ML120480083

Initial Exam 2011-302 Final Simulator Scenarios

ML120480083
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Site:	Robinson
Issue date:	02/10/2012
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Mark Bates
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I Appendix D Scenario Outline Form ES-D-1 Facility: HB ROBINSON Scenario No.: 1 Op Test No.:

Examiners: Operators: SRO -

RO BOP Initial Conditions:

• 100% RTP EOL, 15697 MWD/MTU, 95 ppm Boron

• A MDAFW pump inoperable with the breaker racked out

. Currently thunderstorm watch is in effect for Darlington and Chesterfield counties Turnover:

• Maintain current power level Critical Tasks:

• Start SI Pump C to provide injection to the RCS

• Establish flow path to at least one S/G

• Restore Seal Cooling to the RCPs within 15 minutes or isolate seals Event Ma If. Event Type* Event L No. No. Description (C) RO, BOP, 1 SRO Loss of Instrument Bus #1 (TS) SRO (N) BOP Restore Normal Letdown (R)RO .

2 Heater Drain Pump A trips I Load Reduction (N) BOP, SRQ (I) BOP, SRO 3 SIG C LT-496 fails HIGH (TS) SRO (C) RO, SRO 4 (TS, TRM) SRO Seismic event causes RCS leakage.

5 (M) ALL Small Break LOCA.

6 Loss of SUT on Generator Lockout (C) RO SI Pump C fails to Auto-Start and SI Pump A trips (C) BOP AFW Pump discharge valves V2-14A, B, C and V2-16A, B, C fail to open on auto start of pumps (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-1 ILC-11-2 NRC SCENARIO I

SUMMARY

DESCRIPTION The crew will assume the watch with the plant at 100% steady state power. MDAFW Pump A is out of service for scheduled lube oil cooler replacement. The motor breaker has been racked out and the pump has been isolated and cleared for maintenance. Shift instructions are to maintain current reactor power.

On cue from the Chief Examiner, a loss of Instrument Bus #1 will occur due to the normal supply breaker on MCC-5 being inadvertently opened by cleaning personnel. The crew will perform the immediate actions for the loss of Instrument Bus #1 lAW AOP-024, Loss of Instrument Bus. The crew will verify that letdown is isolated and reduce charging flow to minimum while maintaining minimum RCP seal injection. Once the cause of the loss of Instrument Bus #1 is determined the bus will be re-energized. RCS Makeup will be restored along with various automatic controllers. Letdown will be placed back into service and pressurizer level will be restored to normal band. The SRO will identify that ITS LCO 3.8.7, Condition A, was in effect while the normal supply breaker to Instrument Bus #1 was open. This LCO requires that the AC Instrument Bus Power Source be restored to Operable status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Additionally, ITS LCO 3.8.9, Condition B, was in effect while Instrument Bus #1 was de-energized. This LCO requires that the AC instrument bus subsystem be restored to Operable status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. ITS LCO 3.4.9, Condition A may be entered if pressurizer level is allowed to rise above 63.3%. The LCO requires that the plant be in Mode 3 with reactor trip breakers open within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 4 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. ITS LCO 3.4.1, Condition A may be entered if pressurizer pressure is allowed to lower below 2205 psig. This LCO requires that pressurizer pressure be restored within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or be in Mode 2 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

On cue from the Chief Examiner,Iightning strike results in a trip of A Heater Drain Pump. The crew will perform the immediate actions for a Main Feedwater Malfunction lAW AOP-01 0, Main Feedwater I Condensate Malfunction. The crew will identify the need to reduce turbine load to achieve less than 85% power in accordance with Attachment 1 of AOP-010.

On cue from the Chief Examiner, C SIG LT-496 fails HIGH, affecting the automatic operation of Feedwater Regulating Valve FCV-498 for SIG C. The operator will have to take manual control of the FRV and restore the SIG to program level. The crew will perform the immediate actions for LT-496 failure lAW AOP-025, RTGB Instrument Failure, Section D. The failed S/G level transmitter will be removed from service lAW OWP-027, SGL-9. The SRO will implement ITS 3.3.1-1 Item 13 which requires 3 SIG Level channels with Condition E Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and ITS 3.3.8-1 Item 1 which requires 3 SIG Level channels with Condition C Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND Mode 4 in 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

On cue from the Chief Examiner, a seismic event will occur. APP-036-I5, Seismic Monitor, alarm will be received along with a call from the Load Dispatcher reporting a seismic event report from the US Geological Department. The crew will take actions lAW AOP-021, Seismic Disturbances. The seismic event will cause damage to the RCS piping inside containment that will result in RCS leakage rising to a rate of 1000 gpm over a 10 minute time period. The crew will take actions lAW AOP-016, Excessive Primary Plant Leakage, to address the RCS leakage.

The RCS leakage will also result in APP-036-D8, Process Monitor HI Rad, alarm due to high radiation levels on R-1 1. The crew will implement the actions of AOP-005, Radiation Monitoring AppendixD NUREG-1021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-i I

,, System. If dispatched, an operator will report that the DBE/SSE ALARM on Seismic Monitor A is illuminated The SRO will identify that the plant has exceeded the TRM 3 17 Seismic Shutdown limits of O.iOg horizontal acceleration and O.067g vertical acceleration and that the plant must be placed in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

AOP-016 will be unsuccessful in controlling PZR level and the crew will trip the reactor, enter PATH-i and initiate safety injection. One minute after the reactor trip a generator lockout will occur and the Startup Transformer will fail resulting in a loss of off-site power. Both E-buses will be energized by their respective EDGs. C SI Pump will fail to Auto-start and A SI Pump will trip while attempting to start. The operator must recognize this condition and manually start C SI pump. Also, AFW pump discharge valves V2-14A, B, C and V2-i6A, B, C fail to open on auto start of the AFW pumps. This condition must be recognized and action taken to establish AFW flow to at least one SIG. Also, after the loss of off-site power the A Battery Charger will fail to restart when power is restored to 480V Bus E-i. A modification was added during the last refueling outage that has the Battery Chargers auto-start upon restoration of power to the E bus. This failure must be recognized by the crew during the performance of PATH-i and an operator must be dispatched to manually start A Battery Charger.

Once in PATH-i, Foldout A will identify the need to enter AOP-018, RCP Malfunctions, due to meeting the Loss of RCP Seal Cooling Criteria. AOP-018 will direct the operators to establish thermal barrier cooling by starting one CCW pump and verifying proper valve alignment. The procedure will then direct the operator to start one charging pump and align valves as necessary to establish adequate seal injection flow.

PATH-i will be continued to the transition to EPP-8, Post LOCA Cooldown and Depressurization. Scenario may be terminated at the transition to EPP-8 or at the discretion of the Chief Examiner.

Appendix D NUREG-iO2i, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 ILC-I1-2 NRC SCENARIO I SIMULATOR SETUP ICISETU P:

• IC-801 SCN: 008_i 1_2_NRC_Exam_i

• A MDAFW Pump inoperable with the breaker racked out. Switch RED capped.

• Status board updated to reflect IC-21.

• Switchyard access is RESTRICTED.

PRE-LOADED EVENTS:

The following events should occur on the reactor trip:

Event 6: Loss of SUT on Generator Lockout A SI Pump trips C SI Pump fails to auto-start AFW Valves V2-14A,B,C and V2-16A,B,C fail to open on auto start of pumps A Battery Charger fails to Auto-Start upon restoring power to 480V Bus E-i EVENTSITRIGGERS INITIATED DURING THE SCENARIO:

Event 1: Loss of Instrument Bus #1 Event 2: A Heater Drain Pump trips

) Event 3 C S/G Level Transmitter LT-496 fails HIGH Event 4: Seismic Event causes RCS Leakage Event 5: Small Break LOCA EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

• AOP-024

• AOP-OIO

• AOP-025 Main Body and Section D

• OWP-027, Section SGL-9

• AOP-021

• AOP-016

• AOP-005

• PATH-I

• Foldout A

• AOP-018

• Foldout B

• EPP-8 Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 5 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position Applicants Actions or Behavior BOOTH OPERATOR: When directed, insert Event 1, Loss of Instrument Bus #1 EVENT INDICATIONS:

Rack #1 Nuclear Instruments Lost (N-31, N-35, N-41)

Bistable Status Panel B Extinguished FR-478 Extinguished AOP-024 LOSS OF INSTRUMENT BUS BOP Immediate Action Step Place The Main Turbine in Manual Immediate Action Step BOP Verify SIG(s) Maintained At Prociram Level Immediate Action Step RO Place Rods in M (Manual)

SRO Enters AOP-024 and verifies Immediate Actions.

RO Maintain Reactor Power 100%

Continuous Action Step Determine if RCS Makeup needs to be stopped:

Check Auto Makeup, Boration OR Dilution In Progress (NO) (Auto RO Makeup may or may not be in progress, but could occur.)

OR Check Instrument Bus 2 AND Instrument Bus 7 De-energized (NO)

RO Place the RCS Makeup System Switch to STOP.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # I Event # 1 Page 6 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position T Applicants Actions or Behavior Control PZR Heaters and Sprays to restore RCS Pressure to the desired control band.

RO (No control of PZR heaters and sprays until Instrument Bus is energized due to the controllers locked up.)

CREW Make PA Announcement For Procedure Entry Control Charging and Letdown Flow to Maintain PZR Level.

RO (Letdown cannot be restored until Instrument Bus is energized.)

RO Verify RCP Seal Injection Flow Between 8 GPM and 13 GPM.

Determine Failed Instrument Bus (IB) From Any Of The Following:

. Available indications OR BOP

• Table Below Instrument Bus Indication to Check 1 FR-478, A SIG Level Continuous Action Step BOP Check Emergency Busses E-1 AND E-2 - ENERGIZED FROM THE

_______ 4160V BUSSES (YES)

Continuous Action Step RO/BOP Check Affected Instrument Bus Energized (NO)

RO Check LCV-460A & B, LTDN LINE STOP CLOSED (YES)

RO Place The Selector Switch For LCV-460A & B In The Closed Position RO Verify only ONE Charging Pump running at minimum speed Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 7 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position I Applicants Actions or Behavior RO Check RCP Seal Injection Flow between 8 GPM and 13 GPM Adjust HCV-121, Charging Flow OR Throttle Seal Water Flow Control valves RO . CVC-297A

• CVC-297B

• CVC-297C IF the normal Seal Injection Range can NOT be maintained, THEN an expanded range of between 6 gpm and 20 gpm may be used.

Check Affected Instrument Bus ENERGIZED (NO)

Locally perform the applicable step below:

• lB-i through IB-4

• IF the cause is known AND NOT a fault, THEN attempt to reset BOP and close the open Instrument Bus normal supply breaker.

(YES)

• IF MCC-8 is supplying an Instrument Bus, THEN Go To Step

74. (NO)

• Transfer the affected Instrument Bus to the alternate (MCC-8) power supply. (If not placed back on normal supply breaker.)

Examiners Note: LCO 3.4.1 for PZR Pressure < 2205 psig.

Booth Operator Re-energize Instrument Bus I from Normal Power Supply SRO Stop All Radioactive Batch Releases Check Status Of Local Actions:

BOP a. Check Local Actions Of Step 19 RNO REQUIRED (YES)

b. Check Local Actions Of Step 19 RNO ATTEMPTED (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 8 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position Applicants Actions or Behavior Continuous Action Step BOP Check Affected Instrument Bus ENERGIZED (YES)

Restore Affected Controllers On The RTGB To AUTO Mode RO/BOP (All Controllers go to Auto EXCEPT FC-605 which has no instrument air alianed to it normally)

Restore RCS Makeup Control IN AUTO

. Place the RCS MAKEUP SYSTEM Switch in STOP

. Verify the RCS MAKEUP MODE Switch in AUTO

. Momentarily place the RCS MAKEUP SYSTEM Switch to START RO (If Charging Pump Suction has been allowed to swap to the RWST, then APP-003-D5, BA FLOW DEV and APP-003-E5, MAKEUP WATER DEV, will be received and FCV-1 1 3B will automatically close.

Crew should identify that FCV-114B will need to be opened to allow for Makeup to be routed to the top of the VCT.)

Continuous Action Step Restore Rod Control To Automatic As Follows:

RO a. Check Power GREATER THAN 15% (YES)

b. Check Automatic Rod Control AVAILABLE (YES)

c. Check Tavg WITHIN -1.5 TO +1.5°F OF TREF t2tttf

d. Place the Rod Control Selector Switch to A (Autor)

BOP Check Emergency Busses E-1 AND E-2 ENERGIZED (YES)

Continuous Action Step BOP Check Emergency Busses E-1 AND E-2 - ENERGIZED FROM THEIR 4160V BUSSES (YES)

SRO Implement The EALs Examiners Note Possible ITS LCO 3.4.9 entry for PZR Level greater than 63.3%.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 1 Event # 1 Page 9 of 41 Event

Description:

Loss of Instrument Bus #1 Time - Position Applicants Actions or Behavior Continuous Action Step Check Status Of Turbine:

BOP

. Check Instrument Bus 4 ENERGIZED (YES)

. Place Turbine Controls in Automatic RO Check CCW Pumps More than one running (NO)

BOP Check RMS-1, RMS-2, RMS-3 AND RMS-4 ALL OPEN (YES)

Continuous Action Step -

BOP Check Affected Instrument Bus ENERGIZED (YES)

Check PZR Heater Status DEENERGIZED (YES)

RO (May have been energized earlier as directed to control heaters and spray.)

Reset PZR Heaters As Follows:

a. Place PZR HTR CONTROL GROUP Control Switch to OFF position AND return to ON position RO b. Place PZR HTR BACK-UP GROUP A Control Switch to OFF position AND return to AUTO OR ON position as desired

c. Place PZR HTR BACK-UP GROUP B Control Switch to OFF position AND return to AUTO OR ON position as desired RO Check Normal Letdown ISOLATED (YES)

Restore Normal Letdown Using Attachment 15, Restoration of Normal RO Letdown.

NOTE: The following are the steps to restore normal letdown using Attachment 15 of AOP-024.

RO BOP Normal charging flow through the Regenerative Heat Exchanger is in service.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 10 of 41 Event

Description:

Loss of Instrument Bus #1 Time j Position Applicants Actions or Behavior RO/BOP A Phase A Containment Isolation signal is NOT present.

RO I BOP The Residual Heat Removal System is NOT in service.

VERIFY the following valves are CLOSED:

. CVC-204A, LETDOWN LINE ISO

. CVC-204B, LETDOWN LINE ISO RO/BOP

• LCV-460A, LTDN LINE STOP

• LCV-460B, LTDN LINE STOP

. CVC-200A, LETDOWN ORIFICE ISOLATION

. CVC-200B, LETDOWN ORIFICE ISOLATION

. CVC-200C, LETDOWN ORIFICE ISOLATION ROIBOP VERIFY FULL OPEN HIC-121, CHARGING FLOW (CR 95-01752)

ROIBOP Check Pressurizer level is greater than OR equal to program level.

(YES)

RO/BOP IF desired, THEN PLACE TCV-143, VCT/DEMIN. DIVERSION, in the VCT position.

RO/BOP PLACE PC-145, PRESSURE, in MANUAL.

RO/BOP SET PC-145 to throttle PCV-145 to 45% to 55% open to ensure the Letdown line is NOT overpressurized.

RO/BOP OPEN CVC-204A, LETDOWN LINE ISO.

RO / BOP OPEN CVC-204B, LETDOWN LINE ISO.

PERFORM the following:

I

. OPEN LCV-460A&B by placing switch CVC-460A&B LTDN LINE STOPto OPEN.

.__PLACE_LTDN_LINE_STOP_CVC-460 A&B_switch_to AUTO.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 11 of 41 Event

Description:

Loss of Instrument Bus #1 Time I Position I Anolicants Actions or Behavior PLACE TC-144, NON-REGEN HX OUTLET TEMP, in MANUAL AND RO/BOP adjust as necessary to ensure Letdown temperature does NOT increase above 127°F when letdown is reestablished.

While MAINTAINING Charging Pump discharge pressure as indicated RD I BOP on RTGB instrument P1-121 LESS THAN 2500 psig, ADJUST charging pump speed to the expected letdown flow to be established in the next step.

RO/BOP OPEN one LTDN ORIFICE valve:

CVC-200A, CVC-200B or CVC-200C PLACE PC-145 in AUTO AND CHECK letdown pressure as indicated RO/BOP on P1-145, LOW PRESS LTDN PRESS, is being maintained between 300 psig and 320 psig.

RD I BOP PLACE TC-144, NON-REGEN HX OUTLET TEMP, in AUTO.

RD I BOP IF TCV-143 was selected to the VCT, THEN Position TCV-143 as directed by the CRSISM.

IF Charging flow is changed, THEN establish RCP Seal Injection Flow between 8 GPM and 13 GPM by throttling the following:

RD I BOP

• CVC-297A, RCP A SEAL WATER FLOW CONTROL VALVE

• CVC-297B, RCP B SEAL WATER FLOW CONTROL VALVE

• __CVC-297C,_RCP_C_SEAL WATER_FLOW CONTROL VALVE Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No: 1 Scenario # 1 Event # 1 Page 12 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position Applicants Actions or Behavior IF increased letdown flow is desired, THEN place additional letdown orifices in service as follows:

. Verify HIC-121, Charging Flow is Full Open.

. Verify Charging Pump discharge pressure as indicated on RTGB instrument P1-121 less than 2500 psig.

. IF required, THEN start the second Charging Pump on MINIMUM SPEED.

. IF required, THEN while maintaining Charging Pump discharge pressure as indicated on RTGB instrument P1-121 LESS THAN 2500 psig, ADJUST charging pump speed to meet flow RO / BOP requirement.

. Place PC-145, PRESSURE, in MANUAL.

. Slowly Throttle Open PC-i 45 to achieve 180-200 psig on P1-145 to ensure the Letdown Line is NOT overpressurized.

. OPEN one additional LTDN ORIFICE valve.

. Place PC-145 in AUTO and Check letdown pressure as indicated on P1-145, LOW PRESS LTDN PRESS, is being maintained between 300 psig and 320 psig.

. Verify Seal Injection Flow between 8 GPM and 13 GPM by throttling the following: CVC-297A, B, C.

NOTE: Decision on additional letdown flow may be dependent on PZR Level. PZR Level at> 63.3% is ITS LCO 3.4.9, Condition A.

RO BOP Notify RC that letdown flow has been restored and the affected areas should be monitored for changing radiological conditions.

BOP Check All Radiation Monitor Alarms EXTINGUISHED (YES)

Check R-11 OR R-12 IN SERVICE (YES)

BOP RMS-1 2,3,4OPEN (YES) AND R-1 1 and R-12 Vacuum Pump Operating (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-.D-2 Op Test No.: 1 Scenario # I Event # 1 Page 13 of 41 Event

Description:

Loss of Instrument Bus #1 Time Position Aoolicants Actions or Behavior BOP Check R-20 IN SERVICE (YES)

BOP Check R-21 IN SERVICE (YES)

Check Control Room Ventilation ALIGNED FOR PRESSURIZATION BOP MODE (NO)

• Go To Step 43.

RD Check PZR PRV Safety Acoustic Monitor Lights ILLUMINATED -

(YES)

Locally Reset PZR Safety Acoustic Monitors At INSTRUMENT CABINET A In The Computer Room By Performing The Following:

RD . Depress RESET RC-551A Pushbutton.

. Depress RESET RC-551 B Pushbutton.

. Depress RESET RC-551C Pushbutton.

Booth Operator Reset PZR Safety Valve Acoustic Monitors when requested.

NOTE: The crew may choose to unsaturate PZR Pressure Controller PC-444J Continuous Action Step Check Instrument Busses 1 2, 3, AND 4 ENERGIZED FROM THEIR NORMAL SOURCE (As Indicated Below):

BOP

• lB-I: MCC-5 (Via E-1) (YES)

• IB-2: INVERTER A

• lB-3: INVERTERB

• IB-4: MCC-6 Check Status of EDGs START SIGNAL RECEIVED (NO)

BOP

• Observe the NOTE prior to Step 65 and Go To Step 65.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 1 Page 14 of 41 Event

Description:

Loss of Instrument Bus #1 Time N Position N Applicants Actions or Behavior BOP Check ALL Safety Related Electrical Buses ENERGIZED (YES)

Check Technical Specifications For Applicable LCOs

• ITS LCO 3.8.1, AC Sources Operating (None)

• ITS 3.8.7, Condition A, One AC Instrument Bus power source inoperable Restore AC Instrument Bus Power Source to SRO operable status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

• ITS 3.8.9 Condition B, One AC instrument bus subsystem inoperable Restore AC instrument bus subsystem to operable status within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Check AnntinciatorAPP-005-A3, PR DROP ROD ILLUMINATED RO -

(YES)

Reset Dropped Rod Alarm By Momentarily Placing DROPPED ROD RO MODE Selector Switch For The Affected Power Range Drawer To RESET Position and then back to NORMAL (N-41 Only)

BOP Check APP-006-F5, Steam Dump Armed Illuminated (NO)

RO Check APP-005-F5, AMSAC TROUB/BYP- Illuminated (YES)

Reset AMSAC TROUB/BYP Alarm by depressing the System Reset RO Pushbutton on AMSAC Front Panel. (Key 52 is required.)

Booth Operator Reset AMSAC Trouble Alarm when requested.

SRO Return to Procedure and Step in Effect.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 15 of 41 Event

Description:

Heater Drain Pump A Trips I Load Reduction Time 1 Position JL Applicants Actions or Behavior BOOTH OPERATOR: When directed, insert Event 2, Heater Drain Pump A Trip EVENT INDICATIONS:

APP-007-A5 HDT PMP A Motor OVLDITRIP APP-007-B6 HOT HIILO LVL Heater Drain Pump A GREEN off indication ILLUMINATED AOP-O1O MAIN FEEDWATERICONDENSATE MALFUNCTION Immediate Action Step Check Feedwater Regulating Valves OPERATING PROPERLY BOP (MANUAL OR AUTO): (YES)

. FCV-478

. FCV-488

• FCV-498 Continuous Action Step Check Reactor Trip Setpoint BEING APPROACHED (NO)

BOP

• IF a Reactor Trip Setpoint is approached, THEN trip the Reactor and Go to PATH-i.

. Go to Step 4.

CREW Make PA Announcement For Procedure Entry Go To The Appropriate Step from The Table Below:

BOP

• Heater Drain Pump Trip Step 15 Reduce Turbine Load At 1%/MIN To 5%/MIN Using Attachment I To Achieve Reactor Power Less Than The Target Power Per The Followinq Table:

PUMPS RUNNING Target Power SRO Main FWP Cond I Htr Drn Percent 2 2 1 85%

(OP-301, Section 8.2.8 Quick Boration Checklist included at end of Event 2 if the crew uses Boron to reduce power)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 16 of 41 Event

Description:

Heater Drain Pump A Trips I Load Reduction Time Position I Aoplicants Actions or Behavior BOP Check Main FW Pumps TWO PUMPS RUNNING (YES)

Continuous Action Step Check HCV-1459, LP HEATERS BYP OPEN (NO)

Perform the following:

a. Monitor Feed Water Pump suction pressure (Local Indication)

BOP

• P1-1433 A FW PUMP SUCTION PRESSURE

. P1-1434 B FW PUMP SUCTION PRESSURE

b. IF pressures lower to less than the applicable setpoint, THEN verify OPEN HCV-1459.

• Any HDP Running 300 psig -

• No HDPs Running 350 psig (NO)

Check APP-007-B6, HDT HI/LO LVL EXTINGUISHED (NO)

Perform the following:

a. Dispatch an operator to check operation of HDT Level Control Valves BOP

• LCV-1530A, HDT LEVEL CONTROL VALVE

• LCV-1530B, HEATER DRAIN PUMPS SUCTION DUMP TO CONDENSER

b. IF either HDT level Control Valve is failed open, THEN contact I&C to initiate relairs.

Continuous Action Step BOP Check HCV-1459, LP HEATERS BYP CLOSED (YES)

BOP Check S/G Level AT OR TRENDING TO PROGRAM (YES)

RO Check Tavg AT OR TRENDING TO Tref (YES)

Contact Maintenance To Troubleshoot And Correct The Feedwater CREW Problem SRO Implement the EALs Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 17 of 41 Event

Description:

Heater Drain Pump A Trips / Load Reduction Time Position Aoolicants Actions or Behavior Check current loading for the following pumps LESS THAN -

MAXIMUM (YES)

BOP

• Main Feedwater Pump 0.715 KAMPS -

. Condensate Pumps 370 AMPS

. Heater Drain Pumps 90 AMPS BOOTH OPERATOR: Report the following AMPS as the current readings.

. Main Feedwater Pump 560 AMPS

. Condensate Pumps 310 AMPS

. Heater Drain Pump 75 AMPS Continuous Action Step Determine Iodine Sampling Requirements As Follows: (NO)

SRO a. Check Power Change GREATER THAN 15% IN ONE HOUR

. GoToStep44

. IF YES, then implement SR 3.4.16.2 Continuous Action Step RO Check APP-005-B5, ROD BANKS AIBIC/D LO LIMIT EXTINGUISHED (YES)

Monitor Axial Flux Difference To Ensure Compliance With ITS 3.2.3 RO (YES)

C REW Notify Load Dispatcher Of The Units Load Capability SRO Return To Procedure And Step In Effect Power Reduction Required by A Heater Drain Pump Trip AOP-O1O Attachment 1, Turbine Load Reduction BOP Check Turbine Control Mode AUTOMATIC (YES)

BOP Depress the IMP IN Pushbutton BOP Set The Desired Load In The SETTER Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 18 of 41 Event

Description:

Heater Drain Pump A Trips! Load Reduction Time Position Applicants Actions or Behavior BOP Set The Desired Load Rate Depress The GO Pushbutton BOP END- AOP-01O Attachment I IF a Power Limit Warning is received, reduce power by lowering the BOP turbine governor valve limiter.

NOTE: OP-301, Section 8.2.8 Quick Boration Checklist (shaded area) is included in the following steps, but may be used following the commencement of the plant down power.

Expect about 55 60 gallons of Boric Acid to be added DETERMINE the amount of Boric Acid to add to the RCS and RO OBTAIN an indepçndent check of the volume required OBTAIN permission from the CRS OR the SM to add the amount of RO boric acid previously determined.

PLACE the RCS MAKEUP MODE selector switch in the BORATE RO position.

RO SET YIC-113, BORIC ACID TOTALIZER to the desired quantity.

IF desired, THEN PLACE FCV-113A, BORIC ACID FLOW, in MAN RO AND manually ADJUST controller FCV-1 13A, BORIC ACID FLOW, using the UP and DOWN pushbuttons.

Momentarily PLACE the RCS MAKEUP SYSTEM switch to the RO START position.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 19 of 41 Event

Description:

Heater Drain Pump A Trips / Load Reduction Time N Position Applicants Actions or Behavior IF any of the below conditions occur, THEN momentarily place the RCS MAKEUP SYSTEM switch in the STOP position:

RO . Rod Motion is blocked OR is in the wrong direction

• TAVG goes up

. Boric Acid addition exceeds the desired value WHEN the desired amount of Boric Acid has been added to the RCS, THEN verify the following:

. FCV-1 13A, BORIC ACID FLOW, closes.

RO

. FCV-1 1 3B, BLENDED MU TO CHG SUCT, closes.

. IF in Auto, THEN the operating Boric Acid Pump stops.

. The RCS MAKEUP SYSTEM is OFF.

IF desired, THEN FLUSH the Boric Acid flow as follows:

. PLACE the RCS MAKEUP MODE selector switch in the ALT DILUTE position.

. SET YIC-1 14, PRIMARY WTR TOTALIZER to 15-20 gallons.

. PLACE FCV-1 14B, BLENDED MU TO VCT to the CLOSE position.

. Momentarily PLACE the RCS MAKEUP SYSTEM switch to the START position.

. IF any of the below conditions occur, THEN momentarily place RO the RCS MAKEUP SYSTEM switch in the STOP position:

o Unanticipated Rod Motion o Primary Water addition reaches the desired value

. WHEN the desired amount of Primary Water has been added to the RCS, THEN verify the following:

o FCV-114A, PWTO BLENDER, closes.

o FCV-113B, BLENDED MU TO CHG SUCT, closes.

o IF in Auto, THEN the operating Primary Water Pump stops.

o The RCS MAKEUP SYSTEM is OFF.

RETURN the RCS Makeup System to automatic as follows:

. VERIFY FCV-1 14A, PW TO BLENDER, is in AUTO.

. PLACE FCV-1 14B,BLENDED MU TO VCT to the AUTO position.

RO

. PLACE the RCS MAKEUP MODE switch in AUTO.

. VERIFY FCV-113A, BORIC ACID FLOW, is in AUTO.

. Momentarily PLACE the RCS MAKEUP SYSTEM switch in the START_position.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 2 Page 20 of 41 Event

Description:

Heater Drain Pump A Trips I Load Reduction 1 Time PoslUon I Applicants Actkns or Behavior RECORD, in AUTO LOG, as indicated by PRIMARY WATER RO TOTALIZER, YIC-114 AND Boric Acid TOTALIZER, YIC-113 the total amount of Primary Water AND Boric Acid added durinq the boration.

MONITOR parameters for the expected change in reactivity AND RO inform the CRS OR the SM the results of the boration.

(END OP-301 Section 8.2.8)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 3 Page 21 of 41 Event

Description:

SIG C LT-496 fails HIGH Time Posion ApIicants Actions or Behavior BOOTH OPERATOR: When directed, irntiate Event 3, SIG C LT-496 fails HIGH EVENT INDICATIONS:

APP-006-C2, S!G C STM> FW FLOW APP-006-C3, SIG C LVL 0EV APP-006-F2, SIG C NAR RANGE HI LEVEL FR-498, Pen 3 failing HIGH AOP-025 RTGB Instrument Failure Go To The Appropriate Section For The Failed Transmitter:

SRO SIG NARROW RANGE LEVEL SECTION D J Paqel4 Immediate Action Step BOP Place The Affected FRV In MAN

. FCV-498 (FRV C) (YES)

Immediate Action Step BOP Restore Affected SIG Level To Between 39% And 52%

RO Make PA Announcement For Procedure Entry Remove The Affected Level Channel From Service Using OWP-027:

BOP CHANNEL IOWP I LT-496 I SGL-9 OWP-027 SGL-9 Precaution:

. Refer to ITS Table 3.3.1-1 Item 13 for RPS OPERABILITY requirements in MODES 1 and 2.

BOP

• Refer to ITS Table 3.3.3-1 Item 13 for PAM OPERABILITY requirements in MODES 1, 2, and 3. (NONE)

• Refer to ITS Table 3.3.8-1 Item 1 for AFW instrumentation OPERABILITY requirements in MODES 1, 2, and 3.

. Ensure only one S/G C level channel is out of service at any one time.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 3 Page 22 of 41 Event

Description:

SIG C LT-496 fails HIGH r Time Position Applicants Actions or Behavior AMSAC PROCESSOR A LEVEL 3 NORMAL/BYPASS SWITCH BOP (AMSAC PANEL)

BOP AMSAC PROCESSOR B LEVEL 3 NORMAL/BYPASS SWITCH (AMSAC PANEL)

BISTABLE SWITCH BS 496-1 RACK #16 BOP

. Tripped BISTABLE LIGHT SG NO. 3 HI LEVEL LC496-1 BOP

. Illuminated BISTABLE SWITCH BS 496A-1 RACK #16 BOP

• Tripped BISTABLE LIGHT SG NO. 3 LO-LO LEVEL LC496A1 BOP

. Illuminated FCV-498 CONTROLLER BOP . Manual END OWP-027 SGL-9 AOP-025 SRO Go To Procedure Main Body, Step 2 SRO Implement The EALs The SRO will implement the following Tech. Specs.

ITS 3.3.1-1 Item 13 which requires 3 S/G Level channels with Condition E Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 3 in SRO 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ITS 3.3.8-1 Item I which requires 3 S/G Level channels with Condition C Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND Mode 4 in 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # I Event # 3 Page 23 of 41 Event

Description:

SIG C LT-496 fails HIGH Time Position Applicants Actions or Behavior Return To Procedure And Step In Effect SRO END AOP-025 Appendix D NUREG-1021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 24 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

lime I Pition I Applicants Actions or Behavior BOOTH OPERATOR: When directed, insert Event 4, Seismic event causes RCS leakage to rise to 1000 qm over 10 minutes.

EVENT INDICATIONS:

APP-036-15, Seismic Alarm Load Dispatcher reports a seismic event report from US Geological Department. No tremors felt in the control room.

RR-1 Warning for R-11 APP-036-D8, Process Monitor HI Rad (R-11)

RCS Pressure Lowering PZR Level Lowering Automatic Makeup Begins SRO Enters AOP-021 for Seismic Disturbances.

SRO Dispatch an Operator to the Seismic Monitors to check local alarms.

Crew Make PA Announcement Compare Current RTGB Indications with the Operating Logs to Detect re any abnormal trends.

Check Either Event Below Has Occurred SRO

• Noticeable Tremors or Vibrations (NO)

OR

• __Report_by_Outside_Agency_(YES)

Notify the Manager Operations of the following:

SRO

• A Seismic event has occurred.

• __Any_abnormal_plant_conditions_that_have_been_identified.

SRO Implement the EALs Implement Applicable Technical Specification LCOs.

SRO TRM 3.17 Seismic Shutdown Limits. Place plant in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

SRO Enters AOP-016 for Excessive Primary Plant Leakage Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 25 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position ApIicants Actions or Behavior Continuous Action Step Check RCS Pressure Greater than 1000 psig. (YES)

Check the following:

PZR Level Less than 10%

lowering in an uncontrolled manner (NO)

RO OR RCS Subcooling Less than 35°F (NO)

IF PZR Level can NOT be maintained greater than 10% Q Subcooling can NOT be maintained greater than 35°F, THEN trip the Reactor and Go to PATH-I.

Crew Make PA Announcement for Procedure Ejy Continuous Action Step Check VCT Level LESS THAN 12.5 INCHES (NO)

RO

• IF VCT level lowers to less than 12.5 inches, THEN perform Step 5.

Go To Step 6 Check Charging Pump Status LESS THAN TWO RUNNING (NO)

• GoToStepll.

RD NOTE: May have only one Charging Pump Running due to previous loss of Instrument Bus. Step below annotated with a@ is included if only one charging pump is running.

@Check Charging Pump Status NONE RUNNING (NO)

IF an additional Charging Pump is available, THEN perform the following:

RO

a. Start one additional Charging Pump.

b. Observe charging flow on FI-122A, CHARGING LINE FLOW.

c. GoTo Step 11.

Place running Charging Pump Speed Controllers in MAN AND adjust RO output to maximum Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 26 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position I ApIicants Actions or Behavior Check RCS Level LOWERING IN AN UNCONTROLLED MANNER RO -

(YES)

RO Check Any Letdown - IN SERVICE (YES)

Verify All Letdown Flowpaths Isolated As Follows:

. LCV-460A & B, LTDN LINE STOP Valves CLOSED -

. HIC-142, PURIFICATION FLOW Controller ADJUSTED TO -

RO 0%

. HIC-137, EXCESS LTDN FLOW Controller ADJUSTED TO -

0%

. CVC-387. EXCESS LTDN STOP CLOSED -

Check RCS Level LOWERING IN AN UNCONTROLLED MANNER RO -

(YES)

RO Check RCS Pressure GREATER THAN 1000 PSIG (YES)

RO Trip The Reactor AND Go To PATH-i Steps from AOP-005 Radiation Monitoring System Perform The Following:

a. Make PA Announcement For Procedure Entry

b. Use Non-Performed Attachment(s) Listed Below For Radiation Monitor(s) in Alarm:

BOP Radiation Channel Process Monitor Attachment Number R-1i &R12 PROCESS 12 MONITOR R-1 1/R-12 CV AIR AND PLANT VENT BOP Check R-11/R-12 Selector Switch SELECTED TO CV (YES)

BOP Check RCS Temperature GREATER THAN 200°F (YES)

BOP Check Channel R-1 i/R-12 Low Flow Alarm Illuminated (NO)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 27 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time - Position -

Applicants ActiorisorBehaor BOP Check EOP Network Procedures IMPLEMENTED (NO)

BOP Check Personnel IN CV (NO)

Check CONTAINMENT VENTILATION ISOLATION Valves BOP CLOSED (YES)

Place the following CV IODINE REMOVAL FAN Control Switches to PREPURGE Position:

BOP

. HVE-3

. HVE-4 BOP Request RC to perform a background radiation check at Radiation Monitors R-11 and R-12.

Determine if primary system leakage is occurring, as follows:

. Check RCS Level Unexplained Lowering Level (YES)

OR BOP . RCS Leak Locally Identified (NO)

OR

. VCT Auto Makeups Excessive (YES)

OR

. Charging Pump Speed Rising (YES)

BOP Go to AOP-016, Excessive Primary Plant Leakage, while continuing with this procedure.

Refer to Technical Specification 3.3.6 and ODCM Table 3.10-1, SRO Radioactive Gases BOP Go to the Main Body, Step 1 .b, of this procedure.

Return to Procedure And Step In Effect BOP (END AOP-005)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 28 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: No Action ReqLred. A malfunctions are pre-loaded for the reactor trip and SI Actuation.

J 1 START OF PATH-I ACTIONS PATH-I Actions RO Immediate Action Step Reactor tripped (YES)

Immediate Action Step BOP Turbine tripped (YES)

Immediate Action Step BOP El & E2 energized (YES)

Continuous Action Step BOP IF Dedicated Shutdown Bus is Deenergized THEN Place Dedicated Shutdown Diesel Generator In Service Using EPP-25.

BOOTH OPERATOR: Ensure the actions of AOP-018 to restore seal cooling to the RCPs have been completed prior to re-energizing the OS Bus. At a minimum wait at least 10 minutes from request prior to energizing the DS Bus.

Immediate Action Step RO SI initiated (YES SI was manually initiated due to entry into PATH-i from AOP-0i6)

SRO Open Foldout A Appendix D NUREG-l 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # I Event # 4 and 5 Page 29 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time 1 Position Applicants Actions or Behavior MSR ISOLATION CRITERIA

. IF ANY Purge OR Shutoff Valve does not indicate fully closed, THEN place the associated RTGB Switch to CLOSE.

. IF ANY Purge OR Shutoff Valve can ] be closed from the BOP RTGB AND RCS temperature is less than 540°F and lowering, THEN close the MSIVs AND MSIV BYPs.

. IF a loss of power prevents isolation of the MSRs, THEN close the MSIVs AND MSIV BYPs LOSS OF RCP SEAL COOLING CRITERIA IF both the conditions b&ow are met, THEN perform AOP-018, Reactor Coolant Pump Abnormal Conditions to restore RCP Seal Cooling

. APP-001-B2, LABYRINTH SEAL LOW AP ILLUMINATED RO (YES)

AND

. APP-001-D1, THERMAL BARRIER LO FLOW ILLUMINATED (YES)

(AOP-018 Actions are located followinq the PATH-I Actions)

BOOTH OPERATOR: Ensure the actions of AOP-OI8 to restore seal cooling to the RCPs have been completed prior to re-energizing the DS Bus. At a minimum wait at least 10 minutes from request prior to energizing the OS Bus.

RO Verify Phase A valves closed (YES)

BOP Verify FW isolation valves closed (YES)

BOP Verify both FW pumps tripped (YES)

Verify both MDAFW pumps running (NO)

BOP MDAFW Pump A Inoperable due to initial conditions.

BOP If Additional Feedwater is required, THEN Start SDAFW Pump Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 30 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time I Position 1 Applicants Actions or Behavior Verify two SI pumps running (NO)

Critical RO Manually Start C SI Pump Task A SI Pump trips while attempting to manually start.

CRITICAL TASK: Start C SI Pump to provide injection to the RCS.

RO Verify both RHR pumps running (YES)

RO Verify SI valves properly aligned (YES)

RO At least one CCW pump running (NO)

RO E-1 AND E-2 Energized by Offsite Power (NO)

RO CV Spray Initiated (NO)

Critical RO Start CCW Pump (YES)

Task CRITICAL TASK: Start one CCW pump to restore Seal Cooling to the RCPs within 15 minutes. (May have already been performed lAW AOP-018)

Verify Open Thermal Barrier Flow Control FCV-626 Unless Closed RO Due to Ruptured Thermal Barrier. (FCV-626 Verified Open)

All SW & SW booster pumps running (YES)

BOP RO Verify CV Fans HVH-1,2,3&4 running (YES)

RO Verify IVSW System initiated (YES)

Appendix D NUREG-1021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 31 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actions or Behavior RO Verify CV ventilation isolation (YES)

Verify control room ventUaUon aligned for pressurization mode (YES)

Operator to verify the following:

- Verify CONT RM AIR EXHAUST Fan, HVE-16 STOPPED -

- Verify CLEANING Fan HVE-19 A/B RUNNING BOP - Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CRD1A-SA CLOSED -

- Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1 B-SB CLOSED -

HZ CR-D1A-SAOR CR-D1B-SB have lost power, THEN locally verify Iosition in the Control Room Kitchen.

BOP Verify both EDGs running (YES)

Continuous Action Step BOP Restart Battery Chargers within 30 minutes of Power Loss using OP 601 (A Battery Charger failed to automatically restart. Operator must be dispatched to locally restart the battery charger.)

Continuous Action Step RO CV pressure remained below 10 psig (YES)

BOP Automatic Steam Line Isolation Initiated (NO)

BOP Automatic Steam Line Isolation Required (NO)

BOP Locally open the breaker for HVS-1 at MCC-5 within 60 minutes of SI Initiation BOOTH Open the breaker for HVS-1 3 minutes after directed by the Control Room.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 32 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actions or Behavior RO RCS pressure greater than 1350 psig [1250 psig] (NO)

RO SI flow verified (YES)

RO RCS pressure >125 psig (YES)

BOP At least 300 gpm AFW flow available (YES)

Verify AFW Valves Properly Aligned (NO) (AFW Valves must be Critical manually aligned. May have been performed as an early action.)

Task BOP (Critical Task is to establish flow to at least one S/G.)

CRITICAL TASK: Establish feed flow to at least one SIG.

BOP Control AFW flow to maintain S/G levels between 8% [18%] and 50%

RCP Thermal Barrier Cooling Water Hi or Lo flow alarms illuminated RO (NO)

BOP Place Steam Dump Mode switch to Steam Pressure RO RCS temperature stable at or trending to 547°F (NO)

RO RCS temperature greater than 547°F (NO)

RO Attempt to limit cooldown Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 33 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Tim( Position Applicants Actions or Behavior IF RCS Cooldown continues and is not due to SI flow, THEN CLOSE BOP MSIVs and MSIV Bypasses.

. MSIV and MSIV Bypasses are closed.

RD PZR PORVs Closed (YES)

RD PZR Spray & Aux Spray valves closed (YES)

RO At least one RCP running (NO)

BOP Any SIG with uncontrolled depressurization (NO)

BOP Any SIG Completely Depressurized (NO)

BOP R-i9s, R-3is, R-15 Rad levels normal (YES)

BOP R-2, R-32A, R-32B Rad Levels Normal (YES)

CV Pressure Normal (NO)

RD

. GO TO PATH-i Entry Point C RD Reset SPDS and initiate monitoring CSFSTs Open Foldout B.

CREW (No actions needed from this Foldout.)

BOP Request Periodic Activity Samples of All S/Gs RD At Least One RCP Running (NO)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 OpTestNo.: Scenario # 1 Event # 4 and 5 Page 34 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

time I Position Applicants Actions or Behavior BOP Any SIG with Uncontrolled Depressurization (NO)

BOP Any SIG Completely Depressurized (NO)

BOP Control AFW Flow to Maintain SIG Levels between 8% [18%] and 50%

BOP Any S/G with Uncontrolled Level Rise (NO)

BOP R-19s, R-31s, AND R-15 Rad Levels Normal (YES)

RO PZR PORVs Closed (YES)

Open at least one PORV Block unless Closed to Isolate an Open PZR RO PORV Continuous Action Step RO IF PZR PORV Opens on High Pressure, THEN Verify Reclosure at or Below 2335 PSIG. Close PORV Blocks as Necessary.

RO Reset SI Continuous Action Step CREW lFOffsite Power is Lost, THEN Restart Emergency Safeguard Equipment RO Reset CV Spray RO Reset Phase A AND Phase B Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 OpTestNo.: Scenario # 1 Event # 4 and 5 Page 35 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time I Position Applicants Actions or Behavior Establish Instrument Air to CV. IF Compressor Not Running, THEN RO Start Compressor.

BOP Offsite Power Available to Charging Pumps (NO)

IF Adequate diesel capacity not available to run charging pumps BOP THEN shed non-essential loads using Supplement F.

RO At Least One Charging Pump Running (YES)

RO Establish Charging Flow as Necessary RO CV Spray Pumps Running (NO)

RO RCS Subcooling Greater Than 35°F [55°F] (NO)

Continuous Action Step RO WHEN Below 1 0b0 Amps, THEN Energize Source Range detectors and monitor recorder.

RO RCS Pressure Greater Than 275 PSIG [400 PSIG] (YES)

RCS Pressure Stable or Rising (NO)

RO May be answered as YES depending on PATH-i timing. Steps annotated with a@ are listed if answered YES.

RO @Stop RHR Pumps Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # I Event # 4 and 5 Page 36 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actions or Behavior

@ Continuous Action Step RO @lf RCS Pressure lowers below 275PS1G [400 PSIG], THEN Restart RHR Pumps BOP Any S/G with Uncontrolled Depressurization in Progress (NO)

RO RCS Pressure Rising (NO)

BOP E-1 AND E-2 Energized by Offsite Power (NO)

BOP Attempt to restore offsite power to E-1 AND E-2 BOP Restart Battery Chargers within 30 mm of power loss using OP-601.

BOP Verify EDGs Properly Loaded (YES)

BOP Verify Emergency Oil Pump Running (YES)

BOP Locally verify Air Side Seal Oil Backup Pump running. (YES)

IF Diesel Capacity is not adequate to run Instr Air Compressors AND BOP Battery Chargers, THEN shed non-essential loads using Supplement F.

BOP Locally Load Instr Air Compressors AND Battery Chargers BOP E-1 OR E-2 Energized by Offsite Power (NO)

RO Supplement D components capable of Recirc (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 37 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actions or Behavior RO Aux. Building Radiation Normal (YES)

RO RCS Pressure Greater Than 275 PSIG [400 PSIG] (YES)

RO Obtain RCS Boron, Activity, AND Hydrogen Samples CREW Exit PATH-i to EPP-8 AOP-018, Reactor Coolant Pump Abnormal Conditions RO/BOP Make PA announcement for procedure entry RO/BOP Evaluate plant conditions AND Go to the appropriate section for RCP malfunction not yet addressed: Section C, Loss of Seal Injection.

RO/B P Check APP-001 -Dl, RCP THERM BAR COOL WTR LO FLOW alarm ILLUMINATED (YES)

Check elapsed time since all RCP Seal Cooling was lost GREATER THAN 15 MINUTES (NO)

RO/BOP

• If RCP Seal Cooling is NOT or can NOT be restored in less than 15 minutes, THEN Go To Step 3.

• GoToSteplO AppendixD NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 38 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actkrns or Behavior Establish Thermal Barrier Cooling as follows:

a. Verify the following component alignment:

1. At least ONE CCW Pump RUNNING (YES)

2. CC-716A, CCWTO RCP ISOOPEN (YES)

3. CC-716B, CCWTO RCP ISOOPEN (YES)

RO/BOP

4. FCV-626, THERM BARRIER OUTLET OPEN (YES)

5. CC-735, THERM BARRIER OUTLET OPEN (YES)

b. Check at least One Charging Pump RUNNING (NO)

. Observe the NOTE prior to Step 1 I and Go To Step 1 1 Determine if a charging pump can be started:

RO/BOP a. Check Charging system piping RUPTURED (NO)

. GoToSte12 ROIBOP Check SI INITIATED (YES)

RO/BOP Reset SI RO/BOP Verify at least ONE Charging Pump RUNNING -

Check Seal Injection to RCPs:

RO/BOP . ANY seal injection flow LESS THAN 6 GPM AND

. ANY thermal barrier Delta P LESS THAN 5 inches RO/BOP Check seal injection -ALIGNED Adjust any OR all of the foDowing to restore seal injection flow RO/BOP . HIC-121, CHARGING FLOW

. Charging Pump Speed CVC-297A, B, C Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 39 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time Position Applicants Actions or Behavior Check Seal Injection to RCPs:

. ANY seal injection flow LESS THAN 6 GPM (NO)

RO/BOP AND

. ANY thermal barrier Delta P LESS THAN 5 inches (NO)

.__Go_To_Step_47 RO/BOP Establish Charging flow on FI-122A, CHARGING LINE FLOW GREATER THAN 35 GPM (YES)

Check Normal Letdown IN SERVICE (NO)

RO/BOP If desired, THEN restore normal letdown using Attachment 4, Restoration of Normal letdown Control Charging and Letdown flow to maintain Pressurizer level as follows:

RO/BOP

• Within +1- 5% of reference level OR

• __PZR_level_between_30%_and_40%_with_RCP_C_stopped.

Establish normal seal injection RO/BOP a. Check RCP seal injection ALIGNED (YES)

b. Check RCP seal injection flow BETVVEEN 8 GPM AND 13 GPM Check seal injection flow ESTABLISHED TO ALL RCPs (YES)

RO/BOP SRO lmplement the EALs Refer to Technical Specification for ant applicable LCOs.

• 3.4.13 RCS Operational Leakage SRO

• 3.4.17CVCS

• 3.4.9 PZR Level

• __3.4.4,_3.4.5,_&_3.4.6__RCS_Loops Check RCP Seal Cooling ISOLATED (NO)

RO/BOP

• Observe the NOTE prior to Step 2 and go to the Main Body, Step_2_of_this_procedure.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 1 Event # 4 and 5 Page 40 of 41 Event

Description:

Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Time I Position I Applicants Actions or Behavior Evaluate plant conditions AND Go to the appropriate section for RCP RO/BOP malfunction not yet addressed: None

. Return to procedure and step in affect.

The Chief Examiner may terminate the scenario anytime after the transition to EPP-8 has been made or at his discretion.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

ILC-11-2 NRC SCENARIO I TURNOVER SHEET POWER LEVEL: 100% RTP Core Burnup: 15697 MWD/MTU EFPD: 448 EFPD Boron: 95 PPM Xenon: EQ Xenon Tavg: 575.9°F Bank D Rods 218 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW Pump QOS and Breaker Racked Out EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

• Switchyard access is RESTRICTED.

INSTRUCTIONS FOR THE WATCH:

• Maintain current power level Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board IDate: Todav ITime: 6:00:00 AMkle. 127 IMWDIMT: 15697 IDesian: 116590 IEFPD 448 Ioesign 473.5 I Tank ,Level% I Status HUT Level % Status Monitor A 10 Standby CVCS-A 20 Filling Monitor B 3_j Standby CVCS-B 10 Standby WCTA 37 Standby CVCS-C 86 Standby WCTB 7 Standby WHUT #NAME? Filling WCT C 9 Standby WCT 0 10 Standby inked to P1 WCT E 9 Standby WGDTS Pressure [PSIG Status A #NAME? PSIG On cover DEMINERALIZERS B #NAME? PSIG In Service PPM Resin In Service Date eplaced C 7AME? PSIG Isolated MBA 2194 YES 7I17I2010J0 D #NAME? PSIG ndby MB B 2265 O 7117/2010 CATION Th021 NO 9/1712010 12/9/2009 Shutdown Requirement Temp Boron DEBA 0 NO 1.77% =zK/K 547 F Hot 258 DEBB 0 NO /28/2010 1.77% =Lii 611 SFP 1963 7i23I2008 No 4/2212008 2.6% =L 100 F Cold 776

- 6%=KIK IN/A 11950 SGBD Condenser Air Inleakage I Target Value GPM Status PORV Settings A 13 CFM Flash Tank Setting Date POT GP-3 Psig B lo CFM B With Heat Ani12010 .3.21 11000 Known 8 CFM Recovery 50 1711812010 13.12 1040 Total 5 ICFM N2Flow 18 SCFM C 7/1812010 3.44 1000 Effluent Radiation Monitor Setpoints Rad Current NUE Value RCS Leakage 0.00 Unidentified Monitor Setpoint Alert Value 200X I I 2X Total 0.03 GPM R-14C 1.01E+04 NIA 2.020E+04 PRT 0.02 GPM NIA I .480E+04 RCDT Leakage 0.01 GPM Charging Leakoff Misc Identified 0

0 GPM GPM 9A1.O5E+O4 R-19B 9.72E+03 g!

1.944E+06 1.944E+04 PrimarylSecondary 0 I GPO R-19C 9.58E÷03 1.916E+06 [1.916E+04 Secondary Loss [17.3 GPM R-37 8.53E+03 1.706E+06 FTi06E÷04 Manually Entered Data Linked to CI em data base Hi Flux At Shutdown Boron PPM Date PPM Date PPM Previous ARI Counts Setpoint RCS Today 195 N[.31 j50 150 BAST-A 9116/2010 21,535 #NAME? J#NAME?

Ni-32T60 180 BAST-B 9/16/2010 21,032 #NAME? j#NAME?

SFP 911512010 2246 #NAME7 fAME?

Normal Currents RWST

! 9/16/2010 2219 #NAME? #NAME?

UPPER LOWER TARGET %BAND ccum-A 8/30/2010 2211 #NAME? #NAME?

N41 F144 136 0.0212 5+/- .ccum-B 8130/2010 2206 #NAME? #NAME?

N-42 5+1- Accum-C 8/3012010 2230 #NAME? #NAME?

N-43 121 113 0.0212 5+1- RHR 71612010 12221 N-44 112 [108 0.0212 5+1- Refuel Canal POWERTRAX Rev# 2.1.0 RNP E% APL 112.55 Refuel Cavity SFP Canal FANS TestlHrs [ DatelTst HVE-IAJB 35640.6 3/8/10 Notes/Additional Data HVE-15A I

18643.5 3/18110 IC-21 EOL SR 3.7.11.2 Last Completed [5127/2010 19:45

ILC-11-2 NRC SCENARIO I TURNOVER SHEET POWER LEVEL: 100% RTP Core Burnup: 15697 MWD/MTU EFPD: 448 EFPD Boron: 95 PPM Xenon: EQ Xenon Tavg: 575.9°F Bank D Rods 218 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW Pump OOS and Breaker Racked Out EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

• Switchyard access is RESTRICTED.

INSTRUCTIONS FOR THE WATCH:

• Maintain current power level Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board bate: Today ITime: 6:00:O0AMbCycle: 27 IMWD/MT: 15697 IDesign: 16590 IEFPD 448 IDesign 473.5 HUT Tank ILeveI% I Status 1 Level % Status Monitor A 10 CVCS-A 120 Filling Standby Monitor B 38 Standby CVCS-B 10 IStandby WCTA 37 I Standby CVCS-C 86 Standby WCTB WHUT #NAME? Filling WCT C 7 J Standby WCT D 9 J Standby Data Linked to P1 WCT E 10 J Standby WGDTS Pressure PSIG Status 9

-J Standby AI#NAME? PSIG On cover DEMINERALIZERS B I#NAME? PSIG In Service I PPM In Service Resin Date HEi PSIG Isolated MBA 2194 Replaced D #NAME? YES 7/17/2010 5/4(2010 IPSIG Standby MB B 2265 NO 711712010 3/29/2010 CATION 1021 NO 9/17/2010 12/9/2009 Shutdown Requirement Temp IBoron DEB A 0 NO New 21312010 1.77% =zK/K F Hot 258 DEBB 0 NO 1.77%=LK1K 350F 1611 SFP 1963 NO 9/23/2008 2.6%LK1KjF Cold 4/22,2008 776 6%=KIK N/A 1950 SGBD Condenser Air Inleakage Target Value GPM PORV Settings Status A 113 CFM A 50 Flash Tank Setting Date POT GP-3 Psig l B CFM B A 711812010 3Ji0O0 Known 50 With Heat 8 CFM C 50 Recovery B V18/2OIO 3.12 1040 Total 5 CFM N2 Flow C 711812010 3.44 8 SCFM 1000 Effluent Radiation Monitor Setpoints RCS Leakage 0.00 Unidentified Rad Current Alert Value 200X 1NUE Value Monitor ISetpoint Total 2X 0.03 GPM R-14C 1.OIE+04 N/A 2.020E+04 PRT 0.02 GPM R-20 7.40E+03 N/A 1.480E+04 RCDT Leakage 10.01 GPM R-18 1.OOE+06 2.000E+08 12.000E+06 Charging Leakoff 0 GPM R-19A I1.05E+04 2.IOOE+06 t2.IOOE+04 Misc Identified 0 GPM R-19B 19.72E+03 1.944E+j44E+0 Primary/Secondary 0 GPD R-19C 9.58E+03 1.91 6E+06 Secondary Loss 1ii6E+04 17.3 GPM R-37 8.53E+03 1.706E+06 1.706E+04 Manually Entered Data Linked to Chem data base Hi Flux At Shutdown Boron PPM Date PPM Date PPM Previous ARI Counts ISetpoint RCS Today 95 Nl-31 50 150 BAST-A 9/16/2010 21,535 #NAME? #NAME?

Nl-32 60 180 BAST-B 9/16/2010 21,032 #NAME? J#NAME?

SFP 9/15/2010 2246 #NAME? #NAME?

Normal Currents RWST 9/16/2010 2219 #NAME? #NAME?

UPPER LOWER TARGET  % BAND Accum-A 8/30/2010 2211 #NAME7 #NAME?

N-41 144 136 0.0212 5+!- Accum-B 8/30/2010 2206 #NAME? #NAME?

N-42 126 125 0.0212 5+!- Accum-C 8/30/2010 2230 N-43 121 113 #NAME? #NAME?

0.0212 5+!. RHR 7/6/2010 N-44 112 2221 108 0.0212 5+1- Refuel Canal POWERTRAX Rev# 2.1.0 RNP  % APL 112.55 Refuel Cavity SFP Canal FANS lTest/Hrs Date/Tst HVE-IA/B 0.6 3/8/10 Notes/Additional Data HVE-15A 18643.5 3/18/10 lC-21 HVE.19A/B 6928.3 5/3/10 EOL SR 3.7.11.2 Last Completed 5/27/2010 19:45

Appendix D Scenario Outline Form ES-D-1 Facility: HB ROBINSON Scenario No.: 2 Op Test No.:

Examiners: Operators: SRO -

RO BOP Initial Conditions:

• 75% RTP MOL, 9000 MWD/MTU, 775.5 ppm Boron

. A MDAFW pump inoperable with the breaker racked out

• Currently thunderstorm watch is in effect for Darlington and Cheste rfield counties Turnover:

• Plant is at 75% power following maintenance on A HDP.

Operations Management and RES have reported unusually high vibrations on A MFP and recommend a power reduction be performed and A MFP secured as soon as possible.

Critical Tasks:

• Isolation of C SIG

• Tripping C RCP within 5 minutes of Reactor Trip Event MaIf. Event Type* Event No. No. Description 1 (C) BOP, SRO Service Water Pump D trips (TS) SRO 2 (N) BOP, SRO A MFP Vibrations I Reduce Power 3 (C) RO, SRO Control Bank D Rods unwarranted rod motion 4 (C) BOP, SRO Feedwater Reg. Valve FCV-478 slowly drifts open 5 (I) RO, SRO .

Pressurizer Level Transmitter LT-459 fails LOW (TS) SRO 6 (N) BOP, SRO Restore normal letdown 7 (C) RO, SRO RCP C High Vibrations 8 (M) ALL C S/G Tube Rupture when RCP C is secured following manual reactor trip 9 C S/G PORV fails OPEN I Tube Rupture size rises (C) RD RHR Pumps A and B fail to auto-start (C) BOP FW Isolation Valve V2-6C fails to close on SI Signal (C) RD Conditional: Seal Failure on C RCP if C RCP not secure within 5 mm. of reaching 20 mils vibration on C RCP.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-1 ILC-11-2 NRC SCENARIO 2

SUMMARY

DESCRI PTION The crew will assume the watch with the unit bein g maintained at 75% RTP following the completion of maintenance on A Heater Drain Pump. The control room has received a report from the Operations Manager that the RES syste m engineer has reported that vibrations on A MFP have become abnormally high. RES reco mmends that A MFP be secured within the next hour. MDAFW Pump A is out of service for sche duled lube oil cooler replacement. The motor breaker has been racked out and the pump has been isolated and cleared for maintenance.

Shift instructions are to maintain current power level while RES is monitoring performance of A Heater Drain Pump following maintenance.

On cue from the Chief Examiner, D Service Wate r Pump will trip. Various alarms will be received on APP-002 and APP-008. APP-008-F4, SW PMP AIBICID OVLD, will direct the operator to start a Standby Pump and verify 40 to 50 psig in the SW Headers. The SRO will direct entry into ITS LCO 3.7.7, Condition A, which requires that the train of SW be restored to Operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. Once the Chief Exam iner is satisfied with the ITS compliance he may cue the next event.

Once the crew has lowered power by at least 5%

a malfunction will be inserted such that when D Bank Control Rods are moved, either in Auto or Manual, they will continue to insert until the immediate actions of AOP-001, Malfunction of Reactor Control System, are completed. The crew will perform the necessary actions in AOP-001 On cue from the Chief Examiner, Feedwater Regulatin g Valve FCV-478 will slowly drift open.

The crew will perform the immediate actions for the Main Feedwater malfunction lAW AOP-0i0, Main Feedwater I Condensate Malfunction. The oper ator will take manual control of FCV-478 and restore A SIG to its programmed level band.

The crew will contact maintenance to begin troubleshooting and repair efforts while continuing to operate the plant with one FRV in manual.

Once the Chief Examiner is satisfied with the actions of the crew and stability of the plant, he can cue the next event.

On cue from the Chief Examiner, Pressurizer Level Tran smitter, LT-459 fails LOW causing normal letdown to isolate, de-energizing of pressurize r control group heaters and charging pump speed to rise for the pump in Auto. The crew will select the alternate channel for control and implement OWP-030, Section PLT-1, and remove LT-459 from service. ITS Table 3.3.1-1 Item 8, Pressurizer Water Level High, Condition M requ ires that the channel be placed in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or reduce thermal power to less than P-7 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Once the level transmitter has been removed from service and the Chie f Examiner is satisfied with the Tech Specs compliance and plant restoration, the Chief Exam iner will cue the next event.

On cue from the Chief Examiner, C RCP will begin expe riencing high vibrations. The crew will enter AOP-018, Reactor Coolant Pump Abnormal Conditio ns, and determine that, based on current vibration levels, that a reactor trip is warranted. The crew will initiate a reactor trip, trip C RCP and then continue in PATH-i. A 500 gpm tube ruptu re in C SIG will be ramped in over 1 minute when C RCP is secured. The crew shou ld identify the 500 gpm tube rupture and initiate safety injection while performing the immediat e actions of PATH-i. Neither RHR Pump A nor B will auto-start on the safety injection signal. The operator will manually start Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-i

. both pumps once identified. Also, FW Isolation Valve V2-6C will fail to close on the safety injection signal and must be manually closed by the operator.

If the operator fails to trip C RCP within 5 minutes of reaching 20 mils vibration on C RCP a seal failure will occur on C RCP. The crew will enter AOP-Oi 8, Reactor Coolant Pump Abnormal Conditions, and perform Section A, Reactor Coolant Pump Seal Failure.

Approximately 2 minutes after initiation of safety injection the C S/G Steam Line PORV will fail OPEN and the tube rupture will rise to 775 gpm over a 1 minute time period.

The crew will continue in PATH-i, performing the actions of Foldout A to isolate auxiliary feedwater flowpaths to C SIG and begin performing Supplement G, Steam Generator Isolation, for C SIG. EPP-i 1, Faulted Steam Generator Isolation, will be transitioned to from PATH-i. EPP-i 1 will direct the crew to transition to PATH-2, Entry Point J.

PATH-2 will verify the isolation of C S/G and perform rapid cooldown of the RCS to lower the RCS pressure to a point that will stop the primary to secondary leakage. After the cooldown is secured it will be determined that the ruptured S/G pressure is continuing to lower and RCS subcooling cannot be maintained with the ruptured I faulted SIG. PATH-2 will direct the crew to transition to EPP-i7, SGTR with Loss of Reactor Coolant: Subcooled Recovery. EPP-17 will provide guidance to continue with RCS cooldown along with SI flow reduction, eventually leading up to placing the plant in a cold shutdown condition.

The Chief Examiner may terminate the scenario when the crew has made the determination that EPP-17, SGTR with Loss of Reactor Coolant: Subcooled Recovery, is the appropriate mitigation strategy, or at his discretion.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 ILC-I1-2 NRC SCENARIO 2 SIMULATOR SETUP ICISETUP:

• IC-802, SON: 008_i I _2_NRC_Exam_2

• A MDAFW Pump inoperable with the breaker racked out

• Status board updated to reflect 10-42.

• Switchyard access is RESTRICTED.

PRE-LOADED EVENTS:

The following event should occur when C RCP is secured:

Event 8: C S/C Tube Rupture (500 gpm)

RHR Pumps A and B fail to auto-start on SI Signal FW Isolation Valve V2-6C fails to close on SI Signal EVENTSITRIGGERS INITIATED DURING THE SCENARIO:

Event 1: Service Water Pump D trips Event 2: A MFP Vibrations I Reduce Power Event 3: Control Bank D Rods unwarranted rod motion Event 4: Feedwater Reg. Valve FCV-478 slowly drifts OPEN Event 5: Pressurizer Level Transmitter LT-459 fails LOW Event 6: Restore normal letdown Event 7: RCP C High Vibrations Event 9: C SIG Steam Line PORV fails OPEN and Tube Rupture size rises (775 gpm)

Conditional: Seal Failure on C RCP if C RCP not secure within 5 mm. of reaching 20 mils vibration on C RCP.

EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

• APP-008-F4

• OP-105

• AOP-OO1

• AOP-OIO

• AOP-025 Main Body and Section B

• OWP-030, PLT-I

• AOP-0I8

• PATH-I

• Foldout A

• Supplement G

• EPP-I1

• PATH-2

• Foldout C

• EPP-17 Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 5 of 47 Event

Description:

SW Pump D Trips Time 1 Position Apphcants Actions orBehanor BOOTH OPERATOR: When directed, insert Event 1, SW Pump D Trips EVENT INDICATIONS:

APP-008-F4, SW PMP AIBICID OVLD APP-002- A8, 88, C8, D8 HVH-1, 2, 3, 4 WTR OUTLET LO FLOW Service Water Pump 0 has dual indication on the RTGB Receives annunciator APP-008-F4, SW PMP AIBIC/D OVLD and BOP Identifies that SW Pump D has tripped.

If an operating SW Pump has tripped, THEN PERFORM the following:

BOP Start a Standby Pump.

If an operating SW Pump has tripped, THEN PERFORM the following:

BOP Dispatch operator to check breaker and current limiter fuses for SW Pump D 480V Bus E2 (CMP 25B)

Booth Operator: Report that SW Pump D breaker indicates that it tripped on over-current.

If an operating SW Pump has tripped, THEN PERFORM the following:

BOP THROTTLE CCW Heat Exchanger Return Valves, as necessary, to maintain 40 to 50 psi in the SW Headers.

Directs entry into ITS LCD:

3.7.7, Condition A, One SWS train inoperable. Restore SWS train to Operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

SRO 3.6.6, Condition D, Two containment cooling trains inoperable. (Due to receiving the HVH-1 ,2,3,4 WTR OUTLET LO FLOW). Restore one containment cooling train to Operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 6 of 47 Event

Description:

Main Feedwater Pump A high vibrations and power reduction to secure pump.

Time I Position Aoolicants Actions or Behavior BOOTH OPERATOR: Following a 5% power reduction, insert the failure of the control rods to continue to insert (dependant on whether the control rods are in AUTO or MANUAL)

SRD Notify the Load Dispatcher that unit load will be reduced (SOER 02-3, Larqe Power Transformer Reliability)

SRO Notify RC that higher radiation levels should be expected in the CV Pump Bays and in Pipe Alley due to normal shutdown crud bursts.

RD Monitor the highest operable Power Range Channel and the highest operable Intermediate Range Channel on NR-45.

IF Reactor Engineering has not provided technical guidance, THEN SRD/RO use the most recent DST-947 data to determine the reactivity change required.

For each power change which is greater than or equal to 10%,

SRO UPDATE the Power Change Log in the Reactor Startups-Shutdowns-Trips book.

IF additional letdown flow is desired, THEN PERFORM the following:

RO

• Start additional Charging Pumps as necessary, lAW OP-301.

• Place additional letdown orifice in service lAW OP-301.

RD IF a significant change in RCS Boron concentration occurs (10 ppm or more), THEN energize additional PZR heaters as needed.

DETERMINE the amount of Boric Acid to add to the RCS and RD OBTAIN an independent check of the volume of boric acid required.

OBTAIN permission from the CRS OR the SM to add the amount of RD boric acid previously determined.

PLACE the RCS MAKEUP MODE selector switch in the BORATE RD position.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 7 of 47 Event

Description:

Main Feedwater Pump A high vibrations and power reduction to secure pump.

Time Position I AIicants Actions or Behavior RO SET YIC-1 13, BORIC ACID TOTALIZER to the desired quantity.

IF desired, THEN PLACE FCV-113A, BORIC ACID FLOW, in MAN RO AND manually ADJUST controller FCV-1 1 3A, BORIC ACID FLOW, using the UP and DOWN Dushbuttons.

Momentarily PLACE the RCS MAKEUP SYSTEM switch to the RO START position.

IF any of the below conditions occur, THEN momentarily place the RCS MAKEUP SYSTEM switch in the STOP position:

RO

• Rod Motion is blocked or in the wrong direction

• TAVG goes up

• Boric Acid addition exceeds the desired value WHEN the desired amount of Boric Acid has been added to the RCS, THEN verify the following:

• FCV-1 13A, BA TO BLENDER, closes.

RO

• FCV-113B, BLENDED MU TO CHG SUCT, closes.

• IF in Auto, THEN the operating Boric Acid Pump stops.

• __The_RCS_MAKEUP_SYSTEM_is_OFF.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 8 of 47 Event

Description:

Main Feedwater Pump A high vibrations and power reduction to secure pump.

Time Position Applicants Actions or Behavior IF desired, THEN FLUSH the Boric Acid flow as follows:

. PLACE the RCS MAKEUP MODE selector switch in the ALT DILUTE position.

. SET YIC-1 14, PRIMARY WTR TOTALIZER to 15-20 gallons.

. PLACE FCV-1 14B, BLENDED MU TO VCT to the CLOSE position.

. Momentarily PLACE the RCS MAKEUP SYSTEM switch to the START position.

. IF any of the below conditions occur, THEN momentarily place RO the RCS MAKEUP SYSTEM switch in the STOP position:

o Unanticipated Rod Motion o Primary Water addition reaches the desired value.

. WHEN the desired amount of Primary Water has been added to the RCS, THEN verify the following:

o FCV-114A, PWTO BLENDER, closes.

o FCV-113B, BLENDED MU TO CHG SUCT, closes.

o IF in Auto, THEN the operating Primary Water Pump stops.

o__The_RCS_MAKEUP_SYSTEM_is_OFF.

RETURN the RCS Makeup System to automatic as follows:

. VERIFY FCV-1 14A, PRIMARY WTR FLOW DILUTE MODE is in AUTO.

. PLACE FCV-1 14B, BLENDED MU TO VCT to the AUTO RO position.

. PLACE the RCS MAKEUP MODE switch in the AUTO position.

. VERIFY FCV-1 13A, BORIC ACID FLOW, is in AUTO.

. Momentarily PLACE the RCS MAKEUP SYSTEM switch in the START_position.

RECORD, in AUTO LOG, as indicated by PRIMARY WATER RO TOTALIZER, YIC-1 14 AND Boric Acid TOTALIZER, YIC-1 13 the total amount of Primary Water AND Boric Acid added durinq the boration.

MONITOR parameters for the expected change in reactivity AND RO inform the CRS OR the SM the results of the boration.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 2 Page 9 of 47 Event

Description:

Main Feedwater Pump A high vibrations and power reducti on to secure pump.

Time Position Amlicants Actions or Behavior IF EH Turbine Control is in OPER AUTO, THEN redu ce turbine load as follows:

. Place the EH Turbine Control in the desired position: IMP IN or BOP IMP OUT (Per RNP Standing Instruction IMP OUT preferred.)

. Set the desired load in the SETTER.

. Select the desired Load Rate.

. Depress the GO pushbutton.

RO WHEN Reactor Power is <90% as indicated on NR-45, THEN CHECK that APP-005-D6 is received. (N/A, initial reactor power at 75%)

VERIFY proper programming of the following:

RO Tavg tracks within 5°F of Tref.

PZR level tracks within 5% of reference level.

RO Maintain the control rods above the minimum allowable rod height by borating the RCS lAW OP-301 BOP Maintain Gland Seal Steam Header Pressure in the norm al operating band (3 to 6 psiq) (P1-4004, P1-i 382 or ERFIS Pt GSP 2O95A)

WHEN P1-1458, COND PUMPS HEADER PRESS indicates between 575 psig and 600 psig, THEN PERFORM the following:

BOP SECURE the following as needed for feedwater flow requirem ents:

One Main Feedwater Pump may be secured when reactor pow er is less than or equal to 60%.

Appendix D NUREG-l 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 10 of 47 Event

Description:

Control Bank D rods unwarranted rod motion Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 3, Control rod unwarranted rod motion.

EVENT INDICATIONS:

Control rods continue to insert (AUTO or MANUAL).

Rod direction indication light illuminated.

Step counters audible Tave < Tref RO Immediate Action Step Check unexiected rod motion IN PROGRESS (YES)

RO Immediate Action Step Check Reactor Power GREATER THAN 15% (YES)

Immediate Action Step Check Turbine Load CONTROL RODS STEPPING IN (YES)

AND UNEXPECTED LOAD REDUCTION IN PROGRESS(NO)

OR UNEXPECTED LOAD REDUCTION HAS OCCURRED (NO)

RO RNO

a. IF ROD BANK SELECTOR switch position in A (AUTO), THEN place the ROD BANK SELECTOR switch in M (Manual)

b. IF ROD BANK SELECTOR switch position in M (Manual) OR Individual Bank Select, THEN place the ROD BANK SELECTOR switch in A (AUTO)

Go To Step 5 BOP Make PA Announcement For Procedure Entry CREW Go To Section C, Continuous Rod Motion.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 11 of 47 Event

Description:

Control Bank D rods unwarranted rod motion Time Position Aoolicants Actions or Behavior Check ROD BANK SELECTOR switch position when problem occurred INDIVIDUAL BANK SELECT (NO)

RD RND Go To Step 4 RD Stop any boron dilution in progress.

Check APP-005-B5, RDD BANKS AIB/C/D LO LIMIT RD EXTINGUISHED (YES)

RD Check reactor power LESS THAN DR EQUAL TO 100% (YES)

NOTE: The following step depends on what mode the rod control system was in when the failure occurred.

Check Rod Bank Selector Switch Position AUTO (ND)

RNO Perform the following:

Maintain Tavg within -1.5 to +1.5°F of Tref using manual rod control DR Maintain Tavg within -1.5 to +1.5°F of Tref by adjusting turbine load using Attachment 1, Turbine Load Adjustment.

Attachment I Turbine Load Adjustment

1. Check Turbine Control Mode AUTOMATIC RD RND: Momentarily depress the GV (up/down) buttons on the EH Control Panel as needed to adjust Turbine Load. Return to Step In Effect.

2. Check Turbine Load Adjustment In IMP IN Desired RNO: Perform the following

a. Verify IMP OUT light ILLUMINATED

b. GoTo Step 4

3. Depress the IMP IN Pushbutton

4. Set The Desired Load In The SETTER

5. Set the Desired Load Rate

6. Depress the GO and HOLD Pushbuttons as necessary Contact I&C and Reactor Engineering to troubleshoot and correct the SRD problem.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 3 Page 12 of 47 Event

Description:

Control Bank D rods unwarranted rod motion Time Position Applicants Actions or Behavior SRO Implement The EALs Review Technical Specifications to assure all applicable LCO requirements have been met: (NONE are applicable)

. ITS 3. 1.4 Rod Alignment

. ITS 3.1.5 Shutdown Bank RIL

. ITS 3.1.6 Control Bank RIL and Overlap SRO

• ITS3.1.7IRPI

• ITS 3.2.1Fq(Z)

• ITS 3.2.2 F Delta h

• ITS 3.2.3 AFD

• ITS 3.2.4 QPTR

• __ITS_3.3.1_-_NIS NOTE: Crew should notify WCC SRO and!or l&C to write a work request, investigate and initiate repairs, and notify the Operations Manager.

SRO Return To Procedure And Step In Effect Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 13 of 47 Event

Description:

Feedwater Regulating Valve FCV-478 slowly drifts open.

E Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 4, Feedwater Regulating Valve FCV-478 slowly drifts open.

EVENT INDICATIONS:

FR-478 feedwater flow and SIG level rising APP-006-A3, SIG A LVL DEV Immediate Action Step Check feedwater regulating valves OPERATING PROPERLY (MANUAL OR AUTO) (NO)

RNO

a. Verify FRV for the affected S/G(s) in manual control (FCV-478 placed in manual)

BOP b. Attempt to stabilize S/G level using FRV and/or FRV bypass valves by matching steam flow with feed flow.

c. Stop any load change in progress.

d. IF unable to control S/G level, THEN trip the reactor AND Go To PATH-i OR EOP E-0, REACTOR TRIP or SAFETY INJECTION.

e. Go To Step 37.

RO Make PA announcement for procedure entry unless previously made.

BOP Check S/G level AT OR TRENDING TO PROGRAM (YES)

RO Check Tavg AT OR TRENDING TO Tref (YES)

Contact maintenance to troubleshoot and correct the feedwater SRO problem.

SRO Implement the EAL5 Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 14 of 47 Event

Description:

Feedwater Regulating Valve FCV-478 slowly drifts open.

Time I Position Applicants Actions or Behavior Check current loading for the following pumps LESS THAN MAXIMUM BOP . Main Feedwater Pump 0.715 KAMPS

. Condensate Pumps 370 AMPS

. Heater Drain Pumps 90 AMPS BOOTH OPERATOR: When requested

, respond that the current readings secondary pumps are as follows: on the

. Main Feedwater Pump O575 KAM PS

. Condensate Pumps 320 AMPS

. Heater Drain Pumps 75 AMPS Determine Iodine sampling requirements as follo ws:

a. Check power change GREATER THAN 15%

IN ONE HOUR RO (NO)

RNO WHEN the power change is greater than 15% in one hour, THEN perform step 43.b Go To Step 44 RO Check APP-005-B5, ROD BANKS A/B/C/D LO LIMIT EXTINGUISHED (YES)

RO Monitor axial flux difference to ensure compliance with ITS 3.2.3.

SRO Notify load dispatcher of the units load capability.

SRO Return to procedure and step in effect.

NOTE: Crew should notify WCC SRO andl or l&C to write a work request, investiga initiate repairs for the FRV failure, and te and notify the Operations Manager.

BOOTH OPERATOR: As soon as the plant is stabilized or at the discretion Examiner, insert the next event. of the Chief Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 15 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 5, PZR level Transmitter LT-459 fails LOW.

EVENT INDICATIONS:

APP-003-F4 CHG PMP HI SPEED APP-003-B7 PZR PROT LO LEVEL APP-003-E8 PZR CONTROL HIILO LVL APP-003-F8 PZR LO LVL HTR OFF & LTDN SECURE LR-459 Pen #1 fails to 0%

Ll-459A fails to 0%

Charging Pump C (in AUTO) rises to full speed PRZR LO LEVEL LC459A2 bistable illuminate d

LCV-460A and B valves closed AOP-025 RTGB INSTRUMENT FAILURE RO Go To The Appropriate Section For The Failed Tran smitter:

. Pressurizer Level Section B, Page 7 RO Check LCV-460 A&B, LTDN LINE STOP CLOSED (YES)

RO Place LCV-460A&B switch in the CLOSE position.

RO Verify ONLY ONE Charging Pump Running at mini mum speed.

BOP Make PA announcement for procedure entry.

Restore PRZR LEVEL To Between 22% TO 53%

by performing one of the following:

. Adjust operating Charging Pump speed in manual RO OR

. Level controller LC-459G, in MAN

- Place running Charging Pump speed controller in AUTO

- Adjust LC-459G in MAN Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 16 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position !l_ Applicants Actions or Behavior Check RCP seal injection flow BE1VIEEN 8 GPM AND 13 GPM (NO)

RNO Locally throttle RCP SEAL WATER FLOW CONTROL VALVE(s) to obtain flow to each RCP between 8 gpm and 13 gpm

- CVC-297A, B, C RO IF required to maintain minimum flow, THEN throttle HIC-121, CHARGING FLOW valve while maintaining Charging Pump discharge pressure less than 2500 PSIG.

IF the normal seal injection range can NOT be maintained, THEN an

?xpanded range of between 6 gpm and 20 gpm may be used.

Check Number Of Operable PZR Level Channels GREATER THAN RO -

ONE (YES)

Place LM-459, PZR LEVEL, In The Switch Position For The Alternate Channel Below:

RO Failed Channel I Switch Position LT-459 461 REPL 459 Verify Selector Switch LR-459 SELECTED TO THE CONTROLLING RO CHANNEL

. REC 461 Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 17 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position ApIias Actions or Behavior Continuous Action Step Restore PZR Level Control To Automatic As Follo ws:

a. Check Normal Letdown ISOLATED

b. Restore Letdown to service using Attachment 1, Restoration of Normal Letdown.

c. Start additional Charging Pump as desired

d. Check PZR level WITHIN +/-1% OF PROGRA MMED REFERENCE LEVEL RO o RNO WHEN PZR level is within +/-1%

of programmed reference level, THEN restore PZR Level Control to Automatic.

o GoToStepil.

e. Restore PZR Level control to Automatic (Steps for Attachment 1, Restoration of Normal Letdown, are located at end of this section)

Reset PZR Heaters As Follows:

a. Check affected PZR Level FAILED LOW (YES

)

b. Place PZR HTR CONTROL GROUP Control Swit ch to OFF position AND return to ON position RO c. IF required, THEN place PZR HTR BACK-UP GRO UP A Control Switch to OFF position AND return to AUT O OR ON position as desired

d. IF required, THEN place PZR HTR BACK-UP GRO UP B Control Switch to OFF position AND return to AUT O OR ON position as desired RO Check RCP Seal Injection Flow BETWEEN 8 GPM AND 13 GPM (YES)

Remove The Affected Transmitter From Service Usin g OWP-030:

RO I Channel I OWP LT-459 I PLT-1 Examiner Note: The next step may have been performed earlier Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 18 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Applicants Actins br ehvidi Press. Prot. & (LM-459) Control Switch RO 461 REPLACE 459 BOOTH OPERATOR: Trip the bistables per the crew direction JAW OWP-030, PLT-1 SRO Go To Procedure Main Body, Step 2 SRO Implement The EALs Check Technical Specifications (ITS) For Applicable LCOs

. ITS Table 3.3.1-1 Item 8, Pressurizer Water Level High, SRO Condition M requires that the channel be placed in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or reduce thermal power to less than P-7 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

SRO Return To Procedure And Step In Effect AOP-025, Attachment 1, Restoration of Normal Letdown RO/BOP Check normal charging flow through the Regenerative Heat Exchanger is in service.

RO/BOP Check Phase A Containment Isolation signal NOT present.

RO/BOP Check RHR System NOT in service.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 19 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time I Position Applicants Actions or Behavior Verify Closed the following valves:

. CVC-204A, LETDOWN LINE ISO

. CVC-204B, LETDOWN LINE ISO

• LCV-460A, LTDN LINE STOP RO/BOP

• LCV-460B, LTDN LINE STOP

• CVC-200A, LETDOWN ORIFICE ISOLATION

• CVC-200B, LETDOWN ORIFICE ISOLATION

• __CVC-200C,_LETDOWN_ORIFICE_ISOLATION RO/BOP Verify HIC.121, CHARGING FLOW is full open.

RO/BOP Check PZR level is greater than OR equal to program level.

RO/BOP IF desired, THEN PLACE TCV-143, VCT/DEMIN, in the VCT position.

RO/BOP PLACE PCV-145, PRESSURE in MANUAL.

Set PC-145 to throttle PCV-145 to 45% to 55% open to ensure the RO/BOP Letdown line is NOT overpressurized.

RO/BOP OPEN CVC-204A, LETDOWN LINE ISO.

RO/BOP OPEN CVC-204B, LETDOWN LINE ISO.

Perform the following:

RO/BOP a. OPEN LCV-460A&B by placing switch LCV-460A&B LTDN LINE STOP to OPEN.

b.__PLACE_LTDN_LINE_STOP_LCV-460 A&B_switch_to AUTO.

Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 20 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Applicants Actions or Behavior Establish cooling to the NON-REGEN HX as follows:

a. PLACE TC-144, NON-REGEN HX OUTLET TEMP, in RO/BOP MANUAL

b. ADJUST TC-144, NON-REGEN HX OUTLET TEMP as necessary to ensure Letdown temperature does NOT increase above_127°F_when_letdown_is_reestablished.

While MAINTAINING Charging Pump discharge pressure as indicated RO/BOP on RTGB instrument P1-121 LESS THAN 2500 psig, ADJUST charging pump speed to the expected letdown flow to be established in the next step.

OPEN one LTDN ORIFICE valve:

RO/BOP - CVC-200A, LETDOWN ORIFICE ISOLATION

- CVC-200B, LETDOWN ORIFICE ISOLATION

- CVC-200C, LETDOWN ORIFICE ISOLATION PLACE PC-145 in AUTO AND CHECK letdown pressure as indicated RO/BOP on P1-145, LOW PRESS LTDN PRESS, is being maintained between 300 psig and 320 psig.

RO/BOP PLACE TC-144, NON-REGEN HX OUTLET TEMP, in AUTO.

RO/BOP IF TCV-143 was selected to the VCT, THEN POSITION TCV-143 as directed by the CRS/SM.

Verify RCP seal injection flow between 8 GPM and 13 GPM by throttling the following:

RO/BOP

• CVC-297A, RCP A SEAL WATER FLOW CONTROL VALVE

• CVC-297B, RCP B SEAL WATER FLOW CONTROL VALVE

• CVC-297C, RCP C SEAL WATER FLOW CONTROL VALVE Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5 and 6 Page 21 of 47 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Applicants Actions or Behavior IF increased letdown flow is desired, THEN place additional letdown orifices in service as follows:

a. VERIFY HIC-121, CHARGING FLOW is FULL OPEN

b. VERIFY Charging Pump discharge pressure as indicated on RTGB instrument P1-i 21 LESS THAN 2500 psig.

c. IF required, THEN start the second Charging Pump on MINIMUM SPEED.

d. IF required, THEN while maintaining Charging Pump discharge pressure as indicated on RTGB instrument P1-121 LESS THAN 2500 psi, ADJUST charging pump speed to meet flow 9

requirements RO/BOP e. Place PC-145, PRESSURE, in MANUAL.

f. Slowly throttle open PC-145 to achieve 180-200 psig on P1-145 to ensure the letdown line is NOT overpressurized.

g. OPEN one additional LTDN ORIFICE valve.

h. Place PC-145 in AUTO and check letdown pressure as indicated on P1-145, LOW PRESS LTDN PRESS, is being maintained between 300 psig and 320 psig.

i. Verify RCP seal injection flow between 8 gpm and 13 gpm by throttling the following:

o CVC-297A o CVC-297B o CVC-297C Notify RC that letdown flow has been restored and the affected areas RO/BOP should be monitored for changing radiological conditions.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 7 Page 22 of 47 Event

Description:

RCP C High Vibrations Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 7, RCP C High Vibrations EVENT INDICATIONS:

APP-OO1-B5, RCP HIGH VIB Rising vibrations on C RCP Vibration Monitor and ERFIS GD RCP LOG APP-0O1-B5 Actions:

Checks affected RCP alarm valid as follows:

1. Check the alarming monitor for flashing Alert.

2. Momentarily Depress the RES button for the alarming monitor.

BOP

3. Alarm will reset and then return. Alarm is valid.

4. If the alarm is valid, then refer to AOP-01 8.

5. While alarm is actuated, Monitor RCP Vibration Monitor for any increase on unaffected pumps.

SRO Announces entry into AOP-018.

BOP Make PA Announcement for procedure entry.

Determines that Section B, High Reactor Coolant Pump Vibration, is SRO the appropriate section.

Check The Following Vibration Levels To Determine If RCP Trip(s) Are Required:

Frame GREATER THAN 5 MILS OR Frame GREATER THAN 3 MILS AND RISING AT A RATE OF 0.2 BOP MILS/HOUR CURRENTLY OR PRIOR TO ALARM OR Shaft GREATER THAN 20 MILS OR Shaft GREATER THAN 15 MILS AND RISING AT A RATE OF 1 MIL PER HOUR CURRENTLY OR PRIOR TO ALARM (YES)

RO Check Plant Status Mode 1 OR Mode 2 (YES)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 7 Page 23 of 47 Event

Description:

RCP C High Vibrations Time I Position Aoolicants Actions or Behavior RO Trips the reactor and verifies the reactor tripped.

Critical RO Trip C RCP BOOTH OPERATOR: Insert Seal Failure on C RCP if C RCP is not tripped within 5 of reaching 20 mils on C RCP.

Examiners Note: AOP-018 steps to address the conditional seal failure on C RCP are listed at the end of the scenario guide.

BOOTH OPERATOR: Insert Event 8, SIG C Tube Rupture when the C RCP is tripped.

Immediate Action Step:

RO Reactor Tripped. (YES)

Immediate Action Step:

BOP Turbine Tripped. (YES)

Immediate Action Step:

BOP E-1 AND E-2 energized (YES)

Continuous Action Step:

BOP IF DS Bus is deenergized THEN place DSDG in service using EPP-25 Immediate Action Step:

RO SI initiated. (NO)

Immediate Action Step:

RO SI initiation required. (YES) (NOTE: Initial diagnosis may not determine that an SI is required.)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 7 Page 24 of 47 Event

Description:

RCP C High Vibrations Time jJ Position Applicants Actions or Behavior Immediate Action Step:

RO Initiate SI (YES) (NOTE: Initial diagnosis may not determine that an SI is required.)

BOOTH OPERATOR: Insert Event 9 approximately 2 minutes after SI is initiated. Event 9 is C S!G PORV fails OPEN I C SIG Tube Rupture size rises.

SRO Enters PATH-i and verifies PATH-i Immediate Actions.

Examiners Note: Following the performance and verification of PATH-I Immediate Actions, the crew will continue with AOP-O1 8. These steps may be handed off to the ROIBOP to perform independently. The remaining steps of AOP-018, Section B, High RCP Vibration are listed below.

RO/BOP Check RCP B or C Running (YES)

RO/BOP Check RCP B Running (YES)

RO/BOP Check RCP C Running (NO)

RO/BOP Place PCV-455B controller to MAN AND adjust controller output to ZERO.

RO/BOP Maintain PZR level between 30% and 40% to provide adequate PZR spray.

Check RCP OIL RESERV HI/LO LVL Alarms EXTINGUISHED:

(YES)

RO/BOP

• APP-00i-D8 RCP A

• APP-001-E8 RCP B -

• __APP-00i-F8-RCPC Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 7 Page 25 of 47 Event

Description:

RCP C High Vibrations Time Position ANcants Actions or Behavior Check All RCP #1 Seal Leakoff Flows BETWEEN 1 GPM AND 5 RO/BOP GPM (YES)

Check RCP Seal Injection Flow - BETWEEN 8 GPM AND 13 GPM RO/BOP (NO)

Locally throttle RCP SEAL WATER FLOW CONTROL VALVE(s) to obtain flow to each RCP between 8 gpm and 13 gpm

. CVC-297A

. CVC-297B RD/BC P . CVC-297C IF required to maintain minimum flow, THEN throttle HIC-121, CHARGING FLOW Valve while maintaining Charging Pump Discharqe pressure less than 2500 PSIG.

SRO Notify Manager Operations DR Designee of RCP Performance SRO Implement the EALs Refer to ITS for any applicable LCOs SRO

. 3.4.4, 3.4.5 and 3.4.6 SRO Go to the Main Body, Step 2 of AOP-018.

Examiners Note: This is the end of AOP-018 steps. PATH-I steps commence on the next page.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 26 of 47 Event

Description:

C S/G Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Apphcants Actions or Behavior SRO Open Foldout A MSR ISOLATION CRITERIA Perform the following to isolate the MSRs:

IF ANY Purge OR Shutoff Valve does not indicate fully closed, THEN place the associated RTGB Switch to CLOSE. (YES)

BOP U ANY Purge OR Shutoff Valve can NOT be closed from the RTGB AND RCS temperature is less than 540°F and lowering, THEN close the MSIVs AND MSIV BYPs. (NO)

IF a loss of power prevents isolation of the MSRs, THEN close the MSIVs AND MSIV BYP5. (NO)

FAULTED S/C ISOLATION CRITERIA IF the both the conditions below are met, THEN perform the following:

. Any SIG pressure is lowering in an uncontrolled manner OR Any S/C has completely depressurized.

AND

. At least ONE S/C is intact.

BOP a. ResetSi.

b. CLOSE the appropriate Auxiliary Feedwater isolation valves to the faulted S/Gs AND OPEN the associated breaker for the valves closed.

SIG C

. V2-14C, SDAFW PUMP DISCH (MCC-10, CMPT-4M)

. V2-16C, AFW HDR DISCH (MCC-9, CMPT-3J)

c. WHEN the faulted S/Gs dry out, THEN dump steam from intact S/G to control RCS repressurization.

Appendix D NUREG-1021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 27 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manua l reactor trip. 2 minutes after SI initiation, C SIG PORV tails OPEN / Tube rupture size rises.

Time Position Applicants Actions or Behavior RUPTURED SIG ISOLATION CRITERIA (BOP may not recogn ize the ruptured SIG during initial Foldout A entry.)

IF the conditions below are met, THEN perform the following:

The Ruptured SIG is identified by observing an uncontrolled level rise OR abnormal radiation level on the R-19s or R-31s.

AND The Ruptured SIG Level is Greater than 8% [18%]

BOP a. ResetSi.

b. CLOSE the appropriate Auxiliary Feedwater isolation valves to the Ruptured S/Gs.

S/G C

. V2-14C. SDAFW PUMP DISCH

. V2-16C. AFW HDR DISCH

c. WHEN desired, THEN Perform Supplement G, Steam Generator Isolation Indications Available:

C SIG level trending up at a faster rate than A and B SIGs.

C SIG level continues to trend up when feed secured to C SIG.

PZR level continues to lower.

PZR Pressure continues to lower.

Examiner Note: RO may recognize that neither RHR Pump started and take early action to start both RHR pumps.

Examiner Note: BOP may recognize that V2-6C failed to close on SI and take early action to manually close V2-6C.

F Candidate may direct that Supplement G be performed to isolate I SIG C. Supplement G steps begin on Page 42.

SRO Foldout A is in effect.

RO Verify Phase A Isolation valves closed (YES)

Verify FW isolation valves closed (NO)

BOP Manual action is taken to close V2-6C, if not previously performed.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 28 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior BOP Verify both FW pumps tripped (YES)

Verify both MDAFW pumps running (NO)

BOP MDAFW Pump A inoperable from initial conditions.

BOP If Additional Feedwater is required, THEN Start SDAFW Pump (Running)

RO Verify two SI pumps running (YES)

Verify both RHR pumps running (NO)

RO Manual action is taken to start both RHR pumps, if not previously performed.

RO Verify SI valves properly aligned (YES)

RO At least one CCW pump running (YES)

All SW & SW booster pumps running (NO)

BOP SW Pump D Inoperable BOP Attempt to start all SW and SWB Pumps BOP North OR South SW HDR LO PRESS alarms illuminated (NO)

RO Verify CV Fans HVH-1,2,3 & 4 running (YES)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.; I Scenario # 2 Event # 8 and 9 Page 29 of 47 Event Description; C S)G Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C S/G PORV fails OPEN I Tube rupture size rises.

Time Position J Applicants Actions or Behavior RO Verify IVSW initiated (YES)

Verify CV ventilation isolation (YES)

Verify the following valves CLOSED:

- V12-6, CONT PURGE VALVE

- V12-7, CONT PURGE VALVE

- V12-8, CONT PURGE VALVE RO

- V12-9, CONT PURGE VALVE

- V12-10, CONTAINMENT PRESSURE RELIEF

- V12-11, CONTAINMENT PRESSURE RELIEF

- V12-12, CONTAINMENT VACUUM RELIEF

- V12-13, CONTAINMENT VACUUM RELIEF Verify control room ventilation aligned for pressurization mode (YES)

Operator to verify the following:

- Verify CONT RM AIR EXHAUST Fan, HVE-16 STOPPED -

- Verify CLEANING Fan HVE-19 A/B RUNNING -

BOP - Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1A-SA CLOSED -

- Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1 B-SB CLOSED -

H CR-D1A-SA OR CR-D1 B-SB have lost power, THEN locally_verify_position_in_the_Control_Room_Kitchen.

BOP Verify both EDGs running (YES)

Continuous Action Step BOP Restart Battery Chargers within 30 minutes of Power Loss using OP 601 (Not Required)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 30 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured follow ing manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position j Applicants Actions or Behavior Continuous Action Step RO CV pressure remained below 10 psig (YES)

BOP Automatic steam line isolation initiated (NO)

BOP Automatic Steam Line Isolation Required (NO)

BOP Locally open the breaker for HVS-1 at MCC-5 within 60 minutes of SI Initiation Booth Operator Wait 3 minutes and open the breaker as requested by the operators and report the action completed.

RO RCS pressure greater than 1350 psig [1250 psig] (NO)

RO SI flow verified (YES)

RO RCS pressure >125 psig (YES)

BOP At least 300 GPM AFW flow available (YES)

BOP Verify AFW valves properly aligned (YES)

BOP Control AFW flow to maintain S/G levels between 8% [18%]

and 50%

RO RCP Thermal Barrier Cooling Water Hi or Lo flow alarms illumin ated (NO)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 31 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior BOP Place Steam Dump Mode switch to Steam Pressure RO RCS temperature stable at or trending to 547°F (NO)

RO RCS Temperature greater than 547°F (NO)

BOP Attempt to limit cooldown.

IF RCS cooldown continues AND is not due to SI Flow THEN close BOP MSIVs AND MSIV Bypasses. (Candidates may determine that cooldown is due to the stuck open PORV and decide not to close the MSIVs on the intact SIGs.)

RO PZR PORVs Closed (YES)

RO PZR Spray & Aux Spray valves closed (YES)

RO At least one RCP running (YES)

RO At least one SI Pump Running (YES)

RO RCS Subcooling Less Than 35°F [55°F] (NO)

BOP Any S/G with uncontrolled depressurization (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 32 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Aoolicants Actions or Behavior RD Reset SPDS and monitor CSFSTs.

SRO Transition to EPP-1 1.

BOP Maintain At Least One S/G Available For RCS Cooldow n

Check SIG Status:

a. Identify intact S/Gs as follows:

. ANY SIG PRESSURE STABLE OR INCREASING (YES)

BOP b. Identify faulted S/Gs as follows:

. ANY S/G PRESSURE DECREASING IN AN UNCONTROLLED MANNER (YES)

OR

. ANY S/G COMPLETELY DEPRESSURIZED Isolate Faulted S/Gs Using Supplement G, S/G Isolation BOP (Supplement G actions are included following this secti on.)

BOP Maintain A Faulted S/G In The Isolated Condition During Subsequent Recovery Actions Unless Needed For Cooldown BOP Check CST Level GREATER THAN 10% (YES)

BOP Check Available Secondary Radiation Monitors NORMAL (NO)

SRO Go to PATH-2, Entry Point J.

RD Reset SPDS AND Initiate Monitoring of Critical Safety Func tion Status Trees Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 33 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C S/G PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior Open Foldout C CREW (No steps apply)

Continuous Action Step RD When Below 10b0 AMPS, THEN Energize Source Range Detectors AND Transfer Recorder BOP Request Periodic Activity Samples of All SIGs BOP Place Steam Dump Mode Switch to Steam Pressure BOP Open QCV-1 0426 to bypass Condensate Polishers BOP Close C-48A AND C-48B to isolate Hotwell return to CST RD At Least One RCP Running (YES)

RD At Least One SI Pump Running (YES)

RD RCS Subcooling Less than 35°F [55°F] (NO)

BOP Ruptured SIG Identified (YES)

BOP Maintain at Least One SIG Available for RCS Cooldown Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 34 of 47 Event

Description:

C S/G Tube Rupture when RCP C is secured following manua l reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position I Applicants Actions or Behavior BOP Verify Ruptured Steam Line PORV Setpoint at 1035 PSIG using Status Board BOP Verify RCS Temperature Less Than 547°F Prior to MSIV Closur e

BOP Close Ruptured SIG MSIV and MSIV Bypass BOP Ruptured S/G MSIV and MSIV Bypass Closed (YES)

Continuous Action Step BOP When Ruptured SIG Pressure lowers Below 1035 PSIG THEN Verify Ruptured Steam Line PORV Closed BOP IF MDAFW Pump is not Available, THEN Maintain at least One S/G supply to SDAFW Pump BOP Close Ruptured SIG Steam Shutoff to SDAFW Pump BOP Verify SIG Blowdown Isolation and Sample Valves Closed BOP Locally Close Warmup Steam Supply From Ruptured SIG to SDAF W

Pump Booth Operator Close Warmup Steam Supply Valve (MS-38) and Report action 3

Minutes after requested BOP Locally Close MSIV Above and Below Seat Drains from Ruptured SIG Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 2 Event # 8 and 9 Page 35 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C S/G PORV fails OPEN / Tube rupture size rises.

Time Position Applicants Actions or Behavior Booth Operator Report Above and Below Seat Drains are closed 3 Minutes after requested BOP Isolate Feed Flow to Any Ruptured SIG that is Faulted Unless Needed for RCS Cooldown Continuous Action Step BOP When Ruptured S/G Level Greater Than 8% [18%] THEN Isolate Feed Flow Continuous Action Step BOP Open Breakers for any V1-8, V2-14 AND V2-16 Valve Closed to Isolate Ruotured SIG Booth Operator Wait 3 minutes to Open Breakers as requested and report action complete.

BOP Control Feed Flow to Maintain Intact SIG Level Between 8% [18%]

and 50%

BOP Any Other S/G with Uncontrolled Level Rise (NO)

RO PZR PORVs Closed (YES)

RO Open At Least One PORV Block Unless Closed to Isolate an Open PZR PORV Continuous Action Step RO IF PZR PORV Opens on High Pressure, THEN Verify Reclosure at or Below 2335 PSIG. Close PORV Blocks as Necessary Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 36 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN / Tube rupture size rises.

Time I - Position I ApIicants Actions or Behavior RD Reset SI Continuous Action Step RD/BC P IF Dffsite Power is Lost, THEN Restart Emergency Safeguard Eciuiiment RD Reset CV Spray RD Reset Phase A and Phase B RD Establish Instrument Air to CV. IF Compressor not Running, THEN Start Compressor BOP All AC Busses Energized by Dffsite Power (YES)

RD RCS Pressure Greater Than 275 PSIG [400 PSIG] (YES)

RD Stop RHR Pumps Continuous Action Step RD IF RCS Pressure Lowers Below 275 PSIG [400 PSIG], THEN Restart RHR Pumps Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 2 Event # 8 and 9 Page 37 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manual reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior Ruptured SIG Isolated (YES)

The following must be Isolated to satisfy isolation:

-V1-3C, MSIV

- MS-353C, MSIVV1-3B BYP

- FRV C (Not needed if V2-6C closed.)

- FRV C BYP Critical - V2-6C, FW HDR SECTION (Not needed if FRV and FRV BYP Task BOP closed.)

- V2-14C, SDAFW PUMP DISCH Valve

- V2-1 6C, AFW HDR DISCH Valve

- V1-8C, SDAFW STEAM SHUTOFF Valve

- S/G C Blowdown AND Blowdown Sample Valves

- MS-38 (No indication in Control Room)

- S/G C MSIV Above and Below Seat Drain Valves (No indication in Control Room.

BOP Ruptured S/G Pressure Greater Than 220 PSIG (YES)

BOP At Least One Intact S/G Available for RCS Cooldown (YES)

NOTE: After the Low Steam Line Pressure SI Signal is Blocked, Main RO/BOP Steam Line Isolation will occur if Hi Steam Line Flow Rate Setpoint is Exceeded Determine Required Core Exit Temperature From Table-3 Table 3 -

Ruptured S/G Pressure (PSIG) Required Core Exit Temperature RO/BOP Greater than 1000 490 [470]

900-1000 480 [460]

800-899 465 [445]

700-799 450 [430]

600-699 435 [415]

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 38 of 47 Event

Description:

C S/G Tube Rupture when RCP C is secured following manua l reactor trip. 2 minutes after SI initiation, C S/G PORV fails OPEN I Tube rupture size rises.

Time Position AoDlicants Actions or Behavior Continuous Action Step RO When PZR Pressure Lowers to Less Than 2000 PSIG, THEN Block PZR Pressure/High Steam Line DP Signals RO IF RCPs are NOT Running, THEN Do Not Monitor CSF-4 Examiner Note: Steam Dumps may be available if the MSIVs were left open on the intact S/Gs. If this is the case then the cooldown will be perform ed via the steams dumps vice the Steam Line PORVs.

BOP Condenser Available For Steam Dump (NO)

RO Verify T-AVG less Than 543°F AND Block T-AVG SI Signal Prior to Maximum Steam Dump BOP Dump Steam Using Intact Steam Line PORV Maximum Rate.

- AFW flow may need to be raised.

RO At Least One Charging Pump Running (YES)

RO Align Charging Pump Suction To RWST RO Establish Charging Flow to Maintain PZR Level Core Exit Temperature Less Than Required Temperature (NO)

RO (PATH-2 begins a loop until CET is less than Required Temperature)

BOP Reduce Steam Flow to Stabilize RCS Temperature Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 39 of 47 Event

Description:

C SIG Tube Rupture when RCP C is secured following manua l reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior CREW Allow RCS Temperature to Stabilize from cooldown prior to continu ing BOP Ruptured SIG pressure stable or rising (NO)

BOP Ruptured SIG Pressure lowers to less than 250 psig above pressure of intact S/Gs used for cooldown. (YES)

SRO Transition to EPP-17.

SRO Open Foldout E (No steps apply.)

RO Reset SAFETY INJECTION RO Reset CONTAINMENT ISOLATION PHASE A AND PHASE B Continuous Action Step BOP Check Loss Of Offsite Power IN PROGRESS (NO)

Continuous Action Step Establish Instrument Air To CV As Follows:

. Check APP-002-F7, INSTR AIR HDR LO PRESS RO EXTINGUISHED (YES)

. Momentarily place IA PCV-1716, INSTRUMENT AIR ISO TO CV Switch, to RESET

.__Check_INST AIR VALVE TO_CV PCV-1716 OPEN_(YES)

Continuous Action Step RO Determine If CV Spray Should Be Stopped As Follows:

.__Check_CV Spray_Pumps _RUNNING_(NO)

Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 40 of 47 Event

Description:

C S/G Tube Rupture when RCP C is secured follow ing manual reactor trip. 2 minutes after SI initiation, C S/G PORV fails OPEN I Tube rupture size rises.

{[ Position IL Applicants Actions or Behavior Continuous Action Step Control Ruptured SIG Level As Follows:

BOP

. Check ruptured SIG level LESS THAN 8% [18%] (NO)

• __Stop_feed_flow_to_ruptured_S/Gs.

Continuous Action Step Determine If RHR Pumps Should Be Stopped

a. Check RCS pressure:

R . GREATER THAN 275 PSIG [400 PSIG} (YES)

AND

. STABLE Q INCREASING

b. Verify RHR Pumps Stopped

c. Check RCspressure Less than 275 sia 1400 PSIG1 (NO)

Initiate Evaluation Of Plant Status:

a. Check Auxiliary Building radiation monitors NORMAL (YES)

b. Contact Chemistry to obtain the following periodic samp les:

RD

• RCS for boron and activity

• Ruptured S/G(s) for boron

• Pressurizer for boron

c. Contact Plant Operations Staff to determine additional actio ns to evaluate_plant_status,_while_continuing_with_t his_procedure Establish Charging Flow As Follows:

RD

• Check Charging Pumps ALL STOPPED (NO)

• __Verify_charging_flow_on_FI-122A _Greater than_35_GPM Align Charging Pump Suction To RWST as follows:

a. From the RTGB, verify LCV-1 1 5B, EMERG MU TO CHG SUCT OPEN -

RD b. Verify LCV-1 1 5C, VCT OUTLET CLOSED -

c. Start all available Charging Pumps

d. Increase running Charging Pumps speed to maximum

e. Verify maximum charainc flow on Fl-I 22A (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 41 of 47 Event

Description:

C S/G Tube Rupture when RCP C is secured following manua l reactor trip. 2 minutes after SI initiation, C SIG PORV fails OPEN I Tube rupture size rises.

Time Position Applicants Actions or Behavior Identify Faulted S/Gs As Follows:

a. Check pressure in all S/Gs:

BOP . ANY SIG PRESSURE DECREASING IN AN UNCONTROLLED MANNER (YES)

OR

. ANY SIG COMPLETELY DEPRESSURIZED (NO)

BOP Check Faulted S/Gs PREVIOUSLY ISOLATED (YES)

Control Intact SIG Levels As Follows:

. Check intact S/G levels ANY GREATER THAN 8% [18%]

BOP . Control feed flow to maintain intact S/G levels between 8%

[18%] and 50%

• Check intact S/G levels ANY INCREASING IN AN UNCONTROLLED MANNER (NO)

Continuous Action Step RO Ensure Adequate Shutdown Margin Exists As Follows:

. Check boron sample results AVAILABLE (NO)

Initiate RCS Cooldown To Cold Shutdown As Follows:

. Maintain cooldown rate in RCS cold legs less than 100°F in the last 60 minute

. Maintain RCS temperature and pressure within limits of Curve BOP 3.4, Reactor Coolant System Pressure Temperature Limitations For Cooldown

. Check intact S/Gs AT LEAST ONE AVAILABLE FOR RCS COOLDOWN (YES)

. Check steam dump to Condenser Available (NO)

.__Dump_steam_using_Steam_Line_PORVs The Chief Examiner may terminate the scenario anytime after the RCS cooldown has been commenced or at his discretion.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 42 of 47 Event

Description:

Isolation of S/G C lAW Supplement G Time Position Arplicants Actions or Behavior IJ SUPPLEMENT G Steps SRO Directs the BOP to perform Supplement G to isolate S/G C

Go To Appropriate Step From Following Table:

BOP I S/G TO BE ISOLATED STEP S/GC 134 BOP Check S/G C FAULTED (YES).

BOP Verify V1-3C, MSIV CLOSED (YES)

BOP Verify MS-353C, MSIV V1-3C BYP CLOSED (YES)

BOP Verify FRV C Closed (YES)

BOP Verify FRV C BYP Closed (YES)

BOP Verify V2-6C, FW HDR SECTION Valve CLOSED. (YES)

BOP Verify V2-14C, SDAFW PUMP DISCH Valve CLOSED. (YES)

BOP Verify V2-16C, AFW HDR DISCH Valve CLOSED. (YES)

BOP Verify Steam Line PORV CLOSED (NO)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 43 of 47 Event

Description:

Isolation of SIG C lAW Supplement G Time N Position I Applicants Actions or Behavior IF the PORV will NOT close from the RTGB, THEN isolate air via one of the methods below:

• Close BOTH isolation valves for the individual controller:

BOP o IA-3273, IA TO PIC-497 UPPER I/P o IA-3274, IA TO PIC-497 LOWER I/P OR

• Close lA-298, IA to PORVs (Before Dryer)

BOP Verify V1-8C, SDAFW STEAM SHUTOFF Valve CLOSED. (YES)

BOP Verify SIG C Blowdown AND Blowdown Sample Valve Status Liqht Indication CLOSED (YES)

Dispatch Operator to the Pipe Jungle to Close MS-38, SG C Bypass BOP Drn & Warm-up Line to AFW Pump Booth Operator Close Warmup Steam Supply Valve (MS-38) and Report action 3 Minutes after requested Check S/G C MSIV Above And Below Seat Drain Valves CLOSED BOP (YES)

Booth Operator Report Above and Below Seat Drains are closed 3 Minutes after requested.

Dispatch Operator To The E-IIE-2 To Perform The Following:

• At MCC-9, verify V2-1 6C closed AND open breaker V2-1 6C, BOP MDAFW PUMP HEADER DISCHARGE TO S/G C (CMPT-3J)

• At MCC-6, verify V1-8C closed AND open breaker V1-8C, SDAFW PUMP STEAM ISOLATION (CMPT-18M)

Dispatch Operator To The Aux. Bldg. To Perform The Following:

BOP

• At MCC-10, verify V2-14C closed AND open breaker V2-14C, SDAFW PUMP TO_S/G_C_(CMPT-4M)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 8 and 9 Page 44 of 47 Event

Description:

Isolation of SIG C lAW Supplement G Time Position Applicants Actions or Behavior Booth Operator Wait 3 mfnutes to Open Breakers as requested and report action complete.

BOP Check All Faulted AND Ruptured SIGs ISOLATED (YES)

WHEN the faulted S/Gs dry out, THEN dump steam from intact SIG to BOP control RCS repressurization.

BOP Check Any S/G RUPTURED (YES)

BOP Perform the following to minimize Secondary system contamination:

. Direct AC to start Auxiliary Boilers.

. IF Condensate Polishers are in service:

. Verify QCV-1 0426, SECONDARY BYPASS OPEN. (YES)

. Locally depress the OFF Pushbutton on Condensate Potisher Vessels A, B, C, D, E and F.

. Secure ANY evolution that passes water through the beds, such as a low volume rinse.

BOP Verify Hotwell return to CST isolated as follows:

• Locally verify C-48A, LCV-1417B INLET CLOSED.

. Locally verify C-48B, LCV-1417B DISCHARGE LOCKED -

CLOSED.

Dispatch An Operator To Close GS-36, MANUAL GLAND STEAM BOP DUMP.

End of Supplement G Steps Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # Conditional Page 45 of 47 Event

Description:

Seal Failure on C RCP Time j Position Applicants Actions or Behavior This section is to address a Seal Failure on C RCP due to the Operator not tripping C

RCP within 5 minutes of reachinq 20 mils vibration on C RCP.

RO/BOP Make PA Announcement for Procedure Entry Evaluate Plant Conditions AND Go to the Appropriate Section for RCP RO/BOP Malfunction Not Yet Addressed: Reactor Coolant Pump Seal Failure Section A RO/BOP Check any RCP #1 Seal Leakoff Flow Greater than 5.7 GPM (YES)

Check Either of the following Conditions Exist:

. RCP #1 Seal Leakoff flow On Unaffected RCP(s)

RO/BOP Reduced (YES)

OR

. RCP Thermal Barrier zP On Affected RCP(s) Reduced -

(YES)

RO/BOP Check Plant Status Mode 1 OR Mode 2 (YES)

a. Trip the reactor RO/BOP b. Trip the affected RCP(s).

c. Go to Path-i while continuing in AOP-018.

Check Time Elapsed since stopping the affected RCP(s) Greater RO/BOP Than 3 Minutes (NO)

RNO: When at least 3 minutes elapsed since tripping the affected RCP(s), THEN go to step 6.

RO/BOP Close Seal Leakoff Valve(s) for affected RCP(s): CVC-303C Check SI Actuated (Conditions will be degrading such that an SI will RO/BOP be required.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # Conditional Page 46 of 47 Event

Description:

Seal Failure on C RCP Time Position Aoplicants Actions or Behavior Establish Instrument Air to CV as follows:

a. Check APP-002-F7, INSTR AIR HDR LO PRESS EXTINGUISHED (YES)

RO/BOP b. Reset SAFETY INJECTION

c. Reset CONTAINMENT ISOLATION PHASE A

d. Momentarily place IA PCV-1716 to RESET position

e. Check PCV-1716 OPEN (YES)

RO/BOP Check RCP(s) B OR C Running (YES)

RO/BOP Check RCP B Running (YES)

Check RCP C- Running (NO)

RNO:

RO/BOP a. Place PCV-455B Controller to MAN AND adjust controller output to ZERO.

b. Maintain PZR level between 30% and 40% to provide adequate PZR spray.

Check RCP Seal Injection Flow Between 8 GPM and 13 GPM.

RNO RO/BOP

a. Locally throttle CVC-297A,B,C to obtain between 8 13 gpm.

b. IF required the maintain minimum flow, THEN throttle HIC-121.

RO/BOP Check FCV-626, THERM BAR FLOW CONT VALVE Closed (NO)

RO/BOP Implement EALs Appendix D NUREG-1 021, Rev. 9, Supp. 1

ILC-11-2 NRC SCENARIO 2 TURNOVER SHEET POWER LEVEL: 75% RTP Core Burnup: 9000 MWD/MTU EFPD: 257 EFPD Boron: 775.5 PPM Xenon: Approaching EQ 22 pcm/hr and lowering Tavg: 567.5°F Bank D Rods 183 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW Pump QOS and Breaker Racked Out

• Switchyard access is RESTRICTED.

EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• Plant is at 75% power following maintenance on A HDP. Operations Management and RES have reported unusually high vibrations on A MFP and recommend a power reduction be performed and A MFP secured as soon as possible.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board IDate: Todav iTime: 6:00:00 AMICvcle: 27 IEFPD IMWD/MT: 9000 JDes 16590 257 jDesign 473.5 I HUT Tank Level%

Level % Status Status CVCS-A Monitor A 10 Standby CVCS 1 -B Monitor B 138 ndb Standby cVcS-c -

86 JStandby Standby WHUT WCTB 7

1. NAME?Ti Standby lii WTfl Standby Data Linked to P1 WCTD 10 Standby WCT F 9 WGDTS Pressure PSIG Standby Status A #NAME? -

PSIG On cover DEMINERALIZERS 8#NAME? PSIG )n Service PPM In Service Date Resin C IPSIG Isolated pced MBA 1 2194 0 YES 711712010 5/4/2010 MB B 2265 NO 7/17/2010 3/29/2010 CATION M021J9/17/2012/9/2009 Shutdown Requirement Temp Boron DEBA 0 1.77% =LK/K NO New 213/2010 547 F Hot 795 DE O

2 8

1.77%=AK/K lO BB h

>350 F 1053 SFP 2.6% KIK 1963 i9/23I2008412/200i

- 100 F Cold - 1182 6% LK/K N/A 1950 SGBD Condenser Air Inleakage Target Value GPM PORV Settings Status A 13 CFM A Setting Date POT GP-3 Psig -

50 Flash Tank B __jCFM B 50 With Heat Known ,8 C Recovery Total 5 CFM N2 Flow C 7118/2010 3.44 8 SCFM 1000 Effluent Radiation Monitor Setpoints RCS Leakage Rad 0.00 Unidentified Current Alert Value 200X NUE Value Monitor Setpoint Total 0.03 2X GPM R-14C 1.OIE+04 PRT NIA 2.020E+04 To.02 GPM R-20 7.40E+03 NIA RCDT Leakage .480E+04 R-18 I .OOE+06 2.000E+08 Charging_Leakoff I 2.000E+06 R-19A 1.05E+04 2.IOOE+06 Misc Identified 0 2.IOOE+04 GPM R-19B 9.72E+03 Primary/Secondary -

R-19C 9.58E+03 1.916E+06j I .916E+04 Secondary Loss R-37 B 5

F 3

E O

7 6 + I3 O . .

1.706E+04 Manually Entered Data Linked to Chem data base lii Flux At Shutdown Boron PPM Date PPM Date jvious ARI Counts Setpoint PPM NI-31 RCS Today 775.5 150 Nl-32 BAST-AJ9/16/2010t535 #NAME?

° 180 #NAME?

BAST-B 9/1612010 21,032 #NAME? #NAME?

i9/15/2010 2246 #NAME?

Normal Currents 1#NAME?

RWST 9/16/2010 219 #NAME? #NAME?

UPPER LOWER TARGET  % BAND N-41J 119 8/30/2010 2211 #NAME??

-1.5 5+!- Accum-B 8/30I2010 2206 N-42 110 1iJ-1.5 #NAME? #NAME?

5+,- AT8I3oI2o1o 2230 N-43 99i-1.5 #N 1 NA AM ME E? ?

5 +1- RHR 71612010 N-44i9 2221 45 POWERTRAX Rev# 2.1.0 RNP 1% APL 112.55 Refuel Cavity SFP Canal FANS Test/Hrs LDate/Tst HVE-IA/B 35640.6 j3/8/I0 Notes/Additional Data HVE-15A 118643.5 3/18/10 lC-13, 42 HVE-19A/B T6928.3 J5/3/10 SR 3.7.11.2 Last Completed MOL 5/27/2010 19:45 I I

ILC-11-2 NRC SCENARIO 2 TURNOVER SHE ET POWER LEVEL: 75% RTP Core Burnup: 9000 MWD/MTU EFPD: 257 EFPD Boron: 775.5 PPM Xenon: Approaching EQ 22 pcm/hr and lowering Tavg: 567.5°F Bank D Rods 183 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW Pump OOS and Breaker Racked Out

• Switchyard access is RESTRICTED.

EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darl ington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• Plant is at 75% power following maintenance on A HDP. Operations Management and RES have reported unusually high vibrations on A MFP and recommend a power reduction be performed and A MFP secured as soon as possible.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board IDate; Today ITime: 6:00;00AMICycle: 27 IMWDIMT:

IEFPD 257 9000 IDesign: 16590 IDesian 473.5 I HUT Level % Tank Level %

Status Status CVCS-A 20 Monitor A 10 Filling Standby CVCS-B 10 Mon itor B 38 Standby Standby CVCS-C 86 WCT A 37 Standby Standby WHUT #NAME? WCTB 7 Filling Standby WCT C 9 Standby Data Linked to P1 WCTD 10 Standby WGDTS jPressure PSIG wj Standby Status A #NAME? PSIG On cover DEMINERALIZERS B #NAME? IPSIG In Service PPM .

Iln Service Date Resin C #NAME? PSIG Isolated j Replaced D MB A J2194 jYES

1. NAME? PSIG Standby 7117/2010 5/4)2010 MB B 2265 NO 7/17)2010 3/29/2010 Shutdown Requirement CATION 1021 NO Temp 9/17/2010 J12I912009 Boron DEBA 0 1.77% =tMQK NO New 2(3(2010 547 F Hot 795 DEBB 1.77%=LK/K 0 NO 3/28(2010 350F 1053 2.6% =LK/K SFP 1963 100 F Cold 912312008 4/2212008 1182 6%=K/K NIA 1950 SGBD Condenser Air Inleakage Target Value GPM PORV Settings Status A 13 ICFM Setting Date POT A (50 Flash Tank IGP-3 Psig B 0 A 7(18(2010 3.21 CFM B 50 With Heat tiooo Known 8 B 7/18(2010 T3.12 CFM Recovery J1040 Total C 5 CFM N2 Flow 7/1812010 3.44 (8 SCFM L1000 Effluent Radiation Monitor Setpoints RCS Leakage Rad 0.00 Unidentified .

Current Alert Value 200X NUE Value Monitor .

Setpoint Total 0.03 2X 10PM R-14C 1.OIE+04 PRT N/A 2.020E+04 0.02 10PM R-20 7.40E+03 N/A RCDT Leakage 0.01 1.480E+04 GPM R-18 Charging Leakoff 1.OOE+06 2.000E+08 2.000E+06 0 GPM R-19A Misc Identified 1.05E+04 2.IOOE+06 2.IOOE+04 0 GPM R-19B Primary/Secondary 9.72E+03 1.944E+06 [1.944E+04 0 GPD R-19C 9.58E+03 I .916E+06 Secondary Loss 17.3 GPM I .916E+04 R-37 8.53E+03 1 .706E+06 1.706E+04 Hi Flux At Shutdown Manually Entered Data Linked to Chem data base Previous ARI Counts Boron PPM Date (PPM Date Setpoint PPM Nl-31 RCS Today 775.5 50 150 Nl-32 60 BAST-A 9/16/2010 21,535 #NAME?

180 #NAME?

BAST-B 9(16/2010 21,032 #NAME? #NAME?

SFP 9)15/2010 2246 #NAME?

Normal Currents #NAME?

RWST______ 9/16(2010 2219 #NAME?

UPPER LOWER TARGET #NAME?

%BAND Accum-A N-41 125 8/30/2010 2211 #NAME? #NAME?

119 -1.5 5 i-I N-42 Accum-B 8/30/2010 2206 #NAME?

110 (109 -1.5 #NAME?

5÷!- Accum-C N-43 105 99 8/30/2010 2230 #NAME? #NAME?

-1.5 5 +1- RHR N-44 98 7I6/2010 2221

-1.5 5+1- Refuel Canal POWERTRAX Rev# 2.1.0 RNP  % APL 112.55 Refuel Cavity SFP Canal FANS TestlHrs DatelTst HVE-IA/B 35640.6 3(8/10 HVE-ISA Notes(Additional Data 18643.5 3/18(10 HVE-19A)B lC-13, 42 6928.3 5/3/10 SR 3.7.11.2 Last Completed MOL 5/27/2010 (19:45 I

Appendix D Scenario Outline Form ES-D-1 Facility: HB ROBINSON Scenario No.: 4 Op Test No.:

Examiners: Operators: SRO -

RO BOP Initial Conditions:

• 1E-8 amps BOL, 150 MWD/MTU, 1531 ppm Boron

. Currently thunderstorm watch is in effect for Darlington and Chesterfield counties Turnover:

• Raise Reactor Power to the POAH and continue with plant startup Critical Tasks:

• Open either SI injection valve SI-870A or Sl-870B

• Establish Containment Isolation

• Align CR ventilation to pressurization mode Event Maif. Event Type* Event No. No. Description 1 Withdraw controls rods to POAH (N) SRO (C) BOP, SRO 2 B CCW Pump Trips and FCV-626 closes (TS) SRO (C) BOP, SRO 3 North SW Header break at the intake structure (TS) SRO 4 (TS) SRO Failure of N-35 Compensation Voltage 5 (C) RO, SRO Leak on CC-703B at 25 gpm and rises to 750 gpm 6 (M) ALL Large Break LOCA on Reactor Trip (C) RO SI-870A and B fail to open on SI signal (C) RO FP-248, 249, 256 and 258 fail to close on CIV signal (C) BOP Control Room Ventilation fails to transfer to pressurization mode (C) RO Stop CV Spray Pump(s) and Close Discharge Valve(s)

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG-1 021, Rev. 9, Supp. 1

I Appendix D Scenario Outline Form ES-D-1 ILC-11-2 NRC SCENARIO 4

SUMMARY

DESCRIPTION The crew will assume the watch with the plant at 1 E-8 amps. GP-005, Power Operation, has been completed up to Step 8.2.2. Shift instructions are to adjust contro l rod position as necessary to raise reactor power to the POAH in anticipation of continu ing with plant startup.

Once the Chief Examiner is satisfied with the control of the reactor and RCS temperature is stable, the Chief Examiner may cue the next event.

On cue from the Chief Examiner, B CCW Pump will trip, CCW Pumps A and C will auto start on low pressure and valve FCV-626 will close. The crew will take actions lAW APP-001-F4 orCl and reopen FCV-626. The SRO will direct entry into ITS LCO 3.7.6, Condition A, for one required CCW train being inoperable. The LCO requires that the inoperable CCW train be restored to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The crew may take actions lAW OP-306 to secure one of the two operating CCW pumps.

On cue from the Chief Examiner, the North Service Water Header will experie nce a break at the intake structure on the SW piping downstream of SW-8, SW Pump D Discharge Valve. The crew will take actions lAW AOP-022, Loss of Service Water, and will isolate the ruptured header and disable the service water pumps on the isolated header. This will result in the affected Emergency Diesel Generator being declared inoperable due to all the service water pumps supporting that EDG being disabled. The SRO will declare entry into ITS LCO 3.7.7, Condition A, due to one SW train inoperable. This LCO requires that the inoperable SW train be restored to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The SRO will also declare entry into ITS LCO 3.8.1, Condition B, which requires the following: (1) Perform SR 3.8.1.1 for offsite circuit within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter (OP-604, Section 8.4.9, Emergency Diesel Generator Inoperability), (2) Declare required feature(s) supported by the inoperable DG inoperable when its required redundant feature(s) is inoperable within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discov ery of Condition B concurrent with inoperability of redundant required feature(s), (3) Determine Operable DG is not inoperable due to common cause failure within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and perform SR 3.8.1.2 for Operable DG within 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> and, (4) restore DG to Operable status within 7 days OR be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />. Due to CCW Pump B being inoperable and EDG B being declared inoperable due to all of its supporting Service Water Pumps being disabled, ITS 3.8.l.B.2 requires that CCW Pump C be declared inoperable within the next four hours. This will place the plant in LCO 3.0.3 due to not meeting ITS 3.7.6 for CCW System operability requirements. Once the Chief Examiner is satisfied with the stabilit y of the plant and ITS compliance he may cue the next event.

On cue from the Chief Examiner, N-35, Intermediate Range NI, will experie nce a loss of compensation voltage and APP-005-B2, N35 Loss of Comp Voltag e, will be received. The APP will direct the crew to remove N-35 from service lAW OWP-0l 1, NI-7.

ITS Table 3.3.1-1, Item 3, Intermediate Range Neutron Flux, Condition F, Thermal Power> P-6 and

< P-b, requires that thermal power be reduced to less than P-6 or increased to greater than P-b within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. N 36 will be selected to provide SUR signal by repositioning the Start Up Rate Channel Select switch. Once OWP-01 I has been briefed, the crew may begin briefin g GP-006 to reduce power to less than P-6 to meet the 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ITS requirement. Once the Chief Exami ner is satisfied with the ITS compliance he may cue the next event.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-l On cue from the Chief Examiner, a leak will develop on the downstream side of CC-703B Pump B Discharge Valve, at a rate of 25 gpm , CCW

. The crew will take actions lAW AOP-014, Component Cooling Water System Malfunction, Section A, Loss of CCW Inventory. AOP-014 will direct the crew to commence making up to the CCW surge tank in an effort to maintain normal surge tank control band and dispatch operators to perform a CCW Leak Search.

the CCW Surge Tank level has been stabilized Once and operators dispatched to search for leaks leak will rise to 750 gpm over a 5 minute time the period. The crew will make efforts to maintain surge tank level by starting a second primary water pump. Eventually, it will be determine the CCW Surge Tank level cannot be maintaine d that d and the crew will initiate a reactor trip, stop RCPs and go to PATH-i while continuing with all AOP-014.

On initiation of the manual reactor trip the plan t will experience a Large Break LOCA. The will implement PATH-i due to the reactor trip crew and safety injection. Manual actions will have be taken to open either SI-870A or SI-870B since to neither automatically opens on the SI signal.

The operators must also identify that FP-248, 249, 256 and 258 fail to close automatically on CIV signal and must be manually closed. The the operators must identify that CR ventilation does not transfer to pressurization mode and mus t be manually realigned. The Turbine Building equipment will be secured in accordance with Supplement M, Component Alignment for Loss SW to Turbine Building, due to service water of being isolated to the turbine building as direc PATH-i due to the North SW Header low press ted by ure alarm being illuminated. FRP-P.i, Response to Imminent Pressurized Thermal Shock, will be entered due to the rapid RCS depressurization and cooldown but exited due to the presence of a Large Break LOCA. Due the loss of N-35, Source Range NIs will have to to be manually energized. The crew will eventually transition to EPP-1 5, Loss of Emergen cy Coolant Recirculation, due to having no CCW pumps available to provide cooling to the ECCS equipment. EPP-15 will direct actio make up to the RWST using Supplement P, Eme ns to rgency Makeup to the RWST and eventually reduce ECCS flow to minimize the demand on the RWST.

The scenario may be terminated once direction is given to secure one SI Pump and one RHR Pump and/or at the Chief Examiners discretion Appendix D NUREG-iO2i, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 ILC-11-2 NRC SCENARIO 4 SIMULATOR SETUP ICISETUP:

• IC-804, SCN: 008_i i_2_NRC_Exam_4

• Status board updated to reflect IC-i PRE-LOADED EVENTS:

The following events should occur on the reactor trip:

Event 6: Large Break LOCA on Reactor Trip SI-870A and B fail to open on SI signal FP-248, 249, 256 and 258 fail to cose on CIV signal Control Room Ventilation fails to transfer to pressurization mode EVENTSITRIGGERS INITIATED DURING THE SCENARIO:

Event 1: Withdraw controls rods to POAH Event 2: B CCW Pump Trips and FCV-626 closes Event 3: North SW Header break at the intake structure Event 4: Failure of N-35 Compensation Voltage Event 5: Leak on CC-703B starts at 25 gpm and rises to 750 gpm EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

• GP-005

• OP-306

• AOP-022

• OP-604, Section 8.4.9

• APP-005-B2

• OWP-OI1,Nl-7

• GP-006-1

• AOP-014, Main Body, Section A, Attachment I and Attachment 3

• PATH-I

• Foldout A

• Supplement M

• FRP-P.I Foldout B EPP-15 Supplement P Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 1 Page 5 of 37 Event

Description:

Withdraw control rods to the POAH Time Position Applicants Actions or Behavior BOOTH OPERATOR: Event I involves the withdrawal of control rods to the POAH lAW GP-005, Power Operation.

EVENT INDICATIONS:

None IF additional letdown flow is desired, THEN PERFORM the following lAW OP-301 section for Charging and Letdown Operations with Normal Pressurizer Level:

RO

• START additional Charging Pumps as necessary.

• PLACE additional letdown orifice in service ENERGIZE all available Pressurizer heaters to equalize boron concentration in the Pressurizer.

FO

- PZR HTR CONTROL GROUP

- PZR HTR BACK-UP GROUP A

- PZR HTR BACK-UP GROUP B NOTE: The Point Of Adding Heat (POAH) is that power level identified by NO control rod motion and:

• If MTC is negative, then SUR will be LOWERING

• If MTC is positive, then SUR will be RISING

• Onset of RCS temperature rise, Onset of PZR pressure rise, Onset of PZR level rise, Reduction in AUTO Charging Pump speed demand.

• Rising indication of AUTO Steam Dump demand on PC-464B, Steam Header Pressure, when Steam Dumps are being used for RCS Temperature Contro l.

• Small rise in Steam Generator Steam flow.

CAUTION Startup Rate shall not exceed 1 .0 dpm. Maximum Reactor power is 5%.

The Point Of Adding Heat should be approached slowly and cautiously.

When the MSIVs are closed, heat removal capability of the Main Steam Line drains is limited RO ADJUST Control Rod position as necessary to establish a positive SUR AND RAISE reactor power to the POAH.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 1 Page 6 of 37 Event

Description:

Withdraw contro rods to the POAH Time Position I Applicants Actions or Behavior ADJUST control rods as necessary to achieve the following while continuing with this procedure:

RO RCS Tavg between 547°F and 551 °F

• Maintain Reactor Power 5%.

WHEN Reactor power is greater than 1%, THEN NOTIFY Reactor SRO Encuneergjo COMMENCE Ioaaina data required by EST-067.

Booth Operator Insert Event #2, B CCW Pump trips and FCV-626 closes, on cue from the Chief Examiner.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 2 Page 7 of 37 Event

Description:

B CCW Pump trips and FCV-626 closes Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 2 B CCW Pump trips and FCV.-626 closes EVENT INDICATIONS:

B CCW Pump has dual indication A and C CCW Pumps auto start APP-OO1-A8, CCW TO CRDM LO FLOW APP-OO1-B1, RCP BRG COOL WTR LO FLOW APP-OO1 -Cl, RCP THERM BAR COOL WTR HI FLOW APP-OO1-D1, RCP THERM BAR COOL WTR LO FLOW (Locked in)

APP-DO1-F4, CCW PMP MOTOR OVLDITRIP (Locked in)

APP-OO1-F5, CCW PMP LO PRESS APP-002-E5, SI PMP COOL WTR LO FLOW APP-OO1 -F4 actions RO IF alarm is due to intentional operator actions, THEN no further actions required.

APP-OO1 -F4 actions RO IF the running CCW Pump has tripped, THEN VERIFY Standb y CCW Pump STARTED.

APP-OO1 -F4 actions RO IF Standby CCW Pump can NOT be started, THEN REFER TO AOP 014 (A and C CCW Pumps auto started on low pressure signal)

APP-OO1 -F4 actions IF FCV-626, THERM BAR FLOW CONT, closes due to pump start, THEN PERFORM the following:

RO

1) CHECK R-17 for increasing trends OR alarm.

2) IF no adverse trend on R-17, THEN REOPEN FCV-626.

APP-OO1 -F4 actions IF CCW Pump tripped due to electrical fault, THEN DISPA RO TCH an operator to check breaker and Current Limiter Fuses (E-1IE

-2 breakers only).

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 2 Page 8 of 37

[vent

Description:

B CCW Pump trips and FCV-626 close s

Time Position I Applicants Actions or Behavior Examiner Note: AOP-014 may be entered by the crew to address the event rather than usinq the APP actions. AOP-0 14 steps are listed below.

SRO Implement the EALs.

RO/BOP Make PA announcement for Procedure Entry.

SRO Go to Appropriate Section for Indicated Malf unction: Section C (CCW Pump Discharcie Pressure Low)

RO/BOP Check Spray AND Blackout Signal Actuated (NO)

Start Standby CCW Pump As Follows:

a. Check El AND E2 BUSSES ENERGIZ -

ED BY OFFSITE POWER (YES)

b. Start one CCW Pump (NO, two pum ps running.)

c. Check CCW Pump status AT LEA RO/BOP ST ONE RUNNING (YES)

d. Check APP-001-F5, CCW PMP LO PRESS EXTINGUISHED (YES)

e. Check FCV-626, THERM BAR FLOW CONT CLOSED DUE TO STARTING PUMP (YES)

f. Open FCV-626 (Operator opens FCV

-626)

g. Go to the MAIN BODY, Step 4, of this procedure.

RO/BOP Check RCS temperature LESS THAN 350° F (NO)

IF CCW HX outlet temperature is greater than 105°F, THEN go to step

3. (NO)

RO/BOP OR IF CCW HX outlet temperature is less than 105°F, THEN go to step 4.c. (YES)

RO/BOP Check CCW HX outlet temperature STABLE OR DECREASING (YES)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 2 Page 9 of 37 Event

Description:

B CCW Pump trips and FCV-626 closes Time Position Applicants Actions or Behavior RO/BOP Check APP-001-F5, CCW PMP LO PRESS EXTINGUISHED (YES)

Refer to Technical Specifications for Applicable LCOs T.S. 3.4.17 CVCS (N/A)

SRO T.S. 3.5.2 ECCS Operating (N/A)

T.S. 3.5.3 ECCS Shutdown (N/A)

T.S. 3.6.6 Containment Spray and Cooling Systems (N/A)

T.S. 3.7.6 Comionent Coolinci Water (CCW) System (See below)

APP-OO1 -Cl actions RO IF CCW AND Seal Injection are lost to any RCP, THEN REFER TO AOP-018.

APP-OO1-C1 actions RO IF result of CCW Pump start only, THEN REOPEN FCV-626.

Direct entry into ITS LCO 3.7.6, Condition A, for one required CCW SRO train inoperable. LCO requires that the inoperable CCW train be restored to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

Booth Operator When Tech Specs are identified and at Chief Examiners discretion, proceed to Event #3.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3 Page 10 of 37 Event

Description:

North Service Water Header break at the Intake Structure.

Time I Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 3, North Service Water Header break at the Intake Structure EVENT INDICATIONS:

APP-008-F7, SOUTH SW HDR LO PRESS APP-008-F8, NORTH SW HDR LO PRESS APP-008-E7, S SW HDR STRAINER PIT HI LEVEL APP-008-E8, N SW HDR STRAINER PIT HI LEVEL APP-008-D7, S SW HDR STRAINER PIT HI-HI LVL (Delay ed)

APP-008-D8, N SW HDR STRAINER PIT HI-HI LVL (Delay ed)

P1-I 61 6, North SW Header pressure lowering P1-I 684, South SW Header pressure lowering Immediate Action Step Check the following alarms EXTINGUISHED:

. APP-008-E7, S SW HDR STRAINER PIT HI LEVEL (NO)

. APP-008-E8, N SW HDR STRAINER PIT HI LEVEL (NO)

BOP RNO Perform the following:

a. Close the following valves:

. V6.-12B

. V6-12C

b. Go To Section F.

BOP Verify PA announcement for procedure entry performed Verify SW X-CONN Valves - CLOSED BOP

• V6-12B

• V6-12C Evaluate Control Room Indications AND Perform Local BOP Inspections To Determine Source Of Flooding Prior To Continuing BOP Check Service Water Leak Location ON SOUTH HEADER (NO)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 4 Event # 3 Page 11 of 37 Event

Description:

North Service Water Header break at the Intake Structure.

Time Position I) Applicants Actions or Behavior Verify The Following

a. SW PUMP A - RUNNING BOP b. SW PUMP B - RUNNING

c. SW PUMP C - STOPPED

d. SW PUMP D - STOPPED Evaluate SW Header Pressure Indications As Follows:

. Check North SW Header pressure on P1-1616 BOP LOWERING (YES)

. Check South SW Header pressure on P1-1684 STABLE OR RISING (YES)

Examiners Note: With Service Water Pumps C AND D isolated, EDG B is inoperable. ITS 3.8.1 requires SR 3.8.1.1 to be performed within I iou r.

BOP Close V6-12D, SW NORTH HDR ISO Verify The Following Valves At The Intake Stru cture CLOSED:

BOP . SW-839

. SW-845 BOP Check Flooding Status STOPPED (YES)

BOP Check South SW Header Pressure On P1-1684

- GREATER THAN 40 PSIG (YES)

Remove Control Power Fuses From The Follo wing Breakers At 480V BOP Bus E-2:

. SERVICE WATER PUMP C (CMPT-24A)

. SERVICE WATER PUMP D (CMPT-25B)

Determine If A SW Booster Pump Should Be Started:

BOP a. Check SW Booster Pumps ALL STOPPED (NO)

RNO a. Verify only ONE SW Booster Pump is running (YES)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3 Page 12 of 37 Event

Description:

North Service Water Header break at the Intake Structure.

Time Position Aoolicants Actions or Behavior BOP Check Circulating Water Pump Status ANY RUNNING (YES)

Determine If Adequate Seal Water Is Available To Circulating Water Pumps As Follows:

. APP-008-E4, CW PMP A SEAL WTR LOST EXTINGUISHED BOP (YES)

• APP-008-E5, CW PMP B SEAL WTR LOST EXTINGUISHED (YES)

• APP-008-E6, CW PMP C SEAL WTR LOST EXTINGUISHED (YES)

Determine Maximum Allowable CCW Temperature As Follows:

a. Check RCS temperature LESS THAN OR EQUAL TO 350°F RO (NO)

RNO Maintain CCW Heat Exchanger outlet temperature indicated on TI-607 less than or equal to 105°F.

Perform The Following:

a. Inspect the area of the leak SRO b. Report findings to the Control Room

c. Identify and isolate the source of the SW leak SRO Contact Maintenance To Install Temporary Pumps To Dewater Service Water Pits Contact Engineering To Perform The Following:

SRO

• Evaluate operability of equipment affected by flooding

• Provide corrective actions for flooding Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 3 Page 13 of 37 Event

Description:

North Service Water Header break at the Intake Structure.

Time Position Applicants Actions or Behavior The SRO will declare entry into the following LCOs:

ITS LCO 3.7.7, Condition A, due to one SW train inop erable. This LCO requires that the inoperable SW train be restored to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

ITS LCO 3.8.1, Condition B, which requires the following:

(1) Perform SR 3.8.1.1 for offsite circuit within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter (OP-604, Section 8.4.9, Emergency Diesel Generator Inoperability)

(2) Declare required feature(s) supported by the inoperab le DG inoperable when its required redundant feature(s) is inop SRO erable within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoper ability of redundant required feature(s)

(3) Determine Operable DG is not inoperable due to commo n cause failure within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and perform SR 3.8.1.2 for Oper able DG within 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> and (4) restore DG to Operable status within 7 days OR be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.

Due to CCW Pump B being inoperable and EDG B being declared inoperable due to all of its supporting Service Water Pum ps being disabled, ITS 3.8.1.B.2 requires that CCW Pump C be declared inoperable within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. This will place the plant in LCO 3.0.3 due to not meeting ITS LCO 3.7.6 for CCW System operability requirements.

SRO Implement The EALs SRO Return To Procedure And Step In Effect NOTE: Crew should notify WCC SRO and!or I&C to write a work request, investigate and initiate repairs, and notify the Oper ations Manager.

Booth Operator: Initiate Event #4, Failure of N-35 Compensation Volt age, after ITS entry and on cue from the Chief Examiner.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

4 Event # 4 Page 14 of 37 Event

Description:

Failure of N-35 Com pensation Voltage.

Time Position Applicants Acti ons or Behavior BOOTH OPERATOR: At the discreti on of the Chief Examiner, insert Event 35 Compensation Voltaqe. 4, Failure of N-EVENT INDICATIONS:

APP-005-B2, N-35 LOSS OF COMP VOL T

N-35 indication deflects hiaher that oria inal readina Examiner Note: Due to JPM overlap, the next event sho uld be inserted once it has been identified that OWP-O11, Nl-7 nee ds to be implemented and a plant shutdown performed.

DO NOT HAVE CREW IMPLEMENT THE OWP.

RD APP-005-B2, N-35 LOSS OF COMP VOL T, is received.

RD APP-005-B2 action IF N-35 has failed, THEN REMOVE N 1-35 from service in accordance with DWP-Cii.

APP-005-B2 action RD IF a unit shutdown occurs, THEN Source Range NIS will require manual activation.

DO NOT HAVE CREW IMPLEMENT THE OWP.

DWP-Oil, NI-7 actions:

- Refer to ITS Table 3.3.1-i for Intermediat e Range applicability and operability requirements (ITS Table 3.3.1 SRO -1, Item 3)

- REMOVE NI-35 from ERFIS SCAN: NINOO3 5A

- START UP RATE CHANNEL SELECT Swit ch Switch should be selected to an NI which is NOT removed from service (N 1-36)

- LEVEL TRIP Switch BYPASS

- NIS TRIP BYPASS NI-35 Status Light ILLU -

M The SRO will declare entry into the following LCD:

SRO ITS Table 3.3.1-i, Item 3, Intermediate Ran ge Neutron Flux, Condition F, Thermal Power> P-6 and < P-iC, require s that thermal power be reduced to less than P-6 or increased to greater than P-i C w/in 2 hrs.

BOOTH OPERATOR: As soon as the crew has identified the need to implement OWP-11, Nl-7 and determine the need for a plant shutdown, and with concurrence of the Chief Examiner, inse rt Event 5, CCW system leakage.

Appendix D NUREG-102i, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 5 Page 15 of 37 Event

Description:

Leakage on CC-703B at 25 GPM and rising to 750 GPM.

Time Position Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Exami ner, insert Event 5, Leakage on CC-703B at 25 GPM and rising to 750 GPM.

EVENT INDICATIONS:

APP-001-A4, CCW SURGE TK HIILO LVL CCW Surge Tank Level indicator Ll-614B lowering APP-036-H1, WDBRP TROUBLE (Delayed several minute s)

AOP-014, COMPONENT COOLING WATER SYSTEM MALFUNCTION SRO Implement the EALs BOP Make PA announcement for procedure entry SRO Go To appropriate section for indicated malfunction:

Loss of COW Inventory Go To Section A Continuous Action Step:

Determine If Pump Cavitation is Occuring OR Imminent As Follow s:

- Check Surge Tank Level LESS THAN 5% (NO)

RO - Check CCW Pump Discharge Pressure (Local) AND Flow -

WIDE OSCILLATIONS (NO)

RNO IF CCW Surge Tank level lowers to less than 5% OR CCW Pump Cavitation occurs, THEN Go To Step 2.

Verify at the RTGB, Primary Water Makeup To CCW As Follow RO s:

a. Primary Water Pump RUNNING

b. CC-832, MAKEUP OPEN RO Check CCW Surge Tank level (LI-614B) - STABLE OR RISING (YES)

RO Throttle CC-832 OR CC-71 1 To Maintain Surge Tank Level (LI-614B) 47% to 53%.

Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 5 Page 16 of 37 Event

Description:

Leakage on CC-703B at 25 GPM and rising to 750 GPM.

Time Position I Applicants Actions or Behavior SRO Dispatch Operator To Perform Attachment 3, CCW Leak Search, While Continuing With Procedure Continuous Action Step Check CV For CCW Break Using Control Room Indications As Follows:

a. Monitor the following CV indications:

- ERFIS CV SUMP LEVEL RO - CV WATER LEVEL (White Sump Lights)

- LI-801, CHANNEL I CV WATER LEVEL

- LI-802, CHANNEL II CV WATER LEVEL

- RCP Abnormal Conditions

b. Check CV LOCATION OF CCW BREAK (NO)

Continuous Action Step Determine If Actions For Auxiliary Building Flooding Are Necessary As Follows:

a. Check for any of the following indications of flood ing:

- Water level on Aux Bldg first floor GREATER THA N 6 INCHES (NO)

OR

- APP-O01-E4, RHR PIT A HI LEVEL ILLUMIN ATED (NO)

Ro OR

- APP-001-E5, RHR PIT B HI LEVEL ILLUMINATE D (NO)

b. Dispatch Operator to perform Attachment 4, Floo d Control In The Auxiliary Building RNO IF at any time flooding is indicated, THEN perform Attachment 4, Flood Control In The Auxiliary Buil ding Go_To_Step_26.

Examiners Note: At this point, the CCW leakage will rise to 750 gpm. The crew will transition to Step 8 (Continuous Action Step

) and proceed through the procedure to combat the change in the leaka ge rate.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 5 Page 17 of 37 Event

Description:

Leakage on CC-703B at 25 GPM and rising to 750 GPM.

Time Position I AoIicants Actions or Behavior Continuous Action Step Check CCW Surge Tank level (Ll-614B) STABLE OR RISING (NO)

RO RNO WHEN CCW Surge Tank level (Ll-614B) is Stable OR Rising, THEN perform Step 9.

RO Start a Second Primary Water Pump RO Check CCW Surge Tank level (Ll-614B) LOWERING (YES)

Dispatch Operator To Perform Attachment 3,CCW Leak Search, SRO While Continuing With Procedure Continuous Action Step Determine If Pump Cavitation is Occurring OR Imminent As Follows:

RO - Check Surge Tank Level LESS THAN 5% (YES)

- Check CCW Pump Discharge Pressure (Local) Flow -

WIDE OSCLLATIONS+/-YES)

RO Check Reactor CRITICAL (YES)

Verify Reactor TRIPPED (Large Break LOCA will occur when the RO reactor trip breakers are opened)

RO Stop ALL RCPs Go To PATH-i While Continuing With This Procedure SRO (NOTE: AOP-014 actions are listed at the end of the scenario guide.)

Appendix D NUREG-i 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 18 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position AoDlicants Actions or Behavior START OF PATH-I ACTIONS Immediate Action Step RO Reactor tripped (YES)

Immediate Action Step BOP Turbine tripped (YES)

Immediate Action Step BOP El & E2 energized (YES)

Continuous Action Step BOP IF Dedicated Shutdown Bus is Deenergized THEN Place Dedicated Shutdown Diesel Generator In Service Using EPP-25.

Immediate Action Step RO SI initiated (YES)

SRO Open Foldout A RCP TRIP CRITERIA

a. IF BOTH conditions below are met, THEN stop all RCPs:

. SI Pumps AT LEAST ONE RUNNING AND RO CAPABLE OF DELIVERING FLOW TO THE CORE

. RCS Subcooling LESS THAN 35°F [55° F]

b. IF the PHASE B Isolation valves are closed, THEN stop all RCPs._(YES)

Appendix D NUREG-l 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 19 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time N Position 1 Applicants Actions or Behavior EMERGENCY COOLING WATER SWITCHOVER CRITERIA IF normal cooling is lost to any of the following components, THEN establish emergency cooling water using the referenced procedure:

BOP Charging Pump Oil Coolers Use Attachment 1 of AOP-014, Component Cooling Water System Malfunction. (YES)

Verify Phase A valves closed (NO)

Critical RO FP-248, 249, 256 and 258 did not close automatically and will have to Task be manually closed from the CFPP.

BOP Verify FW isolation valves closed (YES)

BOP Verify both FW pumps tripped (YES)

BOP Verify both MDAFW pumps running (YES)

BOP If Additional Feedwater is required, THEN Start SDAFW Pump Verify two SI pumps running (YES)

RO RO Verify both RHR pumps running (YES)

Verify SI valves properly aligned (NO)

Critical Valves SI-870A and 870B did not open on the SI and at least one of RO Task the valves must be opened to provide an injection flow path to the core.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 20 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior Examiners Note: AOP-014 is in effect due to being a concurrent AOP. Actions in the AOP will lockout all of the CCW Pumps due to the loss of inventory in the system.

Depending on when an operator is assigned to perform the remaining actions in AOP-014 will affect the following steps that are preceded by a @symbol.

AOP-014 actions are continued from previous section at the end of the scenario guide.

RO @ At least one COW pump running (NO)

BOP @ E-1 AND E-2 energized by offsite power (YES)

RO @ Start COW Pump (Cannot be started.)

RO @ Verify open Therm Bar Flow Cont FCV-626 unless closed due to ruptured Therm Bar (Cannot be opened due to a Phase B signal)

All SW & SW booster pumps running (NO)

BOP BOP Attempt to start all SW and SWB Pumps NORTH or SOUTH SW HDR LO PRESS ALARMS ILLUMINATED BOP (YES)

BOP CLOSE V6-16C OR V6-16A and V6-16B Secure Turbine Building equipment using Supplement M.

BOP (Supplement M actions included at the end of PATH-I actions)

RO Verify CV Fans HVH-1 ,2,3 & 4 running (YES)

RO Verify IVSW System initiated (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 21 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position r Applicants Actions or Behavior RO Verify CV ventilation isolation (YES)

Verify control room ventilation aligned for pressurization mode (NO)

Operator to verify the following:

- Verify CONT RM AIR EXHAUST Fan, HVE-16 STOPPED -

- Verify CLEANING Fan HVE-19 A/B RUNNING Critical Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE Task BOP -

DAMPER, CR-D1A-SA CLOSED -

- Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1 B-SB CLOSED -

- H CR-D1A-SA OR CR-D1 B-SB have lost power, THEN locally_verify_position_in_the_Control_Room_Kitchen.

BOP Verify both EDGs running (YES)

Continuous Action Step BOP Restart Battery Chargers within 30 minutes of Power Loss using OP 601 Continuous Action Step RO CV pressure remained below 10 psig (NO)

RO Verify CV Spray Initiated (YES)

RO Verify all CV Spray Pumps running with valves properly aligned (YES)

Verify appropriately 12 GPM Spray Additive tank flow (Valve Sl-845C RO will be throttled to adjust flow to -12 GPM as read on FI-949)

RO Verify Phase B Isolation Valves closed (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 22 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior RO Stop all RCPs (Previously secured lAW AOP-014)

BOP Verify all MSIVs and MSIV Bypasses Closed (YES)

BOP Locally open the breaker for HVS-1 at MCC-5 CMPT 7J within 60 minutes of SI Initiation BOOTH 0 ERATOR: )pen the breaker for HVS-1 3 minutes after directe d by the Control Room.

RO RCS pressure greater than 1350 psig [1250 psig] (NO)

RO SI flow verified (YES)

RO RCS pressure >125 psig (NO)

RO RHR flow verified (YES)

BOP At least 300 gpm AFW flow available (YES)

BOP Verify AFW Valves Properly Aligned (YES)

BOP Control AFW flow to maintain SIG levels between 8% [18%] and 50%

RCP Thermal Barrier Cooling Water Hi or Lo flow alarms illuminated RO (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 23 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time J Position Applicants Actions or Behavior IF seal cooling is NOT restored within 15 minutes, THEN perform RO Supplement R RO At least one charging pump running (YES)

Greater than 5 inches thermal barrier Delta P OR 6 GPM seal injection RO to all RCPs (YES)

RO At least one Instrument Air Compressor running (YES)

Stop RCP with Therm Bar Delta P less than 5 inches AND seal RO injection less than 6 GPM (RCPs previously secured).

RO Seal cooling established to all RCPs (YES)

BOP Place Steam Dump Mode switch to Steam Pressure RO RCS temperature stable at or trending to 547°F (NO)

RO RCS temperature greater than 547° F (NO)

BOP Attempt to limit cooldown IF RCS Cooldown continues and is not due to SI flow, THEN CLOSE MSIVs and MSIV Bypasses.

BOP

. MSIVs and MSIV Bypasses are closed due to Phase B Isolation signal.

Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 24 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior RO PZR PORVs Closed (YES)

RO PZR Spray & Aux Spray valves closed (YES)

RO At least one RCP running (NO)

BOP Any SIG with uncontrolled depressurization (NO)

BOP Any SJG Completely Depressurized (NO)

BOP R-19s, R-31s, R-15 Rad levels normal (YES)

BOP R-2, R-32A, R-32B Rad Levels Normal (YES)

CV Pressure Normal (NO)

RO

. GO TO PATH-i, Entry Point C RO Reset SPDS and initiate monitoring CSFSTs FRP-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL RO SHOCK, has a RED Path due to the excessive RCS cooldown.

FRP-P.1 actions to follow.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 25 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Aoolicants Actions or Behavior FRP-P1 Actions Check CST Level LESS THAN 10% (NO)

BOP RNO IF CST level lowers to less than 10%, THEN perform Step 2.

Go To Step 3.

FRP-P.1 Actions Determine if RCS cooldown is due to a Large Break LOCA as follows:

a. Check both of the following conditions exist:

RO . RCS pressure LESS THAN 275 PSIG [400 PSIG] (YES)

AND

. RHR flow on FI-605 GREATER THAN 1200 GPM (YES)

b. Reset SPDS and return to procedure and step in effect.

SRO Re-enter PATH-i at Entry Point C Open Foldout B SRO (No actions required)

BOP Request periodic activity samples of All S/Gs RO At least one RCP running (NO)

BOP Any S/G with Uncontrolled Depressurization (NO)

BOP Any S/G Completely Depressurized (NO)

SOP Control AFW Flow to Maintain SIG Levels between 8% [18%] and 50%

Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 26 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time I PosWon r Applicants Actions or Behavior BOP Any SIG with Uncontrolled Level Rise (NO)

BOP R-19s, R-31s, AND R-15 Rad Levels Normal (YES)

RO PZR PORVs Closed (YES)

Open at least one PORV Block unless Closed to Isolate an Open PZR RO PORV Continuous Action Step RO IF PZR PORV Opens on High Pressure, THEN Verify Reclosure at or Below 2335 PSIG. Close PORV Blocks as Necessary.

RO Reset SI Continuous Action Step CREW lFOffsite Power is Lost, THEN Restart Emergency Safeguard Equipment RO Reset CV Spray RO Reset Phase A AND Phase B Establish Instrument Air to CV. IF Compressor Not Running, THEN RO Start Compressor.

BOP Offsite Power Available to Charging Pumps (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 27 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position I AøIicants Actions or Behavior RO At Least One Charging Pump Running (YES)

RO Establish Charging Flow as Necessary RO CV Spray Pumps Running (YES)

Continuous Action Step RO WHEN CV PRESS LOWERS BELOW 4 PSIG, THEN STOP CV SPRAY PUMPS AND CLOSE Sl-880 VALVES RO RCS Subcooling Greater Than 35°F [55°F] (NO)

Continuous Action Step RO WHEN Below 10b0 Amps, THEN Energize Source Range detectors and monitor recorder. (Due to failure of N-35, Source Range detectors will have to be manually re-energized)

RO RCS Pressure Greater Than 275 PSIG [400 PSIG] (NO)

BOP E-1 AND E-2 energized by offsite power (YES)

BOP Starting Air Receivers repressurized to unloaded EDGs (YES)

BOP Stop the unloaded EDGs Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 28 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior Supplement D components capable of recirc (NO)

RO No CCW Pumps are available SRO Exit PATH-I to EPP-15, Loss of Emergency Coolant Recirculation Continuous Action Step:

RO Check Emergency Coolant Recirculation Capability RESTORED (NO)

RO Reset SPDS AND Initiate Monitoring Critical Safety Function Status Trees Foldout Pages Are Not Applicable During Performance Of This SRO Procedure Continuous Action Step:

Check Suction Source To Any Of The Following Pumps LOST (NO)

RO

• SI Pumps

. RHR Pumps

. CV Spray Pumps Check Emergency Recirculation Equipment AVAILABLE USING SUPPLEMENT D (NO)

RO RNO Try to restore at least one train while continuing with this procedure.

Verify The Following CV RECIRC FANS RUNNING (YES)

. HVH-1 RO

• HVH-2

• HVH-3

• HVH-4 Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 29 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior Continuous Action Step:

RO Check RWST Level LESS THAN 9% (NO)

RO Prace the CONTIJNMENT SPRAY Key Switch To The OVRD/RESET Position Determine CV Spray Pump Requirements

a. Determine Number Of CV Spray Pumps Required Using the Following Table:

RWST level greater than 27%

CV Pressure less than 4 psig HVH-1, 2, 3, 4 operating RO CV Spray Pumps required 0

b. Check CV Spray Pump running EQUAL TO NUMBER REQUIRED (YES, unless spray not previously secured.)

IF a CV Spray Pump is required to be stopped, THEN close the discharge valves of any stopped pump:

CV Spray Pump A Sl-880A and B CV Spray Pump B Sl-880C and D RO Makeup to RWST using Supplement P while continuing with this procedure.

Continuous Action Step:

BOP Check CST Level LESS THAN 10% (NO)

Control Intact SIG Levels As Follows:

a. Check intact S/G levels ANY GREATER THAN 8% [18%]

BOP (YES)

b. Control feed flow to maintain intact S/G levels BETWEEN 8% [18%] AND_50%

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 30 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time 1 Position Applicants Actions or Behavior Contact Chemistry To Obtain Periodic Boron Samples Of The Following:

RO . Reactor Coolant System

• Pressurizer Continuous Action Step Ensure Adequate Shutdown Margin Exists As Follows:

RO a. Check boron sample results AVAILABLE (NO)

RNO -WHEN sample results available, THEN perform Step 18.b Observe NOTE prior to Ster 19 and Go To Step 19.

Initiate RCS Cooldown To Cold Shutdown As Follows:

a. Maintain cooldown rate in RCS cold legs LESS THAN 100°F IN THE LAST 60 MINUTE BOP b. Maintain RCS temperature and pressure WITHIN LIMITS OF CURVE 3.4, REACTOR COOLANT SYSTEM PRESSURE -

TEMPERATURE LIMITATIONS FOR COOLDOWN

c. Check RHR System ALIGNED FOR CORE COOLING (NO)

RNO Go To Step 19.f Check intact S/Gs AT LEAST ONE AVAILABLE FOR RCS BOP COOLDOWN (YES)

Check steam dump to Condenser AVAILABLE (NO)

BOP RNO Dump steam from S/Gs using STEAM LINE PORVs.

Go To Step 20 RO Check RCS Hot Leg Temperatures LESS THAN 543°F (YES)

Restore Steam Dumps As Follows:

a. Check steam dump to Condenser AVAILABLE (NO)

BOP RNO Continue RCS cooldown using STEAM LINE PORVs.

Observe the NOTE prior to Step 22 and Go To Step 22.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 31 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time I Position I Applicants Actions or Behavior Defeat Low Tavg Safety Injection Signal As Follows:

a. Momentarily place SAFETY INJECTION T-AVG Selector Switch RO to BLOCK position

b. Verify LO TEMP SAFETY INJECTION BLOCKED status light ILLUMINATED (YES)

RO Check RCS Pressure LESS THAN 1950 PSIG (YES)

Defeat Low Pressure Safety Injection Signal As Follows:

a. Momentarily place PZR PRESS/HI STM LINE DP Switch to RO BLOCK position

b. Verify LO PRESS SAFETY INJECTION BLOCKED status light ILLUMINATED (YES)

RO Reset SAFETY INJECTION Continuous Action Step BOP Check Off-Site Power AVAILABLE (YES)

Check Safeguards Pump Status ANY RUNNING (YES)

. SI Pumps RO OR

• RHR Pumps Establish One Train Of SI Flow As Follows:

a. Verify SI PUMPS ONLY ONE RUNNING RO b. Check RCS Pressure LESS THAN 275 PSIG [375 PSIG]

(YES) c._Verify_RHR_PUMPS_-_NO_MORE_THAN_ONE_RUNNING Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 32 of 37 Event

Description:

Large Break LOCA on Reactor Trip F Time E Position I Applicants Actions or Behavior Supplement M, Component Alignment for Loss of SW to Turbine Building Actions Shutdown secondary as follows:

BOP a. Check S/Gs ANY RUPTURED (NO)

Go To Step 1.c BOP Close all MSIVs AND MSIV Bypass Valves Break vacuum to the Condenser as follows:

1. Depress AND hold the THINK pushbutton

2. Open VACUUM BREAKER VALVES:

BOP . MS-70A

. MS-70B

3. WHEN the valves are open, THEN release the THINK pushbutton.

Verify the following equipment is stopped:

. FWPUMPAandB

. CONDPUMPAandB BOP

. HEATER DRAIN PUMP A and B

. GOV FLUID PUMP A and B

. VACUUM PUMPAandB Return to procedure and step in effect BOP END of Supplement M steps Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 33 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior AOP-014, Component Cooling Water System Malfunction ACTIONS Lockout CCW Pumps As Follows:

a. Place AND hold all CCW Pump switches in STOP position RO/BOP b. Check APP-001-F5, CCW PMP LO PRESS ILLUMINATED -

c. Release CCW Pump Switches

d. Go To Step 13 Dispatch Operator To Perform Attachment 3, CCW Leak Search, RO/BOP While Continuing With Procedure Continuous Action Step Check CV For CCW Break Using Control Room Indications As Follows:

a. Monitor the following CV indications:

. ERFIS CV SUMP LEVEL

. CV WATER LEVEL (White Sump Lights)

RO/BOP

• LI-801, CHANNEL I CV WATER LEVEL

• LI-802, CHANNEL II CV WATER LEVEL

• RCP Abnormal Conditions

b. Check CV LOCATION OF CCW BREAK (NO)

RNO IF subsequent parameters indicate location of break in the CV, THEN Go To Step 15.

Observe the NOTE Prior to Step 25 and Go To Step 25 Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 34 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time1L Position Applicants Actions or Behavior Continuous Action Step Determine if actions for Auxiliary Building flooding are necess ary as follows:

a. Check for any of the following indications of flooding:

. Water level on Aux Bldg first floor GREATER THAN 6 INCHES (NO)

RO/BOP

. APP-OO1-E4, RHR PIT A HI LEVEL ILLUMINATED (NO)

OR

. APP-OO1-E5, RHR PIT B HI LEVEL ILLUMINATED (NO)

RNO IF at any time flooding is indicated, THEN perform Attach ment

, Flood Control in the Auxiliary Building.

Go To Step 26.

Determine If RHR Must Be Stopped As Follows:

a. Check CCW Pumps ALL STOPPED (YES)

RO/BOP b. Check RHR Pump status ANY PUMP RUNNING IN CORE COOLING MODE (NO)

RNO Go To Step 29.

Verify Letdown Isolated As Follows RO/BOP

• LCV-460 A&B, LTDN LINE STOP CLOSED -

• HIC-142, PURIFICATION FLOW SET TO 0% -

• CVC-387, EXCESS LTDN STOP CLOSED -

Determine If Charging Pump(s) Should Be Stopped As Follow RO/BOP s:

a. Check Charging Pumps ANY PUMP RUNNING (YES)

b. Check RCS temperature GREATER THAN 150°F (YES)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 35 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time 1 Position Applicants Actions or Behavior Establish Alternate Cooling To Charging Pumps As Follows:

a. Stop ALL but one Charging Pump RO/BOP b. Raise the speed of the running Charging Pump to at least 75%

Demand Signal

c. Dispatch an operator to perform Attachment 1, Emergency Cooling To Charging Pumps Check Attachment 1 COMPLETE (NO)

RNO WHEN Attachment 1, EMERGENCY COOLING TO RO/BOP CHARGING PUMPS, has been completed, THEN perform steps 33, 34 and 35 Go To Step 36 Notify Chemistry Personnel To Stop Any Primary Sampling In RO/BOP Progress Determine If Emergency Cooling To Spent Fuel Pit Heat Exchanger Is Required As Follows:

a. Check APP-036-B4, SPENT FUEL PIT HI TEMP RO/BOP ILLUMINATED (NO)

RNO IF at any time APP-036-B4, SPENT FUEL PIT HI TEMP, illuminates, THEN perform Step 37.b.

Go To Step 38.

Determine If CCW May Be Restored As Follows:

RO/BOP a. Check CV LOCATION OF CCW BREAK (NO)

RNO Go To Step 39.

RO/BOP Check leak source LOCATED (YES)

Check Leak Source ISOLABLE (NO)

RO/BOP RNO Perform one of the following:

. IF CCW Pumps have ALL been stopped, THEN Go To Step 44.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 4 Event # 6 Page 36 of 37 Event

Description:

Large Break LOCA on Reactor Trip Time Position Apilicants Actions or Behavior RO/BOP Initiate Action For Emergency Repair Of The Pipe Break Check Repair Status COMPLETE (NO)

RO/BOP RNO WHEN the repairs have been completed, THEN Go To Step 47.

Booth Operator: After approximately 15 minutes of being requested, report that Attachment 1, Emergency Cooling to Charging Pumps, is completed.

Step 33: Reduce the Speed of the Running Charging Pump to RO/BOP Minimum Step 34: Check RCP Thermal Barrier AP Greater than 5 inches RO/BOP (YES) (IF NO, then locally throttle RCP Seal Water Flow Control Valves to obtain at least 6 gpm to each RCP.)

Check RCP Parameters:

. RCP Thermal Barrier AP Greater Than 5 inches OR RO/BOP . RCP Seal Injection Flow At least 6 gpm to each RCP (IF NO, then raise charging pump speed to establish RCP Thermal Barrier AP greater than 5 inches RCP seal injection flow at least 6 gpm to each RCP.)

The Chief Examiner may terminate the scenario anytime after RHR and SI Pump operation has been reduced to minimum pumps operating or at his discretion.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

ILC-11-2 NRC SCENARIO 4 TURNOVER SHEET POWER LEVEL: 1 E-8 amps Core Burnup: 150 MWD/MTU EFPD: 4.3 EFPD Boron: 1531 PPM Xenon: 88 pcm (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> post trip)

Tavg: 547°F Bank D Rods: 99 Steps EQUIPMENT UNDER CLEARANCE:

• NONE EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• Raise reactor power to the POAH and continue with plant startup.

AppendixD NUREG-1021, Rev. 9, Supp. 1

Unit 2 Status Board IDate: Today ITime: 6:00:00AMICycIe: 27 IMWDIMT:

150 Ioesian: 16590

[FPD 4.3 IDesign 473.5 I Tank Level% Status HUT Level % I Status Monitor A 10 Standby CVCS-A 20 Filling Monitor B 38 Standby CVCS-B ilo Standby WCT A 37 Standby cvcS-C 86 Standby WCIpJ Standby WHUT Fillinci WCT C 9 Standby Standby Data Linked to P1 WCTE 9 Standby WGDTS Pressure PSIG Status A #NAME? lPsic On cover DEMINERALIZERS B ,#NAME? PSIG In Service PPM

. Resin In Service Date Replaced C #NAME? [PSIG Isolated MBA 12194 YES 7117/2010 5/4/2010 D #NAME? PSIG p Stand by MB B [2265 NO 7117/2010 3129/2010 CATION 9117/2010 12/9/2009 Shutdown Requirement Temp Boron DEBA 0 NO New [213/2010 DEBB 0 NO SFP 1963 NO 912312008 412212008 1430 6%=K/K N/A 1950 SGBD Condenser Air Inleakage Target Value GPM Status PORV Settings Selling Date POT GP-3 Psig A 7/18/2010 3.21 1000 orni 18 CFM C Jj Recovery Total CFM N2 Flow 8 SCFM C 7/18/2010 3.4-4 1000 Effluent Radiation Monitor Setpoints RCS Leakage Rad Current NUE Value 0.00 Unidentified Monitor Setpoint Alert Value 200X 2X Total 01E+0[A 2M20E+04 PRT 0.02 GPM R-20 7.40E+03 N/A 1.480E+04 RCDT Leakage 0.01 GPM R-1 8 1 .OOE+06 2.000E+08 2.000E+06 Charging Leakoff 0 PM R-19A 1.05E+04 2.IOOE+06 2.IOOE+04 Misc Identified 0 GPM R-19B 9.72E+03 1.944E+06 1.944E+04 PrimarylSecondary 0 R-19C 9.58E+03 1.916E+06 1.916E+04 SaLos7i7.3 GPM R-37 8Z0T 1.706E+06 1.706E+04 Manually Entered Data Linked to C em data base Hi Flux At Shutdown Boron PPM Date PPM Date PPM reviousAouetpoin RCS Jjay BAST-A 9/16/2010 j35 #NAME? #NAME?

BAST-B 9j2010I21, #NAME? #NAME?

SFP 9/15/20102246 #NAME? #NAME?

Normal Currents RWST 9/1612010 2219 #NAME?  !#NAME?

_j UPPER LOWER TARGET J%BAND Accum-A 8/30120102211 #NAME?

N-41 I#NAME?

J15 109 2.3 5+!- Accum-B8!30/20W2206 N-42 101 100 2.3 5+1- Accum-C 8/30/2010 2230 #NAME?  :#NAME?

N-43 96 89 2.3 5+!- RHR 7/6/2010 2221 N-44 91 87 2.3 [5+!- Refuel Canal tOWERTRAX Rev# 2.1.0 RNP 1% APL 112.55 Refuel Cavity SFP Canal FANS TestlHrs DatelTst HVE-IAIB 35640.6 318110 Notes/Additional Data HV15A85i38/iO IC-I, 2,40 HVE-19A/B 6928.3 5/3/10 BOL SR 3.7.11.2 Last Completed 5/27/2010 19:45 I

ILC-11-2 NRC SCENARIO 4 TURNOVER SHEET POWER LEVEL: 1E-8 amps Core Burnup: 150 MWD/MTU EFPD: 4.3 EFPD Boron: 1531 PPM Xenon: 88 pcm (72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> post trip)

Tavg: 547°F Bank D Rods: 99 Steps EQUIPMENT UNDER CLEARANCE:

• NONE EQUIPMENT STATUS:

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• Raise reactor power to the POAH and continue with plant startup.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board IDate: Today ITime: t6:00:OOAMICvcle: 127 JEFPD 4.3 IDesign IMWD/MT: 150 JDesicjn:

473.5 16590 I

HUT Level % Tank Level %

Status Status CVCS-A 20 Monito_J10 IFilling Standby CVCS-B 10 Monitor 8 38 Standby Standby CVCS-C 186 WCT A [37 Standby Standby WHUT #NAME? Filling WCT B Standby WCTC [9 Standby Data Linked to P1 WCTD 10 Standby WGDTS Pressure IPSIG WCT E Status Standby A #NAME? IPSIG B DEMINERALIZERS

1. NAME? PSIG In Service PPM In Service Date Resin C #NAME? PSIG Isolated Replaced D #NAME? MBA 2194 YES PSIG Standby MB B 2265 NO 7/17/2010 3/29/2010 Shutdown Requirement CATION 1021 NO 9/17/2010 1.77% =zK/K Temp Boron DEB A 0 NO New 12/912009 21312010 F Hot 1051 1.77%=LKIK DEB B 0 NO

>350F 1281 3/28/2010 2.6% =tM<IK SFP 1963 NO 1100 F Cold 1430 9/23/2008 4/22/2008 6%=LK1K IN/A 1950 S3L3D Condenser Air Inlea age PORV Settings Target V lue GPM Status Setting Date POT GP-3 Psig 113 CFM A 50 Flash Tank A 5 0 CFM 17I181i73.21 1000 B 50 With Heat B Known 8 CFM 7118/2010 C 50 Recovery C rotal 5 CFM 7/18/2010 3.44 1000 N2 Flow 8 SCFM Effluent Radiation Monitor Setpoints RCS Leakage 0.00 Unidentified Rad Current Alert Value 200X NUE Value Monitor Setpoint tal 2X R-14C l1.olE+o4 RCDT Leakage R-20 7.40E+03 0.01 N/A 1.480E+04 1GPM R-18 1.OOE+06 Charging Leakoff 2.000E+08 12.000E÷o6 Misc Identified R-19A 1.05E+04 2.IUOE+06 0 GPM 2.IOOE-04 R-19B 9.72E+03 1.944E+06 1.944E+04 R-19C 9.58E+03 1.916E+06 17.3 GPM 1.916E+04 R-37 f8.53E+03 1.706E+06 L1.706E+04 Hi Flux At Shutdown Manually Entered Data Linked to Cl em data base Previous ARI Counts ISe Boron PPM Date tpoin__ PPM Date PPM Nl-31 50 RCS Today 1531 150 NI-32 60 BAST-A 9116/2010 21,535 1180 #NAME? #NAME?

BAST-B 9/16/2010 21,032 #NAME? #NAME?

SFP 9(15(2010 2246 Normal Currents #NAME? #NAME?

UPPER RWST 9116/2010 2219 LOWER TARGET %BAND #NAME? #NAME?

N-41 AccumA [8/30I2010 2211 115 109 2.3 #NAME? #NAME?

5+/-

NZ1& H 5 Accum-B 813012010 2206 #NAME? #NAME?

N-43 96 Accum-C 8/30/2010 2230 89 2.3 5 +I #NAME?

rJ-44 91 RHR 7(6/2010 87 2.3 5 +/.. 12221 OWERTRAX Rev# 2.1.0 RNP Refuel Canal 1% APL 112.55 Refuel Cavity SFP Canal FANS Test/Hrs Ioate!Tst HVE-IA!B 135640.6 3/8/10 5A1864il(18 Notes/Additional Data

/1 HVE-19A!B 6928.3 IC-I, 2,40 513/10 SR 3.7.11.2 Last Completed BOL l5/272o1o 19:45

Appendix D Scenario Outline Form ES-D-1 I Facility: HB ROBINSON Scenario No.: 5 Op Test No.:

Examiners: Operators: SRO -

RO BOP Initial Conditions:

• 68% RTP EOL, 15697 MWD/MTU, 132 ppm Boron

• A MDAFW pump inoperable with the breaker racked out

. Automatic Rod Control is inoperable

. Currently thunderstorm watch is in effect for Darlington and Chesterfield counties Turnover:

• A HDP recently started for PMT following maintenance. Maintain current power while RES is evaluating PMT results.

Critical Tasks:

• Stop excessive steam flow

• Establish feedwater flow to at least one SIG Event MaIf. Event Type* Event No. No. Description 1 (C) BOP, SRO A CW Pump trips and V6-50A fails to close automatically 2 (I) RO, SRO PZR Pressure Controller PC-444J Range Shifts (TS) SRO 3 (l)BOP SRO Steam Pressure Channel PT-485 fails LOW (TS) SRO 4 (C) BOP, SRO Loss of Cooling to the Auxiliary Transformer 5 (R)RO Load Reduction to 50%

(N) BOP, SRO 6 (M) ALL B S/G Feedwater Regulating Valve FCV-488 fails closed and complete loss of feedwater 7 BOP Turbine Trip Does Not Occur 8 B MDAFW and SDAFW Pumps Trip when Start Signal BOP Received 9 BOP Steam Dump Valves fail Open on Reactor Trip 10 BOP MSIVs fail to close on auto-close signal 11 RO RHR-744A and 744B fail to auto-open on Safety Injection (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-1 ILC-11-2 NRC SCENARIO 5

SUMMARY

DESCRIPTION The crew will assume the watch with the plant at 68% RTP. MDAFW Pump A is out of service for scheduled lube oil cooler replacement. The motor breaker has been racked out and the pump has been isolated and cleared for maintenance. Bearing replacement has been completed on A HDP and PMT is in progress. Shift instructions are to mainta in current power level while RES is evaluating the PMT results on A HDP.

On cue from the Chief Examiner, A CW pump will trip on overcurrent and discha rge valve V6-50A will fail to close automatically. The crew will take immediate actions lAW AOP-012, Partial Loss of Condenser Vacuum or Circulating Water Pump Trip. The operator will take manual action to verify that V6-50A is closed. Condenser Vacuum will be minimally affecte d by the loss of A CW Pump. Once the Chief Examiner is satisfied with the crews actions, the Chief Examiner will cue the next event.

PZR Pressure Controller PC-444J control range will shift causing the PZR Spray valves to open and lower PZR pressure. AOP-019, Malfunction of RCS Pressure Control, immed iate actions will be taken and the procedure will take actions to restore pressure to the norma l control band with PC-444J operated in manual control. ITS 3.4.1, Condition A, One or more RCS DNB parameters not within limits Restore RCS DNB parameters to within limit within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, will be entered due to PZR Pressure being less than 2205 psig. Once the Chief Exami ner is satisfied with the crews actions and Tech Spec compliance, the Chief Exami ner will cue the next event.

Steam Pressure Transmitter PT-485 will fail LOW, causing the controlling steam flow channel on SIG B to fail low and causing a transient on the Feedwater Regulating valve FCV-488. AOP 025, RTGB Instrument Failure, Section G immediate actions will be taken by the crew to stabilize the SIG level transient. The procedure will place an alternate control channe l in service and direct the removal of the channel from service. ITS Table 3.3.1-1 Item 14 which requires 2 SIG Level channels (not affected by the failure) and 2 Steam Flow I Feedwater Flow mismatch channels with Condition E Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode within 3 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. ITS Table 3.3.2-1 Items le, ig, and 4e for Safety Injection and Steam Line Isolation High Steam Line Flow with Low Tave or Low Steam Line Pressure Condition D: Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> OR Be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND Be in Mode 4 within 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

ITS Table 3.3.3-1 Item 20 Post Accident Monitoring Instrumentation for Steam Generator pressu re required channels is 2 per SIG which is currently met. ITS Table 3.3.6-1 Item 4 Safety Injection for Containment Ventilation Isolation Instrumentation refers to LCO 3.3.2 Functi ons l.a-f (which have already been addressed) requirements will be reviewed by the SRO to ensure that all of the ITS specs are satisfied. Once the SIG level control has been stabilized and the Chief Examiner is satisfied with the Tech Spec compliance, he can cue the next event.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

LAppendix D Scenario Outline Form ES-D-i I Auxiliary Transformer Trouble alarm (APP-009-C6) will be received on the RTGB. The report from the field is that all cooling fans and oil pum ps on the transformer have been lost. Breaker 4BR on MCC-4 (Power supply to Power Cooler #1 and #2) has tripped and cannot be reset.

AOP-037, Large Transformer Malfunctions, Attachm ent 4, will be implemented by the crew with the requirement to reduce load to less than 50%

within 30 minutes and unload the transformer.

The operator will have to manually insert control rods since the automatic rod insertion function has been disabled. Power reduction will commence and will continue until the UAT is unloaded or until the Chief Examiner cues the next event.

B SIG Feedwater Regulating Valve FCV-488 will fail CLOSED. This will cause an immediate reduction in the B SIG level and the crew will take immediate actions of AOP-01 0, Main Feedwater I Condensate Malfunction, and attem pt to control FCV-488 in manual. This will be unsuccessful and the crew should manually trip the reactor due to lowering B S/G level. Once the reactor is tripped, the crew will enter PATH-i.

The turbine will not trip automatically or manually from the RTGB and the operator will have to manually runback the turbine with the EH controls until the governor valves are closed.

B MDAFW Pump and the SDAFW Pump will trip when the start signal is received.

Steam dump valves will fail open and cannot be close d from the RTGB. The MSIVs will fail to automatically close but can be closed manually from the RTGB control switches. If requested to locally close the Steam Dump valves, the task will be successful to close the valves.

RHR-744A and 744B fail to auto-open on the safet y injection signal. The operator will have to manually open the valves from the RTGB.

The crew will transition to FRP-H. i, Response to Loss of Secondary Heat Sink, due to the inability to feed the S/Gs. During the procedure, all RCP s will be secured to remove the additional heat source to the RCS. FRP-H.1 will direc t the operators to over-ride the Feedwater Isolation Signals and start one MFP to re-establish feed water flow. Once feedwater flow is re established the crew will be directed to reset SPDS and return to PATH-i.

The Chief Examiner may terminate the scenario after the crew has restored feedwater flow to at least one S/G or at his discretion.

Appendix D NUREG-iO2i, Rev. 9, Supp. 1

ILC-II-2 NRC SCENARIO 5 SIMULATOR SETUP ICISETUP:

• lC-805, SCN: 0081 l_2_NRC_Exam_5

• A MDAFW Pump inoperable with the breaker racked out

• Rods selected to Manual with automatic rod control defeated

• Status board updated to reflect IC-17 PRE-LOADED EVENTS:

The following events should occur on the reactor trip and safety injection:

Event 7: Turbine Trip does not occur Event 8: B MDAFW and SDAFW Pumps Trip when Event 9: Start Signal Received Steam Dump Valves fail Open on Reactor Trip Event 10: MSIVs fail to Close on Automatic Signal Event 11: RHR-744A and 744B fail to auto-open on Safety Injection EVENTSITRIGGERS INITIATED DURING THE SCENARIO:

Event 1: A CW Pump trips and V6-50A fails to close auto Event 2: matically PZR Pressure Controller PC-444J Range Shif Event 3: ts Steam Pressure Channel PT-485 fails LOW Event 4: Loss of Cooling to the Auxiliary Transformer Event 5: Load Reduction to 50%

Event 6: B SIG Feedwater Regulating Valve FCV-488 fails closed EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

• AOP-012

• AOP-019

• AOP-025 Main Body and Section G

• OWP-025, SGP-8

• APP-046

• AOP-037

• AOP-OIO

• PATH-I

• Foldout A

• FRP-H.I Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 1 Page 5 of 30 Event

Description:

A OW Pump trips and V6-50A fails to close automatically.

Time Position Applicants Actions or Behavior BOOTH OPERATOR: When directed, insert Event 1, A CW Pump trips and V6-50A fails to close automatically.

EVENT INDICATIONS:

APP-008-D4, CW PMP A MOTORIDISCH VLV TRIPIOVLD, is illuminated.

CW Pump A RTGB indication is Green (Pump Off).

V6-50A indicates OPEN on the RTGB.

Immediate Action Step:

BOP Check Circulating Water Pump ANY TRIPPED (YES)

Immediate Action Step:

BOP Verify The Tripped Circulating Water Pump Discharge Valve -

CLOSED OR CLOSING (BOP takes action to manually close V6-50A from the RTGB.)

Enters AOP-01 2, Partial Loss of Condenser Vacuum or Circulating SRO Water Pump Trip SRO Verifies immediate actions complete.

BOP Start any available CWPs. (AB available are running.)

RO Make PA Announcement for Procedure Entry.

BOP Check Liquid Waste Batch Release In Progress (NO)

Check Condenser Status VACUUM PREVIOUSLY ESTABLISHED B0P (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 1 Page 6 of 30 Event

Description:

A CW Pump trips and V6-50A fails to close automa tically.

Time Position Arplicants Actions or Behavior BOP Check Status of the tripped CWP Discharge Valves Completed Closing (YES, V6-50A manually closed from RTGB.)

BOP Check Plant Conditions In Modes 1 OR 2 (YES)

Check Condenser Back Pressure On P1-1312 AND P1-1 BOP 313 APPROACHES RESTRICTED REGION OF ATTACH MENT 3, CONDENSER BACKPRESSURE LIMIT CURVE (NO)

BOP Check Condenser Vacuum Degrading (NO)

SRO Implement the EALs NOTE: Crew should notify WCC SRO andlor I&C to write a work request, investigate and initiate repairs, and notify the Oper ations Manager.

Booth Operator Insert Event #2 (PZR Pressure Controller PC-444J range shifts) on cue from the Chief Examiner.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 2 Page 7 of 30 Event

Description:

PZR Pressure ControNer PC-444J Rang e Shifts Time I Position ApIicants Actions or Behavior BOOTH OPERATOR: At the discreti on of the Chief Examiner, insert Eve Pressure Controller PC-444J Ran nt 2 PZR ge Shifts EVENT INDICATIONS:

APP-003-D8: PZR CONTROL HIILO PRESS PZR Spray Valves PCV-455A and B OPEN PZR Pressure lowerinci Recognizes PZR Spray Valves are OP RO EN and PZR Pressure lowering below normal control band. Takes Imm ediate Actions of AOP-019, MALFUNCTION OF RCS PRESSURE CONTROL.

Immediate Action Step:

Determine if PZR PORVs should be CLOSED:

RO . Check PZR Pressure less than 2335 PSIG. (YES)

. Verify both PZR PORVs CLOSED. (YE S)

IF any PZR PORV can NOT be CLOS ED, THEN close its PORV BLOCK valve.

Immediate Action Step:

RO Control Heaters and Spray valves to rest ore RCS Pressure to desired control band.

BOP Make PA Announcement for Procedure Entry.

Continuous Action Step:

RO Check PZR Pressure under operator con trol. (YES)

Continuous Action Step RO Check Pressurizer Pressure Transmitte r PT-444 OR PT-445 FAILED (NO)

RO Check PC-444J, PZR PRESSURE ope rating properly in AUTO. (NO)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 2 Page 8 of 30 Event

Description:

PZR Pressure Controller PC-444J Range Shifts Time I Position Applicants Actions or Behavior RO Place PC-444J in MAN. (YES)

RO IF PC-444J is operating properly in manual, THEN Go To Step 9.

(YES)

Operate PC-444J as follows:

a. Check PZR SPRAY VALVE Controllers IN AUTO (YES) -

RO b. Check PZR Heaters IN NORMAL CONFIGURATION (YES)

c. Manually adjust PC-444J to maintain PZR pressure.

d. Check PZR pressure UNDER CONTROL (YES)

SRO Implement the EALs SRO Contact l&C to Make Repairs to the PZR Pressure Contro l System Refer To ITS For Applicable LCOs

. LCO 3.4.11, PZR PORV (N/A)

. TRM 3.4, PZR Spray AT (N/A)

. LCO 3.4.4 AND 3.4.5, RCS Loops (N/A)

SRO . ITS 3.4.1, Condition A, One or more RCS DNB paramete rs not within limits Restore RCS DNB parameters to within limit within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, will be entered due to PZR Pressure being less than 2205 psig (The only applicable LCO.)

. LCD 3.4.9, PZRLev& (N/AL Booth Operator Insert Event #3 (Steam Pressure Channel PT-485 fails LOW) on cue from the Chief Examiner.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 3 Page 9 of 30 Event

Description:

Steam Pressure Channel PT-485 fails LOW Time I*, Position Applicants Actions or Behavior BOOTH OPERATOR: At the discreti on of the Chief Examiner, insert Eve Pressure Channel PT-485 fails LOW nt 3 Steam EVENT INDICATIONS:

APP-006-A4 Steam Line High zP APP-006-B1 S!G B FW>STM Flow APP-006-B2 SIG B STM>FW Flow (W hen bistables are tripped.)

APP-006-B3 S!G B Level 0ev APP-006-E3 SIG B Wide Range HiIL o Level APP-006-E5 Steam Line Low Pressure FR-488, Pen #1 Lowering and Pen #3

- Lowering AOP-025 RTGB INSTRUMENT FAILURE SRO Go To The Appropriate Section For The Failed Transmitter:

SIG Steam Pressure Section G Page 21 SECTION G SIG Steam Pressure Tra nsmitter Failure Immediate Action Step BOP Place The Affected FRV In MAN

. FCV-478 (FRV A) (NO)

. FCV-488 (FRV B) (YES)

. FCV-498 (FRV C) (NO)

BP Immediate Action Step Restore Affected SIG Level To Between 39% And 52%

RO Make PA Announcement For Procedure Entry Place The Affected SIG Steam Flow Selecto r Switch To The Alternate BOP Channel Below:

Failed Channel Affected Channel PT-485 I Selected Position Fl-484 CH 485 Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 3 Page 10 of 30 Event

Description:

Steam Pressure Channel PT-485 fails LOW Time I Position I Arolicants Actions or Behavior Continuous Action Step Restore Affected Controller To Automatic As Follows:

BOP a. Check SIG level -WITHIN +/-1% OF PROGRAMMED LEVEL

b. Place the affected Controller in AUTO Remove The Affected Transmitter From Service Using OWP-025:

BOP I Channel IOWP I PT-485 I SGP-8 OWP-025 GP-8 STEA rdI GENERATOR PRESSURE Main Steam Line B Pressure Transmitter PT-485 BOP FR-488 (STM) Selected To 485 DELETE INPUT PT-485 FROM CALO PROCESSING. (MSPO 421A)

(Two Options)

. Option I Remove via CALO ERFIS program.

o Access Calorimetric on ERFIS by typing CALO o Click on the DELETE INPUTS button. This will display the BOP DELETE INPUT FROM CALORIMETRIC page.

o Select MSPO421A o Click on the ENTER DATA button.

. Option 2 Delete the ERFIS point from scan.

o Access the Delete function by typing DR.

o Click on DELETE SCAN o Enter MSPO421A Trip the Bistables for PT-485 BOP (END OWP-025)

Booth Operator Trip the bistables for PT-485 in accordance with OWP-025, SGP-8, after the operator requests and report completed actio ns SRO Implement The EALs Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 5 Event # 3 Page 11 of 30 Event

Description:

Steam Pressure Channel PT-485 fails LOW Time Position Applicants Actions or Behavior Check Technical Specifications (ITS) For Applicable LCOs

. ITS Table 3.3.1-1 Item 14 which requires 2 SIG Level channels (not affected by the failure) and 2 Steam Flow I Feedwater Flow mismatch channels with Condition E Pla ce channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or Be in Mode 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

. ITS Table 3.3.2-1 Items le, ig, and 4e for Safety Injection and Steam Line Isolation High Steam Line Flow with Low Tave or Low SRO Steam Line Pressure Condition D: Place channel in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> OR Be in Mode 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND Be in Mode 4 within 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br />.

. ITS Table 3.3.3-1 Item 20 Post Accident Monitoring Instrumentation for Steam Generator pre ssure required channels is 2 per S/G which is currently met.

. ITS Table 3.3.6-1 Item 4 Safety Injection for Containment Ventilation Isolation Instrumentation refe rs to LCO 3.3.2 Functions 1 .a-f (which have already been addressed)

NOTE: Crew should notify WCC SRO andlor l&C to write a work request, investigate and initiate repairs, and not ify the Operations Manager.

SRO Return To Procedure And Step In Effect Booth Operator Insert Event #4 (Loss of Cooling to the Auxiliary Transformer) on cue from the Chief Examiner.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 12 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time LI Position IL Apnlicants Actions or Behavior BOOTH OPERATOR: At the direction of the Chief Examiner, insert Event 4, Loss of Cooling to the Auxiliary Transformer.

EVENT INDICATIONS:

APP-009-C6 AUX TRANSF TROUBLE BOP Dispatch an Operator to respond lAW APP-046.

I BOOTH OPERATOR: Acknowledge the request to check the alarms at the Auxiliary Transformer and report the below listed conditions.

Report the following alarms:

APP-46-II, Loss of Normal 48OVac Power Source (18G)

APP-46-3, Loss of Power Cooler #1 (27-1)

BOOTH APP-46-4, Loss of AC Control Power TX-I (27-4)

OPERATOR APP-46-7, Loss of Power Cooler #2 (27-2)

APP-46-8, Loss of AC Control Power TX-2 (27-5)

Attempted to reset the alarms, alarms remained illuminated.

Also, report that NO cooling or oil pumps are operating.

BOP APP-046-1 1 actions are to REFER TO AOP-037.

SRO Directs crew entry to AOP-037.

Crew Make PA Announcement for Procedure Entry SRO Go to Section B for Auxiliary Transformer Dispatch an Operator to the Auxiliary Transformer to determine BOP the alarming function, acknowledge the alarm and attempt to reset the alarm.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 13 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position Appcants Actions or Behavior BOP Check Alarm Function Remains Illuminated. (YES)

NOTE: The APP-046 alarms in the table below are prioritized by SRO importance.

Observe the NOTE OR CAUTION prior to the step and go to the SRO appropriate step based on the listed alarm function that is illuminated.

APP-46-1 1, Loss of Normal 48OVac Power Source (1 8G)

APP-46-3, Loss of Power Cooler #1 (27-1)

APP-46-4, Loss of AC Control Power TX-I (27-4)

BOP APP-46-7, Loss of Power Cooler #2 (27-2)

APP-46-8, Loss of AC Control Power TX-2 (27-5)

Alarms Illuminated. (YES)

Caution: IF the Auxiliary Transformer is operated for more than SRO 30 minutes with no fans or pumps, THEN damage to the Transformer could occur.

Dispatch an Operator to Observe the Status of the Fans and BOP Pumps NOTE: IF APP046-11 orAPP046-12 are valid alarms, THEN SRO there will be no fans OR pumps running and APP-046-3, APP 046-4, APP-046-7, and APP-046-8 will also be illuminated.

BOP Check Status of the Fans and Pumps ALL LOST (YES)

Check Status of 480 Volt Bus 3 POWER LOST (NO)

BOP Goto Step 11 Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 5 Event # 4 and 5 Page 14 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position I Applicants Actions or Behavior Check Status of MCC-4 POWER LOST (NO)

BOP Go to Step 17 BOP Check Status of MCC-4, Breaker 4BR TRIPPED (YES) ttempt to Reset and Close MCC-4, Breaker 4BR One Time.

BOP (YES)

BOP Check Status of MCC-4, Breaker 4BR Closed (NO)

SRO Initiate action to repair problem causing the tripped breaker.

IF breaker MCC-4 (4BR) can NOT be reclosed promptly, THEN SRO o to Step 28.

Continuous Action Step Determine If Trip Required As Follows:

BOP

- Check time elapsed since loss of all cooling Greater than 30 mm. (NO)

IF the Auxiliary Transformer is NOT unloaded within 30 minutes, SRO THEN perform Step 28.b.

Caution Rapid power reductions at the beginning of core life may result in SRO the axial flux difference exceeding the operating band values and require a power reduction to less than 50% to comply with ITS 3.2.3, Condition C.

Reduce power to less than 50% using Attachment 4, Turbine Crew Load Reduction Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 15 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time I Position Applicants Actions or Behavior Check ANY of the following Diesel Generators Paralleled to the G rid BOP -EDGA(NO)

- EDG B (NO)

- DS Diesel (NO)

RO Check Power Less than 50% (NO) (Go to Power Reduction.)

NOTE: The crew is currently in a loop until power is less than 50% RTP and the Auxiliary Transformer Unloaded. The following steps are for the Power Reduction. (Attachment 4, Turbine Load Reduction)

BOP/SRO Notify Load Dispatcher of Load Reduction to less than 50% power.

BOP Check Turbine Control Mode Automatic (YES)

BOP Depress the IMP IN Pushbutton BOP Set the Desired Load in the SETTER BOP Set the Desired Load Rate BOP Depress the GO Pushbutton NOTE: OP-301, Section 8.2.8 Quick Boration Checklist (shaded area) is included in the following steps, as it will be needed for the rapid downpower.

DETERMINE the amount of Boric Acid to add to the RCS and RO OBTAIN an independent check of the volume required.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 16 of 30 Event

Description:

Loss of Coohng to the Auxiliary Transformer Time -

II Posion Applicants Actions or Behavior NOTE: -85 gallons of Boric Acid. (The crew will add Boric Acid in 2-4 batches.) (Values based on 3%Irnin load reduction rate)

OBTAIN permission from the CRS OR the SM to add the amount of RO boric acid previously determined, including the expected change in RCS temperature and Reactor Power RO PLACE the RCS MAKEUP MODE selector switch to in the BORA TE position.

RO SET YIC-1 13, BORIC ACID TOTALIZER to the desired quantity.

IF desired, THEN PLACE FCV-113A, BORIC ACID FLOW, in MAN RO AND manually ADJUST controller FCV-1 13A, BORIC ACID FLOW usinq the UP and DOWN pushbuttons flow rate.

RO Momentarily PLACE the RCS MAKEUP SYSTEM switch to the START position.

IF any of the below conditions occur, THEN momentarily place the RCS MAKEUP SYSTEM switch in the STOP position:

RO

• Rod Motion is blocked or in the wrong direction

• TAVG goes up

• Boric Acid addition exceeds the desired value WHEN the desired amount of Boric Acid has been added to the RCS, THEN verify the following:

• FCV-113A, BORIC ACID FLOW, closes.

RO

• FCV-113B, BLENDED MU TO CHG SUCT, closes.

• IF in Auto, THEN the operating Boric Acid Pump stops.

• __The_RCS_MAKEUP_SYSTEM_is_OFF.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 17 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position Atolicants Actions or Behavior IF desired, THEN FLUSH the Boric Acid flow as follows:

. PLACE the RCS MAKEUP MODE selector switch in the ALT DILUTE position.

. SET YIC-1 14, PRIMARY WTR TOTALIZER to 15-20 gallons.

. PLACE FCV-1 14B, BLENDED MU TO VCT to the CLOSE position.

. Momentarily PLACE RCS MAKEUP SYSTEM switch to the START position.

. IF any of the below conditions occur, THEN momentarily place RO the RCS MAKEUP SYSTEM switch in the STOP position:

o Unanticipated Rod Motion o Primary Water addition reaches the desired value

. WHEN the desired amount of Primary Water has been added to the RCS, THEN verify the following:

o FCV-114A, PWTO BLENDER, closes.

o FCV-113B, BLENDED MU TO CHG SUCT, closes.

o IF in Auto, THEN the operating Primary Water Pump stops.

o The RCS MAKEUP SYSTEM is OFF RETURN the RCS Makeup System to automatic as follows:

. VERIFY FCV-1 14A, PRIMARY WTR FLOW DILUTE MODE is in AUTO.

. PLACE FCV-1 14B, BLENDED MU TO VCT to the AUTO RO position.

. PLACE the RCS MAKEUP MODE switch in the AUTO position.

. VERIFY FCV-113A, BORIC ACID FLOW, is in AUTO.

. Momentarily PLACE the RCS MAKEUP SYSTEM switch in the START Iosition.

RECORD, in AUTO LOG, as indicated by PRIMARY WATER RO TOTALIZER, YIC-1 14 AND Boric Acid TOTALIZER, YIC-1 13 the total amount of Primary Water AND Boric Acid added during the boration.

MONITOR parameters for the expected change in reactivity AND RO inform the CRS OR the SM the results of the boration.

NOTE: End of Boration and Power Reduction Steps. AOP-037 steps continue below.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 18 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time N Position N Apphcants Actions or Behavior Stop the following components:

1. Circulating Water Pump A BOP 2. Feedwater Pump A

3. Heater Drain Pump A

4. Condensate Pump B Transfer loads from the Auxiliary Transformer to the Startup BOP Transformer with the Unit at greater than 1 10 Mwe using Attachment 5, Transfer of Electrical Loads to the Startup Transformer.

NOTE: The following steps are from Attachment 5, Transfer of Electrical Loads to the Startup Transformer.

BOP Notify the Load Dispatcher of the 4KV switching evolution Insert key into Startup Transf synch roscope switch AND turn switch to BOP STARTUP BUS 2 position WHEN the synchroscope comes up to the 12 oclock position, THEN BOP close START-UP TO 4KV BUS 2 BKR 52/12 WHEN breaker 52/12 indicates closed, THEN return switch to the mid-BOP position AND verify UNIT AUX TO 4KV BUS 1 BKR 52/7 has opened.

Insert key into 4KV TIES synchroscope switch AND turn switch to BUS BOP 3 & 4 position.

WHEN synchroscope comes up to 12 oclock position, THEN close BOP 4KV BUS 3-4 TIE BKR 52/1 9.

WHEN breaker 52/19 indicates closed, THEN return switch to the mid BOP position AND verify UNIT AUX TO 4KV BUS 4 BKR 52/20 has opened.

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 4 and 5 Page 19 of 30 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time position Applicants Actions or Behavior BOP Turn synchroscope key switch to mid position.

BOP Check Auxiliary Transformer Unloaded (YES)

Check Auxiliary Transformer Alarm Status as Follows:

BOP a. Press and release the Reset pushbutton.

b. Check all APP-046 Alarms extinguhed. (NO)

IF APP-046 Alarms are present that have not been addressed, THEN SRO qo to Ster 3.

SRO Implement the EALs.

Check Technical Specifications for Applicable Action Statements.

3.8.1 AC Sources Operating (N/A)

SRO 3.8.2 AC Sources Shutdown (N/A) 3.8.9 Distribution Systems Operating (N/A) 3.8.10 Distribution Systems Shutdown (N/A)

NOTE: Crew should notify WCC SRO andlor I&C to write a work request, investigate and initiate repairs for the loss of cooling to the transformer, and notify the Ooerations Manacier.

SRO Check Status of Condition Causing Alarm Corrected (NO)

BOOTH OPERATOR: As soon as the power reduction is? 5% or at the discretion of the Chief Examiner, insert Event # 6 (B S!G Feedwater Regulating Valve FCV-488 fails closed.)

Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D2 Op Test No.: 1 Scenario# 5 Event# 6,7,8,9, 10, Page 20 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time 0 Position 1 Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 6, B SIC Feedwater Regulating Valve FCV-488 fails closed.

EVENT INDICATIONS:

APP-006-B2, SIG B STM>FW FLOW APP-006-B3, SIG B LVL DEV APP-006-E1, S!G B NAR RANGE LOILO-LO LEVEL (Once low level is reached.)

FR-488 Pen 2 Feed Flow Lowers to 0 PPH FCV-488 Indicated CLOSED on the RTGB Immediate Action Step (AOP-O10)

BOP Check Feedwater Regulating Valve Operating Properly (Manual OR Auto) (NO)

Verify FRV for affected S/G in manual control. (Takes manual control BOP of FCV-488 and attempts to OPEN) (No response from controller.)

BOP Stop any load change in progress. (Turbine to Manual, if applicable)

IF unable to control SIG level THEN trip the Reactor AND Go to BOP PATH-i. (YES)

Immediate Action Step:

RO Reactor Tripped. (YES)

Immediate Action Step:

BOP Turbine Tripped.(NO)

Trip or Runback the Turbine. (YES, Runback was successful)

Booth Operator: Manually trip the Turbine locally, if requested, after a 3 mm time delay.

Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 21 of 30 11 Event

Description:

B S/G FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744A1B fail to auto-open Time Position Applicants Actions or Behavior Immediate Action Step:

BOP E-l AND E-2 energized. (YES)

Continuous Action Step BOP IF DS Bus is deenergized THEN place DSDG in service using EPP 25.

Immediate Action Step:

RO SI Initiated. (YES)

SRO Enters PATH-I and verifies Immediate Actions.

CREW Open Foldout A.

MSR Isolation Criteria.

BOP IF ANY Purge OR Shutoff Valve does not indicate fully closed, THEN place the associated RTGB Switch to CLOSE.

NOTE: Operators may identify that steam dump valves have failed open and cannot be closed and take action to close the MSIVs.

NOTE: Operators may identify that RHR-744A and -744B failed to auto-open on SI and take action to open the valves.

Booth Operator: If requested to locally close the Steam Dumps, the task will be successful to close the valves. Begin isolating the steam dumps 5 minutes after requested.

RO Verify Phase A Isolation valves are closed. (YES)

Appendix D NUREG-I 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 22 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744A1B fail to auto-open Time Position I Alicants Actions or Behavior BOP Verify FW Isolation valves are closed. (YES)

BOP Verify both FW pumps are tripped. (YES)

Verify both MDAFW pumps are running. (NO) (Unable to start any BOP MDAFW pump from RTGB.)

BOP If additional Feedwater is required, start the SDAFW pump. (NO, SDAFW Pump started but tripped)

SRO WCC SRO or AO may be dispatched to investigate the cause of the MDAFW Pump B and SDAFW Pump trip.

RO Verify 2 SI pumps running. (YES)

RD Verify Both RHR pumps running. (YES)

Verify SI valves are properly aligned. (NO)

RO RHR-744A1B failed to auto-open on SI. Manual acflon must be taken to open the valves.

RO At least one CCW pump is running. (YES)

BOP All SW and SW Booster pumps running. (YES)

RD Verify CV Fans HVH-1, 2, 3, 4 running. (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: I Scenario # 5 Event # 6, 7, 8, 9, 10, Page 23 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time Poson Applicants Actions or Behavior RO Verify IVSW System Initiated. (YES)

Verify CV Ventilation isolation. (YES)

Verify the following valves CLOSED:

- V12-6, CONT PURGE VALVE

- V12-7, CONT PURGE VALVE

- V12-8, CONT PURGE VALVE RO

- Vi 2-9, CONT PURGE VALVE

- V12-10, CONTAINMENT PRESSURE RELIEF

- V12-11, CONTAINMENT PRESSURE RELIEF

- V12-12, CONTAINMENT VACUUM RELIEF

- V12-13, CONTAINMENT VACUUM RELIEF Verify Control Room Vent aligned for Pressurization Mode. (YES)

Operator to verify the following:

- Verify CONT RM AIR EXHAUST Fan, HVE-16 - STOPPED

- Verify CLEANING Fan HVE-19 A/B - RUNNING BOP - Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1A-SA CLOSED -

- Verify CONTROL ROOM AIR EXHAUST FAN DISCHARGE DAMPER, CR-D1 B-SB CLOSED -

U CR-D1A-SA OR CR-D1 B-SB have lost power, THEN locally verify_position in the Control Room Kitchen.

BOP Verify both EDGs running. (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.; 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 24 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time Position Applicants Actions or Behavior CONTINUOUS ACTION STEP:

BOP Restart battery chargers within 30 minutes of power loss using OP 601.

CONTINUOUS ACTION STEP:

RO CV Pressure has remained below 10 psig. (YES)

BOP Automatic Steam Line Isolation Initiated (ND)

BOP Automatic Steam Line Isolation Required (YES)

Critical Verify all MSIVs AND MSIV Bypasses Closed BOP Task MSIVs must be manually closed, if not performed earlier.

Locally open breaker for HVS-1 at MCC-5 CMPT 7J within 60 mm of SRO SI Initiation.

Booth Operator Open the breaker for HVS-1 within approximately 3 minutes of request.

RCS pressure> 1350 psig. [1250 psig] (YES)

(May be NO if manual turbine runback not started immediately or if the RD steam dump malfunction not identified. Contingency steps have been added should RCS pressure be less than 1350 psig and are annotated with a@ symbol.)

RD @ SI Flow Verified (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 25 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time Position Applicants Actions or Behavior RO @ RCS pressure> 125 psig (YES)

BOP At least 300 GPM AFW flow available. (NO)

BOP Level in at least one SIG greater than 8% [18%] (NO)

BOP Align AFW valves.

BOP At least 300 GPM AFW flow verified (NO)

Reset SPDS and Initiate Monitoring of Critical Safety Function Status RO Trees Transition to FRP-H.1, RESPONSE TO LOSS OF SECONDARY SRO HEAT SINK.

Check Total Feed Flow less than 300 GPM due to operator action.

BOP (NO)

Determine if Secondary Heat Sink is required:

. Check RCS pressure greater than any non-faulted SIG pressure. (YES)

RO

• Check RCS temperature greater than 350°F [310°F] (YES)

(May be NO if manual turbine runback not started immediately or if the steam dump malfunction not identified. Contingency steps have been added should RCS temperature be less than 350°F and are annotated with a symbol.)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 26 of 30 11 Event

Description:

B S/G FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time Position Applicants Actions or Behavior SRO @ Place RHR System in service using Supplement I.

SRO @ Consult Plant Operations Staff to determine if RHR should be placed in Core Cooling Mode.

Booth Operator Operations Staff is not currently available for consultation.

RO @ Check RHR System To be used in core cooling mode. (YES)

RO @ Check RCS Pressure Less than 375 psig [350 psig] (NO)

RO @ WHEN RCS pressure less than 375 psig [350 psig], THEN go to Step 4.

Examiners Note: Crew should have realized at this point that Supplement I is not the appropriate mitigation strategy and transition back to FRP-H.1.

Continuous Action Step:

BOP Check Any TVVO S/G Wide Range Levels less than 10%. [19%] (NO)

Continuous Action Step:

BOP Check CST level Greater Than 10% (YES)

Verify all SIG Blowdown AND Sample Isolation Valves CLOSED BOP (YES)

BOP Check AFW Lines INTACT (YES)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 27 of 30 11 Event

Description:

B S/G FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744NB fail to auto-open Time Position Aoolicants Actions or Behavior BOP Check AFW Pump Breakers Tripped (YES) (B MDAFW Tripped.)

Attempt to reclose breaker on B MDAFW Pump as follows:

a. Position the MDAFW Pump Control Switch to the STOP position.

BOP

b. Reset SI

c. Position the MDAFW Pump Control Switch to the START position.

BOP Check MDAFW Pump RUNNING (NO)

SRO Contact I&C to investigate the tripped breaker.

Attempt to Start SDAFW Pump as follows:

BOP Verify SDAFW Steam Shutoff Valves OPEN (V1-8A,B,C opened and then re-close on SDAFW Pump trip.)

Locally investigate AND attempt to restore AFW Flow as follows:

a. Verify B AFW Pump suction supply is available.

b. Position the B MDAFW Pump LOCAL/REMOTE Switch to LOCAL BOP c. Attempt to start the B MDAFW Pump as follows:

1) Depress the B MDAFW Pump local STOP Pushbutton

2) Depress the B MDAFW Pump local START Pushbutton

3) Check B MDAFW Pump STARTED (NO)

Place the LOCAL/REMOTE Switch to REMOTE.

BOP Check AFW Flow to S/Gs Greater than 300 gpm. (NO)

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 5 Event # 6, 7, 8, 9, 10, Page 28 of 30 11 Event

Description:

B S/G FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744A1B fail to auto-open Time Position I Applicants Actions or Behavior RO Stop ALL RCPs BOP Check Condensate System IN SERVICE (YES)

Place ALL the Feedwater Isolation Key Switches in the OVRD/RESET RO Position Attempt To Establish Feedwater Flow AS Follows:

a. Verify the FW HDR SECTION Valves CLOSED (YES)

. V2-6A

. V2-6B

. V2-6C

b. Start one Main FW Pump (YES)

Critical c. Open the FRV Bypass Valves BOP Task

• FCV-479

. FCV-489

• FCV-499

d. Check FW Flow Established (YES)

Criteria: Must be performed prior to 2 SIG WR Levels reaching less than 10%.

Check SIG Levels As Follows:

BOP a.__Level_In At_Least_One_SIG_-_GREATER THAN_8%_[18%]_(NO)

Determine If Feedwater Flow Is Adequate:

a. Check the following:

• Core Exit T/C Temperature LOWERING (YES)

BOP OR

• S/G Wide Range Level RISING IN AT LEAST ONE S/G (YES)

b. Maintain FW flow to restore S/G Level to greater than 8%[1 8%]

c. Reset SPDS And Return To Procedure And Step In Effect Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 5 Event# 6,7,8,9, 10, Page 29 of 30 11 Event

Description:

B SIG FRV FCV-488 fails closed, Turbine Trip does not occur, Steam Dump Valves fail Open, MSIVs fail to close on auto-close signal, RHR-744A1B fail to auto-open Time Position 1 Applicants Actions or Behavior The Chief Examiner may terminate the scenario anytime after FW flow has been established to at least one SIC, or at his discretion.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

ILC-11-2 NRC SCENARIO 5 TURNOVER SHEET POWER LEVEL: 68% RTP Core Burnup: 15697 MWD/MTU EFPD: 448 EFPD Boron: 132 PPM Xenon: Approaching EQ 37 pcm/hr and lowering.

Tavg: 565.8°F Bank D Rods 168 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW pump inoperable with breaker racked out

• Switchyard access is RESTRICTED.

EQUIPMENT STATUS:

• Automatic Rod Control is not operable.

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• A HDP recently started for PMT following maintenance. Maintain current power while RES is evaluating PMT results.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board w Date: Today Time: 6:00:00 AM Cycle: 127 IMWD/MT: 15697 lflesign: 16590 EFPD 448 Design 473.5 Tank [Level% Status HUT ,  % Status MonitorA 10 Standby Monitor 8 38 j Standby_____________

WCT A 37 Standby Standby WHUT #NAME? Fillina WCTC 9 Standby WCTD 10 [ Standby inked to P1 WGDTS Pressure PSIG Status WCTE [9 r Standby A #NAME? PSIG On cover DEMINERALIZERS B #NAME? jG In Service

ç#NAME?iGoted PPM In Service LOate MB A YES 7/1 7/2010 5/4/2010 MB 8 2265  !/0103I2912010 CATION 1021 NO 9117/2010 12/9/2009 Shutdown Requirement Temp Boron DEB A [ NO New 2/312010 1.77% =LK1K 547 F Hot 258 DEB B 0 NO 3128/2010 1.77%=AKIK >350 F 611 SFP 1963 [NO 9123/2008 2.6% AKIK 776 6% =LKIK NIA 1950 SGBD Condenser Air Inleakage Target Value GPM Status PORV Settings 13 CFM A 50 Flash Tank Setting Date [POT [GP-3 Psig B[0[CFM 8 50 With Heat A 711812010 3.21 1000 K_CF_ C 50 Recovery BTh8120102 Total 5 CFM N2 Flow 8 [SCFM C 7/18/2010 3.44 1000 Effluent Radiation Monitor Setpoints RCS Leakage Rad !Current 0.00 Unidentified .

Monitor Setpoint Alert Value 200X NUE Value 2X R-14C 1.01 E+04 N/A 2.020E+04 PRT cJ!GPM R-20 7.40E+03 N/A 1.480E+04 RCDT Leakage 0.01 GPM R-18 L2.000E+06 Charging Leakoff 0 GPM R-19A 1.05E+04 2.IOOE+06 Misc Identified 0 GPM R-1 98 I .944E+04 PrimarylSecondary 0 GPO R-19C 1 9.58E+03 1.916E+06 1.916E+04 Secondary Loss 3

-ji jiiiTvi R-378.53E+03 1.706E+06 Manually Entered Data Linked to Chem data base Hi Flux At Shutdown Boron PPM Date PPM Date PPM Previous ARI Counts Setpoint RCS LTY 132 150 Bj/16I2010 21,535 #NAME? #NAME?

Nl-32 60 180 BAST-B 9/16/2010 21,032 #NAME? #NAME?

SFP 9/15I2010 2246 #NAME? #NAME?

Normal Currents RWST 6ói0 2219 #NAME? NAME?

LOWER GETAND Accum-A 8/30/2010 2211

1. NAME? #NAME?

N-41 144 36 0.0212 5+1- Accum-B 8/30/2010 2206 #NAME? #NAME?

N-42126 125T0M212 5+!- Accum-C OI 3

I 8

O 1

2 O

223 j #NAME? [#NAME?

113 12 5+!- RHR 7/6/2010 2221 N-44 112 [1o8Ji2 Jf/. RCanalL FOWERTRAXRev#2.1.ORNP I%APL 112.55 Refuel Cavity SFP Canal FANS TestlHrs DatelTst HVE-IAIB 35640.6 3/8(10 I Notes/Additional Data 5A1864Ti3/18I1o IC-17, 20, 22 HVE-I9AIB [6928.3 513/10 EOL SR 3.7.11.2 Last Completed 5/27/2010 19:45

ILC-11-2 NRC SCENARIO 5 TURNOVER SHEET POWER LEVEL: 68% RTP Core Burnup: 15697 MWD/MTU EFPD: 448 EFPD Boron: 132 PPM Xenon: Approaching EQ 37 pcm/hr and lowering.

Tavg: 565.8F Bank D Rods 168 Steps EQUIPMENT UNDER CLEARANCE:

• A MDAFW pump inoperable with breaker racked out

• Switchyard access is RESTRICTED.

EQUIPMENT STATUS:

• Automatic Rod Control is not operable.

• Currently thunderstorm watch is in effect for Darlington and Chesterfield counties.

INSTRUCTIONS FOR THE WATCH:

• A HDP recently started for PMT following maintenance. Maintain current power while RES is evaluating PMT results.

Appendix D NUREG-1 021, Rev. 9, Supp. 1

Unit 2 Status Board IDate: Today ITime: 6:00:00 AMCycIe: 27 IIFPD 448 MWD(MT: 15697 IDesign:

IDesicin 473.5 16590 HUT Level% Tank lLevel%

Status Status CVCS-A MonitorA 10 20 Filling Standby CVCS-B 10 Monitor B 38 Standby Standby CVCS-C 86 WCT A 37 Standby Standby WHUT i#NAME? WCT B 17 Filling Standby WCT C 19 Standby Data Linked to Pt wcr o Ji Standby WGDTS WCT E 19 Pressure PSIG Status Standby A #NAME? IPSIG On cover DEMINERALIZERS B #NAME? PSIG In Service ,

PPM .

In Service Date Resin D #NAME? JPSIG Replaced

)solated D MBA 2194 1#NAME? PSIG Standby YES 7/17/2010 514(2010 MB B 2265 NO 7I17I2010_/2912010 Shutdown Requirement CATION 1021 NO Temp 9/17/2010 12/9/2009 Boron DEB A 1.77% =tK/K 0 NO 2(3(2010 547 F Hot 258 New 1.77%=LK1K DEBB 0 NO

>350 F 611 3/28/2010 2.6%=M<JK SFP 1963 rNO 100 F Cold 9/23/2008 4(22/2008 776 6%=AK/K N/A 1950 SGBD Condenser Air Inleakage PORV_Settings Target Value GPM I Status A 13 CFM Setting Date POT GP-3Psig A 50 Flash Tank A 1711812010 3.21 CFM B 50 With Heat 1000 Known B 7/18/2010 3.12 CFM C 50 Recovery 1040 Total C 5 CFM N2 Flow 7/18/2010 3.44 1000 8 SCFM Effluent Radiation Monitor Setpoints RCS Leakage Rad 0.00 Unidentified Current Alert Value 200X NUE Value Monitor Setpoint I Total 2X 0.03 GPM R-14C PRT 1.OIE+04 N/A 0.02 GPM 2.020E+04 R-20 7.40E+03 NIA RCDT Leakage 0.01 1.480E+04 GPM R-18 Charging Leakoff 1.OOE+06 2.000E+08 0 2.000E+06 GPM R-19A 1.05E+04 Misc Identified 2.IOOE+06 2.IOOE+04 0 IGPM R-198 9.72E+03 1.944E+06 Primary(Secondary 0 1.944E+04 GPD R-19C Secondary Loss 9.58E÷03 1.916E+06 17.3 1.916E+04 R-37 8.53E+03 1 1.706E+06 I.706E+04 Hi Flux At Shutdown Manuafly Entered Data Linked to Chem data base Previous ARI Counts Boron PPM Date PPM Setpoint Date PPM Nl-31 50 RCS Today 132 150 Nl-32 60 BAST-A 9116/2010 21,535 180 #NAME? J#NAME?

BAST-B 9/16/2010 21,032 #NAME? #NAME?

SFP 9/15/2010 2246 Normal Currents #NAME? #NAME?

UPPER RWST 9/16(2010 2219 LOWER TARGET #NAME? #NAME?

N-41 1% BAND Accum-A 8/30(2010 2211 144 #NAME? #NAME?

N-42 126 Accum-B 8130/2010 2206 125 0.0212 #NAME? #NAME?

N-43 Accum-C 8(30(2010 [2230 1121 113 .0.0212 5+,- #NAME? #NAME?

N-44 112 RHR T7iIoio 12221 108 0.0212 POWERTRAXRev#2.1.ORNP Refuel Canal

%APL 112.55 Refuel Cavity SFP Canal FANS TestlHrs Date/Tst HVE-IAIB 35640.6 3/8/10 HVE-15A Notes/Additional Data 118643.5 3/18(10 HVE-I9AJB IC-17, 20, 22 6928.3 5/3/10 SR 3.7.11.2 Last Completed EOL 5/27/2010 19:45 I