed here.

Page 21 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 4 Page 22 of 32 Event

Description:

Dropped Rod Cntrl Bank C1 Rod B8 Proc /Time Position Applicants Actions or Behavior (Step A13) REVIEW Applicable Technical Specifications:

CRS

• 3.1.4.B for Rod Group Alignment Limits NOTE Any time after the Technical Specifications have been identified and at Lead Examiners discretion, move to the next Event Page 22 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 23 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 5 and 6 (Large Steam Line Rupture outside Containment with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start) o Malfunction (AB) AB003, value = 10000, ramp = 2 minutes

• The following PRELOADS are activated o MSIVs dot not auto close and B MSIV fails open (Event 5)

Malfunction (SA) SAS9XX_1, value = Enable, Malfunction (SA) SAS9XX_2, value = Enable, Malfunction (SA) SAS9XX_3, value = Enable, Malfunction (SA) SAS9XX_4, value = Enable Malfunction (SA) SAS9XX_6, value = Enable Remote Function (AB) ABHV0017_AuxM, value = Connected o MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start (Event 6)

Remote Function (AL) PAL02_3, value = TRUE Malfunction (AL) PAL01B_1, value = Trip, Condition = rec0009 eq 1, Delay = 2 min

• When contacted, respond as DUTY MANAGER to acknowledge plant trip.

• If contacted as an OT to locally close TDAFP steam supply (ABV0085) wait 5 minutes a respond I cant enter Area 5 due to steam in the area

• If contacted as an OT to locally check the B MDAFP wait 5 minutes a respond The pump is warm to the touch and has an overcurrent trip on the breaker Indications Available:

STEAM FLOW FEED FLOW MISMATCH RISING REACTOR POWER AND LOWERING TAVG Observes Indications of Steam Line Break and Trips Reactor CREW RCS Temperature Lowering RCS Pressure Lowering E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection Page 23 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 24 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior 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 (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 Verification, while RO/BOP continuing with this procedure E-0 Att A RO/BOP (Step A1) Check Charging Pumps - Both CCPs running RO/BOP (Step A2) Check SI and RHR Pumps - All running Page 24 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 25 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A3) Check ECCS Flow

a. CCPs To Boron Inj Header FLOW INDICATED

• EM FI917A

• EM FI917B RO/BOP b. RCS pressure LESS THAN 1700 PSIG (at this time pressure might be below 1700 psig. If it the applicant will contine with the step, if not the applicant will go to step A4)

c. SI Pump Discharge FLOW INDICATED

d. RCS pressure LESS THAN 325 PSIG - NO Go To Step A4.

RO/BOP (Step A4) CHECK ESW Pumps - BOTH RUNNING (Step A5) CHECK CCW Alignment:

a. 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

b. 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 RO/BOP c. OPEN CCSW To RHR HX valves:

• EG HIS-101

• EG HIS-102

d. CLOSE Spent Fuel Pool HX CCW Outlet Valves:

• EC HIS-11

• EC HIS-12

e. STOP Spent Fuel Pool Cooling Pump(s):

• EC HIS-27

• EC HIS-28

f. RECORD The Time Spent Fuel Pool Cooling Pump Secured

g. MONITOR Time Since CCW Flow Isolated to SFP HX LESS THAN 4 HOURS Page 25 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 26 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A6) CHECK Containment Cooler Fans - RUNNING IN SLOW SPEED

• GN HIS-9 RO/BOP

• GN HIS-17

• GN HIS-5

• GN HIS-13 (Step A7) CHECK Containment Hydrogen Mixing Fans - RUNNING IN SLOW SPEED

• GN HIS-2 RO/BOP

• GN HIS-4

• GN HIS-1

• GN HIS-3 (Step A8) CHECK If Containment Spray should Be Actuated:

a. CHECK the following:

• Containment pressure - GREATER THAN 27 PSIG OR

• GN PR-934 indicates containment pressure - HAS BEEN GREATER THAN 27 PSIG RO/BOP OR

• Annunciator 59A CSAS LIT OR

• Annunciator 59B CISB - LIT (Step A8.a RNO) Go To Step A9 Page 26 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 27 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A9) CHECK If Main Steamlines Should Be Isolated:

a. 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 RO/BOP OR

• AB PR-514 or AB PR-535 indicates steamline pressure - HAS BEEN LESS THAN 615 PSIG

b. CHECK MSIVs and Bypass valves - CLOSED - NO RNO - FAST CLOSE all MSIVs and Bypass valves:

• AB HS79

• AB HS80 IF valve(s) will NOT fast close, THEN CLOSE MSIV(s) and bypass valves as necessary.

The B MSIV does not go closed Critical Manually actuate main steamline isolation before a severe Task (ORANGE path) challenge develops to either the subcriticality or CREW the integrity CSF or before transition to ECA-2.1 (whichever happens first)

(Step A10) CHECK ECCS Valves - PROPER EMERGENCY ALIGNMENT RO/BOP a. ESFAS status panels SIS sections:

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A11) CHECK Containment Isolation Phase A:

a. ESFAS status panels CISA sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT Page 27 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 28 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 Att A (Step A12) CHECK SG Blowdown Isolation:

a. ESFAS status panels SGBSIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A13) CHECK Both Trains of Control Room Ventilation Isolation:

a. ESFAS status panels CRVIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A14) CHECK Containment Purge Isolation:

a. ESFAS status panels CPIS sections:

RO/BOP

• SA066X WHITE lights - ALL LIT

• SA066Y WHITE light - ALL LIT (Step A15) NOTIFY CRS of the following:

• Unanticipated Manual actions taken.

RO/BOP

• Failed Equipment status

• Attachment A, Automatic Action Verification, completed.

E-0, REACTOR TRIP OR SAFETY INJECTION E-0 BOP (Step 6) Check Generator Output Breakers - Open (Step 7) Check Feedwater Isolation

a. Main Feedwater Pumps - Tripped BOP b. Main Feedwater Reg Valves - Closed

c. Main Feedwater Reg Bypass Valves - Closed

d. Feedwater Isolation Valves - Closed Page 28 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 29 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 (Step 8) Check AFW Pumps

a. MD AFW Pumps - Both Running - *NO

b. TD AFW Pump - Running if Necessary - NO RNO

b. START TD AFW Pump:

1) OPEN AFP Turbine Loop Steam Supply valve(s):

BOP

• AB HIS5A (SG B)

• AB HIS6A (SG C)

2) OPEN AFP Turbine Mechanical Trip/Throttle valve:

• FC HIS312A

3) ENSURE AFP Turbine Speed Control is set at 3850 rpm minimum:

• FC HIK313A

• The B MDAFP starts normally and then trips after running for 2 minutes.

Critical Establish 285,000 lbm/hr to the intact SGs before intact SG level CREW Task indicates less than 10% WR (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 > 285,000 lbm/hr (Step 11) Check PZR PORVs and Spray Valves

a. PZR PORVs - Closed RO b. PZR PORVs - Both in AUTO

c. PORV Block Valves - Both Open

d. Normal PZR Spray Valves - Closed (Step 12) Check if RCPs should be Stopped

a. RCPs - Any Running RO b. ECCS Pumps - At least One Running

c. RCS Pressure - Less than 1425 psig RNO - Go to Step 13 Page 29 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 30 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-0 (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:

a. CHECK pressures in all SGs:

RO/BOP

• Any SG pressure lowering uncontrollably

• Any SG completely depressurized Go to E-2, Faulted Steam Generator Isolation, Step 1.

E-2, Faulted Steam Generator Isolation Implement E-2, Faulted Steam Generator Isolation, Initiate CSF CRS Monitoring E-2 (Step 1) Check MSIVs and Bypass Valves - NO RNO - FAST CLOSE all MSIVs and Bypass valves:

• AB HS-79 RO/BOP

• AB HS-80 IF valve(s) will NOT fast close, THEN CLOSE MSIV(s) and bypass valves as necessary.

The B MSIV does not go closed This step may have been completed during the performance of E-0, Attachment A Critical Manually actuate main steamline isolation before a severe Task (ORANGE path) challenge develops to either the subcriticality or CREW the integrity CSF or before transition to ECA-2.1 (whichever happens first)

BOP (Step 2) Check if any SG Secondary Pressure Boundary is Intact Page 30 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 31 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-2 (Step 3) Identify Faulted SG(s)

Any SG pressure lowering uncontrollably BOP Any SG completely depressurized Identifies B as faulted SG (Step 4) Isolate Faulted SG(s)

• Isolate AFW flow (AL HK-9A and AL HK-10A)

• Check ASD closed (AB PIC-2A)

RNO: Close valve as necessary. If valves cannot be closed, then locally close or isolate valves.

• Locally close TDAFP steam supply (ABV0085)

BOP (Due to location of steam leak this will not be completed)

• Check MFRV closed (AE ZL-520)

• Check MFRBV closed (AE ZL-560)

• Check MFIV closed (AE HIS-40)

• Check SGBD CTMT iso valve closed (BM HIS-2A)

• Close Steamline Low Point Drain valve (AB HIS-8)

(Step 5) Check CST to AFP Suction Header Pressure - Greater than BOP/RO 2.75 psig (Step 6) Check Secondary Radiation

• Perform EOP Addendum 11, Restore SG sampling

• Direct Chem. to sample All SGs BOP/RO

• Direct RP to survey steamlines Check unisolated secondary rad monitors Secondary Radiation - Normal Level in all SGs Page 31 of 32

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 3 rev.1 Event # 5 and 6 Page 32 of 32 Event

Description:

Large Steam Line Rupture in Turbine Building with B MSIV failing open / MD AFP B trips 2 minutes after starting and TDAFP fails to automatically start Proc /Time Position Applicants Actions or Behavior E-2 (Step 7) Check If ECCS Flow Should be Reduced

a. RCS Subcooling > 30 Deg F [50 Deg F]

b. Secondary heat sink:

BOP/RO

• NR level in one SG > 5% [25%] OR

• Total AFW low > 285,000 lbm/hr

c. RCS Pressure stable or rising

d. PZR level > 9% [29%]

BOP/RO (Step 8) Reset SI BOP/RO (Step 9)Stop All But One CCP BOP/RO (Step 10) Go To ES-1.1, SI Termination, Step 3 The scenario can be terminated at the discretion of the Lead Examiner Page 32 of 32

Appendix D Scenario Outline Form ES-D-1 Facility: Callaway Scenario No.: 4, Rev 1 Op-Test No.: 2016-1 Examiners: ____________________________ Operators: _____________________________

Initial Conditions: Reactor Start up preparations in progress, Mode 3 with S/D Banks Withdrawn Turnover: The plant is in MODE 3 with shutdown banks withdrawn in preparation for a reactor startup.

AEPS is OOS for breaker repair on PB0501. The crew is to maintain plant conditions until the oncoming crew completes Just In Time Training.

Even Malf. No. Event Event t No. Type* Description HWXST1E21 NE01 Starting Air Receiver air pressure low 1 SRO A (Tech Spec 3.8.3)

Source Range Channel Failure SRO (I) 2 NIS02B OTO SE-00001, Nuclear Instrument Malfunction RO (I)

(Tech Spec 3.3.1)

SRO (C) Steam Dump Valves fail open 3 MSS09A BOP (C) OTO-AB-00001, Steam Dump Malfunction SRO (C)

Lossofswitch Loss of Offsite Power 4 RO (C) yard.lsn E-0, Reactor Trip or Safety Injection BOP (C)

SRO (M)

B ESW Pump Trip / Loss of All AC Power 5 PEF01B RO (M)

ECA-0.0, Loss of All AC Power BOP (M)

A EDG Fails to Start (Local Start Available 5 minutes after SRO (C) 6 NE01 Loss of All AC) A ESW pump fails to AUTO start BOP (C)

ECA-0.0, Loss of All AC Power SRO (C) PZR PORV PCV-455 Fails Open with Manual Control Available 7 PCV455A RO (C) ECA-0.0, Loss of All AC Power

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 2

3. Abnormal events (2-4) 3

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Page 1 of 19

Scenario Event Description Callaway 2016-1 NRC Scenario #4, rev. 1 The plant is in MODE 3 with shutdown banks withdrawn in preparation for a reactor startup.

AEPS is OOS for breaker repair on PB0501. The crew is to maintain plant conditions until the oncoming crew completes Just In Time Training.

Once the crew takes the watch, the Secondary OT reports a worker accidently bumped open two valves and lowered the air pressure on both of the A EDG air receivers and both of the A EDG starting air receivers are at 300 psig. The SRO reviews the applicable TS for the EDG air receivers, Tech Spec 3.8.3 applies.

After Tech Specs have been addressed, the Source Range channel N31 will fail to 1E4 CPS (more than double the original value). The operator will respond in accordance with OTO SE-00001, Nuclear Instrument Malfunction, and, Tech Spec 3.3.1 applies.

After Tech Specs have been addressed, 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 valves manually to control the cooldown.

After the Steam Dumps have been closed, a fault at the Montgomery substation results in a loss of all offsite power. The reactor does not automatically trip (RCP loss) since power is below the P-7 setpoint. However, it should be manually tripped when it is realized that no RCPs are running.

The crew should implement E-0, Reactor Trip or Safety Injection. Emergency Diesel Generator (EDG) NE01 fails to start due to a faulty Start Failure Relay. EDG NE02 starts and energizes Essential Bus NB02, but ESW Pump B trips upon manual start attempt. NE02 trips 10 minutes after starting due to lack of cooling water if it is not manually secured by the crew. The crew should enter ECA-0.0, Loss of All AC Power.

When NB02 is deenergized, PZR PORV BB PCV 455A fails partially open. The crew should close the failed PORV in step 3 of ECA-0.0. The crew should begin making attempts to reenergize one of the busses by dispatching operators to locally check the EDG.

5 minutes after the loss of NB02, the crew can start the A EDG locally. After the A EDG is started and energizes NB01, the A ESW pump will fail to AUTO start and must be manually started.

The scenario is complete when the crew has transitioned out of ECA-0.0.

Page 2 of 19

Scenario Critical Tasks Callaway 2016-1 NRC Scenario #4, rev. 1 Critical Tasks:

Critical Tasks Manually close the Open PORV before completing Step 3 of ECA-0.0 Manually start A ESW pump prior to A EDG tripping on high temperature.

EVENT 7 6 Safety The open PORV greatly increases the rate at which RCS inventory is depleted, at a time Failure to manually start the SW pump under the postulated plant conditions means that significance when the lost inventory cannot be replaced by active injection. Thus, failure to close the the EDG is running without SW cooling. Running the EDG without SW cooling leads to a PORV defeats the basic purpose of ECA-0.0. Additionally, it is critical that the PORV be high-temperature condition that can result in EDG failure due to damage caused by closed as soon as possible. Hence, manual closure of the PORV (when the PORV is engine overheating. Under the postulated plant conditions, the running EDG is the only open and RCS pressure is less than [the setpoint for automatic closure]4) is imperative operable EDG. Thus, failure to perform the critical task constitutes misoperation or and urgent in order to ensure the effectiveness of subsequent actions in extending the incorrect crew performance in which the crew does not prevent degraded emergency time to core uncovery. power capacity.

Cueing Indication and/or annunciation of station blackout Indication and/or annunciation that one ac emergency bus is energized by an EDG Valve position indication and/or annunciation that the PRZR PORV is open

• Bus-energized lamp illuminated Indication that RCS pressure is below the setpoint at which the PRZR PORV should

• Circuit breaker position lamps indicate breaker closed reclose automatically

• Bus voltage indication shows nominal voltage present Indication and/or annunciation of decreasing RCS pressure

• EDG status Indication and/or annunciation consistent with the discharge of PRZR fluid to the PRT AND

• PRT temperature, level, pressure Indication and/or annunciation that no SW pump is running

• Tailpipe RTDs and/or acoustic monitors

• Control switch indication that the circuit breakers or contactors for all SW pumps are open

• SW pump discharge pressure indicator reads zero

• SW flow indicator reads zero Performance Manipulation of controls as required to close the PRZR PORV Manipulation of controls as required to start the SW pump powered from the ac indicator

• PRZR PORV indicates closed emergency bus energized by the EDG

• Control switch indication that the circuit breaker or contactor for a SW pump aligned to supply cooling water to the running EDG is closed Performance PRZR pressure stabilizes Indication and/or annunciation that a SW pump is running, aligned to supply cooling feedback water to the running EDG

• SW low flow condition clear; indication of flow

• SW low pressure condition clear; indication of pressure Justification for This performance standard is imposed because it is imperative and urgent that the If the EDG trips automatically because of an engine over-temperature condition, it the chosen PRZR PORV be closed in order for the strategy of ECA-0.0 to succeed. The PORV means that the station is again blacked out. It also means that the crew failed to start performance limit constitutes a very large leakage path. Leaving it open causes rapid depletion of RCS the SW pump manually as directed by ECA-0.0, Step 27 inventory at a time when that inventory cannot be replaced.

In step 3 of ECA-0.0, the crew is directed to check the major RCS outflow paths that could contribute to rapid depletion of RCS inventory. The PRZR PORVs offer the largest potential for RCS inventory loss.

Therefore, they are an outflow path that must be checked and, if necessary, closed.

PWR Owners CT-22, Manually close an open PORV during SBO. CT - 25, Manually start SW pump for EDG cooling Group Appendix Page 3 of 19

Scenario Procedure References Callaway 2016-1 NRC Scenario #4, rev. 1 References OTG-ZZ-00002, Reactor Startup - IPTE OTA-RK-00016, Add 20D, Diesel Generator NE01 Trouble OTO-AB-00001, Steam Dump Malfunction OTO SE-00001, Nuclear Instrument Malfunction E-0, Reactor Trip or Safety Injection ES-0.1, Reactor Trip Response ECA-0.0, Loss of All AC Power Tech spec 3.3.1 for RTS Instrumentation Tech spec 3.8.3 for Diesel Starting Air ODP-ZZ-00025, EOP/OTO User's Guide PRA Systems, Events or Operator Actions

1. Loss of Offsite Power (T(1))

a. Any Open Pressurizer PORVs Reclose Page 4 of 19

Scenario Setup Guide Callaway 2016-1 NRC Scenario #4, rev. 1 Scenario #4 Setup Guide:

Establish the initial conditions of 0% power: (IC 8 on 15-3)

• RCS boron concentration 1437 ppm

• CCP A 1441 ppm minus 1 day

• CCP B 1439 ppm minus 1 day

• Shutdown Banks at 228 steps all other control rods at 0

• AEPS is OOS for breaker repair on PB0501 (Open PA50103 and place WPA on PBXY0001 interface)

=======SCENARIO PRELOADS / SETUP ITEMS==========

AEPS is OOS for breaker repair on PB0501 B ESW Pump Trip: (Event 5)

• Insert Malfunction (EF) PEF01B, Value = Trip, Condition = HWX19O241R eq 1 A EDG Fails to Start / A ESW pump fails to AUTO start (Event 6)

• Insert Malfunction (NE) NE01, Value = Fail

• Insert Malfunction (EF) PEF01A_1 B lock

======= EVENT 1 ============================

NE02 Starting Air Receiver air pressure low

• Panel SA 066X Insert 21E as RED HWXST1E21A, Value=1

======= EVENT 2 ============================

Source Range Channel Failure

• Insert Malfunction (SE) SEN0031_1, Value = 10000

=======EVENT 3 ============================

Controlling Steam Dump Valves fail open

• Insert Malfunctions (AB) ABPT507A, Value = 1500, Ramp = 5 min

=======EVENT 4 ============================

Loss of Offsite Power

• Insert steps from Loss of Switchyard lesson.

=======EVENT 5 PRELOADED =================

B ESW Pump Trip / Loss of All AC Power

• SEE PRELOADS ABOVE

=======EVENT 6 PRELOADED=================

A EDG Fails to Start / A ESW pump fails to AUTO start

• SEE PRELOADS ABOVE

=======EVENT 7 PRELOADED===============

Pressurizer PORV Fails Open:

• Insert ME Schematic (BB) m22bb02_a, RT04RC_PCV455A_ATVFAILSP, Value = .30

• Delete ME Schematic (BB) m22bb02_a, RT04RC_PCV455A_ATVFAILSP, Value = .30, Condition =

X21I149C eq 1 Page 5 of 19

Scenario Simulator Lesson Plan Callaway 2016-1 NRC Scenario #4, rev. 1 Page 6 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 1 Page 7 of 19 Event

Description:

NE01 Starting Air Receiver air pressure low (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 1 (NE01 Starting Air Receiver air pressure low) o RED HWXST1E21A, Value=1 o ANNUN_D020, value = ON

• When contacted, wait 3 minutes and respond as the Secondary OT reports a scaffold builder accidently bumped open two valves and lowered the air pressure on both of the A EDG air receivers and both of the A EDG starting air receivers are at 300 psig.

• If directed or asked, report the valves can be shut and restore A EDG starting air o Wait 3 minutes and delete the items in event 1 RED HWXST1E21A, Value=1 ANNUN_D020, value = ON o Report that the valve is closed and air has been restored Indications Available ANN 20D, Diesel Generator NE01 Trouble OTA-RK-00016, Add 20D Diesel Generator NE01 Trouble CRS Implement OTA-RK-00016, Add 20D Diesel Generator NE01 Trouble OTA-RK- (Step 3.1) DISPATCH an Operator to Panel KJ-121, PNL CONT D/G RO 00016 NE01, to determine local alarm.

Reviews Technical specifications

• 3.8.3 Cond E CRS o Restore two starting air receivers with pressure 435 psig within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> NOTE At Lead Examiners discretion move to the next Event Page 7 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 2 Page 8 of 19 Event

Description:

Source Range Channel Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 2 (Source Range Channel Failure) o Malfunction (SE) SEN0031_1, Value = 10000

• When contacted as I&C to place the Normal/Test switch on module NM107 of SR Channel 31 Drawer in TEST, wait 3 minutes and:

o Insert Event 2A o Call the CR and report The Normal/Test switch on module NM107 of SR Channel 31 Drawer is in TEST

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

• If contacted and asked if anyone is in containment answer No one is in containment Indications Available N31 fails to 10K CPS 57A SR Flux Doubled 65A SR HI Flux at S/D OTO-SE-00001, Nuclear Instrumentation Failure CRS Implement OTO-SE-00001, Nuclear Instrumentation Failure OTO-SE-RO (Step 1) Check Power Range Nuclear Instruments - Normal 00001 RO (Step 2) Check Intermediate Range Nuclear Instruments - Normal (Step 3) Check Source Range Nuclear Instruments - Normal - NO RO RNO - Go To Attachment C, Source Range Instrument Malfunction ATTACHMENT C, SOURCE RANGE INSTRUMENT MALFUNCTION (Step C1) CHECK Reactor Power - Greater than P NO RO RNO - Go To Step C5 RO (Step C5) CHECK High Flux at Shutdown Alarm - IN ALARM Page 8 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 2 Page 9 of 19 Event

Description:

Source Range Channel Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior (Step C6) CHECK Plant Personnel - INSIDE CONTAINMENT - NO RO RNO - Go to Step C9 (Step C9) Check Plant Status Meets One of the Following:

CRS

• MODE 3 OTO-SE-RO (Step C10) CHECK One Source Range Indication - OPERABLE 00001 RO (Step C11) Suspend Operations Involving Positive Reactivity Additions (Step C12) Check Rod Control System CAPABLE OF ROD CRS WITHDRAWAL CRS (Step C13) Restore Inoperable SR Channel within 48 Hours (Step C14) Check Plant in MODE 6 - NO CRS RNO - Go to Step C17 RO (Step C17) Check ANN 57A, SR Flux Doubled - LIT Page 9 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 2 Page 10 of 19 Event

Description:

Source Range Channel Failure (Tech Spec)

Proc /Time Position Applicants Actions or Behavior (Step C18) Check ANN 57A, SR Flux Doubled - EXTINGUISHED - NO RNO RESTORE charging lineup:

a. On module NM107 of the affected SR Drawer, DIRECT I&C to place the Normal/Test switch, in TEST.

b. PRESS BLOCK on the SR Doubled Block/Reset pushbuttons:

• SE HS-11

• SE HS-12

c. PRESS RESET on both SR Flux Doubling Block/Reset RO pushbuttons:

• SE HS-11

• SE HS-12

d. ENSURE SR FLUX DBL BLOC on SB069 is EXTINGUISHED.

e. OPEN VCT Outlet Valves:

• BG HIS-112B and BG HIS-112C

f. CLOSE CCP Suction From RWST Valves:

• BN HIS-112D and BN HIS-112E

g. UPDATE Status Board for current Boron concentration in charging pumps.

RO (Step C19) SELECT An Operable Channel On NIS Recorder - SE NR-45 CRS (Step C20) PLACE Inoperable Source Range Channel in the EOSL (Step C21) REVIEW Applicable Technical Specifications: Attachment I

• 3.3.1 Cond A:

• 3.3.1 Cond K:

Restore channel to Operable status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> OR CRS Initiate actions to fully insert all rods within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> AND Place the Rod Control System in a condition incapable of rod withdrawal within 49 hours5.671296e-4 days <br />0.0136 hours <br />8.101852e-5 weeks <br />1.86445e-5 months <br />

• 3.3.9 Cond A NOTE At Lead Examiners discretion move to the next Event Page 10 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 3 Page 11 of 19 Event

Description:

Steam Dump Valves fail open Proc /Time Position Applicants Actions or Behavior Booth Operator:

• Insert Event 3 (Controlling Steam Dump Valves fail open) o Malfunctions (AB) ABPT507A, Value = 1500, Ramp = 5 min

• When contacted, respond as DUTY MANAGER. Acknowledge entry into the OTO.

Indications Available ANN 65D, Tref/Tauct HI Steam Dump Valve Position - Open (AB-ZI-34, 35, and 36)

ANN 108-111C SG A-D Level Deviation Pressurizer level decreases due to RCS cooldown Letdown may isolate on low Pressurizer level.

OTO-AB-00001, STEAM DUMP MALFUNCTION OTO-AB-RO (Step 1) CHECK Reactor Power - LESS THAN 100%

00001 (Step 2) CHECK At Least One SG ASD - FAILED OPEN- NO BOP RNO - Go to Step 6 BOP (Step 6) CHECK Steam Header Pressure Channel Failed (Step 7) CHECK Steam Dump Control IN STEAM PRESSURE MODE BOP

• AB US500Z (Step 8) PLACE Steam Header Pressure Controller IN MANUAL BOP

• AB PK507 BOP (Step 9) CHECK Steam Dump Responding in MANUAL (Step 10) MANUALLY Control Steam Generator Pressure At Desired BOP Value Page 11 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 3 Page 12 of 19 Event

Description:

Steam Dump Valves fail open Proc /Time Position Applicants Actions or Behavior OTO-AB-BOP (Step 11) Go To Step 17 00001 CRS (Step 17) INITIATE Actions to Repair the Failed Component.

(Step 18) REVIEW Technical Specification 3.7.4.

CRS NOT applicable for the failure CRS (Step 19) PLACE Inoperable Component In the EOSL.

(Step 20) RECORD Any Locked Valve Manipulations in the Locked Valve CRS Deviation Log Per ODP-ZZ-00004, Locked Component Control.

(Step 21) PERFORM Notifications Per ODP-ZZ-00001 Addendum 13, CRS Shift Manager Communications to Emergency Duty Officer.

NOTE At Lead Examiners discretion move to the next Event Page 12 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 13 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior Booth Operator

• Insert Event 4 (Loss of Off Site Power) o Loss of Switchyard steps.

• The following PRELOADS are activated:

o Event 5 (B ESW Pump Trip / Loss of All AC Power) o (EF) PEF01B, Value = Trip, Condition = HWX19O241R eq 1 o Event 6 (A EDG Fails to Start) o (NE) NE01, Value = Fail

• 10 minutes after the loss of off site power OR when directed to secure B EDG (whichever occurs first) o Acknowledge request o Wait 3 minutes and Insert Local Secure B EDG step of simulator lesson (KJ) KJHS0109, value = Local_Manual (KJ) KJHS0108B, value = Stop, delay = 5 secs o Report to control room that the B EDG is stopped

• Insert Event 7 upon securing Power to NB02 initiating loss of All AC Power. (Pressurizer PORV Fails Open) o ME Schematic (BB) m22bb02_a, RT04RC_PCV455A_ATVFAILSP, Value = .30 o ME Schematic (BB) m22bb02_a, RT04RC_PCV455A_ATVFAILSP, Value = .30, Condition = X21I149C eq 1

• If crew dispatches and OT to manually start A EDG early (i.e. as soon as it is determined not to have started) do not start A EDG until step 6 of ECA-0.0; if OT is sent after step 6 of ECA-0.0 wait 3 minutes to start A EDG o Trigger simulator lesson step Local Start A EDG EOP ADD 21 (AFTER step 7 of ECA-0.0)

• Acknowledge as Power Supervisor. A fault has occurred at the Montgomery substation causing a widespread power outage. Repair crews have been dispatched

• Respond as the Secondary OT and go to panel KJ-121. Report that Annunciator 6A, Diesel Start Failure, is in alarm. Request assistance from maintenance troubleshoot in an attempt to clear the alarm.

• Respond as an OT if directed to investigate the B ESW pump that the motor is hot to the touch Page 13 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 14 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior Indications Available 15BD PA01/02 BUS UV Multiple FIRST OUT Annunciators E-0, Reactor Trip or Safety Injection CRS Implement E-0, Reactor Trip or Safety Injection E-0 (Step 1) Check Reactor Trip

• Rod Bottom Lights - All Lit RO

• Reactor Trip and Bypass Breakers - Open - NO

• Neutron Flux - Lowering RNO: Manually Trip Reactor.

(Step 2) Check Turbine Trip BOP

a. All Turbine Stop Valves - Closed (Step 3) Check Power to AC Emergency Buses

a. AC emergency buses - At Least One Energized BOP

• NB02 Energized from EDG NE02

b. AC emergency buses - BOTH Energized - NO RNO - TRY to restore power - Try to start NE01 using KJ HS-8A (Step 4) Check SI Status

a. Check if SI is actuated RO RNO - Check if SI is Required If SI is NOT required, GO TO ES-0.1, Reactor Trip Response, Step 1.

ES-0.1, Reactor Trip Response CRS Implement ES-0.1, Reactor Trip Response CRS Implement CSF Status Tree Monitoring per CSF-1 Page 14 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 15 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior ES-0.1 (Step 1) Check RCS Temperature

a. Any RCP running -NO BOP RNO: Transfer Condenser Steam Dump to Steam Pressure Mode.

b. Check RCS temperature response - Normal ES-0.1 (Step 8) Check Status of AC Buses

a. Check Generator Output Breakers - Open

b. Check All AC Buses - Energized by Offsite Power RNO:

• Ensure PZR PORVs in AUTO RO

• Ensure PORV Block Valves Open (no power to A PORV block valve)

• Ensure DGs have assumed loads:

o CCP, ESW, CCW, Ctmt Cooler Fans, MDAFP, CR AC Units, Class 1E AC Units

• If any DG running with NO cooling, STOP affected DG ECA-0.0, Loss of All AC Power CRS Transition to ECA-0.0, Loss of All AC Power ECA-0.0 (Step 1) Check Reactor Trip RO a. Reactor Trip and Bypass Breakers - OPEN\

b. Neutron Flux - Lowering (Step 2) Check Turbine Trip RO

a. Turbine Stop Valves - Closed (Step 3) Check if RCS is Isolated

a. Letdown Isolation Valves - CLOSED

b. PZR PORVs - CLOSED BOP RNO: If PZR pressure is < 2335 psig THEN CLOSE PORVs

c. RCS to Excess Letdown HX Valves - CLOSED

d. Reactor Head Vents - CLOSED Page 15 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 16 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior Critical BOP Manually close the Open PORV before completing Step 3 of ECA-0.0 Task CRS (Step 4) Check AFW Flow > 285,000 lbm/hr ECA-0.0 (Step 5) Try to Restore Power to any Emergency Bus

• Energize with DG o Check both DGs running o RNO - Manually Start o Check at least one bus energized CRS o RNO Stop affected DG o Try any available supply - EOP Add 7

• Check AC emergency buses - One energized o RNO - OPEN CR cabinet doors - EOP Add 20 o GO TO Step 6 (Step 6) Place the Following Equipment Switches in PTL

• CCPs

• SI Pumps

• RHR Pumps

• Containment Spray Pumps RO

• CCW Pumps

• Containment Cooler Fans

• Motor Driven AFW Pumps

• Control Room AC Units

• Class 1E Electrical Eq Room AC Units (Step 7) Restore AC Power

a. Check if Offsite is available - NO RNO - Perform the following while continuing with step 8 BOP 1. EOP Add 21 Local EDG start

2. Consult Power Supervisor and TD. If offsite power source not available, restore power using EOP Addendum 39, Alternate Emergency Power Supply. (AEPS NOT available)

CRS (Step 8) Locally Isolate RCP Seals - EOP Add 22 Page 16 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 17 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior (Step 9) Check if CST is Isolated from Hotwell Place AD LIC-79A in manual with zero output BOP Place AD LIC-79B in manual with zero output Locally close APV0012 ECA-0.0 (Step 10) Check SG Status

a. MSIVs and Bypass valves closed

b. MFRVs Closed BOP

c. MFRV bypass valves closed

d. FWIVs closed

e. SG Blowdown isolation valves closed (Step 11) Check if Any SG is Faulted

• Any pressure lowering uncontrollably - or -

BOP

• Any SG completely depressurized RNO Go To Step 12 (Step 12) Check if SG Tubes are intact

a. Steamline Radiation Normal BOP b. Cond Air Removal radiation normal before isolation

c. SG Blowdown and Sample rad normal before isolation

d. No SG Levels rising uncontrollably (Step 13) Check Intact SG Levels BOP a. Narrow Range > 7% (25%)

b. Control AFW flow between 7% (25%) and 52%

(Step 14) Check DC Bus Loads

a. Monitor 125 vdc Class 1E Buses BOP

b. Consult Plant Engineering to evaluate shedding loads

c. Locally Check Security DG - RUNNING (Step 15) Check CST to AFP Suction Header Pressure Greater than 2.75 BOP psig Page 17 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 18 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior ECA-0.0 (Step 16) Monitor RCS Integrity

a. Monitor RCS Inventory:

• Check RCS subcooling - Greater than 30F[50F]

RO

• PZR level - Greater than 9% [29%]

b. Check time elapsed since loss of RCP seal cooling - Less than 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

c. Go to Step 19 (Step 19) Check SI Signal Status:

a. SI Has Been Actuated - NO RO RNO: When SI is actuated Then Perform Steps 19.b, 20, 21, 22.

Continue With Step 23.

RO (Step 23) Check Core Exit TCs - Less than 1200F (Step 24) Check if AC Emergency Power Is Restored:

BOP

a. Check AC Emergency Buses - At least ONE Energized.

(Step 25) Stabilize SG Pressures BOP

a. Manually Control SG ASDs to maintain existing Pressure (Step 26) Check Following Equipment Loaded on Energized Bus

• 480 Busses NG01 and NG03 BOP

• Battery Chargers NK21 and NK23

• Instrument Busses NN01 and NN03

• CR Emergency Lighting NK51-20 (Step 27) Check ESW System Operation

• EF HIS-37, 51, 31, 33, 45 and 49 Open BOP

• EF HIS-41, 23 and 59 Closed

• ESW Pump A Running Page 18 of 19

Appendix D Operator Action Form ES-D-2 Op Test No.: 2016-1 Scenario # 4 rev.1 Event # 4, 5, 6, 7 Page 19 of 19 Event

Description:

Loss of Offsite Power / B ESW Pump Trip / Loss of All AC Power / B ESW Pump Trip / Loss of All AC Power / PZR PORV PCV-455 Fails Open with Manual Control Available Proc /Time Position Applicants Actions or Behavior Critical Manually start A ESW pump prior to A EDG tripping on high BOP Task temperature.

ECA-0.0 (Step 28) Select Recovery Procedure

a. Check RCS Subcooling > 30 °F (50°F)

b. Check PZR level > 9% (29%)

CRS

c. Check if ECCS equipment actuated YES - ECA-0.1 RNO - ECA-0.2 NOTE The scenario can be terminated at the discretion of the Lead Examiner Page 19 of 19

ES-301 Transient and Event Checklist Form ES-301-5 Rev 3 Facility: Callaway Date of Exam: 05/23/2016 Operating Test No.: 2016-1 Team 1 SRO-I: S1, S2, S3, A E Scenarios P V 4 3 2 T M P E O I L N T N CREW POSITION CREW POSITION CREW POSITION I T A I C S1 S2 S3 S2 S3 S1 S3 S1 S2 L M A T U N Y M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 2 1 1 SRO-I NOR 1 1 1 S1 I/C 2,3,4 2,4 3,5 7 4 MAJ 5 6 6 3 2 TS 1,2 2 2 RX 3 1 1 SRO-I NOR 1 1 1 S2 I/C 2,3 1,2,4 2,4 7 4 MAJ 4 5 6 3 2 TS 1,4 2 2 RX 3 1 1 SRO-I NOR 1 1 S3 I/C 2,3,4, 8 4 3,4 1,4 5

MAJ 5 5 6 3 2 TS 2,3 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.

Page 1 of 4

ES-301 Transient and Event Checklist Form ES-301-5 Rev 3 Facility: Callaway Date of Exam: 05/23/2016 Operating Test No.: 2016-1 Team 2 SRO-I: S6, S7 / RO: R1 A E Scenarios P V 4 3 2 T M P E O I L N T N CREW POSITION CREW POSITION CREW POSITION I T A I C S6 S7 R1 S7 R1 S6 S7 S6 R1 L M A T U N Y M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 2 1 1 SRO-I NOR 1 1 1 S6 I/C 2,3,4 2,4 3,5 7 4 MAJ 5 6 6 3 2 TS 1,2 2 2 RX 3 1 1 SRO-I NOR 0* 1 S7 I/C 2,3,4, 2,3 1,2,4 9 4 5

MAJ 4 5 6 3 2 TS 1,4 2,3 4 2 RX 3 1 1 RO NOR 1 1 1 R1 I/C 3,4 1,4 2,4 6 4 MAJ 5 5 6 3 2 TS Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 2 of 4

ES-301 Transient and Event Checklist Form ES-301-5 Rev 3 Facility: Callaway Date of Exam: 05/23/2016 Operating Test No.: 2016-1 Team 2 SRO-I: S4, S5 A E Scenarios P V 4 3 T M P E O I L N T N CREW POSITION CREW POSITION CREW POSITION I T A I C S4 S5 Surro S5 S4 Surr L M A T gate ogat U N Y e M(*)

T P S A B S A B S A B R I U E R T O R T O R T O O C P O C P O C P RX 3 1 1 SRO-I NOR 1 0* 1 S4 I/C 2,3,4 1,4 5 4 MAJ 5 5 2 2 TS 1,2 2 2 RX 3 1 1 SRO-I NOR 0* 1 S5 I/C 2,3 1,2,4 5 4 MAJ 4 5 2 2 TS 1,4 2 2 RX NOR I/C MAJ TS Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 3 of 4

ES-301 Transient and Event Checklist Form ES-301-5 Rev 3 Facility: Callaway Date of Exam: 05/23/2014 Operating Test No.: 2016-1 A E Scenarios P V 1 T M P E O I L N T N CREW CREW CREW CREW I T POSITION POSITION POSITION POSITION A I C L M A T U N Y M(*)

T P S A B S A B S A B S A B R I U E R T O R T O R T O R T O O C P O C P O C P O C P RX 5 5 NOR 1 SPARE I/C 2,3 2,5 3,4

,4 MAJ 6 6 6 TS 2,3 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions; Instant SROs must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an Instant SRO additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a 1-for-1 basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

Page 4 of 4

ES-301 Competencies Checklist Form ES-301-6 Rev 2 Facility: Callaway Date of Examination: 5/23/16 Operating Test No.: 2016-1 APPLICANTS RO RO SRO-I SRO-I SRO-U SRO-U Competencie SCENARIO SCENARIO s

1 2 3 4 1 2 3 4 Interpret/Diag 2,3,4,5,6, 2,3,4,5,6, 1,2,3,4,5, 2,3,4,5,6, 2,3,4,5,6, 2,3,4,5,6, 1,2,3,4,5, 2,3,4,5,6, nose Events 7 7 6 7 7 7 6 7 and Conditions Comply With 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 2,3,5,6,7 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 2,3,5,6,7 and 6,7 6,7 6, 6,7 6,7 6 Use Procedures (1)

Operate 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 2,3,4,5,6, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 2,3,4,5,6, Control 6,7 6,7 6, 7 6,7 6,7 6 7 Boards (2)

Communicate 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, and Interact 6,7 6,7 6 6,7 6,7 6,7 6 6,7 Demonstrate 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, 1,2,3,4,5, Supervisory 6,7 6,7 6 6,7 Ability (3)

Comply With 2,3 2,3 1,4 1,2 and Use Tech.

Specs. (3)

Notes:

(1) Includes Technical Specification compliance for an RO.

(2) Optional for an SRO-U.

(3) Only applicable to SROs.

Instructions:

Check the applicants license type and enter one or more event numbers that will allow the examiners to evaluate every applicable competency for every applicant. (This includes all rating factors for each competency.) (Competency Rating factors as described on forms ES-303-1 and ES-303-3.)