Text

Nine Mile Point, Unit 1 - Final Operating Exam (Sections a, B, and C) (Folder 3)
	ML103500290
Person / Time
Site:	Nine Mile Point
Issue date:	10/27/2010
From:	Fish T H; Operations Branch I
To:	Dean R J; Constellation Energy Nuclear Group
	Hansell S
Shared Package
ML101900588	List: IR 05000220/2010301; ML103050559; ML103090325; ML103090350; ML103090375; ML103500252; ML103500258; ML103500278; ML103500290; ML110110530;
References
	TAC U01797
	Download: ML103500290 (220)
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NRC JPM RO Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Perform Nl-ST-DO DAILY CHECKS (Partial)

Revision:

NRC 20 I 0 Task Number: N/A Approvals:

NIA -Exam Security I General Supervisor I General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

_________________(RO/SRO) Trainer/Evaluator:

Evaluation Method: __ Perform _______ Simulate Evaluation Location:

____ Plant __--"-"--__ Simulator Expected Completion Time: 20 minutes Time Critical Task: No Alternate Path Task: No Start Time: _____ Stop Completion Time: _______ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as faiL Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator Signature:

_______________________

_ Date:_______ NRC 2010 JPM RO COOl November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up: 1. Initialize Simulator to IC-160 2. Verify the following overrides are set: a. 5M80A03SS0

== 73.00 b. 5M81A03560

== 7S.00 c. 5Ml18A03860

= 76.00 d. SM116A03840 68.00 e. SARI TS IA031 000 = 68.00 f. 13MIA042680

== 69.00 g. 9MS3AOS1270

= 70.S0 3. Take the simulator to Run, and then back to Freeze 4. Verify average Drywell temperature is less than 130°F S. Verify total Recirc flow is 38 Mlbmlhr 6. Verify FWLC is selected to column 11 7. Turn off PI monitor Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM / CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM Performance:

This evaluated JPM is a measure of your ability to perform this task independently.

The Control Room Supervisor has determined that a verifier is not available and that additional/concurrent verification will not be provided; therefore, it should not be requested.

Read Before Each Training JPM Performance:

During this Training JPM, the use of applicable methods of verification and checking are Therefore, either another individual or I will act as the independent verifier or peer Notes to Instructor

/ Evaluator:

NRC 2010 JPM RO COOl November 2010 Critical steps are identified in grading areas PasslFail.

All steps are sequenced critical unless denoted by a During Evaluated JPM: Self checking shall be demonstrated. During Training JPM: Self checking shall be demonstrated.

Peer checking shall be NUREG 1123,2.1.18, RO 2.9 Nl-ST-DO Tools and Equipment:

None Task Standard:

Control room RPV water level readings are taken for Nl-ST-DO. Out of spec readings are identified to SRO and inoperable equipment is identified by the candidate.

Initial Conditions: The plant is operating at approximately 67% power. Nl-ST-DO, Daily Checks, is in progress. The provided printout shall be used to determine computer point and PI data. Instructor to ask the operator for any questions.

Initiating cue: "(Operator's name), obtain the instrument readings needed from control room panels to complete Nl-ST-DO Attachment 4 sections 5.0 and 6.0 only, then complete section 8.4 in the body of the procedure.

When completed, report findings and provide completed sections to SRO." I Performance I Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatfUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat back providing correction if necessary RECORDSTARTTIME

_______ Obtain a copy of the reference procedure N-ST-DO obtained, sections 5.0 and 6.0 SatfUnsat and review/utilize the correct section referenced Completed N1-ST-DO is attached JPM key. Small differences in values may occur due to NRC 2010 JPM RO COOl -3 November 2010 I Performance Steps Records section 5.0 readings Compare Recirc Pump Inlet readings and determines readings Record section 6.0 readings Cue: Another operator has completed required Independent Record Total Recirc Flow Determines average Drywell temperature Since Yarway level indicator deviation is less than 4 inches, Drywell temperature reading is not necessary for task completion. Analyzes Yarway level indicator deviation This may be evidenced by the lack of a report to the contrary. Analyzes GEMAC level indicator deviation

10. Determines GEMAC level indicators are inoperable Provides completed sections to SRO and informs of out of spec readings I Standard Records Reactor Recire Pump Temperature readings on Attachment Section Compares readings and determines readings within 15°F of each other Checks YES block in Section 5.0, indicating the maximum difference in loop temperatures is < 15°F Records RPV water level readings Attachment 4 section Records total recirc flow in the correct box on Attachment 4 section 6.0 Observes average Drywell temperature is less than 125°F Determines Yarway level indicator deviation is less than the 6 inch limit Determines GEMAC level indicator deviation is greater than the 6 inch limit Checks INOP option in step 8.4 Proper communications used (GAP-OPS-Ol)

Grade SatlUnsat SatlUnsat PasslFail SatlUnsat PasslFaii PasslFail PasslFaii SatlUnsat TERMINATING CUE: Control room readings are taken. Out of spec readings are identified to SRO and inoperable equipment is identified by the candidate.

RECORDSTOPTlME

_________ NRC 2010 JPM RO COOl November 2010 Initial Conditions:

1. The plant is operating at approximately 67% power. 2. Nl-ST-DO, Daily Checks, is in progress.

3. The provided printout shall be used to determine computer point and PI data. Initiating cue: "(Operator'S name), obtain the instrument readings needed from control room panels to complete Nl-ST-DO Attachment 4 sections 5.0 and 6.0 only, then complete section 8.4 in the body of the procedure.

When completed, report findings and provide completed sections to SRO." NRC 2010 JPM RO COOl November 2010 NRC JPM RO Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: DWFDT I DWEDT Leak Rate Detennination and Evaluation Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Perfonner:

_______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: _-"X-"'--__ Perfonn ______ Simulate Evaluation Location:

____Plant __--"'-"'--__ Simulator or Classroom Expected Completion Time: 10 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:______NRC 2010 RO ADMIN JPM C002 November Recommended Start Location: (Completion time based on the start location)

Classroom Simulator Set-up (if required):

N/A Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipUlated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading areas PasslFail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

References:

1. NUREG 1123,2.1.7, RO 4.4 2. NI-0P-8; Attachment 6 3. Unit 1 Technical Specifications, Section 3.2.5 Tools and Equipment

1. Calculator NRC 2010 RO ADMIN JPM C002 November 2010 Task Determine DWFDT, DWEDT, and total leak rates and recognize Technical Specification limits are being exceeded.

Initial Conditions: The plant is operating at 100% power. The Drywell Leak Detection System is out of service. The following information is available for the Drywell Floor Drain Tank (DWFDT): Leak rate has been constant at 0.92 gpm for the past week. Previous pump down at 21:00 today. Most recent pump down at 21 :25 today. Pump down volume = 140 gallons. The following information is available for the Drywell Equipment Drain Tank (DWEDT): Leak rate has been constant at 0.50 gpm for the past week. Previous pump down at 12:00 today. Most recent pump down at 22:00 today. Pump down volume =430 gallons. Technical Specification (TS) limits are: 5 gpm unidentified leakage. 2 gpm increase in unidentified leakage within any period of24 hours or less. 25 gpm total leakage averaged over any 24-hour period. Instructor to ask the operator for any questions.

Initiating cue: "(Operator's name), determine DWFDT, DWEDT, and total leak rates and determine if they are within the Technical Specification limits or not. Record your findings on the attached worksheet." Performance Steps Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat providing correction if RECORD START TIME ____ Obtain a copy of the reference procedure and Nl-OP-8, Attachment 6 obtained as necessary SatlUnsati review/utilize the correct section NA 3. Determines DWFDTleak (140 gallons/25 minutes) =5.6 gpm PasslFail Evaluates DWFDTleak rate Identifies DWFDT (unidentified leakage) rate PasslFaii is ABOVE the limit (5 gpm) Identifies DWFDT (unidentified leakage) rate PasslFail is ABOVE the limit for increase in a 24-hour period (2gpm) (5.6 gpm -0.92 gpm) =4.68 gpm increase (plus or minus 0.02 gpm) NRC 2010 RO ADMIN JPM C002 November 2010 Performance Steps Standard Grade 5. Determines D WEDT leak rate 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months = 600 minutes PasslFail (430 gallons/600 minutes) = 0.72 gpm (plus or minus 0.02 gpm) 6. Evaluates TOTAL leak rate Determines total leak rate is 6.32 gpm (plus or PasslFail minus 0.04 gpm) (0.72 gpm + 5.6 gpm =6.32 gpm) Note: This may be evidenced by lack of a report Determines total leak rate is within the limit PasslFail to the contrary.

(25 gpm) Terminating DWFDT, DWEDT, and total leak rates are determined and evaluated against Technical Specification criteria.

RECORD STOP TIME ____ NRC 20lO RO ADMIN JPM C002 November 2010 Initial Conditions: The plant is operating at 100% power. The Drywell Leak Detection System is out of service. 3. The following information is available for the Drywell Floor Drain Tank (DWFDT): Leak rate has been constant at 0.92 gpm for the past week. Previous pump down at 21:00 today. Most recent pump down at 21 :25 today. Pump down volume = 140 gallons. The following information is available for the Drywell Equipment Drain Tank (DWEDT): Leak rate has been constant at 0.50 gpm for the past week. Previous pump down at 12:00 today. Most recent pump down at 22:00 today. Pump down volume = 430 gallons. Technical Specification (TS) limits are: 5 gpm unidentified leakage. 2 gpm increase in unidentified leakage within any period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or less. 25 gpm total leakage averaged over any 24-hour period. Initiating cue: "(Operator's name), determine DWFDT, DWEDT, and total leak rates and determine if they are within the Technical Specification limits or not. Record your findings on the attached worksheet." NRC 2010 RO ADMIN JPM November 2010 i i Candidate Worksheet Within Technical Calculated Leak Rate Value Specification Limit? (gpm) DWFDT Leak Rate DWEDT Leak Rate Total Leak Rate NRC 2010 RO ADMIN JPM C002 November 2010 NRCJPM RO EC Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Prepare a tagout for RBCLC pump 13 Revision:

NRC 2010 Task Number: N/A Approvals:

General Supervisor NIA -Exam Security General Supervisor I Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:,______________

(.RO/SRO)

TrainerlEvaluator:,____________

_ Evaluation Method: _---'X'-"--

__ Perform ______ Simulate Evaluation Location:

____ Plant __

__ Simulator or Classroom Expected Completion Time: 40 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time:,_____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:______NRC 2010 RO ADMIN JPM EC November Recommended Start Location: (Completion time based on the start location)

Classroom Simulator Set-up (if required):

N/A Directions to the InstructorlEvaluator:

Prior to performance ofthis JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

I. Critical steps are identified in grading areas Pass/Fail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

References:

1. NUREG 1123,2.2.13, RO 4.1 2. CNG-OP-l.Ol-1007

3. P&ID C-18022-C sheet 2 4. EWDs C-19436-C sheets 1 and 3 5. NI-OP-II NRC 2010 RO ADMIN JPM EC November 2010 Tools and Equipment:

None Task Standard:

Identify the components required be tagged to tagout RBCLC pump 13for a shaft seal replacement.

Initial Conditions: The plant is operating at 100% power. RBCLC pumps 11 and 12 are operating. RBCLC pump 13 is secured. Maintenance is required to replace RBCLC pump 13 shaft seal. eSOMs is unavailable. Ask the operator for any questions.

Initiating cue: "(Operator's name), identify the components required to be tagged to tagout RBCLC pump 13 for the shaft seal replacement.

Record the required components and their tagged positions using CNG-OP-1.0I-l 007 attachment 8." Performance Steps Provides repeat back of initiating cue Evaluator acknowledge repeat providing correction if RECORD START TIME ____ Obtains a copy of the reference procedure and reviews/utilizes the correct section Obtains and references appropriate drawings and/or procedures to determine isolations Records required isolations.

Note: Due to unavailability of eSOMs and other electronic databases, exact component IDs, names, and tagging positions may vary.

Grade Proper communications used for repeat back SatiUnsat (GAP-OPS-Ol) eNG-OP-I.O 1-1 007 obtained as necessary SatlUnsatl NA Obtains and references, as required:

SatlUnsat P&ID C-18022-C sheet 2 EWDs C-19436-C sheets 1 and 3 NI-OP-ll Identifies the following isolations on OP-l.Ol-I007 attachment 8: 70-03, Reactor Building Closed Loop Cooling SatlUnsat Pump 13, Control Switch in pull-to-Iock 70-03, Reactor Building Closed Loop Cooling SatlUnsat Pump 13, Motor Breaker Trip Fuses pulled or installed in OFF NRC 2010 RO ADMIN JPM EC -3 November 2010 Performance Steps Grade 70-03, Reactor Building Closed Loop Cooling Pump l3, Motor Breaker Close Fuses pulled or installed in OFF SatlUnsat 70-03, Reactor Building Closed Loop Cooling Pump 13, Motor Breaker racked out or disconnected PasslFail 70-09, BV -13 RBCLC Pump Discharge, closed PasslFaii 70-141, BV closed 13 RBCLC Pump Suction, PasslFail 70-500, Drain 13 RBCLC Pump, open SatlUnsat 70-501, Vent uncapped 13 RBCLC Pump, open and SatiUnsat Terminating Isolations for RBCLC pump l3 have been identified and recorded on 1007 attachment

8. RECORD STOP TIME ____ NRC 2010 RO ADMIN JPM EC November 2010 Initial Conditions:

1. The plant is operating at 100% power. 2. RBCLC pumps 11 and 12 are operating.

3. RBCLC pump 13 is secured. 4. Maintenance is required to replace RBCLC pump 13 shaft seal. 5. eSOMs is unavailable.

Initiating cue: "(Operator's name), identify the components required to be tagged to tagout RBCLC pump 13 for the shaft seal replacement.

Record the required components and their tagged positions using CNG-OP-1.0I-1007 attachment 8." NRC 2010 RO ADMIN JPM EC November 2010 NRCJPM RO EP Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Perform Actions for External Security Threats Revision:

NRC 20 I 0 Task Number: N/A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date TrainerlEvaluator:

____________

_ Evaluation Method: _-"X=-__ Perform ______ Simulate Evaluation Location:

____Plant Simulator or Classroom Expected Completion Time: 15 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:______NRC 2010 RO ADMIN JPM EP November Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

N/A Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading areas PasslFaii.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

References:

1. NUREG 1123,2.4.28, RO 3.2 2. EPIP-EPP-IO Tools and Equipment:

None NRC 2010 RO ADMIN JPM EP November 2010 Task Standard:

Perform required actions for an external security threat per EPIP-EPP-10, Attachment

2. Initial Conditions: The plant is operating at 100% power. You are the CRO. The NRC calls on the ENS line and informs you of the following: NORAD has reported that two US Airways 737 aircraft have been hijacked from Hancock International Airport in Syracuse, New York. One is headed southeast in the direction of the Indian Point site and one is headed north in the direction of the Fitzpatrick and Nine Mile Point site. The event is classified as a credible, probable airborne threat. 4. Instructor to ask the operator for any questions.

Initiating cue: "(Operator's name), perform actions in response to this security threat in accordance with EPIP-EPP-l 0 attachment 2." Performance Steps Grade Provides repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat back providing correction if necessary RECORDSTARTTTIME

_______ Obtains a copy of the reference procedure EPIP-EPP-IO attachment 2 obtained SatlUnsat and reviews/utilizes the correct section Once the candidate locates EPIP-EPP-IO attachment 2, the examiner may supply an extra copy to the candidate for use during the remainder of the JPM 3. Notifies Shift Manager of security Proper communications used (GAP-OPS-Ol)

PasslFail Checks plant parameters Observes major plant parameters using SatlUnsat control room instrumentation (ex. Reactor power, pressure and level, Containment conditions)

5. Notifies Security Site Proper communications used (GAP-OPS-Ol)

PasslFail Security Site Supervisor may contacted by Gaitronics page or calling x5222 or NRC 2010 RO ADMIN JPM EP -3 November 2010 Performance Steps Initiates any Operating, Special Operating or EOPs required Inform that other operators are executing the required Operating, Special Operating and Emergency Operating Procedures As directed by Shift Manager, makes announcements As Shift Manager, provide EPIP-EPP-l 0 attachment 6, ImminentlProbable Aircraft Attack Announcement (JPM page 6) If candidate begins to broadcast announcement over speakers, examiner should direct the candidate to not broadcast over speakers and direct the announcement to the examiner only. When Security Contingency Event no longer exists, makes a termination announcement in accordance with EPIP-EPP-18 Cue: As Shift Manager, report that Security Contingency Event no longer exists and provide EPIP-EPP-18 attachment 7, Emergency Termination Announcement (JPM page 7) Note: If candidate begins to broadcast announcement over speakers, examiner should direct the candidate to not broadcast over speakers and direct the announcement to the examiner only_ Standard Proper communications used (GAP-OPS-Ol)

Makes plant announcement in accordance with EPIP-EPP-I 0 attachment 6: Places GAItronics in Merge Sounds Evacuation Alarm for 5 seconds Announces:

Attention All Plant Personnel, this (is a drill / is an actual emergency)

Aircraft Impact Imminent.

Evacuate the protected area immediately.

Report directly to the Learning Center or P-Building.

I repeat, this (is a drill / is an actual emergency) Repeats Alarm and Announcement Leaves GAItronics in merge Makes plant announcement in accordance with EPIP-EPP-18 attachment 7: Sounds Station Alarm for 10 seconds Announces:

Attention.

Attention all personneL The security event at Nine Mile Point Unit 1 and 2 has been terminated.

I repeat, the security event has been terminated

c. Repeats alarm and announcement

d. Removes GAItronics from merge Grade SatlUnsat Terminating Cue: Emergency Termination Announcement has been made. RECORD STOP TIME ____ NRC 2010 RO ADMIN JPM EP November 2010 Initial Conditions:

1. The plant is operating at 100% power. You are the CRO. 3. The NRC calls on the ENS line and informs you of the following: NORAD has reported that two US Airways 737 aircraft have been hijacked from Hancock International Airport in Syracuse, New York. One is headed southeast in the direction of the Indian Point site and one is headed north in the direction of the Fitzpatrick and Nine Mile Point site. The event is classified as a credible, probable airborne threat. Initiating cue: "(Operator's name), perform actions in response to this security threat in accordance with EPIP-EPP-IO attachment 2." When making plant announcements, simulate all actions with the GAItronics and provide announcement to the examiner only (i.e. do NOT broadcast over speakers).

NRC 2010 RO ADMIN JPM EP -5 November 2010 ATTACHMENT 6 Date: Today Tune: Now IMMINENT/PROBABLE AIRCRAFT ATTACK ANNOUNCEMENT Instructions:

Aircraft Impact imminent.

Evacuate Report directly to 1. Place GAltrooics in Merge 2. Sound Evacuation Alarm for 5 Seconds 3. Attention All Plant Personnei, this (is a driHan actual emerge, the Learning Center or I repeat this (is a drill

actual Repeat Alarm and Leave GAJtronics in merge for the duration of the Upon comptetion retum this attachment to the EP Page EPIP-EPP-10 Rev 17 NRC 2010 RO ADMIN JPM EP November 2010 ACTIVATION AND DIRECnON OF THE EMERGENCY EPiP-EPP*18 Revision 01900 Page 19 of 21 Page 1 of 1 Attad1ment 7, Emergency Tennination Date: 0 nme! Emergencev Termination (As requested by the SM/EO or Place GAltronk:s in Merge Sound Station Alarm for 10 Seconds Announce, I "AttentiOn.

Attention all The security Nine Mile )! Unit 1 has been Unit 2 has been (ProVide further instructions as necessary) J repeat. the ___s_e_c-u-r-i-t...:::y

_____

condition has been terminated. Repeat Alarm and Announcement Remove GAUronics from merge. Upon completion retum this attachment to the EP Dept. [N0306] NRC 2010 RO ADMIN JPM EP November 2010

NRC JPM SRO Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Determine Thermal Limits with Inoperable Pressure Regulator Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security General Supervisor Date General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security Configuration Control Date Performer:

_______________

Evaluation Method: _--"X-"----

__ Perform ________

Evaluation Location:

____ Plant ___

__ Simulator or other Expected Completion Time: 30 minutes Time Critical Task: No Alternate Path Task: No Start Time: Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluator Signature:

_______________

_ Date:________ NRC 2010 SRO ADMIN JPM COOl November 2010 Recommended Start Location: (Completion time based on the start location)

Classroom Simulator Set-up: NI A Directions to the Applicant is to be provided with Nl-RESP-l for recording data. Applicant must have access to Core Limits Report, Tech Specs, 3D Monicore printout data and Directions to Read Before Every JPM For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to direction to perform this task, I will provide you with the initial conditions and answer any questions. task performance, I will identify the steps to be simulated, or discuss and provide cues as With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning devices will be simulated by discussion and acknowledged by my Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will not provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, the use of applicable methods of verification and checking are expected.

either another individual or I will act as the independent verifier or peer Notes to Instructor I

1. Critical steps are identified in grading areas PassfFail.

2. During Evaluated JPM:

Self checking shall be demonstrated.

3. During Training JPM:

Self checking shall be demonstrated.

Peer checking shall be demonstrated.

References:

1. NUREG 1123,2.1.19, SRO 3.8 2. Core Operating Limits Report (COLR) 3. Nl-RESP-l Daily Thermal Limit Surveillance

4. Tech Spec 3.1.7 Tools and Equipment:

1. Calculator NRC 2010 SRO ADMIN JPM COO I November 2010 Task Standard:

Complete Nl-RESP-l, Daily Thennal Limit Surveillance.

Detennine and evaluate adjusted thennallimits with an inoperable pressure regulator.

Identify COLR MCPR limit is exceeded and Tech Spec 3.1.7 actions are required.

Initial Conditions: The plant is operating at power with 5 recirc loops in service. Feedwater Pump 13 is in operation. The plant is at Beginning of Cycle (BOC). Reactor Engineering reports the value of Tau is 1.0. Scoop Tube setting is 102.5%. Current core thennal power and flow are indicated on the given 3D Monicore printout. Core thennal power has not changed since the last 3D Monicore printout. The Mechanical Pressure Regulator is out of service for repairs. The MPR linkage is disconnected at the Front Standard.

10. Instructor to ask operator for any questions.

Initiating cue: "(Operator's name), using the 3D Monicore printout provided, complete Nl-RESP-l, Daily Thennal Limit Surveillance section 9.2, up to and including step 9.2.14. Report the results in the space below." Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-O

1) Evaluator acknowledge repeat back providing correction if necessary

________ Obtain a copy of the any of the reference Reference materials obtained SatlUnsat documents Record data in Nl-RESP-l by obtaining Records Core Thennal Power in step 9.2.2 as SatlUnsat infonnation from 3D Monicore printout 1591 MWth and 86.0% Records Total Core Flow in step 9.2.3 as SatlUnsat 48.023 Mlbmlhr and 71.1 % Records step 9.2.4 as NA, since all RRPs are SatlUnsat operating Records MAPRAT and location in step 9.2.5 SatlUnsat as 0.775 and 41-38-4 Records step 9.2.6 as NA, since all RRPs are SatlUnsat operating NRC 2010 SRO ADMIN JPM COOl November 2010 I Performance Steps i Determine "Adjusted MCPR limit" value for step 9.2.7, with pressure regulator out of service and thermal power between 45% and 90% from the COLR Uses COLR Figure 2a. 2e and 2f, determine calculation Determine "Actual MCPR Value" from 3D Monicore printout Determine COLR thermal limit restriction for MCPR is not met Role Candidate may make notifications regarding violated thermal limit. Acknowledge report, direct the Candidate to identifY the required action and then complete the rest of the surveillance.

e7. Enter Tech Spec 3.1.7.c I Standard Determines adjusted value to be 1.797, from COLR Section 2.1 and Figures 2a, 2e, and 2f, as follows: For 70% :::; P < 90% MCPR Limit = (Rated OLMCPR)IFRTP Rated OLMCPR= MCPRlim*Kf 1.52*1.017

= 1.545 (1.535-1.581 acceptable)

MCPRLimit 1.545/.860

= (1.785-1.838 Enters 1.797 (1.785-1.83 8

as "Adjusted MCPR limit" value for 9.2.7 Determines actual MCPR value to be 1.708, from printout Enters 1.708 as "Actual MCPR Value" for step 9.2.7 Evaluates actual MCPR value to be less than adjusted limit and that the MCPR thermal limit is NOT met Recognize entry into Tech Spec 3.1.7.c Identifies "action shall be initiated within 15 minutes to restore operation to the prescribed limit. If all operating MCPRs are not returned within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , reactor power reductions shall be initiated at a rate not less than 10% per hour until MCPR is within the prescribed limit". Grade SatlUnsat SatlUnsat SatlUnsat SatlUnsat PasslFail PasslFail SatlUnsat NRC 2010 SRO ADMIN JPM COOl November 2010 Performance Steps Record data in Nl-RESP-l by obtaining information from 3D Monicore printout If candidate recognizes that 0.905 is an incorrect value based on operation without the backup pressure regulator, it is acceptable to calculate a correct value and record in step 9.2.9. This value would be calculated as 1.797/1.708::::

1.052 (1.045-1.076 acceptable). If candidate does not want to proceed through step 9.2.8 due to incorrect MFLCPR values, report that the step deletion process has been completed to delete step 9.2.8. Continue at step 9.2.9. Determine "Adjusted LHGR limit" value for step 9.2.11, with pressure regulator out of service and thermal power between 45% and 90% from the COLR 10. Determine "Actual MFLPD Value" from 3D Monicore printout Determine COLR thermal limit restriction for MFLPD is met Successful completion of this step may be evidenced by the lack of a report to the contrary.

I Standard Records MFLCPR and location in step 9.2.8 as 0.905 and 29-14 Records step 9.2.9 as NA, since all RRPs are operating Records Power to Flow Ratio (PFR) in step 9.2.10 as 0.933 Determines adjusted value to be 0.860, from COLR Section 3.1 and Figure 3, as follows: For 70% ::; P < 90% MFLPD Limit =FRTP = 159111850

= 0.86 Enters 0.86 as "Adjusted LHGR limit" value for step 9.2.11 This value may be 0.02 if Candidate interpolates from graph rather than calculates Determines actual MFLPD value to be 0.735, from printout Enters 0.735 as "Current value" for step 9.2.11 Evaluates actual MFLPD value to be less than adjusted limit and that the MFLPD thermal limit is met Grade SatlUnsat PasslFail SatlUnsat PasslFaii SatlUnsat PasslFail NRC 20 I 0 SRO ADMIN JPM COO I November 2010 I Performance Steps I Standard Grade 12. Record data in Nl-RESP-l by obtaining Records MFLPD and location in step 9.2.12 SatlUnsat information from 3D Monicore printout as 0.735 and 41-38-4 Records FPAPDR in step 9.2.13 as 0.855 SatlUnsat from printout Records step 9.2.14 as NA, since FPAPDR is SatlUnsat

< 1.0 TERMINATING CUE: Nl-RESP-I, Daily Thermal Limit Surveillance completed through step 9.2.14. Adjusted thermal limits for an inoperable pressure regulator are determined.

Violation of MCPR limit and required Tech Spec actions are identified.

RECORDSTOPTlltlE

_________ NRC 2010 SRO ADMIN JPM COOl November 2010 Initial Conditions: The plant is operating at power with 5 recirc loops in service. Feedwater Pump 13 is in operation. The plant is at Beginning of Cycle (BOC). 4. Reactor Engineering reports the value of Tau is 1.0. Scoop Tube setting is 102.5%. Current core thermal power and flow are indicated on the given 3D Monicore printout.

7. Core thermal power has not changed since the last 3D Monicore printout. The Mechanical Pressure Regulator is out of service for repairs. The lVlPR linkage is disconnected at the Front Standard.

Initiating cue: "(Operator's name), using the 3D Monicore printout provided, complete 1, Daily Thermal Limit Surveillance section 9.2, up to and including step 9.2.14. Report the results in the space below." NRC 2010 SRO ADMIN JPM COO 1 November 2010

NRC ..IPM SRO Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Assess Reportability Requirements Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security General Superviso General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security Configuration Control Date Performer:

_______________(SRO) TrainerlEvaluator:

Evaluation Method: _--=X-=---

__ Perform _______ Simulate Evaluation Location:

____Plant ___-----'X'-"-

__ Simulator or other location Expected Completion Time: 30 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: ______ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluator Signature:

________________

_ Date:_______NRC 2010 SRO ADMIN JPM C002 November Recommended Start Location: (Completion time based on the start location)

Classroom Simulator Set-up: NI A Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM Performance:

This evaluated JPM is a measure of your ability to perform this task independently.

The Control Room Supervisor has determined that a verifier is not available and that additional I concurrent verification will not be provided; therefore, it should not be requested.

Read Before Each Training JPM Performance:

During this Training JPM, applicable methods of verification are expected to be used. Therefore, either another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading areas PasslFail.

2. During Evaluated JPM:

Self checking shall be demonstrated.

3. During Training JPM:

Self checking shall be demonstrated.

Peer checking shall be demonstrated.

References:

1. NUREG 1123,2.1.18 , SRO 3.8 2. CNG-NL-1.01-1004

3. 10CFR50.72

4. NUREG 1022 5. EAL Matrix 6. EPIP-EPP-20 NRC 2010 SRO ADMIN JPM C002 November 2010 2 Tools and Equipment:

None Task Standard:

Determine 10 CFR 50.72 reportability requirements.

Initial Conditions: The plant was operating at 100% power with no equipment out of service. A failure of the Feedwater Level Control System has occurred. The plant was manually scrammed in anticipation of an automatic Reactor scram. High Pressure Coolant Injection (HPCI) automatically initiated on low Reactor water level. Reactor water level was restored above the HPCI low level setpoint, and the HPCI initiation signal was reset. Instructor to ask operator for any questions.

Initiating cue: "(Operator's name), list the applicable 10 CFR 50.72 reportability requirements, the reason that they apply and the associated time limitations for reporting under that category.

Record your findings on the sheet provided." I Performance I Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-01)

Evaluator acknowledge repeat back providing correction if necessary RECORD START TIME ____ Obtain a copy of the any of the reference Reference materials obtained as necessary documents related to regulatory These are likely to include the

CNG-NL-1.01-1004

10 CFR 50.72 and 50.73

NUREG 1022

EAL Matrix

EPIP-EPP-20 attachment 6A Locate and identify applicability of 10 CFR Determines no emergency classification is SatlUnsat 50.72(a)(1 ) required This step may be evaluated by absence of a one hour emergency 4. Locate and identify applicability of 10 Identifies reportability per 10 CFR PasslFail 50.72(b)(2)(iv)(B), for a valid RPS while the Reactor is NRC 2010 SRO ADMIN JPM C002 November 2010 I Performance Steps Locate and identifY applicability of 10 CFR 50.72(b)(3)(iv)(A) May alternately refer to 50.72(b)(3)(iv)(B)(5) for reportability Candidate may report that the HPCI notification is due within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to coincide with the RPS actuation notification.

This satisfies the requirement for notification within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . I Standard Determines 10 CFR requires notification within 4 Identifies reportability per 10 CFR 50.72(b)(3)(iv)(A), for a valid actuation of HPCI Determines 10 CFR 50. 72(b )(3)(iv)(A) requires notification within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Grade Terminating Cue: Reportability requirements have been determined.

________ NRC 2010 SRO ADMIN JPM C002 November 2010 Initial Conditions: The plant was operating at 100% power with no equipment out of service. 2. A failure of the Feedwater Level Control System has occurred.

3. The plant was manually scrammed in anticipation of an automatic Reactor scram. 4. High Pressure Coolant Injection (HPCI) automatically initiated on low Reactor water level. Reactor water level was restored above the HPCI low level setpoint, and the HPCI initiation signal was reset. Initiating cue: "(Operator's name), list the applicable 10 CFR 50.72 reportability requirements, the reason that they apply and the associated time limitations for reporting under that category.

Record your findings on the sheet provided." NRC 2010 SRO ADMIN JPM C002 November 2010 Attachment 1 JPM Scorecard KEY Identify the applicable 10 CFR 50.72 reportability requirements, the reason that they apply and the associated time limitations for reporting under that category Reportability Requirement and Reason Time Limit 10 CFR 50.72(b)(2)(iv)(B)

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Valid Reactor Protection System (RPS) actuation while the Reactor is critical 10 CFR 50.72(b)(3)(iv)(A)

Within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Valid actuation of High Pressure Coolant Injection System (HPCI) Note: Candidate may report that the HPCI notification is due Note: May alternately refer to 10CFR within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months to coincide 50.72(b)(3)(iv)(B)(5) for this reportability with the RPS actuation requirement.

notification.

This satisfies the requirement for notification within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

NRC 2010 SRO ADMIN JPM C002 November 2010 Attachment JPM Scorecard for Applicant Identify the applicable 10 CFR 50.72 reportability requirements, the reason that they apply and the associated time limitations for reporting under that category Reportability Requirement and Reason Time Limit NRC 20 I 0 SRO ADMIN JPM C002 November Attachment Actual Plant Event Used as Basis for Power Reactor Event Number: 61005 Facility:

NINE MILE POINT Notification Date: Today's Region: 1 State: NY Notification Time: Today's Time Unit: [1] [ ] [ ] Event Date: Today's RX Type: [1] GE-2,[2] GE-5 Event Time: 11:58 NRC Notified By: Name Last Update Date: Today's HQ OPS Officer: Emergency Class: NON EMERGENCY Person 10 CFR Section: Name SO.72(b)(2)(iv)(B)

-RPS ACTUATION

-

SO.72(b)(3)(iv)(A)

-VALID SPECIF SYS SCRAM Initial Current Unit Code RX CRIT PWR Initial RX Mode PWR Current RX Mode 1 M/R Y 100 Power Operation 0 Hot Shutdown Event Text MANUAL SCRAM AND HIGH PRESSURE COOLANT INJECTION FOLLOWING A LOSS OF FEEDWATER LEVEL CONTROL "At 1158 on Monday, October 5,2009, Nine Mile Point Unit One was manually scrammed from approximately 100% rated power due to failure of the Feedwater Level Control System, in anticipation of a reactor scram. Following the manual scram insertion at 11:58, High Pressure Coolant Injection (HPCI) System automatically initiated on low Reactor Vessel (RPV) level. At 11:59, RPV level was restored above the HPCI System low level actuation setpoint, and the HPCI System initiation signal was reset. At Nine Mile Point Unit One, a HPCI System actuation signal on low RPV level is normally received following a reactor scram, due to level shrink. "Unit 1 has commenced cooldown, in preparation for the forced outage to commence repairs. Reactor water level is being controlled in the normal operating band; reactor temperature is 4S0?F and reactor pressure is approximately 500 psig. "10 CFR 50.72(b)(2)(iv)(B) requires reporting within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when any event or condition that results in actuation of the reactor protection system (RPS) when the reactor is critical.

"10 CFR SO.72(b)(3)(iv)(A) requires reporting within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months when a valid actuation ofthe High Pressure Coolant Injection System occurs. n All control rods fully inserted.

All systems functioned as required following the reactor scram. The reactor is currently stable in Mode 3. HPCI has been secured. Makeup water is being provided by the Reactor Feedwater System and decay heat removal is through the bypass valves to the condenser.

There was no impact on Unit 2 and the plant is in a normal post-scram electrical lineup. The licensee notified the NRC Resident Inspector.

NRC 2010 SRO ADMIN JPM C002 November 2010 NRC JPM SRO EC Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Review ofNl-ST-MlA, Liquid Poison Pump 11 Operability Test Revision:

NRC 20 I 0 Task Number: NI A Approvals:

NIA -Exam Security / General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

_______________(SRO) TrainerlEvaluator:

____________

_ Evaluation Method: _-=__Perform ______ Simulate Evaluation Location:

____Plant __

__ Simulator or Classroom Expected Completion Time: 20 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:_______ NRC 2010 SRO ADMIN JPM EC November 2010 Recommended Start Location: (Completion time based on the start location)

Classroom Simulator Set-up (if required):

N/A Directions to the InstructorlEvaluator:

Prior to performance ofthis JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identifY the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading areas PassIFail.

All steps are sequenced critical unless denoted by a "." . 2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

References:

1. NUREG 1123,2.2.12, SRO 4.1 2. NI-ST-MIA

3. Technical Specification 3.1.2 NRC 2010 SRO ADMIN JPM EC November 2010 Tools and Equipment:

1. Marked up copy ofNI-ST-MlA with flow rate calculation of27.5 Task Standard: Complete review of Nl-ST-MIA.

Identify Liquid Poison pump 11 is inoperable and identify required actions. Initial Conditions: The plant is operating at 100% power. NI-ST-MIA, Liquid Poison Pump 11 Operability Test, has been completed and requires Operations and Shift Manager review. Instructor to ask the operator for any questions.

Initiating Cue: "(Operator's name), using the completed surveillance provided, complete Section 10.1, Operations Review and Section 10.2, SM Review. Record the results of your review and any required actions in the space below." Performance Steps Grade 1. Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-O

1) Evaluator acknowledge repeat back providing correction if necessary

_______ Obtain a copy of the reference procedure Copy of completed surveillance will be and review/utilize the correct section ofthe provided to the performer procedure Completes section 10.1, Operations Determines Liquid Poison pump 11 discharge SatlUnsat Review, references procedure sections as pressure is SAT applicable to verify the required data, and evaluates the data Determines Liquid Poison pump 11 flow rate PasslFaii is UNSAT SatlUnsat Determines Liquid Poison pump 11 motor current is SAT PasslFail Determines NI-ST-MIA results are UNSAT Note: ACRs are no longer generated as a SatlUnsatistandalone document.

Generation of a CR Determines ACR to be initiated NA leads to generation of the required work order, which covers this requirement NRC 2010 SRO ADMIN JPM EC -3 November 2010 Performance Steps Note: May also refer to yellow clearance tag as a caution tag. Standard Informs Operations Manager Determines ESL entry is required for Liquid Poison pump 11 Determines 7 day LCO applies per Tech Spec 3.1.2 Determines entry into Control Room Log is required Determines yellow clearance tag required for Liquid Poison pump 11 Determines CR to be written Grade SatlUnsat SatlUnsat PasslFail SatlUnsat SatlUnsat SatlUnsat Terminating Cue: Operations and Shift Manager Review ofNl-ST-MlA is complete.

Required actions and notifications are identified.

RECORD STOP TIME ____ NRC 2010 SRO ADMIN JPM EC November 2010 Initial Conditions: The plant is operating at 100% power. N1-ST-M1A, Liquid Poison Pump 11 Operability Test, has been completed and requires Operations and Shift Manager review. Initiating Cue: "(Operator's name), using the completed surveillance provided, complete Section 10.1, Operations Review and Section 10.2, SM Review. Record the results of your review and any required actions in the space below." NRC 2010 SRO ADMIN JPM EC November 2010 NRC JPM SRO RC Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Generate and approve an Emergency Exposure Authorization Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security General Supervisor General Supervisor Date Operations Traini Operations (Designee)

NIA -Exam Security Configuration Control Date Perfonner:

__________(SRO) TrainerlEvaluator:

________ Evaluation Method: Perfonn Evaluation Location:

Classroom Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator NRC 2010 SRO ADMIN JPM RC November 2010 Recommended Start Location:

Classroom Simulator Set-up: None Directions to the InstructorlEvaluator:

None Directions to Operators:

Read Before Every JPM For the performance of this JPM, I will function as the Radiation Protection, CRO, and Plant Prior to providing direction to perform this task, I will provide you with the initial conditions and any questions.

During task performance, I will identify the steps to be simulated, or discuss and cues as Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional!

concurrent verification will not be provided; therefore it should not be requested.

Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the additional!

concurrent Notes to Instructor

/ Evaluator:

1. Critical steps are identified as PasslFail.

2. During evaluated JPM:

Self-verification shall be demonstrated.

3. During training JPM:

Self-verification shall be demonstrated.

No other verification shall be demonstrated.

References:

1. NUREG 1123,2.3.4, SRO 3.7 2.

Tools and 1 .

Task Standard:

Generate and approve an Emergency Exposure Authorization Form and estimate NRC 2010 SRO ADMIN JPM RC November 2010 Initial Conditions: A Site Area Emergency is in progress. You have assumed the responsibilities of the Shift ManagerlEmergency Director. An Emergency Condenser 11 steam leak into the Reactor Building cannot be isolated without manually shutting Condensate Return Valve 39-05. Entry to the Reactor Building is required to manually close valve 39-05 to stop a release to Time to complete the task for an experienced Licensed Reactor Operator will be approximately 24 minutes. Time to complete the task for a new Licensed Reactor Operator will be approximately 30 minutes. Radiation levels at the valve are approximately 15 Rlhr. Four (4) individuals are available to perform the task: Worker A is a volunteer who is an experienced Licensed Reactor Operator, has previously received a planned special exposure at another facility, and has received a dose of 150 mR this year (TLD Badge No. 11111, SSN 111-11-1111). Worker B is a volunteer who is an experienced Licensed Reactor Operator and is a declared pregnant worker and has received a dose of 15 mR this year (TLD Badge No. 22222, SSN 222-22-2222). Worker C is a volunteer who is an experienced Licensed Reactor Operator and has received a dose of 1800 mR this year (TLD Badge No. 33333, SSN 333-33-3333). Worker D is a volunteer who is a new Licensed Reactor Operator that has received a dose of 500 mR this year (TLD Badge No. 44444, SSN 444-44-4444). Ask the operator for any questions.

Initiating Cue: "(Operator's name), choose an individual to close valve 39-05, state the reason why that worker was chosen, estimate the expected radiation exposure and document your authorization for an Emergency Exposure." I Performance I Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat back providing correction if necessary RECORD START TIME ____ Obtain a copy of the reference procedure EPIP-EPP-lS is obtained and Attachments 1 Sat/Unsat and review/utilize the correct section and 1-1 are referenced Determine the expected exposure for the F or an experienced worker -Calculates that a SatlUnsat 24 minute exposure in a 15 Rlhr field cause a dose of6 For a new worker -Calculates that a 30 minute exposure in a 15 Rlhr field will cause a dose of7.5 R NRC 2010 SRO ADMIN JPM RC November 2010 I Performance Steps Select the best worker to perform the task The following rationale supports worker selection: Worker A should NOT be chosen due to previously receiving a planned special exposure Worker B should NOT be chosen due to being a declared pregnant worker Worker C should be chosen because both their dose for the emergency exposure (6 R) will be less than that for Worker D; additionally, the dose to the public will be minimized by the shorter task completion time of this experienced worker Worker D should NOT be chosen because their dose for the emergency exposure (7.5 R) will be greater than that for Worker C State reason for choosing the Estimate expected exposure Role The Candidate may choose to brief the worker on radiological conditions, potential for steam leakage in the area, planned task, applicable ALARA measures, and contingency measures.

Role play as Worker C and acknowledge the briefing.

NRC 2010 SRO ADMIN JPM RC I Standard Determines the best worker for the task: Does NOT select Worker A Does NOT select Worker B Selects Worker C Does NOT select Worker D States that Worker C was chosen to minimize dose States that Worker A was NOT chosen due to a previous planned special exposure States that Worker B was NOT chosen due to being a declared pregnant worker States that Worker D was NOT chosen due to higher dose Determines Worker C will receive an estimated 6 R while completing the task (24 minutes x 15 Rlhr 160 minlhr) Grade PasslFail PasslFail PasslFail PasslFaii SatlUnsat Sat/Unsat Sat/Unsat SatlUnsat SatlUnsat November 2010 i Peiformance Steps I Standard Grade Role Play: The Candidate may ask for an RWP to be generated.

Role play as RP and state that an RWP has been generated. Generate an Emergency Exposure

Candidate obtains a copy of EPIP-EPP-15 PasslFail Authorization form Attachment 1-1 Candidate completes Section A (see attached key) TERMINATING CUE: Emergency Exposure Authorization Form has been completed.

_________ NRC 2010 SRO ADMIN JPM RC November 2010 Initial Conditions: A Site Area Emergency is in progress.

2. You have assumed the responsibilities of the Shift ManagerlEmergency Director. An Emergency Condenser 11 steam leak into the Reactor Building cannot isolated without manually shutting Condensate Return Valve Entry to the Reactor Building is required to manually close valve 39-05 to stop a release to the environment. Time to complete the task for an experienced Licensed Reactor Operator will be approximately 24 minutes. 6. Time to complete the task for a new Licensed Reactor Operator will approximately 30 Radiation levels at the valve are approximately 15 Rlhr. Four (4) individuals are available to perform the task: Worker A is a volunteer who is an experienced Licensed Reactor Operator, has previously received a planned special exposure at another facility, and has received a dose of 150 mR this year (TLD Badge No. 11111, SSN 111-11-1111). Worker B is a volunteer who is an experienced Licensed Reactor Operator, is a declared pregnant worker and has received a dose of 15 mR this year (TLD Badge No. 22222, SSN 222-22-2222). Worker C is a volunteer who is an experienced Licensed Reactor Operator and has received a dose of 1800 mR this year (TLD Badge No. 33333, SSN 3333). Worker D is a volunteer who is a new Licensed Reactor Operator that has received a dose of 500 mR this year (TLD Badge No. 44444, SSN 444-44-4444).

Initiating Cue: "(Operator's name), choose an individual to close valve 39-05, state the reason why that worker was chosen, estimate the expected radiation exposure and document your authorization for an Emergency Exposure." NRC 2010 SRO ADMIN JPM RC November 20 I 0 NRC JPM SRO EP Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Emergency Event Classification and Notification Revision:

NRC 2010 Task Number: N/A Approvals:

/ N/A Exam Security General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NtA -Exam Security Configuration Control Date Performer:

____________(SRO) TrainerlEvaluator:

__________ Evaluation Method: Perform Evaluation Location:

Classroom/Simulator Expected Completion Time: 30 minutes Time Critical Task: Yes Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluator Signature:

______________

_ Date:_______ NRC 2010 SRO ADMIN JPM EP November 2010 Recommended Start Location:

Classroom/Simulator Simulator Set-up: None Directions to the InstructorlEvaluator:

None Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the Unit 2 SM, Security Supervisor, Communication Aid, and other personnel as necessary.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

Read Before Each Evaluated JPM Performance:

This evaluated JPM is a measure of your ability to perform this task independently.

The Control Room Supervisor has determined that a verifier is not available and that additional/concurrent verification will not be provided; therefore it should not be requested.

Read Before Each Training JPM Performance:

During this Training JPM, applicable methods of verification are expected to be used. Therefore, either another individual or I will act as the additional/concurrent verifier.

Notes to Instructor

/ Evaluator:

1. Critical steps are identified as Pass/Fail.

2. During Evaluated JPM:

Self-verification shall be demonstrated.

3. During Training JPM:

Self-verification shall be demonstrated.

No other verification shall be demonstrated.

References:

1. NUREG 1123,2.4.41, SRO 4.6 2. EPIP-EPP-Ol

3. EPIP-EPP-18

4. EPIP-EPP-20

5. EPMP-EPP-OI0l Tools and Equipment:

1.0 EPIP-EPP-Ol, ATTACHMENT 1, UNIT 1 EAL FLOWCHART 2.0 SM/ED Checklist Package NRC 2010 SRO ADMIN JPM EP November 2010 Task Standard:

Classify and declare the emergency event within 15 minutes of the time that indications are available to the Candidate that an EAL has been exceeded.

Make notifications to New York State and Oswego County within 15 minutes of the time the event is declared.

Initial Conditions: You are the Unit 1 Shift Manager. Unit 1 was operating at 100% power. Unit 2 is operating at 100% power. The following conditions have occurred: A leak in the Drywell results in rising Drywell pressure. A manual Reactor scram is inserted and all control rods fully insert. Containment Spray is initiated due to high Torus pressure. EOP-8, RPV Blowdown, is entered due to low RPV water level. RPV water level momentarily lowers below Top of Active Fuel (TAF), but is quickly recovered to the normal band using Core Spray. Reactor Building DIP is -0.25" H 2 0. Reactor Building ventilation radiation monitors read at normal background levels. Stack radiation monitors read at normal background levels. The time of shutdown is 10 minutes ago. Instructor to ask the operator for any questions.

Initiating Cue: "(Operator's name), based on the above conditions, determine the event classification per EPIP-EPP-Ol and complete steps 1 through 9.a of EPIP-EPP-18, Attachment 1, SM/ED Checklist.

This is a time critical task." Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat providing correction if

________ Obtain a copy of EPIP-EPP-O1 attachments 1 EPIP-EPP-O 1 attachments 1 and 2, and Shift SatlUnsat and 2, and Shift Manager emergency Manager emergency paperwork is obtained paperwork and review/utilize the correct section NRC 2010 SRO ADMIN JPM EP November 2010

I Performance Steps Enters EPIP-EPP-18, Attachment 1, SMIED Checklist and completes Steps 1 through 9.a Classifies and declares the emergency Completes EPIP-EPP-18 attachment 1, figure 1 flowchart to determine evacuation and accountability requirements Calls the Communications Aides to the Control Rooms Role Play: Acknowledge communication Fills out the ERO Notification System (ERONS) form Calls Unit 2 SM to inform that ERONS form is coming and to get Unit 2 plant status Role If asked about the status of Unit 2, report that Unit 2 is still operating at 100% power with no issues Completes EPlP-EPP-18 attachment 2, Emergency Announcement I Standard Completes steps 1 thm 9.a of EPIP-EPP-18, as described in subsequent JPM steps Declares an Alert within fifteen minutes of the JPM initial condition sheet being accepted in accordance with EAL 3.1.1 EXAMINER NOTE: Time difference below must be 15 minutes or less: JPM start time: ___ Time of Declaration:

Completes Attachment as shown in KEY Proper communications used (GAP-OPS-O

1) Completes Attachment as shown in KEY Proper communications used (GAP-OPS-Ol)

Completes Attachment as shown in KEY Grade SatlUnsat PasslFail SatlUnsat SatlUnsat SatlUnsat SatlUnsat SatlUnsat NRC 2010 SRO ADMIN JPM EP November 2010 I Performance Steps 10. Completes EPIP-EPP-20 Part 1 Notification Fact Sheet I Standard Completes Attachment as shown in KEY Part 1 Notification Fact Sheet Steps 3 tbru 7 are Critical Steps EXAMINER NOTE: Time difference must be 15 minutes or less: Time of Declaration (from JPM step 4): Time EPIP-EPP-20 Part 1 Notification Fact Sheet is complete:

___ Grade PasslFail TERMINATING CUE: ERONS Fonn, Emergency Announcement Fonn, and Part 1 Notification Fact Sheet completed.

Task completion reported to examiner.

_________ NRC 2010 SRO ADMIN JPM EP November 2010 Initial Conditions:

1. You are the Unit 1 Shift Manager. 2. Unit 1 was operating at lOO% power. 3. Unit 2 is operating at 100% power. 4. The following conditions have occurred: A leak. in the Drywell results in rising Drywell pressure. A manual Reactor scram is inserted and all control rods fully insert. Containment Spray is initiated due to high Torus pressure. EOP-8, RPV Blowdown, is entered due to low RPV water level. RPV water level momentarily lowers below Top of Active Fuel (TAF), but is quickly recovered to the normal band using Core Spray. Reactor Building DIP is -0.25" H 2 0. Reactor Building ventilation radiation monitors read at normal background levels. Stack radiation monitors read at normal background levels. 5. The time of shutdown is lO minutes ago. Initiating Cue: "(Operator's name), based on the above conditions, determine the event classification per EPIP-EPP-Ol and complete steps 1 through 9.a ofEPIP-EPP-18, Attachment 1, SMIED Checklist.

This is a time critical task." Meteorological Data 30ft 200 ft Wind Speed 5 mph 10 mph 60 0 60 0 Wind Direction Stability Class I NRC 2010 SRO ADMIN JPM EP November 2010 NRC JPM 5-1 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Respond to a Loss of Service Water (PRA) (Alternate Path) Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

_______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: __Perform ______ Simulate Evaluation Location:

____Plant __---".!!:.-

__ Simulator Expected Completion Time: 15 minutes Time Critical Task: No Alternate Path Task: Yes Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator's Signature:

______________

_ Date:_______ NRC 2010 JPM 8-1 -1 November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC 161 2. VerifY Service Water pump 11 is red flagged and Service Water pump 12 is green flagged 3. VerifY malfunction CW02B is on trigger 1 with a 15 second time delay 4. VerifY trigger 1 command is set to zdcwpstr(4)=1 (Service Water pump 12 control switch in start) 5. VerifY malfunction CW02A is active Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM ! CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM ! CRO permission.

Directions to Operators:

Read Before JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identifY the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional!

concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor!

Evaluator:

1. Critical steps are identified in grading area as PasslFail.

2. During Evaluated IPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

No other verification shall be demonstrated.

References:

1. NUREG 1123,295018, AA1.01, RO 3.3, SRO 3.4 2. Nl-SOP-I8.1 NRC 2010 JPM S-1 November 2010 Tools and Equipment:

None Task Nl*SOP-18.1 actions are complete through the override step for a sequential loss of Service Water pumps. Initial Conditions: The plant is operating at approximately 100% power. Service Water pump 11 has tripped on overcurrent. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), enter and execute NI-SOP-18.1 for Service Water Failure." Performance Steps Grade Provide repeat back of initiating cue Proper communications used for repeat back SatiUnsat (GAP-OPS-Ol)

Evaluator Acknowledge repeat providing correction if

____________

__ Obtain a copy of the reference procedure and NI-SOP-IS.10btained SatiUnsat review/utilize the correct section of the procedure Start standby Service Water pump by placing Rotates Service Water pump 12 control switch PasslFail control switch on Panel H to START CW to start, observes red light on, green light off, proper pump amps Note: Service Water pump 12 will trip after a 15 second time delay, requiring an alternate path to execute the override for loss of both Service Water pumps Identifies trip of Service Water pump 12 Observes Service Water pump 12 green light SatiUnsat on, red light off, pump amps drop to zero, annunciator Hl-2-2 alarms If neither Service Water pump can be started Enters override ofNI-SOP-I8J SatiUnsat OR Service Water Header pressure can NOT be restored to greater than 60 psig, then performs the following steps: NRC 2010 JPM S*1 -3 November 2010 Performance Steps Start Emergency Service Water pumps SCRAM the Reactor AND concurrently execute NI-S0P-l Cue: Another operator will perform SOP-I actions. Continue in SOP-18.1. Initiate Emergency Condensers Cue: Another operator will maintain Reactor pressure per EOP-2. Close MSIV s 10. Trip all Rx Recirculation Pumps Cue: Another operator will monitor RBCLC and TBCLC temperatures.

Standard Rotates ESW pump 11 control switch CW to start, observes red light on, green light off, proper pump amps Rotates ESW pump 12 control switch CW to start, observes red light on, green light off, proper pump amps Rotates the Reactor Mode Switch CW to Shutdown Rotates 39-05 control switch CW to open and/or rotates 39-06 control switch CW to open Rotates 01-01 control switch CCW to close Rotates 01-02 control switch CCW to close Rotates 01-03 control switch CCW to close Rotates 01-04 control switch CCW to close Rotates RRP 11 control switch CCW to stop Rotates RRP 12 control switch CCW to stop Rotates RRP 13 control switch CCW to stop Rotates RRP 14 control switch CCW to stop Rotates RRP 15 control switch CCW to stop Grade PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail PasslFail Terminating Nl-SOP-lS.1 actions are completed through the override step for a sequential loss of Service Water pumps.

________ NRC 2010 JPM S-1 November 2010 Initial Conditions:

1. The plant is operating at approximately 1000/0 power. 2. Service Water pump 11 has tripped on overcurrent.

Initiating Cue: "(Operator's name), enter and execute NI-SOP-I8.1 for Service Water Failure." NRC 2010 JPM S-1 November 2010

NRC JPM Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Bypass LPRM Input To APRM Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: _....::X-"--

__ Perform Simulate Evaluation Location:

____ Plant X Simulator Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator's Signature:

______________

_ Date:_______ NRC 2010 JPM S-2 November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC-162 (shared with JPM S-8) 2. Verify LPRM 20-25A failed downscale (malfunction NM29R20C25A active) 3. Verify LPRM 20-25A Power Supply, NPWRS-RJOIC-L, on backpanel is selected to Position 1 Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before EveI)' JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading area as Pass/Fail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training lPM:

Self verification shall be demonstrated.

Peer verification shall be demonstrated.

References:

1. NUREG 1123,215005, A4.04, RO 3.2, SRO 3.2 2. NI-OP-38C NRC 2010 JPM S-2 November 2010 Tools and Equipment:

None Task Standard:

LPRM 20-25A input to APRM 13 is bypassed per NI-0P-38C and APRM 13 is unbypassed.

Initial Conditions: LPRM 20-2SA failed downscale. There are no other LPRMs inoperable or bypassed. No APRMs are bypassed. A review of Control Room logs has been performed by the CRS to verifY APRMs are operable. The CRS has reviewed Technical Specifications and verified that the associated APRM can be bypassed. The CRS has completed NI-OP-38C, Attachment 5, and determined that the LPRM 20-2SA input to its associated ARPM can be bypassed. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), bypass LPRM 20-2SA input to its associated APRM per NI-OP-38C, and then return the APRM to operable.

You are NOT required to bypass the LPRM alarm function." Performance Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator Acknowledge repeat back providing correction if necessary RECORDSTARTTUME

_______ Obtain a copy of the reference procedure and NI-OP-38C obtained, precautions

& SatlUnsat review/utilize the correct section of the limitations reviewed & section H.3.0 procedure referenced Confirm LPRM can be bypassed Determines step complete per initial SatlUnsat per Technical Specifications, using conditions Attachment 5 Bypass selected APRM which includes the DeterminesLPRM 20-25A is assigned to SatlUnsat associated LPRM that is to be bypassed APRM 13 (back panel or Att. 50fOP-38C) Candidate may use OP-38C section H.l.0 Positions APRM 11-12-13-14 BYPASS PasslFail to bypass the APRM. joystick to CH 13 Checks E-panellight, computer, then checks SatlUnsat back panel light to verifY APRM bypassed Position LPRM to be bypassed to readout on At APRM 13 drawer, positions INPUT SatlUnsat APRM module drawer selector switch, S9, to position 4 SatlUnsat drawer. Note: APRM 12 and APRM 13 share the Observes meter indication NRC 2010 JPM S-2 -3 November 2010 Performance Steps Position LPRM to readout on its power supply module Slide APRM drawer open to expose red LPRM bypass knurled knobs Switches used to bypass the specific LPRM signal to its APRM averaging circuit are located in the related APRM module. Withdrawing this module exposes knurled knobs, which are numbered to correspond with the LPRMs on the faceplate. Rotate appropriate LPRM red knob clockwise to bypass LPRM The bypass switch is a two-position switch and will only rotate 1/4 turn Confirm LPRM reading on APRM drawer reads zero 10. Confirm LPRM reading on power supply module remains the same Place APRM drawer counts switch 12. Confirm LPRM count rate on module drawer reflects the number of bypassed LPRMs assigned to that When in COUNT, the APRM drawer meter indicates the number of available LPRMs times 10% (in this case, 7 x 10% =70%). 13. Verify APRM drawer switch is in Average Standard Positions Power Supply selector switch for NPWRS-RJ01C-L to Position 4 Observes meter indication (0 on 0-125 scale) APRM drawer pulled out to expose red knurled knobs Rotates LPRM red knurled knob S4 clockwise 114 turn Observes PERCENT POWER meter at 0% with APRM 13 INPUT selector switch, S9, in position 4 Observes LPRM reading on power supply module did not change (remains 0) Positions APRM 13 drawer counts switch to COUNT Determines that there are 7 operable LPRM inputs to APRM 13 Determines that LPRM count rate on APRM 13 should indicate 70% Observes PERCENT POWER meter for APRM 13 indicates 70% Positions APRM 13 drawer switch to AVERAGE Grade SatJUnsat SatJUnsat PasslFail SatJUnsat SatJUnsat SatJUnsat SatJUnsat SatJUnsat SatJUnsat SatJUnsat NRC 2010 JPM S-2 November 2010 Performance Steps 14. NotifY the Reactor Engineering (RE) ment that an LPRM has been bypassed Cue: As RE, acknowledge the report that LPRM 20-25A input to APRM 13 is bypassed.

Cue: Inform the operator that RE will perform the APRM GAIN ADJUSTMENTS per Nl-REP-12.

15. Perform APRM gain adjustment per OP43A Attachment, APRM GAIN ADJUSTMENT, orNI-REP-12, APRM GAIN ADJUSTMENT Booth Operator -Perform an AGAF once the LPRM is bypassed. As RE, report to the reactor operator that the APRM GAIN ADJUSTMENT per Nl-REP-12 is complete.

16. Remove selected APRM from bypass Candidate may use OP-38C section H.2.0 to un-bypass the APRM. 17. Ensure an ESL entry is made for the bypassed LPRM As the SM/CRS, report that the bypassed LPRM has been entered into the ESL log. 18. Ensure a CRC Book Entry is made in the LPRM bypass status sheet section for the bypassed LPRM As the SM/CRS, report that the CRC Book has been updated for the bypassed LPRM. Standard Notifies RE that LPRM 20-25A input to APRM 13 is bypassed Acknowledges report from RE that the APRM GAIN ADJUSTMENTperN1-REP-12 is complete Positions APRM 11-12-13-14 BYPASS joystick to NEUTRAL position Checks E-panellight, computer, then checks back panel light to verifY APRM un-bypassed Informs the SM/CRS that an ESL entry is required for the bypassed LPRM Informs the SM/CRS that a CRC Book entry is required for the bypassed LPRM Grade SatlUnsat SatlUnsat Pass/Fail Terminating Cue: LPRM 20-25A input to APRM 13 is bypassed per NI-OP-38C and APRM 13 is unbypassed.

RECORD STOP TIME ____ NRC 2010 JPM 8-2 November 2010 Initial Conditions: LPRM 20-25A failed downscale. There are no other LPRMs inoperable or bypassed. No APRMs are bypassed.

4. A review of Control Room logs has been performed by the CRS to verify APRMs are operable. The CRS has reviewed Technical Specifications and verified that the associated APRM can be bypassed.

6. The CRS has completed NI-OP-38C, Attachment 5, and determined that the LPRM 20-25A input to its associated ARPM can be bypassed.

Initiating Cue: "(Operator's name), bypassLPRM 20-25A input to its associated APRM per 38C, and then return the APRM to operable.

You are NOT required to bypass the LPRM alarm function." NRC 2010 JPM 8-2 November 2010 NRC JPM 5-3 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Synchronize Main Generator to Grid, Main Generator Locks Out Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

Configuration Control Date Performer:

______________(ROISRO) Evaluation Method: _-'X'-"'--

__ Perform ______ Simulate Evaluation Location:

____ Plant __----"'-"--

__ Simulator Expected Completion Time: 30 minutes Time Critical Task: No Alternate Path Task: Yes Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluator's Date:_______ NRC 2010 JPM S-3 November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC-163. 2. Generator ready to be synchronized.

3. Complete NI-OP-32 through Step E.3.1. Candidate will start JPM with Step E.3.2. 4. Verify malfunction TCOI is set on Trigger 1 with a 10 second delay time. 5. Verify remote EGlO is set on Trigger 2 with a fmal value of"greenf'.

6. Verify remote EG 12 is set on Trigger 2 with a final value of "redf' and a 2 second delay time. 7. Verify Trigger 1 is set to activate on "hzleglOc=l&zdeglOSO=O".

Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading area as Pass/Fail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training lPM:

Self verification shall be demonstrated.

Peer verification shall be demonstrated.

NRC 20 I 0 JPM S-3 November 2010

References:

1. NUREG 1123,245000, A4.02, RO 3.1, SRO 2.9 2. N1-0P-32 3. N1-ARP-A7

4. Nl-SOP-31.1 Tools and Equipment:

None Task Standard:

Main Generator synchronized to the grid, and then Turbine trip responded to in accordance with N1-S0P-31.1.

Initial Conditions:

1. A plant startup is in progress.

2. Reactor power is approximately 18%. 3. NI-OP-43A step E.S.9 is in progress to synchronize and load the turbine and generator.

4. The Main Generator is ready to be synchronized to the grid. 5. NI-0P-32 is completed through step E.3.1. 6. Nine Mile Point Unit 2 Lines 5 and 6 are in-service.

7. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), complete synchronizing the Main Generator to the grid by starting at step E.3.2 of N 1-0P-32. Load the Generator until all turbine bypass valves are closed. Then, complete the remainder of section E.3.0." Performance Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat back prOViding correction if necessary RECORDSTARTTUME

_______ Obtain a copy of the reference procedure N 1-0P-32 obtained and section E.3.0 entered SatlUnsat and review/utilize the correct section of the procedure Verify open R91S and R925 Verifies R915 and R925 indicate open by SatlUnsat verifying red lights off, green lights on Note: There is a short time delay movement ofMOD-18 results indicating light change and clearing annunciator A 7 5 "Generator 18 4. Close switch Places SW 18 Generator 1 switch to close and PasslFail NRC 2010 JPM S-3 -3 November 2010 Per{sJrmance Stees Insert Sync Key into R915 (R925) SYNCHRONIZING Switch, AND place R915 (R925) SYNCHRONIZING Switch to ON Verifies INCOMING and RUNNING voltages are matched Adjust GOVERNOR Switch UNTIL synchroscope is rotating slowly in the FAST direction When INCOMING and RUNNING voltages are matched, AND synchroscope is indicating 3 to 5 degrees lead time, close R915 (R925) Immediately load the generator to 15-60 MWe OR UNTIL all Turbine Bypass Valves Close Place R915 (R925) SYNCHRONIZING Switch to OFF and remove key When the SYNCHRONIZING Switch is placed in OFF, a trigger with a 10 second time delay will cause a Turbine trip. This initiates the alternate path. Executes alarm response procedures If candidate requests guidance, tell them to respond using the procedure for a Turbine trip. Verify the following: Turbine Stop valves closed Turbine Control valves closed Turbine Reheat Stop Valves closed Turbine Intercept Valves closed Bypass valves maintaining Reactor pressure as necessary NRC 2010 JPM S-3 Standard verifies green light goes out and red light is on Grade Inserts Sync Key into R915 (R925) SYNCHRONIZING Switch, AND places R915 (R92S) SYNCHRONIZING Switch to ON PasslFail Adjusts voltage as needed using the Exciter Rheostat SatlUnsat Adjusts generator frequency using by adjusting the GOVERNOR Switch SatlUnsat When synchroscope indicates 3 to 5 degrees PasslFail lead time, places control switch for R915 (R925) in the CLOSE position Places governor control switch in the RAISE SatlUnsat position until all turbine bypass valves are closed (as observed on panel AI, all Turbine BV indicating lights "green") R915 (R925) SYNCHRONIZING Switch SatlUnsat placed in OFF and key removed Observes annunciators, determines the SatlUnsat Turbine and Generator have tripped and enters NI-SOP-31.1 Visually observes the following:

Turbine Stop Valves closed (green lights on) SatlUnsat Turbine Control Valves closed (green lights SatlUnsat on) Combined Reheat Valves closed (green lights SatlUnsat on) Turbine Bypass Valves open to control reactor SatlUnsat pressure (red lights on for several valves) November 2010 Perfgrmance Stell.S Grade Verify the following Electrical Visually observes the following:

Distribution system conditions: 345 Kv Breakers R915, R925 TRIPPED 345Kv Breakers R915, R925 TRIPPED Sat/Unsat (Green light on)

MOD 18 MOD 18 OPEN (Green light on) Sat/Unsat PB 11, PBl2 supplied from Reserve PB 11, PBl2 supplied from Reserve Power Sat/Unsat Power (R123 and Rl12 CLOSED, Red lights on) Another Operator will control RPV water level and pressure.

Continue with the actions ofSOP-31.1. Perform the following: VerifY ON, Aux. Oil pumps Rotates Aux. Oil Pump switches (2) SatlUnsat clockwise, observes red lights illuminate, green lights extinguish Resets 86 relays by rotating control switches PasslFailReset Generator 86 Dispatches operator to restart Stator Water PasslFailRestart Stator Water Cooling Cooling When dispatched to restart Stator Water Cooling, insert trigger 2, then report the task has been completed with time compression.

Rotates Bearing lift pump switches (5) Sat/UnsatStart bearing lift pumps clockwise, observes red lights illuminate, green lights extinguish Shutdown turbine per NI-OP-31 Proper communications used (GAP-OPS-Ol)

Sat/Unsat Inform candidate that another operator will be tasked with Turbine shutdown. Verify ATS Gross Failure Lights are OFF Observes ATS Gross Failure Lights are OFF SatlUnsat Contact Structural Engineering to perform Proper communications used (GAP-OPS-Ol)

Sat/Unsat walkdown of System 03 piping and support for damage Terminating Cue: Main Turbine tripped, TCVs, TSVs and Combined Reheat Valves closed, plus Generator 86s reset, Stator Water Cooling on, Auxiliary Oil pumps on, and Bearing Lift pumps on. RECORD STOP TIME ____ NRC 2010 JPM S-3 -5 November 2010 Initial Conditions: A plant startup is in progress. Reactor power is approximately 18%. N1-0P-43A step E.S.9 is in progress to synchronize and load the turbine and generator. The Main Generator is ready to be synchronized to the grid. N1-0P-32 is completed through step E.3.l. Nine Mile Point Unit 2 Lines S and 6 are in-service.

Initiating Cue: "(Operator's name), complete synchronizing the Main Generator to the grid by starting at step E.3.2 ofN1-0P-32.

Load the Generator until all turbine bypass valves are closed. Then, complete the remainder of section E.3.0." NRC 2010 JPM S-3 -6 November 2010

NRCJPM 8-4 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Rapid RWCU System Restoration for Level Control Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:.

______________(RO/SRO) TrainerlEvaluator:

Evaluation Method: ____Perform ___________

Simulate Evaluation Location:

____ Plant ____--"-"'--___ Simulator Expected Completion Time: 20 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: Completion Time: ______ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a .comment.

Comments:

Evaluator's Signature:

____________________________

_ Date:____________NRC 2010 JPM 8-4 November Recommended Start Location:

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC-164 2. Verify RPV water level is above 100 inches 3. Verify RWCU system isolated with isolation signal clear Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM Performance:

This evaluated JPM is a measure of your ability to perform this task independently.

The Control Room Supervisor has determined that a verifier is not available and that additional I concurrent verification will not be provided; therefore, it should not be requested.

Read Before Each Training JPM Performance:

During this Training JPM, applicable methods of verification are expected to be used. Therefore, either another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading area as PasslFall.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

Peer verification shall be demonstrated.

References:

1. NUREG 1123,204000, A4.06, RO 3.0, SRO 2.9 2. NI-EOP-HC Tools and Equipment:

None NRC 2010 JPM S-4 November 2010 Task Standard:

R WCU is rejecting to the condenser for level control. Initial Conditions: RWCU isolated following a low-low RPV water level transient. RPV water level is high. RWCU system is needed to control RPV water level. Another Operator will be controlling RPV pressure using the ERVs. 5. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), perform rapid RWCU system restoration for RPV water level control and establish reject flow to the condenser, per NI-EOP-HC Attachment 12." Performance Standard Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-O

1) Evaluator Acknowledge repeat back providing correction if necessary

________ Obtain a copy of the reference procedure N1-EOP-HC Attachment 12 is obtained SatlUnsat and review/utilize the correct section of the procedure Verify the following: All Reactor Water Cleanup isolation Observes K3-4-4 clear SatlUnsat signals clear The cause of the isolation is known Determines cause is known and corrected per SatlUnsat AND corrected initial conditions Verify closed the following valves: 33.1-01B, CLEANUP PCV 11 (LP) Observes 33.1-0 IB in MAN and output signal SatlUnsat atO SatlUnsat33-39B, CLEANUP PCV 12 (HP) Places controller PC-33-39 in MAN and to Using RMC-33-151, CLEANUP SYS Verifies controller RMC-33-15I CLEANUP SatlUnsat SELECTOR, close 33-40 SYS SELECTOR in MAN and dialed to 0 Manipulation ofFC-33-169 is inconsequential, but does not satisfy this step. NRC 2010 JPM S-4 November 2010 Performance Steps Using RMC-33-165, CLEANUP TO COND & WASTE FLOW, close 33-165 VerifY open one of the following using the CLEANUP SELECTOR CONDENSER WASTE control switch: WASTE (valve 33-10, CLEANUP TO WASTE DISPOSAL BV) COND (valve 33-11, CLEANUP TO CONDENSER BV) Initiating cue directs the candidate to reject to the condenser Open 33-01R, CU RETURN ISOLATION VALVE 1 (INSIDE) Open 33-04R, CU SUPPLY ISOLATION VALVE 12 (OUTSIDE), for approximately 3 seconds THEN TO-STOP Cleanup System Inlet Pressure will rapidly rise in the next step Jog open 33-02R, CU SUPPLY TION VALVE 11 (INSIDE), using second open signals followed by TO-STOP UNTIL Cleanup System Inlet Pressure has stabilized at Reactor Pressure 11. Fully open 33-02R Standard VerifY controller RMC-33-165C dialed to 0 Rotates CLEANUP SELECTOR ER WASTE control switch clockwise to COND position Observes right hand set of lights red light ON and green light OFF, for 33-11 valve to condenser Rotates33-01R control switch clockwise to open Observes red light ON, green light OFF Rotates33-04R control switch clockwise to open and uses pull-to-stop function after 3 seconds Observes red light ON, green light ON Rotates33-02R control switch clockwise to open and uses pull-to-stop in Yz second intervals UNTIL Cleanup system inlet pressure rises and stabilizes at reactor pressure on indicators Observes red light ON, green light ON Observes cleanup system pressure and reactor pressure approximately equal Rotates33-02R control switch clockwise to open Observes red light ON, green light OFF Grade SatlUnsat PasslFail SatlUnsat PasslFaii PasslFail SatlUnsat NRC 2010 JPM S-4 November 20lO Pertormance Steps Fully open the following valves: 33-04 33-41,AOBLOCKINGVALVE Simultaneously perform the following: Adjust the in-service PCV to maintain Reactor Water Cleanup System pressure <100 psig Operator may set the PCV in AUTO after pressure is established Adjust RMC-33-165C, CLEANUP TO COND & WASTE FLOW to control Reactor Water Level AND maintain Non-Regenerative Heat Exchanger outlet temperature

< 120°F on computer point F359 Another operator will monitor computer point F359.33-165 controller must be greater than 20% before the valve will open, then may be lowered below 20% to adjust flow. As time permits, continue with NI-OP-3, H.10.0. Another operator will continue with N OP-3 H.10.0. Reports to CRS that RWCU is restored and rejecting to condenser for level control Standard Rotates33-04R control switch clockwise to open Observes red light ON, green light OFF Rotates 33-41 control switch clockwise to open Observes red light ON, green light OFF Using controller PC-33-39, dials output signal to open valve and establish inlet pressure below 100 psig Using controller RMC-33-165C, dials output signals to open valve and establish system reject flow Maintains parameters to prevent a subsequent RWCU system isolation Proper communications used (GAP-OPS-Ol)

Proper communications used (GAP-OPS-Ol)

Grade PasslFail SatJUnsat PasslFaiI SatJUnsat SatJUnsat PasslFail PasslFail SatJUnsat SatJUnsat Terminating Cue: RWCU is rejecting to the condenser for level control. RECORD STOP TIME ____ NRC 2010 JPM S-4 -5 November 2010 Initial Conditions:

1. RWCU isolated following a low-low RPV water level transient.

2. RPV water level is high. 3. R WCU system is needed to control RPV water level. 4. Another Operator will be controlling RPV pressure using the ERVs. Initiating Cue: "(Operator's name), perform rapid RWCU system restoration for RPV water level control and establish reject flow to the condenser, per Nl-EOP-HC Attachment 12." NRC 20 I 0 JPM S-4 November 2010

NRC ..IPM Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Start the Emergency Ventilation System (Loop 11) Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

_______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: _--"X-"--__ Perform Simulate Evaluation Location:

____ Plant __------=c-"'---

X __ Simulator Expected Completion Time: 15 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator's Signature:

______________

_ Date:______NRC 2010 JPM S-5 November Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC-165 (100% power, shared with JPM S-6). 2. VerifY RB Ventilation Exhaust fan 11 is running and Supply fan 12 is running, with other fans secured. 3. VerifY Drywell vent lineup is in service, with valves 201-31 and 201-32 open or throttled open. 4. Take simulator out of freeze. Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM/CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identifY the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional!

concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

1. Critical steps are identified in grading area as PasslFail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

References:

1. NUREG 1123,288000, A4.01, RO 3.1, SRO 2.9 2. NI-OP-IO Tools and Equipment:

NRC 2010 JPM S-5 November 2010 None Task Standard:

Emergency Ventilation System (Loop 11) is running, normal Reactor Building Ventilation is isolate, and Drywell venting is isolated.

Initial Conditions: The plant is operating at 100% power. Drywell venting is in progress in preparation for an outage. Fuel was being moved in the SFP in preparation for the outage. An irradiated fuel bundle has been dropped in the SFP. The refuel floor has been evacuated. Refuel floor radiation levels are rising slowly, but not enough to auto initiate RBEVS. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), manually start Reactor Building Emergency Ventilation System Loop 11, isolate normal Reactor Building Ventilation, and isolate Drywell venting, in accordance with NI-0P-1O Section H.l.O." Performance Steps Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator Acknowledge repeat providing correction if RECORD START TIME ____ Obtain a copy of the reference procedure NI-OP-IO obtained, precautions

& limitations SatlUnsat and review/utilize the correct section of the reviewed and section H.l.O referenced procedure Verify open 202-36, EM Ventilation from Observes 202-36 red light on and green light SatlUnsat Reactor Bldg BV off Verify closed the following valves: 202-47, EM VENTILATION TIE BV Observes 202-47 green light on and red light SatlUnsat off 202-74, EM VENTILATION LOOP Observes 202-74 green light on and red light SatlUnsat 11 COOLING BV off Observes 202-75 green light on and red light SatlUnsat202-75, EM VENTILATION LOOP off 12 COOLING BV Place 202-37, EM VENTILATION LOOP Rotates 202-37 switch CW to open PasslFail 11 INLET BV control switch to OPEN Verify open 202-37, EM VENTILATION Observes 202-37 red light on and green light SatlUnsat LOOP 11 INLET BV off NRC 2010 JPM 8-5 November 2010 Performance Steps Start 202-53, EVS FAN 11 VerifY open 202-34, EM VENT EXHAUST FAN 11 OUTLET BV Conftrm proper operation of 202-50, EM VENT EXHAUST FAN 11 INLET FCV, by observing indicating lights and flow indication VerifY control switches for the following fans are in OFF: 202-01, REACTOR BLDG SUPPL Y FAN 11 202-02, REACTOR BLDG SUPPLY FAN 12 VerifY control switches for the following fans are in OFF: 202-05, REACTOR BLDG EXHAUST FAN 11 202-06, REACTOR BLDG EXHAUST FAN 12 VerifY closed the following valves: 202-32, REACTOR BLDG EXHAUST ISOLATION VALVE 11 202-15, REACTOR BLDG SUPPLY

ISOLATION VALVE 11 202-31, REACTOR BLDG EXHAUST ISOLATION VALVE 12 202-16, REACTOR BLDG SUPPLY

ISOLATION VALVE 12 Standard Grade Rotate switch CW to start PasslFaii Observes 202-34 red light on and green light off SatlUnsat Observes 202-50 red and green lights both on as valves goes to intermediate position Observes flow meter 202-49B SatlUnsat SatlUnsat Observes Reactor Building Supply Fan 11 control switch in OFF Rotates Reactor Building Supply Fan 12 control switch CCW to OFF SatlUnsat SatlUnsat Rotates Reactor Building Exhaust Fan 11 control switch CCW to OFF SatlUnsat Observes Reactor Building Exhaust Fan 12 control switch in OFF SatlUnsat Rotates control switch for 202-32 and 202-31 CCWtoclose Rotates control switch for 202-15 and 202-16 CCWtoclose PasslFail PasslFail I NRC 2010 JPM November 2010 Performance Steps 13. VeritY closed the following valves: 202-03, REACTOR BLDG EXHAUST FAN 11 INLET DAMPER Note: The procedure has the incorrect name for 202-03. It should be REACTOR BLDG SUPPLYFAN 11 INLET DAMPER. If candidate identifies need for procedure enhancement, report that CRS has processed an Immediate Procedure Change, and direct candidate to continue as though the procedure has been corrected. 202-08, REACTOR BLDG EXHAUST FAN 11 OUTLET DAMPER 202-04, REACTOR BLDG SUPPLY FAN 12 INLET DAMPER 202-07, REACTOR BLDG

EXHAUST FAN 12 OUTLET DAMPER IF drywell and torus venting was in progress, THEN clear personnel from the drywell at the discretion of the Shift Manager after consulting with Radiation Protection Cue: No personnel are in the drywell. VeritY 201-35 drywell and torus vent purge fan VeritY closed the following valves: 201-22, DRYWELL & TOR VENT &* PURGE FAN OUTLET BV 201-21, DRY WELL & TOR VENT & PURGE FAN INLET BV 201-16, TORUS N2 VENT & PURGE ISOLATION VALVE 11 201-17, TORUS N2 VENT & PURGE ISOLATION VALVE 12 NRC 20lO JPM 8-5 Standard Grade Observes 202-03 green light on and red light SatlUnsat off Observes 202-08 green light on and red light off SatlUnsat Observe 202-04 green light on and red light off SatlUnsat Observes 202-07 green light on and red light off SatlUnsat Proper communications used (GAP-OPS-O

1) SatlUnsat Rotates 201-35 control switch clockwise SatlUnsat Observes 201-22 green light on and red light off Observes 201-21 green light on and red light off Observes 201-16 green light on and red light off Observes 201-17 green light on and red light off SatlUnsat SatlUnsat SatlUnsat SatlUnsat -5 November 2010 Performance Steps

201-32, DWN2 VENT & PURGE ISOLATION VALVE 11

201-31,DWN2VENT&PURGE ISOLATION VALVE 12 Monitor RX BLDG/A TM DP and EM VENT DIS FLOW CFM meters on panel L (normal flow approximately 1600 CFM) Reactor Building DIP and RBEVS flow may take a short period of time to stabilize at normal levels. If candidate recognizes low Reactor Building DIP and/or low RBEVS flow, state that the parameters are improving and direct them to allow them to stabilize. Notify RP and CRS/SM that EVS loop 11 has been placed in service Standard Rotates 201-32 control switch clockwise Rotates 201-31 control switch clockwise Observes Lll' and flow meters on L Panel Proper communications used (GAP-OPS-Ol)

Grade SatlUnsat SatlUnsat Terminating Cue: Emergency Ventilation System (Loop 11) is running and normal Reactor Building ventilation is isolated.

RECORD STOP TIME ____ NRC 2010 JPM November 2010 Initial Conditions:

1. The plant is operating at 100% power. 2. Drywell venting is in progress in preparation for an outage. 3. Fuel was being moved in the SFP in preparation for the outage. 4. An irradiated fuel bundle has been dropped in the SFP. 5. The refuel floor has been evacuated.

6. Refuel floor radiation levels are rising slowly, but not enough to auto initiate RBEVS. Initiating Cue: "(Operator's name), manually start Reactor Building Emergency Ventilation System Loop 11, isolate normal Reactor Building Ventilation, and isolate Drywell venting, in accordance with NI-OP-l 0 Section H.I.O." NRC 2010 JPM S-5 November 2010 NRC ...'PM Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: MSIV Stroke Test and Limit Switch Test (NI-ST-Q26)

Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

N/A -Exam Security I Configuration Control Date Performer:

______________

TrainerlEvaluator:

____________Evaluation Method: __Perform _____

Evaluation Location:

____ Plant __-.:2'--_

Expected Completion Time: 15 minutes Time Critical Task: No Alternate Path Task: Start Time: ____ Stop Time: ____ Completion Time: ____JPM Overall Rating: Pass NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat individual competency area unsat requires a comment. Comments:

Evaluator's Signature:

_____________

_ NRC 2010 JPM S-6 November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize the simulator to IC-16S. 2. Take the simulator out of freeze. Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM / CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor

/ Evaluator:

1. Critical steps are identified in grading area as Pass/Fail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

No other verification shall be demonstrated.

References:

1. NUREG 1123,239001, A4.01, RO 4.2, SRO 4.1 2. NI-ST-Q26 NRC 2010 JPM 8-6 November 2010 Tools and Equipment:

None Task Standard:

N l-ST-Q26 completed for Main Steam Isolation Valve 112. Initial Conditions:

1. The plant is operating at 100% power. 2. All prerequisites for N1-ST-Q26 are complete.

3. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), test Main Steam Line Isolation Valve 112 in accordance with Nl-ST-Q26, Section 8.2." Performance Standard Provide repeat back of initiating cue Proper communications used for repeat Evaluator Acknowledge repeat back providing correction if necessary RECORDSTARTTTIME

__________ Obtain a copy of the reference procedure Nl-ST-Q26 obtained, precautions

& and review/utilize the correct section of the limitations reviewed procedure Prepare to initiate a Half-Scram CHANNEL Verify NO RPS Half-Scram signals Observes all scram solenoid lights energized

Notify CRO that the following steps Proper communications used

will initiate a Half-Scram Place Main Steam Isolation Valve 7% Test Test switch is rotated to the 112 Switch to the 112 Confirm 01-03 MSN 112 white test light White test light for MSN 112 is ON Confirm 01-03 MSN 112 yellow test light Yellow test light for MSN 112 is verified de-OFF energized NRC 2010 JPM -3 Grade SatlUnsat SatlUnsat PasslFaii November 2010 Performance Steps JPM steps 7 to 11 will occur in rapid sequence; expect annunciators F 1-1-7 and Fl-2-1. Notify the candidate that you will be monitoring the valve mimic board for MSIV 112. Momentarily place 01-03 MSIV -112 control switch to CLOSE position Confrrm RPS Channel 11 Half-Scram indications If F 1-1-7 is cleared before candidate completes verification, report that F 1-1-7 alarmed and cleared as expected. Confirm 01-03, MSIV-112 automatic partial closure indications The MSIV 112 mimic light came on and went off as expected. Confirm 01-03 MSIV-112 yellow illuminated Confirm 01-03 MSIV-112 automatic opening indications Place MSIV 7% Test Switch to the OFF position NRC 2010 JPM 8-6 Grade Rotates control switch for MSIV 112 PassfFail momentarily CCW to CLOSE, then releases Observes the following: CHANNEL 11 SCRAM SOLENOID SatlUnsat GROUPS 1, 2, 3, 4, white light off CHANNEL 11 B.U. SCRAM S.D.V. SatlUnsat VENT & DRAIN VALVE red light off Annunciator FI-I-7, RPS CH 11 MN SatlUnsat STM LINE 11 ISOL VALVE CLOSED, alarms SatlUnsatAnnunciator FI-2-1, RPS CH AUTO REACTOR TRIP, Observes the following: 01-03 MSIV-112 Green Light ON SatlUnsat momentarily SatlUnsat 01-03 MSIV-112 Red Light ON SatlUnsat 01-03 MSIV-112 Mimic Light Observes 01-03 MSIV 112 yellow test light SatlUnsat ON brightly Observes the following: 01-03 MSIV-112 Green Light OFF SatlUnsat 01-03 MSIV -112 Red Light ON SatlUnsat

01-03 MSIV-112 Mimic Light OFF SatlUnsat Rotates Test Switch to OFF PassfFaii November 2010 Performance Steps Inform candidate that another operator has completed the Independent Verification. Confmn 01-03 MSIV 112 White Test Light OFF Confirm 01-03 MSIV 112 Yellow Test Light OFF Depress REACTOR TRIP RESET at Panel E Fl-2-1 clears Confirm RPS Channel 11 Half-Scram indications clear Standard Observes White Test Light for MSIV -112 is OFF Observes Yellow Test Light for MSIV -112 is OFF Depresses Rx Trip RESET Button on Console Observes the following: CHANNEL 11 SCRAM SOLENOID Groups 1,2,3,4 White Light ON CHANNEL 11 BACKUP SCRAM VALVE S.D.V. VENTNDDRAIN VALVE Red Light ON Annunciator FI-1-7, RPS CH 11 MN STh! LINE 11 ISOL VALVE CLOSED, clear Annunciator Fl-2-1, RPS CH AUTO REACTOR TRIP, Grade SatlUnsat SatlUnsat PasslFaii SatlUnsat SatlUnsat SatlUnsat SatlUnsat Terminating Cue: Nl-ST-Q26 completed for MSIV 01-03. RECORD STOP TIME ____ NRC 2010 JPM 8-6 -5 November 2010 Initial Conditions:

1. The plant is operating at 100% power. 2. All prerequisites for NI-ST-Q26 are complete.

Initiating Cue: "(Operator's name), test Main Steam Line Isolation Valve 112 in accordance with ST -Q26, Section 8.2." NRC 2010 JPM S-6 November 2010 NRC JPM 8-7 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Perform a Rod Block Withdrawal Test IA W NI-ST-R4 Revision:

NRC 20 I 0 Task Number: NI A Approvals:

N/A -Exam Security I General Supervisor General Supervisor Date Operations Training ( Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:.

______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: __Perform ______ Simulate Evaluation Location:

____ Plant _____ Simulator Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: Yes Start Time: ____ Stop Completion Time:._____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluator's Recommended Start Location: (Completion time based on the start location)

NRC 2010 JPM S-7 November 2010 Simulator Simulator Set-up (if required): Initialize Simulator to IC-167. Verify malfunction RDOSR18S1 is active. Verify Trigger 1 command is set to "zdrdin=1 &&rdvposd(12S>>

767". Verify Trigger 1 event action is set to "dmfrdOSr18S1". Provide a copy of NI-ST-R4 marked up to step 8.1.6. Mark the procedure with control rods 18-51 and 34-03 selected for steps 8.1.4 and 8.1.9, respectively.

Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM Performance:

This evaluated JPM is a measure of your ability to perform this task independently.

The Control Room Supervisor has determined that a verifier is not available and that additional I concurrent verification will not be provided; therefore, it should not be requested.

Read Before Each Training JPM Performance:

During this Training JPM, applicable methods of verification are expected to be used. Therefore, either another individual or I will act as the independent/peer verifier.

Notes to Instructor

/ Evaluator: Critical steps are identified in grading area as PasslFail. During Evaluated JPM: Self verification shall be demonstrated. During Training JPM: Self verification shall be demonstrated. No other verification shall be demonstrated.

NRC 2010 JPM S-7 November 2010

References:

NUREG 1123,201003, A2.02, RO 3.7, SRO 3.8 Nl-ST-R4 NI-0P-5 Tools and Equipment:

None Task Standard:

Control Rod 18-51 re-coupled and Nl-ST-R4 section 8.1 successfully performed.

Initial Conditions: The plant is shut down. NI-ST-R4 is complete up to step 8.1.6 for the Rod Blocks Withdrawal Test. Reactor Engineering has directed using control rod 18-51 for the first rod withdrawal, and control rod 34-03 for the second attempted rod withdrawal. Reactor Engineering has directed continuous rod withdrawal for control rod 18-51 and single notch withdrawal for control rod 34-03. 5. The instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), perform Nl-ST-R4 Section 8.1, Rod Blocks Withdrawal Test, withdrawing control rod 18-51." Performance Steps Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator acknowledge repeat providing correction if RECORDSTARTTUME

__________

__ Obtain a copy of the reference procedure Nl-ST-R4 obtained, section 8.1 referenced SatlUnsat and review/utilize the correct section of the procedure Withdraw selected control rod to position Obtains NI-0P-5, references section F.l.0 SatlUnsat 48 in accordance with NI-OP-5, Control Rod Drive System 4. Verify Control Rod Power is Rotates Control Rod Power switch CW to ON PasslFaii Depress Rod Select pushbutton for control Depresses Control Rod 18-51 select button PasslFaii rod to be withdrawn on Rod Map Display atE Panel NRC 2010 JPM S-7 -3 November 201 0 Performance Steps Confirm the following: Rod Select pushbutton back lighted on Rod Map Display SELECT light illuminated for appropriate control rod at F Panel Verify no other control rods indicate Selected at Rod Map Display, OR F Panel Place and hold (4S3), Control Rod N Override Switch to NOTCH OVERRIDE position and while still holding, place and hold (4S1), Control Rod Movement switch to the ROD OUT NOTCH position The uncoupled control rod will become apparent when the rod travels beyond position 48 during the coupling check. This cues the candidate to the alternate path. IF the target position is 48, WHEN the control rod reaches 48, perform the following:

a. CRD coupling check as follows: Position 48 illuminates with red backlighting AND remains illuminated for selected rod at F Panel ROD OVERTRA VEL annunciator, F3-1-6 does NOT alarm Computer Point BO 12, CRD OVERTRA VEL does NOT alarm Release 4S1, Control Rod Movement Switch AND 4S3, Control Rod N Override Switch. Goes to OP-5 Sect. H.l8. NRC 2010 JPM S-7 Grade Observes Control Rod 18-51 select button LIT SatlUnsat Observes Control Rod 18-51 select light LIT SatlUnsat on Full Core Display Observes no other Control Rod select lights SatlUnsat LIT on Control Rod select matrix and Full Core Display Rotates Control Rod N Override Switch CW SatlUnsat and holds during Control Rod movement Rotates Control Rod Movement Switch CW SatlUnsat and hold during Control Rod movement Control Rod 18-51 withdrawn to position 48 PasslFail Observes Rod Position Indication for Control SatlUnsat Rod 18-51 illuminate 48 and then go blank Observes F3-1-6 in SatlUnsat Observes Computer Point B012 in alarm SatlUnsat Releases 4S1, Control Rod Movement Switch SatlUnsat AND 4S3, Control Rod N Override Switch Obtains OP-5 and goes to section H.l8 SatlUnsat November 2010 Performance Steps Insert Control Rod 18-51 to position 44 When Control Rod 18-51 is inserted to position 44, verifY Trigger 1 activates and deletes the rod uncoupling malfunction. ConfIrm Annunciator F3-1-6 CONTROL ROD OVERTRA VEL, clear Withdraw control rod 18-51 to position 48 Perform rod over-travel check in accordance with NI-0P-5 Confrrm the following:

ALL RODS IN light off at RSP 11

ALL RODS IN light off at RSP 12 The ALL RODS IN lights are off at the RSPs. Standard Grade Rotates Control Rod Movement Switch CCW PasslFail to move Control Rod 18-51 to position 44 Observes Annunciator F3-1-6 clear SatiUnsat Rotates Control Rod Movement Switch CW to move Control Rod 18-51 to position 48 (may also rotate Control Rod N Override Switch CW to achieve continuous rod motion) SatiUnsat Rotates Control Rod N Override Switch CW and holds during coupling check SatiUnsat Rotates Control Rod Movement Switch CW and hold during coupling check SatiUnsat Observes Rod Position Indication for Control Rod 18-51 illuminate and remain at 48 SatiUnsat Observes F3-1-6 does NOT alarm SatiUnsat Observes Computer Point B012 does NOT alarm SatlUnsat Releases 4S1, Control Rod Movement Switch AND 4S3, Control Rod N Override Switch SatiUnsat Proper communications used (GAP-OPS-Ol)

SatlUnsat NRC 2010 JPM 8-7 -5 November 2010 Performance Steps Attempt withdrawal of a second rod as follows: Select AND record rod ID Note: Control Rod 34-03 should be selected per the initial conditions, but any Control Rod other than 18-51 will allow for successful surveillance completion. Attempt to withdraw rod ConfIrm the following: Selected rod did NOT move Rod Block Monitor REFUEL ONE ROD PERMIT light -lit Annunciator F3-4-4, ROD BLOCK alarmed Select control rod 18-51 AND insert fully VerifY rod at position 00 ConfIrm the following: Rod Block Monitor REFUEL ONE ROD PERMIT light off Annunciator F3-4-4, ROD BLOCK clear ALL RODS IN light lit on RSP 11 ALL RODS IN light lit on RSP 12 The ALL RODS IN lights are lit at Standard Observes Control Rod 34-03 has been recorded Depresses a Control Rod select button other than 18-51 Rotates Control Rod Movement Switch CW Observes selected Control Rod does not move Observes Rod Block Monitor REFUEL ONE ROD PERMIT light -lit Observes F3-4-4 in alarm Depresses Control Rod 18-51 select button Rotates Control Rod Movement Switch CCW and holds until Control Rod 18-51 is fully inserted Observes Control Rod 18-51 indicates 00 Observes Rod Block Monitor REFUEL ONE ROD PERMIT light OFF Observes F3-4-4 clear Proper communications used (GAP-OPS-Ol)

Grade PasslFaii SatJUnsat PasslFaii PasslFaii SatJUnsat SatJUnsat SatJUnsat SatJUnsat Terminating Cue: Control Rod 18-51 re-coupled and Nl-ST-R4 section 8.1 successfully performed.

RECORD STOP TIME ____ NRC 2010 JPM 8-7 November 2010 Initial Conditions: The plant is shut down. NI-ST-R4 is complete up to step 8.1.6 for the Rod Blocks Withdrawal Test. 3. Reactor Engineering has directed using control rod 18-51 for the first rod withdrawal, and control rod 34-03 for the second attempted rod withdrawal. Reactor Engineering has directed continuous rod withdrawal for control rod 18-51 and single notch withdrawal for control rod 34-03. Initiating Cue: "(Operator's name), perform NI-ST-R4 Section 8.1, Rod Blocks Withdrawal Test, withdrawing control rod 18-51." NRC 2010 JPM S-7 November 2010 NRC JPM 5-8 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Vent the DryweU Prior to Personnel Entry Per NI-OP-9 Revision:

NRC 2010 Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

_________

TrainerlEvaluator:

______Evaluation Method: X Perform ___

Evaluation Location:

___ Plant X Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: No Start Time: Stop Time: Completion Time: __ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluator's Signature:

_________ Date:_____ NRC 2010 JPM 8-8 November 2010 Recommended Start Location: (Completion time based on the start location)

Simulator Simulator Set-up (if required):

1. Initialize Simulator to IC-162 (shared with JPM S-2). 2. Verify Torus pressure is 0 psig. Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM / CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional/concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor

/ Evaluator:

1. Critical steps are identified in grading area as PasslFail.

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

No other verification shall be demonstrated.

NRC 20 I 0 JPM 8-8 November 2010

References:

NUREG 1123,223001, A4.03, RO 3.4, SRO 2. Tools and Task Standard:

Drywell vented to atmospheric pressure in accordance with Initial The plant is operating at 100% power. Preparations are underway for a plant shutdown. The Torus has already been vented. NI-OP-9 is completed through Step G.1.11.3.

5. Instructor to ask operator for any questions.

Initiating Cue: "(Operator's name), vent the Drywell and secure the lineup when Drywell pressure is below 0 psig in accordance with N 1-0P-9, starting at step G .1.12." Performance Steps Grade Provide repeat back of initiating cue Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator Acknowledge repeat providing correction if RECORD START TIME Obtain a copy of the reference procedure and NI-0P-9 obtained, precautions and limitation SatlUnsat review/utilize the correct section ofthe reviewed, section G.1.0 referenced procedure Open 201-32, DW N2 VENT & PURGE Rotates 201-32 control switch CW PasslFail ISOLA nON VALVE 11 Start 201-35, DRYWELL & TORUS VENT Rotates 201-35 control switch CW PassIFail

& PURGE Verify open the following valves: 201-21, DRYWELL & TOR VENT & Observes 201-21 red light on, green light off SatlUnsat PURGE FAN INLET BV 201-22, DRYWELL & TOR VENT & Observes 201-22 red light on, green light off SatlUnsat* PURGE FAN OUTLET BV NRC 2010 JPM 8-8 -3 November 2010 Performance Steps Throttle open 201-31, DWN2 VENT & PURGE ISOLATION VALVE 12 Cue: After the low drywell pressure alann clears (K2-4-3), report drywell pressure is below o psig for purposes of this JPM (time compression used). When drywell pressures drops BELOW 0 psig, perfonn the following steps: Stop 201-35 DRY WELL & TORUS VENT & PURGE FAN Verify closed the following valves: 201-21, DRYWELL & TOR VENT & PURGE FAN INLET BV 201-22, DRYWELL & TOR VENT & PURGE FAN OUTLET BV 10. Verify closed the following valves: 201-32, DWN2 VENT & PURGE ISOLATION VALVE 11 201-31, DWN2 VENT & PURGE ISOLATION VALVE 12 Cue: Another operator will complete this procedure.

Standard Grade Rotates 201-31 control switch CW PasslFail Throttles 201-31 by using pull-to-stop feature SatJUnsat of control switch Observes Drywell pressure and when pressure SatJUnsat lowers below 0 psig continues the JPM Rotates 201-35 control switch CCW PasslFail Observes 201-21 green light on, red light off SatJUnsat Observes 201-22 green light on, red light off SatJUnsat Rotates 201-32 control switch CCW PasslFaii Rotates 201-31 control switch CCW PasslFail Terminating Drywell vented to atmospheric pressure in accordance with NI-0P-9 and lineup returned to nonna!. RECORD STOP TIME __ NRC 2010 JPM 5-8 November 2010 Initial Conditions:

1. The plant is operating at 100% power. 2. Preparations are underway for a plant shutdown.

3. The Torus has already been vented. 4. NI-OP-9 is completed through Step G.I.II.3.

Initiating Cue: "(Operator's name), vent the Drywell and secure the lineup when Drywell pressure is below 0 psig in accordance with NI-OP-9, starting at step G.1.12." NRC 2010 JPM S-8 November 2010 NRC JPM P-1 Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Lineup Lake Water to Supply the EC Makeup Tanks Revision:

NRC 2010 Using the Electric Fire Pump Task Number: NI A Approvals:

NIA -Exam Security I General Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:.

______________(RO/SRO) TrainerlEvaluator:

____________

_ Evaluation Method: ____Perform __-----'x'-"--

__ Simulate Evaluation Location: __ Plant ______ Simulator Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: Yes Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:_______ NRC 2010 JPM P-l -1 November 2010 Recommended Start Location: (Completion time based on the start location)

Screenhouse Simulator Set-up (if required):

None Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM I CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM I CRO permission.

Directions to Operators:

Read Before JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identify the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional I concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor I Evaluator:

I. Critical steps are identified in grading areas PasslFaiL

2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

No other verification shall be demonstrated.

References:

1. NUREG 1123, 207000, A2.0S, RO 4.0, SRO 4.0 2. NI-SOP-21.2, Attachment 5 3. NI-0P-21A Tools and Equipment:

None NRC 2010 JPM P-1 November 2010 Task Standard:

Emergency Condenser Makeup Tanks filled to 10 feet using the Electric Fire Pump. Initial Conditions: The plant was operating at 100% power. A control room evacuation has occurred. Emergency Condenser Makeup Tank levels are low at 6 feet. Emergency Condenser Makeup cross-connect valve, 60-13, has failed closed. Instructor to ask operator for any questions.

Initiating cue: "(Operator's name), raise Emergency Condenser Makeup Tank levels to 10 feet using the Diesel Fire Pump, in accordance with NI-SOP-21.2, Attachment 5." Performance Steps Grade Provide repeat back of initiating cue. Proper communications used for repeat back SatlUnsat (GAP-OPS-Ol)

Evaluator Acknowledge repeat providing correction if RECORDSTARTTlldE

_______ Obtain a copy of the reference procedure N I-S0P-21.2, Attachment 5 obtained SatlUnsat and review/utilize the correct section of the procedure Start at least one of the following Fire Attempts to starts the Diesel Fire Pump by one SatlUnsat Pumps (Screenhouse):

of the following means: Diesel Fire Pump (Preferred)

Rotates control switch to TEST Electric Fire Pump

Rotates control switch clockwise to the Note: If the candidate requests an additional MAN 1 position and depresses the start procedure to perform the Diesel Fire Pump start, pushbutton give them NI-OP-21A sections H.l.0 and H.2.0. The candidate will then perform additional

Rotates control switch clockwise to the and post-start actions beyond those listed in the MAN 2 position and depresses the start standard, but listed below: pushbutton Verify Diesel Fire Pump lubricant is at Full Verify Diesel Fire Pump lubricant level Verify the following: Engine coolant full Day tank level 150 gallons or greater Air tank pressures 11 and 12 > 80 psig Engine water temperature>

100°F NRC 2010 JPM P-I -3 November 2010 Performance Steps Grade Cue: Report that the Diesel Fire Pump failed to start and is now damaged. Role Play: If candidate asks for direction how to proceed, direct them to take appropriate action to raise Emergency Condenser Makeup Tank levels to 10 feet. Note: If the candidate requests an additional procedure to perform the Electric Fire Pump start, give them NI-OP-21A sections H.l.O and H.2.0. The candidate will then perform additional pre-and post-start actions beyond those listed in the standard, but listed below: Verify lubricant levels of Electric Fire Pump is at STANDSTILL LEVEL in top and bottom Bull's Eyes Verify Electric Fire Pump oil reservoir full Cue: When Electric Fire Pump control switch is taken to START, inform the candidate that the Electric Fire Pump started. Cue: If requested, Electric Fire Pump indications are: Motor current 40 amps Discharge pressure 140 psig Strainer DIP = 1.5 psid Annunciator 2-2 2 Electric Fire Pump # 1 started is alarming on Main Fire Panel 2 Note: The candidate will proceed to TB 369' for the remaining steps. PasslFaii Starts the Electric Fire Pump by rotating control switch clockwise to START NRC 2010 JPM P-l November 2010 Performance Steps Unlock and throttle open the following valves to maintain level in Emergency Condenser Makeup Tanks: 100-68, BV -FIRE WATER TO EMERG COND MIU TANK 12 Cue: Once candidate has opened 100-68, report that EC MIU Tank 12 level is 10 feet 100-69, BV -FIRE WATER TO EMERG COND MIU TANK 11 Cue: Once candidate has opened 100-69, report that EC MIU Tank 11 level is 10 feet Standard Unlocks 100-68 and removes chain from valve handwheel Rotates 100-68 handwheel CCW to open valve Observes Makeup tank level Proper communications used for repeat back (GAP-OPS-Ol)

Rotates 100-68 handwheel CW to close the valve Unlocks 100-69 and removes chain from valve handwheel Rotates 100-69 handwheel CCW to open valve Observes Makeup tank level Proper communications used for repeat back (GAP-OPS-O

1) Rotates 100-69 handwheel CW to close the valve Grade Terminating Cue: Emergency Condenser Makeup Tanks filled to 10 feet using the Electric Fire Pump. RECORD STOP TIME ____ NRC 2010 JPM P-I -5 November 2010 Initial Conditions:

1. The plant was operating at 100% power. 2. A control room evacuation has occurred.

3. Emergency Condenser Makeup Tank levels are low at 6 feet. 4. Emergency Condenser Makeup cross-connect valve, 60-13, has failed closed. Initiating Cue: "(Operator's name), raise Emergency Condenser Makeup Tank levels to 10 feet using the Diesel Fire Pump, in accordance with N1-S0P-21.2, Attachment 5." NRC 2010 JPM P-I November 2010 NRC JPM Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Transfer UPS Loads from UPS 162A to 162B Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security I eneral Supervisor General Supervisor Date Operations Training (Designee)

Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

______________

(,RO/SRO)

TrainerlEvaluator:

____________

_ Evaluation Method: ____Perform __---"=-__ Simulate Evaluation Location:

---,X=-__ Plant ______ Simulator Expected Completion Time: 20 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: _____ Completion Time: _____ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of un sat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

______________

_ Date:.______NRC 2010 JPM P-2 November Recommended Start Location: (Completion time based on the start location)

TB 261' between EDG Room and Aux Control Room Simulator Set-up (if required):

None Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM / CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identifY the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional/concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, the use of applicable methods of verification and checking are Therefore, either another individual or I will act as the independent verifier or peer checker. Notes to Instructor

/ Evaluator:

1. Critical steps are identified in grading areas PasslFail.

All steps are sequenced critical unless denoted by a 2. During Evaluated JPM:

Self checking shall be demonstrated.

3. During Training JPM:

Self checking shall be demonstrated.

Peer checking shall be demonstrated.

References:

1. NUREG 1123,212000, AZ.02, RO 3.7, SRO 3.9 2. NI-OP-40 Tools and Equipment:

None NRC 2010 JPM P-2 November 20 I 0 Task Standard:

RPS Bus 11 transferred from UPS 162A to UPS 162B, and then to I&C Bus 130A. Initial Conditions: The plant is operating at 100% power. UPS 162A is in service supplying RPS Bus 11. UPS 162B is in standby. The Electrical Safety requirements for the upcoming job have been determined to be as follows: Leather gloves Safety glasses or goggles 100% cotton long sleeve shirt and pants, OR 100% cotton short sleeve shirt and pants under resistant lab coat Instructor to ask operator for any questions.

Initiating Cues: "(Operator's name), transfer RPS Bus 11 from UPS 162A to UPS 162B per NI-0P-40 section F.l.O." Performance Steps Provide repeat back of initiating cue. Evaluator Acknowledge repeat back providing correction if necessary RECORD START TIME Obtain a copy of the reference procedure and review/utilize the correct section of the procedure Notify Control Room that RPS Bus 11 will be transferred from UPS 162A to UPS 162B At UPS 162B, verify UPS 162B in standby by observing the following: Rectifier Output approximately 40 Battery DC Input (AI) 0 amps Inverter Voltage (V2) 120 VAC Static Switch Output (V202) 120 VAC Grade Proper communications used for repeat back SatfUnsat (GAP-OPS-Ol)

NI-OP-40 obtained, precautions

& limitations SatfUnsat reviewed & section F.1.0 referenced Proper communications used for repeat back SatfUnsat (GAP-OPS-Ol)

At UPS 162B, verify UPS 162B in standby by observing the following: Rectifier Output on Rectifier Bay 1 SatfUnsat reading 40 amps Battery DC input on Inverter Bay 2 SatfUnsat reading 0 amp Inverter output on Inverter Bay 3 SatfUnsat reads 120 VAC Static Switch Output on Static Bay 4 SatfUnsat reads 120 VAC NRC 2010 lPM P-2 November 2010 Performance Steps Provide the following parameter values to the candidate:

A404 = 40 amps

Al =0 amps

V2 = I20VAC

V202 = 120 VAC Place Synchroscope Control (S701) in ON position and confirm the following:

Cue: S701 is not on the switch labeL When the candidate locates the switch, if there is any confusion, state that this is the S701 switch. UPS A Volts To Synchroscope V701 approximately 120 VAC UPS B Volts To Synchroscope V702 approximately 120 VAC Cue: UPS A Volts = l20VAC UPS B Volts = 120 VAC Note: There is not expected to be a frequency or phase difference between UPS A and UPS B. Therefore, the operator should expect the synchroscope to be at the 12 o'clock position. Synchroscope is at the 12 o'clock position If synchroscope is NOT within 10 degrees ofthe 12 o'clock position, then contact Electrical Maintenance to perform adjustment. When needle of synchroscope is within 10 degrees of 12 o'clock position, then place Manual Transfer Switch (S702) to the UPS B Supplying Load position.

Cue: S702 is not on the switch labeL When the candidate locates the switch, if there is any confusion, state that this is the S702 switch. Note: Operation of the manual transfer switch is a two handed operation NRC 2010 JPM P-2 Standard On Manual Transfer Cabinet, places Synchroscope Control toggle switch in ON Observes UPS A Volts to left of sync switch Observes UPS B Volts to right of sync switch Observes synchroscope on Manual Transfer Cabinet Marks step NI A Observes synchroscope Firmly rotates switch counterclockwise to the UPS B Supplying Load protection Grade PasslFail SatlUnsat SatlUnsat SatlUnsat PasslFail November 2010 Performance Steps Confirm load transfer by observing

UPS A Supplying Load Light OFF AND/OR

UPS 162A Static Switch Output (A202) o amps Cue: UPS A Supply Light is extinguished, A202 on UPS 162A = 0 amps

UPS B Supplying Load Light ON AND/OR

UPS 162B Static Switch Output (A202) approximately 80-90 amps Cue: UPS B Supplying Load Light is extinguished, A202 on UPS 162B = 0 amps. The control room has reported a loss of RPS Bus 11. The control room has directed you to re-energized RPS Bus 11 from I&C Bus 130A in accordance with NI-0P-40 section H.1.0. Note: The Examiner is to provide the candidate with a copy ofNI-0P-40 section H.1.0 at this point. Verify I&C Bus 130A is available to carry RPS loads. I&C Bus 130A is available to carry Notify CRO that dead bus transfer is to be performed.

Role Play: Acknowledge communication. Review list of affected systems in N SOP-40.1, Loss ofRPS Bus, for the RPS channel to be de-energized. The control room has reviewed affected systems and directs you to continue.

NRC 2010 JPM P-2 Standard At the Manual Transfer Cabinet, observes the following: UPS A Supply Load Light extinguished On Static Switch Bay 4 for UPS, Static Switch Output ammeter for UPS 162A at 0 amps Observe UPS B Supply Load Light extinguished Observe Static Switch Output ammeter for UPS 162B at 0 amps Proper communications used (GAP-OPS-Ol)

Proper communications used (GAP-OPS-Ol)

Proper communications used (GAP-OPS-OI) Grade SatlUnsati NA SatlUnsati NA SatlUnsati NA SatlUnsati NA SatlUnsat SatlUnsat SatlUnsat November 2010 Performance Steps Grade Review Attachment 6 AND current plant conditions for possible Technical Specification impact. Cue: The control room has reviewed Attachment 6 and directs you to continue. Confirm NO 112 scram signals are present OR anticipated due to testing on the opposite RPS Bus AND notify CRO that performance of the following step will initiate a 112 scram. Role Play: Acknowledge and report that no Y2 scram signals are present on RPS Bus 12. IF RPS BUS #12 to be de-energize AND SDC isolation is NOT desired, THEN perform section H.6.0. The following breakers are at the Protective Relaying Cabinet near the UPS. Open RPS BUS #11 (12) NORMAL SUPPLY FROM UPS 162 (172). Close RPS BUS #11 (12) MAINTENANCE SUPPLY FROM I&C BUS # BOA. Cue: All remaining actions will be completed by other operators.

Proper communication used (GAP-OPS-Ol)

Proper communication used (GAP-OPS-O!)

Marks step as NI A Pushes RPS BUS # 11 NORMAL SUPPLY FROM UPS 162 breaker handle up. Pushes RPS BUS # 11 MAINTENANCE SUPPL Y FROM I&C BUS # BOA breaker handle down. SatlUnsat SatlUnsat SatlUnsat Terminating Cue: Transfer ofRPS Bus 11 from UPS 162A to UPS 162B, and then to I&C Bus BOA, is complete.

RECORD STOP TIME ____ NRC 2010 JPM P-2 November 2010 Initial Conditions: The plant is operating at 100% power. UPS 162A is in service supplying RPS Bus 11. 3. UPS 162B is in standby. The Electrical Safety requirements for the upcoming job have been determined to be as follows: Leather gloves Safety glasses or goggles 100% cotton long sleeve shirt and pants, OR 1000/0 cotton short sleeve shirt and pants under flame-resistant lab coat Initiating Cues: "(Operator's name), transfer RPS Bus 11 from UPS 162A to UPS 162B per NI-0P-40 section F.l.O." NRC 2010 JPM P-2 November 2010 NRC JPM Constellation Energy Nuclear NINE MILE POINT UNIT OPERATOR JOB PERFORMANCE Title: Inject Boron Into the Reactor Using the Hydro Pump Revision:

NRC 2010 Task Number: N/A Approvals:

NIA -Exam Security I eneral Supervisor General Supervisor Date Operations Training ( Operations (Designee)

NIA -Exam Security I Configuration Control Date Performer:

______________(RO/SRO) TrainerlEvaluator:

Evaluation Method: Simulate Evaluation Location:

Plant Expected Completion Time: 25 minutes Time Critical Task: No Alternate Path Task: No Start Time: ____ Stop Time: ________ Completion Time:.______ JPM Overall Rating: Pass Fail NOTE: A JPM overall rating of fail shall be given if any critical step is graded as fail. Any grade of unsat or individual competency area unsat requires a comment. Comments:

Evaluators Signature:

________________________

_ Date:_________NRC 2010 JPM P-3 November Recommended Start Location: (Completion time based on the start location)

Reactor Building Elev. 281 Simulator Set-up (if required):

None Directions to the InstructorlEvaluator:

Prior to performance of this JPM, obtain SM / CRO general permission to open equipment cabinets and inspection covers. If opening the equipment cabinet or inspection cover will affect Tech. Spec. Operability, operational status, or the effects are unknown, obtain specific SM / CRO permission.

Directions to Operators:

Read Before Every JPM Performance:

For the performance of this JPM, I will function as the SM, CRO, and Plant Operators.

Prior to providing direction to perform this task, I will provide you with the initial conditions and answer any questions.

During task performance, I will identifY the steps to be simulated, or discuss and provide cues as necessary.

With the exception of accessing panels, NO plant equipment will be physically manipulated.

Repositioning of devices will be simulated by discussion and acknowledged by my cues. Read Before Each Evaluated JPM This evaluated JPM is a measure of your ability to perform this task independently.

The Control Supervisor has determined that a verifier is not available and that additional/concurrent verification will be provided; therefore, it should not be Read Before Each Training JPM During this Training JPM, applicable methods of verification are expected to be used. Therefore, another individual or I will act as the independent/peer verifier.

Notes to Instructor

/ Evaluator:

1. Critical steps are identified as PasslFaii.

All steps are sequenced critical unless denoted by a".". 2. During Evaluated JPM:

Self verification shall be demonstrated.

3. During Training JPM:

Self verification shall be demonstrated.

(IndependentlPeerlNo other) verification shall be demonstrated.

References:

1. NUREG 1123,295037, EA1.10, RO 3.7, SRO 2.

3. NI-EOP-3.2, Attachment Tools and Task Standard:

Boron is being pumped into the Reactor vessel using the Hydro NRC 2010 JPM P-3 November 2010 Initial Conditions: N l-EOP-3 has been entered due to a failure to scram. An RO has tried to initiate Liquid Poison from the Control Room but the pumps will not start. RWCU has isolated. Radiation Protection is providing continuous monitoring of your activities. Instructor to ask operator for any questions.

Initiating Cues: "(Operator's name), lineup and inject boron using the Hydro Pump per NI-EOP-3.2, Alternate Boron Injection, Attachment 1." Performance Steps Provide repeat back of initiating cue. Evaluator Acknowledge repeat back providing correction if necessary

_______ Obtain a copy of the reference procedure and review/utilize the correct section of the procedure Verify RWCU system is isolated Notify Rad Protection to provide continuous monitoring Once EOP Box 2 is located, prompt candidate to simulate opening the box and describe the equipment to be used. Connect air supply hose from 95-157, HSA to Alternate Boron Injection System (in overhead above Hydro Pump area), to the Hydro pump 95-157 is in the overhead above a small platform.

It is not desired for the candidate to access the valve, since this would require RP coverage for work above 6 feet. Successful completion of this JPM step will be for the candidate to indicate the general location of the valve. Once candidate indicates location of 95-157, report that the air supply hose is connected to 95-157 NRC 2010 JPM P-3 Standard Proper communications used for repeat back (GAP-OPS-Ol)

NI-EOP-3.2 obtained, Attachment 1 referenced Determines RWCU system is isolated per initial conditions Determines Rad Protection is providing continuous monitoring per initial conditions Indicates location of 95-157 Attaches one end of air supply hose to Hydro pump air inlet line Grade SatlUnsat SatlUnsat SatlUnsat SatlUnsat PasslFail PasslFail November 2010 Perfonnance Steps Connect high-pressure hose to discharge of Hydro pump Connect 2" hose from hose connection downstream of 89-20, Drain -Liquid Poison Tank, to suction of Hydro pump Unlock and verifY closed 89-21, Drain -LP Tank to 55 Gal Drum Unlock and close 42-13, BV-LP Squibb Vlv 11 Outlet 10. Unlock and close 42-14, BV -LP Squibb Vlv 12 Outlet Unlock and open 41-04, Drain Liquid Poison Tank 12. Unlock and open 89-20, Drain Liquid Poison Tank 13. VerifY Hydro Pump Air inlet Valve closed 14. Adjust regulator fully clockwise

15. Depress outer collar of adjusting downward to lock pressure 16. Connect high pressure hose (from pump discharge) to hose upstream of 42-1 0, Drain -LP Sys Before Ck Vlvs -17. Unlock and open valve 42-10, SYS HDR BEFORE CK VLVS -18. Unlock and open valve 42-09, Drain SYS HDR BEFORE CK VLVS -1 NRC 2010 JPM P-3 Standard Grade Connects one end of hose to discharge of Hydro pump Pass/Fail Connects one end of hose to hose connection downstream of 89-20 Pass/Fail Connects other end of hose to suction of Hydro pump Pass/Fail 89-21 is unlocked Pass/Fail 89-21 is closed by rotating handwheel fully clockwise Pass/Fail 42-13 (LP-Il) is closed by unlocking and turning handwheel fully clockwise (RB Elev. 298') Sat/Unsat 42-14 (LP-IO) is closed by unlocking and turning handwheel fully clockwise (RB Elev. 298') Sat/Unsat 41-04 (LP-701) is opened by unlocking and turning handwheel fully counter-clockwise Pass/Fail 89-20 is opened by unlocking and turning handwheel fully counter-clockwise Pass/Fail Hydro pump air inlet valve is closed by verifYing handwheel is rotated fully clockwise (at Hydro pump) Sat/Unsat Rotates regulator fully clockwise Pass/Fail Depresses outer collar of adjusting knob downward Sat/Unsat Connects other end of hose previously attached to Hydro pump discharge to hose connection upstream of 42-1 0 Pass/Fail 42-10 (LP-708) is opened by unlocking and Pass/Fail turning handwheel fully counter-clockwise (RB Elev. 281) 42-09 (LP-707) is opened by unlocking and PasslFail turning handwheel fully counter-clockwise (RB Elev. 281) November 2010 Perfonnance Steps 19. Open 95-157, BV-HSA to Alt Boron Injection System 95-157 is in the overhead above a small platfonn.

It is not desired for the candidate to access the valve, since this would require RP coverage for work above 6 feet. Report that 95-157 has been opened by another operator 20. Open hydro pump Air Inlet BV Hydro pump is running and indicating proper discharge pressure 21. Notifies Control Room liquid poison being injected with the Hydro Pump. RECORD STOP TIME ____ Standard Proper communications used (GAP-OPS-Ol)

Air inlet valve is opened by turning PasslFail handwheel counter-clockwise Proper communications used (GAP-OPS-Ol)

SatJUnsat NRC 2010 JPM P-3 November 2010 Initial Conditions:

I. NI-EOP-3 has been entered due to a failure to scram. An RO has tried to initiate Liquid Poison from the Control Room but the pumps will not start. 3. RWCU has isolated.

4. Radiation Protection is providing continuous monitoring of your activities.

Initiating Cues: "(Operator's name), lineup and inject boron using the Hydro Pump per NI-EOP-3.2, Alternate Boron Injection, Attachment I." NRC 2010 JPM P-3 November 2010 NMP SIMULATOR NRC Scenario 1 REV. 0 No. of Pages: 24 EPR Oscillation, Loss of P8 102, 168 and 16A, Seismic Event with Steam Leak and PREPARER DATE /0;'1)/10 VALIDATED DATE GEN OPS TRAINING DATE OPERATIONS MANAGER N/A -Exam Security DATE CONFIGURATION CONTROL N/A -Exam Security DATE SCENARIO

SUMMARY

Length: 90 minutes Initial Power Level: Approximately 85% The scenario begins at 85% power following a rod pattern adjustment.

APRM 14 is bypassed for a gain adjustment.

The crew is to place APRM 14 back in service per N1-0P-38C.

The crew will then raise power using recirculation flow in accordance with a Reactivity Maneuver Instruction.

Then, the EPR will begin to slowly oscillate, requiring the crew to enter N1-S0P-31.2 and place the MPR in service. The CRS will address the thermal limit implications of loss of the backup pressure regulator.

Next, Powerboard 102 will develop a fault. The crew will take actions to investigate the loss of the powerboard and to reenergize Powerboard 168 from Powerboard 16A and restore loads. When Powerboard 16A is reenergized, a fault will develop on the powerboard.

This will result in a loss of three Drywell cooling fans. The crew will start an additional Drywell cooling fan to address rising Containment temperatures.

The CRS must assess the impact of the equipment that is lost and enter Technical Specifications.

Next, the seismic event annunciator alarms. The crew responds using the alarm response procedure and N1-S0P-28.

Simultaneously with the seismic monitor alarm, a line break will occur in the Drywell causing slowly rising Drywell pressure, temperature and humidity.

Deteriorating Drywell conditions will require a manual scram. The crew will enter N1-EOP-2, RPV Control, and N1-EOP-4, Primary Containment Control. The crew will initiate Containment Spray when Torus pressure exceeds 13 psig (Critical Task). NRC Scenario 1 1 November 2010 Once Containment Spray is initiated, an aftershock will cause a break in the Torus. The crew must diagnose that Torus water level is lowering.

The crew may attempt to add water to the Torus. Makeup to the Torus will be unavailable due to plant conditions.

If Containment Spray Raw Water pump 121 is lined up for Torus makeup, it will trip after a time delay. As Torus level lowers, the crew must enter N1-EOP-8, RPV Blowdown, and RPV pressure must be lowered using ERVs or alternate Blowdown systems (Critical Task). Major N1-S0P-31.2, N1-S0P-1.1, N1-S0P-1, N1-EOP-1, N1-EOP-2, N1-EOP-4, and N1-EOP-8 Dynamic Mitigation Strategy Code: PC2, RPV Blowdown due to Low Torus Water Level EAL Alert EAL 3.1.1 -High Drywell Pressure Alert EAL 8,4,4 -Earthquake>

0.075g (If given report from Unit 2 seismic instrumentation. ) (Based on Emergency Director judgement, Site Area Emergency EAL 9.1.6 -Loss of Primary Containment Integrity with Loss of Rx Coolant Pressure Boundary if possible)

Termination RPV water level controlled in assigned band, RPV Blowdown in progress, Primary Containment pressure maintained per EOP-4 NRC Scenario 1 November 2010 SIMULATOR SET UP IC Number: IC-151 Presets/Function Key Assignments 1 Malfunctions: R035A, CRO Hydraulic Pump 11 Trip PRESET TC06, Electrical Pres. Regulator Fails -Oscillates TRG 1 E007, PB 102 Electrical Fault TRG2 E012A, PB 16A Electrical Fault, OT=30 TRG3 PC05, Seismic Event Triggered TRG4 EC01, Steam Supply Line Break in PC, OT=3:00, FV=12 TRG4 PC04, Torus Water Leak, OT=10, FV=25 TRG5 CT02C, CT Raw Water Pump 121 Trip, OT=45 TRG23 A007A, ERV 111 Fails Closed PRESET Remotes: None Overrides: None Annunciators: None Triggers:

a. TRG 3 -Inserts fault on PB 16A when R1042 is taken to close position Event Action:

zded602c==1 Command: None TRG 5 -Inserts second seismic event and Torus leak when Containment Spray flow is initiated Event Action: ctfdw>300 Command: None TRG 20 -Raises severity level of steam leak after the mode switch is taken to shutdown i. Event Action:

it Command: imf ec01 (0 0) 30 4:00 TRG 21 -Runs batch file to setup second seismic event when Orywell pressure exceeds 12.5 psig Event Action: dwpgas>27.2 NRC Scenario 1 November 2010 Command: bat n10scen1trg21.bat TRG 22 -Adjusts Torus leak rate once Torus water level lowers below 10.4 feet Event Action: trlevel<10.4 Command: imf pc04 (0 0) 10 TRG 23 -Trips Containment Spray Raw Water pump 121 4S seconds after it is started Event Action: hzlctpmp(14)==1 Command: None Equipment Out of Service CRD pump 11 in PTL with yellow tag APRM 14 bypassed with no tag Support Documentation RMI for power ascension with recirculation flow Miscellaneous Ensure Drywell cooling fan 11 is secured with control switch in neutral Ensure batch file "n1 Oscen1trg21.bat" is in the root batch file directory with the following commands: dmf pcOS irf pc16 (0 0) reset imf pcOS (S 10) true Protect the following equipment:

CRD pump 12 control switch, R-10S3, R-10S2 Update Divisional Status Board NRC Scenario 1 November 2010 II. SHIFT TURNOVER INFORMATION OFF GOING SHIFT: 0 N , D DATE: Today PART I: To be performed by the oncoming Operator before assuming the shift. Control Panel Walkdown (all panels) (SM, CRS, STA, RO, CRE) PART II: To be reviewed by the oncoming Operator before assuming the shift. Shift Manager Log (SM, CRS, STA)

Shift Turnover Checklist (ALL) RO Log (RO)

LCO Status (SM, CRS, STA) Lit Control Room Annunciators

Computer Alarm Summary (RO) (SM, CRS, STA, RO, CRE) Evolutions/General Information/Equipment Status: Reactor Power is approximately 85% CRD pump 11 is out of service for repairs (Day 1 of planned 2 day window; 7 day LCO per TS 3.1.6.b) APRM 14 is bypassed, gain adjustments have just been completed PART III: Remarks/Planned Evolutions:

1 Return APRM 14 to service using N1-0P-38C, Sect. H.2.0. 2. Increase Reactor power with recirculation flow per RMI. PART IV: To be reviewed/accomplished shortly after assuming the shift: Review new Clearances (SM)

Test Control Annunciators (CRE) Shift Crew Composition (SM/CRS) NAME TITLE NAME NRC Scenario 1 November 2010 ATTACHMENT 2: REACTIVITY MANEUVER INSTRUCTION Reactivity Maneuver:

Power Ascension to Rated Step: 1 INITIAL CONDITIONS/STEP DESCRIPTION I RE presence required in the Control Room? Yes_ No If YES above, RE presence not required for steps Initial conditions to be verified prior to initiation of step:

Expected Range Actual Parameter Expected Range Actual CTP 1550 -1590 MWth Description of Step: 1. Raise reactor power to 98% CTP with recirculation flow (1800 -1813 MWth) over 30 minutes. 2. Raise reactor power to rated (98% to 100%) over one hour. Critical parameters to be monitored DURING Critical parameters not used must be deleted OR marked Critical Parameter Limit Owner Frequency CTP 1850 MWth RO Continuous Lower recirculation flow II RMI evaluated against approved power profile:.

N/A O.I Other Comments:

I Step Prepared by: Step Reviewed fjr:Ick 0<fJer:m RE/STA Date RElSTAISRO Date Approval to perform Step c.;;!bhn .&.artJn I Step Shift Manager Date SRO NRC Scenario 1 6 November 2010 Critical Tasks: Given a LOCA in the Drywell, the crew will initiate Containment Sprays prior to exceeding the Pressure Suppression Pressure limit, in accordance with N 1-EOP-4. Given a lowering Torus water level, the crew will execute N1-EOP-8, RPV Blowdown, when it is determined Torus water level cannot be maintained above eight (8) feet, in accordance with N1-EOP-4.

NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Take the simulator out of freeze before the crew enters for the pre-shift walkdown and briefing.

Allow no more than 5 minutes for panel walkdown.

Event 1 -Place APRM 14 in Service OPERATOR ACTIONS CREW Conducts pre-brief, walks down the panels, assumes the shift SRO Directs restoration of APRM 14 per OP-38C, Sect H.2.0 Provides oversight for evolution RO Reviews OP-38C, Sect H.2.0 Verifies no trip signals present Places APRM BYPASS switch in neutral position Confirms APRM BYPASS light is OFF on Panel E Confirms computer printout "APRM__BYPASS NO" Confirms APRM BYPASS light is OFF on the LPRM-APRM drawer BOP Monitors plant parameters NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 2 -Raise Power with Recirculation Flow Note: I n order for event 3 to result in a thermal limit penalty, the EPR oscillation must be inserted below 90% power. OPERATOR ACTIONS SRO Directs power ascension with recirculation flow in accordance with OP-438 and the Reactivity Maneuver Instruction (RMI) Provides oversight of reactivity maneuver RO Acknowledges direction from SRO Raises recirculation flow with master recirculation flow controller Monitors APRMs Monitors recirculation flow Monitors Feedwater flow and RPV water level BOP Monitors individual RRPs for response Individual MIA-Speed Control stations trending uniformly Individual RRP indications trending normally for speed increase Monitors Feedwater controls for proper response FWP 13 FCV responding to power change RPV water level remains within program band (65" -83") NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 3 -EPR Oscillations When directed by lead examiner, insert malfunction:

TC06, Electrical Pres. Regulator Fails Oscillates TRG 1 EPR servo stroke oscillates Reactor power and pressure oscillate Expected Annunciator:

A2-4-4, Turbine Mechanical Press. Reg. In Control Role If contacted as Reactor Engineering, request to analyze thermal limits for without a backup pressure NRC Scenario 10 OPERATOR ACTIONS CREW Acknowledges I reports annunciator A2-4-4 Observes Reactor power and pressure oscillations Diagnoses EPR oscillations SRO Acknowledges report from crew May direct execution of ARP A2-4-4 May direct entry into SOP-1.5, Unplanned Power Changes Directs execution of SOP-31.2, Pressure Regulator Malfunctions References COLR restrictions for operation without a backup pressure regulator Determines thermal limit penalty must be applied to MCPR and LHGR limits with power between 45% and 90% Announce or brief crew on the change to MCPR and LHGR limits. RO Executes SOP-31.2, Pressure Regulator Malfunctions Determines EPR was originally in control Determines pressure is oscillating May lower MPR set point until MPR is in control November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 3 continued OPERATOR ACTIONS RO continued Raises the EPR setpoint to 1010 psig Works with BOP to return Reactor pressure to pre-transient value by adjusting MPR setpoint, as time permits BOP Monitors plant parameters Works with RO to return Reactor pressure to pre-transient value, as time permits NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 4 -Power Board 102 Electrical When directed by lead examiner, ED07, PB 102 Electrical TRG2 Powerboard 102 and 16B voltage lower to zero EDG 102 starts but does not close on bus Major expected annunciators:

A4-1-6, PB 102 Bus Voltage Low A4-1-8, Trans 101N Aux Fdr 102 R1012 Trip A 4-4-2, PB 16 Low Bus Voltage K3-4-3, PB 16 Bkr Lockout Relay 86-16 OPERATOR ACTIONS CREW Diagnose/report loss of PB 102 and 16B SRO Acknowledges reports Directs execution of ARP A4-1-6 Directs shutdown of EDG 102 Reviews Technical Specifications Determines limiting Technical Specifications are: TS 3.1.5, 10 hour1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months shutdown LCO for ADS TS 3.2.7, 10 hour1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months shutdown LCO for Coolant Isolation Valves NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 4 continued Role Play: If dispatched as operator to PB 102, wait 3 minutes and report R1012 tripped on overcurrent.

Role Play: If dispatched to check PB 16B, wait 2 minutes and report that Maintenance reports PB 16B appears free of faults. Role Play: If directed to verify EDG 102 shutdown wait 2 minutes and report EDG 102 is shutdown with no apparent damage. Note: Scenario continues automatically with Event 5 when R1042 control switch is taken to close. If crew does not crosstie PB 16, examiner may direct manual insertion of TRG 3. OPERATOR ACTIONS RO Monitors plant parameters BOP Executes ARP A4-1-6 Determines PB 102 cannot be energized Places breaker R1012 in PTL Places EDG 102 control switch in emergency stop Verifies CRD pump 12 running Verifies RBCLC header pressure >40 psig (May start additional RBCLC pump) Resets 86-16 Verifies open R1043 Closes R1042 NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 5 -Power Board 16A Electrical Fault The following malfunction is automatically inserted when R1042 control switch is taken to close (or manually inserted as directed by lead examiner):

ED12A, PB 16A Electrical Fault, DT=30 TRG3 Power board 16A and 16B voltage lower to zero Three Drywel/ cooling fans trip Containment temperature and pressure slowly rise Major expected annunciators:

A4-3-1, Power Bd 16 R1041 Trip A4-4-2, Power Bd 16 Low Bus Voltage L 1-4-4, Drywell-Torus Temp High L4-3-6, Drywell Cooling Fan Trip-Vib Note: If RBClC pump 12 was not started in the last event, RBClC flow will be lost in this event. This will lead to a RWCU isolation.

Note: Procedural guidance for starting Drywell cooling fan 11 may come from either OP-8 via the ARPs, or directly from EOP-4. NRC Scenario 14 OPERATOR ACTIONS CREW Diagnose/report loss of PB 16A and 168 Diagnose/report loss of three Drywell cooling fans Diagnoselreport rising Containment temperature and pressure SRO Acknowledges reports Directs execution of ARPs If Drywell average temperature exceeds 150°F, enters EOP-4 Directs lockout of Containment Spray pumps May direct emergency power reduction per SOP-1.1 May direct start of RBClC pump 12 Directs start of Drywell cooling fan 11 Reviews Technical Specifications, determines loss of EDG 102 auxiliaries, lP pump 11, and ESW pump 11 all lead to less restrictive LeOs than those of event 4 May enter N1-S0P-6.1, loss of SFP/RX Cavity level/Decay Heat Removal November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 5 continued Role Play: If dispatched as operator to PB 16, wait 2 minutes and report R1041 tripped on overcurrent.

Role Play: If dispatched as operator to investigate/restore SFP Cooling, acknowledge order but delay any action. OPERATOR ACTIONS RO Monitors plant parameters lowers power using Recirc flow per N 1-S0P-1.1, as required BOP Executes ARPs Determines Powerboards 16A and 16B cannot be re-energized May start RBClC pump 12 Starts Drywell cooling fan 11 Green flags Drywell cooling fan 13, 14, and 15 control switches to clear l4-3-6. Starts RBClC Pump Reports Containment pressure and temperature If Drywell average temperature exceeds 150°F, locks out Containment Spray pumps Starts Condensate Transfer Pump 12 May enter N1-S0P-6.1, loss of SFP/RX Cavity level/Decay Heat Removal and direct an operator to investigate SFP Cooling. NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 6 -Seismic Event and Steam Leak Requiring a Scram on Rising Drywell Pressure When directed by the lead examiner, insert CREW malfunctions:

Diagnose/report seismic annunciator PCOS, Seismic Event Triggered

Diagnose/report leak in the EC01, Steam Supply Line Break in PC, DT=3:00, Containment FV=12 TRG4 Drywel/ pressure, temperature, humidity and leak rate increase Expected Annunciators:

H2-1-6, Seismic Detection Equipment Event K2-4-3, Drywel/ Pressure High-Low F1-1-5, RPS Ch 11 Drywel/ Press High F4-1-4, RPS Ch 12 DrywelJ Press High SRO Acknowledges report of seismic event Directs execution of SOP-28, Seismic Event Acknowledges report of degrading Containment parameters Directs Crew to monitor containment parameters May direct emergency power reduction per SOP-1.1 Note: The Reactor may automatically scram on Drywell High Pressure.

Directs Reactor scram Acknowledges scram report NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 6 continued SRO continued Note: Verify the following malfunction is

Enters EOP-2, RPV Control on low automatically adjusted when the mode switch is RPV water level and high Drywell taken to SHUTDOWN:

pressure/temperature EC01, Steam Supply Line Break in PC, RT=4:00,

Answers "Are all control rods inserted IV=12, FV=30 to at least position 04?" YES Directs entry into SOP-1, Reactor Scram Directs RPV water level control 53-95" using Feedwater/Condensate and CRD Directs RPV pressure control, as required May direct MSIVs closed to minimize cooldown rate Note: May not prevent Core Spray injection until

Enters EOP-4, Primary Containment RPV pressure is reduced for the Torus leak in Control, on high Drywell pressure and event 7. May direct Core Spray pumps placed in temperature PTL if needed before EOP-1 attachment 4 jumpers

Directs lockout of Containment Spray can be installed due to scenario progression and pumps resource limitations.

If Core Spray pumps are

May direct preventing Core Spray placed in PTL, at least one Core Spray pump injection not needed for core cooling should be restarted after jumper installation for App per EOP-1 attachment 4 J water seal. When Torus pressure exceeds 13 psig or as Drywell temperature Note: When Drywell pressure exceeds 12.5 psig, approaches 300°F: verify the following are automatically loaded: Answers "Below the Containment Remote PC16, Seismic Mon Pnl Event Light Spray Initiation Limit?" YES Reset,

Directs verification of Recirc Malfunction PC05, Seismic Event Triggered, pumps tripped DT=10, on TRG 5

Directs Drywell cooling fans tripped NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 6 continued SRO continued Directs initiation of Containment Spray per EOP-1 attachment 17 (CT-1.0) Monitors Pressure Suppression Pressure limit RO When directed, lowers reactor power using recirc flow per SOP-1.1 Places Reactor Mode Switch to SHUTDOWN Provides scram report Performs scram verification actions of N1-S0P-1, Reactor Scram: Confirms all rods inserted Observes Reactor power lowering Places I RMs on range 9 Inserts IRM and SRM detectors Down-ranges I RMs as necessary Reduces Recirc Master flow to 25-43 x 10 6 1bm/hr Verifies main turbine and generator tripped Monitors RPV pressure BOP Executes SOP-28, Seismic Event May confirm seismic event indicator on J panel NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 6 continued Role Play: If contacted as Unit 2 or JAF, report that you have also experienced a seismic event and that you have confirmed the seismic event with JAF or Unit 2 (as appropriate).

Report that Unit 2 seismic recorders indicated 0.09g. OPERATOR ACTIONS BOP continued May: Contacts Unit 2 and JAF confirm seismic Notifies I&C to interpret seismic data Dispatches operators to inspect plant equipment for damage Monitors Drywell instrumentation Performs RPV water level control actions of SOP-1 : Restores RPV water level to 95" by controlling injection and rejecting through RWCU, as necessary Determines

13 FWP was running Determines RPV water level is recovering Verifies at least one Electric FW Pump running Terminates 13 FWP injection as follows:

Places FWP 13 FCV in manual and closes Disengages 13 FWP Gives 29-10, FEEDWATER PUMP 13 BLOCKING VALVE a CLOSE signal Verifies RPV water level above 53" Verifies 11/12 FWP controllers in MANUAL and set to zero output Resets HPCI signal NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 6 continued Note: Containment Spray pumps 111 and 112 are unavailable due to loss of Powerboard 102 OPERATOR ACTIONS BOP continued Places 11 or 12 FWP BYPASS Valve in AUTO, sets to 65-70" If RPV level reaches 85 inches and rising, then: Verifies off all Feedwater Pumps Secures CRD Pumps not required Maximizes RWCU reject flow Closes FWIVs if required Closes MSIVs if required Maintains RPV water level in aSSigned band RO/BOP Closes MSIVs as directed Reports when Torus pressure exceeds 13 psig or Drywell temperature approaches 300°F Verifies Recirc pumps tripped Trips Drywell cooling fans Initiates Containment Spray per EOP-1 attachment 17 Verifies started Containment Spray pumps 121 and 122 (CT-1.0) Reports Drywell pressure lowering NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 7, 8 and 9 -Second Seismic Event and Torus Leak, Trip of Containment Spray Raw Water Pump 121, ERV 111 Fails to Open Verify the following malfunctions are automatically inserted when Containment Spray flow is initiated:

pe05, Seismic Event Triggered, OT=10 PC04, Torus Water Leak, OT=10, FV=25 TRG5 Torus water level slowly lowers Torus room water level slowly rises Expected Annunciators:

K3-3-1, Torus Water Level High -Low H2-2-1, RBldgFIDrSumps 11-16 Area WtrLvl Level High Verify the following malfunction is preset: A007A, ERV 111 Fails Closed (Burned Out Solenoid)

ERV 111 fails to open Verify the following malfunction is automatically inserted if Containment Spray Raw Water pump 121 is started: CT02C, CT Raw Water Pump 121 Trip, OT=45 TRG23 Containment Spray Raw Water pump 121 trips after 45 seconds if started OPERATOR ACTIONS CREW Diagnose/report second seismic event Diagnose/report Torus water level is lowering NRC Scenario 1 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Events 7! 8 and 9 continued SRO Note: Torus makeup will be unavailable.

EOP-1 attachment 6 (low capacity makeup from Core Spray Keep-Fill) is unavailable because Core Spray is running due to high Drywell pressure.

EOP-1 attachment 18 (high capacity makeup from Containment Spray Raw Water) is unavailable due to earlier electrical power losses and the trip of Containment Spray Raw Water pump 121. Additionally, the crew may determine based on the rate of Torus water level lowering, that makeup will not be able to reverse the trend and immediately proceed to RPV Slowdown.

Note: Verify the following malfunction is automatically adjusted when Torus water level lowers below 10.4 feet: PC04, Torus Water Leak, FV=10 Note: If MSIVs have been previously closed to limit cooldown rate, they may be reopened in order to use TSVs as an alternate Slowdown system NRC Scenario 22 Acknowledges reports Re-enters EOP-4 on low Torus water level May enter EOP-5 on Hi Sump Level Evaluates ability to add water to the Torus per EOP-1 attachments 6 & 18 Determines Torus makeup is unavailable due to plant conditions May direct rapid depressurization of RPV with ECs andlor TSVs in anticipation RPV Slowdown Sefore Torus water level drops to 8 feet, re-enters EOP-2, RPV Control Determines Torus water level cannot be maintained above 8 feet Enters EOP-8, RPV Blowdown 2.0) Answers "Are all control rods inserted to at least position 04?" YES Answers "Drywell pressure?" At or above 3.5 psig Directs prevention of Core Spray injection not needed for core cooling per EOP-1 attachment 4, if not previously performed Directs EC initiation If Torus water level is above 8 feet, directs open 3 ERVs If Torus water level is at or below 8 feet, directs rapid RPV depressurization using Slowdown Systems (Detail 0) November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 7! 8 and 9 continued Role Play: If directed to investigate the Torus leak, wait 2 minutes then report no water in the Corner Rooms, but can hear leak inside the Torus Room. OPERATOR ACTIONS RO/BOP May evaluate ability to add water to the Torus per EOP-1 attachments 6 and/or 18 If attempts to lineup Containment Spray Raw Water for Torus makeup: If operating, secures Containment Spray Raw Water pump 121 Closes 80-16 Closes 80-45 Places CONT SPRAY RAW WTR 121 INTERTIE control switch to CNT SPR 111 Starts Containment Spray Raw Water pump 121 Diagnoses pump trip after time delay Determines Torus makeup is unavailable due to plant conditions Reports Torus water level approaching 8 feet May rapidly depressurize RPV with ECs and/or TBVs in anticipation of RPV Blowdown Prevents Core Spray injection not needed for core cooling per EOP-1 attachment 4 Installs EOP jumpers 17, 18, 19, 24,25 and 26 Throttles Core Spray IVs as necessary NRC Scenario 1 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 7! 8 and 9 continued Terminating Cues: RPV water level controlled in assigned band RPV Blowdown in progress Primary Containment pressure maintained per EOP-4 NRC Scenario 24 OPERATOR ACTIONS RO/BOP continued Initiates ECs (CT-2.0)

Verifies open the following valves: 39-05, EMERG CNDSR COND RET ISOLATION VALVE 11 39-06, EMERG CNDSR COND RET ISOLATION VALVE 12 If Torus water level is above 8 feet, opens 3 ERVs (CT -2.0) Recognizes/reports ERV 111 fails to open Opens additional ERVs as necessary to achieve 3 open If Torus water level is at or below 8 feet, rapidly depressurizes RPV with Blowdown Systems (CT -2.0) Turbine Bypass Valves Emergency Condensers Main steam line drains Reactor head vent valves Emergency Condenser vents SJAEs Offgas mixing jet Reactor Water Cleanup November 2010 NMP SIMULATOR NRC Scenario 2 REV. 0 No. of Pages: 25 EDG Failure, Power Reduction, Recirc Pump Failures, RPS MG Set Trip, Instrument Air Leak, A TWS, Feedwater Isolation Valves Stick PREPARER DATE VALIDATED DATE 7/20/10 GEN SUPERVISOR OPS TRAINING DATE JC/(;kvo OPERATIONS MANAGER NIA Exam Security DATE CONFIGURATION CONTROL NIA Exam Security DATE SCENARIO

SUMMARY

Length: 90 minutes Initial Power Level: Approximately 100% The crew will perform N 1-ST -M4A, a monthly surveillance on the Emergency Diesel Generator (EDG). During performance of this surveillance, the EDG governor will fail high. With the EDG exceeding the KW limit in the surveillance, the crew will trip the EDG. The SRO will address Technical Specifications for the inoperable EDG. Then, the crew will lower power to approximately 95% in preparation for Control Rod Pattern Exchange to adjust the margins to Unit 1 thermal limits. Next the Recirculation pump 12 controller output signal fails high. This results in rising recirculation flow and rising Reactor power. The crew will perform a power reduction to restore and maintain Reactor power below rated. Recirculation pump 12 trips following a time delay. The crew will enter SOP-1.3 for the tripped pump. The pump discharge valve will fail to close. The crew will take alternate action to close the pump suction valve. The SRO must address Technical Specifications to determine the resulting Reactor power limit and required actions. Then, RPS MG set 141 will trip. The crew will enter SOP-16.1 due to the resulting partial loss of Feedwater heating. The crew must recover the RPS trip bus by shifting to its alternate supply. Next, an Instrument Air leak will occur in the piping to the CRD system. The crew will insert a manual Reactor scram as CRD air pressure lowers below 60 psig (Critical Task). When the scram occurs the control rods will not fully insert. The crew must terminate and prevent injection (Critical Task). When the operator attempts to close Feedwater Isolation Valves 11 and 12, the valves will fail to isolate Feedwater flow. The crew must diagnose the NRC Scenario 2 1 November 2010 failure and place the Feedwater pumps in Pull-To-Lock to terminate feeding the RPV. The crew will lower Reactor power by inserting control rods per EOP-3.1 and/or using Liquid Poison (Critical Task). Major N1-ST-M4A, N1-0P-43B, N1-S0P-1.3, N1-0P-48, N1-S0P-16.1, 20.1, N1-S0P-1, N1-EOP-1, N1-EOP-3, N1-EOP-3.1 Dynamic Mitigation Strategy AT1, ATWS requiring RPV water level to be lowered, no Blowdown EAL Site Area Emergency per EAL 2.2.2, Failure of Automatic and Manual Scrams with Reactor Power> 6% Termination RPV water level controlled in assigned band, Reactor power < 6%, Control rod insertion in progress or complete NRC Scenario 2 November 2010 SIMULATOR SET UP IC Number: IC-152 Presets/Function Key Assignments Malfunctions: RD35A, CRD Hydraulic Pump 11 Trip Preset RR68B, RR Pump 12 M/A Station Failure -High TRG2 RR01 B, RR Pump 12 Drive Breaker Trip, DT=4:00 TRG2 RP01 B, Reactor Trip Bus Motor Generator Trips 141 TRG3 RD34, Loss of CRD Instrument Air Pres., RT=5:00, FV=20 TRG4 IA01, Loss of Instrument Air, RT=5:00, FV=40 TRG4 RD33A, Control Rod Bank Blocked Bank 1, FV=12 Preset RD33B, Control Rod Bank Blocked Bank 2, FV=12 Preset RD33C, Control Rod Bank Blocked Bank 3, FV=18 Preset RD33D, Control Rod Bank Blocked Bank 4, FV=12 Preset RD33E, Control Rod Bank Blocked Bank 5, FV=12 Preset Remotes: DG01, DG 102 Governor Speed Droop, FV=ON Preset RP02, Rx Trip Bus 141 Pwr Source, FV=maint TRG29 MS05, FW Htr String 12 Reset, FV=reset TRG30 MS02, H P FW Htr 125 Reset, FV=reset TRG 30 FW24 , Removal of HPCI Fuses FU8/FU9, FV=pulled TRG24 Overrides: 1A4S18D11149, POS_1 DG#102 GOVCS-RAISE, FV=on TRG 1 5S66DI3813 POS_1 2F29/NG03A-A POS A, FV=OFF Preset 5S6D13011, POS-21F10/31-03A POS A, FV=OFF Preset 5S5D1308, POS-2 1F10/31-03A POS A, FV=OFF Preset Annunciators: None Triggers: TRG 1 -Fails EDG 102 governor control switch to RAISE when EDG 102 power is above 2600 KW Event Action: dgemvr>2600 Command: None NRC Scenario 2 November 2010 TRG 21 -Runs a batch file which deletes override on EDG 102 governor control switch RAISE position and fails off the EDG 102 governor control switch LOWER position, when EDG 102 power is above 2950 KW Event Action: dgemvr>2950 Command: bat n1 Oscen2trg21.bat TRG 26 -Activates when ARI is overridden, RPS has been reset and SDV has drained to allow a manual scram to achieve full inward rod movement Event Action: hzlrp12g1

==1 &&Zdrrarov==1

&&anxstat2(177)==0 Command: bat n10scen2trg26.bat Equipment Out of Service CRD pump 11 in PTL with yellow tag Support Documentation N1-ST-M4A, Emergency Diesel Generator 102 and PB102 Operability completed up to step Flag the required control room switches per Attachment 8 of OP-45 for the EDG 102 surveillance. RMI for power reduction with recirculation flow Miscellaneous Protect the following:

CRD pump 12, PB 17, PB 103, Line 1, Line 4, LP pump 12, Core Spray Loops 112 and 122, EDG 103, Containment Spray Loops 121 and 122, RBEVS Loop 12, CREVS 12, Battery Charger 171A or 171B, Battery 12 Update Divisional Status Board Ensure two stopwatches are available for EDG surveillance timing Ensure batch file "n1 Oscen2trg21.bat" is in the root batch file directory with the following commands: dor 1a4s18di1149 ior 1a4s18di11410 (0 0) false Ensure batch file "n10scen2trg26.bat" is in the root batch file directory with the following commands: dmf rd33a dmf rd33b dmf rd33c dmf rd33d dmf rd33e NRC Scenario 2 November 2010 II. SHIFT TURNOVER INFORMATION OFF GOING SHIFT: 0 N DATE: Today 'D PART I: To be performed by the oncoming Operator before assuming the shift. Control Panel Walkdown (all panels) (SM, CRS, STA, RO, CRE) PART II: To be reviewed by the oncoming Operator before assuming the shift. Shift Manager Log (SM, CRS, STA)

Shift Turnover Checklist (ALL) RO Log (RO)

LCO Status (SM, CRS, STA) Lit Control Room Annunciators

Computer Alarm Summary (RO) (SM, CRS, STA, RO, CRE) Evolutions/General Information/Equipment Status: Reactor is at approximately 100% N1-ST-M4A, EDG 102 monthly surveillance test completed through step pump 11 is out PART III: Remarks/Planned Evolutions: Perform N 1-ST -M4A, starting at step 8.1.15. 2. Lower power to 95% in preparation for a Control Rod Pattern Exchange to adjust the margins to thermal limits. PART IV: To be reviewed/accomplished shortly after assuming the shift: Review new Clearances (SM)

Test Control Annunciators (CRE) Shift Crew Composition (SM/CRS) NAME TITLE NAME NRC Scenario 2 November 2010 ATTACHMENT 2: REACTIVITY MANEUVER Reactivity Maneuver:

Power Reduction from Rated Step: INITIAL CONDITIONS/STEP DESCRIPTION I RE presence required in the Control Room? Yes_ No If YES above, RE presence not required for steps Initial conditions to be verified prior to initiation of Parameter Expected Range Actual Parameter Expected Range CTP 1840-1850 Description of Step: Lower power to 95% with recirculation flow (1745 -1770 MWth) Critical parameters to be monitored DURING Critical parameters not used must be deleted OR marked Critical Parameter Limit Owner Frequen"CYT RM I evaluated against approved power profile:

N/A 0, I I Other Comments:

I Step Prepared by:

/z;;,@Jz Step Reviewed by: derek C<J)t!crfI RE/STA Date RE/STAISRO Approval to perform Step c;;John Aan7l1 I Step Completed by: Shift Manager Date SRO NRC Scenario 2 6 November 2010 Critical Tasks: CT-1.0 Given lowering CRD system air pressure, the crew will insert a manual reactor scram before control rods begin drifting, in accordance with N1-ARP-F3 and/or SOP-20.1.

CT-2.0 Given a failure of the reactor to scram with power above 6% and RPV water level above -41 inches, the crew will terminate and prevent all injection except boron and CRD, in accordance with N1-EOP-3.

CT-3.0 Given a failure of the reactor to scram with power above 6%, the crew will lower reactor power by inserting control rods or injecting boron, in accordance with EOP-3. NRC Scenario 2 7 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Take the simulator out of freeze before the crew enters for the pre-shift walkdown and briefing.

Allow no more than 5 minutes for panel walkdown.

Events 1 and 2 -EDG 102 Surveillance Test and Governor Failure NRC Scenario 8 OPERATOR ACTIONS CREW Conducts pre-brief, walks down the panels, assumes the shift SRO Directs performance of N1-ST-M4A, starting at step 8.1.15 Provides oversight for evolution Directs tripping EDG 102 when KW limit is exceeded Declares EDG 102 inoperable Reviews Technical Specifications for inoperable EDG (14 day LCO per TS 3.6.3.c) RO Monitors plant parameters Assist in timing of EDG 102 start BOP Performs N1-ST-M4A, starting at step 8.1.15 Places EDG 102 control switch to START Records time to reach running frequency and voltage Adjusts speed to 60 Hz using DIESEL GOV control switch Inserts Sync Key in R1022 SYN and places to ON Adjusts EDG to establish a slow clockwise rotation on the synchroscope November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 1 and 2 continued Expected alarm A4-2-3, DG Gen 102 Start When EDG load is raised above 2600 KW, verify the following override is automatically inserted:

1A4S18DI1149, POS_1 DG #102 GOV CS-RAISE TRG 1 EDG load rises to approximately 2900 KW When EDG load rises above 2900 KW, verify TRG 21 activates, the above override is deleted, and the following override is inserted:

1A4S180111410, POS_2 DG #102 GOV LOWER EDG load stabilizes above the surveillance test trip criteria Role Play: If contacted as an operator at the EDG, report that the EDG is shutdown with no abnormal indications.

Role Play: If contacted as Ops Management or as directed by lead examiner to facilitate next event, inform crew that a team has been dispatched to investigate the EDG 102 failure. Direct the crew to stop all actions in N1-ST-M4A and continue with the Reactor power reduction.

OPERATOR ACTIONS BOP continued When sync scope is 5 minutes before 12 o'clock, closes R1022 Adjusts DIESEL GOV control to establish at least 100 KW Adjusts VOLT ADJ RHEO GEN 102 switch to establish reactive load between 300 and 800 KV ARs to the bus Adjusts DIESEL GOV control switch to raise load to at least 2650-2750 KW Recognizes/reports EDG 102 governor malfunction Recognizes/reports EDG 102 load is above the 2845 KW trip criteria of N ST-M4A step 8.1.13 Places Diesel Generator 102 Control Switch to Emergency Stop Verifies R 1022 open NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 3 -Lower Power with Recirculation Flow OPERATOR ACTIONS SRO Directs power reduction with recirculation flow in accordance with OP-438 and the Reactivity Maneuver Instruction (RMI) Provides oversight of reactivity maneuver RO Acknowledges direction from SRO Lowers recirculation flow with master recirculation flow controller Monitors APRMs Monitors recirculation flow Monitors Feedwater flow and RPV water level BOP Monitors individual RRP for response Individual MIA-Speed Control stations trending uniformly Individual RRP indications trending normally for speed increase Monitors Feedwater controls for proper response FWP 13 FCV responding to power change RPV water level remains within program band (65" -83") NRC Scenario 2 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 4 and 5 -Recirculation Pump MA Station Fails High with Delayed Pump Trip and Recirculation Pump Discharge Valve Fails to Close When directed by lead examiner, insert malfunctions:

RR68B, RR Pump 12 MIA Failure -High RR01B, RR Pump 12 Drive Breaker Trip, DT=4:00 rRG2 Initial Response:

RRP 12 flow rises Reactor power rises Delayed Response (after 4 minutes if pump not tripped earlier):

RRP 12 trips and flow lowers Reactor power lowers Expected Annunciators:

F2-2-2, REACT RECIRC M-G SET 12 F2-3-5, REACT RECIRC PUMP M-G SET LOCKOUTREL86BLOCKED Note: When RRP 12 trips, RPV water level may exceed the high level alarm briefly. OPERATOR ACTIONS CREW Recognize/report rising Reactor power Diagnose RRP 12 flow high NRC Scenario 2 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Events 4 and 5 continued SRO Note: N1-0P-1 Precaution and Limitation states: Observe the following individual RRP 11 (12, 13, 14, 15) limits: Generator MW O. 790 Generator Amps 240 RRP Flow 16.8 x 10 6 Ibmlhr continuous

Generator Frequency 11.5 Hz to 56 Hz SRO may direct tripping the pump due to exceeding these limits for current and flow. Role Play: When contacted as Reactor Engineering, acknowledge request to verify thermal limits. Acknowledges reports May direct entry into SOP-1.5 for unplanned power change May direct entry into SOP-1.1 to restore and maintain power less than 1850 MWth, as required May direct taking RRP 12 MIA station to MAN May direct taking RRP 12 to local lock May direct tripping RRP 12 Directs entry into SOP-1.3 for RRP 12 trip Acknowledges APRMs are inoperable Acknowledges failure of RRP 12 discharge valve to close Provides oversight of reactivity manipulation while closing suction valve Reviews Tech Specs for impact of removal of pump from service and failure of discharge valve to close TS 3.1.7.e applies for partial loop operation; limits power to 90.5% until RRP 12 suction, discharge and discharge bypass valves are closed with motor breakers locked open, and RRP 12 motor breaker is opened and racked out Contacts Reactor Engineering to verify thermal limits NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 4 and 5 continued Role Play: If dispatched as operator to take RRP 12 to local lock, wait 1 minute, then report to the control room that you cannot take local control of RRMG set 12 because the Operating Lever will not move. Note: Expected annunciator F2-1-2 comes in when RRP 12 suction valve is fully closed. This annunciator clears when the suction valve is opened. NRC Scenario 13 OPERATOR ACTIONS RO Monitors plant parameters Lowers power as directed per 1.1 Monitors Reactor power and recirculation flow during closure of RRP suction valve Verifies position on four loop P/F map BOP May execute SOP-1.5 for unplanned power change Monitors RPV water level response to transient May take RRP 12 M/A station to MAN May dispatch operator to take RRP 12 to local lock May trip RRP 12 Enters SOP-1.3 for RRP trip Verifies proximity to restricted zone on four loop Power to Flow Map Notifies SRO that APRMs are inoperable Attempts to close RRP 12 discharge valve Recognizes/reports that RRP 12 discharge valve will not close Informs crew that reactor power must be monitored and maintained less than 90% Closes RRP 12 suction valve Opens RRP 12 suction valve for 2-3 seconds November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 4 and 5 continued OPERATOR ACTIONS BOP continued Notifies SRO that APRMs are operable Green flags RRP 12 control switch Places RRP 12 MIA station to MAN NRC Scenario 2 November 2010 141 INSTRUCTOR PLANT RESPONSE OPERATOR Event 6 -RPS MG Set 141 CREW When directed by the examiner,

Recognize/report RPS 12 half scram malfunction:

Diagnose trip of RPS MG set 141 RP01 B, Reactor Trip Bus Motor Generator Trips TRG3 Scram solenoid lights for RPS 12 de-energize Feedwater temperature slowly lowers Reactor power slowly rises Expected annunciators:

F4-3-2, RX. TRIP BUS M-G SET 141 TROUBLE F4-3-8, RPS CH 12 MAN REACTOR TRIP F4-2-8, RPS CH 12 AUTO REACTOR TRIP SRO Acknowledges reports Directs execution of ARP F4-3-2 Directs entry into OP-48, H.5 Directs entry into SOP-16.1 for loss of Feedwater heating May direct emergency power reduction per SOP-1.1 if needed to control Feedwater temperatures or Reactor power Provides oversight of reactivity changes RO Monitors plant parameters Lowers power per SOP-1.1 as required to control Feedwater temperatures or Reactor power Resets half scram NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 6 continued BOP

Role Play: When dispatched as operator to

investigate problem with MG Set 141, wait two minutes then report that you can smell burnt

insulation in the vicinity of MG Set 141 motor. Report that the drive motor breaker tripped on

overcurrent.

If asked, report no overvoltage trip occurred.

Role Play: When dispatched as operator to transfer Reactor Trip Bus 141 to I&C Bus 130A,

wait 2 minutes and insert remote:

RP02, Rx Trip Bus 141 Pwr Source, FV=maint TRG 29

Then report Reactor Trip Bus 141 has been energized from I&C Bus 130A, and that half scram

and Feedwater heaters can be reset. Role Play: When dispatched as operator to reset Feedwater heaters, wait 2 minutes and insert remotes: MS05, FW Htr String 12 Reset, FV=reset MS02, HP FW Htr 125 Reset, FV=reset TRG30 Then report 12 Feedwater heaters have been reset. Executes ARP F4-3-2 Dispatches an operator to investigate MG Set 141 Determines I & C Bus 130A is available Obtains SRO permission to perform dead bus transfer of Reactor Trip Bus 141 Dispatches an operator to perform dead bus transfer of Reactor Trip Bus 141 per OP-48 section H.5.0 Enters SOP-16.1 due to loss of Feedwater heating Monitors Feedwater temperatures Acknowledges that Reactor Trip Bus 141 is re-energized Coordinates with RO to reset half scram Dispatches operator to reset Feedwater heaters NRC Scenario 2 16 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 7 -Instrument Air Leak When directed by lead examiner, insert malfunctions:

RD34, Loss of CRD Instrument Air Pres, RT=5:00, FV=20 IA01, Loss of Instrument Air, RT=5:00, FV=40 TRG4 Instrument air pressure lowers Backup Instrument Air Compressor (lAC) loads Standby Instrument Air Compressor (lAC) starts CRD air pressure lowers Expected Annunciators:

L1-4-7, INST AIR BACK-UP VALVE OPEN F3-3-2, CRD CONTROL AIR PRESSURE HI-LO OPERATOR ACTIONS CREW Recognizes/reports lowering instrument air pressure Observes start of standby lAC SRO Acknowledges reports Directs execution of ARP F3-3-2 May direct entry into SOP-20.1 May direct execution of ARP L 1-4-7 Acknowledges CRD air pressure is less than 60 psig Directs manual Reactor scram (CT-1.0) Acknowledges scram report RO Monitors plant parameters Places the Mode Switch in SHUTDOWN (CT -1.0) Provides scram report NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 7 continued BOP Role Play: When directed as operator check for air leaks, acknowledge order. Wait 2 minutes and report air leakage on Reactor Building 237' West, near the HCUs. Executes ARP F3-3-2 If directed executes ARP L 1-4-7 Dispatches Operator to check for air leaks Monitors CRD air pressure Reports when CRD air pressure lowers below 60 psig NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 8 and 9 -A TWS with Failure of FW Isolation Valves to Isolate Verify the following malfunctions are preset: R033A, Control Rod Bank Blocked Bank 1, FV=12 R033B, Control Rod Bank Blocked Bank 2, FV=12 R033C, Control Rod Bank Blocked Bank 3, FV=18 R0330, Control Rod Bank Blocked Bank 4, FV=12 R033E, Control Rod Bank Blocked Bank 5, FV=12 Control rods partially insert Reactor power remains> 6% OPERATOR ACTIONS CREW Diagnose failure of control rods to insert Diagnose Reactor power above 6% NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Events 8 and 9 continued SRO NRC Scenario 2 Enters EOP-2, RPV Control, due to Reactor power above 6% when scram required Answers "Are all rods inserted to at least position 04?" NO Answers "Will the reactor stay shutdown without boron?" NO Exits EOP-2, enters EOP-3, Failure to Scram Directs ADS bypassed Directs prevention of Core Spray injection per EOP-1 att 4 May enter EOP-4 on high torus temperature Directs lockout of Containment Spray pumps except pump(s) used for torus cooling EOP-3 Level Leg Actions: Directs bypass of low-low RPV water level MSIV isolation per EOP-1 att 2 Determines Reactor power is above 6% and RPV water level is above 41 inches Directs terminate and prevent of all RPV injection except boron and CRD per EOP-1 att 24 (CT -2.0) Acknowledges failure of FW Isolation Valves 11 and 12 Directs placing FW Pumps in PTL Directs RPV level lowered to at least -41 inches November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 8 and 9 continued NRC Scenario 2 OPERATOR SRO Directs RPV water level controlled

-109 to -41 inches with Condensate/FW and CRD EOP-3 Pressure Leg Actions: If any ERV is cycling: Directs initiation of Emergency Condensers Directs ERVs opened to lower RPV pressure to less than 965 psig Directs RPV pressure controlled below 1080 psig using TBVs, ECs and/or ERVs Monitors Figure M, Heat Capacity Temperature Limit EOP-3 Power Leg Actions: Directs initiation of ARI Answers "Is the Turbine Generator On-line?" NO Answers "Reactor power?" Above 6% Directs Recirc pumps verified tripped Directs execution of EOP-3.1, Alternate Rod Insertion (CT-3.0) If power is oscillating more than 25% or before Torus temperature reaches 110°F: Records Liquid Poison tank level Directs Liquid Poison injection (CT-3.0) November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Events 8 and 9 continued SRO continued Acknowledges first Liquid Poison pump injecting RO Depresses RPS push buttons Initiates ARI Bypasses Core Spray IV interlocks per N1-EOP-1 Att 4 by installing six jumpers (17, 18, 19,24,25,26) inside Panel N Bypasses low-low RPV water level MSIV isolation per EOP-1 att 2 by installing four jumpers (1, 2, 8, 9) inside Panel N Performs EOP-3.1, Section 3 (driving rods) and/or 4 (manual scrams) (see actions below) Inserts SRMs I nserts I RMs Controls IRM recorders and range switches as required to monitor power Reports when APRMs are < 6% Reports status of control rod insertion NRC Scenario 2 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 8 and 9 continued OPERATOR ACTIONS RO continued Possible EOP-3.1 Section 3 Actions: Note: Control rods will successfully insert using RMCS. Note: RO will likely have to fully open the CRD flow control valve and/or close 44-04 in order to achieve rod movement via RMCS; these methods are preferential to closing 44-167 due to ability to perform from the control room and not preventing further scram attempts by blocking the charging water header. Note: When ARI is overridden, the scram is reset, and annunciator F4-1-1 clears, then TRG 27 will activate.

Verify this occurs and the R033 malfunctions all delete. This allows all control rods to insert on the next manual scram attempt. Verify a CRD Pump running Place Reactor Mode Switch in REFUEL Place ARI OVERRIDE switch in OVERRIDE Installed RPS jumpers (5, 6, 12, 13) Reset the scram Insert rods to 00 using EMER ROD IN starting with high power regions of core (use LPRM indications) (CT -3.0) If more drive pressure is required, then perform one of more of the following: Fully open CRD Flow Control Valve (F panel) Close 44-04, Control Rod Drive Water Cont V (F Panel) Close 44-167, Charging Water Header Blocking Valve (RB 237') Possible EOP-3.1 Section 4 Actions: Place ARI OVERRIDE switch in OVERRIDE Installed RPS jumpers (5,6, 12, 13) Reset the scram Verify open 44-167, Charging Water Header Blocking Valve (RB 237') When the SOV is drained, then initiate a manual scram (CT-3.0) NRC Scenario 2 November 2010 INSTRUCTOR ACTIONS/ PLANT RESPONSE Events 8 and 9 continued Role Play: When directed as NAO to pull HPCI fuses FU-8 and FU-9, wait one minute and insert remote: FW24, Removal of HPCI Fuses FU8/FU9, FV=pulled TRG24 Then report that HPCI fuses FU-8 and FU-9 have been pulled OPERATOR ACTIONS BOP Bypasses ADS Terminates and prevents all injection except boron and CRD per N1-EOP-1 Att 24 (CT -2.0): Closes both FEEDWATER ISOLATION Valves 11 and 12 Diagnoses failure of ISOLATION Valves 11 and 12 to close places FEEDWATER Pumps 11 and 12 in PTL Selects Manual on 11, 12 and 13 FWP Valve Control selector switches Closes 11, 12 and 13 Feedwater FCV (Knurled Knob) full counterclockwise Directs NAO to remove fuses 8 and FU-9 from Panel IS34 in the Aux Control Room Verifies closed, FEEDWATER PUMP 13 BLOCKING VALVE Verifies in MAN, FWP 11 BYPASS VALVE, AND set to zero output Verifies in MAN, FWP 12 BYPASS VALVE, AND set to zero output Informs SRO when RPV water level reaches -41 inches NRC Scenario 2 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Events 8 and 9 continued Terminating Cues: RPV water level controlled in assigned band Reactor power < 6% Control rod insertion in progress or complete OPERATOR ACTIONS BOP continued If any ERV is cycling: Initiates Emergency Condensers IF initiating EC Loop 11, places 39-05, EMERG CNDSR COND RET ISOLATION VALVE 11 control switch in OPEN IF initiating EC Loop 12, places 39-06, EMERG CNDSR COND RET ISOLATION VALVE 12 control switch in OPEN Subsequently controls EC valves per EOP-HC att 9

Manually opens ERVs to lower RPV pressure to 965 psig Controls RPV pressure below 1080 psig with TBVs, ECs and/or ERVs Verifies all Recirc Pumps tripped Initiates Liquid Poison as directed Reports initial tank level Starts Liquid Poison pump 11 or 12 Verifies RWCU isolated NRC Scenario 2 November 2010 NMP SIMULATOR NRC Scenario 3 REV. 0 No. of Pages: Powerboard 101 Fault. RBCLC TCV Failure, ERV Inadvertently Opens, Degraded 345 KV Coolant Leak in Drywell. Feedwater Pump Trip PREPARER VALIDATED Mazuroski, Alfieri, Revelle DATE _.:..:.71=20=/...:..;10=--_

GEN SUPERVISOR OPS TRAINING MANAGER N/A -Exam Security DATE ____

CONTROL N/A -Exam Security DATE ____SCENARIO

SUMMARY

Length: 90 minutes Initial Power Level: Approximately 100% The crew assumes the shift at approximately 100% power with Feedwater pump 11 out of service. They are directed to transfer the Powerboard 101 supply from the normal breaker, R1014, to the alternate breaker, R1011. Once this evolution is complete, a fault will occur causing a loss of Powerboard 101. The crew will respond to a loss of RRP 13 per SOP-1.3. Additional lost loads include Condensate Pump 12, Feedwater Booster Pump 12 and the Electric Fire Pump. After the loss of PB 101, the Reactor Building Closed Loop Cooling (RBCLC) Temperature Controller will fail such that RBCLC temperatures rise. This failure will require placing the RBCLC controller in manual and restoring the effected equipment to normal temperatures.

Next, ERV 111 opens inadvertently.

The crew will enter SOP-1.4. Power will be reduced to approximately 85% power, and fuses will be pulled. This will close the ERV (Critical Task). The SRO will enter TS 3.1.5.a, requiring a 10 hour1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months shutdown LCO. Next, a grid disturbance will result in lowering frequency and voltage on the 345KV power lines. The crew will enter SOP-33B.1 and monitor grid frequency to determine action times for tripping the turbine. As the grid continues to degrade, the crew will scram the Reactor. A coolant leak in the Drywell will develop following the scram. The crew will enter EOP-4 and re-enter EOP-2. The crew will initiate Containment Sprays to prevent exceeding Pressure Suppression Pressure, in accordance with EOP-4 (Critical Task). The remaining high pressure Feedwater pump will trip. causing RPV water level to lower to the top of active fuel (TAF). With NRC Scenario 3 1 November 2010 the degraded high pressure injection capability, the crew will enter RPV Slowdown before RPV water level drops below -109 inches, in accordance with EOP-2 (Critical Task). Major N1-0P-30, N1-S0P-1.3, N1-S0P-11.1, N1-S0P-1.4, N1-S0P-1.1, SOP-33S.1, N1-S0P-1, N1-EOP-2, N1-EOP-4, N1-EOP-1, N1-EOP-8 Dynamic Mitigation Strategy RL2, LOCA Results in RPV Water Level Selow TAF, Slowdown and Recover Level with Low Pressure Systems EAL Classification:

Alert per EAL 3.1.1, Drywell Pressure>

3.5 psig Termination RPV water level controlled in assigned band, RPV Slowdown in progress, Primary Containment pressure maintained per EOP-4 NRC Scenario 3 November 2010 SIMULATOR SET UP IC Number: IC-153 Presets/Function Key Assignments Malfunctions:

a. FW03A, Feedwater Pump Trip Preset b. ED06, PB 101 Electrical Fault, TRG 1 CW19, RBCLC Temperature Controller Failure, FV=minimum co-TRG 2 AD05, ERV 111 Failure -Opens Inadvertently TRG 3 EG11, 345 KV Power Grid Transient, RT=7:00, IV=355*, FV=345 TRG 4 RR29, RR Loop Rupture on Pump 15 Suction Line, DT=3:00, RT=7:00, FV=17 TRG5 FW03B, Feedwater Pump Trip 12, DT=6:00 TRG5 Remotes: a. AD01A, ERV 111 Fuses, TRG 27 b. AD07, Acoustic Monitor Alarm Reset, TRG 28 c. FW24, Removal of HPCI Fuses FU8/FU9, FV=puiled TRG24 Overrides: None Annunciators: None Triggers: TRG 1 -Triggers the PB 101 fault when R1011 control switch is taken to CLOSE Event Action: zded551 c==1 Command: None TRG 5 -Triggers the LOCA and the trip of Feedwater pump 12 when the mode switch is taken to SHUTDOWN Event Action: zdrpstdn==1 Command: None Equipment Out of Service Feedwater pump 11 control switch is in pull-to-Iock with a yellow clearance tag applied. Feedwater pump 11 block valve is closed with a yellow clearance tag applied. Support Documentation N1-0P-30 section H.B marked up through H.B.1. NRC Scenario 3 November 2010 Flag protected equipment for FWP 11 out of service (FWP 12, FWBP 13, CP 13, EDG 103, PB 103, PB 12). Update Divisional Status Board.

Displays current value until triggered NRC Scenario 3 November 2010 SHIFT TURNOVER INFORMATION OFF GOING SHIFT: 0 N , DATE: Today PART I: To be performed by the oncoming Operator before assuming the shift. Control Panel Walkdown (all panels) (SM, CRS, STA, RO, CRE) PART II: To be reviewed by the oncoming Operator before assuming the shift. Shift Manager Log (SM, CRS, STA)

Shift Turnover Checklist (ALL) RO Log (RO)

LCO Status (SM, CRS, STA) Lit Control Room Annunciators

Computer Alarm Summary (RO) (SM, CRS, STA, RO, CRE) Evolutions/Generallnformation/Equipment Status: Preparing to transfer Powerboard 101 supply from R1014 to R1011. Previous shift completed step H.8.1 of Feedwater pump 11 is out of service for maintenance (Day 1 of planned 3 day window, 3.1.8, 15 day LCO PART III: Remarks/Planned Evolutions:

Transfer Powerboard 101 supply from R1014 to R1011 in accordance with N1-0P-30 section H.8.0. PART IV: To be reviewed/accomplished shortly after assuming the shift: Review new Clearances (SM)

Test Control Annunciators (CRE) Shift Crew Composition (SM/eRS) TITLE NAME NAME NRC Scenario 3 November 2010 Critical Tasks: CT-1.0 Given an inadvertently open ERV at power, the crew will close the ERV or insert a manual scram prior to torus temperature exceeding 110°F, in accordance with N SOP-1.4. CT-2.0 Given a LOCA in the Drywell, the crew will initiate Containment Sprays prior to exceeding the Pressure Suppression Pressure limit, in accordance with N1-EOP-4.

CT-3.0 Given a LOCA with degraded high pressure injection capability, the crew will depressurize the RPV and inject with Preferred and Alternate Injection Systems to restore and maintain RPV water level above -84 inches, in accordance with EOP-2. NRC Scenario 3 6 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Take the simulator out of freeze before the crew CREW enters for the pre-shift walkdown and briefing.

Conducts pre-brief, walks down the Allow no more than 5 minutes for panel walkdown.

panels, assumes the shift Event 1 -Transfer PB 101 from R1014 to R1011 SRO Directs transfer of PB 101 from R1014 to R1011 per OP-30, starting at step H.8.2 Provides oversight for evolution RO Monitors plant parameters BOP Acknowledges direction to perform N1-0P-30 section H.8, starting at step H.8.2 Note: Annunciator A5-2-1 is expected while

Places PB1 01 SUPPLY BREAKER PB101 SUPPLY BREAKER INTERLOCK BY-PASS INTERLOCK BY-PASS SWITCH in SWITCH is in BYPASS BYPASS Inserts Sync. Key in Breaker R1011 Turns Sync. Key ON Confirms incoming AND running voltage NORMAL Closes Breaker R 1011 Turns Sync. Key OFF Removes Sync. Key Opens Breaker R1014 NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 2 -PB 101 Fault Verify the following malfunction automatically inserts when R1011 control switch is taken to E006, PB 101 Electrical Fault, TRG 1 Loss or voltage on PB 101 Lowering Reactor power Lowering Recirc flow Expected Annunciators:

A4-1-7, POWER BOARD 101 R1011 TRIP A4-2-7, POWER BOARD 101 LOCKOUT B6BT F2-2-3, React Recirc M-G Set 13 F2-3-5, React Recirc Pump M-G Set Lockout ReI B6 Blocked Note: The next event should be inserted when the crew closes the RRP 13 Discharge Valve. OPERATOR ACTIONS CREW Diagnose/report loss of PB 101 Diagnose/report the trip of RRP 13 SRO Acknowledges reports Directs entry into SOP-1.3 for RRP trip May direct entry into SOP-1.5 for unplanned power change Acknowledges APRMs are inoperable for scram and rod block functions of TS 3.6.2 Provides oversight of reactivity change during closure of RRP 13 discharge valve Reviews Powerboard 101 loads Reviews TS 3.1.7.e and determines Reactor power may be raised to 100% Determines thermal limits penalty NRC Scenario 3 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 2 continued Role Play: If dispatched to PB 101, wait 2 minutes to report R 1011 tripped on overcurrent and that Electrical Maintenance is at the PB investigating.

OPERATOR ACTIONS RO Monitors plant parameters Monitors Reactor power and recirculation flow during closure of RRP suction valve Verifies position on four loop P/F map BOP May execute SOP-1.5 for unplanned power change Monitors RPV water level response to transient Enters SOP-1.3 for RRP trip Verifies proximity to restricted zone on four loop Power to Flow Map Notifies SRO that APRMs are inoperable Closes RRP 13 discharge valve Opens RRP 13 discharge valve for 2-3 seconds Notifies SRO that APRMs are operable Green flags RRP 13 control switch Places RRP 13 MIA station to MAN NRC Scenario 3 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 3 -RBCLC Temperature Controller Failure When directed by lead examiner, insert malfunction:

CW19, RBCLC Temperature Controller Failure, FV=minimum TRG2 TGV 70-137 closes and bypass opens RBGLG water temperature rises Temperatures of components cooled by RBGLG rise Expected Annunciator:

H1-4-1, R BUILDING GOOLING WATER PRESS TEMP MAKEUP FLOW OPERATOR ACTIONS CREW Recognize/report rising RBCLC temperatures Diagnose failure of RBCLC automatic temperature control SRO Acknowledges report of RBCLC TCV failure Directs execution of ARP H 1-4-1 May direct entry into SOP-11.1 , RBCLC Failure Directs manual control of RBCLC temperature RO Monitor plant parameters Monitor RRPs and other components cooled by RBCLC NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 3 continued OPERATOR ACTIONS BOP Executes ARP H 1-4-1 May enter SOP-11.1, RBCLC Failure Monitors equipment cooled by RBCLC Places RBCLC Temperature Controller 70-23B in manual (OP-11, Section H.13 may be referenced) Depress the AIM Button until red LED is illuminated next to "M" Turns knurled knob as required to open/close RBCLC TCV Manually adjust RBCLC Temperature Controller to maintain RBCLC temp between srF and 9s o F NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 4 -ERV 111 Opens Inadvertently When directed by lead examiner, insert malfunction:

AD05, ERV 111 Failure -Opens Inadvertently TRG3 ERV 111 opens Reactor pressure lowers Slightly Reactor power lowers and then rises slightly Torus temperature rises Torus level rises Expected annunciators:

F1-4-8, STEAM LINE DETECTION SYS FLOW OFF NORM F2-4-1, MAIN STM LINE ELECTROMA TIC RELIEF VALVE OPEN H3-4-5, PRESS SAFETYIRELIEF VALVES FLOW NRC Scenario 12 OPERATOR ACTIONS CREW Acknowledges/reports annunciators Diagnoses ERV 111 has inadvertently opened SRO Acknowledges reports Directs entry into SOP-1.4, Stuck Open ERV Directs emergency power reduction to approximately 85% power Provides oversight for reactivity manipulation Determines that ERV 111 is inoperable per TS 3.1.5.a, requiring a 10 hour1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months shutdown Directs taking action to close ERV 111 or directs a manual scram prior to Torus temperature exceeding 11 OOF, in accordance with SOP-1.4 (CT-1.0) November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 4 continued SRO continued Acknowledges that ERV 111 has closed Enters EOP-4 if Torus temp rises above 85°F or Torus level rises above 11.25' Directs Containment Spray to PTL May direct initiation of Torus Cooling per EOP-1 att 16 or SOP-1.4 RO Performs emergency power reduction per SOP-1.1 Reduces recirculation master controller to lower power to approximately 85% Monitors APRMs Monitors recirculation flow Monitors Feedwater flow and RPV water level Monitors position on power to flow map If Torus temperature approaches 110°F, inserts manual Reactor scram (CT -1.0) NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 4 continued BOP Role Play: When directed as operator to go to Auxiliary Control Room and verify ERV 111 is open, wait one minute and report ERV 111 is open; subsequent reports on acoustic monitor status may be given immediately, with close attention paid to the actual status of the ERV. Note: Safety glasses and gloves are required for pulling fuses in F panel Role Play: If the operator is directed to pull fuses in the RB wait 3 minutes and insert remote: AD01A, ERV 111 Fuses, FV=pulled TRG27 Report fuses are pulled. Role Play: When directed as operator to reset the acoustic monitor, wait 1 minute and insert remote: AD07, Acoustic Monitor Alarm Reset, FV=reset TRG 28 Report acoustic monitor is reset. NRC Scenario 14 * * * * * * * * * *

Enters SOP-1.4 Determines ERV 111 is open using: Valve indicating lights on F panel Red ERV flow indicating light on F panel Sends an operator to the Aux Control Room to verify ERV open using Acoustic Monitor May send an operator to RB 237' to standby for pulling local ERV fuses Attempts to close ERV 111 by performing one or all of the following: Depresses ADS Timer Reset pushbuttons Cycles Control Switch for ERV 111 Pulls control power fuses F15 and F30 in F panel (ERV 111) (CT-1.0) OR Directs operator to pull ERV 111 fuses on RB 237' (CT -1.0) Checks with operator in Aux Control Room to see if ERV is still open Determineslverifies ERV closes Directs reset of acoustic monitor Notifies crew that ERV 111 has closed Monitors Torus temperature Reports if/when Torus temperature exceeds 85°F or Torus level exceeds 11.25' Places Containment Spray pumps in PTL if directed November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 4 continued OPERATOR ACTIONS BOP continued Places Torus cooling in service when directed, per SOP-1.4, att 2 or EOP-1 att 16: Close CONT SPRAY BYPASS BV(s) for selected loop Verifies closed 80-115 Verifies closed 80-114 Verifies closed Cont Spray Discharge IV for selected loop Verifies open CO NT SPRAY BYPASS BV for selected loop Fully opens80-118 Starts Containment Spray Raw Water pump in selected loop Starts Containment Spray pump in selected loop NRC Scenario 3 November 2010 I NSTRUCTOR ACTIONS/ PLANT RESPONSE Event 5 -Degraded 345KV Grid Conditions When directed by lead examiner, insert malfunction:

EG11, 345 KV Power Grid Transient, RT=7:00, IV=355, FV=345 TRG4 345KV frequency and voltage Expected A 6-3-3, 345 KV Sys Frequency High -Low A8-1-3, 115 KV Bus Low Voltage A6-2-6, 345 KV Bus Voltage High-Low Note: Turbine operational time limit changes as grid conditions continue to degrade: Variation from 60 Hz Operation Time +/- 0.6 Hz Unlimited

+/- 0.6 Hz to 1.4 Hz 90 minutes +/- 1.4 Hz to 1.9 Hz 12 minutes > +/- 1.9 Hz o minutes OPERATOR ACTIONS CREW Acknowledges/reports annunciators Diagnoseslreports lowering 345 KV grid frequency SRO Acknowledges reports Directs execution of ARPs Directs entry into SOP-33B.1, Major 345 KV Grid Disturbances Directs entry into SOP-33A3, Major 115 KV Grid Disturbances Acknowledges report that turbine operational time limit is exceeded for current frequency variation Directs manual scram Acknowledges scram report Enters EOP-2 on low RPV water level Directs SOP-1 actions Directs RPV water level controlled 95" with Condensate/FW and CRD Directs RPV pressure controlled 1000 psig with Turbine Bypass Valves or Emergency Condensers NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 5 continued Role Play: [f contacted as operator to check for abnormal indications (pump operation, Aux Control Room panels, breaker targets, etc.) due to the grid disturbance, wait 2 minutes and report there are no abnormal indications.

Role Play: If contacted as Power Control regarding grid voltage or frequency, give current values based on the simulator instructor station. Role Play: [f contacted as Power Control regarding status of offsite power, inform that thunderstorms have caused a loss of some generation and you do not currently have an estimated time for restoration.

Role Play: If contacted as Power Control regarding the low voltage post contingency alarm, inform that the low voltage post contingency alarm is NOT alarming.

OPERATOR ACTIONS RO Monitors plant parameters When directed, places Mode Switch in Shutdown Provides scram report Performs SOP-1, Reactor Scram, scram verification actions Places I RMs on range 9 Inserts IRM and SRM detectors Downranges IRMs as necessary to monitor power decrease Reduces Recirc Master flow to 43 x 10 6 Ib/hr Maintains RPV pressure below 1080 psig and in aSSigned band BOP Executes ARPs May execute SOP-33A.3 Executes SOP-33B.1 Monitors 345 KV grid frequency and determines magnitude of frequency variation Contacts Power Control and obtains 345 KV line frequency Updates crew on turbine operational time limit as grid frequency lowers May notify Power Control of turbine operational time limit Places Turbine Vibration chart recorder in fast speed NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 5 BOP continued

When grid frequency lowers to 58.1 Note: If the crew fails to insert a manual reactor Hz, notifies crew that turbine must be scram for a prolonged period of time following grid tripped and Reactor must be frequency lowering below 58.1 Hz, the lead scrammed examiner may choose to force the scenario

Performs SOP-1, Reactor Scram, progression by inserting malfunction:

level control actions: TC01, Main Turbine Trip Restores RPV level to 53-95" by contrOlling injection and rejecting through RWCU, as necessary Determines

13 FWP was running Determines RPV water level is recovering Verifies at least one Electric FW Pump running Terminates 13 FWP injection as follows: Places 13 FWP VALVE CONTROL in MANUAL and closes Disengages 13 FWP Gives 29-10, FEEDWATER PUMP 13 BLOCKING VALVE a CLOSE signal Verifies RPV water level above 53" Verifies 11/12 FWP controllers in MANUAL and set to zero output Resets HPCI signal, if required Places 12 FWP BYPASS Valve in AUTO, sets to 65-70 inches NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 5 continued OPERATOR ACTIONS BOP continued If RPV level reaches 85 inches and rising, then: Verifies all Feedwater Pumps OFF Secures CRD Pumps not required Maximizes RWCU reject flow Closes FWIVs if required Closes MSIVs if required Maintains RPV water level in assigned band NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 6 and 7 -Coolant Leak in the Drywell with a Trip of the Operating FW Pump Verify the following malfunctions are automatically inserted when the mode switch is taken to SHUTDOWN:

RR29, RR Loop Rupture on Pump 15 Suction Line, DT=3:00, RT=7:00, FV=17 FW03B, Feedwater Pump Trip 12, DT=6:00 TRG5 Initial response:

Drywell humidity, pressure and temperature rise Drywellleakage rises RPV level and pressure lower Expected annunciators:

H2-4-7, Drywell Water Leak Detection Sys K2-4-3, Drywell Pressure High-Low F1-1-5, RPS Ch 11 Drywell Press High F4-1-4, RPS Ch 12 Drywell Press High Delayed response:

Feedwater Pump 12 trips Expected annunciators:

H3-2-7, Reactor FW Pump 12 Trip Overload Suction Hi-Level H3-2-8, Reactor FW Pump 12 Aux System OPERATOR ACTIONS CREW Diagnose/report degrading containment parameters NRC Scenario 3 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Events 6 and 7 continued SRO Note: If Torus cooling is in service candidate will use EOP-1, att 17, sect. 3.2.3 NRC Scenario 21 Acknowledges reports Enters EOP-4 due to high drywell pressure and temperature Re-enters EOP-2 due to high drywell pressure and low RPV level Directs Containment Spray pumps locked out (unless pump is in Torus cooling) Acknowledges trip of Feedwater pump 12 When torus pressure exceeds 13 psig or drywell temperature approaches 300°F: Answers "Below the Containment Spray Initiation Limit?" -Yes Verifies all Recirc pumps are tripped Directs trip of all Drywell cooling fans Directs operation of Containment Spray per EOP-1 attachment 17 (CT-2.0) Evaluates/monitors position on Pressure Suppression Pressure curve Directs RPV injection with CRD and Liquid Poison May direct closure of MSIVs and pressure control using Emergency Condensers Transitions to alternate level control leg of EOP-2 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Events 6 and 7 continued SRO continued Note: Most likely injection sources are Core Spray, Condensate/Feedwater, CRD and/or Liquid Poison. Directs ADS bypassed Directs verification of EC initiation Answers "Are 2 or more Subsystems available?" -Yes (Both loops of Core Spray available) Waits until RPV water level drops to 84 inches Answers "Is any Subsystem lined up with a pump running?" -Yes (Both loops of Core Spray running) Answers "Is any injection source lined up with a pump running?" -Yes Enters EOP-8, RPV Blowdown: Answers "Are all control rods inserted to at least position 04?" -Yes Answers "Drywell pressure?" -At or above 3.5 psig Directs EC initiation Answers "Torus water level?" Above 8.0 ft Directs open 3 ERVs (CT -3.0) Verifies injection of entire contents of Liquid Poison tank Directs injection with available systems to restore and maintain RPV water level above -84 inches (CT-3.0) Directs installation of Core Spray jumpers (EOP-1 attachment

4) to allow control of Core Spray IVs NRC Scenario 3 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Events 6 and 7 continued Note: If Torus cooling is in service candidate will use EOP-1, att 17, sect. 3.2.3 NRC Scenario 3 OPERATOR ACTIONS SRO continued Transitions back to normal level control leg of EOP-2 Directs restoration of RPV level to 53-95 inches RO/BOP Updates crew on reactor and containment parameters Locks out Containment Spray pumps Recognizes/reports trip of Feedwater pump 12 Maximizes RPV injection with CRD and Liquid Poison When torus pressure exceeds 13 psig or drywell temperature approaches 300°F: Verifies all Recirc pump are tripped Trips all Drywell cooling fans Initiates Containment Spray per N1*EOP-1 attachment 17 (CT-2.0) Verifies started two Containment Spray pumps (111 or 122 preferred) May start additional Containment Spray and Containment Spray Raw Water pumps as necessary Bypasses ADS Verifies EC initiation Verifies 39-05 and 39-06 open or previously open November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Events 6 and 7 continued RO/BOP continued Note: Available injection systems include: Condensate/FW CRD Core Spray Containment Spray Raw Water valved to Core Spray Fire Water Liquid Poison Terminating Cues: RPV water level controlled in assigned band RPV Blowdown in progress Primary Containment pressure maintained per EOP-4 May secure ECs for pressure control If RPV water level is above 5", then closes 39-05 and/or 39-06 If RPV water level is below 5", then closes EC steam IVs When RPV water level drops below 84 inches: Initiates ECs Verifies open 39-05 Verifies open 39-06 Opens 3 ERVs (CT -3.0) Verifies Liquid Poison injection to inject entire contents of Liquid Poison tank Injects with available systems to restore and maintain RPV water level above -84 inches (CT-3.0) Bypasses Core Spray IV interlocks per N1-EOP-1 Att 4 by installing six jumpers (17,18,19,24,25,26) inside Panel N Throttles Core Spray IVs as necessary to control RPV water level Restores RPV water level to 53-95 inches NRC Scenario 3 November 2010 NMP SIMULATOR NRC Scenario 4 REV. 0 No. of Pages: Generator Voltage Regulator Failure, RRP Seal Failure, FWLC Instrument

Failure, RWCU Break in Reactor Building, TBVs Fail PREPARER DATE VALIDATED Mazuroski, Alfieri, Revelle DATE 7/21/10 GEN SUPERVISOR OPS TRAINING OPERATIONS J DATE 1/1 (W;'2o/e;)

MANAGER N/A --Exam Security DATE CONFIGURATION CONTROL N/A -Exam Security DATE SCENARIO

SUMMARY

Length: 90 minutes Initial Power Level: Approximately 85% The crew assumes the shift at approximately 85% power. They are directed to remove Condensate Pump 13 from service immediately for maintenance due to a motor oil leak. After the pump has been removed from service, the crew will conduct a rod pattern exchange.

During the rod pattern exchange, the Main Generator Auto Voltage Regulator will fail. The crew will diagnose the failure and take manual control of generator voltage and restore the correct generator output. Following the Main Generator Auto Voltage Regulator malfunction, the inner seal will fail on Reactor Recirculation Pump 11. A few minutes later, the outer seal will fail, affecting drywell leakage. The crew will remove the pump from service and isolate it. The SRO will review Technical Specifications for dryweilleakage and partial loop operation.

Next, a Reactor pressure transmitter will fail low. This will affect Feedwater level control. The crew will be required to shift to manual Feedwater level control. The crew may then shift reactor pressure/level columns and return to automatic Feedwater level control. Technical SpeCifications must be addressed due to the affect on the HPCI mode of Feedwater.

A Reactor Water Cleanup system line break will occur in the Secondary Containment downstream of the Supply Isolation Valves. Reactor Water Cleanup will fail to isolate on high area temperature.

The crew will attempt to isolate the system, but the valves will fail to fully close. This break will require a scram (Critical Task) and RPV blowdown (Critical Task) due to exceeding the Maximum Safe Value for general area temperatures.

The Turbine Bypass NRC Scenario 4 1 November 2010 Valves will fail to open throughout the transient, complicating pressure control and limiting anticipatory blowdown.

Major N1-0P-15A, N1-0P-5, N1-ARP-A7, N1-S0P-1.2, N1-S0P-16.1, EOP-5, N1-EOP-2, and N1-EOP-8 Dynamic Mitigation Strategy Code: SC1, Primary System Leak in Secondary Containment, Blowdown Required EAL Classification:

Site Area Emergency per EALs 3.4.1 (RWCU Isolation Failure and Release Outside Primary Containment) and/or 4.1.1 (Primary System Discharging Outside Primary Containment, >135°F in Two General Areas) Termination Criteria:

RPV water level controlled in assigned band, RPV Blowdown in progress NRC Scenario 4 November 2010 SIMULATOR SET UP IC Number: IC-154 Presets/Function Key Assignments Malfunctions: CT01D, CT Pump 122 Trip Preset EG02, Generator Auto Voltage Regulator Fails -Increase TRG 1 RR06A, RR Pump 11 Lower (Inner) Seal Failure, RT=3:00, FV=75 TRG2 RR07A, RR Pump 11 Upper (Outer) Seal Failure, DT=4:00, RT=5:00, FV=60 TRG2 RR92, Rx Vesl Pres Xmr 36-31 (Local-FW Control) Fails Low TRG3 CU11, CU Coolant Leak Outside of Drywell, FV=45 TRG4 CU14, CU Isolation Valves Stuck Open Preset TC12, All Bypass Valves Fail--Closed, FV=100 TRG5 Remotes: FW01C, Condensate Pump 13 Discharge Valve 50-12, FV=close TRG30 Overrides: None Annunciators: None Triggers: TRG 11 -Re-inserts RRP 11 seal failure at 10% when RRP 11 suction and discharge green light are energized Event Action: hzlrrv02c( 1 )== 1 &&hzlrrv03c( 1 )==1 Command: imf rr06a (0 0) 10 TRG 12 --Re-inserts RRP 11 seal failure at 10% when RRP 11 suction and discharge green light are energized

i. Event Action: hzlrrv02c(1

)==1 &&hzlrrv03c(1

)==1 it Command: imf rr07a (00) 10 TRG 21 -Energizes RWCU IV 33-01 green light when control switch is taken to close i. Event Action: zdcu301 it Command: ior 9ds51 1051912 (00) TRG 22 --Energizes RWCU IV 33-02 green light when control switch is taken to close NRC Scenario 4 November 2010

i. Event Action:

it Command: ior 9ds531051914 (0 0) TRG 23 -Energizes RWCU IV 33-04 green light when control switch is taken to close Event Action: zdcu304c==1 Command: ior 9ds55105200 (00) true Equipment Out of Service Containment Spray pump 122 control switch in PTL with yellow tag Containment Spray pump 122 suction valve closed with yellow tag Support Documentation N1-0P-15A section H.9.0, completed through step 9.2 RMI and Rod Movement Sheets for sequence exchange Miscellaneous Ensure FWLC is selected to column 11 Protect the following equipment:

Containment Spray Pumps 111, 112, 121, EDG 102, PB 102 Update Divisional Status Board NRC Scenario 4 November 2010 SHIFT TURNOVER INFORMATION OFF GOING SHIFT: 0 N , D DATE: PART I: To be performed by the oncoming Operator before assuming the Control Panel Walkdown (all panels) (SM, CRS, STA, RO, CRE) PART II: To be reviewed by the oncoming Operator before assuming the shift. Shift Manager Log (SM, CRS, STA)

Shift Turnover Checklist (ALL) RO Log (RO)

LCO Status (SM, CRS, STA) Lit Control Room Annunciators

Computer Alarm Summary (RO) (SM, CRS, STA, RO, CRE) Evolutions/General Information/Equipment Status: Reactor power is approximately 85% Containment Spray Pump 122 is out of service for maintenance (Day 1 of planned 4 day window, TS 3.3.7.b 15 day LCO applies) Condensate pump 13 motor has an oil leak PART III: Remarks/Planned Evolutions: Shutdown Condensate pump 13 per OP-15A section H.9.O. Perform Control Rod Sequence Exchange per RMI. PART IV: To be reviewed/accomplished shortly after assuming the shift: Review new Clearances (SM)

Test Control Annunciators (CRE) Shift Crew Composition (SM/CRS) TITLE NAIVIE NAME NRC Scenario 4 November 2010 ATTACHMENT 2: REACTIVITY MANEUVER Reactivity Maneuver:

Rod Sequence Exchange Step: 1 INITIAL CONDITIONS/STEP DESCRIPTION RE presence required in the Control Room? Yes_ No ./ If YES above, RE presence not required for steps _' Initial conditions to be verified prior to initiation of step: Parameter Expected Range Actual Parameter Expected Range Recirc Flow 56 60 Mlbm/hr 57 Mlbm/hr Actual Description of Step: Complete attached rod movement sheets. Critical parameters to be monitored DURING Step: Critical parameters not used must be deleted OR marked N/A Critical Parameter Limit Owner Frequency CTP 1850 MWth RO Continuous RMI evaluated against approved power profile:.

Other Comments:

N/A O. Power may rise to as high as 95% on highest reading APRM by the end of the rod withdrawals.

Step Prepared by:

RE/STA I Date Step Reviewed by:

RE/STAISRO Date Approval to perform Step c;'blm Aamn I 'Vqdqp Step Completed Shift Manager Date SRO Date NRC Scenario 4 6 November 2010 Insert FROM: 48 TO: Initials Control Rod Move From TR.H I 5D Complete To 14-27 48 08 38-27 48 08 Additional Qualified ndividual confirms rod mH position by reselecting rods [or by using 00-7 printout Prepared by ,& Veriledby.4.)J_,£,.,_________NMP1 ROD MOVEMENT SHEET NI Check Coupling (as Expected)

Check ,/ NlA ,/ NlA Dale Date N/A N/A Ul Ub lU 02 06 Step: .1 o ..... o N ... E Comments z 14 lU II 20 JU J4 jij 42 40 1 2 o""'" .r:::ns 11 r::: 07 en 03 ()14 18 22 26 30 34 38 42 46 0:: Z

NMP1 ROD MOVEMENT SHEET Withdrawal Step: 1 o o t...FROM: 04 TO: 08 N E Control Rod Inlials I Move NI Check Coupling FulOut From Comments Complete (as Expected)

Check Light To z N/A 14-35 04 08 NlA 38-35 04 08 NlA N/A 38-19 04 08 NlA NIA 14-19 04 08 NlA N/A Q) Alkiitional QUalified UL Ub 10 14 18 .22 26 3D 34 38 42 46 ndividual confirms rod 51 position by reselecting rods 47 lor by using 00-7 printout 43 39 35 1 2 31 27 23 19 4 3 o 15 15 ((I 11 11 Prepel\'!d by .& £d Date 01 07 C/)03 03 ()

________________

___ Date 02 06 10 14 18 22 26 30 34 38 42 46 Z Critical Tasks: Given an un-isolable RWCU leak outside primary containment and one general area temperature above the maximum safe limit, the crew will insert a manual reactor scram, in accordance with N1-EOP-S. Given an un-isolable RWCU leak outside primary containment and two general area temperatures above the maximum safe limit, the crew will execute N 1-EOP-8, RPV B lowd own , in accordance with N1-EOP-S.

NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Take the simulator out of freeze before the crew enters for the pre-shift walkdown and briefing.

Allow no more than 5 minutes for panel walkdown.

Event 1 -Shutdown Condensate Pump 13 Role Play: When directed to slowly close 50-12, acknowledge order, wait approximately 1 minute and insert remote: FW01C, Condensate Pump 13 Discharge Valve 50-12, FV=close TRG30 Then report 50-12 is 90% closed. OPERATOR ACTIONS CREW Conducts pre-brief, walks down the panels, assumes the shift SRO Directs shutdown of Condensate pump 13 per OP-15A, Section H.9.0 Provides oversight for evolution Enters T.S. 3.1.8.b for removal of a redundant HPCI component from service, 15 day LCD RO Monitors plant parameters BOP Acknowledges direction to shutdown Condensate pump 13 Notifies SRO to enter LCO for HPCI Monitors Feedwater Booster pump suction pressure (computer point 0454 -123 psig) Directs operator in field to slowly close 50-12, BV -COND PMP 13 DISCHARGE WHEN the Condensate Pump 13 discharge valve is 90% closed, places the pump control switch in PTL NRC Scenario 4 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 1 continued Role Play: If contacted as operator to report local FW pump suction pressure, immediately report FW pump suction pressure based on simulator value of FWBP discharge pressure minus 50 psig (-300 psi). Role Play: When directed to fully close 50-12, acknowledge order, wait approximately 15 seconds and report valve is fully closed. OPERATOR ACTIONS BOP continued Verifies: Maximum Condensate pump motor current s 135 amps Minimum FW Booster pump suction pressure within the acceptable range of curve shown in OP-15C attachment 4 (minimum pressure at 85% flow (-S mlbs/hr) is 72 psig) Minimum FW pump suction pressure;::::

200 psig Directs operator in field to fully close 50-12, BV -COND PMP 13 DISCHARGE Verifies no abnormal Main Condenser air in-leakage is occurring NRC Scenario 4 November 2010 14-19 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 2 -Rod Sequence Exchange SRO Note: Lead examiner may move to the next event once sufficient action is observed on the reactivity manipulation.

Note: RMI includes rods 14-35, 38-35, 38-19, and Directs performance of Control Rod Sequence Exchange per RMI and OP-5 Provides oversight for reactivity manipulation RO Acknowledges direction from SRO Obtains copy of RIVII Withdraws control rods per rod movement sheets and OP-5 Turns control rod power on Selects rod Uses CONTROL ROD MOVEMENT switch to notch rod Monitors APRM indications BOP Monitors Feedwater controls for proper response FWP 13 FCV responding to power change RPV water level remains within program band (65" -83") NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 3 -Generator Auto Voltage Regulator Fails High When directed by lead examiner, insert malfunction:

EG02, Generator Auto Voltage Regulator Fails Increase TRG 1 Amplidyne output meter indication rises Exciter output voltage rises Generator field current rises Expected Annunciators:

A3-1-1, TURB GEN EXC. TRANS. 1 TEMP RECORDER (first) A7-2-6, GEN VOL T REGULA TOR TRIP (second) OPERATOR ACTIONS CREW Recognize/diagnose Auto Voltage Regulator Failure SRO Acknowledges reports Directs ARP response Directs adjustment of generator reactive load RO Monitors plant parameters Places VOLTAGE REG TRANSFER switch to OFF Adjusts generator reactive load using exciter field rheostat to 60 MVARS to the bus (OP-32) NRC Scenario 4 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 3 continued BOP Role Play: When contacted as Power Control, acknowledge the voltage regulator is in manual and request NMP1 supply 100 MVARS to the bus while in manual voltage control. Role Play: If directed to investigate the voltage regulator failure, wait 3 minutes and report no visible problems at the exciter or breaker cabinet. Executes ARP A7-2-6 for voltage regulator trip Confirms computer point FOgg Monitors generator output voltage Coordinates with RO to place VOLTAGE REG TRANSFER switch to OFF Notifies Power Control that voltage regulator is in manual May refer to S-ODP-OPS-0112, Site Power Operations and Interface, attachment 4 Coordinates with RO to adjust generator reactive load Enter OP-32, Sect H.5, raise Vars using Exciter Rheostat to 100 Mvars to the bus. NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 4 -RRP 11 Seal Failures When directed by lead examiner, insert malfunctions:

RR06A, RR Pump 11 Lower (Inner) Seal Failure, RT=3:00, FV=75 RR07A, RR Pump 11 Upper (Outer) Seal Failure, DT=4:00, RT=5:00, FV=60 TRG2 Initial response:

RRP 11 LP seal pressure rises Delayed response:

RRP 11 HP seal pressure lowers RRP 11 LP seal pressure lowers OW temp, pres and humidity slowly rise DW leakage rises Expected F2-1-1, REACT RECIRC PUMP-MOTOR H2-4-7, Drywel/ Water Leak Detection Sys Note: Verify TRG 11 and TRG 12 automatically re-insert malfunctions RR06A and RR07A at 10% when RRP 11 suction and discharge valve green lights energize.

OPERATOR ACTIONS CREW Diagnoses/reports RRP 11 inner seal failure Diagnoses/reports RRP 11 outer seal failure (later) Recognizes/reports degrading Primary Containment parameters (later) SRO Acknowledges reports Directs execution of ARP F2-1-1 Directs entry into SOP-1.2, RRP Seal Failure Reviews Technical Specifications Determines Drywelileakage rates are affected in Tech Spec 3.2.5 Determines Tech Spec 3.1.7.e requires power be maintained

< 90.5% until the pump isolation is complete Verifies power < 90.5% Provide oversight of reactivity change during evolution NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 4 continued Note: SOP-1.2 defines a seal failure as catastrophic if it results in a noticeable rise in OW pressure or floor drain leakage. Note: Closing RRP suction and discharges valves during this event is an approved two-handed manipulation.

Note: Allow Reactor water level to recover to normal value before moving to next event in order to avoid a high level Turbine trip. Also allow the crew to isolate RRP 11 to prevent the seal leak from causing a high drywell pressure scram. OPERATOR ACTIONS RO Monitors plant parameters Monitor total recirculation flow and APRM power levels while RRP 11 is being shutdown and isolated Verifies position on four loop Power to Flow Map BOP Executes ARP F2-1-1 Enters SOP-1.2, RRP Seal Failure Initially answers "Did both seals fail on a single Recirc pump?" NO Monitors OW equipment drain tank level Contacts Engineering for evaluation Monitors RRP 11 seal indications for signs of degradation Determines 2 nd seal is failing Re-enters SOP-1.2 Answers "Did both seals fail on a single Recirc pump?" YES Answers "Is failure catastrophic?" YES Places RRP 11 control switch to STOP Closes RRP 11 bypass valve Simultaneously closes RRP suction and discharge valves Verifies proximity to restricted zone using four loop Power to Flow Map Monitors containment parameters NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 5 -RPV Pressure Transmitter Failure CREW Resulting in FWLC Deviation When directed by lead examiner, insert malfunction:

RR92. Rx Vesl Pres Xmtr 36-31 (Local-FW Control) Fails -Low TRG3 RPV pressure instrument indicates downscale Controlling RPV water level instrument indicates lower than actual Feedwater flow rises RPV water level rises Expected Annunciator:

F2-3-3, REACT VESSEL LEVEL HIGH-LOW Note: This event may cause a turbine trip and subsequent reactor scram on high RPV water level if Feedwater flow is not controlled properly.

In the event of a scram, TRG 4 should be immediately inserted and the scenario will continue in event 6. Note: N1-ST-DO contains acceptance criteria for GEMAC level instrument deviation with regards to HPCloperability. Diagnoses/reports failure of pressure instrument Diagnoses/reports failure of FWLC Pressure/Level Column SRO Acknowledges reports Directs entry into SOP-16.1 for failure ofFWLC Directs placing FWLC in manual Directs shifting Reactor Pressure/Level Columns per OP-16, section F.10.0 Reviews Tech Spec 3.1.8 for affect of level instrument deviation on HPCI operability, as time permits NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE Event 5 continued Note: Switching level columns may result in Annunciator F2-3-3, REACT VESSEL LEVEL HIGH-LOW, due to circuit interruption.

Note: The same channel of level and pressure should be selected OPERATOR ACTIONS RO Monitor plant parameters If directed to shift FWLC pressure/level columns: Verifies Feedwater lineup Verifies BOP has manual control of FWLC Shifts reactor pressure and level columns using the key lock switches on the E Panel Coordinates with BOP to return FWLC to auto: Places FEEDWATER MASTER CONTROL M/A station mode switch in MAN Nulls FWP 13 VALVE CONTROL by adjusting the FEEDWATER MASTER CONTROL station output with the manual knob until the deviation meter indicates 50% on FWP 13 VALVE CONTROL GEMAC Directs BOP to place FWP 13 FCV M/A Station in BAL Controls RPV water level with the manual knob at the FEEDWATER MASTER CONTROL Nulls FEEDWATER MASTER CONTROL setpoint error by adjusting SP ADJUST knob to null the deviation meter (upper, vertical) at midpoint NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 5 RO continued Places FEEDWATER MASTER CONTROL MIA station mode switch in AUTO or SAL Confirms system response by adjusting the SP ADJUST knob on FEEDWATER MASTER CONTROL to maintain RPV water level BOP Enters SOP-16.1 due to failure of FWLC Takes manual control of Feedwater pump 13 FCV Manually restores RPV water level to normal band If directed to shift FWLC pressurellevel columns:

Coordinates with RO to return Note: Once the FWP 13 VALVE CONTROL MIA FWLC to auto: STATION mode switch is in SAL, manual FWLC is

Places FWP 13 VALVE shifted to the RO at E-panel CONTROL MIA STATION mode switch in SAL NRC Scenario 4 November 2010 INSTRUCTOR PLANT RESPONSE OPERATOR Events 6. 7 and 8 -RWCU Leak in the CREW Secondary Containment.

Failure of the RWCU

Diagnoses/reports leak from RWCU Isolation Valves. Failure of TBVs into secondary containment When directed by lead examiner, insert

Diagnoses/reports RWCU failed to malfunction:

isolate CU11, CU Coolant Leak Outside of Orywell

Diagnoses/reports failure of TBVs TRG 4 after the scram Rising temperatures, pressures and radiation levels in the Secondary Containment RBEVS auto-starts RBVS isolates RWCU IVs fail to close on isolation signal Expected Annunciators:

H1-4-8, AREA RADIATION MONITORS L 1-4-3, REACT BLDG VENT RAD MONITOR OFF NORMAL L1-3(4)-6, EMER VENT SYS CHANNEL 11(12) RELA Y OPERA TE K3-3-4, CLEAN-UP SYS LEAK AREA T HI L 1-3-3, CONTINUOUS AIR RAD MONITOR Later Reactor Building DIP goes to Zero Verify the following malfunctions are preset: CU14, CU Isolation Valves Stuck Open TC12, All Bypasss Va.lves Fail -Closed, FV=100% NRC Scenario 4 20 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 6, 7 and 8 continued SRO Acknowledges reports Enters EOP-S, Secondary Containment Control, on high Reactor Building Vent rad levels, high Reactor Building area temperatures loss of DIP and rad levels Directs RWCU system isolation Directs Reactor Building evacuation Acknowledges report that RWCU failed to isolate both automatically and manually Directs dispatching of an operator and RP tech to obtain general area temperatures and radiation levels in the Reactor Building When Reactor Building Ventilation exhaust radiation exceeds S mRlhr, directs verification of RB Vent isolation and RBEVS initiation Determines area temperatures and radiation levels are above setpoints in Tables T and R, and transitions to EOP-S circle 27 Determines a primary system is discharging into the Reactor Building and the discharge cannot be isolated, and transitions to EOP-S circle 28 Before any area temperature or radiation level reaches 13SoF or 8 Rlhr, respectively: Directs manual scram (CT-1.0) Acknowledges scram report NRC Scenario 4 November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE OPERATOR ACTIONS Event 6, 7 and 8 continued SRO continued Note: Turbine Bypass Valves are unavailable for pressure control due to a malfunction Note: AntiCipatory blowdown is likely to be directed from EOP-2 once one Reactor Building General Area temperature is above 135°F with a second temperature trending towards 135°F. Enters EOP-2, RPV Control on low RPV water level Answers "Are all control rods inserted to at least position 04?" YES Directs entry into SOP-1, Reactor Scram Directs RPV water level control 53-95" using Feedwater/Condensate and CRD Directs RPV pressure maintained

<1080 psig using Emergency Condensers May direct anticipatory blowdown with Emergency Condensers with cooldown in excess of 100°F Ihr Acknowledges reports of Reactor Building temperatures and radiation levels When report is received that 2 General Areas temperatures are above 135°F, enters EOP-8, RPV Blowdown Answers "Are all control rods inserted to at least position 04" YES Answers "Drywell pressure?" <3.5 psig Directs initiation of Emergency Condensers Answers "Torus water level?" >8 ft Directs open 3 ERVs (CT-2.0) NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 6, 7 and 8 continued Note: No General Area temperature information is available until an operator has been dispatched to the Reactor Building to monitor area temperatures.

The timeline of field reports may be adjusted by examiner as necessary for evaluation purposes.

RO Makes evacuation announcements due to steam leak Places Reactor Mode Switch to SHUTDOWN Provides scram report Performs scram verification actions of N1-S0P-1, Reactor Scram: Confirms all rods inserted Observes Reactor power lowering Places IRMs on range 9 Inserts IRM and SRM detectors Down-ranges IRMs as necessary Reduces Recirc Master flow to 25-43 x 10 6 lbm/hr Verifies main turbine and generator tripped Controls RPV pressure as directed using Emergency Condensers BOP Attempts to isolate RWCU by closing 33-01 R,33-02R and 33-04R Recognizes/reports failure of RWCU IVs (33-01 R,33-02R and 33-04R) to close Dispatches operator and RP tech to obtain Reactor Building General Area temperatures and radiation levels Notifies crew of reports on General Area temperatures and radiation levels NRC Scenario 4 November 2010 INSTRUCTOR ACTIONSI PLANT RESPONSE OPERATOR ACTIONS Event 6, 7 and 8 continued BOP continued Role Play: When directed as operator and RP tech to obtain General Area temperatures and radiation levels in the Reactor Building:

Wait 4 minutes and report RB 261' east side temperature is 125°F and rising, radiation level is 100 mr/hr and rising. Also report that you see steam coming from the area of the RWCU rooms. Note: When one general area temperature is reported above 135°F and a second general area temperature is reported as approaching 135°F, the crew is likely to perform an anticipatory blowdown per EOP-2. Wait 2 more minutes and report RB 261' east side temperature is 137°F and rising, radiation level is 150 mr/hr and rising. Report RB 261' west side temperature is 123°F and rising, radiation level is 35 mr/hr and riSing. Wait 3 more minutes and report RB 261' east side temperature is 145°F and rising. radiation level is 175 mr/hr and rising. Report RB 261' west side temperature is 136°F and rising, radiation level is 45 mr/hr and rising. NRC Scenario 24 Performs RPV water level control actions of SOP-1 : Restores RPV water level to 53-95" by controlling injection and rejecting through RWCU, as necessary Determines

13 FWP was running Determines RPV water level is recovering Verifies at least one Electric FW Pump running Terminates 13 FWP injection as follows: Places FWP 13 FCV in manual and closes Disengages 13 FWP Gives 29-10, FEEDWATER PUMP 13 BLOCKING VALVE a CLOSE signal Verifies RPV water level above 53" Verifies 11/12 FWP controllers in MAN UAL and set to zero output Resets HPCI signal Places 11 or 12 FWP BYPASS Valve in AUTO, sets to 65-70" If RPV level reaches 85 inches and rising, then: Verifies off all Feedwater Pumps Secures CRD Pumps not required Closes FWIVs if required Closes MSIVs if required Maintains RPV water level in assigned band November 2010 INSTRUCTOR ACTIONS! PLANT RESPONSE Event 6, 7 and 8 continued OPERATOR ACTIONS BOP continued Notifies crew of reports on General Area temperatures and radiation levels When EOP-8, RPV Slowdown, is entered: Verifies Emergency Condensers in service Verifies open 39-05 Verifies open 39-06 Opens 3 ERVs (CT -2.0) Terminating Cues: RPV water level controlled in assigned band RPV Slowdown in progress NRC Scenario 4 November 2010

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