ML110820645

___ 12.

___ 13.

1ES-1.1

___ 14.

___ 15.

1C1.4

___ 16.

T.S. 3.4.14

___ 17.

1C28.2

___ 18.

47009-0501

___ 19.

47003-0503

___ 20.

___ 21.

On the NIS panel, verify Scaler Timer power switch is in Off position.

Set Turbine Control HMI Displays as follows:

___ 1.

U1 E-H Turb Cont STA 2 (48087) to:

Control Valve Overview

___ 2.

U1 Turb Aux Cont (48088) to:

Turb Overview

___ 3.

U1 E-H Turb Cont STA 1 ( 48086) to:

On Line Control DEHC alarms cleared Turbine Control in FSP mode

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Post-Scenario Checklist EOOS computer is cleared of information added during the scenario Computer generated PINGP 577 cleared.

Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

47015-0103

___ 7.

1C12.1

___ 8.

47013-0305

___ 9.

1C51.2

___ 10.

1C4 AOP1

___ 11.

___ 12.

___ 13.

1ES-1.1

___ 14.

___ 15.

1C1.4

___ 16.

T.S. 3.4.14

___ 17.

1C28.2

___ 18.

47009-0501

___ 19.

47003-0503

___ 20.

___ 21.

Protected equipment tags in place:

___ 1.

None Remove Caution Tags to the following control switches:

___ 1.

None Board-mounted EAL Table is cleaned All books, note pads, and calculators put away End Of Day Checklist Signs/placards removed and put away unless normal simulator configuration Floor PCs logged off if simulator will not be used again that day Instructor station returned to normal with all books, paper, and etc. put away Headsets turned off and put away if simulator will not be used again that day Simulator reset to IC-10 unless another IC will be used for further training Simulator placed in DORT if simulator will not be used again that day Recorder power "OFF" if simulator will not be used again that day

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RETENTION: 7 Days UNIT 1 LPEO / PEO TURNOVER LOG DATE:

DAY/NIGHT SHIFT: Day CAT 1 VENT OPENINGS: 0 ft2 SYSTEM CONDITION: GREEN SAFEGUARDS EQUIPMENT OOS/TECH SPEC REQUIRED ACTION STATEMENTS None PROTECTED EQUIPMENT None RAD MONITORS OOS ANNUNCIATORS OOS OUTSTANDING SPS FIRE DET / PROT EQP IMPAIRMENTS OTHER EQUIPMENT OOS / STATUS TWO Condensate pumps AND TWO Heater Drain pumps are running.

MAJOR EQUIPMENT REPAIRED / RETURNED TO SERVICE OPERATIONAL PLANS FOR COMING SHIFT Place 12 MFW pump in service, 12 MFW pump recirc valve is NOT blocked open.

Raise power from 50% to 60%.

Xenon building in, need to dilute 40 gals approximately every 10 minutes.

An Extra Operator has been stationed at the Heater Drain Panel to address Heater Drains during power ascension.

NEW PROCEDURES / INSTRUCTIONS

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Reactivity Plan The crew has been directed to Start 12 MFWP, then raise reactor power from 50% to 60%.

Prior to simulator:

verify the reactivity plan completed by the off going reactor operator complete a Pre-Job Brief Current conditions are:

Power level: 50%

Xenon: Increasing, diluting 40 gals approximately every 10 minutes Control Rod Position: Bank D @ 173 steps Boron Concentration: 1023 ppm Core Exposure: 10,000 MWD/MTU NO Fuel Conditioning requirements exist Target: Power Level: 60%

Rate: 0.5% /minute Control Mode: First Stage Pressure (FSP) with Rod Control in Manual Boration/Dilution: 60 gal dilutions every two minutes Reactivity Prediction:

Change in Power Defect: 142 pcm Differential Boron Worth: -7.8 pcm/ppm Calculated RCS PPM change: 18.2 ppm Assumed half rods and half RMU addition Calculated Boric Acid / Reactor Makeup Water addition: 9 ppm change = 272 gals RMU Calculated final Control Rod Position : Bank D @ 182 steps

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Simulator Scenario Development Checklist Mark with an X Yes or No for any of the following. If the answer is No, include justification for the no answer or the corrective action needed to correct the discrepancy after the item.

The scenario contains objectives for the desired tasks and relevant human performance tools.

Yes No X

The scenario identifies key parameter response, expected alarms, and automatic actions associated with the induced perturbations.

Yes No X

The scenario content adequately addresses the desired tasks, through simulator performance, instructor-led training freezes, or both.

Yes No X

Plant PRA initiating events, important equipment, and important tasks are identified.

Yes No X

Turnover information includes a Daily At Power or Shutdown Safety Risk Assessment.

Yes No X

The scenario contains procedurally driven success paths. Procedural discrepancies are identified and corrected before training is given.

Yes No X

The scenario guide includes responses for all anticipated communications to simulated personnel outside the Control Room, based on procedural guidance and standard operating practices. Include estimated completion times and/or notes for use of time compression.

Yes No X

The scenario includes related industry experience. SOER, SER and similar OE recommendations are clearly identified and fully addressed.*

Yes No X

The scenario guide incorporates verification of Operator Fundamental application.*

Yes No X

Training elements and specific human performance elements are addressed in the scenario critique guide to be used by the critique facilitator. The critique guide includes standards for expected performance.*

Yes No X

For evaluations, it has been verified that without operator action the critical tasks will be failed.

Yes No X

Developer and Reviewer: Once checklist is completed and deficiencies are corrected, sign the cover page.

For evaluations these items may be marked NO without justification.

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Simulator Scenario Validation Checklist Mark with an X Yes or No for any of the following. If the answer is No, include an explanation after the item.

1. The desired initial condition(s) could be achieved.

Yes X

No

2. All malfunctions and other instructor interface items were functional and responded to support the simulator scenario.

Yes X

No

3. All malfunctions and other instructor interface items were initiated in the same sequence described within the simulator scenario.

Yes X

No

4. All applicable acceptance criteria were met for procedures that were used to support the simulator scenario.

Yes X

No

5. During the simulator scenario, observed changes corresponded to expected plant response.

Yes X

No

6. Did the scenario satisfy the learning or examination objectives without any significant simulator performance issues, or deviations from the approved scenario sequence? If learning objective(s) could not be satisfied, identify the objectives in the Simulator Action Request Yes X

No

7. Evaluation: The simulator is capable of being used to satisfy learning or examination objectives without exceptions, significant performance discrepancies, or deviation from the approved scenario sequence.

Yes X

No Discrepancies noted (Check none or list items found)

X None SMAR = Simulator Action Request SMAR:

SMAR:

Comments:

Validator: Sign the cover page only after noted discrepancies are corrected or compensatory actions are taken to ensure quality training.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 1 of 23 Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

2010 ILT NRC SIMULATOR EVALUATION #2 SEG TITLE:

2010 ILT NRC SIMULATOR EVALUATION

2 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME:

1.5 HOUR Additional site-specific signatures may be added as desired.

Developed by:

Mike Fish 12/11/09 Instructor Date Reviewed by:

John DuBose 12/13/09 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

John DuBose 12/13/09 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

During all plant operating conditions, the crew will demonstrate the ability to monitor and operate the plant within the limits of the Operations Manuals and Technical Specifications.

When presented with various scenario events, the crew will demonstrate the ability to respond to the events using appropriate operating and administrative procedures to return the plant to stable conditions.

Learning Objectives:

1.

During all plant operating conditions, demonstrate the ability to perform communications, verification practices (STAR and peer checks), procedure use, alarm response, reactivity control, and crew briefs in accordance with Operations Standards and Expectations.

2.

Diagnose and respond to N44 failing high per C47 and 1C51.

3.

Diagnose and respond to a Main Feedwater pump trip per C47.

4.

Diagnose and respond to Loss of Instrument Bus 113 per 1E-0, 1ES-0.1, C47 and 1C20.8 AOP1.

5.

Diagnose and respond to MSLB per 1E-0, 1E-2, 1E-1, and 1FR-P.1.

6.

Diagnose and respond to a failure of both MSIVs to close per 1E-0.

Prerequisites:

1.

NONE Training Resources:

1.

Full Scope Simulator

2.

Lead Evaluator

3.

Booth Operator

4.

Backup Communicator

References:

1.

NONE Commitments: 1.

NONE Evaluation Method:

This is an evaluation scenario

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Operating Experience:

None - Evaluation Scenario Related PRA Information:

Initiating Event with Core Damage Frequency:

None Important Components:

11 CC pump Important Operator Actions with Task Number:

None

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE:

None. This is an evaluation scenario and no credit will be taken for tasks performed.

GENERAL EXPECTATIONS Over the duration of the scenario, monitor crew performance for adherence to the conduct of operations standards and Operations department Standards and Expectations:

Communications Verification Practices (STAR and Peer Checks)

Procedure Use Alarm Response Reactivity Control Crew Briefs Performance for adherence to administrative procedural requirements and operations management expectations:

Reportability of the malfunction or event Notifications to the Operations Manager and NRC Resident Inspector per SWI-O-28 Notification to the Duty Station Manager per operations management request Tech Spec implementation; interpretation; and documentation of decision made, actions taken, and the basis for decisions made and actions taken

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QUANTITATIVE ATTRIBUTES (Use this form for Evaluations only.)

Malfunctions:

Before EOP Entry:

1. N44 Power Range NI Fails High.

2. 11 Main Feedwater Pump Trip.

3. Loss of Power to Instrument Bus 113.

After EOP Entry:

1. 11/12 MSIVs Fail to Automatically Close.

Normal Events:

1. None Abnormal Events:

1. N44 Power Range NI Fails High.

2. 11 Main Feedwater Pump Trip.

2. Reactor Trip due to loss of Instrument Bus 113.

3. Loss of Power to Instrument Bus 113.

Major Transients:

1. MSLB - 11 Steam Generator faults inside Containment.

Critical Tasks:

1. E-0 -- P: Manually close MSIVs before transition out of E-0.

2. E TCOA4 Control AFW flow within 38 minutes following a Reactor Trip.

(SWI O-35 identified Time Critical Operator Action).

3. E-2 -- A: Isolate the faulted STEAM GENERATOR before transition out of E-2.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 6 of 23 2010 ILT NRC SIMULATOR EVALUATION #2, Rev. 0 Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

SCENARIO OVERVIEW:

INITIAL CONDITIONS:

1. This scenario can be run from the following Standard (Specific) IC sets:

IC-25

2. The following equipment is OOS:

11 CC pump SEQUENCE OF EVENTS:

Event 1: N-44 Power Range NI Fails High N-44 will fail high, resulting in automatic inward rod motion.

The crew will respond per C47 and 1C51 to remove the instrument from service.

Event 2: 11 Main Feedwater Pump Trip 11 Main Feedwater Pump trip.

The crew will respond per 1C4 AOP1.

The crew will respond per C47.

Event 3: Reactor Trip due to loss of Instrument Bus 113 The loss of power to Instrument Bus 113 will a cause reactor trip due to 2 of 4 logic with power range NIs due to N-44 being OOS.

The crew will respond to the reactor trip per 1E-0 and transition to 1ES-0.1.

Event 4: Loss of Power to Instrument Bus 113 The SS will have the Lead Operator perform actions in 1C20.8 AOP1 to restore power to Instrument Bus 113 from Panel 117.

Event 5: MSLB 11 Steam Generator faults inside Containment.

The crew will respond per 1E-0, 1E-2, 1E-1, and 1FR-P.1.

Event 6: 11/12 MSIVs fail to automatically close

During the Main Steam Line Break, 11/12 MSIVs fail to automatically close.

The crew will manually close 11 MSIV using Attachment L of 1E-0.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 7 of 23 2010 ILT NRC SIMULATOR EVALUATION #2, Rev. 0 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES INITIAL CONDITIONS:

Standard IC-25 Mode: 1 Exposure: MOC Power: 71%

Boron: (CB): 706 Temperature: 556°F Pressure: 2235 psig Xenon: Increasing Rods: Bank D @ 187, all others at 228 Generator: ~388 MWe Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SCENARIO TIME-LINE:

SEQ RUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES SEQUE CE OF EVEN N

TS / INST

1.

SIMULATOR SET UP

a. Set up the simulator to IC-25

b. Enter the malfunctions, remotes, and overrides, as specified by the "Simulator Input Summary."

c. Complete the "Simulator Setup Checklist.

d.

Place Turbine Control in FSP mode and NOT on VPL.

e.

Ensure VCT level is approximately 30-40% and VCT pressure is 25-35#, divert VCT to CVCS HUT to adjust level if needed.

f.

Place Rod Control in AUTO.

g.

Run simulator for at least 10 minutes and allow plant to stabilize and acknowledge heater drain alarms.

h.

Maintain Tave and Tref matched.

i.

Place simulator back in FREEZE once plant appears to be stable.

2.

Simulator Pre-brief:

a.

The Simulator Pre-Brief is conducted prior to the crew entering the simulator.

3.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

a.

Verify crew performs walk down of control boards and reviews turnover checklists.

CREW Review the following with the off-going operator:

Unit 1 LPEO / PEO Turnover Log PRA printout Walk-down the control boards and ask questions as appropriate Retention: Life of Plant

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ARIO TIME-LINE:

SCEN SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 1

4.

When the crew has assumed the duty, and at the discretion of the Lead Evaluator, enter the N44 Power Range NI high failure (Relative Order 1, Event Trigger

1)

5.

The following indications will be observed:

a.

Indicator N-44 indicates off-scale high

b.

Control Rods insert in AUTO

c.

Annunciators:

1) 47013-0101, NIS POWER RANGE POSITIVE FLUX RATE CHANNEL ALERT

2) 47013-0102, NIS POWER RANGE HI SETPOINT CHANNEL ALERT

3) 47013-0103, NIS POWER RANGE OVERPOWER ROD WITHDRAWAL STOP

4) 47013-0203, NIS POWER RANGE CHANNEL DEVIATION

5) 47013-0303, COMPUTER ALARM DELTA I CHECK TYPER (Possible)

6) 47013-0403, COMPUTER ALARM FLUX TILT CHECK TYPER (Possible)

If directed as I&C to trip bistables, report that 2 I&C technicians will be available in 45 minutes.

(Note: the OTDT and OTDT rod stop bistables will not be tripped during this scenario. )

RO LEAD LEAD SS NOTE: As a plant stabilization action the crew is expected to take rod control to manual once instrument malfunction is diagnosed.

47013-0101, NIS POWER RANGE POSITIVE FLUX RATE CHANNEL ALERT Determine initiating channel(s) by observing NIS indications If due to power range channel failure, Then refer to 1C51 1C51.4, INSTRUMENT FAILURE GUIDE Place rod control in manual and maintain Tave at Tref using rods. Adjust turbine load as necessary o Rod withdrawal will not be possible until after Rod Stop is bypassed Enter T.S. LCO 3.3.1 Condition A and Table 3.3.1-1 Functions 2a, 2b, 3a, 3b, 6, 16b.1, 16c, 16d, 16e.

Enter TRM TLCO 3.2.1 Remove N-44 from service per C51 Restore Tavg to Tref using control rods and then place rod control to AUTO Direct I&C to trip the bistables Initiate temporary logs and required surveillance procedures per C51 Initiate repair activities Retention: Life of Plant

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ARIO TIME-LINE:

SCEN SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 2 6.

When the crew has completed actions for the N44 failure, and/or at the discretion of the Lead Evaluator, then enter the 11 Feedwater Pump trip (Relative Order 2, Trigger 2)

a. If asked to investigate the 11 FW pump lockout, acknowledge the request THEN wait 3 minutes and report overcurrent relay is actuated on BKR-11-3, 11 feedwater Pump.

b. If contacted as Operations Management, acknowledge the report of the failure, and agree to make other notifications to the NRC, Duty Station Manager, etc. as asked.

If contacted as the FIN Team Supervisor, inform the crew that you will write a work order and assign an Electrical Supervisor to investigate.

LEAD LEAD/

RO 47010-0101, 11 FEEDWATER PUMP LOCKED OUT If reactor power is greater than 85%, then trip the reactor and go to 1E-0.

If turbine power is greater than 330 MWe, then reduce to less than 330 MWe per 1C1.4 AOP1.

1C1.4 AOP1, RAPID POWER REDUCTION If any reactor or turbine trip setpoint is reached, then verify the reactor is tripped and go to 1E-0.

Place or verify the following control systems in automatic or control in manual per C7:

o Rod control o Steam dump o Pressurizer pressure control o Pressurizer level control.

o Place pressurizer heaters ON.

o Reduce turbine load to the desired value using one of the following methods:

Automatic Manual Borate the RCS as necessary to maintain control rods above the insertion limit and control delta I within limits.

Retention: Life of Plant

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O TIME-LINE:

SCENARI SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 3

7.

When the crew has completed the actions associated with the 11 FW pump trip, and/or at the discretion of the Lead Evaluator, enter the Reactor trip due to Loss of Instrument Bus 113 (Relative Order 3, Event Trigger 3).

8.

The reactor will receive a automatic trip due to N44 being OOS and the loss of the instrument bus. 2 of 4 PR NI will reach the reactor trip setpoint due to the failure.

9.

When called as the Turbine Building Operator to verify the status of Turbine Building Roof Exhausters, report that the Turbine Building Roof Exhausters are all secured.

10. Upon hearing the announcement of Reactor Trip, or when called as the Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, enter CAEP - Att E-0 to start the isolation (Relative Order 3a). When the isolation is complete, inform the crew that MSRs are isolated.

NOTE: The crew will perform actions to restore power to Instrument Bus 113 once the plant is stable in 1ES-0.1. The SS should assign the LEAD operator to perform actions in 1C20.8 AOP1 and the SS should continue in 1ES-0.1.

CREW CREW CREW 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify Reactor Trip Verify turbine Trip Verify Both Safeguards Buses - Energized Check if SI is actuated o Transition to 1ES-0.1, Reactor Trip Recovery, due to no SI.

Continue actions in 1ES-0.1 1ES-0.1, REACTOR TRIP RECOVERY Announce Unit 1 Reactor Trip.

Transfer Steam Dump To Pressure Mode.

Check RCS Temperatures.

Check Cooling Water Header Pressures.

Notify turbine Building Operator To Isolate Unit 1 MSRs Per Attachment J.

Check FW Status.

Verify All Control Rods Inserted.

Note: Due to the loss of Instrument Bus 113 the crew must take manual control of Pressurizer level and pressure. Crew might refer to 1C51.3 for guidance prior to re-energizing Instrument Bus 113.

Check PRZR Level Control.

Check PRZR Pressure Control.

Check SG Levels.

Verify Offsite Power Available.

Check RCP Status - At Least One Running.

Check If Source Range Detectors Should Be Energized.

Maintain Stable Plant Conditions.

Open Turbine Drain Valves.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS T RESPONSES EXPECTED STUDEN Align AMSAC/DSS System.

Perform Administrative Notifications.

Check If AFW Pumps Can Be Stopped.

Align Generator Breakers.

Complete Part A Of PINGP 662, Reactor Trip Report Perform Applicable Shutdown Steps Of 1C1.4.

Determine If Natural Circulation Cooldown Is Required.

Retention: Life of Plant

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IO TIME-LINE:

SCENAR SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 4

11. The crew will respond to the Loss of Instrument Bus once the plant is stable in 1ES-0.1.

12. If contacted as the Turbine Building operator concerning the status of the Instrument Inverter 13, wait 3 minutes and report the following:

a.

Inverter 13 is de-energized with no apparent cause.

13. When Turbine Building operator is contacted to transfer the source breaker to the INTERRUPTABLE PANEL 117 position for Instrument Bus 113 enter (Relative Order 4, Event Trigger 4) in 1 minute.

LEAD LEAD 47005-0307, PNL 113 INSTR BUS 111(BLUE) LOSS OF VOLTAGE Verify bus undervoltage Place Rod Control in MANUAL At the instrument bus panel, transfer the main breaker for Panel 113 (Blue) to PANEL 117 ALTERNATE SOURCE Position per 1C20.8 AOP1, ABNORMAL OPERATION, INSTRUMENT AC INVERTERS 1C20.8 AOP1, ABNORMAL OPERATION, INSTRUMENT AC INVERTERS If a loss of voltage to Instrument Bus 113 has occurred, Then perform the following:

o Place Rod Control in MANUAL o At the instrument Bus 113 Panel, transfer the source breaker to the INTERRUPTABLE PANEL 117 position Retention: Life of Plant

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RIO TIME-LINE:

SCENA SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 5

14. When the crew has restore power to Instrument Bus 113, and/or at the discretion of the Lead Evaluator enter the 11 S/G Main Steam Line Break (Relative Order 5, Trigger 5).

15. If asked for Unit 2 help to perform ATT L, inform the U1 SS that no operators are available at this time.

NOTE: As part of Att. L step 6b the crew will also manually close the Instrument Air to Containment Valves as part of the Failure of the MSIVs to isolate.

16. 1E-2 response

a.

If asked as the chemist to take secondary samples, state that you will begin samples immediately.

CREW LEAD LEAD CREW 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify Reactor Trip.

Verify Turbine Trip.

Verify Both Safeguards Buses Energized.

Check if SI is actuated.

Check if SI is required.

Critical Task: Manually close MSIVs before transition out of 1E-0.

Verify Status of Equipment on Attachment L.

Critical Task: TCOA4 Control AFW flow within 38 minutes following a Reactor Trip.

(SWI O-35 identified Time Critical Operator Action).

Check AFW Status.

Check RCS Temperatures.

Check PRZR PORVs and Spray Valves.

Check if RCPs should be stopped.

Check if SGs are not faulted.

Go to 1E-2, Faulted Steam Generator Isolation.

1E-2, FAULTED STEAM GENERATOR ISOLATION Critical Task: Isolate the faulted Steam Generator before transition out of 1E-2.

Check MSIV and Bypass Valve on affected SG(s) -

CLOSED.

Check if either SG is not faulted.

Identify faulted SG.

Isolate faulted SG.

Isolate Main Feedline Isolate AFW flow Close steam supply valve to TDAFWP Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS X

ES E PECTED STUDEN RE T

SPONS CREW CREW Verify SG PORV closed.

Verify SGB isolation valve closed.

Check CST level greater than 10000 gallons.

Check secondary radiation.

Go to 1E-1.

1E-1, LOSS OF REACTOR OR SECONDARY COOLANT Check If RCPs Should Be Stopped.

Check If SGs Are Not Faulted.

Check Intact SG Levels.

Check Secondary Radiation - Normal.

Check PRZR PORVs And Block Valves.

Reset SI.

Reset Containment Isolation.

Established Instrument Air To Containment.

Check Power Supply To Charging Pumps - Offsite Power Available.

Check If Charging Flow Has Been Established.

Check If SI Flow Should Be Terminated.

o Go To 1ES-0.2, SI Termination Note: Crew may transition to 1ES-0.2, SI Termination based on Information Page.

1ES-0.2, SI TERMINATION Reset SI.

Reset Containment Isolation.

Established Instrument Air To Containment.

Stop Safeguards Pumps.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Note: Crew may transition to 1FR-P.1 due to a integrity CSFST orange or red path.

CREW 1FR-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITION.

Check RCS pressure - greater than 550 psig.

Check RCS cold leg temperatures - stable or increasing.

Check PORV block valves - power available and at least one block valve open.

Check if PORVs should be closed.

Check SI pumps - any running.

Check if SI should be terminated.

Reset SI.

Reset Containment Isolation.

Establish Instrument Air to Containment.

Stop Safeguards pumps.

17. When the crew has stopped safeguards pumps in 1ES-0.2 or 1FR-P.1, or at the discretion of the lead evaluator, then place the simulator in FREEZE and inform the crew that training has the duty.

18. Emergency Plan Classification None

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SUMMARY

Relative Order System Or Panel Drawing Type Code Severity Or Value Event Trigger Timing Description 0

MALF RP06 MSIVs fail to isolate 1

SIMNI03 MALF NI05D 100 1

N44 Summing Amp failure high 2

MALF FW13A 2

11 FW pump trip 3

SIMED13 MALF ED08C 3

Loss of instrument bus 113 3a E-0_Att-J.sch Perform Attachment J 4

REMOTE ED168 PNL 117 4

Source to 125VAC Panel 113 Transfer Switch 5

MALF MS01A 100 5

Main Steam Line Break Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SIMULATOR SETUP CHECKLIST Standard IC-25 Before Training Simulator Status:

___ 1.

"Training Load"

___ 2.

Step counters "ON"

___ 3.

Alarm sound "ON"

___ 4.

Reset to IC-25

___ 5.

Speed: REAL Cycle recorder power OFF then back ON to clear Yokogawa recorder memory Verify Summary matches Simulator Input Summary page in the SEG Boric Acid/RMU integrators set to: BA: 3, RMU: 125, and reset MOC I sheet displayed on C panel Check all ERCS alarms are cleared (ATWS scenario)

MOC Reactivity Briefing sheet available at Reactor Operator Desk Chart recorders operating and forwarded Turnover sheet/PRA sheet Log in on floor PCs using user ID: <pitrgsim> (password is the same as user ID)

Update Control Board Placards:

___ 1.

High Flux At Shutdown Alarm Setpoint placards: 1400 cps

___ 2.

Feedwater regulating valve position placard: 66/65, 67/64

___ 3.

RCS boron on the CVCS panel placard: 734 ppm

___ 4.

Turbine reference/setter values on the CVCS panel set to current (Target/Demand on-line positions)

___ 5.

Shift Reactivity Guidance placard: BA: 2.3 gallons, RMU: 67 gallons Magnetic placards in place:

___ 1.

11 BA TANK "Lined Up For Service"

___ 2.

11 BA PUMP "Lined Up To 11 BA Tank"

___ 3.

CC TO SFP MV-32115 "In Service"

___ 4.

Blowdown 46470 "SGB To CDSR" Protected equipment tags in place:

___ 1.

12 CC pump Attach Caution Tags to the following control switches:

___ 1.

Place CS-46036, 11 CC pump control switch in PULLOUT and attach caution tag ERCS driven recorders are on-scale (RCS temperature scaled to 550º F to 560º F)

ERCS alarm screen operating and alarms reset All ERCS terminals operating and set as follows:

CONF VARS R02 Alarm Summary Page CONE1 Group OP31_U1 R03 AFD CONC SAS (XS11)

R04 TPM CONG1 Group QP CCDATA R05 QP LOADFOLL ERCS-R01 Group RADMON_U1 R06 Alarm Summary Page

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ERCS single point displays:

CONB 1T0499A 1U1613A CONE2 1V4501A 1Q0340A ERCS TPM set (NIS - Auto Scaling - LEFM)

Pens/Paper/Markers available on the simulator B oard-mounted EAL Table is cleaned E AL sticker books in F3-2 are checked for missing stickers Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

___ 7.

1ES-0.1

___ 8.

1E-2

___ 9.

___ 10.

1ES-0.2

___ 11.

___ 12.

C47010-0101

___ 13.

C47013-0101

___ 14.

C47013-0102

___ 15.

C47005-0307

___ 16.

1C4 AOP1

___ 17.

1C51.4

___ 18.

TS 3.3.1

___ 19.

TS 3.8.7

___ 20.

1C20.8 AOP1

___ 21.

On the NIS panel, verify Scaler Timer power switch is in Off position.

Set Turbine Control HMI Displays as follows:

___ 1.

U1 E-H Turb Cont STA 2 (48087) to:

Control Valve Overview

___ 2.

U1 Turb Aux Cont (48088) to:

Turb Overview

___ 3.

U1 E-H Turb Cont STA 1 ( 48086) to:

On Line Control DEHC alarms cleared

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Post-Scenario Checklist EOOS computer is cleared of information added during the scenario Computer generated PINGP 577 cleared.

Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

___ 7.

1ES-0.1

___ 8.

1E-2

___ 9.

___ 10.

1ES-0.2

___ 11.

___ 12.

C47010-0101

___ 13.

C47013-0101

___ 14.

C47013-0102

___ 15.

C47005-0307

___ 16.

1C4 AOP1

___ 17.

1C51.4

___ 18.

TS 3.3.1

___ 19.

TS 3.8.7

___ 20.

1C20.8 AOP1

___ 21.

Protected equipment tags in place:

___ 1.

Remove tag from 12 CC pump Remove Caution Tags to the following control switches:

___ 1.

11 CC pump Board-mounted EAL Table is cleaned All books, note pads, and calculators put away End Of Day Checklist Signs/placards removed and put away unless normal simulator configuration Floor PCs logged off if simulator will not be used again that day Instructor station returned to normal with all books, paper, and etc. put away Headsets turned off and put away if simulator will not be used again that day Simulator reset to IC-10 unless another IC will be used for further training Simulator placed in DORT if simulator will not be used again that day Recorder power "OFF" if simulator will not be used again that day

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RETENTION: 7 Days UNIT 1 LPEO / PEO TURNOVER LOG DATE:

DAY/NIGHT SHIFT: Day CAT 1 VENT OPENINGS: 0 ft2 SYSTEM CONDITION: GREEN SAFEGUARDS EQUIPMENT OOS/TECH SPEC REQUIRED ACTION STATEMENTS 11 CC pump is OOS for pump seal replacement. Entered T.S. 3.7.7 Condition A at 0400 with expected return to service at 2300.

PROTECTED EQUIPMENT 12 CC pump RAD MONITORS OOS ANNUNCIATORS OOS OUTSTANDING SPS FIRE DET / PROT EQP IMPAIRMENTS OTHER EQUIPMENT OOS / STATUS MAJOR EQUIPMENT REPAIRED / RETURNED TO SERVICE 12 SI pump OPERATIONAL PLANS FOR COMING SHIFT Suspend Tech Spec required shutdown due to repair of 12 SI Pump.

Hold at current power for TSO, TSO will call when load change is desired.

Xenon is building in after load decrease from 100%.

Adding 125 gallons of RMU every 8 - 10 minutes to maintain Tave at Tref.

NEW PROCEDURES / INSTRUCTIONS

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Simulator Scenario Development Checklist Mark with an X Yes or No for any of the following. If the answer is No, include justification for the no answer or the corrective action needed to correct the discrepancy after the item.

1. The scenario contains objectives for the desired tasks and relevant human performance tools.

Yes No X

2. The scenario identifies key parameter response, expected alarms, and automatic actions associated with the induced perturbations.

Yes No X

3. The scenario content adequately addresses the desired tasks, through simulator performance, instructor-led training freezes, or both.

Yes No X

4. Plant PRA initiating events, important equipment, and important tasks are identified.

Yes No X

5. Turnover information includes a Daily At Power or Shutdown Safety Risk Assessment.

Yes No X

6. The scenario contains procedurally driven success paths. Procedural discrepancies are identified and corrected before training is given.

Yes No X

7. The scenario guide includes responses for all anticipated communications to simulated personnel outside the Control Room, based on procedural guidance and standard operating practices. Include estimated completion times and/or notes for use of time compression.

Yes No X

8. The scenario includes related industry experience. SOER, SER and similar OE recommendations are clearly identified and fully addressed.*

Yes No X

9. The scenario guide incorporates verification of Operator Fundamental application.*

Yes No X

10. Training elements and specific human performance elements are addressed in the scenario critique guide to be used by the critique facilitator. The critique guide includes standards for expected performance.*

Yes No X

11. For evaluations, it has been verified that without operator action the critical tasks will be failed.

Yes No X

Developer and Reviewer: Once checklist is completed and deficiencies are corrected, sign the cover page.

For evaluations these items may be marked NO without justification.

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Simulator Scenario Validation Checklist Mark with an X Yes or No for any of the following. If the answer is No, include an explanation after the item.

1. The desired initial condition(s) could be achieved.

Yes X

No

2. All malfunctions and other instructor interface items were functional and responded to support the simulator scenario.

Yes X

No

3. All malfunctions and other instructor interface items were initiated in the same sequence described within the simulator scenario.

Yes X

No

4. All applicable acceptance criteria were met for procedures that were used to support the simulator scenario.

Yes X

No

5. During the simulator scenario, observed changes corresponded to expected plant response.

Yes X

No

6. Did the scenario satisfy the learning or examination objectives without any significant simulator performance issues, or deviations from the approved scenario sequence? If learning objective(s) could not be satisfied, identify the objectives in the Simulator Action Request Yes X

No

7. Evaluation: The simulator is capable of being used to satisfy learning or examination objectives without exceptions, significant performance discrepancies, or deviation from the approved scenario sequence.

Yes X

No Discrepancies noted (Check none or list items found)

None SMAR = Simulator Action Request SMAR:

SMAR:

Comments:

Validator: Sign the cover page only after noted discrepancies are corrected or compensatory actions are taken to ensure quality training.

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SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

2010 ILT NRC SIMULATOR EVALUATION #3 SEG TITLE:

2010 ILT NRC SIMULATOR EVALUATION

3 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME:

1.5 HOUR Additional site-specific signatures may be added as desired.

Developed by:

John DuBose 10/30/09 Instructor Date Reviewed by:

Mike Fish 12/13/09 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Mike Fish 12/13/09 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

During all plant operating conditions, the crew will demonstrate the ability to monitor and operate the plant within the limits of the Operations Manuals and Technical Specifications.

When presented with various scenario events, the crew will demonstrate the ability to respond to the events using appropriate operating and administrative procedures to return the plant to stable conditions.

Learning Objectives:

1.

During all plant operating conditions, demonstrate the ability to perform communications, verification practices (STAR and peer checks), procedure use, alarm response, reactivity control, and crew briefs in accordance with Operations Standards and Expectations.

2.

Raise power to the Point of Adding Heat IAW 1C1.2.

3.

Transfer running Condensate Pumps per 1C28.3.

4.

Diagnose and respond to failure of 122 Instrument Air Compressor per C47 and 1C34 AOP1.

5.

Diagnose and respond to a Pressurizer Heater Backup Group 1B Breaker Trip per 1C20.6.

6.

Diagnose and respond to PT-431 blue channel Pressurizer Pressure failure per C47 and 1C51.3.

7.

Diagnose and respond to a Steam Generator Tube Rupture per 1E-0 and 1E-3.

8.

Diagnose and respond to a Cooling Water pump failing to auto start per 1E-0 Attachment L.

Prerequisites:

1.

NONE Training Resources:

1.

Full Scope Simulator

2.

Lead Evaluator

3.

Booth Operator

4.

Backup Communicator

References:

1.

NONE Commitments:

1.

NONE

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Evaluation Method:

This is an evaluation scenario Operating Experience:

None - Evaluation Scenario Related PRA Information:

Initiating Event with Core Damage Frequency:

SGTR (2%)

Important Components:

11 CLG WTR PMP 12 DD CLG WTR PMP 121 MD CLG WTR PMP 122 STA AIR COMPR 123 STA AIR COMPR Important Operator Actions with Task Number:

Cooldown and depressurize RCS from SGTR before SG overfill (2%)

CRO 3010040601

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE:

None. This is an evaluation scenario and no credit will be taken for tasks performed.

GENERAL EXPECTATIONS Over the duration of the scenario, monitor crew performance for adherence to the conduct of operations standards and Operations department Standards and Expectations:

Communications Verification Practices (STAR and Peer Checks)

Procedure Use Alarm Response Reactivity Control Crew Briefs Performance for adherence to administrative procedural requirements and operations management expectations:

Reportability of the malfunction or event Notifications to the Operations Manager and NRC Resident Inspector per SWI-O-28 Notification to the Duty Station Manager per operations management request Tech Spec implementation; interpretation; and documentation of decision made, actions taken, and the basis for decisions made and actions taken

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. 122 Air Compressor fails.

2. Pressurizer Heater Backup Group 1B Breaker Trip.

3. PT-431 Blue Channel Pressurizer Pressure fails.

After EOP Entry:

1. Failure of the SI signal to the Cooling Water system.

Normal Events:

1. Raise power to the Point of Adding Heat.

2. Transfer running Condensate Pumps.

Abnormal Events:

1. 122 Instrument Air Compressor fails.

2. Pressurizer Heater Backup Group 1B Breaker Trip.

3. PT-431 Blue Channel Pressurizer Pressure fails Major Transients:

1. SGTR Critical Tasks:

1. E-O - TCOA4: Control AFW flow within 38 minutes following a Reactor trip.

(SWI O-35 identified Time Critical Operator Action).

2. E A: Isolate feedwater flow into and steam flow from the ruptured Steam Generator before a transition to ECA-3.1 occurs.

3. E B: Establish/maintain an RCS temperature so that transition from E-3 does not occur because of the inability to maintain required subcooling or such that an extreme or severe challenge to the Subcriticality and/or the Integrity CSF occurs.

4. E C: Depressurize RCS to meet SI termination criteria prior to overfilling the ruptured Steam Generator.

5. E D: Terminate SI prior to overfilling the ruptured Steam Generator.

QF-1075-02 Rev. 3 (FP-T-SAT-75)

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

1. This scenario can be run from the following Standard IC sets:

IC-26

2. The following equipment is OOS:

13 Charging Pump OOS SEQUENCE OF EVENTS:

Event 1: Raise power to the POAH

Candidates will perform a pre-job brief prior to entering the Control Room.

Power will be raised to the POAH.

The crew will start 12 Condensate Pump and stop 11 Condensate Pump for Filter Demin Support.

Event 2: 122 Air compressor fails.

122 Instrument Air Compressor fails and 123 Instrument Air Compressor fails to function automatically.

The Crew will respond per C47 and C34 AOP1, Loss of Instrument Air to start 123 Instrument Air Compressor.

Event 3: Pressurizer Heater Backup Group 1B Breaker Trip

Pressurizer Heater Backup Group 1B Breaker Trips.

The crew will respond to breaker failure per 1C20.6.

Event 4: PT-431 Pressurizer Pressure Channel fails high

PT-431 fails high.

Both Pressurizer spray valves will fully open and Pressurizer heaters will de-energize.

The crew will take manual control of spray valves and close them.

The crew will respond per C47 and 1C51.3 to change the controlling pressure channel and restore pressure.

Event 5: 12 Steam Generator tube rupture

The Steam Generator tube leak will escalate to 400 GPM tube rupture.

The Crew will respond per 1E-0 and 1E-3.

Event 6: SI Signal to CL System Fails To Actuate

The SI signal to the Cooling Water system will fail.

The crew will manually align the Cooling Water system.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 7 of 26 2010 ILT NRC SIMULATOR EVALUATION #3, Rev. 0 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES INITIAL CONDITIONS:

IC-26 Mode: 2 Exposure: ZBC Power: 1E-8 amps Boron: 1822 ppm Temperature: ~548°F Pressure: ~2235 psig Xenon: Free Rods: D @ 140 Generator: OFFLINE (RO/LO

/SRO)

Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SCENARIO TIME-LINE:

SEQ RUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES SEQUE CE OF EVEN N

TS / INST

1.

SIMULATOR SET UP

a. Set up the simulator to IC-26.

b. Enter the malfunctions, remotes, and overrides, as specified by the "Simulator Input Summary."

c. Complete the "Simulator Setup Checklist.

2.

Simulator Pre-brief:

a.

The Simulator Pre-Brief is conducted prior to the crew entering the simulator.

b.

The crew will brief the power change and swapping of running condensate pumps prior to entering to Control Room.

3.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

a. Verify crew performs walk down of control boards and reviews turnover checklists.

CREW Review the following with the off-going operator:

Unit 1 LPEO / PEO Turnover Log PRA printout Walk-down the control boards and ask questions as appropriate EVENT 1

4.

When the crew has assumed the duty allow the crew to raise power to the point of adding heat and start 12 Condensate pump and stop 11 Condensate pump.

RO 1C1.2 UNIT 1 STARTUP PROCEDURE Starting at step 5.10.18 o Raise power to the POAH o When one or more intermediate range indicates greater than 1E-9 amps, THEN verify ERCS is in Mode 2.

o Using ERCS display XS02 and C41, verify the Subcriticality CSF Activation Status is INACTIVE.

o Maintain reactor power between 0.5 and 2.0%.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES

5.

Follow along in 1C28.3 step 5.6 and report back all local actions and checks are complete as requested after 2 minutes. None of the local checks are modeled in the simulator.

LEAD 1C28.3, UNIT 1 CONDENSATE SYSTEM Step 5.6 Swapping Condensate Pumps o Check condensate pump oil cooling water flow using cooling water return sight glass.

o Check condensate pump gland seal water flow using the following:

Flow through the gland seal water sight glass - local.

Seal water pressure is 18-24 psig -

local.

Following annunciators NOT LIT:

47009-0402, 11 CONDENSATE PUMP SEAL WATER LO PRESS 47009-0403, 12 CONDENSATE PUMP SEAL WATER LO PRESS 47009-0404, 13 CONDENSATE PUMP SEAL WATER LO PRESS o Ensure the motor bearing of the condensate pump have the proper oil level - local.

o Verify all condensate pump suction valves are open - local.

o Notify the duty chemist that a condensate pump is being started and secondary chemistry may be affected.

o Place the desired condensate pump selector switch in MANUAL.

o Start the desired condensate pump by placing Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES LEAD the control switch to the START position.

o Check the pump visually for excessive vibration or seal leakage.

o Check the bearing temperatures and motor stator temperatures on ERCS o Close the discharge vent of the running condensate pump - local.

o Verify pump gland seal water pressure is 18-24 psig - local.

o Verify heat removal fans have started - local.

o Check condensate header pressure approx.

440 psig on 4122101, 11/12/13 CD PMP DISCH HDR PI.

o Stop the desired condensate pump by placing the control switch to the STOP position.

o If desired, Then place a condensate pump selector switch in STANDBY.

o Open the discharge vent valve of the condensate pump that was stopped - local.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 2 6.

When the crew has stabilized power at the POAH, Condensate pumps have been swapped and/or at the discretion of the Lead Evaluator enter the failure of 122 Air compressor. (Relative Order 2, Trigger 2)

NOTE: The Booth operator MUST remove the fault on 123 Air Compressor when actions are taken to start 123 Air Compressor (Relative Order 2b)

a.

If directed to investigate 122 Air Compressor trip, local alarm, and/or C70551 Panel alarm, after 2 minutes perform (Relative Order 2a) report the following:

1) 122 Air Compressor Low Oil Pressure alarm on Panel 70551.

2) 122 air compressor appears intact with no visible damage

b.

If directed to investigate C47023-0101, 121 AIR COMPRESSOR LOCAL ALARM, after 2 minutes report the following:

1) 121 Air Dryer Purge Exhaust Isolation CV-31960 Closed alarm was flashing on C75550 Panel and cleared when the alarm was acknowledged.

c.

If directed to investigate 123 Air Compressor after it has been started, after 3 minutes, report the air compressor and air dryer are operating normally.

d.

If contacted as the FIN team supervisor, inform the crew that you will write a work order and assign an Electrical Maintenance supervisor to investigate.

e.

If directed, as Turbine Building Operator, wait 2 minutes and report CP-40-7 open.

If desired, allow the crew to hold a crew brief.

LEAD LEAD LEAD NOTE: 123 Air Compressor may be manually started as a plant stabilization action.

C47023-0102, 122 AIR COMPRESSOR LOCAL ALARM Check station and instrument air header pressures.

Start addition compressors as necessary.

Dispatch operator to Panel 70551, 122 Station Air Compressor Annunciator Panel to perform the following:

o Determine the initiating alarm.

o Respond per C70551, 122 STATION AIR COMPRESSOR REMOTE ALARM RESPONSE.

C47023-0202, 122 AIR COMPRESSOR AUTOMATIC START OR STOP Check station and instrument air header pressures.

If alarm is due to normal cycling of standby air.

If instrument air pressure is low, then refer to C34 AOP1, LOSS OF INSTRUMENT AIR.

NOTE: The crew might refer to C34 AOP1, but no actions should be required. The loss of air is NOT expected to cause a reactor trip.

C47023-0101, 121 AIR COMPRESSOR LOCAL ALARM Check station and instrument air header pressures.

Start addition compressors as necessary.

Dispatch operator to Panel 70550, 121 Station Air Compressor Annunciator Panel to perform the following:

o Determine the initiating alarm.

Respond per C70550, 122 STATION AIR COMPRESSOR REMOTE ALARM RESPONSE.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS T RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EXPECTED STUDEN EVENT 3

7.

When the crew has completed actions for the 122 Air Compressor failure, and/or at the discretion of the Lead Evaluator enter the Pressurizer Heater Backup Group 1B breaker failure (Relative Order 3, Trigger 3).

a.

If asked to investigate 122C breaker tripping, after 2 minutes report back the following:

1) Report workers in the Bus 122 room dropped a ladder which hit the 122C breaker.

2) The 122C breaker has significant damage.

8.

When crew places CS-46242 PRZR HEATER BACK-UP GROUP 1B, to OFF remove OVERRIDE on control switch. (Relative Order 3a)

9.

If the crew informs Turbine Building operator to transfer to backup power supply Bus 180 per 1C20.6 wait 3 minutes and then perform (Relative Order 3b, Trigger 8).

CREW RO LEAD SS RO Crew will respond to ERCS alarm:

BKRCHK: 1YB122C PZR BU-HTR Determine Pressurizer Heater Backup Group 1B breaker tripped 1C20.6 UNIT 1 - 480V SYSTEM Transfer Unit 1 Pressurizer Heater Group B from Bus 122 to Bus 180 per step 5.35 o Enter T.S. LCO 3.4.9 Condition B.

o Place CS-46242 PRZR HEATER BACK-UP GROUP 1B, to OFF.

o Have Turbine Building operator transfer power supplies locally o Place CS-46242 PRZR HEATER BACK-UP GROUP 1B, to ON.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 4 10. When the crew has completed actions for the pressurizer heater breaker failure, and/or at the discretion of the Lead Evaluator, then enter the Blue Channel Pressurizer pressure failing high (Relative Order 4, Trigger 4).

a.

If directed as I&C to trip bistables, report that 2 I&C technicians will be available in 45 minutes.

(Note: bistables will not be tripped during this scenario.)

b.

If contacted as Operations Management, acknowledge the report of the failure, and agree to make other notifications to the NRC Resident Inspector, Duty Station Manager, etc., as asked.

c.

If contacted as the FIN team supervisor, inform the crew that you will write a work order and assign an I&C supervisor to investigate.

d.

If desired, allow the crew to hold a crew brief.

RO LEAD/

RO SS NOTE: As a plant stabilization action the crew is expected to take manual control of the Pressurizer Spray Valves and close them.

C47012-0408, PRZR HI/LO PRESS CHANNEL ALERT If necessary, then refer to 1E-0 Check pressurizer pressure high or low.

Restore pressure to normal through use of heaters or sprays.

If necessary, then refer to 1C51.

1C51.3, Pressurizer Pressure 1P-431 - HIGH If the blue channel is selected on the przr pressure control selector switch then:

o Place pressurizer pressure controller in manual and stabilize pressure.

o Select position 2-1 (WHITE-RED) on channel selector switch.

o When pressure returned to normal with no deviation from setpoint, then return pressure control to automatic.

Verify pressurizer pressure recorder not selected to blue channel.

Refer to the following technical specification requirements:

o T.S. LCO 3.3.1 condition A & Table 3.3.1-1 Functions 6, 8a, 8b.

o T.S. LCO 3.3.2 Condition A & Table 3.3.2-1 Function 1d.

T.S. LCO 3.4.1.a TRM Spec for RCS Pressure (<2205) also applies Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 5

11. When the crew has completed actions for the pressurizer pressure channel failing high, and/or at the discretion of the Lead Evaluator, then enter the 12 Steam Generator Tube Rupture (Relative Order 5, Trigger 5).

a.

Upon hearing the announcement of reactor trip, or when called as Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, then enter Relative Order 6 (Schedule file E-0_Att-J.sch)

b.

When called as the Turbine Building Operator to verify the status of Turbine Building Roof Exhausters, report that the Turbine Building Roof Exhausters are all secured.

c.

If asked, as Duty Chemist, wait 4 mins and report 11 Steam Genetor cation column reads background, 12 Steam Generator Cation column has elevated counts.

d.

If asked to open FCU CLG WTR RTN BP VLVs perform (Relative Order 7, Trigger 7).

CREW LEAD CREW 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify Reactor Trip Verify Turbine Trip Verify Both Safeguards Buses - ENERGIZED.

Check if SI is actuated Verify status of equipment on ATTACHMENT L: SI alignment verification.

NOTE: During Att. L the failure of the SI signal to the cooling water system will require it to be aligned appropriately. Unit 2 will not be available to perform this.

Critical Task: Control AFW flow within 38 minutes following a Reactor Trip. (SWI O-35 identified Time Critical Operator Action).

Check AFW status:

o Verify total AFW flow - Greater than 200 gpm If SG wide range level greater than 50% in either SG If SG wide range level less than 50% in both SGs, then manually start AFW pumps and align valves, as necessary.

o Verify AFW pumps discharge pressure - greater than 900 psig.

o Check SG levels - Narrow range greater than 5%

o Control feed flow to maintain narrow range SG level between 5% and 50%

Check RCS temperatures Check PRZR PORVs and Spray Valves Check if RCPs should be stopped Check if SGs are not faulted Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS S

EXPECTED STUDEN RES T

PONSE NOTE: Due to Zero Burn Core/Low RCS activity and low initial reactor power radiation monitors may NOT alarm.

The crew may NOT identify the SGTR at step 11. Crew will identify ruptured SG at step 15 and go to 1E-3.

CREW CREW Check if SG tubes are not ruptured:

o Condenser air ejector radiation - normal o SGB radiation - normal o Main steamline radiation - normal Check if RCS is intact Check if SI flow should be terminated Initiate montoring of critical safety function status trees Check SG levels o NR level > 5%

o Control feed flow to maintain NR levels 5 - 50%

If SG NR level in one SG continues to increase in an uncontrolled manner, THEN go to 1E-3, STEAM GENERATOR TUBE RUPTURE, Step 1.

1E-3, STEAM GENERATOR TUBE RUPTURE Check if RCPs should be stopped Identify Ruptured SG Critical Task: Isolate feedwater flow into and steam flow from the ruptured Steam Generator before a transition to ECA-3.1 occurs.

Isolate flow from ruptured SG Check ruptured SG level Reset SI Check ruptured SG pressure - Greater than 210 psig Critical Task: Establish/maintain an RCS Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES CREW temperature so that transition from E-3 does not occur because of the inability to maintain required subcooling or such that an extreme or severe challenge to the Subcriticality and/or the Integrity CSF occurs.

Initiate RCS Cooldown Note: During the cooldown, the SS must continue with step 8 to prepare the plant for depressurization.

Check intact SG level Check PRZR PORVs and Block Valves Reset SI Reset Containment Isolation Establish Instrument Air to containment Check if RHR pumps should be stopped Establish Charging flow Check if RCS Cooldown should be stopped Check Ruptured SG pressure - Stable or increasing Check RCS subcooling based on core exit T/Cs -

greater than 40°F Critical Task: Depressurize RCS to meet SI termination criteria prior to overfilling the ruptured Steam Generator.

Depressurize RCS to minimize break flow and refill PRZR Check if SI flow should be terminated Critical Task: Terminate SI prior to overfilling the ruptured Steam Generator.

Stop SI pumps Establish Charging flow Verify SI flow not required Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES

12. When the crew has stopped SI and verified it is not required, or at the discretion of the Lead Evaluator, then place the simulator in FREEZE and inform the crew that training has the duty.

13. Emergency Plan Classification Site Area Emergency - EAL SS1.1

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SUMMARY

Relative Order System Or Panel Drawing Type Code Severity Or Value Event Trigger Timing Description 0

OVRD DI-46098SP TRUE FAILURE OF #123 AIR COMPRESSOR AUTO 0

MALF RP12 SI SIGNAL TO CL WATER 0

MALF IA02 5

AIR USAGE IN PLANT 2

MALF IA03B 2

LOSS OF AIR COMPRESSOR #122 2

ANN MALF M47023:0102W CRY WOLF 2

122 AIR COMPRESSOR LOCAL ALRM 2a ANN MALF M47023:0102W REMOVE 122 AIR COMPRESSOR LOCAL ALRM 2b OVRD DI-46098SP REMOVE REMOVE FAULT ON #123 AIR COMPRESSOR 3

OVRD DI-46242OFF TRUE 3

TRIP OFF PRZR HTR BU GROUP B 3a OVRD DI-46242OFF REMOVE TRIP OFF PRZR HTR BU GROUP B 3b REMOTE RX100 BUS 180 8

PZR HTR GROUP B PS XFER 4

SYS OVRD RX202 2500 4

PT-431 FAILS HIGH 5

MALF SG02B 20 5

60 SECOND RAMP 12 SG TUBE RUPTURE

(~400 GPM) 6 E-0_Att-J.sch Perform Attachment J Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SIMULATOR INPUT

SUMMARY

Relative Order System Or Panel Drawing Type Code Severity Or Value Event Trigger Timing Description 7

REMOTE CL105 OPEN 7

11/13 FCU CLG WTR RTN BP VLV 7

REMOTE CL106 OPEN 7

12/14 FCU CLG WTR RTN BP VLV

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SIMULATOR SETUP CHECKLIST Standard IC-26 Before Training Simulator Status:

___ 1.

"Training Load"

___ 2.

Step counters "ON"

___ 3.

Alarm sound "ON"

___ 4.

Reset to IC-26

___ 5.

Speed: REAL Cycle recorder power OFF then back ON to clear Yokogawa recorder memory Verify Summary matches Simulator Input Summary page in the SEG Boric Acid/RMU integrators set to: BA: 3, RMU: 10, and reset ZBC I sheet displayed on C panel Check all ERCS alarms are cleared.

ZBC Reactivity Briefing sheet available at Reactor Operator Desk Chart recorders operating and forwarded Turnover sheet/PRA sheet Log in on floor PCs using user ID: <pitrgsim> (password is the same as user ID)

Update Control Board Placards:

___ 1.

High Flux At Shutdown Alarm Setpoint placards: 1400 cps

___ 2.

Feedwater regulating valve position placard: BLANK

___ 3.

RCS boron on the CVCS panel placard: 1822 ppm

___ 4.

Turbine reference/setter values on the CVCS panel set to current (Target/Demand on-line positions)

___ 5.

Shift Reactivity Guidance placard: BA: 6.0 gallons, RMU: 67 gallons Magnetic placards in place:

___ 1.

11 BA TANK "Lined Up For Service"

___ 2.

11 BA PUMP "Lined Up To 11 BA Tank"

___ 3.

CC TO SFP MV-32115 "In Service"

___ 4.

Blowdown 46470 "SGB To CDSR" Protected equipment tags in place:

___ 1.

None Attach Caution Tags to the following control switches:

___ 1.

13 Charging Pump in Pullout

___ 2.

CS-46362, 4.16KV Bus 11 1M XFMR

___ 3.

CS-46363, 4.16KV Bus 12 1M XFMR

___ 4.

CS-46364, 4.16KV Bus 13 1M XFMR

___ 5.

CS-46365, 4.16KV Bus 14 1M XFMR ERCS driven recorders are on-scale (RCS temperature scaled to 545º F to 555º F)

All ERCS Screens are displaying Shift+F7 screens.

ERCS alarm screen operating and alarms reset

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All ERCS terminals operating and set as follows:

CONF VARS R02 Alarm Summary Page CONE1 Group OP31_U1 R03 AFD CONC SAS (XS11)

R04 TPM CONG1 Group QP CCDATA R05 Per step below ERCS-R01 Group RADMON_U1 R06 Alarm Summary Page ERCS single point displays:

CONB 1T0499A 1U1613A CONE2 1V4501A 1Q0340A R05 displays a 3 point trend of:

___ 1.

1T0449A

___ 2.

1T0496A

___ 3.

1N0035A ERCS TPM set (NIS - Auto Scaling - LEFM)

Pens/Paper/Markers available on the simulator B oard-mounted EAL Table is cleaned E AL sticker books in F3-2 are checked for missing stickers Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

C47012-0408

___ 7.

C47022-0108

___ 8.

C47023-0202

___ 9.

C47048:1R-15

___ 10.

C34 AOP1

___ 11.

1C20.6

___ 12.

1C51.3

___ 13.

___ 14.

1E-3

___ 15.

1c1.2

___ 16.

C28.3

___ 17.

1C1.2

___ 18.

C47011-0302

___ 19.

C47023-0101

___ 20.

47023-0102

___ 21.

On the NIS panel, verify Scaler Timer power switch is in Off position.

Set Turbine Control HMI Displays as follows:

___ 1.

U1 E-H Turb Cont STA 2 (48087) to:

Control Valve Overview

___ 2.

U1 Turb Aux Cont (48088) to:

Turb Overview

___ 3.

U1 E-H Turb Cont STA 1 ( 48086) to:

On Line Control DEHC alarms cleared Markup 1C1.2, UNIT 1 STARTUP PROCEDURE thru step 5.10.17 as complete

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Post-Scenario Checklist EOOS computer is cleared of information added during the scenario Computer generated PINGP 577 cleared.

Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

C47012-0408

___ 7.

C47022-0108

___ 8.

C47023-0202

___ 9.

C47048:1R-15

___ 10.

C34 AOP1

___ 11.

1C20.6

___ 12.

1C51.3

___ 13.

___ 14.

1E-3

___ 15.

1c1.2

___ 16.

C28.3

___ 17.

1C1.2

___ 18.

C47011-0302

___ 19.

C47023-0101

___ 20.

47023-0102

___ 21.

Protected equipment tags in place:

___ 1.

None Remove Caution Tags to the following control switches:

___ 1.

13 Charging Pump

___ 2.

CS-46362, 4.16KV Bus 11 1M XFMR

___ 3.

CS-46363, 4.16KV Bus 12 1M XFMR

___ 4.

CS-46364, 4.16KV Bus 13 1M XFMR

___ 5.

CS-46365, 4.16KV Bus 14 1M XFMR Board-mounted EAL Table is cleaned All books, note pads, and calculators put away End Of Day Checklist Signs/placards removed and put away unless normal simulator configuration Floor PCs logged off if simulator will not be used again that day Instructor station returned to normal with all books, paper, and etc. put away Headsets turned off and put away if simulator will not be used again that day Simulator reset to IC-10 unless another IC will be used for further training Simulator placed in DORT if simulator will not be used again that day Recorder power "OFF" if simulator will not be used again that day

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DAY/NIGHT SHIFT: Day CAT 1 VENT OPENINGS: 0 ft2 SYSTEM CONDITION: GREEN SAFEGUARDS EQUIPMENT OOS/TECH SPEC REQUIRED ACTION STATEMENTS None PROTECTED EQUIPMENT None RAD MONITORS OOS ANNUNCIATORS OOS OUTSTANDING SPS FIRE DET / PROT EQP IMPAIRMENTS OTHER EQUIPMENT OOS / STATUS 13 Charging Pump is OOS for motor replacement.

MAJOR EQUIPMENT REPAIRED / RETURNED TO SERVICE OPERATIONAL PLANS FOR COMING SHIFT Reactor power is currently stable at 1E-8 amps in the Intermediate Range (N-35 &N-36).

Main Feedwater is in service.

Raise Power to Point of Adding Heat per 1C1.2, Unit 1 Start Procedure.

Start 12 Condensate pump and stop 11 Condensate pump for Filter Demin support.

NEW PROCEDURES / INSTRUCTIONS Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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Simulator session will include a power change.

Prior to simulator:

Provide crew a copy of 1C1.2, Unit 1 Startup Procedure marked up to step 5.10.17.

The crew should prepare a reactivity plan to raise power to Point of Adding Heat.

The crew should complete a Pre-Job Brief for the power increase.

Current conditions are:

Power level - 1E-8 amps Xenon - None Control Rod Position - CBD @ 140 steps Boron Concentration - 1822 ppm Core Exposure - ZBC Desired Endpoint:

Power Level 2%

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Simulator Scenario Development Checklist Mark with an X Yes or No for any of the following. If the answer is No, include justification for the no answer or the corrective action needed to correct the discrepancy after the item.

1. The scenario contains objectives for the desired tasks and relevant human performance tools.

Yes No X

2. The scenario identifies key parameter response, expected alarms, and automatic actions associated with the induced perturbations.

Yes No X

3. The scenario content adequately addresses the desired tasks, through simulator performance, instructor-led training freezes, or both.

Yes No X

4. Plant PRA initiating events, important equipment, and important tasks are identified.

Yes No X

5. Turnover information includes a Daily At Power or Shutdown Safety Risk Assessment.

Yes No X

6. The scenario contains procedurally driven success paths. Procedural discrepancies are identified and corrected before training is given.

Yes No X

7. The scenario guide includes responses for all anticipated communications to simulated personnel outside the Control Room, based on procedural guidance and standard operating practices. Include estimated completion times and/or notes for use of time compression.

Yes No X

8. The scenario includes related industry experience. SOER, SER and similar OE recommendations are clearly identified and fully addressed.*

Yes No X

9. The scenario guide incorporates verification of Operator Fundamental application.*

Yes No X

10. Training elements and specific human performance elements are addressed in the scenario critique guide to be used by the critique facilitator. The critique guide includes standards for expected performance.*

Yes No X

11. For evaluations, it has been verified that without operator action the critical tasks will be failed.

Yes No X

Developer and Reviewer: Once checklist is completed and deficiencies are corrected, sign the cover page.

For evaluations these items may be marked NO without justification.

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Simulator Scenario Validation Checklist Mark with an X Yes or No for any of the following. If the answer is No, include an explanation after the item.

1. The desired initial condition(s) could be achieved.

Yes X

No

2. All malfunctions and other instructor interface items were functional and responded to support the simulator scenario.

Yes X

No

3. All malfunctions and other instructor interface items were initiated in the same sequence described within the simulator scenario.

Yes X

No

4. All applicable acceptance criteria were met for procedures that were used to support the simulator scenario.

Yes X

No

5. During the simulator scenario, observed changes corresponded to expected plant response.

Yes X

No

6. Did the scenario satisfy the learning or examination objectives without any significant simulator performance issues, or deviations from the approved scenario sequence? If learning objective(s) could not be satisfied, identify the objectives in the Simulator Action Request Yes X

No

7. Evaluation: The simulator is capable of being used to satisfy learning or examination objectives without exceptions, significant performance discrepancies, or deviation from the approved scenario sequence.

Yes X

No Discrepancies noted (Check none or list items found)

None SMAR = Simulator Action Request SMAR:

SMAR:

Comments:

Validator: Sign the cover page only after noted discrepancies are corrected or compensatory actions are taken to ensure quality training.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 1 of 29 Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

2010 ILT NRC SIMULATOR EVALUATION #4 SEG TITLE:

2010 ILT NRC SIMULATOR EVALUATION

4 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME:

1.5 HOUR Additional site-specific signatures may be added as desired.

Developed by:

Mike Fish 10/12/09 Instructor Date Reviewed by:

John DuBose 12/13/09 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

John DuBose 12/13/09 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Training Supervision Date

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Guide Requirements Goal of Training:

During all plant operating conditions, the crew will demonstrate the ability to monitor and operate the plant within the limits of the Operations Manuals and Technical Specifications.

When presented with various scenario events, the crew will demonstrate the ability to respond to the events using appropriate operating and administrative procedures to return the plant to stable conditions.

Learning Objectives:

1.

During all plant operating conditions, demonstrate the ability to perform communications, verification practices (STAR and peer checks), procedure use, alarm response, reactivity control, and crew briefs in accordance with Operations Standards and Expectations.

2.

Perform power reduction per 1C1.4.

3.

Remove Heater Drain Pump from service per 1C28.4.

4.

Diagnose and respond to a Loss of Bus 16 per C47 and 1C20.5 AOP2.

5.

Diagnose and respond to a failed Steam Generator pressure transmitter per C47 and 1C51.

6.

Diagnose and respond to a Tave instrument failure per C47 and C51.

7.

Diagnose and respond to a failure of the Reactor to automatically trip and an ATWS condition per 1E-0 and 1FR-S.1.

Prerequisites:

1.

NONE Training Resources:

1.

Full Scope Simulator

2.

Lead Evaluator

3.

Booth Operator

4.

Backup Communicator

References:

1.

NONE Commitments:

1.

NONE

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Evaluation Method:

This is an evaluation scenario Operating Experience:

None - Evaluation Scenario Related PRA Information:

Initiating Event with Core Damage Frequency:

None Important Components:

11 TDAFW pump Important Operator Actions with Task Number:

None

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TASKS ASSOCIATED WITH SIMULATOR EXERCISE:

None. This is an evaluation scenario and no credit will be taken for tasks performed.

GENERAL EXPECTATIONS Over the duration of the scenario, monitor crew performance for adherence to the conduct of operations standards and Operations department Standards and Expectations:

Communications Verification Practices (STAR and Peer Checks)

Procedure Use Alarm Response Reactivity Control Crew Briefs Performance for adherence to administrative procedural requirements and operations management expectations:

Reportability of the malfunction or event Notifications to the Operations Manager and NRC Resident Inspector per SWI-O-28 Notification to the Duty Station Manager per operations management request Tech Spec implementation; interpretation; and documentation of decision made, actions taken, and the basis for decisions made and actions taken

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QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. Loss of Bus 16

2. Steam Generator Pressure Transmitter PT-478 fails high (12 SG PORV Fails Open)

3. Tavg instrument fails high

4. Turbine Trip with ATWS After EOP Entry:

1. 11 TDAFW Pump Fails to Auto Start Normal Events:

1. Reduce power from 100% to 94% per 1C1.4.

2. Stop 12 Heater Drain Pump for Brush inspection per 1C28.4.

Abnormal Events:

1. Loss of Bus 16

2. Steam Generator Pressure Transmitter PT-478 fails high (12 SG PORV Fails Open)

3. Tavg instrument fails high Major Transients:

1. Turbine Trip with ATWS Critical Tasks:

1. E F: Establish and maintain 200 gpm AFW flow to the Steam Generator(s) before transition out of E-0, unless the transition is to FR-H.1, in which case the task must be initiated before RCPs are manually tripped in accordance with step 2 of FR-H.1.

2. FR-S.1 - C: Insert negative reactivity into the core by inserting rods or establishing emergency boration flow to the RCS during the performance of FR-S.1.

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SCENARIO OVERVIEW:

INITIAL CONDITIONS:

1. This scenario can be run from the following Standard (Specific) IC sets:

IC-10

2. The following equipment is OOS:

12 Motor Driven AFWP

13 Heater Drain Pump SEQUENCE OF EVENTS:

Event 1: Reduce power from 100% to 94% using 1C1.4

The crew will reduce reactor power from 100% to 94% in accordance with 1C1.4, Unit 1 Power Operation, for Main Turbine Valve Testing.

The crew will remove 12 Heater Drain Pump from service for brush inspection per 1C28.4.

Event 2: Loss of Bus 16

The normal supply breaker to Bus 16 will trip open due to operator error.

The Bus 16 sequencer will fail to re-energize Bus 16.

The crew will respond per 1C20.5 AOP 2 to re-energize the bus.

The sequencer failure will not be addressed in this scenario.

Event 3: Steam Generator Pressure Transmitter PT-478 Fails High

B Steam Generator PORV will open.

The crew will manually close the PORV.

The crew will respond per C47 and 1C51.

Event 4: Tavg instrument Fails High

Blue channel Thot fails high.

Control rods will insert in automatic

The crew will place rod control in manual

The crew will place running charging pumps in manual

The crew will respond per C47 and C51.

Event 5: ATWS

The Reactor will not automatically trip from the Turbine trip.

The reactor cannot be tripped from the Control Room and the crew will enter 1FR-S.1 and manually trip the reactor.

The crew will perform 1FR-S.1 and locally trip the Reactor.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 7 of 29 2010 ILT NRC SIMULATOR EVALUATION #4, Rev. 0 Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

Event 6: 11 TDAFW Pump Fails to Automatically Start 11 TDAFW Pump will not auto start during the ATWS event.

The crew will manually start the 11 TDAFW Pump per 1FR-S.1.

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 8 of 29 2010 ILT NRC SIMULATOR EVALUATION #4, Rev. 0 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES INITIAL CONDITIONS:

IC-10 Mode: 1 Exposure: MOC Power: 100%

Boron: (CB): 669 ppm Temperature: ~560°F Pressure: ~2235 psig Xenon: Equlibrium Rods: D @ 218 Generator: 571 MW (RO/LO

/SRO)

Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SCENARIO TIME-LINE:

SEQ RUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES SEQUE CE OF EVEN N

TS / INST

1.

SIMULATOR SET UP

a. Set up the simulator to IC-10.

b. Enter the malfunctions, remotes, and overrides, as specified by the "Simulator Input Summary."

c. Complete the "Simulator Setup Checklist.

d. Place 2nd letdown orifice in service.

2.

Simulator Pre-brief:

a.

The Simulator Pre-Brief is conducted prior to the crew entering the simulator.

1) Inform the crew a power reduction to 94% is necessary to remove 12 Heater Drain Pump from service for brush inspection.

2) Provide the crew a marked up copy of 1C1.4 section step 5.2 a) N/A steps 5.2.1 b) Sign off step 5.2.2 (these notifications are not necessary)

3) Provide the crew a reactivity plan developed by the off going RO for the power reduction from 100% to 94%.

4) Inform the crew to verify the reactivity plan developed by the off going reactor operator.

5) Inform the crew that Nuclear Engineering was not available to provide a reactivity prediction.

6) Have SRO candidate perform the pre-job brief for the power reduction.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 1

3.

When the crew has assumed the duty they will proceed with a power reduction to 94% in accordance with 1C1.4, Unit 1 Power Operation.

4.

When notified as Duty Chemist, acknowledge power reduction.

CREW LEAD RO Crew should start the power reduction to 94% IAW 1C1.4, Unit 1 Power Operation, at section 5.2, step 5.2.6.

Notify Duty Chemist of the load decrease Turn ON all pressurizer heaters Increase letdown flow if desired (80 gpm letdown flow will already be established, no actions will be needed)

If desired, THEN transfer Heating System to Unit 2 or to heating boiler (No actions will be needed since power reduction is only to 90%)

If desired, THEN place CS-46280, ROD BANK SELECTOR, in MANUAL. Refer to precaution 3.7 Start the load decrease as follows:

a. Using the On Line Control screen, select the desired Control Mode (VPC,FSP or LOAD).

b. Using the On Line Control screen, select the desired rate.

c. Set the desired Target setting using the Target increase/decrease controls using the On Line Control screen.

d. Initiate a negative reactivity addition by using control rods or boration of the RCS per C12.5

e. WHEN Tave shows a decrease, THEN select Go on the On Line Control screen to initiate the load decrease.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS E

EXP CTED STUDENT RESPONSES

5.

The crew should stop the load decrease at 94% IAW 1C1.4, Unit 1 power Operation.

6.

When power is less than 95% the Lead operator should remove 12 Heater Drain Pump from service per 1C28.4.

RO LEAD

f.

Vary the boration rate or batch borate as necessary to maintain Tave and Tref within the desired +/- 1.5°F band.

g. To suspend the load decrease, perform the following:

i. Select Hold on the On Line Control screen.

ii. Stop the boration per C12.5, if necessary iii. If reduced power steady state operation is anticipated, THEN, change ERCS TPM Power Source from NIS to calorimetric (LEFM preferred source) when steady state conditions are attained.

iv. Place CS-46300, MAKE-UP MODE SELECTOR, in AUTO.

v. Momentarily turn CS-46457, BORIC ACID MAKE-UP CONTROL, to START.

vi. Verify CS-46280, ROD BANK SELECTOR, is returned to AUTO.

1C28.4, UNIT 1 HEATER DRAINS Step 5.7, Single Heater Drain Pump Operation with Reactor Power Greater Than 50%

a. Verify reactor power is less than or equal to 95%.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS E

EXP CTED STUDENT RESPONSES CUE: If necessary as SM, direct the SS to stop the power reduction and remove 12 HDP from service.

a.

The crew may choose to start a additional condensate pump.

b.

When requested to open the discharge vent on 12 HD Pump wait 2 minutes and report valve is open.

This action is not modeled on the simulator.

LEAD

b. Place all three HTR DRN Pump selector switches to MANUAL.

c. IF Auto Speed Control is available, Then verify HTR DRN Pump Speed Selector switch for HDT Pump to be left running is in AUTO.

d. Verify the HDT DRN Pump Speed Selector switch for the pump to be stopped is in MANUAL.

e. Gradually lower the speed of the HDP to be removed from service to minimum while verifying the speed of the HDP to remain in service is increasing.

f.

Throttle open 15 FW heater drains to the condenser approximately equal amounts to maintain 15 FW HTR levels normal with HDT level stable or increasing.

g. Stop the Heater Drain Pump to be removed from service.

h. Open the discharge vent on the HTR DRN pump that was stopped.

i.

If necessary, Then start the standby condensate pump.

Retention: Life of Plant

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 13 of 29 2010 ILT NRC SIMULATOR EVALUATION #4, Rev. 0 Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES EVENT 2

7.

When the crew has removed 12 Heater Drain Pump from service, reduced power to 94% and/or at the discretion of the Lead Evaluator, enter the de-energization of Bus 16 (Relative Order 1, Event Trigger 1)

8.

After the bus 16 is deenergized, verify override DI-46924T auto DELETES(Relative Order 1) This restores light indication on the CT11 supply breaker.

9.

The following indications will be observed:

a.

Bus 16 will be de-energized

b.

All bus 16 source breakers indicate open

c.

D2 Diesel Generator will auto start

d.

11 Charging pump trips, seal injection and charging flows decrease

e.

Multiple annunciators associated with loss of Bus 16, including:

1) 47024-0204 BUS 16 4.16 KV UNDERVOLTAGE

2) 47024-0205 BUS 122 480V UNDERVOLTAGE

3) 47024-0206 BUS 121 480V UNDERVOLTAGE RO Lead As plant stabilization action SS may direct the RO to removing a letdown orifice from service IAW 1C12.1 since only one charging pump is running.

Respond to loss of 11 charging pump using C12.1 AOP 1 or by increasing the speed of 12 charging pump in manual Respond to loss of Bus 16 per C47024-0204 and 1C20.5 AOP 2 Record alarms and bus targets Determine cause of de-energization (local operator error)

Isolate and repair the problem, no repairs are needed Place Bus 16 sequencer in MANUAL Determine desired voltage source for bus 16 (CT-11 is preferred)

Place source breakers in MANUAL Place loads in pullout Re-energize Bus 16 Restore loads SS should enter the following T.S.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUE CREW POS P

T RESPONSES NCE OF EVENTS / INSTRUCTOR NOTES EX ECTED STUDEN

4) 47024-0704 BUS 16 SEQUENCER CHANNEL ALERT

5) 47024-0904 BUS 16 SEQUENCER FAILURE

6) 47024-1206 D2 EMERGENCY GENERATOR LOCAL ALARM

7) 47024-1003 BUS 16 SEQUENCER NOT IN SERVICE when sequencer placed in MANUAL

10. Perform the following actions as directed to simulate actions of personnel outside the Control Room:

a.

1 minutes after the bus de-energizes, call the control room as the Turbine Building operator and inform them that you inadvertently tripped breaker 16-8.

b.

When asked to check bus 16 breakers and targets, report UV relays are the only targets showing and that all bus breakers are open

c.

If asked as the system engineer for a recommendation regarding re-energizing the bus, recommend re-energizing the bus from CT-11

d.

If directed to investigate D2 Local alarm, acknowledge the alarm (Relative Order 2, Event Trigger 2) and report the alarm is due to failure of the constant lube oil alarm SS T.S. 3.8.9 Condition A T.S. 3.8.4 Condition A for Bus 16 inoperable(de-energized).

T.S. 3.8.1 Condition A T.S. 3.3.4.C Condition C Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES NOTE :

If the crew responds to 47024-0904 BUS 16 SEQUENCER FAILURE and goes to 1C20.7 AOP3, BUS 16 LOAD SEQUENCER OUT OF SERVICE have Unit 2 take over required actions. Completing these actions is not part of this scenario.

SS After Bus 16 power is restored the crew will respond to 47024-0904 BUS 16 SEQUENCER FAILURE and go to 1C20.7 AOP3, BUS 16 LOAD SEQUENCER OUT OF SERVICE Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 3

11. When the crew has restored power to Bus 16 or at the discretion of the Lead Evaluator, then enter the Steam Generator Pressure Transmitter PT-478 (blue) high failure. (Relative Order 3, Event Trigger 3).

a.

If directed as I&C to trip bistables, report that 2 I&C technicians will be available in 45 minutes.

(Note: bistables will not be tripped during this scenario.)

b.

If contacted as Operations Management, acknowledge the report of the failure, and agree to make other notifications to the NRC Resident Inspector, Duty Station Manager, etc., as asked.

c.

If contacted as the FIN team supervisor, inform the crew that you will write a work order and assign an I&C supervisor to investigate.

d.

If contacted as computer group, acknowledge the information and agree to investigate if further actions are warranted.

e.

If desired, allow the crew to hold a crew brief.

f.

Ensure rods are in AUTO prior to moving to next event.

g. Ensure charging is in AUTO prior to the next step.

LEAD LEAD LEAD SS Note: As a plant stabilization action the crew may close the B Steam Generator PORV prior to ARP entry.

C47011-0405. FW CONTROL SYSTEM TROUBLE Verify Steam Generator Level Control operating properly in automatic.

Control level in manual for any Steam Generator which has shifted to manual.

Refer to 1C51 Instrument Failure Guide.

1C51.3 12 STEAM GENERATOR PRESSURE 1P-478 HIGH Take manual control of 12 SG PORV and ensure valve is closed.

Verify SG Level Control operating properly in automatic.

Refer to T.S. LCO 3.3.2 Condition A and Table 3.3.2-1 Function 1e. (6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> to trip B/S)

Trip and concurrently verify the following bistables If the Thermal Power Monitor is selected to Calorimetric input, then perform the following:

o Check if TPM power is affected by the steam pressure channel failure.

o If TPM power is affected, then change TPM power source input from Calorimetric to NIS and notify the computer group.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 4

12. When the crew has completed actions for the Steam Generator Pressure transmitter failure or at the discretion of the Lead Evaluator, enter the malfunction to cause the Blue channel of Thot to fail high (Relative Order 4, Event Trigger 4).

a. If contacted as I&C to trip bistables, acknowledge the request and inform the Control Room that you will have two technicians available in 45 minutes.

(Note: bistables will not be tripped during this scenario.)

b. If contacted as Operations Management, acknowledge the report of the failure, and agree to make other notifications to the NRC, Duty Station Manager, etc. as asked.

c. If contacted as the FIN Team Supervisor, inform the crew that you will write a work order and assign an Electrical Supervisor to investigate.

RO LEAD LEAD/

RO Note: As a plant stabilization action, the crew should diagnose the failure and place Rod Control in manual.

C47012-0104, REACTOR COOLANT SYSTEM LO-LO TAVG Check RCS Tavg.

If due to an instrument malfunction, then:

Place rod control in MANUAL and adjust rod position as necessary.

Shift charging pump control to MANUAL and adjust speed as necessary.

Verify steam dumps are not armed. If armed and open, then:

Place steam dump controller in MANUAL.

If necessary, then close steam dumps using manual controller.

Refer to 1C51.

1C51.3 (Tavg Loop 1B 1T-403 - High)

Place rod control in MANUAL and maintain Tavg at Tref.

Place charging pump speed control in MANUAL and maintain pressurizer level.

If necessary, then take manual control of steam dump.

Select Blue channel on the Tavg defeat switch and pull out.

Return the following to AUTO:

Rod control Charging pump speed control Steam dump control.

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDEN RES T

PONSES SS Refer to Technical Specifications.

TS LCO 3.3.1 Condition A and Table 3.3.1-1 Functions 6,7 TS LCO 3.3.2 Condition A and Table 3.3.2-1 Function 4d TRM LCO 3.3.3 Condition A Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ CREW POS EXPECTED STUDENT RESPONSES SEQUENCE OF EVENTS / INSTRUCTOR NOTES EVENT 5

13. When the crew has completed actions for the Tave high failure or at the discretion of the Lead Evaluator, enter the malfunction to cause the Turbine to Trip and the Failure of the reactor to trip/ATWS (Relative Order 5, Event Trigger 5.

a.

Upon hearing the announcement of Reactor Trip, or when called as the Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, enter CAEP - Att E-0 to start the isolation (Relative Order 5a). When the isolation is complete, inform the crew that MSRs are isolated.

b.

When called as the Turbine Building Operator to open the reactor trip breakers, verify RO is driving in rods, wait 1 minute, and delete the malfunctions to prevent opening the Reactor Trip Breakers (Relative Order 6)

14. 11 TDAFW pump fails to auto start CREW CREW LEAD/

RO LEAD LEAD 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify Reactor Trip Manually trip the reactor.

If power is greater than 5%, then go to 1FR-S.1 1FR-S.1, RESPONSE TO NUCLEAR GENERATION/ATWS Verify Reactor Trip.

Critical Task: Insert negative reactivity into the core by inserting rods or establishing emergency boration flow to the RCS during the performance of FR-S.1.

Verify automatic control rod insertion OR manually insert Control Rods.

Verify Turbine Trip.

Critical Task: Establish and maintain 200 gpm AFW flow to the Steam Generator(s) before transition out of E-0, unless the transition is to FR-H.1, in which case the task must be initiated before RCPs are manually tripped in accordance with step 2 of FR-H.1.

Check AFW Pumps running. (Lead will need to manually start the TDAFW pump)

Manually start AFW pumps if required.

(Lead will need to manually start the 11 TDAFW pump, 12 MDAFW pump is OOS)

Initiate normal boration of RCS at 12 to 15 gpm Check if a Reactor Trip and a Turbine Trip have occurred.

Dispatch operator to locally open Reactor Trip Breakers OR locally open Rod Drive MG Set Motor and Generator Breakers.

Check if Reactor is subcritical.

Power Range Channels (NFM less than 5%.)

Retention: Life of Plant

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SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES CREW Intermediate Range Channels (NFM) - NEGATIVE STARTUP RATE.

Go to step 15.

Return to procedure and step in effect, 1E-0.

15. When the crew has returned to 1E-0, or at the discretion of the lead evaluator, then place the simulator in FREEZE and inform the crew that training has the duty.

16. Emergency Plan Classification Site Area Emergency - EAL SS2.1

QF-1075-02 Rev. 3 (FP-T-SAT-75) Page 21 of 29 2010 ILT NRC SIMULATOR EVALUATION #4, Rev. 0 SIMULATOR INPUT

SUMMARY

Relative Order System Or Panel Drawing Type Code Severity Or Value Event Trigger Timing Description 0

MALF RP07A A Rx Trip Breaker mech failure 0

MALF RP07B B Rx Trip Breaker mech failure 0

OVRD DI DI-46447B Block True AMSAC Switch to Block 0

OVRD DI DI-46447I Initiate False Disable AMSAC Switch 0

ANN MALF M47014:0606B DISABLE Disable AMSAC Annunciator 0

ERCS PT CP-1Y0501D RESET Disable AMSAC in Test 0

ERCS PT CP-1Y0500D SET Disable AMSAC Trouble 0

SIMED04 MALF ED17B Bus 16 sequencer failure 0

SIMFW08 MALF FW34A 11 TDAFWP auto start failure 1

SIMED04 OVRD DI DI-46924T TRUE 1

5 second DELETE Open breaker 16-8, CT-11 to bus 16 2

SIMDG02 REMOTE DG107 SILENCE 2

Acknowledge D2 local alarm 3

MALF/SYS OVRD RX216 1400 3

12 SG LOOP B (CHNL 111 -

BLU) P XMTR (1PT-478)

FAILS HIGH 4

MALF RX05C 4

Blue Channel Thot fails high Retention: Life of Plant Retain in: Training Program File Form retained in accordance with record retention schedule identified in FP-G-RM-01.

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SIMULATOR INPUT

SUMMARY

Relative Order System Or Panel Drawing Type Code Severity Or Value Event Trigger Timing Description 5

MALF TC12 5

Turbine Trip 5a RP07A & B DELETE Delete Reactor Trip Bkr Failures 6

SIMMS03A E0_ATT. J.sch Perform Attachment J

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SIMULATOR SETUP CHECKLIST Standard IC-10 Before Training Simulator Status:

___ 1.

"Training Load"

___ 2.

Step counters "ON"

___ 3.

Alarm sound "ON"

___ 4.

Reset to IC-10

___ 5.

Speed: REAL Cycle recorder power OFF then back ON to clear Yokogawa recorder memory Verify Summary matches Simulator Input Summary page in the SEG Boric Acid/RMU integrators set to: BA: 3, RMU: 10, and reset MOC I sheet displayed on C panel Check all ERCS alarms are cleared MOC Reactivity Briefing sheet available at Reactor Operator Desk Chart recorders operating and forwarded Turnover sheet/PRA sheet Log in on floor PCs using user ID: <pitrgsim> (password is the same as user ID)

Update Control Board Placards:

___ 1.

High Flux At Shutdown Alarm Setpoint placards: 1400 cps

___ 2.

Feedwater regulating valve position placard: 66/65, 67/64

___ 3.

RCS boron on the CVCS panel placard: 669 ppm

___ 4.

Turbine reference/setter values on the CVCS panel set to current (Target/Demand on-line positions)

___ 5.

Shift Reactivity Guidance placard: BA: 2.1 gallons, RMU: 67 gallons Dilutions @ 10 gal RMU, 1-2 times per shift Magnetic placards in place:

___ 1.

11 BA TANK "Lined Up For Service"

___ 2.

11 BA PUMP "Lined Up To 11 BA Tank"

___ 3.

CC TO SFP MV-32115 "In Service"

___ 4.

Blowdown 46470 "SGB To CDSR" Protected equipment tags in place:

___ 1.

11 TDAFW pump Attach Caution Tags to the following control switches:

___ 1.

Place CS-46439, 12 MD AFWP selector switch in MANUAL

___ 2.

Place CS-46425, 12 MD AFWP control switch in PULL OUT

___ 3.

Place CS-46483, 13 HTR DRN PUMP in PULL OUT

___ 4.

Place CS-46464, 13 HTR DRN PUMP SPEED SELECTOR in MANUAL

___ 5.

Place CS-46103, 13 HTR DRN PUMP SELECTOR in MANUAL ERCS driven recorders are on-scale (RCS temperature scaled to 555º F to 565º F)

ERCS alarm screen operating and alarms reset All ERCS terminals operating and set as follows:

CONF VARS R02 Alarm Summary Page CONE1 Group OP31_U1 R03 AFD CONC SAS (XS11)

R04 TPM CONG1 Group QP CCDATA R05 QP LOADFOLL ERCS-R01 Group RADMON_U1 R06 Alarm Summary Page

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ERCS single point displays:

CONB 1T0499A 1U1613A CONE2 1V4501A 1Q0340A ERCS TPM set (Calorimetric - Auto Scaling - LEFM)

Pens/Paper/Markers available on the simulator B oard-mounted EAL Table is cleaned E AL sticker books in F3-2 are checked for missing stickers Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.

___ 7.

1FR-S.1

___ 8.

1C1.4

___ 9.

47024-0204

___ 10.

1C20.5 AOP 2

___ 11.

T.S. 3.8.9

___ 12.

T.S. 3.8.4

___ 13.

C47011-0405

___ 14.

1C51.3

___ 15.

T.S. 3.3.1

___ 16.

T.S. 3.3.2

___ 17.

TRM 3.3.3

___ 18.

1C28.4

___ 19.

C47024-0904

___ 20.

___ 21.

On the NIS panel, verify Scaler Timer power switch is in Off position.

Set Turbine Control HMI Displays as follows:

___ 1.

U1 E-H Turb Cont STA 2 (48087) to:

Control Valve Overview

___ 2.

U1 Turb Aux Cont (48088) to:

Turb Overview

___ 3.

U1 E-H Turb Cont STA 1 ( 48086) to:

On Line Control DEHC alarms cleared

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Post-Scenario Checklist EOOS computer is cleared of information added during the scenario Computer generated PINGP 577 cleared.

Procedures to be used during scenario are cleaned of any place keeping marks

___ 1.

F3-2

___ 2.

F3-2.1 Bases

___ 3.

F3-2 Copy 275

___ 4.

SWI O-28

___ 5.

Boration Card

___ 6.