Text

2016 Prairie Island Nuclear Generating Plant Initial License Examination Administered Simulator Scenarios
	ML16141A511
Person / Time
Site:	Prairie Island
Issue date:	06/10/2016
From:	Mcneil D; NRC/RGN-III/DRS/OLB
To:	;
References
	PI-ILT-NRC-1601S, Rev. 0
	Download: ML16141A511 (71)
	v • d • e

Page 1 of 18 SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

PI-ILT-NRC-1601S SEG TITLE:

2016 ILT NRC SIMULATOR EVALUATION #1 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME: 2.0 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Shawn Sarrasin 11/23/2015 Instructor Date Reviewed by:

Fred Collins 12/28/2015 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Fred Collins 12/28/2015 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Mike Petersen 3/25/2016 Training Supervision Date

Page 2 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. N44, Power Range Nuclear Instrument, fails LOW.

2. 1LT-921, 11 RWST Level Transmitter, fails LOW.

3. 11 Reactor Vessel Support Cooling Fan trips OFF.

4. CV-31167, 1A Turbine Control Intercept Valve, and CV-31173, 2B Turbine Control Intercept Valve, fail CLOSED.

5. Dropped Rod - Control Bank D Rod K7.

After EOP Entry:

1. Failure of the reactor to automatically trip.

2. CS-46450, C Panel Reactor Trip Switch fails to operate.

3. Failure of Containment Isolation to automatically actuate.

Abnormal Events:

1. Nuclear Instrument Failure.

2. Loss of GAP Cooling.

3. Turbine Malfunction.

4. Dropped Rod.

Major Transients:

1. Small Break LOCA.

Critical Tasks:

1. Trip Reactor Coolant Pumps within ten minutes of RCP trip criteria being met.

2. Manually actuate Containment Isolation or close Containment Isolation valves such that at least one valve is closed on each penetration before the end of the scenario.

Page 3 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 CRITICAL TASK SHEET Critical Task:

Trip Reactor Coolant Pumps within ten minutes of RCP trip criteria being met.

Safety Significance:

Failure to trip the RCPs under the postulated plant conditions lead to core uncovery and to fuel cladding temperatures in excess of 2200F.

Thus, failure to perform the task represents misoperation or incorrect crew performance in which the crew has failed to prevent degradation of the fuel cladding barrier to fission product release.

Plant Conditions:

Small Break LOCA.

Break size less than 2.5 inches.

At least one Safety Injection Pump running.

RCPs Running.

RCP trip criteria are met.

Cues:

Injection flow exists to RCS:

o At least one SI Pump running and flow indicated.

-OR-o At least one RHR Pump running and flow indicated.

RCS Pressure is less than 1250 psig [1575 psig].

An operator controlled cooldown has NOT been initiated.

Performance Indicator:

Manually stopping RCPs using:

CS-46255, 11 REACTOR CLNT PUMP.

CS-46256, 12 REACTOR CLNT PUMP.

Feedback:

Indication that all RCPs are stopped.

Both RCP Pump green indicating lights LIT.

Both RCP Pump red indicating lights NOT LIT.

RCP flow decreasing.

Page 4 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 CRITICAL TASK SHEET Critical Task:

Manually actuate Containment Isolation or close Containment Isolation valves such that at least one valve is closed on each Containment penetration before the end of the scenario.

Safety Significance:

Failure to close at least one Containment Isolation valve on each containment penetration results in unnecessary degradation of the Containment barrier that is relied upon in the safety analysis for a Loss of Coolant Accident.

Plant Conditions:

LOCA is occurring.

At least one Containment penetration has both Containment Isolation valves fail to close automatically.

At least one Containment Isolation valve on each Containment penetration can be closed manually from the control room.

Cues:

Indication that SI actuated.

AND

At least one of the following indications in the Control Room:

o Containment Isolation did NOT actuate.

o Both valves on at least one Containment penetration are open.

Performance Indicator:

Manually actuating Containment Isolation using one of the following:

o CS-46085.

o CS-46113.

Closing at least one Containment Isolation per Containment penetration by manipulating controls from the Control Room or directing an out-plant operator.

Feedback:

Containment Isolation Status Light Panel indicates at least one Containment Isolation valve is closed on each Containment penetration.

Page 5 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO OVERVIEW:

SEQUENCE OF EVENTS:

Event 1: Yellow Channel Power Range Nuclear Instrument fails LOW

N44 indicator pegs low.

Bank D Control Rods step out two steps.

The crew will perform the following per 1C51.4:

Place control rods in manual.

Remove N44 from service.

Restore Tavg to Tref and place control rods in auto.

The crew will enter TS LCO 3.3.1 Conditions A, D, E, Q, and R.

Event 2: 11 RWST Level Transmitter fails LOW

One RWST level indicator will peg low.

Other RWST level indicator will remain unchanged.

The crew will enter TS LCO 3.3.3 Condition A.

Event 3: Loss of GAP Cooling

11 Reactor Support Cooling fan trips.

Reactor Support Cooling Low Flow annunciator is received.

The crew will respond per C47021-0503 and start 12 Rx Support Cooling Fan.

Event 4: Turbine Malfunction requiring a Rapid Downpower

CV-31167, Intercept Valve 1A, fails closed.

10 seconds later, CV-31173, Intercept Valve 2B, fails closed.

Plant load lowers and control rods automatically step in.

The crew enters 1C23 AOP2 for a Turbine Malfunction.

Crew diagnoses that two intercept valves from diagonally opposite MSRs have closed.

The crew performs a rapid downpower to 50% per 1C1.4.

Event 5: Dropped Rod

Control Bank A Group 1 Rod K-7 will indicate zero steps.

RCS Tavg will lower.

NI Power will lower.

A negative flux rate reactor trip will be received.

The reactor will fail to automatically trip.

The crew will diagnose a dropped rod and manually trip the reactor per 1C5 AOP4.

The crew will enter 1E-0 and transition to 1ES-0.1.

Page 6 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 Event 6: Small Break LOCA

PRZR level and pressure will lower.

CTMT pressure and humidity will rise.

The crew will actuate Safety Injection and re-enter 1E-0.

The crew will trip both RCPs.

Containment Isolation will fail to automatically actuate.

The crew will manually actuate Containment Isolation.

The crew will transition to 1E-1.

The crew will stop RHR pumps.

Page 7 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

1.

SIMULATOR PRE-BRIEF:

a.

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

2.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

c. Verify crew performs walk down of control boards and the 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

Page 8 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 1 EVENT 1 (CONT)

Booth Operator:

1.

After the crew has assumed the duty and/or at the discretion of the lead evaluator, enter:

Trigger 1, PR Yellow Channel N44, fails LOW.

2.

If contacted as I&C to trip bistables, inform the crew two I&C Technicians will be available in 45 minutes.

3.

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

4.

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.

5.

If contacted as Nuclear Engineering, acknowledge the request to perform SP-1120.

Plant Response:

1.

Control rods step out automatically.

2.

The following annunciators will be received:

a.

47013-0201, NIS PR NEG FLUX RATE CH ALERT.

b.

47013-0203, NIS PR RANGE DEVIATION.

RO SS RO SS LEAD 1C5 AOP1, UNCONTROLLED ROD MOTION Check generator load stable.

Place rod bank selector switch to MANUAL.

Check rod motion stopped.

Determine N44 is failed.

Go to 1C51.4.

1C51.4, PWR RNG NUCLEAR INSTR N LOW Place rods in MANUAL and maintain Tavg at Tref.

Refer to the following TS requirements:

o Enter TS LCO 3.3.1 Condition A Reference Table 3.3.1-1 immediately.

o Enter TS LCO 3.3.1 Condition D Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and perform SP-1120 OR Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months o Enter TS LCO 3.3.1 Condition E Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months o Enter TS LCO 3.3.1 Condition Q Verify P-10 is in required state for existing unit conditions in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR Be in Mode 3 in 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months o Enter TS LCO 3.3.1 Condition R Verify P-7, P-8, and P-9 are in required states for existing unit conditions in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR Be in Mode 3 in 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months o TRM TLCO 3.2.1 Condition A.

o SR 3.2.4.2 (SP-1120).

QPTR every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Remove N44 from service as follows:

o Place ROD STOP BYPASS SW in N-44 o Place POWER MISMATCH BYPASS SW in N-44 o Place UPPER SECTION CURRENT COMPARATOR DEFEAT SW in N-44

Page 9 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

RO /

SS o Place LOWER SECTION CURRENT COMPARATOR DEFEAT SW in N-44 o Place COMPARATOR CHANNEL DEFEAT SW in N-44 o Remove N-44 PR B drawer instrument fuses.

o Remove N-44 PR A drawer control power fuses.

o Verify annunciators 47013-0101, 0102, 0201, 0202, and 0403 are received.

o Verify status lights LIT for 44178-0406 & 0407; and 44205-0404.

Restore Tavg to Tref with rods and return rod control to AUTO.

Trip bistables within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Check P7 in its required state in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Check P8 and P9 in its required state in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Log I every 30 minutes.

Verify NR-45 selected to operable channel.

Check TPM.

Notify Nuclear Engineering to perform SP-1120.

Page 10 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 2 Booth Operator:

1.

After the crew has removed N44 from service, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 2, 11 RWST Level Transmitter, fails LOW

2.

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

3.

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.

4.

If contacted as the out-plant operator to inspect for leakage from the RWST, wait approximately 2 minutes and report there is NO leakage.

Plant Response:

1.

LI-920 normal indication.

2.

LI-921 indicates zero.

3.

The following annunciators will be received:

a.

47019-0403, 11 RWST LO-LO LVL.

b.

47019-0503, 11 RWST LO LVL.

LEAD SS C47019-0403, 11 RWST LO-LO LVL Check alarm is valid using alternate indications:

o 47016-0104, 11 RWST LO-LO LVL, LIT o 1LI-920, 11 RWST LI o 1LI-921, 11 RWST LI Determine safeguards initiation has not occurred.

Determine NO operating pumps are taking a suction from the RWST.

Determine an instrument malfunction has occurred.

Initiate Action Request and Work Request.

Enter TS LCO 3.3.3 Condition A due to one of two channels of Function 16 is NOT operable.

o Restore required channel to OPERABLE status within 30 days.

Determine RWST is still OPERABLE (TS LCO 3.5.4).

Page 11 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

1. After Shift Supervisor has addressed Technical Specifications for RWST failure, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 3, 11 RX SUPPORT COOLING FAN TRIP.

2. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc.

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

Plant Response:

1. 11 Rx Support Cooling fan trips.

2. Annunciator 47021-0503 alarms.

LEAD/

RO C47021-0503, REACTOR SUPPORT COOLING LO FLOW Determine no reactor support cooling fan running.

Determine no SI signal present.

Start standby reactor support cooling fan.

Page 12 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 4 EVENT 4 (cont)

Booth Operator:

1. After 12 Reactor Vessel Support Cooling Fan is started, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 4, Two Opposing Turbine Control Intercept Valves Fail Closed.

2. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc.

3. If contacted as the FIN Team Supervisor, inform the crew that you will write a work order and assign a Turbine Control Engineer to investigate.

4. If contacted as Unit 2 Control Room Operators to monitor Unit 1 Heater Drain Tank alarms (Panel F), then acknowledge request and inform Unit 1 Operators that an extra operator will monitor Panel F.

Plant Response:

1. MW load lowers.

2. RCS Tavg rises.

3. Rods automatically step out initially then step in.

4. CV-31167 (Intercept Valve 1A) closed indication.

5. CV-31173 (Intercept Valve 2B) closed indication.

NOTE It is NOT intended to wait for the plant to reach 50%

power prior to proceeding to the next event. Once the Lead Evaluator is satisfied with the reactivity manipulation, proceed to Event 5.

LEAD LEAD /

RO 1C23 AOP2, MALFUNCTION OF TURBINE EH CONTROL SYSTEM Determine EH oil pressure is normal.

Determine a turbine runback is NOT in progress.

If the symptoms indicate a potential problem with the EH oil system, then notify the Turbine Building operator of the symptoms and direct the operator to locally check operation of the system.

Determine load cycling is NOT occurring.

Determine flow is NOT lost to one of the LP turbines.

Determine two valves on the same side of the turbine are NOT closed.

Determine two valves from diagonally opposite MSRs have closed.

Reduce turbine load to 50% per 1C1.4 AOP1.

1C1.4 AOP1, RAPID POWER REDUCTION UNIT 1 Determine the predicted Boron addition and final Control Rod Position by obtaining values from the appropriate contingency reactivity plan.

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

Control Rods in manual during the load reduction.

Place pressurizer heaters to ON.

Using the On Line Control screen, select the Control Mode pop-up screen.

Select the desired control mode (VPC, FSP, or LOAD).

Using the On Line Control screen, select the Demand Rate pop-up screen.

Select the desired rate of load change.

Set the desired Target setting using the On Line Control screen.

Using the On Line Control screen, select the Go control to initiate load reduction.

1C12.5, UNIT 1 BORON CONCENTRATION CONTROL

Page 13 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

RO Verify the Boric Acid integrator is reset.

Set 1YIC-110, BA TO BLENDER BATCH INTEGRATOR, to quantity desired.

Place CS-46300, MAKE-UP MODE SELECTOR, to BORATE.

If desired, then adjust 1HC-110, BA TO BLENDER FLOW CONT, to MANUAL and adjust output for desired flow rate.

Momentarily place CS-46457, BORIC ACID MAKE-UP CONTROL, to START, to initiate the boration.

When the desired quantity of boric acid has been added, then verify automatic makeup stopped as indicated by CS-46457, BORIC ACID MAKE-UP CONTROL, green light LIT.

If additional boration is desired, then return to step 2.

When the boration is complete, then verify 1HC-110, BA TO BLENDER FLOW CONT, is in AUTO.

Reset the Boric Acid integrator.

Perform a 10 gallon flush.

Page 14 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

1. When the lead evaluator is satisfied with the reactivity manipulation, then enter:

Trigger 5, Dropped Rod K CBA GR1.

2. Upon hearing the announcement of Reactor Trip, or when called as the Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, then open and run schedule file E-0_Att-J.sch located in X:\\\\Trex_PI\\Lightning\\Schedule\\EOPs. When the isolation is complete, inform the crew the MSRs are isolated.

Plant Response:

1. CB-D Rod K-7 rod bottom indication.

2. NIS power and RCS Tavg lowering.

3. Flux Rate Reactor Trip and Rod at Bottom Alarms.

4. The reactor fails to automatically trip.

5. Panel C Reactor Trip Switch does not operate.

EMERGENCY PLAN CLASSIFICATION ALERT - SA2.1 due to the reactor failing to automatically trip during the high negative flux rate condition and the crew successfully manually tripping the reactor.

However, this classification may NOT be used due to a higher classification being met in the next event.

RO RO/

LEAD 1C5 AOP4, DROPPED RCCA Confirm Rod Drop using diverse indications:

Rod Position Indication and RCS Tavg Changes OR Rod Position Indication and NIS Changes.

Manually trip the reactor.

Perform 1E-0.

C47017-0404, FLUX RATE REACTOR TRIP Perform 1E-0.

1E-0, REACTOR TRIP OR SAFETY INJECTION Determine the reactor did NOT automatically trip.

Manually trip the reactor.

Manually trip the main turbine.

Verify both safeguards buses are energized.

Determine SI is NOT actuated and NOT required.

o No SI Actuated or SI first-out annunciator.

o Both SG pressures >530 PSIG.

o PRZR pressure >1830 PSIG.

o Containment pressure <3.5 PSIG.

Go to 1ES-0.1 1ES-0.1, REACTOR TRIP RECOVERY Announce Unit 1 Reactor Trip.

Transfer Steam Dump to Pressure Mode.

Check RCS temperatures.

Check CL Header Pressures greater than 75 psig.

Notify TBO to isolate Unit 1 MSRs per Attachment J.

Check FW status.

Verify all control rods inserted.

Page 15 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 6 EVENT 6 (cont)

Booth Operator:

1. After the crew has transitioned to 1ES-0.1, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 6, Small Break LOCA.

2. Upon hearing the announcement of Safety Injection, or when called as the Turbine Building Operator to secure the Turbine Building Roof Exhausters, wait 2 minutes and report the Turbine Building Roof Exhausters are all secured.

3. If Control Room personnel ask if Unit 2 personnel are available to perform Attachment L, then inform the Control Room that Unit 2 personnel are NOT available for performing Attachment L.

4. If Control Room personnel ask if Unit 2 personnel are available to secure Diesel Generators and/or Safeguards Cooling Water Pumps, then inform the Control Room that Unit 2 personnel WILL secure the Diesel Generators and/or Safeguards Cooling Water Pumps.

Plant Response:

1. PRZR level and pressure lowers.

2. CTMT pressure and humidity rise.

3. RCS leak rate rises.

CRITICAL TASK Trip both Reactor Coolant Pumps within 10 minutes of meeting RCP Trip Criteria.

Booth Operator:

1.

If contacted by the Control Room to report status of CAT 1 Vent Zone openings, then inform the CR that all CAT 1 Vent Zone openings are closed.

2.

If Control Room personnel ask for status of Unit 2 Cooling Water/Chilled Water lineup, then inform the LEAD /

RO SS RO /

SS LEAD 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify the reactor is tripped.

o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

Verify the Main Turbine is tripped.

o Left and right Stop Valves are CLOSED.

Determine both Safeguards buses energized.

Determine SI is either actuated and/or required.

o Check Pressurizer Pressure and determine that SI is required.

Perform Attachment L (see SEG pages 16, 17, & 18).

Check AFW Status.

o Total AFW flow >200 GPM.

o AFWP discharge pressure >1000 PSIG.

o Maintain SG NR level 5-50% [WR levels 50-59%].

Check RCS Tavg trending to 547°F.

o Cold leg temperature is used if RCPs have been tripped.

Check PRZR PORVs and Spray valves closed.

Stop RCPs due to trip criteria being met.

o Injection flow to the RCS.

o RCS Pressure < 1250 PSIG [1576 PSIG].

o Operator Controlled Cooldown NOT initiated.

Determine SGs are NOT faulted.

o No SG pressure decreasing in an uncontrolled manner.

o No SG completely depressurized.

Determine SG Tubes are NOT ruptured.

o Condenser air ejector radiation normal.

o SGB radiation normal.

o Main Steam Line radiation normal.

Determine RCS is NOT intact due to Containment pressure rising.

Go to 1E-1.

Page 16 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 6 (cont)

Control Room that Unit 2 Cooling Water/Chilled Water valves are in their safeguards positions.

3.

If Control Room personnel ask for status of Battery Room Temperatures, then inform the Control Room that Battery Room temperatures are 74°F.

CRITICAL TASK Manually actuate Containment Isolation or close Containment Isolation valves such that at least one valve is closed on each penetration before the end of the scenario.

EMERGENCY PLAN CLASSIFICATION SITE AREA EMERGENCY -FS1 due to loss of RCS fission product barrier due to Small Break LOCA and potential loss of Containment fission product barrier due to failure of Containment Isolation to automatically actuate during a Safety Injection.

ATTACHMENT L MALFUNCTIONED COMPONENT LIST Panel 44104 ID Component Control Switch C

A1 CV-31318 CS-46266 C

B1 CV-31319 CS-46262 B

D2 CV-31339 CS-46166 B

A3 MV-32199 CS-46173 B

B3 MV-32166 CS-46132 A

A4 CV-31545 CS-46235 A

B4 CV-31546 CS-46234 A

C4 CV-31434 CS-46237 A

D4 CV-31435 CS-46236 A

A5 CV-31436 CS-46231 A

B5 CV-31437 CS-46230 A

C5 CV-31438 CS-46233 LEAD 1E-1, LOSS OF REACTOR OR SECONDARY COOLANT Check if RCPs should be stopped.

Determine SGs are NOT faulted.

Check SG levels.

Determine secondary radiation levels are normal.

Check PRZR PORVs CLOSED.

Reset SI and CI.

Establish IA to CTMT.

Check power available to charging pumps.

Establish charging flow.

Determine SI should NOT be stopped.

Secure RHR pumps.

1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION Verify Safeguards Component Alignment:

Verify both trains of SI actuated:

o Both RHR pumps or both SI pumps - RUNNING.

"SI NOT READY" lights - NOT LIT.

"SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

"CONTAINMENT ISOLATION" lights - LIT FOR PLANT CONDITIONS.

o CI Phase A fails to actuate.

o Manually actuate CI or manually align individual components per the table on page

17.

Check Category 1 Vent Zone Boundary.

Close MV-32115, 122 SFP HX INLT HDR MV B.

Check Cooling Water Header Pressures - BOTH GREATER THAN 65 PSIG.

Verify Plant Announcements Complete.

Check If Main Steamlines Are Isolated.

Determine MSIVs, Bypass Valves, and Containment Instrument Air Valves do NOT need to be closed.

Verify SI Flow.

Page 17 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

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

D5 CV-31439 CS-46232 D

B6 MV-32044 CS-46339 D

C6 MV-32058 CS-46340 D

D6 MV-32040 CS-46969 D

E6 MV-32043 CS-46968 A

A7 CV-31621 CS-46054 A

B7 CV-31622 CS-46055 E

C7 MV-32023 CS-46413 E

D7 MV-32024 CS-46414 OP*

D8 CV-31402 CS-70612 OP*

E8 CV-31403 CS-70613 RMR**

A10 CV-31750 CS-19447 RMR**

B10 CV-31022 CS-19449 D15 CV-31438 OR CV-31439 CS-46233 OR CS-46232 E15 CV-31438 OR CV-31439 CS-46233 OR CS-46232

Control Switch located in Out-Plant. If examinee directs the out-plant operator to close the 11/12 SGB Isolation Valves, then enter REMOTES SG102 & SG103 to CLOSE.

- Panel located opposite R-11/R-12 Radiation Monitor Racks.

- - Closing either CV will cause both SMP A and ANN Discharge valves to CLOSE.

Verify RHR Flow.

Verify Containment Spray is actuated (if necessary).

Check RCP Cooling.

Verify Local Actions Complete.

Verify Generator Breakers - OPEN.

Verify All Heater Drain Pumps - STOPPED.

Check Turbine Valves:

o Turbine reheat and intercept valves - CLOSED.

o Open turbine drain valves.

Verify Main Feedwater Alignment:

o Both main feedwater pumps - STOPPED.

o Main and bypass FRVs - CLOSED.

Verify All Condensate Pumps - STOPPED.

Verify Steam Dump in "STM PRESS" Mode.

Verify Unit 1 Cooling Water/Chilled Water Alignment:

o CFCU control switches - "SLOW".

o CFCU dampers - ALIGNED TO DOME.

o Unit 1 cooling water/chilled water valves closed.

o Unit 1 CRDM shroud cooling supply and return valves - CLOSED.

o CFCU cooling water supply and return valves -

OPEN.

o CFCU chilled water supply and return valves -

CLOSED.

Verify 11 Safeguards Screenhouse Ventilation lineup.

Verify Control Room Ventilation Alignment:

o Chillers and fans - RUNNING.

o Control room chiller suction/discharge tie closed -

STATUS LIGHT LIT.

Verify Unit 2 Cooling/Chilled Water Alignment.

Verify 21 Safeguards Screenhouse Ventilation lineup.

Verify 11 and 12 Battery Charger Operation is normal.

Verify Battery Room temps less than 84°F.

Check status of Spent Fuel Cooling.

Page 18 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Check Status of Notifications.

Notify SS Of Any Discrepancies.

END Once the crew has secured RHR pumps and/or at the discretion of the Lead Evaluator, then place the simulator in FREEZE. Inform the crew that training has the duty.

Page 1 of 21 SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

PI-ILT-NRC-1602S SEG TITLE:

2016 ILT NRC SIMULATOR EVALUATION #2 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME: 2.0 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Shawn Sarrasin 11/23/2015 Instructor Date Reviewed by:

Fred Collins 12/15/2015 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Fred Collins 12/15/2015 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Mike Petersen 3/25/2016 Training Supervision Date

Page 2 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 Guide Requirements Evaluation Objectives:

Evaluate the crews ability to:

1.

Raise SI Accumulator pressure per 1C18.

2.

Perform a load increase from 90% to 95% power per 1C1.4.

Evaluate the crews ability to diagnose and respond to a:

3.

First Stage Pressure Instrument failing LOW per 1C5 AOP1 and 1C51.2.

4.

Loss of Charging Flow to the Regenerative Heat Exchanger per 1C12.1 AOP2.

5.

Fire Protection Line Break per C31 AOP1.

6.

Steam Generator Fault into Containment per 1E-0 and 1E-2.

7.

Loss of Containment Cooling per Attachment L of E-0 or 1FR-Z.1.

Training Resources:

1.

Full Scope Simulator

2.

NRC Evaluation Team

3.

Booth Operator (Backup Communicator)

4.

Primary Communicator Related PRA Information:

Initiating Event with Core Damage Frequency:

INTERNAL FLOOD (45.4%)

MSFLB (<1%)

Important Components:

NONE Important Operator Actions with Task Number:

OPERATORS FAIL TO ISOLATE AFW TO AFFECTED SG (1.3%)

CRO 301 003 06 01 000 - Faulted Steam Generator Isolation

Page 3 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. 1PT-485, Turbine First Stage Pressure Instrument, fails LOW.

2. CV-31328, Regenerative HX Charging Line Valve, fails to the CLOSED position.

3. Fire Protection System automatically starting on low fire header pressure.

After EOP Entry:

1. 11 and 13 Containment Fan Coil Units fail to start in SLOW or FAST after SI signal.

2. 12 and 14 Containment Fan Coil Units fail to automatically start in SLOW after SI signal.

3. 11 and 12 Containment Spray Pumps fail to automatically start on HIGH-HIGH Containment Pressure.

Abnormal Events:

1. Uncontrolled Rod Motion.

2. Loss of Charging Flow to Regenerative Heat Exchanger.

3. Fire Protection Line Break.

Major Transients:

1. 11 Steam Generator Faults into Containment.

Critical Tasks:

1. Manually actuate containment cooling as necessary to prevent containment pressure from exceeding 46 psig.

2. Establish feedwater flow to the Steam Generators before both Steam Generator Wide Range Levels lower below 9% [20%] (Only applicable if both AFW Pumps trip on low discharge pressure).

3. Stop feed flow to the faulted Steam Generator before the end of the scenario.

Page 4 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 CRITICAL TASK SHEET Critical Task:

Manually actuate containment cooling as necessary to prevent containment pressure from exceeding 46 psig.

Safety Significance:

Failure to actuate sufficient containment cooling during a high energy release into containment will result in containment pressure exceeding the design limit of 46 psig. Exceeding this limit will result in a loss of the Containment Barrier.

Plant Conditions:

At least one of the following accidents:

LOCA into Containment.

Unisolable Steam Line Break into Containment.

Containment pressure will exceed 46 psig if no operator action is taken to start available containment cooling equipment.

Sufficient containment cooling equipment is available to start from the Control Room to prevent containment pressure from exceeding 46 psig.

Cues:

Containment pressure is rising.

Containment cooling equipment fails to start, actuate, or align to their safeguards alignment.

Performance Indicator:

Starting, actuating, or aligning the following equipment, as necessary, to establish sufficient containment cooling to prevent containment pressure from exceeding 46 psig:

Containment Fan Coil Units (CFCUs)

Cooling Water / Chilled Water supply to CFCUs.

Containment Spray System Feedback:

Containment pressure lowering or stable below 46 psig.

Page 5 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 CRITICAL TASK SHEET Critical Task:

Establish feedwater flow to the Steam Generators before both Steam Generator Wide Range Levels lower below 9% [20%].

Safety Significance:

With insufficient feedwater flow, the Steam Generators dry out, causing an RCS pressure increase that opens the pressurizer PORVs. The open PORVs create a small break LOCA that challenges the Core Cooling CSF.

Plant Conditions:

SGs are required for heat sinks.

Feedwater flow is available but not established from any of the following:

o Auxiliary Feedwater Pumps o Main Feedwater Pumps o Condensate Pumps

Sufficient time is available to align feedwater flow to at least one Steam Generator prior to Wide Range level lowering below 9%

[20%].

NO ATWS

NO Station Blackout Cues:

Less than 200 GPM of feedwater flow to the Steam Generators.

Both Steam Generator levels lowering.

RCS pressure is above the pressure of all Steam Generators.

Performance Indicator:

Prior to the need to establish bleed and feed, the crew manipulates controls to establish feedwater flow into at least one SG with one or more of the following:

o Auxiliary Feedwater Pumps o Main Feedwater Pumps o Condensate Pumps

The crew establishing RCS bleed and feed instead of using a feedwater source would most likely constitute a failure.

Feedback:

Increasing water level in at least one Steam Generator.

Feedwater flow into at least one SG.

Total feedwater flow is at least 200 GPM.

Page 6 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 CRITICAL TASK SHEET Critical Task:

Stop feed flow to the faulted Steam Generator before the end of the scenario.

Safety Significance:

Failure to stop feed flow to a Steam Generator that is faulted into Containment and can NOT be isolated will result in a challenge to the Containment Barrier.

Plant Conditions:

One faulted Steam Generator.

The fault is into Containment.

The fault can NOT be isolated.

A Red/Orange Path in Integrity CSF is likely and can NOT be prevented by crew actions.

Subcriticality, Core Cooling, and Heat Sink CSFs are green or yellow.

Cues:

A single Steam Generator depressurizing in an uncontrolled manner or completely depressurized.

Main feedwater or auxiliary feedwater continues to be delivered to the faulted SG.

Performance Indicator:

Close/Secure the following valves/pumps aligned to the faulted Steam Generator (as necessary):

AFW Pump Discharge Valve(s)

AFW Pump(s)

Main and Bypass Feedwater valve(s)

MFW Pump(s)

Feedback:

AFW flow to the faulted Steam Generator is secured.

SG Feedwater Flow to the faulted Steam Generator is secured.

Page 7 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO OVERVIEW:

SEQUENCE OF EVENTS:

Event 1: Raise SI Accumulator Pressure

The crew will raise 12 Safety Injection Accumulator pressure per 1C18.

Event 2: Raise Reactor Power to 95%

The crew will place rods in manual.

The crew will perform alternate dilutions per 1C12.5.

The crew will operate the turbine to raise load.

Event 3: First Stage Pressure Instrument fails LOW

Rods will automatically step in.

The crew will place rod control in manual per 1C5 AOP1.

The crew will perform actions per 1C51.2.

The SS will enter TS LCO 3.3.1 Conditions A and R.

Event 4: Loss of Charging Flow to Regenerative Heat Exchanger CV-31328, REGEN HX CHG LINE OUTLET, fails CLOSED.

Charging flow and pressurizer level lower.

The crew will secure normal letdown and stop one charging pump.

The crew will place excess letdown in service.

Event 5: Fire Protection Line Break

Fire header pressure will lower to 90 psig.

The Screen wash Pump, MD Fire Pump, and DD Fire Pump will start on low fire header pressure.

Fire header pressure will stabilize at 110 psig.

The crew will be unable to isolate the fire header leak.

The crew will secure all fire protection pumps per 1C31 AOP1.

Event 6: 11 Steam Generator Faults into Containment

Pressurizer level and pressure lowers.

RCS temperature lowers.

Containment pressure rises.

The crew will trip the reactor, actuate SI, and enter 1E-0.

The crew will transition to 1E-2 and isolate 11 Steam Generator.

If a RED path in Integrity CSF occurs, then a transition to 1FR-P.1 will be necessary.

Page 8 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 Event 7: Loss of Containment Cooling

11 and 13 CFCUs will stop running in FAST and fail to automatically shift to SLOW.

12 and 14 CFCUs will fail to start in SLOW or FAST speed.

11 and 12 Containment Spray Pumps will fail to automatically start.

The crew will manually start 11 and 13 CFCUs in SLOW speed and manually start 11 and 12 Containment Spray Pumps per Attachment L of 1E-0 or 1FR-Z.1.

Page 9 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

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

1.

SIMULATOR PRE-BRIEF:

a.

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

2.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

c. Verify crew performs walk down of control boards and the 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 Booth Operator:

1. After the crew has assumed the duty, they will raise 12 Safety Injection Accumulator pressure per 1C18.

2. When contacted as the out-plant operator to perform steps 6.5.1 - 6.5.2 of 1C18, wait approximately 2 minutes and report completion.

3. When contacted as the out-plant operator to perform step 6.5.7 of 1C18, wait approximately 2 minutes and report completion and d/p is zero.

4. When contacted as the out-plant operator to perform steps 6.5.14 and 6.5.15 of 1C18, wait approximately 2 minutes and report completion.

5. When contacted as the SI System Engineer, acknowledge completion of raising pressure in 12 SI Accumulator.

Plant Response:

1. 12 SI Accumulator pressure rises.

2. Annunciator 47018-0204, 12 ACC LO PRESS, clears.

LEAD 1C18, ENGINEERED SAFEGUARDS SYSTEM UNIT 1 Direct an out-plant operator to perform steps 6.5.1 -

6.5.3 of 1C18.

Under administrative control, OPEN CV-31444, NITROGEN TO 12 ACCUM, using CS-46220.

Under administrative control, OPEN CV-31440, ACCUM NITROGEN SPLY, using CS-46212.

Direct an out-plant operator to perform step 6.5.6 of 1C18.

When 12 SI accumulator pressure reaches 750 psig, then CLOSE CV-31440, ACCUM NITROGEN SPLY, using CS-46212.

CLOSE CV-31444, NITROGEN TO 12 ACCUM, using CS-46220.

Independently verify CV-31444 is closed.

Independently verify CV-31440 is closed.

Direct an out-plant operator to perform steps 6.5.12 and 6.5.13 of 1C18.

Notify the SI System Engineer of completion of procedure.

Page 10 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 2 EVENT 2 (cont)

Booth Operator:

1. After the crew has completed raising pressure in 12 SI Accumulator and/or at the discretion of the lead evaluator, then:

a.

As the Shift Manager, direct the Unit 1 SS to raise Unit 1 Reactor Power to 95%.

2. If contacted as the duty chemist, acknowledge Unit 1 power will be raised from 90% to 95%.

Plant Response:

1. Reactor Power rises.

2. Generator Load rises.

3. RCS Tavg rises.

NOTE It is NOT intended to wait for the plant to reach 40%

power prior to proceeding to the next event. Once the Lead Evaluator is satisfied with the reactivity manipulation, proceed to Event 3.

RO/SS RO/SS RO/SS 1C1.4, UNIT 1 POWER OPERATION Place CS-46280, ROD BANK SELECTOR, in MANUAL.

Using the On Line Control screen:

o Select LOAD or FSP.

o Select 0.5% demand rate.

Verify the VPL control is not Red.

Raise the VPL to 101% using the Valve Limiter pop-up screen.

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

Initiate an alternate dilution of the RCS per 1C12.5.

When Tave shows an increase, then select the Go control using the On Line Control screen.

Adjust the alternate dilution rate or perform alternate dilutions per 1C12.5 to maintain Tave and Tref with the desired +/-1.5°F band.

1C12.5, UNIT 1 BORON CONCENTRATION CONTROL Verify the RMU integrator is reset.

Set 1YIC-111, RX MU WTR TO BLENDER BATCH INTEGRATOR, to quantity desired.

Place CS-46300, MAKE-UP MODE SELECTOR, to ALT DIL.

Place CS-46454, BA BLENDER TO VCT INLT CV-31201, to CLOSE.

If desired, then adjust 1HC-111, RX MU WTR TO BLENDER FLOW CONT, set point to desired flow rate or place in MANUAL adjusted for desired flow rate.

Momentarily place CS-46457, BORIC ACID MAKE-UP CONTROL, to START, to initiate dilution.

When the desired quantity of makeup has been added, then verify automatic makeup stopped as indicated by CS-46457, BORIC ACID MAKE-UP CONTROL, green light LIT.

If additional alternate dilution is desired, then return to step 2.

Page 11 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Verify CS-46454, BA BLENDER TO VCT INLT CV-31201, is selected to AUTO.

Verify 1HC-111, RX MU WTR TO BLENDER FLOW CONT, is in AUTO set to 45%.

Place CS-46300, MAKE-UP MODE SELECTOR, to AUTO.

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

Reset the RMU integrator.

Page 12 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

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

1. When control rods are back in AUTO and/or at the discretion of the Lead Evaluator, then enter:

Trigger 3, Turbine 1st Stage Pressure fails LOW.

2. If contacted as I&C to trip bistables, inform the crew two I&C Technicians will be available in 45 minutes.

3. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc.

4. 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.

Plant Response:

1. Control Rods automatically step IN.

2. Tavg will lower due to rod movement.

3. The following annunciators will alarm:

a. 47011-0405, FW CONTROL SYSTEM TROUBLE.

b. 47013-0305, AUCTIONEERED TAVG-TREF DEVIATION.

LEAD/

RO LEAD/

RO SS 1C5 AOP1, UNCONTROLLED ROD MOTION Check turbine generator load STABLE.

Place rods in MANUAL.

Check rod motion STOPPED.

Determine Turbine First Stage Pressure Instrument failed.

Go to 1C51.2.

1C51.2, TURBINE 1ST STAGE PRESSURE 1P-485-LOW Place rod control in manual.

Control Tave at value appropriate for power level.

Place one steam dump interlock bypass to OFF.

Place steam dump in pressure mode.

Verify steam dump valves are CLOSED.

Verify zero output on steam dump controller.

Return steam dump interlock bypass to ON.

Verify SG level control operating properly in AUTO.

Enter TS LCO 3.3.1 Condition A o Reference Table 3.3.1-1 Function 16.b.2 Enter TS LCO 3.3.1 Condition R o Verify P-7 is in required state in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR o Be in Mode 2 in 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months .

Enter TRM TLCO 3.3.4 Condition A o Reference TRM Table 3.3.4-1 Function 3 Trip Bistable (no six hour requirement).

Page 13 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 4 EVENT 4 (cont)

Booth Operator:

1. When the crew has determined the appropriate Technical Specifications for PT-485 failing low, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 4, Loss of Charging Flow to Regen HX.

2. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc.

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

4. If contacted as Duty RP Tech, acknowledge the need to perform special surveys per PINGP 1483 and PINGP 1492.

5. If contacted as Duty Chemist, acknowledge purification is removed from service.

Plant Response:

1. Charging Flow lowers.

2. Pressurizer level lowers.

3. VCT level rises.

4. The following annunciators will alarm:

a. 47015-0205, CHARGING LINE HI PRESS.

b. 47015-0206, 11 RCP LAB SEAL LO DP.

c. 47015-0207, 12 RCP LAB SEAL LO DP.

d. 47015-0408, LTDN FLOW HI TEMP.

e. 47015-0509, REGEN HX LTDN LINE HI PRESS.

f. 47015-0608, LTDN RELIEF LINE TO PRT HI TEMP.

RO SS RO /

LEAD C47015-0205, CHARGING LINE HI PRESS Verify high charging line pressure at 1PI-133.

Verify proper operation of 1HC-142, 11 CHG LINE FLOW CONTROLLER.

Verify pressurizer level and programmed level are approximately equal.

Switch to MANUAL on the charging pump speed controller that is in AUTO and adjust as necessary to prevent lifting charging pump relief valves.

Determine flow is lost to regenerative heat exchanger.

Go to 1C12.1 AOP2.

1C12.1 AOP2, LOSS OF CHARGING FLOW TO THE REGEN HX Determine seal injection has NOT been lost.

Verify Reactor Makeup Controller in AUTO.

If VCT level is less than 17%, then verify automatic makeup is initiated.

CLOSE the letdown orifice isolation valves:

o CV-31325 o CV-31326 o CV-31327 Close the letdown isolation valves:

o CV-31226 o CV-31255 Place speed control for all operating charging pumps in MANUAL.

Stop one of the charging pumps as follows:

o Reduce charging pump speed and at the same time CLOSE CV-31198, CHG LINE FLOW CONT, to maintain seal injection of 6-10 gpm to each RCP. Continue until the selected charging pump is at minimum speed.

o Adjust CV-31198, CHG LINE FLOW CONT, until seal injection flow is approximately 9.5 gpm, then stop the selected charging pump.

o Adjust the speed of the inservice charging pump and CV-31198 to maintain seal injection flow of 6-10 gpm to each RCP. Continue until charging

Page 14 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES LEAD line flow control valve is fully CLOSED. Verify high charging line pressure at 1PI-133.

Initiate CC flow through Excess Letdown Heat Exchanger by OPENING MV-32095, 11 EXESS LTDN HX CC INLT/OUTL.

Establish Excess Letdown flow to the VCT.

Position CV-31333, EXCESS LTDN DIVERT TO RCDT, to the V.C. TK position.

OPEN CV-31330, EXCESS LTDN HX INLT.

Slowly OPEN CV-31210, EXCESS LTDN FLOW CONT.

Monitor pressurizer level, adjusting Excess Letdown flow as needed with CV-31210.

Notify Duty RP Tech to implement radiation surveys per PINGP 1483, Special Survey Checklist - Mixed Bed OOS and PINGP 1492, Excess Letdown in Service.

Notify Duty Chemist if purification is removed from service.

Minimize load changes.

Page 15 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 5 EVENT 5 (cont)

Booth Operator:

1. When the plant is stable, or at the discretion of the lead evaluator, then enter:

Trigger 5, Fire Protection Line Break.

2. If examinees ask if Unit 2 personnel are available to address the Fire Protection Line Break event, then inform examinees that Unit 2 personnel are NOT available.

3. If contacted as the out-plant operator to determine status of the motor driven fire pump, wait 1 minute and report the MDFP and DDFP are both running.

4. If contacted as the out-plant operator to walk down the fire protection system, wait 2 minutes and report there is a tremendous amount of water spraying everywhere in the Service Building stairway and it is from the Fire Protection Header. Also, report there is NO fire occurring.

5. If requested to isolate the fire protection leak, then report FP-35-1 and FP-35-3 are stuck open. If requested to close specific valves to the stairway, report you can not find them due to the water spraying. Recommend securing the fire protection pumps.

6. If contacted as the Fire Brigade Chief, then acknowledge the pending loss of all fire pumps.

NOTE: the Diesel Driven Fire Pump and Jockey Pump are not modeled in the simulator.

7. If contacted as the out-plant operator to secure the MD Fire Protection Pump, then wait 1 minute and enter:

Trigger 11, Motor Driven Fire Pump secured.

a. Inform the Control Room that the MDFP is secured.

8. If contacted as the out-plant operator to secure the DD Fire Protection Pump, then wait 1 minute and enter:

Trigger 12, Diesel Driven Fire Pump secured.

a. Inform the Control Room that the DDFP is secured.

9. If contacted as the out-plant operator to secure the Jockey pump, then wait 1 minute and inform the Control Room the Jockey Pump is secured.

LEAD LEAD SS C47022-0307, FIRE HEADER LOW PRESSURE Dispatch an operator to the screen house to determine status of the motor driven fire pump.

Determine reason for start of motor driven fire pump by checking fire detection panels and/or walking down the fire protection system.

Refer to C31 AOP1.

C31 AOP1, FIRE PROTECTION LINE BREAK Attempt to locate and identify method for isolation of leakage. Refer to Figure 1.

If shutdown of FP system is required for isolation, then perform the following:

o Notify Fire Brigade Chief of pending loss of all Fire Pumps.

o Place CS-46466, 121 SCREEN WASH PUMP, in Pull Out to prevent pump start on low FP header pressure.

o Dispatch an Operator to Unit 1 Rod Drive Room to stop 121 MDFP by locally tripping BKR 185, 121 MD FIRE PMP, on Bus 180.

o Dispatch an operator to Screen House to stop 122 DDFP by placing CS-70394-01, 122 DD FIRE PUMP 5 POSITION SEL SW, in OFF.

o Instruct operator in Screen House to locally stop 121 Jockey Pump.

Refer to F5 APP K for compensatory actions and notifications.

Isolate the portion of the fire header containing the leak.

Page 16 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

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

10. When the triggers for securing the MDFP and DDFP are inserted and the Jockey pump has been simulated secured, then enter:

Trigger 13, Fire Protection Header pressure lowering.

11. If contacted to check if the leak is stopped, then wait 1 minute and report back that the Fire Protection Leak in the Service Building Stairway has stopped.

12. If contacted to check the status of the CL Water cross-connect valves, inform the CR that ALL CL Water cross-connect valves are closed.

13. If contacted as the Fire Protection Group to assess comp measures, then inform the Control Room you will look into it.

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

Plant Response:

1. Fire Protection Header pressure will lower until the MDFP and DDFP pumps auto start, then header pressure will rise to a higher than original pressure and stabilize.

When the Fire Pumps are secured, fire header pressure will lower to zero or near zero psig. The following annunciators will be received:

a. 47022-0307, FIRE HEADER LO PRESS.

b. 47022-0305, 122 FIRE PUMP RUNNING.

Page 17 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 6 EVENT 6 (cont)

Booth Operator:

1. When the crew has shutdown the Fire Protection System, and/or at the discretion of the Lead evaluator, then enter:

Trigger 6, 11 Steam Generator Faults into Containment.

2. Upon hearing the announcement of Reactor Trip, or when called as the Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, then:

a. Open and run schedule file E-0_Att-J.sch located in X:\\\\Trex_PI\\Lightning\\Schedule\\EOPs.

b. When the isolation is complete, inform the crew the MSRs are isolated.

3. Upon hearing the announcement of Safety Injection, or when called as the Turbine Building Operator to secure the Turbine Building Roof Exhausters, wait approximately 2 minutes and report the Turbine Building Roof Exhausters are all secured.

4. If there is NO examinee in the Unit 2 Lead position and Control Room personnel ask if Unit 2 personnel are available to perform Attachment L, then inform the Control Room that Unit 2 personnel are NOT available for performing Attachment L.

CRITICAL TASKS Establish at least 200 GPM of feedwater flow to the Steam Generators before both Steam Generator Wide Range Levels lower below 9% [20%] (Only applicable if both AFW Pumps trip on low discharge pressure).

Stop feed flow to the faulted Steam Generator before the end of the scenario.

5. If contacted as Duty Chemist or Duty RP to check status of secondary radiation levels and/or SG activity levels, then inform the control room that both SG cation column frisks are reading background and secondary radiation levels are normal.

LEAD/

RO SS RO SS RO 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify reactor tripped.

o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

Verify the Main Turbine tripped.

o Left and right Stop Valves are CLOSED.

Determine both Safeguards buses energized.

Determine SI is required.

o Check Containment Pressure and determine that SI is required.

Perform Attachment L (see SEG pages 20 & 21).

Check AFW Status o Total AFW flow >200 GPM.

o AFWP discharge pressure >1000 PSIG.

o Maintain SG WR levels 50-59%.

Check RCS Tavg trending to 547°F.

Check PRZR PORVs and Spray valves closed.

Determine RCPs running and do NOT meet trip criteria. (NOTE: RCS pressure may lower enough to meet RCP trip criteria due to Cooldown, in which case RCPs WILL be tripped).

o Injection flow to the RCS.

o RCS Pressure NOT < 1576 PSIG.

o Operator Controlled Cooldown NOT initiated.

Determine 11 SG is faulted.

o 11 SG pressure decreasing in an uncontrolled manner.

OR o 11 SG completely depressurized.

Transition to 1E-2.

Transition to 1FR-Z.1 may occur if an orange path in Containment Critical Safety Function has occurred.

1FR-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE

Page 18 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

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

6. If contacted by the Control Room to report status of CAT 1 Vent Zone openings, then inform the CR that all CAT 1 Vent Zone openings are closed.

7. If Control Room personnel ask for status of Unit 2 Cooling Water/Chilled Water lineup, then inform the Control Room that Unit 2 Cooling Water/Chilled Water valves are in their safeguards positions.

8. If Control Room personnel ask for status of Battery Room Temperatures, then inform the Control Room that Battery Room temperatures are 74°F.

Plant Response:

1. PRZR Pressure lowers rapidly.

2. CTMT Pressure rises.

3. Annunciator 47022-0611, FIRE DETECTION PANEL 121

- FIRE ALARM, alarms.

SS RO /

LEAD SS Verify Containment Isolation Valves are CLOSED.

Verify containment spray actuated.

Determine Containment Spray pumps are NOT running.

Manually start spray pumps.

Verify proper spray system alignment.

Verify FCUs running slow to the dome.

Verify FCU cooling water MVs are OPEN.

Check cooling water header pressure - both greater than 65 psig.

Verify MSIVs and bypass valves are CLOSED.

Isolate feed flow to 11 SG if not already done.

Return to procedure and step in effect.

1E-2, FAULTED STEAM GENERATOR ISOLATION Check MSIV and Bypass valve on 11 SG closed.

Determine 11 SG is faulted.

Determine 12 SG is NOT faulted.

Isolate 11 SG:

o Isolate main feed line.

o Isolate AFW flow.

o Close steam supply valve to TD AFWP.

o Verify 11 SG PORV closed.

o Verify SGB isolation valves closed.

Determine CST levels are greater than 10000 gallons.

Determine secondary radiation levels are normal.

Go to 1E-1.

1E-1, LOSS OF REACTOR OR SECONDARY COOLANT Determine whether RCPs be stopped.

o May or may NOT meet RCP Trip Criteria.

Determine 11 SG is faulted and isolated.

Check 12 SG WR level greater than 50%.

Page 19 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Check secondary radiation normal.

Determine PRZR PORVs are closed.

Determine PRZR PORV block valves have power and both are open.

Reset SI and CI.

Establish instrument air to CTMT.

Determine offsite power available to charging pumps and at least one pump is running.

Determine SI should be terminated.

Go to 1ES-0.2.

Page 20 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 7 EVENT 7 (cont)

Booth Operator:

1. When the reactor is tripped, then verify the following is automatically inserted:

AUTO Trigger 7, Loss of Containment Cooling.

2. If contacted as an out-plant operator to open CFCU bypass valves, then wait 4 minutes and enter:

Trigger 17, CFCU Cooling Water Return Orifice Bypass Valves OPEN, and inform the control room that CFCU CL bypass valves are open.

CRITICAL TASKS Manually actuate containment cooling as necessary to prevent containment pressure from exceeding 46 psig.

TABLE 1 CS NUMBER COMPONENT DESIRED POSITION 46018 11 CFCU SLOW 46019 13 CFCU SLOW 46039 MV-32144 CLOSE 46144 MV-32159 CLOSE 46519 MV-32036 CLOSE 46509 MV-32037 CLOSE 46336 12 DDCLWP MAN/AUTO MANUAL 46053 12 DDCLWP START 46537 22 DDCLWP MAN/AUTO MANUAL 46523 22 DDCLWP START NOTE: 12 and 14 CFCUs will fail to restart.

Plant Response:

1. Containment Spray pumps do not start automatically.

2. 12 and 14 CFCU fail to automatically or manually start.

3. 11 and 13 CFCU fail to automatically start.

4. SI to Cooling Water signal fails to actuate.

LEAD LEAD The crew may restore Containment Cooling using 1FR-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE, due to an orange or red path in the Containment Critical Safety Function.

1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION Verify both trains of SI actuated:

o Both RHR pumps or both SI pumps - RUNNING.

"SI NOT READY" lights - NOT LIT.

"SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

o Actuate and align components per Table 1.

"CONTAINMENT ISOLATION" lights - LIT FOR PLANT CONDITIONS.

Check Category 1 Vent Zone Boundary.

Close MV-32115, 122 SFP HX INLT HDR MV B.

Check Cooling Water Header Pressures - BOTH GREATER THAN 65 PSIG.

Verify Plant Announcements Complete.

Check If Main Steamlines Are Isolated.

Determine MSIVs, Bypass Valves, and Containment Instrument Air Valves are already closed.

Verify SI Flow.

Verify RHR Flow.

Verify Containment Spray is actuated (if necessary).

o 11 & 12 CS pumps do NOT start automatically o Manually start 11 & 12 CS pumps.

Check RCP Cooling.

Verify Local Actions Complete.

Verify Generator Breakers - OPEN.

Verify All Heater Drain Pumps - STOPPED.

Check Turbine reheat and intercept valves CLOSED.

Open turbine drain valves.

Verify Main Feedwater Alignment:

o Both main feedwater pumps - STOPPED.

o Main and bypass FRVs - CLOSED.

Verify All Condensate Pumps - STOPPED.

Verify Steam Dump in "STM PRESS" Mode.

Verify Unit 1 Cooling Water/Chilled Water Alignment:

Page 21 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 SCENARIO TIME-LINE:

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

5. Containment pressure rises and will exceed 46 psig without operator action.

EMERGENCY PLAN CLASSIFICATION NOTIFICATION OF UNUSUAL EVENT - FU1 due to potential loss of Containment fission product barrier due to Containment pressure greater than 23 psig with less than one full train of depressurization equipment operating.

SITE AREA EMERGENCY - a RED path in RCS Integrity CSF may occur due to the rapid cooldown from the faulted steam generator. If this occurs, then FS1 is met due to potential loss of RCS fission product barrier and potential loss of Containment fission product barrier.

o CFCU control switches - "SLOW".

o CFCU dampers - ALIGNED TO DOME.

o Unit 1 cooling water/chilled water valves closed.

o Unit 1 CRDM shroud cooling supply and return valves - CLOSED.

o CFCU cooling water supply and return valves -

OPEN.

o CFCU chilled water supply and return valves -

CLOSED.

Verify 11 Safeguards Screenhouse Ventilation lineup.

Verify Control Room Ventilation Alignment:

o Chillers and fans - RUNNING.

o Control room chiller suction/discharge tie closed -

STATUS LIGHT LIT.

Verify Unit 2 Cooling/Chilled Water Alignment.

Verify 21 Safeguards Screenhouse Ventilation lineup.

Verify 11 and 12 Battery Charger Operation is normal.

Verify Battery Room temps less than 84°F.

Check status of Spent Fuel Cooling.

Check Status of Notifications.

Notify SS Of Any Discrepancies.

END Once the crew has isolated 11 Steam Generator and restored Containment Cooling and/or at the discretion of the Lead Evaluator, then place the simulator in FREEZE. Inform the crew that training has the duty.

Page 1 of 17 SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

PI-ILT-NRC-1603S SEG TITLE:

2016 ILT NRC SIMULATOR EVALUATION #3 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME: 2.0 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Shawn Sarrasin 11/23/2015 Instructor Date Reviewed by:

Fred Collins 12/28/2015 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Fred Collins 12/28/2015 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Mike Petersen 3/25/2016 Training Supervision Date

Page 2 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. 1PT-431, Blue Channel Pressurizer Pressure Transmitter, fails LOW.

2. Failure of Bus 15 Load Sequencer.

3. 11 Main Feed Pump Lockout.

After EOP Entry:

1. Reactor Fails to automatically trip.

2. Failure of CC Pumps to automatically start.

Abnormal Events:

1. Controlling Channel Pressurizer Pressure Instrument Failure.

2. Bus 15 Load Sequencer Out of Service.

3. Loss of Main Feedwater.

4. Loss of Component Cooling.

Major Transients:

1. Large Break LOCA.

Critical Tasks:

1. Manually trip the reactor from the Control Room before both Steam Generator Wide Range Levels lower below 9%.

2. Manually start at least one CC Pump before the end of the scenario.

Page 3 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 CRITICAL TASK SHEET Critical Task:

Manually trip the reactor from the Control Room before both Steam Generator Wide Range Levels lower below 9%.

Safety Significance:

If the main turbine trips and the reactor fails to automatically trip, then the steam dumps and/or SG PORVs will draw steam from the Steam Generators.

This steam will not return to the main condenser and hotwell. This results in rapidly lowering hotwell level, eventual trip of the Main Feedwater Pumps, and loss of feedwater to the Steam Generators.

During a loss of feedwater to the Steam Generators, the turbine, steam dumps, or SG PORVs are drawing steam from the Steam Generators. This causes Steam Generator levels to rapidly lower. Once the SGs are dry, the heat removal capability of the RCS is lost. This leads to RCS pressure increase and RCS boundary failure.

Plant Conditions:

At least one of the following occurs:

o Loss of normal feedwater to the Steam Generators.

o Main Turbine Trip.

The reactor fails to automatically trip.

Rods fail to automatically insert.

Reactor Power is greater than 5%.

At least one of the following is drawing steam from the SGs:

o Main Turbine.

o Steam Dumps.

o SG PORVs.

Cues:

Steam Generator levels lowering.

Both Reactor Trip breakers closed.

Performance Indicator:

Opening the Reactor Trip Breakers by operating one of the following Reactor Trip Switches:

o CS-46331.

o CS-46450.

-OR-

Inserting all control rods by operating CS-46447, AMSAC/DSS Control Switch.

Feedback:

Control rods at bottom of core.

Neutron flux decreasing.

Page 4 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 CRITICAL TASK SHEET Critical Task:

Manually start at least one CC Pump before the end of the scenario.

Safety Significance:

Operation of the ECCS injection pumps without Component Cooling Water could lead to pump failure or damage. This would result in a degraded emergency core cooling system (ECCS) capacity.

Plant Conditions:

Safety Injection.

Both Component Cooling Water Pumps are NOT running.

At least one Component Cooling Water Pump can be started from the Control Room.

Cues:

Indication that Safety Injection actuated.

SI ACTIVE lights are NOT lit for both CC Pumps.

Component Cooling Water Discharge pressure reads zero.

Component Cooling Water Low Flow alarms to ECCS Pumps.

Performance Indicator:

Starting one or both CC Pumps by operating the following switches:

CS-46036, 11 CC WTR PUMP.

CS-46037, 12 CC WTR PUMP.

Feedback:

SI ACTIVE lights are LIT for at least one CC Pump.

Component Cooling Water Low Flow alarm clears for at least one train of Safeguards components.

Page 5 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO OVERVIEW:

SEQUENCE OF EVENTS:

Event 1: Swap Component Cooling Water Pumps

The crew will start 12 CC Pump and stop 11 CC Pump per 1C14.

Event 2: Controlling Pressurizer Pressure Channel fails LOW

PT-431 fails low.

Both spray valves close and PRZR heaters energize.

The crew will take manual control of PRZR pressure and select WHITE/RED on selector switch.

The Shift Supervisor will address TS LCO 3.3.1 and TS LCO 3.3.2.

Event 3: Perform a Load Increase from 30% to 40%

The crew will place rods in manual.

The crew will perform alternate dilutions per 1C12.5.

The crew will operate the turbine to raise load.

Event 4: Failure of Bus 15 Load Sequencer

The crew will place Bus 15 Voltage Restoration in manual.

The crew will take D1 Diesel Generator in Pullout.

The Shift Supervisor will address TS LCO 3.8.9.

Event 5: Reactor Fails to Automatically Trip on a Loss of Main Feedwater

11 Main Feedwater Pump locksout.

The Main Turbine will trip.

The Reactor will fail to automatically trip.

The crew will manually trip the reactor and enter 1E-0.

Event 6: Large Break LOCA

After the crew transitions to 1ES-0.1, a large break LOCA occurs on the B Hot Leg.

Containment Pressure rises, RCS pressure and Pressurizer level rapidly lowers.

The crew will transition back to 1E-0.

The crew will transition into and out of 1FR-P.1 when a red path in integrity CSF occurs.

The crew will diagnose a Loss of Coolant Accident and transition to 1E-1.

Page 6 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 Event 7: Loss of Component Cooling

After the Safety Injection, both Component Cooling Water Pumps will fail to automatically start.

The crew will manually start Component Cooling Water Pumps per Attachment L of 1E-0.

Page 7 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

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

1.

SIMULATOR PRE-BRIEF:

a.

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

2.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

c. Verify crew performs walk down of control boards and the 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 Booth Operator:

3.

After the crew has assumed the duty, they will swap Component Cooling Water Pumps per 1C14.

4.

When contacted as the out-plant operator to perform step 5.2.1 of 1C14, then acknowledge order. Wait approximately 1 minute and report bearing oil level is normal and there is no seal leakage.

5.

If contacted as an out-plant operator to perform a sweep of Bus 16 Room, then wait approximately 1 minute and report that Bus 16 Room is clear of personnel.

6.

When contacted as the out-plant operator to perform step 5.2.4 of 1C14, then acknowledge order. Wait approximately 2 minutes, then report step 5.2.4 is completed SAT.

7.

After the crew indicates they will wait 10 minutes prior to stopping 11 CC Pump, then inform the crew TIME COMPRESSION is being used and that 10 minutes has elapsed.

Plant Response:

1.

12 CC Heat Exchanger flowrate rises.

2.

11 CC Heat Exchanger flowrate lowers.

LEAD 1C14, COMPONENT COOLING SYSTEM - UNIT 1 Notify the Aux Building Operator to check the following on 12 CC Pump.

Bearing oil level in sight glass.

No seal leakage.

Start 12 CC Pump using CS-46037.

Verify MV-32146, 12 CC HX CLG WTR INLT, is OPEN.

Direct an out-plant operator to perform step 5.2.4 of 1C14.

Operate both CC pumps for at least ten minutes.

Determine single pump operation is desired and go to section 5.3.

Determine B Train RHR is NOT being used for shutdown cooling.

Place and hold CS-46036, 11 CC WTR PUMP, in STOP until CC system pressure stabilizes above 75 psig.

Page 8 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

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

1.

After the crew has assumed the duty and/or at the discretion of the lead evaluator, then enter:

Trigger 2, PRZR Pressure Blue Channel fails LOW.

2.

If contacted as I&C to trip bistables, inform the crew two I&C Technicians will be available in 45 minutes.

3.

If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc. as asked.

4.

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.

Plant Response:

1.

PRZR spray valves close.

2.

PRZR Pressure rises.

3.

Tavg rises.

4.

The following annunciators are received:

a.

47012-0108, PRZR LO PRESS SI CHANNEL ALERT.

b.

47012-0408, PRZR HI/LO PRESS CHANNEL ALERT.

LEAD/

RO SS LEAD SS C47012-0108, PRZR LO PRESS SI CHANNEL ALERT Check PRZR pressure.

Verify all heaters on.

Verify sprays closed.

If necessary, then control pressure in manual.

Refer to 1C51.3.

1C51.3, PRESSURIZER PRESSURE 1P-431 - LOW If the Blue channel is selected on the PRZR Pressure Control Selector Switch, then:

o Place PRZR Press Cont in MANUAL and stabilize pressure.

o Select 2-1 (WHITE/RED) on channel sel sw o When pressure returned to normal with no deviation from setpoint, then return pressure control to automatic.

Verify PRZR Press Rec. not selected to Blue channel.

Enter TS LCO 3.3.1 Condition A o Reference Table 3.3.1-1 immediately.

Enter TS LCO 3.3.1 Condition E o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Enter TS LCO 3.3.1 Condition K o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR o Reduce thermal power to <P-7/P-8 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Enter TS LCO 3.3.2 Condition A o Reference Table 3.3.2-1 immediately.

Enter TS LCO 3.3.2 Condition D o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND o Be in Mode 4 in 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months Trip bistables.

Page 9 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 EVENT 3 EVENT 3 (cont)

Booth Operator:

1. After the crew has restored pressurizer pressure control to automatic and/or at the discretion of the lead evaluator, then:

a.

As the Shift Manager, direct the Unit 1 SS to raise Unit 1 Reactor Power to 40%.

2. If contacted as the duty chemist, acknowledge Unit 1 power will be raised from 30% to 40%.

3. If contacted as Unit 2 Control Room Operators to monitor Unit 1 Heater Drain Tank alarms (Panel F), then acknowledge request and inform Unit 1 Operators that an extra operator will monitor Panel F.

Plant Response:

1. Reactor Power rises.

2. Generator Load rises.

3. RCS Tavg rises.

NOTE It is NOT intended to wait for the plant to reach 40%

power prior to proceeding to the next event. Once the Lead Evaluator is satisfied with the reactivity manipulation, proceed to Event 4.

RO/SS RO/SS RO/SS 1C1.4, UNIT 1 POWER OPERATION Place CS-46280, ROD BANK SELECTOR, in MANUAL.

Using the On Line Control screen:

o Select LOAD or FSP.

o Select 0.5% demand rate.

Verify the VPL control is not Red.

Raise the VPL to 101% using the Valve Limiter pop-up screen.

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

Initiate an alternate dilution of the RCS per 1C12.5.

When Tave shows an increase, then select the Go control using the On Line Control screen.

Adjust the alternate dilution rate or perform alternate dilutions per 1C12.5 to maintain Tave and Tref with the desired +/-1.5°F band.

1C12.5, UNIT 1 BORON CONCENTRATION CONTROL Verify the RMU integrator is reset.

Set 1YIC-111, RX MU WTR TO BLENDER BATCH INTEGRATOR, to quantity desired.

Place CS-46300, MAKE-UP MODE SELECTOR, to ALT DIL.

Place CS-46454, BA BLENDER TO VCT INLT CV-31201, to CLOSE.

If desired, then adjust 1HC-111, RX MU WTR TO BLENDER FLOW CONT, set point to desired flow rate or place in MANUAL adjusted for desired flow rate.

Momentarily place CS-46457, BORIC ACID MAKE-UP CONTROL, to START, to initiate dilution.

When the desired quantity of makeup has been added, then verify automatic makeup stopped as indicated by CS-46457, BORIC ACID MAKE-UP CONTROL, green light LIT.

Page 10 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES If additional alternate dilution is desired, then return to step 2.

Verify CS-46454, BA BLENDER TO VCT INLT CV-31201, is selected to AUTO.

Verify 1HC-111, RX MU WTR TO BLENDER FLOW CONT, is in AUTO set to 45%.

Place CS-46300, MAKE-UP MODE SELECTOR, to AUTO.

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

Reset the RMU integrator.

Page 11 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

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

1. When the lead evaluator is satisfied with the reactivity manipulation, then enter:

Trigger 4, Failure of Bus 15 Load Sequencer.

2. If contacted as an out-plant operator to investigate Bus 15 Load Sequencer, then wait approximately 1 minute and report the following:

a. Blocking Relay Switch is in NORMAL.

b. PLC Key Switch is in RUN and NOT in REMOTE.

c. Unable to identify cause of the problem.

3. When the crew starts to perform SP 2094/2095 or asks Unit 2 to perform SP 2094/2095, then inform the crew that Unit 2 personnel will perform SP 2094 and SP 2095 to verify Unit 2 load sequencers are operable.

4. When the crew starts to perform SP 1118 or asks for an extra operator to perform SP 1118, then inform the crew TIME COMPRESSION is used and SP 1118 is completed SAT.

5. When the crew starts to perform SP 1095 or asks for an extra operator to perform SP 1095, then inform the crew TIME COMPRESSION is used and SP 1095 is completed SAT.

6. When the crew starts to verify grid voltage alarm limits or asks for an extra operator to verify grid voltage alarm limits, then inform the crew TIME COMPRESSION is used and voltage alarm limits have been verified.

Plant Response:

1. Annunciator 47024-1001, BUS 15 SEQUENCER NOT IN SERVICE, alarms.

2. Bus 15 Load Sequencer will not load reject during an SI.

LEAD SS LEAD 1C20.7 AOP2, BUS 15 LOAD SEQUENCER OUT OF SERVICE Place CS-46932, BUS 15 VOLTAGE RESTORATION SEL SW, in MAN.

Place CS-46935, D1 DIESEL GENERATOR, in PULLOUT.

Verify annunciator panel and/or ERCS alarms for BUS 15 voltages are in service.

Log D1 DSL GEN inoperable.

Check Unit 2 sequencers operable per SP 2094/2095.

Log Bus 15 Load Sequencer inoperable.

Enter TS LCO 3.3.4 Condition C.

Enter TS LCO 3.8.1 Condition B.

Log Bus 15 inoperable.

Enter TS LCO 3.8.9 Condition A.

Perform the applicable portions of SP 1118, Verifying Paths from the grid to Unit 1 buses.

Perform SP 1095, Bus 16 Load Sequencer Test to verify Bus 16 load sequencer is operable.

Verify Bus 15 is powered from 1RY and Bus 16 is powered from CT11.

Verify grid voltage limits are appropriate.

Align for block loading.

o 11 and 13 CFCUs in SLOW.

o 121 and 123 Waste Gas Compressors in Pullout.

o 121 Air Compressor in Pullout.

o Verify 121 Control Room Chiller and Fan running.

o Start 121 Auxiliary Building Special Ventilation.

o On D1 Aux Panel, Place CS-55401, D1 AIR COMP CONTROL SW, in OFF.

Log Bus 15 operable.

Exit TS LCO 3.8.9 Condition A.

Page 12 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

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

1. After the crew has placed D1 in pullout and/or at the discretion of the Lead Evaluator, then enter:

Trigger 5, Loss of Main Feedwater.

2. Upon hearing the announcement of Reactor Trip, or when called as the Turbine Building Operator to isolate the Unit 1 MSRs per Attachment J, then:

a. Open and run schedule file E-0_Att-J.sch located in X:\\\\Trex_PI\\Lightning\\Schedule\\EOPs.

b. When the isolation is complete, inform the crew the MSRs are isolated.

Plant Response:

1. Annunciator 47010-0101, 11 FW PUMP LOCKOUT.

2. Main Turbine automatically trips.

3. Rapidly lowering levels in both Steam Generators.

4. The reactor will fail to automatically trip.

CRITICAL TASK Manually trip the reactor before both Steam Generator Wide Range levels lower below 9%.

EMERGENCY PLAN CLASSIFICATION ALERT - SA2.1 due to the reactor failing to automatically trip after the turbine automatically tripped on loss of 11 Main Feed Pump and the crew successfully manually tripping the reactor.

LEAD /

RO SS RO /

SS 1E-0, REACTOR TRIP OR SAFETY INJECTION Manually trip the reactor.

Verify reactor tripped.

o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

Verify the Main Turbine tripped.

o Left and right Stop Valves are CLOSED.

Verify both Safeguards buses energized.

Direct an operator to perform 1C20.5 AOP1.

Determine SI is NOT actuated and NOT required.

Go to 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 greater than 75 psig.

Notify Turbine Building Operator to isolate Unit 1 MSRs per Attachment J.

Check FW status.

Verify all control rods inserted.

Check PRZR level and PRZR pressure control.

Check SG levels.

Page 13 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 EVENT 6 EVENT 6 (cont)

Booth Operator:

1. After the crew has transitioned to 1ES-0.1 and/or at the discretion of the Lead Evaluator, then enter:

Trigger 6, Large Break LOCA.

2. Upon hearing the announcement of Safety Injection, or when called as the Turbine Building Operator to secure the Turbine Building Roof Exhausters, wait 2 minutes and report the Turbine Building Roof Exhausters are all secured.

3. If Control Room personnel ask if Unit 2 personnel are available to perform Attachment L, then inform the Control Room that Unit 2 personnel are NOT available for performing Attachment L.

Plant Response:

1. RCS pressure lowers rapidly.

2. Pressurizer level lowers rapidly.

3. Containment Pressure rises.

4. The reactor automatically trips.

5. Safety Injection fails to automatically actuate.

6. CC pumps fail to automatically start after load rejection /

restoration.

EMERGENCY PLAN CLASSIFICATION ALERT - FA1 due loss of RCS fission product barrier due to RCS leak rate greater than available makeup.

Booth Operator:

4. If Control Room personnel ask if Unit 2 personnel are available to secure Diesel Generators and/or Safeguards Cooling Water Pumps, then inform the Control Room that RO /

SS RO/

LEAD SS RO SS RO /

SS 1ES-0.1, REACTOR TRIP RECOVERY INFO PAGE Actuate SI and go to 1E-0 if EITHER condition listed below occurs:

o RCS subcooling - LESS THAN 20F.

o PRZR level - CANNOT BE MAINTAINED GREATER THAN 5%.

1E-0, REACTOR TRIP OR SAFETY INJECTION Verify reactor tripped.

o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

Verify the Main Turbine tripped.

o Left and right Stop Valves are CLOSED.

Verify both Safeguards buses energized.

Manually actuate or determine SI has actuated.

o Either SG pressure < 530 psig.

o PRZR pressure < 1830 psig.

o Containment pressure > 3.5 psig.

Perform Attachment L (see SEG pages 17 & 18).

Check AFW Status o Total AFW flow >200 GPM.

o AFWP discharge pressure >1000 PSIG.

o Maintain SG WR levels 50-59%.

Check RCS Average Temperatures trending to 547°F.

o Cold leg temperature is used if RCPs have been tripped.

Check PRZR PORVs and Spray valves closed.

Stop RCPs due to trip criteria being met.

o Injection flow to the RCS.

o RCS Pressure < 1250 PSIG [1576 PSIG].

o Operator Controlled Cooldown NOT initiated.

Determine SGs are NOT faulted.

o No SG pressure decreasing in an uncontrolled manner.

Page 14 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Unit 2 personnel WILL secure the Diesel Generators and/or Safeguards Cooling Water Pumps.

5. When called as the Auxiliary Building Operator to open RD-4-6 and 2RD-4-2, wait 2 minutes and report these valves are open.

o No SG completely depressurized.

Determine SG Tubes are NOT ruptured.

o Condenser air ejector radiation normal.

o SGB radiation normal.

o Main Steam Line radiation normal.

Determine RCS is NOT intact due to Containment pressure rising.

Go to 1E-1.

Transition to 1FR-P.1 may occur if a red or orange path in Integrity Critical Safety Function has occurred.

1FR-P.1 RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITION Check RCS pressure > 550 psig - NO.

RHR flow >950 gpm - YES.

Return to 1E-1.

1E-1, LOSS OF REACTOR OR SECONDARY COOLANT Check if RCPs should be stopped.

Check SGs NOT faulted and NOT ruptured.

Check PRZR PORVs and Block Valves:

o Power to block valves available.

o PRZR PORVs - CLOSED.

o At least ONE block valve OPEN.

Reset SI and CI.

Establish Instrument Air to Containment.

Check power supply to charging pumps.

Check if Charging Flow has been established.

Determine SI flow should NOT be terminated.

Determine RHR Pumps should NOT be stopped.

Check RCS and SG Pressures.

Page 15 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Stop Diesel Generators and Cooling Water Pumps.

Verify at least one train of recirculation capability.

Check Aux Building Radiation - NORMAL.

Start all containment dome recirculation fans.

Check if outside air can be supplied to CR.

Align Containment FCU Cooling Water Outlet Radiation Monitor R-16 and R-38.

Check Annulus Sump High Level Alarm - OFF.

Determine RCS Cooldown and Depressurization is NOT required.

Prepare for Switchover to Recirculation Phase:

o Stop Spent Fuel Pool Vent System.

o Notify Outplant to perform Attachment K.

Isolate SI Accumulators.

Go to 1ES-1.2 when RWST level is below 33%.

Page 16 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 EVENT 7 EVENT 7 (cont)

Booth Operator:

1. If contacted by the Control Room to report status of CAT 1 Vent Zone openings, then inform the CR that all CAT 1 Vent Zone openings are closed.

2. If Control Room personnel ask for status of Unit 2 Cooling Water/Chilled Water lineup, then inform the Control Room that Unit 2 Cooling Water/Chilled Water valves are in there safeguards positions.

3. If Control Room personnel ask for status of Battery Room Temperatures, then inform the Control Room that Battery Room temperatures are 74°F.

4. If Control Room personnel ask for status of Spent Fuel Cooling, then inform the Control Room that Spent Fueling level and temperature are normal.

Plant Response:

1. 11 and 12 CC Pumps will fail to automatically start on SI signal or on low pressure.

2. 11 CC pump may still be in pullout due to the loss of power to Bus 15.

3. Low CC pressure on both trains.

CRITICAL TASK Manually start at least one CC Pump before the end of the scenario.

LEAD LEAD 1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION Verify Safeguards Component Alignment:

Verify both trains of SI actuated:

o Both RHR pumps or both SI pumps - RUNNING.

"SI NOT READY" lights - NOT LIT.

"SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

o Manually start both CC Pumps.

"CONTAINMENT ISOLATION" lights - LIT FOR PLANT CONDITIONS.

Check Category 1 Vent Zone Boundary.

Close MV-32115, 122 SFP HX INLT HDR MV B.

Check Cooling Water Header Pressures - BOTH GREATER THAN 65 PSIG.

Verify Plant Announcements Complete.

Check If Main Steamlines Are Isolated.

Determine MSIVs, Bypass Valves, and Containment Instrument Air Valves do NOT need to be closed.

Verify SI Flow.

Verify RHR Flow.

Verify Containment Spray is actuated (if necessary).

Check RCP Cooling.

Verify Local Actions Complete.

Verify Generator Breakers - OPEN.

Verify All Heater Drain Pumps - STOPPED.

Check Turbine Valves:

o Turbine reheat and intercept valves - CLOSED.

o Open turbine drain valves.

Verify Main Feedwater Alignment:

o Both main feedwater pumps - STOPPED.

o Main and bypass FRVs - CLOSED.

Verify All Condensate Pumps - STOPPED.

Verify Steam Dump in "STM PRESS" Mode.

Verify Unit 1 Cooling Water/Chilled Water Alignment:

o CFCU control switches - "SLOW".

o CFCU dampers - ALIGNED TO DOME.

o Unit 1 cooling water/chilled water valves closed.

Page 17 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 SCENARIO TIME-LINE:

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES o Unit 1 CRDM shroud cooling supply and return valves - CLOSED.

o CFCU cooling water supply and return valves -

OPEN.

o CFCU chilled water supply and return valves -

CLOSED.

Verify 11 Safeguards Screenhouse Ventilation lineup.

Verify Control Room Ventilation Alignment:

o Chillers and fans - RUNNING.

o Control room chiller suction/discharge tie closed -

STATUS LIGHT LIT.

Verify Unit 2 Cooling/Chilled Water Alignment.

Verify 21 Safeguards Screenhouse Ventilation lineup.

Verify 11 and 12 Battery Charger Operation is normal.

Verify Battery Room temps less than 84°F.

Check status of Spent Fuel Cooling.

Check Status Of Notifications.

Notify SS Of Any Discrepancies.

END Once the crew has restored flow to one train of component cooling and/or at the discretion of the Lead Evaluator, then place the simulator in FREEZE. Inform the crew that training has the duty.

Page 1 of 15 SIMULATOR EXERCISE GUIDE (SEG)

SITE: PRAIRIE ISLAND SEG #

PI-ILT-NRC-1604S SEG TITLE:

2016 ILT NRC SIMULATOR EVALUATION #4 REV. #

0 PROGRAM:

INITIAL LICENSE OPERATOR TRAINING FL-ILT COURSE:

INITIAL LICENSE OPERATOR TRAINING FL-ILT TOTAL TIME: 2.0 HOURS Additional site-specific signatures may be added as desired.

Developed by:

Shawn Sarrasin 12/21/2015 Instructor Date Reviewed by:

Fred Collins 1/20/2016 Instructor (Simulator Scenario Development Checklist.)

Date Validated by:

Fred Collins 1/20/2016 Validation Lead Instructor (Simulator Scenario Validation Checklist.)

Date Approved by:

Mike Petersen 3/25/2016 Training Supervision Date

Page 2 of 15 2016 ILT NRC SIMULATOR EVALUATION #4 QUANTITATIVE ATTRIBUTES Malfunctions:

Before EOP Entry:

1. 11 CFCU trips on overload.

2. 1PI-431, Blue Channel Pressurizer Pressure Transmitter, fails HIGH.

After EOP Entry:

1. Train A and B Safety Injection fails to automatically actuate.

2. Feedwater Components fail to automatically align after SI Signal.

Abnormal Events:

1. Instrument Failure Guide.

2. Alarm Response Procedure for CFCU Trip.

Major Transients:

1. Large Break LOCA.

2. Transfer ECCS to recirculation mode.

Critical Tasks:

1. Manually actuate at least one train of SI-actuated safeguards equipment before core exit temperatures exceed 700°F.

2. Transfer to cold leg recirculation and establish ECCS recirculation flow before an ORANGE or RED path in Core Cooling CSF occurs.

Page 3 of 15 2016 ILT NRC SIMULATOR EVALUATION #4 CRITICAL TASK SHEET Critical Task:

Manually actuate at least one train of SI-actuated safeguards equipment before core exit temperatures exceed 700°F.

Safety Significance:

Failure to actuate safeguards equipment during an accident condition will lead to a loss of water inventory in the core. With no water or low water level in the core, the fuel will heat up and result in damage to the fuel cladding barrier.

Plant Conditions:

Reactor Trip

One of the following accidents:

o LOCA o Unisolable Steam Line Break o SGTR

Both trains of Safety Injection fail to automatically actuate.

Safety Injection can be manually actuated from the Control Room.

Cues:

Any of the following has occurred or is imminent:

o Pressurizer pressure less than 1830 psig.

o Any Steam Generator pressure less than 530 psig.

o Containment pressure greater than 3.5 psig.

SI-actuated Safeguards equipment is NOT running or repositioned.

Performance Indicator:

Operating one of the following Safety Injection Actuation Switches:

o CS-46180.

o CS-46408.

-OR-

Manually starting at least one train of ECCS pumps. This option may result in other Critical Tasks becoming applicable.

Feedback:

At least one train of ECCS pumps running.

Page 4 of 15 2016 ILT NRC SIMULATOR EVALUATION #4 CRITICAL TASK SHEET Critical Task:

Transfer to cold leg recirculation and establish ECCS recirculation flow before an ORANGE or RED path in Core Cooling CSF occurs.

Safety Significance:

If the ECCS system is not transferred to recirculation mode, a loss of the ECCS pumps will occur when RWST level is lost. Subsequently, if recirculation is not established, a loss of water inventory in the core will occur and fuel temperatures will rise. This will result in damage to the fuel cladding barrier.

Plant Conditions:

Large Break LOCA inside Containment.

RWST level is less than 33%.

Containment level greater than 2 feet OR Sump B level greater than 75%.

At least one train of ECCS recirculation equipment is available and can be operated from the Control Room.

Cues:

SI Actuation.

RWST level less than 33%.

Containment Level greater than 2 feet.

Sump B level greater than 75%.

Performance Indicator:

Manipulation of the following controls, as required, to align at least one train of ECCS to cold leg recirculation:

Close RWST to RHR Isolation Valve.

Close at least one SI Test Line to RWST Valve.

Open CC to RHR HX.

Open Sump B to RHR Isolation Valve.

Restart RHR Pump.

Feedback:

RHR flow for the train aligned for recirculation.

Page 5 of 15 2016 ILT NRC SIMULATOR EVALUATION #4 SCENARIO OVERVIEW:

SEQUENCE OF EVENTS:

Event 1: Raise Reactor Power to the Point of Adding Heat

Reactor power is at 1 x 10-8 amps.

Rods will be stepped out to establish a positive startup rate.

Power will rise to between 0.5% and 2%.

Rods will be stepped in to level power out.

Event 2: Secure 12 MDAFW Pump

The crew will stop 12 MD AFW Pump per 1C28.1.

Event 3: Loss of the 11 Containment Fan Coil Unit

11 CFCU trips on overload.

The crew responds by realigning 12 CFCU to support.

The SS will enter TS LCO 3.6.5 Condition C.

Event 4: 1PT-431, Blue Channel Pressurizer Pressure, fails HIGH.

PT-431 slowly drifts to max.

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.

The SS will enter the following:

TS LCO 3.3.1 Condition A and E.

TS LCO 3.3.2 Condition A and D.

Event 5: Large Break LOCA

Safety Injection fails to automatically actuate.

The crew will manually actuate Safety Injection.

Containment Pressure rises, RCS pressure and Pressurizer level rapidly lowers.

The crew will transition back to 1E-0.

The crew will transition into and out of 1FR-P.1 when a red path in integrity CSF occurs.

All feedwater components will fail to automatically align for Safety Injection.

The crew will manually align feedwater components per Attachment L of 1E-0.

The crew will diagnose a Loss of Coolant Accident and transition to 1E-1.

When RWST level lowers to 33%, the crew will place one train of ECCS on recirculation per 1ES-1.2.

The evaluation will be terminated once one train of ECCS is on recirculation.

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

1.

SIMULATOR PRE-BRIEF:

a.

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

2.

COMPLETE TURNOVER:

a. UNIT 1 LPEO / PEO TURNOVER LOG.

b. PRA Printout.

c. Verify crew performs walk down of control boards and the 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 Booth Operator:

1. After the crew has assumed the duty, they will raise power to the Point of Adding Heat.

RO/SS 1C1.2, UNIT 1 STARTUP PROCEDURE Raise reactor power to the point of adding heat using manual rod control or boron concentration change.

When one or more intermediate range indicates greater than 1 x 10-9 amps, then verify ERCS is in Mode 2, STARTUP.

Maintain reactor power between 0.5 and 2.0%.

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

1. After the crew has raised power to the Point of Adding Heat, they will secure 12 MD AFW Pump per the OPERATIONAL PLANS FOR COMING SHIFT.

2. When directed as an out-plant operator to verify, 12 MD AFW Pump has stopped, CV-31154 has closed, and Auxiliary lube oil pump is running, then wait approximately 2 minutes and report 12 MD AFW Pump is stopped, CV-31154 is closed, and Auxiliary lube oil pump is running.

3. When directed as an out-plant operator to stop 12 MD AFW Pump Aux Lube Oil Pump, then wait approximately 3 minutes and report Aux Lube Oil Pump has been stopped.

4. If contacted as the duty chemist, acknowledge 12 MD AFW Pump has been stopped.

LEAD 1C28.1, AUXILIARY FEEDWATER SYSTEM UNIT 1 CLOSE MV-32381, 12 MD AFWP TO 11 STM GEN, using CS-46316.

CLOSE MV-32382, 12 MD AFWP TO 12 STM GEN, using CS-46317.

Stop 12 MD AFW Pump using CS-46425.

Direct an out-plant operator to verify locally:

o 12 MD AFW Pump has stopped.

o CV-31154, 12 MD AFW PMP RECIRC/L-O CLG CV, has CLOSED.

o Auxiliary lube oil pump is running.

Direct an out-plant operator to locally stop 12 MD AFW Pump Aux Lube Oil Pump when 12 MD AFW Pump stops rotating.

OPEN MV-32381, 12 MD AFWP TO 11 STM GEN, using CS-46316.

OPEN MV-32382, 12 MD AFWP to 12 STM GEN, using CS-46317.

Independently verify MV-32381 and MV-32382 are OPEN.

Verify SI Not Ready panel light 44102-B9, 12 AFW DISCH VLV CLOSED, is NOT LIT, indicating the discharge valves are OPEN.

Place CS-46439, 12 MD AFWP selector switch in AUTO.

Independently verify CS-46439 in AUTO.

Notify the Duty Chemist that 12 MD AFW Pump has been stopped.

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

1. After 12 AFWP has been secured, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 3, 11 CFCU trips on overload.

2. If contacted as the out-plant operator to check the breaker of 11 CFCU, report that it is tripped open.

3. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc.

4. 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.

Plant Response:

1. The following annunciators are received:

a. 47019-0404, 11 CFCU MOTOR STATOR HI TEMP.

b. 47021-0503, REACTOR VESSEL SUPPORT COOLING LO FLOW.

c. 11 CFCU light indication turn off.

LEAD LEAD SS C47019-0404, 11 CFCU MOTOR STATOR HIGH TEMP Verify one of 11 CFCU discharge dampers is open.

Verify proper cooling water alignment to 11 CFCU.

If above steps did not reduce stator temperature then, o

Stop 11 CFCU.

o Verify CD-34075, 12 FCU NORM DISCH TO RX VESSEL SUPPORT, OPEN.

o Verify 12 CFCU running in fast.

C47021-0503, REACTOR VESSEL SUPPORT COOLING LO FLOW Verify a Reactor Vessel Support Cooling Fan running.

Then verify a FCU is running in FAST with the discharge damper aligned to the Support.

If annunciator does not clear, then start standby Support Cooling Fan.

1C19.2, Section 5.6.4 (May be used by crew to shift 12 CFCU)

Align 12 CFCU damper to the Support position.

Shift 12 FCU to FAST, pausing in OFF for 1 second.

Enter TS LCO 3.6.5 Condition C:

o Restore to operable within 7 days.

The SS should make notifications per SWI O-28.

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

1. When the crew has responded to the 11 CFCU trip, and/or at the discretion of the Lead Evaluator, then enter:

Trigger 4, Blue Channel Pressurizer Pressure fails high.

NOTE: The Lead Evaluator may elect to have the BOP operator sequestered during the initial phase of this event to ensure

2. If contacted as I&C to trip bistables, inform the crew two I&C Technicians will be available in 45 minutes.

3. If contacted as the Operations Management, acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station Manager, etc. as asked.

4. 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.

Plant Response:

1. Pressurizer Spray valves open.

2. Pressurizer pressure lowers rapidly.

3. The following annunciators are received:

a. 47012-0508, PRZR HI/LO PRESS.

b. 47012-0608, PRZR CONTROL HI PRESS OR BACKUP HTRS ON

4. If spray valves are not manually closed, then:

a. Reactor Trip.

b. Safety Injection.

C47012-0408 PRZR HI/LO PRESS CHANNEL ALERT Check pressure high or low.

If necessary then control pressure in manual.

Go to 1C51.3 C51.3, PRESSURIZER PRESSURE 1P-431 HIGH Place Pressurizer Pressure Controller in MANUAL and stabilize pressure.

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

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.

Enter TS LCO 3.3.1 Condition A o Reference Table 3.3.1-1 immediately.

Enter TS LCO 3.3.1 Condition E o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Enter TS LCO 3.3.2 Condition A o Reference Table 3.3.2-1 immediately.

Enter TS LCO 3.3.2 Condition D o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND o Be in Mode 4 in 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months Trip bistables.

QF-1075-02 Rev. 4 (FP-T-SAT-75) Page 10 of 15 PI-ILT-NRC-1604S, 2016 ILT NRC SIMULATOR EVALUATION #4, REV. 0 EVENT 5 EVENT 5 (cont)

Booth Operator:

1. When the crew has responded to the Pressurizer Pressure Instrument failure and/ or at the discretion of the Lead Evaluator, then enter:

Trigger 5, Large Break LOCA.

2. Upon hearing the announcement of Safety Injection, or when called as the Turbine Building Operator to secure the Turbine Building Roof Exhausters, wait approximately 2 minutes and report the Turbine Building Roof Exhausters are all secured.

3. If there is NO examinee in the Unit 2 Lead position and Control Room personnel ask if Unit 2 personnel are available to perform Attachment L, then inform the Control Room that Unit 2 personnel are NOT available for performing Attachment L.

Plant Response:

1. RCS pressure and Pressurizer level lowers rapidly.

2. Containment Pressure rises.

3. Safety Injection fails to automatically actuate.

4. Feedwater Components fail to automatically align.

CRITICAL TASK Manually actuate at least one train of SI-actuated safeguards equipment before a RED path in Core Cooling CSF occurs.

EMERGENCY PLAN CLASSIFICATION ALERT - FA1 due to a loss of RCS Fission Product Barrier caused by the LBLOCA.

Booth Operator:

1. If contacted by the Control Room to report status of CAT 1 Vent Zone openings, then inform the CR that all CAT 1 Vent Zone openings are closed.

RO/

LEAD SS RO SS LEAD 1E-0, REACTOR TRIP OR SAFETY INJECTION Verify reactor tripped.

o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

Verify the Main Turbine tripped.

o Left and right Stop Valves are CLOSED.

Verify both Safeguards buses energized.

Determine SI is required.

o Check EITHER Pressurizer Pressure or Containment Pressure and determine that SI is required.

Manually actuate SI.

Perform Attachment L (see SEG pages 14 & 15).

Check AFW Status o Total AFW flow >200 GPM.

o AFWP discharge pressure >1000 PSIG.

o Maintain SG WR levels 50-59%.

Check RCS Average Temperatures trending to 547°F.

o Cold leg temperature is used if RCPs have been tripped.

Check PRZR PORVs and Spray valves closed.

Stop RCPs due to trip criteria being met.

o Injection flow to the RCS.

o RCS Pressure < 1250 PSIG [1576 PSIG].

o Operator Controlled Cooldown NOT initiated.

Determine SGs are NOT faulted.

o No SG pressure decreasing in an uncontrolled manner.

o No SG completely depressurized.

Determine SG Tubes are NOT ruptured.

o Condenser air ejector radiation normal.

o SGB radiation normal.

o Main Steam Line radiation normal.

QF-1075-02 Rev. 4 (FP-T-SAT-75) Page 11 of 15 PI-ILT-NRC-1604S, 2016 ILT NRC SIMULATOR EVALUATION #4, REV. 0 EVENT 5 (cont)

2. If Control Room personnel ask for status of Unit 2 Cooling Water/Chilled Water lineup, then inform the Control Room that Unit 2 Cooling Water/Chilled Water valves are in their safeguards positions.

3. If Control Room personnel ask for status of Battery Room Temperatures, then inform the Control Room that Battery Room temperatures are 74°F.

4. If Control Room personnel ask for status of Spent Fuel Cooling, then inform the Control Room that Spent Fuel Pool level and temperatures are normal.

LEAD Determine RCS is NOT intact due to Containment pressure rising.

Go to 1E-1.

NOTE: Expected to enter 1FR-P.1 as soon as Red or Orange Path in Integrity CSF is received.

1FR-P.1 RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITION Determine RCS pressure is greater than 550 psig.

Determine RHR flow is greater than 950 gpm.

Return to procedure and step in effect.

1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION Verify Safeguards Component Alignment:

Verify both trains of SI actuated:

o Both RHR pumps or both SI pumps - RUNNING.

"SI NOT READY" lights - NOT LIT.

"SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

"CONTAINMENT ISOLATION" lights - LIT FOR PLANT CONDITIONS.

QF-1075-02 Rev. 4 (FP-T-SAT-75) Page 12 of 15 PI-ILT-NRC-1604S, 2016 ILT NRC SIMULATOR EVALUATION #4, REV. 0 EVENT 5 (cont)

Booth Operator:

1. If Control Room personnel ask if Unit 2 personnel are available to secure Diesel Generators and/or Safeguards Cooling Water Pumps, then inform the Control Room that Unit 2 personnel WILL secure the Diesel Generators and/or Safeguards Cooling Water Pumps.

2. When called as the Auxiliary Building Operator to open RD-4-6 and 2RD-4-2, wait approximately 2 minutes and report these valves are open.

3. When requested to perform Attachment K, then wait approximately 2 minutes and perform the following:

a. Enter Trigger 15, Att. K Out-Plant Actions.

b. When all items from Trigger 15 have been entered, then inform Control Room Attachment K is complete.

RO /

SS Check Category 1 Vent Zone Boundary.

Close MV-32115, 122 SFP HX INLT HDR MV B.

Check Cooling Water Header Pressures - BOTH GREATER THAN 65 PSIG.

Verify Plant Announcements Complete.

Check If Main Steamlines Are Isolated.

Manually close both MSIVs.

If necessary, manually close Containment Instrument Air Valves.

Verify SI Flow.

Verify RHR Flow.

Verify Containment Spray is actuated.

Check RCP Cooling.

Verify Local Actions Complete.

Verify Generator Breakers - OPEN.

Determine Heater Drain Tank Pumps did NOT automatically stop.

Secure any running Heater Drain Tank Pumps.

Check Turbine Valves:

o Turbine reheat and intercept valves - CLOSED.

o Open turbine drain valves.

Verify Main Feedwater Alignment:

o Determine both main feedwater pumps did NOT automatically stop.

o Secure any running Main Feedwater Pumps.

o Verify Main and bypass FRVs are CLOSED.

Determine Condensate Pumps did NOT automatically stop.

Secure any running Condensate Pumps.

Verify Steam Dump in "STM PRESS" Mode.

Verify Unit 1 Cooling Water/Chilled Water Alignment:

o CFCU control switches - "SLOW".

o CFCU dampers - ALIGNED TO DOME.

QF-1075-02 Rev. 4 (FP-T-SAT-75) Page 13 of 15 PI-ILT-NRC-1604S, 2016 ILT NRC SIMULATOR EVALUATION #4, REV. 0 EVENT 5 (cont)

CRITICAL TASK Transfer to cold leg recirculation and establish ECCS recirculation flow before an ORANGE or RED path in Core Cooling CSF occurs.

SS RO /

LEAD /

SS o Unit 1 cooling water/chilled water valves closed.

o Unit 1 CRDM shroud cooling supply and return valves - CLOSED.

o CFCU cooling water supply and return valves -

OPEN.

o CFCU chilled water supply and return valves -

CLOSED.

Verify 11 Safeguards Screenhouse Ventilation lineup.

Verify Control Room Ventilation Alignment:

o Chillers and fans - RUNNING.

o Control room chiller suction/discharge tie closed -

STATUS LIGHT LIT.

Verify Unit 2 Cooling/Chilled Water Alignment.

Verify 21 Safeguards Screenhouse Ventilation lineup.

Verify 11 and 12 Battery Charger Operation is normal.

Verify Battery Room temps less than 84°F.

Check status of Spent Fuel Cooling.

Check Status Of Notifications.

Notify SS Of Any Discrepancies.

1E-1, LOSS OF REACTOR OR SECONDARY COOLANT Determine RCPs are already stopped.

Check SGs NOT faulted and NOT ruptured.

Check PRZR PORVs and Block Valves:

o Power to block valves available.

o PRZR PORVs - CLOSED.

o At least ONE block valve OPEN.

Reset SI and CI.

Establish Instrument Air to Containment.

Check power supply to charging pumps.

Check if Charging Flow has been established.

Determine SI flow should NOT be terminated.

Determine RHR Pumps should NOT be stopped.

Check RCS and SG Pressures.

Stop Diesel Generators and Cooling Water Pumps.

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SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Verify at least one train of recirculation capability.

Check Aux Building Radiation - NORMAL.

Start all containment dome recirculation fans.

Check if outside air can be supplied to CR.

Align Containment FCU Cooling Water Outlet Radiation Monitor R-16 and R-38.

Check Annulus Sump High Level Alarm - OFF.

Determine RCS Cooldown and Depressurization is NOT required.

Prepare for Switchover to Recirculation Phase:

o Stop Spent Fuel Pool Vent System.

o Notify Outplant to perform Attachment K.

Go to 1ES-1.2 when RWST level is below 33%.

1ES-1.2, TRANSFER TO RECIRCULATION Prepare for switchover to recirculation phase.

Reset SI and CS.

Check both trains of safeguards pumps available for recirculation.

Stop one train of safeguards pumps.

Close RWST to RHR Isolation Valve for idle RHR pump.

o MV-32084 if 11 RHR Pump is idle.

o MV-32085 if 12 RHR Pump is idle.

Close SI Test Line to RWST Valves, MV-32202 AND MV-32203.

Verify RHR to Reactor Vessel Injection Valve Alignment by verifying open MV-32064 AND MV-32065.

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SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW POS EXPECTED STUDENT RESPONSES Align CC to RHR HX for idle RHR train by verifying OPEN:

o MV-32093 if 11 RHR Pump is idle.

o MV-32094 if 12 RHR Pump is idle.

Check Containment Level greater than 2 feet.

Check if RHR suction can be aligned to Containment Sump by verifying power to:

o MV-32077 if 11 RHR Pump is idle.

o MV-32078 if 12 RHR Pump is idle.

Verify RWST to RHR isolation valve for idle RHR pump is CLOSED.

o MV-32084 if 11 RHR Pump is idle.

o MV-32085 if 12 RHR Pump is idle.

Open Sump B to RHR isolation valves for idle RHR pump.

o MV-32077 if 11 RHR Pump is idle.

o MV-32078 if 12 RHR Pump is idle.

Check if second CS pump can be stopped.

Verify Sump B to RHR isolation valves for idle RHR pump are full open.

o MV-32077 if 11 RHR Pump is idle.

o MV-32078 if 12 RHR Pump is idle.

Start idle RHR pump.

Determine RCS pressure is less than 250 psig.

Determine RHR flow is greater than 950 gpm.

END When one train of ECCS has been placed in the recirculation mode, or at the discretion of the Lead Evaluator, then place the simulator in FREEZE.

ML16141A511

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