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 Date (Simulator Scenario Development Checklist.)

Validated by: Fred Collins 12/28/2015 Validation Lead Instructor Date (Simulator Scenario Validation Checklist.)

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 Trip Reactor Coolant Pumps within ten minutes of RCP trip criteria being Critical Task:

met.

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

Safety Thus, failure to perform the task represents misoperation or incorrect Significance:

crew performance in which the crew has failed to prevent degradation of the fuel cladding barrier to fission product release.

Small Break LOCA.

Break size less than 2.5 inches.

Plant

At least one Safety Injection Pump running.

Conditions:

RCPs Running.

RCP trip criteria are met.

Injection flow exists to RCS:

o At least one SI Pump running and flow indicated.

-OR-Cues:

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.

Manually stopping RCPs using:

Performance

CS-46255, 11 REACTOR CLNT PUMP.

Indicator:

CS-46256, 12 REACTOR CLNT PUMP.

Indication that all RCPs are stopped.

Both RCP Pump green indicating lights LIT.

Feedback:

Both RCP Pump red indicating lights NOT LIT.

RCP flow decreasing.

Page 4 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 CRITICAL TASK SHEET Manually actuate Containment Isolation or close Containment Isolation Critical Task: valves such that at least one valve is closed on each Containment penetration before the end of the scenario.

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

LOCA is occurring.

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

Conditions:

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

Indication that SI actuated.

AND Cues:

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.

Manually actuating Containment Isolation using one of the following:

o CS-46085.

Performance o CS-46113.

Indicator:

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

Containment Isolation Status Light Panel indicates at least one Feedback:

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 EXPECTED STUDENT RESPONSES POS

1. SIMULATOR PRE-BRIEF:

a. The Simulator Pre-Brief is conducted prior to the crew entering the simulator. Review the following with the off-going operator:

2. COMPLETE TURNOVER: CREW

Unit 1 LPEO / PEO Turnover Log

a. UNIT 1 LPEO / PEO TURNOVER LOG.

PRA printout

b. PRA Printout.

Walk-down the control boards and ask questions as

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

Page 8 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 1 Booth Operator: 1C5 AOP1, UNCONTROLLED ROD MOTION

1. After the crew has assumed the duty and/or at the RO

Check generator load stable.

discretion of the lead evaluator, enter:

Place rod bank selector switch to MANUAL.

Trigger 1, PR Yellow Channel N44, fails LOW.

Check rod motion stopped.

Determine N44 is failed.

2. If contacted as I&C to trip bistables, inform the crew two SS

Go to 1C51.4.

I&C Technicians will be available in 45 minutes.

3. If contacted as the Operations Management, 1C51.4, PWR RNG NUCLEAR INSTR N LOW acknowledge the report of the failure, and agree to make RO

Place rods in MANUAL and maintain Tavg at Tref.

other notifications to the NRC, Duty Station Manager,

Refer to the following TS requirements:

etc. as asked. o Enter TS LCO 3.3.1 Condition A

4. If contacted as the FIN Team Supervisor, inform the - Reference Table 3.3.1-1 immediately.

crew that you will write a work order and assign an I&C SS o Enter TS LCO 3.3.1 Condition D Supervisor to investigate. - Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and perform

5. If contacted as Nuclear Engineering, acknowledge the SP-1120 OR request to perform SP-1120. - 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 EVENT 1 Plant Response:

(CONT) o Enter TS LCO 3.3.1 Condition R

1. Control rods step out automatically. - Verify P-7, P-8, and P-9 are in required states

2. The following annunciators will be received: for existing unit conditions in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR

a. 47013-0201, NIS PR NEG FLUX RATE CH ALERT. - Be in Mode 3 in 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months

b. 47013-0203, NIS PR RANGE DEVIATION. 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:

LEAD 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 EXPECTED STUDENT RESPONSES POS 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.

RO 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.

LEAD /

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

RO /

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

SS

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: C47019-0403, 11 RWST LO-LO LVL

1. After the crew has removed N44 from service, and/or at LEAD

Check alarm is valid using alternate indications:

the discretion of the Lead Evaluator, then enter: o 47016-0104, 11 RWST LO-LO LVL, LIT Trigger 2, 11 RWST Level Transmitter, fails LOW o 1LI-920, 11 RWST LI o 1LI-921, 11 RWST LI

2. If contacted as the Operations Management,

Determine safeguards initiation has not occurred.

acknowledge the report of the failure, and agree to make

Determine NO operating pumps are taking a suction other notifications to the NRC, Duty Station Manager, from the RWST.

etc. as asked.

Determine an instrument malfunction has occurred.

3. If contacted as the FIN Team Supervisor, inform the

Initiate Action Request and Work Request.

crew that you will write a work order and assign an I&C

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

4. If contacted as the out-plant operator to inspect for o Restore required channel to OPERABLE status leakage from the RWST, wait approximately 2 minutes within 30 days.

and report there is NO leakage.

Determine RWST is still OPERABLE (TS LCO 3.5.4).

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.

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

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW EXPECTED STUDENT RESPONSES POS EVENT 3 Booth Operator: C47021-0503, REACTOR SUPPORT COOLING LO

1. After Shift Supervisor has addressed Technical LEAD/ FLOW Specifications for RWST failure, and/or at the discretion RO

Determine no reactor support cooling fan running.

of the Lead Evaluator, then enter:

Determine no SI signal present.

Trigger 3, 11 RX SUPPORT COOLING FAN TRIP.

Start standby reactor support cooling fan.

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.

Page 12 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 EVENT 4 Booth Operator: 1C23 AOP2, MALFUNCTION OF TURBINE EH

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

Determine EH oil pressure is normal.

Trigger 4, Two Opposing Turbine Control Intercept

Determine a turbine runback is NOT in progress.

Valves Fail Closed.

If the symptoms indicate a potential problem with the EH oil system, then notify the Turbine Building

2. If contacted as the Operations Management, operator of the symptoms and direct the operator to acknowledge the report of the failure, and agree to make locally check operation of the system.

other SWI O-28 notifications to the NRC, Duty Station

Determine load cycling is NOT occurring.

Manager, etc.

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

3. If contacted as the FIN Team Supervisor, inform the crew

Determine two valves on the same side of the turbine that you will write a work order and assign a Turbine are NOT closed.

Control Engineer to investigate.

Determine two valves from diagonally opposite MSRs

4. If contacted as Unit 2 Control Room Operators to monitor have closed.

Unit 1 Heater Drain Tank alarms (Panel F), then

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

acknowledge request and inform Unit 1 Operators that an extra operator will monitor Panel F.

1C1.4 AOP1, RAPID POWER REDUCTION UNIT 1

Determine the predicted Boron addition and final Plant Response: LEAD /

Control Rod Position by obtaining values from the

1. MW load lowers. RO appropriate contingency reactivity plan.

2. RCS Tavg rises.

3. Rods automatically step out initially then step in.

Borate the RCS as necessary to maintain control rods

4. CV-31167 (Intercept Valve 1A) closed indication. above the insertion limit and control delta I within

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

Control Rods in manual during the load reduction.

NOTE

Place pressurizer heaters to ON.

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

Using the On Line Control screen, select the Control power prior to proceeding to the next event. Once the Mode pop-up screen.

Lead Evaluator is satisfied with the reactivity

Select the desired control mode (VPC, FSP, or manipulation, proceed to Event 5. LOAD).

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

Select the desired rate of load change.

EVENT 4

Set the desired Target setting using the On Line (cont)

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 EXPECTED STUDENT RESPONSES POS LEAD /

Verify the Boric Acid integrator is reset.

RO

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 EXPECTED STUDENT RESPONSES POS EVENT 5 Booth Operator: 1C5 AOP4, DROPPED RCCA

1. When the lead evaluator is satisfied with the reactivity

Confirm Rod Drop using diverse indications:

manipulation, then enter: RO

Rod Position Indication and RCS Tavg Changes Trigger 5, Dropped Rod K CBA GR1. OR

Rod Position Indication and NIS Changes.

2. Upon hearing the announcement of Reactor Trip, or when

Manually trip the reactor.

called as the Turbine Building Operator to isolate the Unit

Perform 1E-0.

1 MSRs per Attachment J, then open and run schedule file E-0_Att-J.sch located in C47017-0404, FLUX RATE REACTOR TRIP X:\\Trex_PI\Lightning\Schedule\EOPs. When the

Perform 1E-0.

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

1E-0, REACTOR TRIP OR SAFETY INJECTION Plant Response:

Determine the reactor did NOT automatically trip.

RO/

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

Manually trip the reactor.

LEAD

2. NIS power and RCS Tavg lowering.

Manually trip the main turbine.

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

Verify both safeguards buses are energized.

4. The reactor fails to automatically trip.

Determine SI is NOT actuated and NOT required.

5. Panel C Reactor Trip Switch does not operate. o No SI Actuated or SI first-out annunciator.

o Both SG pressures >530 PSIG.

o PRZR pressure >1830 PSIG.

EMERGENCY PLAN CLASSIFICATION o Containment pressure <3.5 PSIG.

ALERT - SA2.1 due to the reactor failing to automatically

Go to 1ES-0.1 trip during the high negative flux rate condition and the crew successfully manually tripping the reactor. 1ES-0.1, REACTOR TRIP RECOVERY However, this classification may NOT be used due to a

Announce Unit 1 Reactor Trip.

higher classification being met in the next event.

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 Booth Operator: 1E-0, REACTOR TRIP OR SAFETY INJECTION

1. After the crew has transitioned to 1ES-0.1, and/or at the LEAD /

Verify the reactor is tripped.

discretion of the Lead Evaluator, then enter: RO o Reactor Trip Breakers are OPEN.

Trigger 6, Small Break LOCA. o SUR is NEGATIVE.

o RPI indicate ZERO.

2. Upon hearing the announcement of Safety Injection, or o Rod at Bottom lights are LIT.

when called as the Turbine Building Operator to secure

Verify the Main Turbine is tripped.

the Turbine Building Roof Exhausters, wait 2 minutes and o Left and right Stop Valves are CLOSED.

report the Turbine Building Roof Exhausters are all

Determine both Safeguards buses energized.

secured.

Determine SI is either actuated and/or required.

3. If Control Room personnel ask if Unit 2 personnel are o Check Pressurizer Pressure and determine available to perform Attachment L, then inform the that SI is required.

Control Room that Unit 2 personnel are NOT available for

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

performing Attachment L.

Check AFW Status.

4. If Control Room personnel ask if Unit 2 personnel are o Total AFW flow >200 GPM.

available to secure Diesel Generators and/or Safeguards o AFWP discharge pressure >1000 PSIG.

Cooling Water Pumps, then inform the Control Room that SS o Maintain SG NR level 5-50% [WR levels Unit 2 personnel WILL secure the Diesel Generators 50-59%].

and/or Safeguards Cooling Water Pumps.

Check RCS Tavg trending to 547°F.

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

1. PRZR level and pressure lowers. RO /

Check PRZR PORVs and Spray valves closed.

2. CTMT pressure and humidity rise. SS

Stop RCPs due to trip criteria being met.

3. RCS leak rate rises.

o Injection flow to the RCS.

o RCS Pressure < 1250 PSIG [1576 PSIG].

CRITICAL TASK o Operator Controlled Cooldown NOT Trip both Reactor Coolant Pumps within 10 minutes of initiated.

meeting RCP Trip Criteria.

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.

Booth Operator: o Condenser air ejector radiation normal.

EVENT 6 (cont) 1. If contacted by the Control Room to report status of CAT o SGB radiation normal.

1 Vent Zone openings, then inform the CR that all CAT 1 o Main Steam Line radiation normal.

Vent Zone openings are closed.

Determine RCS is NOT intact due to Containment

2. If Control Room personnel ask for status of Unit 2 pressure rising.

Cooling Water/Chilled Water lineup, then inform the LEAD

Go to 1E-1.

Page 16 of 18 2016 ILT NRC SIMULATOR EVALUATION #1 Control Room that Unit 2 Cooling Water/Chilled Water 1E-1, LOSS OF REACTOR OR SECONDARY valves are in their safeguards positions. COOLANT

3. If Control Room personnel ask for status of Battery

Check if RCPs should be stopped.

Room Temperatures, then inform the Control Room that

Determine SGs are NOT faulted.

Battery Room temperatures are 74°F.

Check SG levels.

Determine secondary radiation levels are normal.

Check PRZR PORVs CLOSED.

Reset SI and CI.

Establish IA to CTMT.

CRITICAL TASK

Check power available to charging pumps.

Manually actuate Containment Isolation or close

Establish charging flow.

Containment Isolation valves such that at least one valve is closed on each penetration before the end of the

Determine SI should NOT be stopped.

scenario.

Secure RHR pumps.

EMERGENCY PLAN CLASSIFICATION SITE AREA EMERGENCY -FS1 due to loss of RCS fission product barrier due to Small Break LOCA and 1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION potential loss of Containment fission product barrier due

Verify Safeguards Component Alignment:

to failure of Containment Isolation to automatically

Verify both trains of SI actuated:

actuate during a Safety Injection. 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.

EVENT 6 o CI Phase A fails to actuate.

(cont) ATTACHMENT L MALFUNCTIONED COMPONENT LIST o Manually actuate CI or manually align individual components per the table on page Panel 44104 ID Component Control Switch 17.

C A1 CV-31318 CS-46266

Check Category 1 Vent Zone Boundary.

C B1 CV-31319 CS-46262 B D2 CV-31339 CS-46166

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

B A3 MV-32199 CS-46173 LEAD

Check Cooling Water Header Pressures - BOTH B B3 MV-32166 CS-46132 GREATER THAN 65 PSIG.

A A4 CV-31545 CS-46235 A B4 CV-31546 CS-46234

Verify Plant Announcements Complete.

A C4 CV-31434 CS-46237

Check If Main Steamlines Are Isolated.

A D4 CV-31435 CS-46236

Determine MSIVs, Bypass Valves, and Containment A A5 CV-31436 CS-46231 Instrument Air Valves do NOT need to be closed.

A B5 CV-31437 CS-46230 A C5 CV-31438 CS-46233

Verify SI Flow.

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

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW EXPECTED STUDENT RESPONSES POS A D5 CV-31439 CS-46232

Verify RHR Flow.

D B6 MV-32044 CS-46339 D C6 MV-32058 CS-46340

Verify Containment Spray is actuated (if necessary).

D D6 MV-32040 CS-46969

Check RCP Cooling.

D E6 MV-32043 CS-46968

Verify Local Actions Complete.

A A7 CV-31621 CS-46054 A B7 CV-31622 CS-46055

Verify Generator Breakers - OPEN.

E C7 MV-32023 CS-46413

Verify All Heater Drain Pumps - STOPPED.

E D7 MV-32024 CS-46414

Check Turbine Valves:

OP* D8 CV-31402 CS-70612 o Turbine reheat and intercept valves - CLOSED.

OP* E8 CV-31403 CS-70613 RMR** A10 CV-31750 CS-19447 o Open turbine drain valves.

RMR** B10 CV-31022 CS-19449

Verify Main Feedwater Alignment:

- - D15 CV-31438 OR CV- CS-46233 OR CS- o Both main feedwater pumps - STOPPED.

31439 46232 o Main and bypass FRVs - CLOSED.

CV-31438 OR CV- CS-46233 OR CS-

- - E15 31439 46232

Verify All Condensate Pumps - STOPPED.

Control Switch located in Out-Plant. If examinee directs the out-plant operator to

Verify Steam Dump in "STM PRESS" Mode.

close the 11/12 SGB Isolation Valves, then enter REMOTES SG102 & SG103 to CLOSE.

Verify Unit 1 Cooling Water/Chilled Water Alignment:

- Panel located opposite R-11/R-12 Radiation Monitor Racks. o CFCU control switches - "SLOW".

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

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 Date (Simulator Scenario Development Checklist.)

Validated by: Fred Collins 12/15/2015 Validation Lead Instructor Date (Simulator Scenario Validation Checklist.)

Approved by: Mike Petersen 3/25/2016 Training Supervision Date

Page 2 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 Guide Requirements Evaluation Evaluate the crews ability to:

Objectives:

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 1. Full Scope Simulator Resources: 2. NRC Evaluation Team

3. Booth Operator (Backup Communicator)

4. Primary Communicator Related PRA Initiating Event with Core Damage Frequency:

Information: 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 Manually actuate containment cooling as necessary to prevent Critical Task:

containment pressure from exceeding 46 psig.

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

At least one of the following accidents:

- LOCA into Containment.

- Unisolable Steam Line Break into Containment.

Plant

Containment pressure will exceed 46 psig if no operator action is Conditions: 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.

Containment pressure is rising.

Cues:

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

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

Indicator:

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 Establish feedwater flow to the Steam Generators before both Steam Critical Task:

Generator Wide Range Levels lower below 9% [20%].

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

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 Plant o Condensate Pumps Conditions:

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

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

Cues:

Both Steam Generator levels lowering.

RCS pressure is above the pressure of all Steam Generators.

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 Performance o Main Feedwater Pumps Indicator:

o Condensate Pumps

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

Increasing water level in at least one Steam Generator.

Feedback:

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 Stop feed flow to the faulted Steam Generator before the end of the Critical Task:

scenario.

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

Containment Barrier.

One faulted Steam Generator.

The fault is into Containment.

The fault can NOT be isolated.

Plant Conditions:

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.

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

Cues:

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

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

Performance

AFW Pump Discharge Valve(s)

Indicator:

AFW Pump(s)

Main and Bypass Feedwater valve(s)

MFW Pump(s)

AFW flow to the faulted Steam Generator is secured.

Feedback:

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 EXPECTED STUDENT RESPONSES POS

1. SIMULATOR PRE-BRIEF:

a. The Simulator Pre-Brief is conducted prior to the crew entering the simulator. Review the following with the off-going operator:

2. COMPLETE TURNOVER: CREW

Unit 1 LPEO / PEO Turnover Log

a. UNIT 1 LPEO / PEO TURNOVER LOG.

PRA printout

b. PRA Printout.

Walk-down the control boards and ask questions as

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

EVENT 1 Booth Operator: 1C18, ENGINEERED SAFEGUARDS SYSTEM UNIT 1

1. After the crew has assumed the duty, they will raise 12 LEAD

Direct an out-plant operator to perform steps 6.5.1 -

Safety Injection Accumulator pressure per 1C18. 6.5.3 of 1C18.

Under administrative control, OPEN CV-31444,

2. When contacted as the out-plant operator to perform NITROGEN TO 12 ACCUM, using CS-46220.

steps 6.5.1 - 6.5.2 of 1C18, wait approximately 2 minutes

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

3. When contacted as the out-plant operator to perform step

Direct an out-plant operator to perform step 6.5.6 of 6.5.7 of 1C18, wait approximately 2 minutes and report 1C18.

completion and d/p is zero.

When 12 SI accumulator pressure reaches 750 psig,

4. When contacted as the out-plant operator to perform then CLOSE CV-31440, ACCUM NITROGEN SPLY, steps 6.5.14 and 6.5.15 of 1C18, wait approximately 2 using CS-46212.

minutes and report completion.

CLOSE CV-31444, NITROGEN TO 12 ACCUM, using

5. When contacted as the SI System Engineer, CS-46220.

acknowledge completion of raising pressure in 12 SI

Independently verify CV-31444 is closed.

Accumulator.

Independently verify CV-31440 is closed.

Direct an out-plant operator to perform steps 6.5.12 Plant Response:

and 6.5.13 of 1C18.

1. 12 SI Accumulator pressure rises.

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

Notify the SI System Engineer of completion of procedure.

Page 10 of 21 2016 ILT NRC SIMULATOR EVALUATION #2 EVENT 2 Booth Operator: 1C1.4, UNIT 1 POWER OPERATION

1. After the crew has completed raising pressure in 12 SI

Place CS-46280, ROD BANK SELECTOR, in Accumulator and/or at the discretion of the lead RO/SS MANUAL.

evaluator, then:

Using the On Line Control screen:

a. As the Shift Manager, direct the Unit 1 SS to raise o Select LOAD or FSP.

Unit 1 Reactor Power to 95%. o Select 0.5% demand rate.

2. If contacted as the duty chemist, acknowledge Unit 1

Verify the VPL control is not Red.

power will be raised from 90% to 95%.

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

Plant Response:

Set the Target setting to the desired Load using On

1. Reactor Power rises. Line Control screen Target increase/decrease

2. Generator Load rises. controls.

3. RCS Tavg rises.

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

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

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

Adjust the alternate dilution rate or perform alternate power prior to proceeding to the next event. Once the dilutions per 1C12.5 to maintain Tave and Tref with Lead Evaluator is satisfied with the reactivity the desired +/-1.5°F band.

manipulation, proceed to Event 3.

1C12.5, UNIT 1 BORON CONCENTRATION CONTROL RO/SS

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.

EVENT 2

When the desired quantity of makeup has been (cont) added, then verify automatic makeup stopped as RO/SS 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 EXPECTED STUDENT RESPONSES POS

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 EXPECTED STUDENT RESPONSES POS EVENT 3 Booth Operator: 1C5 AOP1, UNCONTROLLED ROD MOTION

1. When control rods are back in AUTO and/or at the LEAD/

Check turbine generator load STABLE.

discretion of the Lead Evaluator, then enter: RO

Place rods in MANUAL.

Trigger 3, Turbine 1st Stage Pressure fails LOW.

Check rod motion STOPPED.

Determine Turbine First Stage Pressure Instrument

2. If contacted as I&C to trip bistables, inform the crew two failed.

I&C Technicians will be available in 45 minutes.

Go to 1C51.2.

3. If contacted as the Operations Management, LEAD/

acknowledge the report of the failure, and agree to make RO 1C51.2, TURBINE 1ST STAGE PRESSURE 1P-485-LOW other SWI O-28 notifications to the NRC, Duty Station

Place rod control in manual.

Manager, etc.

Control Tave at value appropriate for power level.

4. If contacted as the FIN Team Supervisor, inform the crew

Place one steam dump interlock bypass to OFF.

that you will write a work order and assign an I&C

Place steam dump in pressure mode.

Supervisor to investigate.

Verify steam dump valves are CLOSED.

Plant Response:

Verify zero output on steam dump controller.

1. Control Rods automatically step IN. SS

Return steam dump interlock bypass to ON.

2. Tavg will lower due to rod movement.

Verify SG level control operating properly in AUTO.

3. The following annunciators will alarm:

Enter TS LCO 3.3.1 Condition A

a. 47011-0405, FW CONTROL SYSTEM TROUBLE. o Reference Table 3.3.1-1 Function 16.b.2

b. 47013-0305, AUCTIONEERED TAVG-TREF

Enter TS LCO 3.3.1 Condition R DEVIATION. 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 Booth Operator: C47015-0205, CHARGING LINE HI PRESS

1. When the crew has determined the appropriate Technical RO

Verify high charging line pressure at 1PI-133.

Specifications for PT-485 failing low, and/or at the

Verify proper operation of 1HC-142, 11 CHG LINE discretion of the Lead Evaluator, then enter: FLOW CONTROLLER.

Trigger 4, Loss of Charging Flow to Regen HX.

Verify pressurizer level and programmed level are approximately equal.

2. If contacted as the Operations Management,

Switch to MANUAL on the charging pump speed acknowledge the report of the failure, and agree to make controller that is in AUTO and adjust as necessary other SWI O-28 notifications to the NRC, Duty Station to prevent lifting charging pump relief valves.

Manager, etc.

Determine flow is lost to regenerative heat exchanger.

3. If contacted as the FIN Team Supervisor, inform the crew SS

Go to 1C12.1 AOP2.

that you will write a work order and assign a Maintenance Supervisor to investigate. 1C12.1 AOP2, LOSS OF CHARGING FLOW TO THE

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

Determine seal injection has NOT been lost.

1492. RO /

Verify Reactor Makeup Controller in AUTO.

5. If contacted as Duty Chemist, acknowledge purification is LEAD

If VCT level is less than 17%, then verify automatic removed from service.

makeup is initiated.

Plant Response:

CLOSE the letdown orifice isolation valves:

1. Charging Flow lowers. o CV-31325

2. Pressurizer level lowers. o CV-31326

3. VCT level rises. o CV-31327

4. The following annunciators will alarm:

Close the letdown isolation valves:

a. 47015-0205, CHARGING LINE HI PRESS. o CV-31226

b. 47015-0206, 11 RCP LAB SEAL LO DP. o CV-31255

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

Place speed control for all operating charging pumps

d. 47015-0408, LTDN FLOW HI TEMP. in MANUAL.

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

Stop one of the charging pumps as follows:

f. 47015-0608, LTDN RELIEF LINE TO PRT HI TEMP. 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 EVENT 4 pump is at minimum speed.

(cont) 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 EXPECTED STUDENT RESPONSES POS line flow control valve is fully CLOSED. Verify high charging line pressure at 1PI-133.

Initiate CC flow through Excess Letdown Heat LEAD 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 Booth Operator: C47022-0307, FIRE HEADER LOW PRESSURE

1. When the plant is stable, or at the discretion of the lead LEAD

Dispatch an operator to the screen house to determine evaluator, then enter: status of the motor driven fire pump.

Trigger 5, Fire Protection Line Break.

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

2. If examinees ask if Unit 2 personnel are available to the fire protection system.

address the Fire Protection Line Break event, then inform

Refer to C31 AOP1.

examinees that Unit 2 personnel are NOT available.

3. If contacted as the out-plant operator to determine status C31 AOP1, FIRE PROTECTION LINE BREAK of the motor driven fire pump, wait 1 minute and report

Attempt to locate and identify method for isolation of the MDFP and DDFP are both running. leakage. Refer to Figure 1.

4. If contacted as the out-plant operator to walk down the LEAD

If shutdown of FP system is required for isolation, then fire protection system, wait 2 minutes and report there is perform the following:

a tremendous amount of water spraying everywhere in o Notify Fire Brigade Chief of pending loss of all the Service Building stairway and it is from the Fire Fire Pumps.

Protection Header. Also, report there is NO fire o Place CS-46466, 121 SCREEN WASH PUMP, in occurring. Pull Out to prevent pump start on low FP header

5. If requested to isolate the fire protection leak, then report pressure.

FP-35-1 and FP-35-3 are stuck open. If requested to o Dispatch an Operator to Unit 1 Rod Drive Room close specific valves to the stairway, report you can not to stop 121 MDFP by locally tripping BKR 185, find them due to the water spraying. Recommend 121 MD FIRE PMP, on Bus 180.

securing the fire protection pumps. o Dispatch an operator to Screen House to stop

6. If contacted as the Fire Brigade Chief, then acknowledge 122 DDFP by placing CS-70394-01, 122 DD FIRE the pending loss of all fire pumps. PUMP 5 POSITION SEL SW, in OFF.

NOTE: the Diesel Driven Fire Pump and Jockey Pump are o Instruct operator in Screen House to locally stop not modeled in the simulator. 121 Jockey Pump.

7. If contacted as the out-plant operator to secure the MD

Refer to F5 APP K for compensatory actions and Fire Protection Pump, then wait 1 minute and enter: SS notifications.

Trigger 11, Motor Driven Fire Pump secured.

Isolate the portion of the fire header containing the

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

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.

EVENT 5 a. Inform the Control Room that the DDFP is secured.

(cont)

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.

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

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

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 Booth Operator: 1E-0, REACTOR TRIP OR SAFETY INJECTION

1. When the crew has shutdown the Fire Protection System, LEAD/

Verify reactor tripped.

and/or at the discretion of the Lead evaluator, then enter: RO o Reactor Trip Breakers are OPEN.

Trigger 6, 11 Steam Generator Faults into o SUR is NEGATIVE.

Containment. o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

2. Upon hearing the announcement of Reactor Trip, or when

Verify the Main Turbine tripped.

called as the Turbine Building Operator to isolate the Unit o Left and right Stop Valves are CLOSED.

1 MSRs per Attachment J, then:

Determine both Safeguards buses energized.

a. Open and run schedule file E-0_Att-J.sch located in

Determine SI is required.

X:\\Trex_PI\Lightning\Schedule\EOPs. o Check Containment Pressure and

b. When the isolation is complete, inform the crew the SS determine that SI is required.

MSRs are isolated.

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

3. Upon hearing the announcement of Safety Injection, or

Check AFW Status when called as the Turbine Building Operator to secure o Total AFW flow >200 GPM.

the Turbine Building Roof Exhausters, wait approximately o AFWP discharge pressure >1000 PSIG.

2 minutes and report the Turbine Building Roof o Maintain SG WR levels 50-59%.

Exhausters are all secured.

Check RCS Tavg trending to 547°F.

4. If there is NO examinee in the Unit 2 Lead position and

Check PRZR PORVs and Spray valves closed.

Control Room personnel ask if Unit 2 personnel are RO

Determine RCPs running and do NOT meet trip available to perform Attachment L, then inform the criteria. (NOTE: RCS pressure may lower enough to Control Room that Unit 2 personnel are NOT available for meet RCP trip criteria due to Cooldown, in which case performing Attachment L.

RCPs WILL be tripped).

o Injection flow to the RCS.

CRITICAL TASKS o RCS Pressure NOT < 1576 PSIG.

Establish at least 200 GPM of feedwater flow to the o Operator Controlled Cooldown NOT Steam Generators before both Steam Generator Wide initiated.

Range Levels lower below 9% [20%] (Only applicable

Determine 11 SG is faulted.

if both AFW Pumps trip on low discharge pressure).

o 11 SG pressure decreasing in an

Stop feed flow to the faulted Steam Generator before uncontrolled manner.

the end of the scenario.

SS OR o 11 SG completely depressurized.

5. If contacted as Duty Chemist or Duty RP to check status EVENT 6

Transition to 1E-2.

of secondary radiation levels and/or SG activity levels, (cont) then inform the control room that both SG cation column RO Transition to 1FR-Z.1 may occur if an orange path in frisks are reading background and secondary radiation Containment Critical Safety Function has occurred.

levels are normal.

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 EXPECTED STUDENT RESPONSES POS

6. If contacted by the Control Room to report status of CAT

Verify Containment Isolation Valves are CLOSED.

1 Vent Zone openings, then inform the CR that all CAT 1

Verify containment spray actuated.

Vent Zone openings are closed.

Determine Containment Spray pumps are NOT

7. If Control Room personnel ask for status of Unit 2 Cooling running.

Water/Chilled Water lineup, then inform the Control Room

Manually start spray pumps.

that Unit 2 Cooling Water/Chilled Water valves are in their

Verify proper spray system alignment.

safeguards positions. SS

Verify FCUs running slow to the dome.

8. If Control Room personnel ask for status of Battery Room

Verify FCU cooling water MVs are OPEN.

Temperatures, then inform the Control Room that Battery

Check cooling water header pressure - both greater Room temperatures are 74°F.

than 65 psig.

Verify MSIVs and bypass valves are CLOSED.

RO /

Plant Response: LEAD

Isolate feed flow to 11 SG if not already done.

1. PRZR Pressure lowers rapidly.

Return to procedure and step in effect.

2. CTMT Pressure rises.

3. Annunciator 47022-0611, FIRE DETECTION PANEL 121 1E-2, FAULTED STEAM GENERATOR ISOLATION

- FIRE ALARM, alarms.

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.

SS 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 EXPECTED STUDENT RESPONSES POS

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 Booth Operator: The crew may restore Containment Cooling using 1FR-Z.1,

1. When the reactor is tripped, then verify the following is RESPONSE TO HIGH CONTAINMENT PRESSURE, due to an automatically inserted: orange or red path in the Containment Critical Safety Function.

AUTO Trigger 7, Loss of Containment Cooling.

LEAD 1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION

2. If contacted as an out-plant operator to open CFCU

Verify both trains of SI actuated:

bypass valves, then wait 4 minutes and enter: o Both RHR pumps or both SI pumps - RUNNING.

Trigger 17, CFCU Cooling Water Return Orifice * "SI NOT READY" lights - NOT LIT.

Bypass Valves OPEN, and inform the control room that * "SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

CFCU CL bypass valves are open. o Actuate and align components per Table 1.

"CONTAINMENT ISOLATION" lights - LIT FOR CRITICAL TASKS PLANT CONDITIONS.

Manually actuate containment cooling as necessary to

Check Category 1 Vent Zone Boundary.

prevent containment pressure from exceeding 46 psig.

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

Check Cooling Water Header Pressures - BOTH TABLE 1 GREATER THAN 65 PSIG.

Verify Plant Announcements Complete.

CS COMPONENT DESIRED

Check If Main Steamlines Are Isolated.

NUMBER POSITION

Determine MSIVs, Bypass Valves, and Containment 46018 11 CFCU SLOW Instrument Air Valves are already closed.

46019 13 CFCU SLOW

Verify SI Flow.

46039 MV-32144 CLOSE

Verify RHR Flow.

46144 MV-32159 CLOSE

Verify Containment Spray is actuated (if necessary).

46519 MV-32036 CLOSE o 11 & 12 CS pumps do NOT start automatically 46509 MV-32037 CLOSE o Manually start 11 & 12 CS pumps.

46336 12 DDCLWP MAN/AUTO MANUAL

Check RCP Cooling.

46053 12 DDCLWP START

Verify Local Actions Complete.

46537 22 DDCLWP MAN/AUTO MANUAL

Verify Generator Breakers - OPEN.

46523 22 DDCLWP START

Verify All Heater Drain Pumps - STOPPED.

NOTE: 12 and 14 CFCUs will fail to restart.

Check Turbine reheat and intercept valves CLOSED.

Open turbine drain valves.

EVENT 7

Verify Main Feedwater Alignment:

(cont) Plant Response: o Both main feedwater pumps - STOPPED.

LEAD

1. Containment Spray pumps do not start automatically. o Main and bypass FRVs - CLOSED.

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

Verify All Condensate Pumps - STOPPED.

3. 11 and 13 CFCU fail to automatically start.

Verify Steam Dump in "STM PRESS" Mode.

4. SI to Cooling Water signal fails to actuate.

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 EXPECTED STUDENT RESPONSES POS

5. Containment pressure rises and will exceed 46 psig o CFCU control switches - "SLOW".

without operator action. o CFCU dampers - ALIGNED TO DOME.

o Unit 1 cooling water/chilled water valves closed.

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

NOTIFICATION OF UNUSUAL EVENT - FU1 due to o CFCU cooling water supply and return valves -

potential loss of Containment fission product barrier due OPEN.

to Containment pressure greater than 23 psig with less o CFCU chilled water supply and return valves -

than one full train of depressurization equipment CLOSED.

operating.

Verify 11 Safeguards Screenhouse Ventilation lineup.

Verify Control Room Ventilation Alignment:

SITE AREA EMERGENCY - a RED path in RCS Integrity o Chillers and fans - RUNNING.

CSF may occur due to the rapid cooldown from the o Control room chiller suction/discharge tie closed -

faulted steam generator. If this occurs, then FS1 is met STATUS LIGHT LIT.

due to potential loss of RCS fission product barrier and

Verify Unit 2 Cooling/Chilled Water Alignment.

potential loss of Containment fission product barrier.

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 Date (Simulator Scenario Development Checklist.)

Validated by: Fred Collins 12/28/2015 Validation Lead Instructor Date (Simulator Scenario Validation Checklist.)

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

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 Safety loss of feedwater to the Steam Generators.

Significance: 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.

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.

Plant

Rods fail to automatically insert.

Conditions:

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.

Steam Generator levels lowering.

Cues:

Both Reactor Trip breakers closed.

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

o CS-46331.

Performance o CS-46450.

Indicator:

-OR-

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

Control rods at bottom of core.

Feedback:

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.

Operation of the ECCS injection pumps without Component Cooling Safety Water could lead to pump failure or damage. This would result in a Significance:

degraded emergency core cooling system (ECCS) capacity.

Safety Injection.

Plant

Both Component Cooling Water Pumps are NOT running.

Conditions:

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

Indication that Safety Injection actuated.

SI ACTIVE lights are NOT lit for both CC Pumps.

Cues:

Component Cooling Water Discharge pressure reads zero.

Component Cooling Water Low Flow alarms to ECCS Pumps.

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

Performance

CS-46036, 11 CC WTR PUMP.

Indicator:

CS-46037, 12 CC WTR PUMP.

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

Feedback:

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 EXPECTED STUDENT RESPONSES POS

1. SIMULATOR PRE-BRIEF:

a. The Simulator Pre-Brief is conducted prior to the crew entering the simulator. Review the following with the off-going operator:

2. COMPLETE TURNOVER: CREW

Unit 1 LPEO / PEO Turnover Log

a. UNIT 1 LPEO / PEO TURNOVER LOG.

PRA printout

b. PRA Printout.

Walk-down the control boards and ask questions as

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

EVENT 1 Booth Operator: 1C14, COMPONENT COOLING SYSTEM - UNIT 1

3. After the crew has assumed the duty, they will swap LEAD

Notify the Aux Building Operator to check the following Component Cooling Water Pumps per 1C14. on 12 CC Pump.

Bearing oil level in sight glass.

4. When contacted as the out-plant operator to perform

No seal leakage.

step 5.2.1 of 1C14, then acknowledge order. Wait

Start 12 CC Pump using CS-46037.

approximately 1 minute and report bearing oil level is

Verify MV-32146, 12 CC HX CLG WTR INLT, is normal and there is no seal leakage. OPEN.

5. If contacted as an out-plant operator to perform a sweep

Direct an out-plant operator to perform step 5.2.4 of of Bus 16 Room, then wait approximately 1 minute and 1C14.

report that Bus 16 Room is clear of personnel.

Operate both CC pumps for at least ten minutes.

6. When contacted as the out-plant operator to perform

Determine single pump operation is desired and go to step 5.2.4 of 1C14, then acknowledge order. Wait section 5.3.

approximately 2 minutes, then report step 5.2.4 is

Determine B Train RHR is NOT being used for completed SAT.

shutdown cooling.

7. After the crew indicates they will wait 10 minutes prior to stopping 11 CC Pump, then inform the crew TIME

Place and hold CS-46036, 11 CC WTR PUMP, in COMPRESSION is being used and that 10 minutes has STOP until CC system pressure stabilizes above 75 elapsed. psig.

Plant Response:

1. 12 CC Heat Exchanger flowrate rises.

2. 11 CC Heat Exchanger flowrate lowers.

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

SEQ SEQUENCE OF EVENTS / INSTRUCTOR NOTES CREW EXPECTED STUDENT RESPONSES POS EVENT 2 Booth Operator: C47012-0108, PRZR LO PRESS SI CHANNEL ALERT

1. After the crew has assumed the duty and/or at the LEAD/

Check PRZR pressure.

discretion of the lead evaluator, then enter: RO

Verify all heaters on.

Trigger 2, PRZR Pressure Blue Channel fails LOW.

Verify sprays closed.

If necessary, then control pressure in manual.

2. If contacted as I&C to trip bistables, inform the crew two SS

Refer to 1C51.3.

I&C Technicians will be available in 45 minutes.

3. If contacted as the Operations Management, 1C51.3, PRESSURIZER PRESSURE 1P-431 - LOW acknowledge the report of the failure, and agree to make

If the Blue channel is selected on the PRZR Pressure other SWI O-28 notifications to the NRC, Duty Station LEAD Control Selector Switch, then:

Manager, etc. as asked. o Place PRZR Press Cont in MANUAL and stabilize

4. If contacted as the FIN Team Supervisor, inform the pressure.

crew that you will write a work order and assign an I&C o Select 2-1 (WHITE/RED) on channel sel sw Supervisor to investigate. o When pressure returned to normal with no deviation from setpoint, then return pressure Plant Response: control to automatic.

1. PRZR spray valves close.

Verify PRZR Press Rec. not selected to Blue channel.

2. PRZR Pressure rises.

Enter TS LCO 3.3.1 Condition A

3. Tavg rises. SS o Reference Table 3.3.1-1 immediately.

4. The following annunciators are received:

Enter TS LCO 3.3.1 Condition E

a. 47012-0108, PRZR LO PRESS SI CHANNEL o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR ALERT.

o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

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

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 Booth Operator: 1C1.4, UNIT 1 POWER OPERATION

1. After the crew has restored pressurizer pressure control

Place CS-46280, ROD BANK SELECTOR, in to automatic and/or at the discretion of the lead evaluator, RO/SS MANUAL.

then:

Using the On Line Control screen:

a. As the Shift Manager, direct the Unit 1 SS to raise o Select LOAD or FSP.

Unit 1 Reactor Power to 40%. o Select 0.5% demand rate.

2. If contacted as the duty chemist, acknowledge Unit 1

Verify the VPL control is not Red.

power will be raised from 30% to 40%.

Raise the VPL to 101% using the Valve Limiter

3. If contacted as Unit 2 Control Room Operators to monitor pop-up screen.

Unit 1 Heater Drain Tank alarms (Panel F), then

Set the Target setting to the desired Load using On acknowledge request and inform Unit 1 Operators that an Line Control screen Target increase/decrease extra operator will monitor Panel F. controls.

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

Plant Response:

When Tave shows an increase, then select the Go

1. Reactor Power rises. control using the On Line Control screen.

2. Generator Load rises.

Adjust the alternate dilution rate or perform alternate

3. RCS Tavg rises.

dilutions per 1C12.5 to maintain Tave and Tref with the desired +/-1.5°F band.

NOTE 1C12.5, UNIT 1 BORON CONCENTRATION CONTROL It is NOT intended to wait for the plant to reach 40% RO/SS power prior to proceeding to the next event. Once the

Verify the RMU integrator is reset.

Lead Evaluator is satisfied with the reactivity

Set 1YIC-111, RX MU WTR TO BLENDER BATCH manipulation, proceed to Event 4. 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.

EVENT 3

When the desired quantity of makeup has been (cont) added, then verify automatic makeup stopped as RO/SS 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 EXPECTED STUDENT RESPONSES POS

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 EXPECTED STUDENT RESPONSES POS EVENT 4 Booth Operator: 1C20.7 AOP2, BUS 15 LOAD SEQUENCER OUT OF

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

Place CS-46932, BUS 15 VOLTAGE RESTORATION Trigger 4, Failure of Bus 15 Load Sequencer. SEL SW, in MAN.

Place CS-46935, D1 DIESEL GENERATOR, in

2. If contacted as an out-plant operator to investigate Bus PULLOUT.

15 Load Sequencer, then wait approximately 1 minute

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

a. Blocking Relay Switch is in NORMAL.

Log D1 DSL GEN inoperable.

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

Check Unit 2 sequencers operable per SP 2094/2095.

c. Unable to identify cause of the problem.

Log Bus 15 Load Sequencer inoperable.

3. When the crew starts to perform SP 2094/2095 or asks

Enter TS LCO 3.3.4 Condition C.

Unit 2 to perform SP 2094/2095, then inform the crew

Enter TS LCO 3.8.1 Condition B.

that Unit 2 personnel will perform SP 2094 and SP 2095

Log Bus 15 inoperable.

to verify Unit 2 load sequencers are operable.

4. When the crew starts to perform SP 1118 or asks for an

Enter TS LCO 3.8.9 Condition A.

extra operator to perform SP 1118, then inform the crew

Perform the applicable portions of SP 1118, Verifying TIME COMPRESSION is used and SP 1118 is completed Paths from the grid to Unit 1 buses.

SAT.

Perform SP 1095, Bus 16 Load Sequencer Test to

5. When the crew starts to perform SP 1095 or asks for an verify Bus 16 load sequencer is operable.

extra operator to perform SP 1095, then inform the crew

Verify Bus 15 is powered from 1RY and Bus 16 is TIME COMPRESSION is used and SP 1095 is completed powered from CT11.

SAT.

Verify grid voltage limits are appropriate.

6. When the crew starts to verify grid voltage alarm limits or LEAD

Align for block loading.

asks for an extra operator to verify grid voltage alarm o 11 and 13 CFCUs in SLOW.

limits, then inform the crew TIME COMPRESSION is o 121 and 123 Waste Gas Compressors in Pullout.

used and voltage alarm limits have been verified. o 121 Air Compressor in Pullout.

o Verify 121 Control Room Chiller and Fan running.

Plant Response: o Start 121 Auxiliary Building Special Ventilation.

1. Annunciator 47024-1001, BUS 15 SEQUENCER NOT IN o On D1 Aux Panel, Place CS-55401, D1 AIR COMP SERVICE, alarms. CONTROL SW, in OFF.

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

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 EXPECTED STUDENT RESPONSES POS EVENT 5 Booth Operator: 1E-0, REACTOR TRIP OR SAFETY INJECTION

1. After the crew has placed D1 in pullout and/or at the LEAD /

Manually trip the reactor.

discretion of the Lead Evaluator, then enter: RO

Verify reactor tripped.

Trigger 5, Loss of Main Feedwater. o Reactor Trip Breakers are OPEN.

o SUR is NEGATIVE.

2. Upon hearing the announcement of Reactor Trip, or when o RPI indicate ZERO.

called as the Turbine Building Operator to isolate the Unit o Rod at Bottom lights are LIT.

1 MSRs per Attachment J, then:

Verify the Main Turbine tripped.

a. Open and run schedule file E-0_Att-J.sch located in SS o Left and right Stop Valves are CLOSED.

X:\\Trex_PI\Lightning\Schedule\EOPs.

Verify both Safeguards buses energized.

b. When the isolation is complete, inform the crew the

Direct an operator to perform 1C20.5 AOP1.

MSRs are isolated. RO /

Determine SI is NOT actuated and NOT required.

SS

Go to 1ES-0.1.

Plant Response:

1. Annunciator 47010-0101, 11 FW PUMP LOCKOUT. 1ES-0.1, REACTOR TRIP RECOVERY

2. Main Turbine automatically trips.

Announce Unit 1 Reactor Trip.

3. Rapidly lowering levels in both Steam Generators.

Transfer Steam Dump to Pressure Mode.

4. The reactor will fail to automatically trip.

Check RCS temperatures.

CRITICAL TASK

Check Cooling Water Header Pressures greater than Manually trip the reactor before both Steam Generator 75 psig.

Wide Range levels lower below 9%.

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

Check FW status.

EMERGENCY PLAN CLASSIFICATION

Verify all control rods inserted.

ALERT - SA2.1 due to the reactor failing to automatically

Check PRZR level and PRZR pressure control.

trip after the turbine automatically tripped on loss of 11

Check SG levels.

Main Feed Pump and the crew successfully manually tripping the reactor.

Page 13 of 17 2016 ILT NRC SIMULATOR EVALUATION #3 EVENT 6 Booth Operator: 1ES-0.1, REACTOR TRIP RECOVERY INFO PAGE

1. After the crew has transitioned to 1ES-0.1 and/or at the RO /

Actuate SI and go to 1E-0 if EITHER condition listed discretion of the Lead Evaluator, then enter: SS below occurs:

Trigger 6, Large Break LOCA. o RCS subcooling - LESS THAN 20F.

o PRZR level - CANNOT BE MAINTAINED

2. Upon hearing the announcement of Safety Injection, or GREATER THAN 5%.

when called as the Turbine Building Operator to secure the Turbine Building Roof Exhausters, wait 2 minutes and 1E-0, REACTOR TRIP OR SAFETY INJECTION report the Turbine Building Roof Exhausters are all RO/

Verify reactor tripped.

secured. LEAD o Reactor Trip Breakers are OPEN.

3. If Control Room personnel ask if Unit 2 personnel are o SUR is NEGATIVE.

available to perform Attachment L, then inform the o RPI indicate ZERO.

Control Room that Unit 2 personnel are NOT available for o Rod at Bottom lights are LIT.

performing Attachment L.

Verify the Main Turbine tripped.

o Left and right Stop Valves are CLOSED.

Plant Response:

Verify both Safeguards buses energized.

1. RCS pressure lowers rapidly.

Manually actuate or determine SI has actuated.

2. Pressurizer level lowers rapidly. o Either SG pressure < 530 psig.

3. Containment Pressure rises. o PRZR pressure < 1830 psig.

4. The reactor automatically trips. o Containment pressure > 3.5 psig.

5. Safety Injection fails to automatically actuate.

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

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

Check AFW Status restoration. o Total AFW flow >200 GPM.

o AFWP discharge pressure >1000 PSIG.

EMERGENCY PLAN CLASSIFICATION o Maintain SG WR levels 50-59%.

ALERT - FA1 due loss of RCS fission product barrier SS

Check RCS Average Temperatures trending to 547°F.

due to RCS leak rate greater than available makeup.

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

Check PRZR PORVs and Spray valves closed.

RO

Stop RCPs due to trip criteria being met.

SS o Injection flow to the RCS.

o RCS Pressure < 1250 PSIG [1576 PSIG].

EVENT 6 Booth Operator: o Operator Controlled Cooldown NOT (cont)

4. If Control Room personnel ask if Unit 2 personnel are initiated.

available to secure Diesel Generators and/or Safeguards RO /

Determine SGs are NOT faulted.

Cooling Water Pumps, then inform the Control Room that SS 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 EXPECTED STUDENT RESPONSES POS Unit 2 personnel WILL secure the Diesel Generators o No SG completely depressurized.

and/or Safeguards Cooling Water Pumps.

Determine SG Tubes are NOT ruptured.

5. When called as the Auxiliary Building Operator to open o Condenser air ejector radiation normal.

RD-4-6 and 2RD-4-2, wait 2 minutes and report these o SGB radiation normal.

valves are open. 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 EXPECTED STUDENT RESPONSES POS

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 Booth Operator: 1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION

1. If contacted by the Control Room to report status of CAT LEAD

Verify Safeguards Component Alignment:

1 Vent Zone openings, then inform the CR that all CAT 1

Verify both trains of SI actuated:

Vent Zone openings are closed. o Both RHR pumps or both SI pumps - RUNNING.

2. If Control Room personnel ask for status of Unit 2 Cooling * "SI NOT READY" lights - NOT LIT.

Water/Chilled Water lineup, then inform the Control Room * "SI ACTIVE" lights - LIT FOR PLANT CONDITIONS.

that Unit 2 Cooling Water/Chilled Water valves are in o Manually start both CC Pumps.

there safeguards positions. * "CONTAINMENT ISOLATION" lights - LIT FOR

3. If Control Room personnel ask for status of Battery Room PLANT CONDITIONS.

Temperatures, then inform the Control Room that Battery

Check Category 1 Vent Zone Boundary.

Room temperatures are 74°F.

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

4. If Control Room personnel ask for status of Spent Fuel

Check Cooling Water Header Pressures - BOTH Cooling, then inform the Control Room that Spent Fueling GREATER THAN 65 PSIG.

level and temperature are normal.

Verify Plant Announcements Complete.

Check If Main Steamlines Are Isolated.

Plant Response:

Determine MSIVs, Bypass Valves, and Containment

1. 11 and 12 CC Pumps will fail to automatically start on SI Instrument Air Valves do NOT need to be closed.

signal or on low pressure.

Verify SI Flow.

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

Verify RHR Flow.

power to Bus 15.

Verify Containment Spray is actuated (if necessary).

3. Low CC pressure on both trains.

Check RCP Cooling.

Verify Local Actions Complete.

Verify Generator Breakers - OPEN.

CRITICAL TASK

Verify All Heater Drain Pumps - STOPPED.

Manually start at least one CC Pump before the end of

Check Turbine Valves:

the scenario. 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.

EVENT 7

Verify Unit 1 Cooling Water/Chilled Water Alignment:

(cont) LEAD 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 EXPECTED STUDENT RESPONSES POS 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 Date (Simulator Scenario Development Checklist.)

Validated by: Fred Collins 1/20/2016 Validation Lead Instructor Date (Simulator Scenario Validation Checklist.)

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 Manually actuate at least one train of SI-actuated safeguards equipment Critical Task:

before core exit temperatures exceed 700°F.

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

Reactor Trip

One of the following accidents:

o LOCA Plant o Unisolable Steam Line Break Conditions:

o SGTR

Both trains of Safety Injection fail to automatically actuate.

Safety Injection can be manually actuated from the Control Room.

Any of the following has occurred or is imminent:

o Pressurizer pressure less than 1830 psig.

Cues: 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.

Operating one of the following Safety Injection Actuation Switches:

o CS-46180.

o CS-46408.

Performance Indicator: -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 Transfer to cold leg recirculation and establish ECCS recirculation flow Critical Task:

before an ORANGE or RED path in Core Cooling CSF occurs.

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 Safety recirculation is not established, a loss of water inventory in the core will Significance:

occur and fuel temperatures will rise. This will result in damage to the fuel cladding barrier.

Large Break LOCA inside Containment.

RWST level is less than 33%.

Plant

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

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

SI Actuation.

RWST level less than 33%.

Cues:

Containment Level greater than 2 feet.

Sump B level greater than 75%.

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.

Performance

Close at least one SI Test Line to RWST Valve.

Indicator:

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 EXPECTED STUDENT RESPONSES POS

1. SIMULATOR PRE-BRIEF:

a. The Simulator Pre-Brief is conducted prior to the crew entering the simulator. Review the following with the off-going operator:

2. COMPLETE TURNOVER: CREW

Unit 1 LPEO / PEO Turnover Log

a. UNIT 1 LPEO / PEO TURNOVER LOG.

PRA printout

b. PRA Printout.

Walk-down the control boards and ask questions as

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

EVENT 1 Booth Operator: 1C1.2, UNIT 1 STARTUP PROCEDURE

1. After the crew has assumed the duty, they will raise

Raise reactor power to the point of adding heat using power to the Point of Adding Heat. RO/SS 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 EXPECTED STUDENT RESPONSES POS EVENT 2 Booth Operator: 1C28.1, AUXILIARY FEEDWATER SYSTEM UNIT 1

1. After the crew has raised power to the Point of Adding

CLOSE MV-32381, 12 MD AFWP TO 11 STM GEN, LEAD Heat, they will secure 12 MD AFW Pump per the using CS-46316.

OPERATIONAL PLANS FOR COMING SHIFT.

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

2. When directed as an out-plant operator to verify, 12 MD

Stop 12 MD AFW Pump using CS-46425.

AFW Pump has stopped, CV-31154 has closed, and

Direct an out-plant operator to verify locally:

Auxiliary lube oil pump is running, then wait o 12 MD AFW Pump has stopped.

approximately 2 minutes and report 12 MD AFW Pump is o CV-31154, 12 MD AFW PMP RECIRC/L-O CLG stopped, CV-31154 is closed, and Auxiliary lube oil pump CV, has CLOSED.

is running. o Auxiliary lube oil pump is running.

3. When directed as an out-plant operator to stop 12 MD

Direct an out-plant operator to locally stop 12 MD AFW AFW Pump Aux Lube Oil Pump, then wait approximately Pump Aux Lube Oil Pump when 12 MD AFW Pump 3 minutes and report Aux Lube Oil Pump has been stops rotating.

stopped.

OPEN MV-32381, 12 MD AFWP TO 11 STM GEN,

4. If contacted as the duty chemist, acknowledge 12 MD using CS-46316.

AFW Pump has been stopped.

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 EXPECTED STUDENT RESPONSES POS EVENT 3 Booth Operator: C47019-0404, 11 CFCU MOTOR STATOR HIGH TEMP

1. After 12 AFWP has been secured, and/or at the

Verify one of 11 CFCU discharge dampers is open.

LEAD discretion of the Lead Evaluator, then enter:

Verify proper cooling water alignment to 11 CFCU.

Trigger 3, 11 CFCU trips on overload.

If above steps did not reduce stator temperature then, o Stop 11 CFCU.

2. If contacted as the out-plant operator to check the o Verify CD-34075, 12 FCU NORM DISCH TO RX breaker of 11 CFCU, report that it is tripped open. VESSEL SUPPORT, OPEN.

3. If contacted as the Operations Management, o Verify 12 CFCU running in fast.

acknowledge the report of the failure, and agree to make other SWI O-28 notifications to the NRC, Duty Station C47021-0503, REACTOR VESSEL SUPPORT COOLING Manager, etc. LO FLOW

4. If contacted as the FIN Team Supervisor, inform the crew

Verify a Reactor Vessel Support Cooling Fan running.

that you will write a work order and assign an I&C LEAD

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

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

1. The following annunciators are received:

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

a. 47019-0404, 11 CFCU MOTOR STATOR HI TEMP. 12 CFCU)

b. 47021-0503, REACTOR VESSEL SUPPORT

Align 12 CFCU damper to the Support position.

COOLING LO FLOW.

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

c. 11 CFCU light indication turn off.

SS

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 EXPECTED STUDENT RESPONSES POS EVENT 4 Booth Operator: C47012-0408 PRZR HI/LO PRESS CHANNEL ALERT

1. When the crew has responded to the 11 CFCU trip,

Check pressure high or low.

and/or at the discretion of the Lead Evaluator, then enter:

If necessary then control pressure in manual.

Trigger 4, Blue Channel Pressurizer Pressure fails

Go to 1C51.3 high.

C51.3, PRESSURIZER PRESSURE 1P-431 HIGH NOTE: The Lead Evaluator may elect to have the BOP

Place Pressurizer Pressure Controller in MANUAL and operator sequestered during the initial phase of this stabilize pressure.

event to ensure

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

2. If contacted as I&C to trip bistables, inform the crew two

When pressure returned to normal with no deviation I&C Technicians will be available in 45 minutes. from setpoint, then return pressure control to

3. If contacted as the Operations Management, automatic.

acknowledge the report of the failure, and agree to make

Verify Pressurizer Pressure Recorder not selected to other SWI O-28 notifications to the NRC, Duty Station Blue channel.

Manager, etc. as asked.

Enter TS LCO 3.3.1 Condition A

4. If contacted as the FIN Team Supervisor, inform the crew o Reference Table 3.3.1-1 immediately.

that you will write a work order and assign an I&C

Enter TS LCO 3.3.1 Condition E Supervisor to investigate.

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 Plant Response:

1. Pressurizer Spray valves open.

Enter TS LCO 3.3.2 Condition A

2. Pressurizer pressure lowers rapidly. o Reference Table 3.3.2-1 immediately.

3. The following annunciators are received:

Enter TS LCO 3.3.2 Condition D

a. 47012-0508, PRZR HI/LO PRESS. o Place channel in trip in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR

b. 47012-0608, PRZR CONTROL HI PRESS OR o Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND BACKUP HTRS ON o Be in Mode 4 in 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months

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

Trip bistables.

a. Reactor Trip.

b. Safety Injection.

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 Booth Operator: 1E-0, REACTOR TRIP OR SAFETY INJECTION

1. When the crew has responded to the Pressurizer

Verify reactor tripped.

Pressure Instrument failure and/ or at the discretion of the RO/ o Reactor Trip Breakers are OPEN.

Lead Evaluator, then enter: LEAD o SUR is NEGATIVE.

Trigger 5, Large Break LOCA. o RPI indicate ZERO.

o Rod at Bottom lights are LIT.

2. Upon hearing the announcement of Safety Injection, or

Verify the Main Turbine tripped.

when called as the Turbine Building Operator to secure o Left and right Stop Valves are CLOSED.

the Turbine Building Roof Exhausters, wait approximately

Verify both Safeguards buses energized.

2 minutes and report the Turbine Building Roof

Determine SI is required.

Exhausters are all secured. o Check EITHER Pressurizer Pressure or

3. If there is NO examinee in the Unit 2 Lead position and Containment Pressure and determine that Control Room personnel ask if Unit 2 personnel are SI is required.

available to perform Attachment L, then inform the

Manually actuate SI.

Control Room that Unit 2 personnel are NOT available for SS

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

performing Attachment L.

Check AFW Status o Total AFW flow >200 GPM.

Plant Response: o AFWP discharge pressure >1000 PSIG.

1. RCS pressure and Pressurizer level lowers rapidly. o Maintain SG WR levels 50-59%.

2. Containment Pressure rises.

Check RCS Average Temperatures trending to 547°F.

3. Safety Injection fails to automatically actuate. RO o Cold leg temperature is used if RCPs have

4. Feedwater Components fail to automatically align.

been tripped.

SS

Check PRZR PORVs and Spray valves closed.

CRITICAL TASK Manually actuate at least one train of SI-actuated

Stop RCPs due to trip criteria being met.

safeguards equipment before a RED path in Core o Injection flow to the RCS.

Cooling CSF occurs. o RCS Pressure < 1250 PSIG [1576 PSIG].

o Operator Controlled Cooldown NOT EMERGENCY PLAN CLASSIFICATION initiated.

ALERT - FA1 due to a loss of RCS Fission Product

Determine SGs are NOT faulted.

Barrier caused by the LBLOCA. o No SG pressure decreasing in an uncontrolled manner.

o No SG completely depressurized.

Determine SG Tubes are NOT ruptured.

EVENT 5 o Condenser air ejector radiation normal.

Booth Operator: LEAD (cont) o SGB radiation normal.

1. If contacted by the Control Room to report status of CAT 1 Vent Zone openings, then inform the CR that all CAT 1 o Main Steam Line radiation normal.

Vent Zone openings are closed.

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

2. If Control Room personnel ask for status of Unit 2 Cooling

Determine RCS is NOT intact due to Containment Water/Chilled Water lineup, then inform the Control Room pressure rising.

that Unit 2 Cooling Water/Chilled Water valves are in their

Go to 1E-1.

safeguards positions.

3. If Control Room personnel ask for status of Battery Room NOTE: Expected to enter 1FR-P.1 as soon as Red or Orange Path in Integrity CSF is received.

Temperatures, then inform the Control Room that Battery Room temperatures are 74°F.

4. If Control Room personnel ask for status of Spent Fuel 1FR-P.1 RESPONSE TO IMMINENT PRESSURIZED Cooling, then inform the Control Room that Spent Fuel THERMAL SHOCK CONDITION Pool level and temperatures are normal.

Determine RCS pressure is greater than 550 psig.

Determine RHR flow is greater than 950 gpm.

Return to procedure and step in effect.

EVENT 5 LEAD 1E-0 ATTACHMENT L: SI ALIGNMENT VERIFICATION (cont)

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

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.

Booth Operator:

1. If Control Room personnel ask if Unit 2 personnel are EVENT 5 (cont) available to secure Diesel Generators and/or Safeguards RO /

Verify Main Feedwater Alignment:

Cooling Water Pumps, then inform the Control Room that SS o Determine both main feedwater pumps did NOT Unit 2 personnel WILL secure the Diesel Generators automatically stop.

and/or Safeguards Cooling Water Pumps. o Secure any running Main Feedwater Pumps.

2. When called as the Auxiliary Building Operator to open o Verify Main and bypass FRVs are CLOSED.

RD-4-6 and 2RD-4-2, wait approximately 2 minutes and

Determine Condensate Pumps did NOT automatically report these valves are open. stop.

3. When requested to perform Attachment K, then wait

Secure any running Condensate Pumps.

approximately 2 minutes and perform the following:

Verify Steam Dump in "STM PRESS" Mode.

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

Verify Unit 1 Cooling Water/Chilled Water Alignment:

b. When all items from Trigger 15 have been entered, o CFCU control switches - "SLOW".

then inform Control Room Attachment K is complete. 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 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.

SS

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.

CRITICAL TASK RO /

EVENT 5 Transfer to cold leg recirculation and establish ECCS LEAD /

(cont) 1E-1, LOSS OF REACTOR OR SECONDARY recirculation flow before an ORANGE or RED path in SS COOLANT Core Cooling CSF occurs.

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 EXPECTED STUDENT RESPONSES POS

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 EXPECTED STUDENT RESPONSES POS

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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