Text

Initial Exam 2011-302 Draft Simulator Scenarios
	ML120470364
Person / Time
Site:	Robinson
Issue date:	02/10/2012
From:	; NRC/RGN-II
To:	;
	Mark Bates
References
	Download: ML120470364 (155)
	v • d • e

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 SIG Restore Seal Cooling to the RCPs within 15 minutes or isolate seals Event MaIf.

Event Type*

Event 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 / Load Reduction (N) BOP, SRO (I) BOP, SRO 3

S/G C LT-496 fails HIGH 1(TS),SRO (6) RO, SRO (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 ljQ7 CondilionA, was in effect while the normal supply breaker to Instrument Bus #1 was open. This LCD requires that the AC Instrument Bus Power Source be restored to Operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Additionally, ITS LCD 9CondjtionB was in effect while Instrument Bus #1 was de-energized. This LCD requires that the AC instrument bus subsystem be restored to Operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . SLCO_4.

gndjtionA may be entered if pressurizer level is allowed to rise above 63.3%. The LCD requires that the plant be in Mode 3 with reactor trip breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Mode 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . ITS LCO3.4.1, 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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or be in Mode 2 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

On cue from the Chief Examiner,lightning 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 / 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-01 0.

On cue from the Chief Examiner, C S/G LT-496 fails HIGH, affecting the automatic operation of Feedwater Regulating Valve FCV-498 for S/G C. The operator will have to take manual control of the FRV and restore the S/G 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 requires3SIG Level channels with QonitionPlac?ch?nEfl th within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 3 in 12 hournd ITS 33 8-1 Item 1 which requires 3 S/C Level channels with Condition C

- PlacehFiW in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 3 inf2 18ho.

On cue from the Chief Examiner, a seismic event will occur. APP-036-15, 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 Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-l 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 LRM 3.i7J Shutdown limits of O.iOg horizontal acceleration and O.067g vertical acceleration and that the it must be placed in Mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Mode 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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 S/G. Also, after the loss of off-site power the A Battery Charger will fail to restart when power is restored to 480V Bus E-1. 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-Oi 8, RCP Malfunctions, due to meeting the Loss of RCP Seal Cooling Criteria. AOP-0i8 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-102i, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 ILC-11-2 NRC SCENARIO I SIMULATOR SETUP ICISETUP:

IC-801, SON: 0081 l_2_N RC_Exa rn_I A MDAFW Pump inoperable with the breaker racked out. Switch RED capped.

Status board updated to reflect 10-21.

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-1 EVENTS!TRIGGERS 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-O1O 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-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

1 Event #

1 Page 5

of 40 Event

Description:

Loss of Instrument Bus #1 Time 1

Position II 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 BOP Immediate Action Step Verify S/G(s) Maintained At Program Level Immediate Action Step RO Place Rods in M (Manual)

SRO Enters AOP-024 and verifies Immediate Actions.

RO Maintain Reactor Power 1 00%

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

RO Check Auto Makeup, Boration OR Dilution In Progress (NO) (Auto 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.:

1 Scenario #

1 Event #

1 Page 6

of 40 Event

Description:

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

RD (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.

RD (Letdown cannot be restored until Instrument Bus 5 energized.)

RD 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 S!G 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)

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

RD Place The Selector Switch For LCV-460A & B In The Closed Position RD Verify only ONE Charging Pump running at minimum speed 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 7

of 40 Event

Description:

Loss of Instrument Bus #1 Time Position Applicants Actions or Behavior RO RO Check RCP Seal Injection Flow between 8 GPM and 13 GPM Adjust HCV-121, Charging Flow OR Throttle Seal Water Flow Control valves 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 lB-4 IF the cause is known AND NOT a fault, THEN attempt to reset 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.)

BOP a.

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

Check Local Actions Of Step 19 RNO ATTEMPTED (YES)

BOP Examiners Note:

LCO 3.4.1 for PZR Pressure < 2205 psig. Z Booth Operator Transfer Instrument Bus I to Alternate Power Supply SRO Stop All Radioactive Batch Releases Check Status Of Local Actions:

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 40 Event

Description:

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

Restore Affected Controllers On The RTGB To AUTO Mode (All Controllers go to Auto EXCEPT FC-605 which has no instrument air aligned 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 (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 toD of the VCT.)

Examiners Note Possible ITS LCO 3.4.9 entry for PZR Level greater than 63.3%.

Continuous Action Step Restore Rod Control To Automatic As Follows:

a.

Check Power

- GREATER THAN 15% (YES) b.

Check Automatic Rod Control AVAILABLE (YES) c.

Check Tavg WITHIN -1.5 TO +1.5F OF TREF d.

Place the Rod Control Selector Switch to A (Automatic)

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

Continuous Action Step Check Emergency Busses E-1 AND E-2

- ENERGIZED FROM THEIR 4160V BUSSES (YES)

Implement The EALs 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 9

of 40 Event

Description:

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

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 RD 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)

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

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

RD 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 40 Event

Description:

Loss of Instrument Bus #1 Time 1

Position Applicants Actions or Behavior RO I BOP RO/BOP RO I BOP RO/BOP RO / BOP PERFORM the following:

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

.__PLACE_LTDN_LINE_STOP_CVC-460 A&B_switch_to AUTO.

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

A Phase A Containment Isolation signal is NOT present.

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 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 VERIFY FULL OPEN HIC-121, CHARGING FLOW (CR 95-01752)

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

(YES)

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

PLACE PC-145, PRESSURE, in MANUAL.

SET PC-145 to throttle PCV-145 to 45% to 55% open to ensure the Letdown line is NOT overessurized.

OPEN CVC-204B, LETDOWN LINE ISO.

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

1 Event #

1 Page 11 of 40 Event

Description:

Loss of Instrument Bus #1 Time ii osition Applicants Actions or Behavior RO I BOP RO/BOP RO I BOP RO I BOP PLACE TC-144, NON-REGEN HX OUTLET TEMP, in MANUAL AND 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 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:

CVC-200A, CVC-200B or CVC-200C 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 psiq.

RO 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:

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

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

1 Event #

I Page 12 of 40 Event

Description:

Loss of Instrument Bus #1 Time II Position II Applicants Actions or Behavior RO I BOP 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.

jf 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 requirement.

Place PC-145, PRESSURE, in MANUAL.

Slowly Throttle Open PC-145 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-1,2,3,4 OPEN (YES)

AND R-1 1 and R-1 2 Vacuum Pump Operating (YES)

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 13 of 40 Event

Description:

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

Check R-21 IN SERVICE (YES)

Check Control Room Ventilation

- ALIGNED FOR PRESSURIZATION MODE (NO)

Go To Step 43.

RO RO 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:

Depress RESET RC-551A Pushbutton.

Depress RESET RC-551B 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:

INVERTERA IB-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 40 Event

Description:

Loss of Instrument Bus #1 Time Position Applicants Actions or Behavior BOP SRO RO 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 operable status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Check Annunciator APP-005-A3, PR DROP ROD

- ILLUMINATED (YES)

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

Check APP-006-F5, Steam Dump Armed

- Illuminated (NO)

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

Reset AMSAC TROUB/BYP Alarm by depressing the System Reset 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 40 Event

Description:

Heater Drain Pump A Trips I Load Reduction Time Position 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 OVLD!TRIP APP-007-B6 HOT HIILO LVL Heater Drain Pump A GREEN off indication ILLUMINATED AOP-O1 0 MAIN FEEDWATER!CONDENSATE 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.

Goto Step 4.

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

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 Following Table:

SRO I

Main FWP I

Cond I

Htr Drn PUMPS RUNNING I Target Power 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 40 Event

Description:

Heater Drain Pump A Trips I Load Reduction Time Position Acolicants Actions or Behavior BOP BOP BOP BOP RO BOOTH OPERATOR: Report the following AMPS as the current readings.

Main Feedwater Pump 560 AMPS Condensate Pumps 310 AMPS Heater Drain Pump 75 AMPS CREW SRO BOP Check Main FW Pumps

- TWO PUMPS RUNNING (YES)

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 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 repairs.

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

Check S/G Level

- AT OR TRENDING TO PROGRAM (YES)

Check Tavg

- AT OR TRENDING TO Tref (YES)

Contact Maintenance To Troubleshoot And Correct The Feedwater Problem Implement the EALs Check current loading for the following pumps

- LESS THAN MAXIMUM (YES)

Main Feedwater Pump

- 0.7 15 KAMPS Condensate Pumps

- 370 AMPS Heater Drain Pumps

- 90 AMPS 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 40 Event

Description:

Heater Drain Pump A Trips / Load Reduction Time Position Aoolicants Actions or Behavior BOP BOP BOP SRO RO RO CREW SRO Power Reduction Required by A Heater Drain Pump Trip BOP AOP-O1O Attachment 1, Turbine Load Reduction Check Turbine Control Mode AUTOMATIC (YES)

Continuous Action Step Check HCV-1 459, LP HEATERS BYP OPEN (NO)

Monitor Feed Water Pump suction pressure (Local Indication)

P1-1433 A FW Pump Suction Pressure P1-1434 B FW Pump Suction Pressure IF pressure lowers to less than the applicable setpoint, THEN verify OPEN HCV-1459. (NO)

Any HDP Running 300 psig No HDP Running 350 psig Continuous Action Step Determine Iodine Sampling Requirements As Follows: (NO) a.

Check Power Change

- GREATER THAN 15% IN ONE HOUR Go To Step 44 IF YES, then implement SR 3.4.16.2 Continuous Action Step Check APP-005-B5, ROD BANKS AIB/C/D LO LIMIT

EXTINGUISHED (YES)

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

Notify Load Dispatcher Of The Units Load Capability 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 18 of 40 Event

Description:

Heater Drain Pump A Trips I Load Reduction Time Position Anrlicants Actions or Behavior BOP BOP BOP BOP BOP RO RO RO Depress the IMP IN Pushbutton Set The Desired Load In The SETTER Set The Desired Load Rate Depress The GO Pushbutton END-AOP-010 Attachment I IF a Power Limit Warning is received, reduce power by lowering the 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 60 gallons of Boric Acid to be added RO Momentarily PLACE the RCS MAKEUP SYSTEM switch to the START position.

RO RO DETERMINE the amount of Boric Acid to add to the RCS and OBTAIN an independent check of the volume required OBTAIN permission from the CRS OR the SM to add the amount of boric acid previously determined.

PLACE the RCS MAKEUP MODE selector switch in the BORATE oosition.

SET YIC-1 13, BORIC ACID TOTALIZER to the desired quantity.

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

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

1 Event #

2 Page 19 of 40 Event

Description:

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

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:

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

FCV-113B, 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 1 5-20 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.

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

1 Event #

2 Page 20 of 40 Event

Description:

Heater Drain Pump A Trips! Load Reduction Time Position Applicants Actions or Behavior 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.

PLACE the RCS MAKEUP MODE switch in AUTO.

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 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 inform the CRS OR the SM the results of the boration.

END OP-301 Section 8.2.8)

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 21 of 40 Event

Description:

SIG C LT-496 fails HIGH Time II Position II Applicants Actions or Behavior EVENT INDICATIONS:

APP-006-C2, SIC C STM> FW FLOW APP-006-C3, SIG C LVL DEV APP-006-F2, SIC C NAR RANGE HI LEVEL FR-498, Pen 3 failing HIGH 14 BOOTH OPERATOR:

When directed, initiate Event 3, SIC C LT-496 fails HIGH AOP-025 RTGB Instrument Failure SRO Go To The Appropriate Section For The Failed Transmitter:

S/G NARROW RANGE LEVEL SECTION D I Page Immediate Action Step BOP Place The Affected FRV In MAN FCV-498 (FRV C) (YES)

BOP Immediate Action Step Restore Affected S/G 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 I LT-496 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.

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.

IOWP SGL-9 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 40 Event

Description:

SIG C LT-496 fails HIGH Time 0 ition Applicants Actions or Behavior BOP BOP BOP BOP BOP BOP Check Technical Specifications (ITS) For Applicable LCOs ITS LCO 3.3.1 SRO ITS [CO 3.3.2 ITS [CO 3.3.3

.__ITS_LCO_3.3.4 BOP SRO SRO AMSAC PROCESSOR A LEVEL 3 NORMAL/BYPASS SWITCH (AMSAC PANEL)

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

BISTABLE SWITCH BS 496-1 RACK #16 Tripped BISTABLE LIGHT SG NO. 3 HI LEVEL LC496-1 Illuminated BISTABLE SWITCH BS 496A-1 RACK #16 Tripped BISTABLE LIGHT SG NO. 3 LO-LO LEVEL LC496A1 Illuminated FCV-498 CONTROLLER Manual END OWP-027 SGL-9 AOP-025 Go To Procedure Main Body, Step 2 Implement The EALs Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Event

Description:

Time Scenario #

1 Event #

3 Page 23 of 40 SIG C LT-496 fails HIGH Position Applicants Actions or Behavior Return To Procedure And Step In Effect SRO END AOP-025 Appendix D NUREG-1 021, 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 40 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 II Aoolicants Actions or Behavior 13 BOOTH OPERATOR:

When directed, insert Event 4, Seismic event causes RCS leakage to rise to 1000 gpm over 10 minutes.

EVENT INDICATIONS:

APP-036-15, Seismic Alarm Load Dispatcher reports a seismic event report from US Geological Department.

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

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

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

Crew Make PA Announcement SRO Enters AOP-016 for Excessive Primary Plant Leakage Compare Current RTGB Indications with the Operating Logs to Detect any abnormal trends.

SRO Check Either Event Below Has Occurred Noticeable Tremors or Vibrations (NO)

OR Report by Outside Agency (YES)

SRO SRO Notify the Manager Operations of the following:

A Seismic event has occurred.

Any abnormal plant conditions that have been identified.

SRO Implement the EALs Implement Applicable Technical Specification LCOs.

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

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 25 of 40 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 Check RCS Pressure Greater than 1000 psig. (YES)

Check the following:

PZR Level Less than 10% AND 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% OR Subcooling can NOT be maintained greater than 35°F, THEN trip the Reactor and Go to PATH-i Crew Make PA Announcement for Procedure Entry 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 Steo 6 RO Check Charging Pump Status LESS THAN TWO RUNNING (NO)

GoToStepil.

RO Place running Charging Pumps Speed Controllers in MAN AND adjust output to maximum 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 Appendix D NUREG-i 021, 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 40 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 BOP Radiation Channel R-11 &R12 Process Monitor PROCESS MONITOR R-11/R-12 CV AIR AND PLANT VENT Attachment Number 12 RID Check RCS Level

- LOWERING IN AN UNCONTROLLED MANNER (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 Check R-1 1/R-12 Selector Switch

- SELECTED TO CV (YES)

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

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

BOP Check EOP Network Procedures IMPLEMENTED (NO)

BOP Check Personnel IN CV (NO)

Check CONTAINMENT VENTILATION ISOLATION Valves

BOP CLOSED (YES Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 F

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 Aoolicants Actions or Behavior Op Test No.:

1 Scenario #

1 Event #

4 and 5 Page 27 of 40 BOP BOP BOP Place the following CV IODINE REMOVAL FAN Control Switches to PREPURGE Position:

HVE-3 HVE-4 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 RCS Leak Locally Identified (NO)

OR VCT Auto Makeups Excessive (YES)

OR Charging Pump Speed Rising (YES)

BOOTH 0 BOP SRO BOP 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, Radioactive Gases Go to the Main Body, Step 1.b, of this procedure.

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

ERATOR: No Action Required.

All malfunctions are pre-loaded for the reactor trip nd SI Actuation.

C START OF PATH-I ACTIONS PATH-I Actions RO Immediate Action Step Reactor tripped (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 28 of 40 Event

Description:

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

Time N

Position 0

Applicants Actions or Behavior BOP BOP BOP RO SRO Immediate Action Step Turbine tripped (YES)

Immediate Action Step El & E2 energized (YES)

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

Immediate Action Step SI initiated (YES SI was manually initiated due to entry into PATH-I from AOP-016)

Open Foldout A MSR ISOLATION CRITERIA IF ANY Purge OR Shutoff Valve does not indicate fulTy closed, THEN place the associated RTGB Switch to CLOSE.

IF 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.

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 below are met, THEN perform AOP-018, Reactor Coolant Pump Abnormal Conditions to restore RCP Seal Cooling p.,

APP-00l-B2, LABYRINTH SEAL LOW AP ILLUMINATED R

(YES)

AND APP-00l-Dl, THERMAL BARRIER LO FLOW ILLUMINATED (YES)

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

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

Event

Description:

Twne ir RD Verify Phase A valves closed (YES)

BOP Verify FW isolation valves closed (YES)

BOP Verify both FW pumps tripped (YES)

BOP Verify both MDAFW pumps running (NO)

MDAFW Pump A Inoperable due to initial conditions.

BOP If Additional Feedwater is required, THEN Start SDAFW Pump Verify two SI pumps running (NO)

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

CRITICAL TASK:

Start C SI Pump to provide injection to the RCS.

RD Verify both RHR pumps running (YES)

RO Verify SI valves properly aligned (YES)

RO At least one CCW pump running (ND)

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

RD CV Spray Initiated (NO)

RD Start CCW Pump (YES)

Scenario #

1 Event #

4 and 5 Page 29 of 40 Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Position Applicants Actions or Behavior 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 30 of 40 Event

Description:

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

Time II Position Applicants Actions or Behavior CRITICAL TASK:

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

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

All SW & SW booster pumps running (YES)

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

Verify IVSW System initiated (YES)

Verify CV ventilation isolation (YES)

If Additional Feedwater is required, THEN Start SDAFW Pump (NO)

(SDAFW Pump tripped on overspeed. Unable to restart.)

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.)

BOP BOP 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

- 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 DR CR-D1 B-SB have lost power, THEN locally verify position in the Control Room Kitchen.

Verify both EDGs running (YES)

Continuous Action Step Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 OpTestNo.:

Event

Description:

Time II Position N

Scenario #

1 Event #

4 and 5 Page 31 of 40 Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

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 Open the breaker for HVS-1 3 minutes after directed by the Control Room.

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 SIG levels between 8% [18%] and 50%

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

BOP Place Steam Dump Mode switch to Steam Pressure Appendix D NUREG-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

Event

Description:

RO RCS temperature stable at or trending to 547°F (NO)

(No RCPs are running. Candidate should use TICs.)

RO RCS temperature greater than 547°F (NO)

(No RCPs are running. Candidate should use TICs.)

RO Attempt to limit cooldown IF RCS Cooldown continues and is not due to SI flow, THEN CLOSE BOP MSIVs and MSIV Bypasses.

MSIV and MSIV Bypasses are closed.

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 S/G 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)

Time sition II Scenario #

1 Event #

4 and 5 Page 32 of 40 Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Applicants Actions or Behavior 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 40 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 CV Pressure Normal (NO)

RO GO TO PATH-i Entry Point C RO 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 BOP Any S/G with Uncontrolled Depressurization (NO)

BOP Control AFW Flow to Maintain S/G Levels between 8% [18%] and 50%

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

BOP R-i9s, R-31s, AND R-15 Rad Levels Normal (YES)

RO Open at least one PORV Block unless Closed to Isolate an Open PZR PORV BOP RO At Least One RCP Running (NO)

Any S/G Completely Depressurized (NO)

PZR PORVs Closed (YES)

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

Appendix D Operator Action Form ES-D-2 OpTestNo.:

Event

Description:

Time II 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 IFOffsite Power is Lost, THEN Restart Emergency Safeguard Equipment RO Reset CV Spray RO Reset Phase A AND Phase B RO Establish Instrument Air to CV. IF Compressor Not Running, THEN Start Compressor.

BOP Offsite Power Available to Charging Pumps (NO)

BOP IF Adequate diesel capacity not available to run charging pumps 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)

Scenario #

1 Event #

4 and 5 Page 34 of 40 Seismic event that causes RCS leakage to rise to 1000 GPM over 10 minutes, Loss of Startup Transformer upon Generator Lockout.

Position 1

Applicants Actions or Behavior 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 35 of 40 Event

Description:

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

Time J

Position Applicants Actions or Behavior Continuous Action Step RO WHEN Below 10b0 Amps, THEN Energize Source Range detectors and monitor recorder.

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

RO RCS Pressure Stable or Rising (YES)

RO Stop RHR Pumps Continuous Action Step RO If 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 E-2 SOP Restart Battery Chargers within 30 mm of power loss using OP-601.

SOP Verify EDGs Properly Loaded (YES)

BOP Verify Emergency Oil Pump Running (YES)

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

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

Appendix D Operator Action Form ES-D-2 r

Op Test No.:

1 Scenario #

1 Event #

4 and 5 Page 36 of 40 Event

Description:

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

Time II Position II ApIicants Actions or Behavior IF Diesel Capacity is not adequate to run lnstr Air Compressors AND BOP Battery Chargers, THEN shed non-essential loads using Supplement F.

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

RO Supplement D components capable of Recirc (YES)

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/BOP Check APP-001-D1, RCP THERM BAR COOL WTR LO FLOW alarm ILLUMINATED (YES)

Appendix D NUREG-i 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 40 Event

Description:

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

Time II Position II Aoolicants Actions or Behavior RO/BOP RO/BOP RO/BOP RO/BOP RO/BOP RO/BOP Check elapsed time since all RCP Seal Cooling was lost GREATER THAN 15 MINUTES (NO)

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

GoToSteplO 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) 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 1 and Go To Step 1 1 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 Determine if a charging pump can be started:

a.

Check Charging system piping RUPTURED (NO)

GoToStepl2 Check SI INITIATED (YES)

Reset SI Verify at least ONE Charcincj Pump

- RUNNING 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 38 of 40 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 Adjust any OR all of the following to restore seal injection flow RO/BOP HIC-121, CHARGING FLOW Charging Pump Speed

__CVC-297A,_B,_C Check Seal Injection to RCPs:

ANY seal injection flow LESS THAN 6 GPM (NO)

R/BO AND

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

__GoToSte47 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_storped.

Establish normal seal injection RO/BOP a.

Check RCP seal injection ALIGNED (YES) b.

Check RCP seal injection flow BETWEEN 8 GPM AND 13 GPM RO/BOP Check seal injection flow ESTABLISHED TO ALL RCPs (YES)

SRO Implement 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 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 40 Event

Description:

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

Time II Position II Applicants Actions or Behavior RO/BOP Check RCP Seal Cooling ISOLATED (NO)

Observe the NOTE prior to Step 2 and go to the Main Body, Step 2 of this procedure.

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 MWDIMTU 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.

INSTRUCTIONS FOR THE WATCH:

Maintain current power level Appendix D NUREG-1021, Rev. 9, Supp. 1

Unit 2 Status Board NoteslAdditional Data IC-21 EOL IEFPD i448 IDesian 473.5 IDate:

iToday ITime:

6:00:00 AMiCycle:

27 IMWDIMT:

15697 IDesign:

116590 HUT Level %

Status CVCS-A 20 Filling CVCS-B 10 Standby CVCS-C 86 Standby WHUT

NAME?

Filling Data Linked to P1 WGDTS Pressure PSIG Status A

NAME?

PSIG On cover B

NAME?

PSIG In Service C

NAME?

PSIG Isolated D

NAME?

PSIG Standby Shutdown Requirement Temp Boron 1.77% =AK/K 547 F Hot 258 1.77% =K1K

>350 F 611 2.6% =LK/K 100 F Cold 776 Tank Level%

Status Monitor A 10 Standby Monitor B 38 Standby WCTA 37 Standby WCTB Standby WCTC 9

Standby WCTD 10 Standby WCTE 9

Standby DEMINERALIZERS Resin PPM In Service Date Replaced MB A 2194 YES 711712010 5/412010 MB B 2265 NO 711712010 13/2912010 CATION 1021 NO 911712010

- 12/9/2009 DEB A 0

NO New 2/3/2010 DEB B

,0 NO 312812010 SFP 1963 NO 9/23/2008 4/22I2008 6%=AKIK IN/A 11950 PORV Settings Setting Date POT GP-3 Psig A

7/1812010 3.21 1000 5

7/18/2010 3.12 1040 C

7/18/2010 3.44 1000 Condenser Air Inleakage Target Value GPM SGBD Total RCS Leakage 0.00 Unidentified PRT Status A

13 CFM A

50 Flash Tank B

0 CFM B

50 With Heat Known I!

CFM C

50 Recovery Total 5

CFM N2 Flow 8

SCFM 0.03 RCDT Leakage GPM

0.02 Charging Leakoff

GPM 001 Misc Identified 0

GPM 0

i GPM Primary/Secondary Secondary Loss Hi Flux At Shutdown I Previous ARI Counts Setpoint Nl-31 150 150 Nl-32 160 180 10 GPM 17.3 GPD GPM Effluent Radiation Monitor Setpoints Rad Current

.NUE Value Alert Value 200X Monitor Isetpornt 2X R-14C 1.O1E÷04 N/A 2.020E÷04 R-20 7.40E+03 N/A 1.480E+04 R-1 8 1.OOE+06 2.000E+08 2.000E+06 R-19A 1.05E+04

2.IOOE+06 2.IOOE+04 R-19B 9.72E+03 I.944E+06 I.944E+04 R-19C 9.58E+03

1.916E+06 1.916E+04 R-37 8.53E÷03 1.706E+06 1.706E+04 Manuaily Entered Data Linked to Chem data base Boron PPM I

Date PPM Date PPM RCS Today 95 BAST-A 9/16/2010 21,535

NAME?

NAME?

BAST-B 9/1612010 21,032

NAME?

NAME?

SFP 9I15I2010 2246

NAME?

NAME?

RWST 9/16/2010 2219

NAME?

NAME?

fccum-A 8/3012010 2211

NAME?

NAME?

ccum.B 8/3012010 12206

NAME?

NAME?

ccum-C 8/30/2010 2230

NAME?

NAME?

Normal Currents UPPER LOWER TARGET

% BAND N-41 144 136 0.0212 5+1-N-42 126 125 0.0212 5+1-N-43 121 113 0.0212 5+/-

N-44 112 108 10.0212 5+1-POWERTRAX Rev# 2.1.0 RNP 1% APL 112.55 FANS Test/Hrs IDate/Tst HVE-IA/B 35640.6 3/8/10 HVE-15A 18643.5 13/18/10 HVE-19A/B 6928.3 5/3/10 RHR Refuel Canal 7/6/2010 Refuel Cavity 2221 SR 3.7.11.2 Last Completed 5/27/2010 SFP Canal 19:45

0 Appendix D Scenario Outline Form ES-D-1 j 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 Chesterfield counties Turnover:

Maintain current power level while RES personnel are monitoring the performance of A Heater Drain Pump following maintenance.

Critical Tasks:

Isolation of C S/G Identify that EPP-17, SGTR with Loss of Reactor Coolant: Subcooled Recovery must be implemented.

Event MaIf.

Event Type*

Event No.

No.

Description 1

(C) BOP, SRO Seice Water Pump D trips RO 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 (T.S)SRO 6

(N) BOP, SRO Restore normal letdown 7

(C) RO, SRO RCP C High Vibrations S

(M) ALL C S/G Tube Rupture when RCP C is secured following manual reactor trip 9

C SIG PORV fails OPEN I Tube Rupture size rises (C) RO RHR Pumps A and B fail to auto-start (C) BOP FW Isolation Valve V2-6C fails to close on SI Signal (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 2

SUMMARY

DESCRIPTION The crew will assume the watch with the unit being maintained at 75% RTP following the completion of maintenance on A Heater Drain Pump. 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 power level while RES is monitoring performance of A Heater Drain Pump following maintenance.

On cue from the Chief Examiner, D Service Water Pump will trip. Various alarms will be received on APP-002 and APP-008. APP-008-F4, SW PMP AJBICID 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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Once the Chief Examiner is satisfied with the ITS compliance he may cue the next event.

On cue from the Chief Examiner, the control room will receive a report from the Operations Manager that RES system engineer has reported that vibrations on A MFP have become abnormally high. RES recommends that A MFP be secured as soon as possible. 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 Regulating Valve FCV-478 will slowly drift open.

The crew will perform the immediate actions for the Main Feedwater malfunction lAW AOP-01 0, Main Feedwater I Condensate Malfunction. The operator will take manual control of FCV-478 and restore A S/G 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 Transmitter, LT-459 fails LOW causing normal letdown to isolate, de-energizing of pressurizer 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, Condftion M requires that the channFlacir[tff wfthin 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or reduce thermal power to less than P-T within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Once the level transmitter has been removed from service and the Chief Examiner is satisfied with the Tech Specs compliance and plant restoration, the Chief Examiner will cue the next event.

On cue from the Chief Examiner, C RCP will begin experiencing high vibrations. The crew will enter AOP-01 8, Reactor Coolant Pump Abnormal Conditions, 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 rupture in C SIG will be ramped in over 1 minute when C RCP is secured. The crew should identify the 500 gpm tube rupture and initiate safety injection while performing the immediate actions of PATH-i. Neither RHR Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Scenario Outline Form ES-D-i Pump A nor B will auto-start on the safety injection signal. The operator will manually start 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.

Approximately 2 minutes after initiation of safety injection the C SIG 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 S/G. EPP-i 1, Faulted Steam Generator Isolation, will be transitioned to from PATH-i. EPP-1 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-17, SGTR with Loss of Reactor Coolant: Subcooled Recovery. ER11.will providguidance to continue with RCS cooldown along 1

ç el 1ng up to placing the plant ma cold shutdown condiflon.

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 0 NUREG-i 021, Rev. 9, Supp. 1

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

IC-802, SCN:008_11_2_NRC_Exam_2 A MDAFW Pump inoperable with the breaker racked out Status board updated to reflect IC-42.

PRE-LOADED EVENTS:

The following event should occur when C RCP is secured:

Event 8:

C SIG 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)

EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

APP-008-F4 OP-105 AOP-OOI AOP-OIO AOP-025 Main Body and Section B OWP-030, PLT-I AOP-018 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.:

I Scenario #

2 Event #

1 Page 5

of 45 Event

Description:

SW Pump D Trips Time II Position II Aiijlicants Actions or Behavior 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)

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

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

Directs entry into ITS LCO:

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

3.6.6, Condition D, Two containment cooling trains inoperable. (Due to receiving the HVH1,2,3,4 WTR OUTLET LO FLOW). Restore one containment cooling train to Operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

BOOTH OPERATOR:

When directed, insert Event 1, SW Pump 0 Trips EVENT INDICATIONS:

APP-008-F4, SW PMP AIBICID OVLD APP-002-A8, B8, C8, D8 HVH-1, 2, 3, 4 WTR OUTLET LO FLOW Service Water Pump D has dual indication on the RTGB BOP BOP Receives annunciator APP-008-F4, SW PMP A/B/CID OVLD and Identifies that SW Pump D has tripped.

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

Start a Standby Pump.

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

I Scenario #

2 Event #

2 Page 6

of 45 Event

Description:

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

Time Position Applicants Actions or Behavior BOOTH OPERATOR:

At the discretion of the Chief Examiner, Notify the Control Room personnel that Main Feedwater Pump A has high vibrations and RES System Engineer has requested that the pump be secured within the next hour.

EVENT INDICATIONS:

Notification that vibrations are excessive on Main Feedwater Pump A.

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)

SRO Notify the Load Dispatcher that unit load will be reduced (SOER 02-3, Large 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.

RO 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 SRO/RO use the most recent OST-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.

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

RO DETERMINE the amount of Boric Acid to add to the RCS and OBTAIN an independent check of the volume of boric acid 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 #

2 Page 7

of 45 Event

Description:

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

Time Position II Apolicants Actions or Behavior RO RO 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, using the UP and DOWN pushbuttons.

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:

RO FCV-113A, BATO BLENDER, closes.

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

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

__The_RCS_MAKEUP_SYSTEM_is_OFF.

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

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

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 45 Event

Description:

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

IL Position Applicants Actions or Behavior Time 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 1 3A, 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 during the boration.

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

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 9

of 45 Event

Description:

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

Time Position Applicants Actions or Behavior BOP RO RO RO BOP BOP IF EH Turbine Control is in OPER AUTO, THEN reduce turbine load as follows:

Place the EH Turbine Control in the desired position: IMP IN or 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.

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:

Tavg tracks within 5°F of Tref.

PZR level tracks within 5% of reference level.

\\ilaintain the control rods above the minimum allowable rod height by Dorating the RCS lAW OP-301.

Maintain Gland Seal Steam Header Pressure in the normal operating band (3 to 6 psiQ) (P1-4004, P1-i 382 or ERFIS Pt G5P2095A)

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

SECURE the following as needed for feedwater flow requirements:

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

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 10 of 45 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 RD Immediate Action Step Check unexpected rod motion IN PROGRESS (YES)

RD 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)

RD 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 45 Event

Description:

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

RNO Go To Step 4 RO Stop any boron dilution in progress.

Check APP-005-B5, ROD BANKS AIB/C/D LO LIMIT

R EXTINGUISHED (YES)

RO Check reactor power LESS THAN OR 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 (NO)

RNO Perform the following:

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

SRO Contact I&C and Reactor Engineering to troubleshoot and correct the problem.

SRO Implement The EALs Appendix D NUREG-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

2 Event #

3 Page 12 of 45 Event

Description:

Control Bank D rods unwarranted rod motion Time II Position II ArIicants Actions or Behavior Review Technical Specifications to assure all applicable LCO requirements have been met:

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 3.2.1 Fq(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 I&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 45 Event

Description:

Feedwater Regulating Valve FCV-478 slowly drifts open.

Time jJ Positio 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 S!G level rising APP-006-A3, SIG A LVL 0EV 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 SIG 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-O, REACTOR TRIP or SAFETY INJECTION.

e.

Go To Step 37.

RD Make PA announcement for procedure entry unless previously made.

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

RD Check Tavg AT OR TRENDING TO Tref (YES)

SRO Contact maintenance to troubleshoot and correct the feedwater problem.

SRO Implement the EALs Appendix D NUREG-102i, Rev. 9, Supp. i

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

2 Event #

4 Page 14 of 45 Event

Description:

Feedwater Regulating Valve FCV-478 slowly drifts open.

Time Position Applicants Actions or Behavior BOP Check current loading for the following pumps LESS THAN MAXIMUM Main Feedwater Pump 0.715 AMPS Condensate Pumps 370 AMPS Heater Drain Pumps 90 AMPS BOOTH OPERATOR: When requested, respond that the current readings on the secondary pumps are as follows:

Main Feedwater Pump 0.575 AMPS Condensate Pumps 320 AMPS Heater Drain Pumps 75 AMPS Determine Iodine sampling requirements as follows:

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 Check APP-005-B5, ROD BANKS AIB/C/D LO LIMIT

R 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 andlor I&C to write a work request, investigate and initiate repairs for the FRV failure, and notify the Operations Manager.

BOOTH OPERATOR:

As soon as the plant is stabilized or at the discretion of the Chief Examiner, insert the next event.

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 15 of 45 Event

Description:

PZR level transmitter LT-459 fails LOW Time ositioj 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 illuminated LCV-460A and B valves closed AOP-025 RTGB INSTRUMENT FAILURE RO Go To The Appropriate Section For The Failed Transmitter:

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 minimum 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 45 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Applicants Actions or Behavior Check RCP seal injection flow BETWEEN 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 PS 1G.

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

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

RO Check Number Of Operable PZR Level Channels

- GREATER THAN ONE (YES)

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

Verify Selector Switch LR-459

- SELECTED TO THE CONTROLLING RO CHANNEL REC 461 RO Failed Channel Switch Position LT-459 461 REPL 459 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 17 of 45 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position Aoolicants Actions or Behavior RO RO RO RO Continuous Action Step Restore PZR Level Control To Automatic As Follows:

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 PROGRAMMED REFERENCE LEVEL o

RNO

- WHEN PZR level is within +/-1% of programmed reference level, THEN restore PZR Level Control to Automatic.

o GoToStepli.

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 Switch to OFF position AND return to ON position c.

IF required, THEN place PZR HTR BACK-UP GROUP A Control Switch to OFF position AND return to AUTO OR ON position as desired d.

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

Channel OWP Remove The Affected Transmitter From Service Using OWP-030:

I I

I LT-459 PLT-1 Examiner Note:

The next step may have been performed earlier 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 18 of 45 Event

Description:

PZR level transmitter LT-459 fails LOW F

Time 1

Position N

Applicants Actions or Behavior RO 461 REPLACE 459 Press. Prot. & (LM-459) Control Switch BOOTH OPERATOR: Trip the bistables per the crew direction lAW 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 for RPS OPERABILITY requirements in MODEl.

SRO ITS Table 3.3.3-1 Item 12 for PAM instrumentation OPERABILITY requirements in MODES 1, 2, and 3.

ITS LCO 3.3.4 for Remote Shutdown System OPERABILITY requirements_in_MODES_1,_2,_and_3.

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-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 19 of 45 Event

Description:

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

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 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.

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

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. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

2 Event #

5 and 6 Page 20 of 45 Event

Description:

PZR level transmitter LT-459 fails LOW Time Position N

Applicants Actions or Behavior Establish cooling to the NON-REGEN HX as follows:

a.

PLACE TC-144, NON-REGEN HXOUTLETTEMP, 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 psia.

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 45 Event

Description:

PZR level transmitter LT-459 fails LOW Time II Position II Aoolicants Actions or Behavior RO/BOP RO/BOP Notify RC that letdown flow has been restored and the affected areas should be monitored for changing radiological conditions.

IF increased letdown flow is desired, THEN place additional letdown orifices in service as follows:

a.

VERIFY HIC-121, CHARGING FLOWis FULL OPEN b.

VERIFY Charging Pump discharge pressure as indicated on RTGB instrument P1-121 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 psig, ADJUST charging pump speed to meet flow requirements e.

Place PC-145, PRESSURE, in MANUAL.

f.

Slowly throttle open PC-I 45 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 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 22 of 45 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-001-B5 Actions:

Checks affected RCP alarm valid as follows:

1.

Check the alarming monitor for flashing Alert.

BOP 2.

Momentarily Depress the RES button for the alarming monitor.

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.

SRO Determines that Section B, High Reactor Coolant Pump Vibration, is 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-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

2 Event #

7 Page 23 of 45 Event

Description:

RCP C High Vibrations Time 1

Position ir Applicants Actions or Behavior RD RD BOOTH OPERATOR: Insert Event 8, SIG C Tube Rupture when the C RCP is tripped.

Immediate Action Step:

RD Initiate SI (YES)

BOOTH OPERATOR: Insert Event 9 approximately 2 minutes after SI is initiated. Event 9 is C SIG PORV fails OPEN I C S1G Tube Rupture size rises.

RD BOP BOP BOP RD RD Trips the reactor and verifies the reactor tripped.

Trip C RCP Immediate Action Step:

Reactor Tripped. (YES)

Immediate Action Step:

Turbine Tripped. (YES)

Immediate Action Step:

E-1 AND E-2 energized (YES)

Continuous Action Step:

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

SI initiated. (NO)

Immediate Action Step:

SI initiation required. (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 #

7 Page 24 of 45 Event

Description:

RCP C High Vibrations Time Position II Arplicants Actions or Behavior SRO Examiners Note:

Following the performance and verification of PATH-I Immediate Actions, the crew will continue with AOP-OI 8. These steps may be handed off to the ROIBOP to perform independently. The remaining steps of AOP-018 are listed here.

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-001-D8

- RCP A APP-001-E8

- RCP B

__APP-001-F8_-_RCP_C RO/BOP Check All RCP #1 Seal Leakoff Flows

- BETWEEN 1 GPM AND 5 GPM (YES)

RO/BOP Check RCP Seal Injection Flow - BETWEEN 8 GPM AND 13 GPM jNO)

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

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 45 Event

Description:

RCP C High Vibrations Time 1

Position Applicants Actions or Behavior RO/BOP SRO Examiner Note:

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

SRO SRO SRO 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 CVC-297C IF required to maintain minimum flow, THEN throttle HIC-121, CHARGING FLOW Valve while maintaining Charging Pump Discharge pressure less than 2500 PS 1G.

Notify Manager Operations OR Designee of RCP Performance Implement the EALs Refer to ITS for any applicable LCOs 3.4.4, 3.4.5 and 3.4.6 Go to the Main Body, Step 2 of AOP-018.

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 45 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 SRO BOP BOP Open Foldout A MSR Isolation Closes all Purge and Shutoff Valves FAULTED SIG 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 SIG has completely depressurized.

AND At least ONE S/G is intact.

a. Reset SI.

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.

RUPTURED S/G ISOLATION CRITERIA (BOP may not recognize 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 S!G Level is Greater than 8% [18%]

BOP

a. Reset SI.

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 S!G 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.

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 27 of 45 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 N

Position 1

Applicants Actions or Behavior Examiner Note:

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

NOTE:

Candidate may direct that Supplement G be performe SIG C. Supplement G steps begin on Page 42.

Examiner Note:

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

SRO Foldout A is in effect.

RD 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.

BOP Verify both FW pumps tripped (YES)

BOP Verify both MDAFW pumps running (NO)

MDAFW Pump A inoperable from initial conditions.

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

RD Verify two SI pumps running (YES)

Verify both RHR pumps running (NO)

RD Manual action is taken to start both RHR pumps, 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 45 Event

Description:

C S1G 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 II Position Applicants Actions or Behavior RO Verify SI valves properly aligned (YES)

RO At least one CCW pump running (YES)

BOP All SW & SW booster pumps running (NO)

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)

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 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 29 of 45 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 Aoolicants Actions or Behavior BOP BOP BOP 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 BOP 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

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

Verify both EDGs running (YES)

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

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

Automatic steam line isolation initiated (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 30 of 45 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 II Aoolicants Actions or Behavior RD RCS pressure greater than 1350 psig [1250 psig] (NO)

RD SI flow verified (YES)

RD 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 SIG levels between 8% [18%] and 50%

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

BOP Place Steam Dump Mode switch to Steam Pressure RD RCS temperature stable at or trending to 547°F (ND)

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 45 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 / Tube rupture size rises.

Time N

Position II Applicants Actions or Behavior BOP Attempt to limit cooldown.

BOP IF RCS cooldown continues AND is not due to SI Flow THEN close MSIVs AND MSIV Bypasses.

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)

RO Reset SPDS and monitor CSFSTs.

SRO Transition to EPP-1 1.

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 32 of 45 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 Applicants Actions or Behavior Check SIG Status:

a.

Identify intact SIGs as follows:

ANY SIG PRESSURE STABLE OR INCREASING (YES) 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 (Supplement G actions are included following this section.)

Maintain A Faulted S/G In The Isolated Condition During Subsequent Recovery Actions Unless Needed For Cooldown Check CST Level

- GREATER THAN 10% (YES)

Check Available Secondary Radiation Monitors NORMAL (NO)

Go to PATH-2, Entry Point J.

Reset SPDS AND Initiate Monitoring of Critical Safety Function Status Trees Open Foldout C (No steps apply)

BOP BOP BOP BOP BOP Continuous Action Step RO When Below I 0° AMPS, THEN Energize Source Range Detectors AND Transfer Recorder SRO RO C REW 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 45 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 II Aoølicants Actions or Behavior BOP BOP BOP BOP RO RO Request Periodic Activity Samples of All S/Gs Place Steam Dump Mode Switch to Steam Pressure Open QCV-1 0426 to bypass Condensate Polishers Close C-48A AND C-48B to isolate Hotwell return to CST At Least One RCP Running (YES)

At Least One SI Pump Running (YES)

BOP Close Ruptured S/G MSIV and MSIV Bypass RO BOP BOP BOP BOP RCS Subcooling Less than 35°F [55°F] (NO)

Ruptured S/G Identified (YES)

Maintain at Least One SIG Available for RCS Cooldown Verify Ruptured Steam Line PORV Setpoint at 1035 PSIG using Status Board Verify RCS Temperature Less Than 547°F Prior to MSIV Closure 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 45 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 II Position I

Anolicants Actions or Behavior BOP BOP BOP Ruptured SIG MSIV and MSIV Bypass Closed (YES)

IF MDAFW Pump is not Available, THEN Maintain at least One S/G supply to SDAFW Pump Close Ruptured SIG Steam Shutoff to SDAFW Pump Verify SIG Blowdown Isolation and Sample Valves Closed BOP BOP BOP BOP Continuous Action Step When Ruptured SIG Pressure lowers Below 1035 PSIG THEN Verify Ruptured Steam Line PORV Closed Locally Close Warmup Steam Supply From Ruptured SIG to SDAFW Pump Booth Operator Close Warmup Steam Supply Valve (MS-38) and Report action 3 Minutes after requested Locally Close MSIV Above and Below Seat Drains from Ruptured S/G Booth Operator Report Above and Below Seat Drains are closed 3 Minutes after requested lso[ate Feed How to Any Ruptured S/Gthat is Faulted Unless Needed BOP for RCS Cooldown 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 35 of 45 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 II Position Aoolicants Actions or Behavior BOP BOP Continuous Action Step Open Breakers for any V1-8, V2-14 AND V2-16 Valve Closed to Isolate Ruptured SIG Booth Operator Wait 3 minutes to Open Breakers as requested and report action corn plete.

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

and 50%

Any Other SIG with Uncontrolled Level Rise (NO)

PZR PORVs Closed (YES)

Continuous Action Step When Ruptured S/G Level Greater Than 8% [18%] THEN Isolate Feed Flow Continuous Action Step RO/BOP IF Offsite Power is Lost, THEN Restart Emergency Safeguard Equipment RO RO RO RO Open At Least One PORV Block Unless Closed to Isolate an Open PZR PORV Continuous Action Step IF PZR PORV Opens on High Pressure, THEN Verify Reclosure at or Below 2335 PS 1G. Close PORV Blocks as Necessary Reset SI 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 45 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 II Aoolicants Actions or Behavior RO RO RO BOP RO RO Reset CV Spray Reset Phase A and Phase B Establish Instrument Air to CV.

IF Compressor not Running, THEN Start Compressor All AC Busses Energized by Offsite Power (YES)

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

Stop RHR Pumps Continuous Action Step RO IF RCS Pressure Lowers Below 275 PSIG [400 PSIG], THEN Restart RHR Pumps Ruptured S/G 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

- V2-6C FW HDR SECTION (Not needed if FRV and FRV BYP Criti&

BOP closed.)

as

- V2-14C, SDAFW PUMP DISCH Valve

- V2-16C, 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.)

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 37 of 45 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 Am,licants Actions or Behavior RO/BOP Table

- 3 Ruptured S/G Pressure (PSIG)

Greater than 1000 900-1000 800-899 700-799 600-699 Required Core Exit Temperature

(°F) 490 [470]

480 [4601 465 [4451 450 [4301 435 [415]

BOP Ruptured SIG 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 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 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.

- Second AFW oumo should be started 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 45 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 II Aørlicants Actions or Behavior RO RO RO RO BOP CREW RO Reset CONTAINMENT ISOLATION PHASE A AND PHASE B Critical Task BOP BOP SRO SRO RO At Least One Charging Pump Running (YES)

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

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

Reduce Steam Flow to Stabilize RCS Temperature Allow RCS Temperature to Stabilize from cooldown prior to continuing Ruptured SIG pressure stable or rising (NO)

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

Transition to EPP-17.

Open Foldout E (No steps apply.)

Reset SAFETY INJECTION 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 45 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 BOP RO RO BOP Continuous Action Step 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

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 Determine If CV Spray Should Be Stopped As Follows:

Check CV Spray Pumps RUNNING (NO)

Continuous Action Step Control Ruptured S/G Level As Follows:

Check ruptured S/G level

- LESS THAN 8% [18%] (NO)

Stop feed flow to ruptured S/Gs.

Initiate Evaluation Of Plant Status

a. Check Auxiliary Building radiation monitors NORMAL (YES)

b. Contact Chemistry to obtain the following periodic samples:

RO RCS for boron and activity Ruptured S/G(s) for boron Pressurizer for boron

c. Contact Plant Operations Staff to determine additional actions to evaluate_plant_status,_while_continuing_with_this_procedure RO Continuous Action Step Determine If RHR Pumps Should Be Stopped a.

Check RCS pressure:

GREATER THAN 275 PSIG [400 PSIG] (YES)

AND STABLE OR INCREASING b.

Verify RHR Pumps Stopped c.

Check RCS pressure Less than 275 psi 1400 PSIG1 (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 40 of 45 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 / Tube rupture size rises.

Time 1

Position II Applicants Actions or Behavior Establish Charging Flow As Follows:

RO Check Charging Pumps ALL STOPPED (NO)

.__Verify_charging_flow_on_Fl-i 22A__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 RO

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 charging flow on Fl-122A (YES)

Identify Faulted S/Gs As Follows:

a. Check pressure in all S/Gs:

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

OR ANY S/G COMPLETELY DEPRESSURED NO)

BOP Check Faulted S/Gs PREVIOUSLY ISOLATED (YES)

Control Intact S/G Levels As Follows:

Check intact SIG 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)

Appendix D NUREG-i021, 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 45 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 II Position II Applicants Actions or Behavior BOP 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 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)

Dumr steam usinci 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 45 Event

Description:

Isolation of SIG C lAW Supplement G Time N

Position 1

Applicants Actions or Behavior 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 I S/G C BOP Check S/G C FAULTED (YES).

BOP Verify Vi -3C, MSIV CLOSED (YES)

BOP Verify MS-353C, MSIV Vi -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)

I STEP I

I I

34 Appendix D NUREG-i 021, Rev. 9, Supp. i

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

2 Event #

8 and 9 Page 43 of 45 Event

Description:

Isolation of SIG C lAW Supplement G Time 1

Position II Applicants Actions or Behavior BOP BOP BOP BOP Booth Operator Close Warmup Steam Supply Valve (MS-38) and Report action 3 Minutes after requested BOP Check SIG TOT MSIV Above And Below Seat Drain Valves CLOSED (YES)

Booth Operator Report Above and Below Seat Drains are closed 3 Minutes after requested.

Dispatch Operator To The E-1IE-2 To Perform The Following:

At MCC-9, verify V2-16C closed AND open breaker V2-16C, 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 MOO-b, verify V2-14C closed AND open breaker V2-14C, SDAFW PUMP TO_S/G_C_(CMPT-4M)

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:

o IA-3273, IA TO PIC-497 UPPER I/P o

IA-3274, IA TO P10-497 LOWER I/P OR Close lA-298, IA to PORVs (Before Dryer)

Verify yb-SC, SDAFW STEAM SHUTOFF Valve CLOSED. (YES)

Verify S/G C Blowdown AND Blowdown Sample Valve Status Licjht Indication CLOSED (YES)

Dispatch Operator to the Pipe Jungle to Close MS-38, SG C Bypass Drn & Warm-up Line to AFW Pump 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 45 Event

Description:

Isolation of SIG C lAW Supplement G Time II Position Applicants Actions or Behavior Booth Operator Wait 3 minutes to Open Breakers as requested and report action complete.

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.

BOP Dispatch An Operator To Close GS-36, MANUAL GLAND STEAM DUMP.

End of Supplement G Steps BOP BOP BOP BOP Check All Faulted AND Ruptured S/Gs ISOLATED (YES)

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

Check Any S/G RUPTURED (YES)

Perform the following to minimize Secondary system contamination:

Direct AO 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 Polisher Vessels A, B, C, D, E and F.

Secure ANY evolution that passes water through the beds, such as a low volume rinse.

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:

EQ Xenon Tavg:

567.5°F Bank D Rods 183 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.

INSTRUCTIONS FOR THE WATCH:

Maintain current power level while RES is monitoring performance of A Heater Drain Pump following maintenance.

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

Unit 2 Status Board PORV Settings Setting Date POT GP-3 Psig A

7118/2010 3.21 1000 B

7118/2010 3.12

1040 Total 0.03 GPM PRT p0.02 GPM RCDT Leakage 0.01 GPM Charging Leakoff 0

GPM Misc Identified 0

GPM PrimaryiSecondary 0

GPD Secondary Loss 117.3 GPM Hi Flux At Shutdown IEFPD 257 IDesicin 473.5 IDate:

Today ITime:

6:00:00 AMiCycle:

27 IMWDIMT:

19000 IDesign:

16590 HUT Level %

I Status CVCS-A 20 Filling CVCS-B 10 Standby CVCS-C 86 Standby WHUT

NAME?

Filling Data Linked to P1 WGDTS Pressure PSIG Status A

NAME?

PSIG On cover B

NAME?

PSIG In Service C

,#NAME?

P510 Isolated D

NAME?

IPSIG Standby Shutdown Requirement Temp Boron 1.77% =AK/K 547 F Hot 795 1.77% =AKIK

>350 F 1053 2.6% =AKIK 100 F Cold 1182 Tank ILevel%

Status Monitor A 10 Standby Monitor B 38 Standby WCTA 37 Standby WCT B Standby LP 19 Standby WCT D 10 Standby WCTE 9

Standby DEMINERALIZERS Resin PPM In Service Date Replaced MBA 2194 YES 7)17/2010 5/412010 MB B 2265 NO L201_ 3/29/2010 CATION 1021 NO 9117/2010 12/9/2009 DEBA 0

NO New 21312010 DEB B NO

/2010 SFP 1963 NO 9123/2008 412212008 6%=AKIK IN/A 1950 Condenser Air Inleakage C

7/1812010 13.44 1000 SGBD RCS Leakage 0.00 Unidentified Target Value GPM Status A

113 CFM A

50 Flash Tank B

0 CFM B

50 With Heat Known 8

ICFM C

50 Recovery Total 5

!CFM N2 Flow 8

SCFM Effluent Radiation Monitor Setpoints Rad Current NUE Value Alert Value 200X Monitor Setpoint 2x N/A 2.020E+04 R-14C 1.OIE+04 N/A 1.480E+04 R-20 7.40E+03 2 000E+08 2 000 E+06 R-18 1.OOE+06 R-19A 1.05E+04 R-19B 9.72E+03 1.944E+06 1.944E+04 R-19C 9.58E+03 1.916E+06 1.916E+04 R-37 B.53E+03 1.706E+06 Previous ARI Counts

Setpoint Nl-31 50 1150 Nl-32 60 180 Manually Entered Data Linked to Chem data base Boron PPM Date PPM Date PPM RCS

Today 775.5 BAST-A

9/1612010 21,535

NAME?

NAME?

BAST-B 19/16/2010 21,032

NAME?

NAME?

SFP 19/15/2010

2246

NAME?

1#NAME?

RWST 9/16/2010 12219

NAME?

NAME?

Accum-A

NAME?

NAME?

Accum-B 8/3012010 2206

NAME?

NAME?

Accum-C 8/3012010 2230

NAME?

NAME?

Normal Currents uPPER LOWER TARGET

%BAND N-41 125 119

-1.5 5+1-r4-42 110 109

-1.5 5+1-N-43 105 99

-1.5 5 +1-1-44 98 94

-1.5 5 +1-OWERTRAX Rev# 2.1.0 RNP

)% APL 112.55 FANS Test/Hrs Date/Tst HVE-IA/B 35640.6 3/8/10 HVE-15A 18643.5 3/18/10 HVE-I9AIB 692&3 5/3/10 RHR 7/6/2010 2221 Refuel Canal Refuel Cavity SFP Canal SR 3.7.11.2 Last Completed 5/27/2010 19:45 I

Notes/Additional Data

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 S 1-87DB Establish Containment Isolation Align CR ventilation to pressurization mode

[ Event MaIf.

Event Type*

Event L

No.

Description (R)RO 1

Withdraw controls rods to POAH (N) SRO (C) RO, 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 (I) BOP, SRO 4

Failure of N-35 Compensation Voltage (TS) SRO 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, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG-1021, Rev. 9, Supp. 1

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 control rod position as necessary to raise reactor power to the POAH in anticipation of continuing 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 or Cl and reopen FCV-626. The SRO will direct entry into ITS LCO 3.7.6, Condition A, for one required COW train being inoperable. The LCO requires that the inoperable COW train be restored to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . The crew may take actions lAW OP-306 to secure one of the two operating COW pumps On cue from the Chief Examiner, the North Service Water Header will experience 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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery 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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and perform SR 3.8.1.2 for Operable DG within 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months and, (4) restore DG to Operable status within 7 days OR be in Mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Mode 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . Due to COW Pump B being inoperable and EDG B being declared inoperable due to all of its supporting Service Water Pumps being disabled, ITS 3.8.1.B.2 requires that CCW Pump C be declared inoperable. This places 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 stability of the plant and ITS compliance he may cue the next event.

On cue from the Chief Examiner, N-35, Intermediate Range NI, will experience a loss of compensation voltage and APP-005-B2, N35 Loss of Comp Voltage, will be received. The APP will direct the crew to remove N-35 from service lAW OWP-0i 1, NI-7. ITS Table 3.3.1-i, Item 3, Intermediate Range Neutron Flux, Condition F, Thermal Power> P-6 and < P-iC, requires that thermal power be reduced to less than P-6 or increased to greater than P-iC within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . N 36 will be selected to provide SUR signal by repositioning the Start Up Rate Channel Select switch. Once OWP-0i 1 has been briefed, the crew may begin briefing GP-006 to reduce power to less than P-6 to meet the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ITS requirement. Once the Chief Examiner 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, CCW Pump B Discharge Valve, at a rate of 25 gpm. The crew will take actions lAW AOP-0i4, 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. Once the CCW Surge Tank level has been stabilized and operators dispatched to search for leaks the leak will rise to 750 gpm over a 5 minute time period. The crew will make efforts to maintain surge tank level by starting a second primary water pump. Eventually, it will be determined that the CCW Surge Tank level cannot be maintained and the crew will initiate a reactor trip, stop all RCPs and go to PATH-i while continuing with AOP-014.

On initiation of the manual reactor trip the plant will experience a Large Break LOCA. The crew will implement PATH-i due to the reactor trip and safety injection. Manual actions will have to be taken to open either SI-870A or SI-870B since neither automatically opens on the SI signal.

The operators must also identify that FP-248, 249, 256 and 258 fail to close automatically on the CIV signal and must be manually closed. The operators must identify that CR ventilation does not transfer to pressurization mode and must be manually realigned. The Turbine Building equipment will be secured in accordance with Supplement M, Component Alignment for Loss of SW to Turbine Building, due to service water being isolated to the turbine building as directed by PATH-i due to the North SW Header low pressure alarm being illuminated. FRP-P.1, 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 to the loss of N-35, Source Range NIs will have to be manually energized. The crew will eventually transition to EPP-15, Loss of Emergency Coolant Recirculation, due to having no CCW pumps available to provide cooling to the ECCS equipment. EPP-i5 will direct actions to make up to the RWST using Supplement P, Emergency 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-102i, 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 close 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-OII, NI-7 GP-006-I 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-1 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Op Test No.:

I Scenario #

4 Event #

1 Page 5

of 36 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 RO Normal Pressurizer Level:

START additional Charging Pumps as necessary.

PLACE additional letdown orifice in service ENERGIZE all available Pressurizer heaters to equalize boron concentration in the Pressurizer.

- PZR HTR CONTROL GROUP F

- 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 Control.

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 36 Event

Description:

Withdraw control rods to the POAH Time Position Applicants Actions or Behavior RO SRO WHEN Reactor power is greater than 1%, THEN NOTIFY Reactor Enqineerinq to COMMENCE loqqinq data required by EST-067 ADJUST control rods as necessary to achieve the following while continuing with this procedure:

RCS Tavg between 547°F and 551 °F

Maintain Reactor Power 5%.

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 36 Event

Description:

B CCW Pump trips and FCV-626 closes

[

Time Position II 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-C1, RCP THERM BAR COOL WTR HI FLOW APP-OO1-.D1, RCP THERM BAR COOL WTR LO FLOW (Locked in)

APP-OO1-F4, CCW PMP MOTOR OVLD/TRIP (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 RD IF the running CCW Pump has tripped, THEN VERIFY Standby CCW Pump STARTED.

APP-OO1 -F4 actions RD IF Standby COW Pump can NOT be started, THEN REFER TO AOP 014 (A and C COW Pumps auto started on low pressure signal).

APP-OO1-F4 actions IF FCV-626, THERM BAR FLOW CONT, closes due to pump start, RD THEN PERFORM the following:

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 RD IF COW Pump tripped due to electrical fault, THEN DISPATCH an operator to check breaker and Current Limiter Fuses (E-1IE-2 breakers only).

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 8

of 36 Event

Description:

B COW Pump trips and FCV-626 closes Time Position 1 Applicants Actions or Behavior Direct entry into ITS LCD 3.7.6, Condition A, for one required CCW SRO train inoperable. LCD requires that the inoperable CCW train be restored to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Booth Operator When Tech Specs are identified and at Chief Examiners discretion, proceed to Event #3.

APP-OO1-C1 actions IF CCW AND Seal Injection are lost to any RCP, THEN REFER TO AOP-O1 8.

RD RD APP-OO1 -Cl actions IF result of CCW Pump start only, THEN REOPEN FCV-626.

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 9

of 36 Event

Description:

North Service Water Header break at the intake Structure.

Time Position II Appicants 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 (Delayed)

APP-008-D8, N SW HDR STRAINER PIT HI-HI LVL (Delayed)

P1-1616, North SW Header pressure lowering P1-I 684, South SW Header pressure lowering BOP 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)

RNO Perform the following:

a.

Close the following valves:

V6-12B V6-12C b.

Go To Section F 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)

BOP Verify PA announcement for procedure entry performed 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 36 Event

Description:

North Service Water Header break at the Intake Structure.

Time 1

Position Aoolicants Actions or Behavior BOP Verify The Following a.

SW PUMP A - RUNNING b.

SW PUMP B

- RUNNING c.

SW PUMP C

- STOPPED d.

SW PUMP D

- STOPPED BOP Evakjate SW Header Pressure Indications As Follows:

Check North SW Header pressure on P1-i 616 LOWERING (YES)

Check South SW Header pressure on P1-i 684 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 hour.

BOP Close V6-12D, SW NORTH HDR ISO BOP SW-845 Verify The Following Valves At The Intake Structure

- CLOSED:

SW-839 BOP Check Flooding Status STOPPED (YES)

BOP 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)

Check South SW Header Pressure On P1-1684

- GREATER THAN 40 PSIG (YES)

BOP Remove Control Power Fuses From The Following Breakers At 480V Bus E-2:

SERVICE WATER PUMP C (CMPT-24A)

SERVICE WATER PUMP D (CMPT-25B)

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 11 of 36 Event

Description:

North Service Water Header break at the Intake Structure.

Time Position Applicants 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 o

(YES)

B 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 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 12 of 36 Event

Description:

North Service Water Header break at the Intake Structure.

(

Position Applicants Actions or Behavior Time The SRO will declare entry into the following LCOs:

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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter (OP-604, Section 8.4.9, Emergency Diesel Generator Inoperability)

(2) Declare required feature(s) supported by the inoperable DC inoperable when its required redundant feature(s) is inoperable within SRO 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature(s)

(3) Determine Operable DC is not inoperable due to common cause failure within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and perform SR 3.8.1.2 for Operable DC within 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months and (4) restore DG to Operable status within 7 days OR be in Mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Mode 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

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 3.8.1.B.2 requires that COW Pump C be declared inoperable. This places 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 Operations Manager.

Booth Operator:

Initiate Event #4, Failure of N-35 Compensation Voltage, 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 13 of 36 Event

Description:

Failure of N-35 Compensation Voltage.

Time L

Position L

Applicants Actions or Behavior BOOTH OPERATOR: At the discretion of the Chief Examiner, insert Event 4, Failure of N-35 Compensation Voltaqe.

EVENT INDICATIONS:

APP-005-B2, N-35 LOSS OF COMP VOLT N-35 indication deflects hiqher that oriqinal readinci BOOTH OPERATOR:

As soon as the Intermediate Range has been removed from service or the decision is made to shutdown the plant to comply with the ITS action statement, and with concurrence of the Chief Examiner, insert Event 5, CCW system leakage.

RO RO RO SRO SRO APP-005-B2, N-35 LOSS OF COMP VOLT, is received.

APP-005-B2 action IF N-35 has failed, THEN REMOVE NI-35 from service in accordance with OWP-Ol 1.

APP-005-B2 action IF a unit shutdown occurs, THEN Source Range NIS will require manual activation.

OWP-O1 1, Nl-7 actions:

Refer to ITS Table 3.3.1-1 for Intermediate Range applicability and operability requirements (ITS Table 3.3.1-1, Item 3)

REMOVE NI-35 from ERFIS SCAN: NINOO35A START UP RATE CHANNEL SELECT Switch Switch should be selected to an NI which is NOT removed from service (Nl-36)

LEVEL TRIP Switch BYPASS NIS TRIP BYPASS N 1-35 Status Liqht

- ILLUM The SRO will declare entry into the following LCO:

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-lU within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

4 Event #

5 Page 14 of 36 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 Examiner, 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 minutes)

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 Follows:

Check Surge Tank Level

- LESS THAN 5% (NO)

RO Check COW Pump Discharge Pressure (Local)

Flow WIDE OSCILLATIONS (NO)

RNO

- IF CCW Surge Tank level lowers to less than 5% Q, CCW Pump Cavitation occurs, THEN Go To Step 2.

Verify at the RTGB, Primary Water Makeup To CCW As Follows:

RO

a. Primary Water Pump

- RUNNING

b. CC-832, MAKEUP OPEN RO Check COW Surge Tank level (Ll-614B)

- STABLE OR RISING (YES)

RO Throttle CC-832 OR 00-7 1 1 To Maintain Surge Tank Level (Ll-614B) 47% to 53%.

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 15 of 36 Event

Description:

Leakage on CC-703B at 25 GPM and rising to 750 GPM.

Time Position AnIicants Actions or Behavior SRO 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)

Ll-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 flooding Water level on Aux Bldg first floor - GREATER THAN 6 INCHES (NO)

OR APP-001-E4, RHR PIT A HI LEVEL ILLUMINATED (NO)

OR RO APP-001-E5, RHR PIT B HI LEVEL ILLUMINATED (NO) b.

Dispatch Operator to perform Attachment 4, Flood Control In The Auxiliary Building RNO IF at any time flooding is indicated, THEN perform, Flood Control In The Auxiliary Building 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 leakage rate.

Dispatch Operator To Perform Attachment 3, CCW Leak Search, While Continuing With Procedure 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 16 of 36 Event

Description:

Leakage on CC-703B at 25 GPM and rising to 750 GPM.

Time Position Applicants Actions or Behavior RO RD RD SRO RD RD RD RD Continuous Action Step Check CCW Surge Tank level (Ll-614B)

- STABLE DR RISING (ND)

RNO

- WHEN CCW Surge Tank level (Ll-614B) is Stable DR Rising, THEN perform Step 9.

Start a Second Primary Water Pump Check COW Surge Tank level (LI-614B)

LOWERING (YES)

Dispatch Operator To Perform Attachment 3, COW Leak Search, While Continuinq With Procedure SRO Go To PATH-i While Continuing With This Procedure Continuous Action Step Determine If Pump Cavitation is Occurring OR Imminent As Follows:

Check Surge Tank Level

- LESS THAN 5% (YES)

Check COW Pump Discharge Pressure (Local) AND Flow -

WIDE OSCILLATIONS (YES)

Check Reactor CRITICAL (YES)

Verify Reactor TRIPPED (Large Break LOCA will occur when the reactor trip breakers are opened)

Stop ALL ROPs Appendix D NUREG-i 021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 CT Time Op Test No.:

1 Scenario #

4 Event #

6 Page 17 of 36 Event

Description:

Large Break LOCA on Reactor Trip Position Anolicants Actions or Behavior RO START OF PATH-I ACTIONS Immediate Action Step Reactor tripped (YES)

BOP Immediate Action Step Turbine tripped (YES)

BOP Immediate Action Step El & E2 energized (YES)

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

RD RCP TRIP CRITERIA a.

IF BOTH conditions below are met, THEN stop all RCPs:

SI Pumps AT LEAST ONE RUNNING AND RD 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)

Verify Phase A valves closed (NO)

Critical Task RD FP-248, 249, 256 and 258 did not close automatically and will have to be manually closed from the CFPP.

Immediate Action Step SI initiated (YES)

SRO Open Foldout A 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 18 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior Verify SI valves properly aligned (NO)

Critical RO Valves Sl-870A and 870B did not open on the SI and at least one of Task the valves must be opened to provide an injection flow path to the core.

Examiners Note: AOP-O14 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-O14 will affect the following steps that are preceded by a @ symbol.

RO

@ At least one CCW pump running (NO)

BOP

@ E-1 AND E-2 energized by offsite power (YES)

RO

@ Start CCW Pump 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 RO Verify two SI pumps running (YES)

RO Verify both RHR pumps running (YES)

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

Appendix D Operator Action Form ES-D-2 C7 Time Op Test No.:

1 Scenario #

4 Event #

6 Page 19 of 36 Event

Description:

Large Break LOCA on Reactor Trip Position II Aonlicants Actions or Behavior RO

@ Verify open Therm Bar Flow Cont FCV-626 unless closed due to ruptured Therm Bar BOP All SW & SW booster pumps running (NO)

BOP Attempt to start all SW and SWB Pumps BOP NORTH or SOUTH SW HDR LO PRESS ALARMS ILLUMINATED (YES)

BOP CLOSE V6-16C OR V6-16A and V6-168 BOP Secure Turbine Building equipment using Supplement M.

(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)

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 BOP

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

- CLOSED

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

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

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

RD RD Continuous Action Step CV pressure remained below 10 psig (NO)

Verify CV Spray Initiated (YES)

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

4 Event #

6 Page 20 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time 1

Position Applicants Actions or Behavior BOP Verify both EDGs running (YES)

Continuous Action Step BDP Restart Battery Chargers within 30 minutes of Power Loss using DP 601 RD Verify all CV Spray Pumps running with valves properly aligned (YES)

RD Verify appropriately 12 GPM Spray Additive tank flow (Valve Sl-845C will be throttled to adjust flow to -12 GPM as read on Fl-949)

RD Verify Phase B Isolation Valves closed (YES)

RD Stop all RCPs (Previously secured lAW Foldout A)

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 OPERATOR: 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 #

4 Event #

6 Page 21 of 36 Event

Description:

Large Break LOCA on Reactor Trip 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 (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%

RO RCP Thermal Barrier Cooling Water Hi or Lo flow alarms illuminated (YES)

RO IF seal cooling is NOT restored within 15 minutes, THEN perform Supplement R RO At least one charging pump running (YES)

RO Greater than 5 inches thermal barrier Delta P OR 6 GPM seal injection to all RCPs (YES)

RO At least one Instrument Air Compressor running (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 36 Event

Description:

Large Break LOCA on Reactor Trip Time N

Position N

Applicants Actions or Behavior RO RO BOP RO RO BOP Stop RCP with Therm Bar Delta P less than 5 inches AND seal injection less than 6 GPM (RCPs previously secured).

Seal cooling established to all RCPs (YES)

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

(No RCPs are running. Candidate should use TICs.)

RCS temperature greater than 547°F (NO)

(No RCPs are running. Candidate should use TICs.)

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.

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)

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 23 of 36 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 Fl-605 GREATER THAN 1200 GPM (YES) b.

Reset SPDS and return to procedure and step in effect.

Event

Description:

Large Break LOCA on Reactor Trip Time Position II Anolicants Actions or Behavior BOP BOP BOP RO RO RO BOP Any S/G Completely Depressurized (NO)

R-19s, R-31s, R-15 Rad levels normal (YES)

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

CV Pressure Normal (NO)

GO TO PATH-i, Entry Point C Reset SPDS and initiate monitoring CSFSTs FRP-P.i, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK, has a RED Path due to the excessive RCS cooldown.

FRP-P.1 actions to follow.

FRP-P.1 Actions Check CST Level LESS THAN 10% (NO)

RNO IF CST level lowers to less than 10%, THEN perform Step 2.

Go To Step 3.

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

Appendix D Operator Action Form ES-D-2 1

Scenario #

4 Event #

6 Page 24 of 36 Event

Description:

Large Break LOCA on Reactor Trip Position IL Applicants Actions or Behavior Op Test No.:

Time SRO Re-enter PATH-i at Entry Point C Open Foldout B SRO (No actions required)

BOP Request periodic activity samples of All SIGs RO At least one RCP running (NO)

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 SIG with Uncontrolled Level Rise (NO)

BOP R-i9s, R-31s, AND R-15 Rad Levels Normal (YES)

RO PZR PORVs Closed (YES)

RO Open at least one PORV Block unless Closed to Isolate an Open PZR PORV 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 25 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior RO RO RO Continuous Action Step IF PZR PORV Opens on High Pressure, THEN Verify Reclosure at or Below 2335 PSIG. Close PORV Blocks as Necessary.

Reset SI Continuous Action Step IFOffsite Power is Lost, THEN Restart Emergency Safeguard Equipment Reset CV Spray Reset Phase A AND Phase B Establish Instrument Air to CV.

IF Compressor Not Running, THEN Start Compressor.

Offsite Power Available to Charging Pumps (YES)

At Least One Charging Pump Running (YES)

Establish Charging Flow as Necessary CV Spray Pumps Running (YES)

RO RO CREW RO RO RO Continuous Action Step RO WHEN CV PRESS LOWERS BELOW 4 PSIG, THEN STOP CV SPRAY PUMPS AND CLOSE SI-880 VALVES BOP 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 26 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position N

Applicants Actions or Behavior RO RO RO BOP BOP BOP RO SRO RO RO RCS Subcooling Greater Than 35°F [55°F] (NO)

Continuous Action Step 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-enerciized)

RCS Pressure Greater Than 275 PSIG [400 PSIG] (NO)

E-1 AND E-2 energized by offsite power (YES)

Starting Air Receivers repressurized to unToaded EDGs (YES)

Stop the unloaded EDGs SRO Foldout Pages Are Not Applicable During Performance Of This Procedure No CCW Pumps are available Supplement D components capable of recirc (NO)

Exit PATH-i to EPP-i 5, Loss of Emergency Coolant Recirculation Continuous Action Step:

Check Emergency Coolant Recirculation Capability RESTORED (NO)

Reset SPDS AND Initiate Monitoring Critical Safety Function Status Trees 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 27 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II osition II Applicants Actions or Behavior RO RO Continuous Action Step:

Check Suction Source To Any Of The Following Pumps LOST (NO)

SI Pumps RHR Pumps CV Spray Pumps Check Emergency Recirculation Equipment AVAILABLE USING SUPPLEMENT D (NO)

RNO Try to restore at least one train while continuing with this procedure.

RO Place The CONTAINMENT SPRAY Key Switch To The OVRD/RESET Position RO RO Verify The Following CV RECIRC FANS RUNNING (YES)

HVH-1 HVH-2 HVH-3 HVH-4 Continuous Action Step:

Check RWST Level

- LESS THAN 9% (NO)

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 36 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior 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 (NO)

IF a CV Spray Pump is required to be stopped, THEN close the discharge valves of any stopped pump:

CV Spray Pump A SI-880A and B CV Spray Pump B SI-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%

Contact Chemistry To Obtain Periodic Boron Samples Of The Following:

RO Reactor Coolant System Pressurizer 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 29 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior RO BOP BOP Ensure Adequate Shutdown Margin Exists As Follows:

a.

Check boron sample results AVAILABLE (NO)

RNO -WHEN sample results available, THEN perform Step 18.b Observe NOTE prior to Step 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 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 COOLDOWN (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.

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)

BOP RO Check steam dump to Condenser AVAILABLE (NO)

RNO Dump steam from S/Gs using STEAM LINE PORVs.

Go To Step 20 Check RCS Hot Leg Temperatures

- LESS THAN 543°F (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 30 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time Position Applicants Actions or Behavior RO RO RO BOP Shutdown secondary as follows:

BOP a.

Check S/Gs ANY RUPTURED (NO)

GoToStepl.c RO 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 BLOCK position

b. Verify LO PRESS SAFETY INJECTION BLOCKED status light

ILLUMINATED (YES)

Reset SAFETY INJECTION Continuous Action Step Check Off-Site Power AVAILABLE (YES)

Check Safeguards Pump Status

- ANY RUNNING (YES)

SI Pumps OR RHR Pumps Establish One Train Of SI Flow As Follows:

a. Verify SI PUMPS

- ONLY ONE RUNNING

b. Check RCS Pressure LESS THAN 275 PSIG [375 PSIGJ

c. Verify RHR PUMPS

- NO MORE THAN ONE RUNNING Supplement M, Component Alignment for Loss of SW to Turbine Building Actions 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 31 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position II Applicants Actions or Behavior BOP BOP BOP 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:

MS-70A MS-70B 3.

WHEN the valves are open, THEN release the THINK pushbutton.

AOP-014, Component Cooling Water System Malfunction ACTIONS Verify the following equipment is stopped:

FWPUMPAandB COND PUMP A and B HEATER DRAIN PUMP A and B GOV FLUID PUMP A and B VACUUM PUMP A and B Return to procedure and step in effect 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 32 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position AroIicants Actions or Behavior 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 COW 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 Ll-802, CHANNEL II CV WATER LEVEL ROP Abnormal Conditions

b. Check CV - LOCATION OF COW BREAK (NO)

RNO

- IF subsequent parameters indicate location of break in the CV, THENGoToStep15.

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 33 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position Anolicants Actions or Behavior Continuous Action Step Determine if actions for Auxiliary Building flooding are necessary as follows:

a.

Check for any of the following indications of flooding:

Water level on Aux Bldg first floor GREATER THAN 6 INCHES (NO)

OR RO/BOP APP-001-E4, RHR PIT A HI LEVEL ILLUMINATED (NO)

OR APP-001-E5, RHR PIT B HI LEVEL ILLUMINATED (NO)

RNO IF at any time flooding is indicated, THEN perform Attachment

, 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 LCV-460 A&B, LTDN LINE STOP

- CLOSED RO/BOP HIC-142, PURIFICATION FLOW

- SET TO 0%

__CVC-387,_EXCESS_LTDN_STOP -_CLOSED Determine If Charging Pump(s) Should Be Stopped As Follows:

RO/BOP

a. Check Charging Pumps ANY PUMP RUNNING (YES)

b. Check RCS temperature

- GREATER THAN 150°F (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 34 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position Aorlicants 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 Coolinq To Charciinq 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 Steo 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. I

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

4 Event #

6 Page 35 of 36 Event

Description:

Large Break LOCA on Reactor Trip Time II Position II Applicants Actions or Behavior RO/BOP RO/BOP Initiate Action For Emergency Repair Of The Pipe Break Check Repair Status COMPLETE (NO)

RNO

- WHEN the repairs have been completed, THEN Go To Step 47.

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:

IE-8 amps Core Burnup:

150 MWD/MTU EFPD:

4.3 EFPD Boron:

1531 PPM Xenon:

88 pcm (72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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-1021, Rev. 9, Supp. 1

Unit 2 Status Board Ite HUT Level %

Status CVCS-A 20 Filling CVCS-B 10 Standby CVCS-C 86 Standby WHUT

NAME?

Filling Data Linked[1 WGDTS Pressure PSIG Status A

NAME?

PSIG On cover 5

NAME?PSIG In Service CHiA7 PSIG D

NAME?iJandby Shutdown Requirement Temp Boron 1.77% =AKIK 547 F Hot 1051 1.77%

F 1281 2.6%=AK/K 100 F Cold 1430 PORV Settings Setting Date 7/18/2010 321 1000 1040 1000 RCS Leakage Unidentified EZEEEEH.O 2

GP M

0 GPM 0

GPM Hi Flux At Shutdown

_jylpts 1

Setpoint Nl-31 50 150 i160 180 Normal Currents UPPER LOWER TARGET BAND N-41 115 109 2.3 5+1-N42 101 100 2.3 5+1-N-43 96 89 2.3 5+!-

191 87 2.3 5+!-

POWERTRAX Rev# 2.1.0 RNP 1% APL 112.55 FANS TestlHrs DatelTst HVE-IAIB 35640.6 p8/10 HVE-15A 18643.5 3118/10 HVE-19A/B 6928.3 5/3110 127 IMWDT15Q jpesign:

16590 Tank Level%

I Status Monitor A 10 Standby Monitor B 38 Standby WCT A Standby WCTB 7

Standby WCT C 91 Standby WCTD 10 Standby WCTE 9

Standby

DEMINERALIZERS Resin PPM In Service Date MBA 21 H-Replaced 711712010 514/2010 MBB 12265 NO i2010 3/29/2010 1

NO 9/17/2010 12/9/2009 NONe2/3/201 DEBA 0

DEB B NO 3/28/2010 1950 Condenser Air Inleakage

_Target Value GPM SGBD 0.00 A

13 CFM A

50 Flash Tank lCFM B

50 With Heat fji7CFM C

50 Recovery Total N2 Flow 8

SCFM Status Total PRT RCDT Leakage Charging Leakoff Misc Identified Primary/Secondary Secondary Loss Effluent Radiation Monitor Setpoints Rad Current NUE Value Alert Value 200X Monitor Setpoint 2X R-14C 1.OIE+04 N/A 2.020E+04 R-20 7.40E+03 N/A 1.480E+04 R-18 1.OOE+06 2.000E+08 2.000E+06 R-19A 1.05E+04 2.IOOE+06 2.IOOE+04 R-19B 9.72E+03 1.944E+06 1.944E+04 R-1 9C 9.58E+03 1.91 6E+06 1.91 6E÷04 R-37 8.51i.706E+0 1.706E+04 Manually Entered Data Linked to Chem data base Boron PPM I

Date PPM Date PPM RCS Today 1531 BAST-A 9/16/2010 21,535

NAME?

NAME?

BAST-5 j6/201 0_I 21,032

NAME?

- #NAME?

SFP J2010

NAME?

NAME?

RWST 19/16/2010 12219

NAME?

NAME?

ccum-A 8I30i 2211

NAME?

NAME?

fccum-B 8/30/2010 2206

NAME?

NAME?

áccum-C 8/30/2010 2230

NAME?

NAME?

RHR 7/6/2010 2221 Refuel Canal Refuel Cavity SFP Canal Notes/Additional Data IC-I, 2,40 BOL 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.:

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

(I) 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 SIG Feedwater Regulating Valve FCV-488 fails closed and complete loss of feedwater 7

BOP Turbine Trip Does Not Occur 8

BOP B MDAFW and SDAFW Pumps Trip when Start Signal Received 9

BOP Steam Dump Valves fail Open on Reactor Trip 10 BOP MSIVs fail to close on auto-close signal 1 1 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 maintain 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 discharge valve V6-50A will fail to close automatically. The crew will take immediate actions lAW AOP-01 2, 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 affected 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, immediate actions will be taken and the procedure will take actions to restore pressure to the normal 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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , will be entered due to PZR Pressure being less than 2205 psig. Once the Chief Examiner is satisfied with the crews actions and Tech Spec compliance, the Chief Examiner 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 channel in service and direct the removal of the channel from service. ITS Table 3.3.1-1 Item 14 which requires 2 S/G 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months . ITS Table 3.3.3-1 Item 20 Post Accident Monitoring Instrumentation for Steam Generator pressure required channels is 2 per S/C 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 Functions 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 S/G 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-l 021, Rev. 9, Supp. 1

LAppendix D Scenario Outline Form ES-D-l 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 pumps 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, Attachment 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 / Condensate Malfunction, and attempt 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 s received.

Steam dump valves will fail open and cannot be closed 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 safety injection signal. The operator will have to manually open the valves from the RTGB.

The crew will transition to FRP-H. 1, Response to Loss of Secondary Heat Sink, due to the inability to feed the S/Gs. During the procedure, all RCPs will be secured to remove the additional heat source to the RCS. FRP-H.1 will direct the operators to over-ride the Feedwater Isolation Signals and start one MFP to re-establish feedwater 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 SIG or at his discretion.

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

ILC-1I-2 NRC SCENARIO 5 SIMULATOR SETUP ICISETUP:

lC-805, SCN: 008_i i_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 Start Signal Received Event 9:

Steam Dump Valves fail Open on Reactor Trip Event 10:

MSIVs fail to Close on Automatic Signal Event ii:

RHR-744A and 744B fail to auto-open on Safety Injection EVENTS!TRIGGERS INITIATED DURING THE SCENARIO:

Event 1:

A CW Pump trips and V6-50A fails to close automatically Event 2:

PZR Pressure Controller PC-444J Range Shifts Event 3:

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 S/G Feedwater Regulating Valve FCV-488 fails closed EXPECTED PROCEDURE FLOWPATH OR COPIES NEEDED:

AOP-012 AOP-0I9 AOP-025 Main Body and Section C 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 29 Event

Description:

A CW 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 TRIP!OVLD, is illuminated.

CW Pump A RTGB indication is lost.

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.)

Check Condenser Status VACUUM PREVIOUSLY ESTABLISHED BOP (YES)

SRO SRO BOP RO BOP Enters AOP-012, Partial Loss of Condenser Vacuum or Circulating Water Pump Trip Verifies immediate actions complete.

Start any available CWPs. (All available are running.)

Make PA Announcement for Procedure Entry.

Check Liquid Waste Batch Release In Progress (NO)

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

1 Page 6

of 29 Event

Description:

A CW Pump trips and V6-50A fails to close automatically.

Time Position Aoolicants Actions or Behavior BOP BOP Check Status of the tripped CWP Discharge Valves Completed Closing (YES, V6-50A manually closed from RTGB.)

Check Plant Conditions In Modes 1 OR 2 (YES)

Check Condenser Back Pressure On P1-1312 AND P1-i 313

APPROACHES RESTRICTED REGION OF ATTACHMENT 3, CONDENSER BACKPRESSURE LIMIT CURVE (NO)

BOP BOP SRO Check Condenser Vacuum Degrading (NO)

Implement the EALs NOTE:

Crew should notify WCC SRO andlor l&C to write a work request, investigate and initiate repairs, and notify the Operations Manager.

Booth Operator Insert Event #2 (PZR Pressure Controller PC-444J range shifts) 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 #

2 Page 7

of 29 Event

Description:

PZR Pressure Controller PC-444J Range Shifts Time Position Applicants Actions or Behavior BOOTH OPERATOR:

At the discretion of the Chief Examiner, insert Event 2 PZR Pressure Controller PC-444J Range Shifts EVENT INDICATIONS:

APP-003.-D8: PZR CONTROL HIILO PRESS PZR Spray Valves PCV-455A and B OPEN PZR Pressure lowerina RO Check PC-444J, PZR PRESSURE operating properly in AUTO. (NO)

RO RO RO BOP RO RO Recognizes PZR Spray Valves are OPEN and PZR Pressure lowering below normal control band. Takes Immediate Actions of AOP-019, MALFUNCTION OF RCS PRESSURE CONTROL.

Immediate Action Step:

Determine if PZR PORVs should be CLOSED:

Check PZR Pressure less than 2335 PSIG. (YES)

Verify both PZR PORVs CLOSED. (YES)

IF any PZR PORV can NOT be CLOSED, THEN close its PORV BLOCK valve.

Immediate Action Step:

Control Heaters and Spray valves to restore RCS Pressure to desired control band.

Make PA Announcement for Procedure Entry.

Continuous Action Step:

Check PZR Pressure under operator control. (YES)

Continuous Action Step Check Pressurizer Pressure Transmitter PT-444 OR PT-445 FAILED (NO)

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

2 Page 8

of 29 Event

Description:

PZR Pressure Controller PC-444J Range Shifts Time Position Appjicants Actions or Behavior RD RD RD SRO SRO SRO Place PC-444J in MAN. (YES)

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) b.

Check PZR Heaters

- IN NORMAL CONFIGURATION (YES) c.

Manually adjust PC-444J to maintain PZR pressure.

d.

Check PZR pssure UNDER CONTROL (YES)

Implement the EALs Booth Operator Insert Event #3 (Steam Pressure Channel PT-485 fails LOW) on cue from the Chief Examiner.

Contact l&C to Make Repairs to the PZR Pressure Control System Refer To ITS For Applicable LCOs LCD 3.4.11, PZR PORV (N/A)

TRM 3.4, PZR Spray i\\T (N/A)

LCO 3.4.4 AND 3.4.5, RCS Loops (N/A)

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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , will be entered due to PZR Pressure being less than 2205 psig (The only applicable LCD.)

LCD 3.4.9, PZR Level (N/A)

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

Appendix D Operator Action Form ESD-2 Op Test No.:

1 Scenario #

5 Event #

3 Page 9

of 29 Event

Description:

Steam Pressure Channel PT-485 fails LOW Applicants Actions or Behavior Time Position BOOTH OPERATOR:

At the discretion of the Chief Examiner, insert Event 3 Steam Pressure Channel PT-485 fails LOW EVENT INDICATIONS:

APP-006-A4 Steam Line High AP APP006-B1 SIG B FW>STM Flow APP-006-B2 SIG B STM>FW Flow (When bistables are tripped)

APP-006-B3 SIG B Level Dev APP-006-E3 SIG B Wide Range HiILo 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:

I S/G Steam Pressure Section G Page 21 SECTION G

- SIG Steam Pressure Transmitter 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)

BOP Immediate Action Step Restore Affected S/G Level To Between 39% And 52%

RO Make PA Announcement For Procedure Entry Place The Affected S/G Steam Flow Selector Switch To The Alternate Channel Below:

BOP Failed Channel Affected Channel Selected Position PT-485 FI-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 29 Event

Description:

Steam Pressure Channel PT-485 fails LOW Time j Position Applicants Actions or Behavior BOP OWP-025 BOP GP-8 STEA Remove The Affected Transmitter From Service Using OWP-025:

Channel OwP I PT-485 SGP-8 M GENERATOR PRESSURE Main Steam Line B Pressure Transmitter PT-485 Booth Operator Trip the bistables for PT-485 in accordance with OWP-025, SGP-8, after the operator requests and report completed actions SRO Implement The EALs BOP BOP BOP Continuous Action Step Restore Affected Controller To Automatic As Follows:

a.

Check S/G level

- WITHIN +/-1% OF PROGRAMMED LEVEL b.

Place the affected Controller in AUTO FR-488 (STM) Selected To 485 DELETE INPUT PT-485 FROM CALO PROCESSING. (MSPO421A)

(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 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 (END OWP-025)

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

Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

5 Event #

3 Page 11 of 29 Event

Description:

Steam Pressure Channel PT-485 fails LOW Time Position Applicants Actions or Behavior SRO NOTE:

Crew should notify WCC SRO andlor I&C to write a work request, investigate and initiate repairs, and notify the Operations Manager.

Booth Operator Insert Event #4 (Loss of Cooling to the Auxiliary Transformer) on cue from the Chief Examiner.

SRO Check Technical Specifications (ITS) For Applicable LCOs ITS Table 3.3.1-1 Item 14 which requires 2 S/G 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ITS Table 3.3.2-1 Items le, lg, 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 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR Be in Mode 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months .

ITS Table 3.3.3-1 Item 20 Post Accident Monitoring Instrumentation for Steam Generator pressure 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 refers to LCO 3.3.2 Functions l.a-f (which have already been addressed)

Return To Procedure And Step In Effect Appendix D NUREG-l 021, 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time jj Applicants 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 I

BOP Dispatch an Operator to respond lAW APP-046.

BOOTH OPERATOR: Acknowledge the request to check the alarms at the Auxiliary Transformer and report the below listed conditions.

Report the following alarms:

APP-46-11, Loss of Normal 48OVac Power Source (180)

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-1021, 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time II Position II Arplicants Actions or Behavior Check Alarm Function Remains Illuminated. (YES)

NOTE: The APP-046 alarms in the table below are prioritized by i mporta nce.

Observe the NOTE OR CAUTION prior to the step and go to the 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)

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 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 Pumps NOTE: IF APP-046-1 1 or APP-046-1 2 are valid alarms, THEN 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.

Check Status of the Fans and Pumps ALL LOST (YES)

BOP SRO SRO BOP SRO BOP Check Status of 480 Volt Bus 3 POWER LOST (NO)

Go to Step 11 BOP SRO BOP Appendix D NUREG-1021, 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time II Position 1 Applicants Actions or Behavior BOP Check Status of MCC-4 POWER LOST (NO)

Go to Step 17 BOP Check Status of MCC-4, Breaker 4BR TRIPPED (YES)

BOP Attempt to Reset and Close MCC-4, Breaker 4BR One Time.

(YES)

BOP Check Status of MCC-4, Breaker 4BR Closed (NO)

SRO Initiate action to repair problem causing the tripped breaker.

SRO IF breaker MCC-4 (4BR) can NOT be reclosed promptly, THEN go to Step 28.

Continuous Action Step BOP Determine If Trip Required As Follows:

- Check time elapsed since loss of all cooling Greater than 30 mm._(NO)

SRD IF the Auxiliary Transformer is NOT unloaded within 30 minutes, 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position 1

Applicants Actions or Behavior BOP Check ANY of the following Diesel Generators Paralleled to the G rid

- EDG A (NO)

- EDG B (NO)

- DS Diesel (NO)

NOTE:

RO Check Power Less than 50% (NO) (Go to Power Reduction.)

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)

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.

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

BOP/SRO BOP BOP BOP BOP BOP Notify Load Dispatcher of Load Reduction to less than 50% power.

Check Turbine Control Mode Automatic (YES)

Depress the IMP IN Pushbutton Set the Desired Load in the SETTER Set the Desired Load Rate Depress the GO Pushbutton 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time II Position A

Applicants Actions or Behavior NOTE:

-1OO gallons of Boric Acid. (The crew will add Boric Acid in 2-4 batches.) (Values based on 3%lmin 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 BORATE 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, usinci 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:

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

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-1021, 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer IPosition 1

Applicants Actions or Behavior Time RO RO 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-1 1 3A, BORIC ACID FLOW, is in AUTO.

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

NOTE:

End of Boration and Power Reduction Steps. AOP-037 steps continue below.

RECORD, in AUTO LOG, as indicated by PRIMARY WATER 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 inform the CRS OR the SM the results of the boration.

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 18 of 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position Aoolicants Actions or Behavior BOP BOP Stop the foflowing components:

1.

Circulating Water Pump A 2.

Feedwater Pump A 3.

Heater Drain Pump A 4.

Condensate Pump B Transfer loads from the Auxiliary Transformer to the Startup 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 BOP Insert key into Startup Transf synchroscope switch AND turn switch to STARTUP BUS 2 position BOP WHEN the synchroscope come up to the 12 oclock position, THEN close START-UP TO 4KV BUS 2 BKR 52/12 BOP WHEN breaker 52/12 indicates closed, THEN return switch to the mid-position AND verify UNIT AUX TO 4KV BUS 1 BKR 52/7 has opened.

BOP Insert key into 4KV TIES synchroscope switch AND turn switch to BUS 3 & 4 position.

BOP WHEN synchroscope comes up to 12 oclock position, THEN close 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 29 Event

Description:

Loss of Cooling to the Auxiliary Transformer Time Position II Applicants Actions or Behavior BOP BOP BOP SRO SRO Turn synchroscope key switch to mid position.

Check Auxiliary Transformer Unloaded (YES)

Check Auxiliary Transformer Alarm Status as Follows:

a.

Press and release the Reset pushbutton.

b.

Check all APP-046 Alarms extinguished. (NO)

IF APP-046 Alarms are present that have not been addressed, THEN go to Step 3.

Implement the EALs.

BOOTH OPERATOR:

As soon as the power reduction is> 5% or at the discretion of the Chief Examiner, insert Event # 6 (B SIG Feedwater Regulating Valve FCV-488 fails closed.)

SRO Check Technical Specifications for Applicable Action Statements.

3.8.1 AC Sources Operating (N/A) 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 and!or l&C to write a work request, investigate and initiate repairs for the loss of cooling to the transformer, and notify the Operations Manager.

SRO Check Status of Condition Causing Alarm Corrected (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 20 of 29 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 1

Position II Applicants Actions or Behavior BOOTH OPERATOR:

At the discretion of the Chief Examiner, insert Event 6, B SIG 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 BOP BOP Immediate Action Step (AOP-O10)

Check Feedwater Regulating Valve Operating Properly (Manual OR Auto) (NO)

Verify FRV for affected SIG in manual control. (Takes manual control of FCV-488 and attempts to OPEN) (No response from controller.)

Stop any load change in progress. (Turbine to Manual, if applicable)

BOP 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.

BOP RO IF unable to control SIG level THEN trip the Reactor AND Go to PATH-i. (YES)

Immediate Action Step:

Reactor Tripped. (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 21 of 29 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 1

Position ir Ailicants Actions or Behavior BOP BOP RO SRO C REW Immediate Action Step:

E-i AND E-2 energized. (YES)

Continuous Action Step IF DS Bus is deenergized THEN place DSDG in service using EPP 25.

Immediate Action Step:

SI Initiated. (YES)

Enters PATH-i and verifies Immediate Actions.

Open Foldout A.

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)

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

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 22 of 29 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 TLme Position Applicants Actions or Behavior BOP BOP BOP BOP SRO RO RO RO RO BOP Verify FW Isolation valves are closed. (YES)

Verify both FW pumps are tripped. (YES)

Verify both MDAFW pumps are running. (NO) (Unable to start any MDAFW pump from RTGB.)

If additional Feedwater is required, start the SDAFW pump. (NO, SDAFW Pump started but tripped)

WCC SRO or AO may be dispatched to investigate the cause of the MDAFW Pump B and SDAFW Pump trip.

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

Verify 2 SI pumps running. (YES)

Verify Both RHR pumps running. (YES)

Verify SI valves are properly aligned. (NO)

RHR-744A/B failed to auto-open on SI. Manual action must be taken to open the valves.

At least one CCW pump is running. (YES)

All SW and SW Booster pumps running. (YES)

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 23 of 29 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 1

Applicants Actions or Behavior RD 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 RD

- V12-9, CONT PURGE VALVE

- V12-1O, 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 HZ 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-1021, Rev. 9, Supp. 1

Appendix D Operator Action Form ES-D-2 Time N

Position N

-- Applicants Actions or Behavior Op Test No.:

1 Scenario #

5 Event #

6, 7, 8, 9, 10, Page 24 of 29 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 BOP RO BOP Critical Task BOP BOP SRO 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 RO steam dump malfunction not identified. Contingency steps have been added should RCS pressure be less than 1350 psig and are annotated with a @ symbol.)

RO

CONTINUOUS ACTION STEP:

Restart battery chargers within 30 minutes of power loss using OP 601.

CONTINUOUS ACTION STEP:

CV Pressure has remained below 10 psig. (YES)

Automatic Steam Line Isolation Initiated (NO)

Automatic Steam Line Isolation Required (YES)

Verify all MSIVs AND MSIV Bypasses Closed MSIVs must be manually closed, if not performed earlier.

Locally open breaker for HVS-1 at MCC-5 CMPT 7J within 60 mm of SI Initiation.

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 29 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 II Aplicants 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)

RO Reset SPDS and Initiate Monitoring of Critical Safety Function Status Trees SRO Transition to FRP-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

BOP Check Total Feed Flow less than 300 GPM due to operator action.

(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 29 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-744N8 fail to auto-open Time N

Position Aoolicants Actions or Behavior Booth Operator

)perations Staff is not currently available for consultation.

Examiners Note:

Crew should have realized at this point that Supplement I is not the appropriate mitiqation strategy and transition back to FRP-H.1.

BOP Check AFW Lines INTACT (YES)

SRO SRO RO RO RO BOP BOP BOP

@ Place RHR System in service using Supplement I.

@ Consult Plant Operations Staff to determine if RHR should be placed in Core Cooling Mode.

@ Check RHR System To be used in core cooling mode. (YES)

@ Check RCS Pressure Less than 375 psig [350 psig] (NO)

@ WHEN RCS pressure less than 375 psig [350 psig], THEN go to Step 4.

Continuous Action Step:

Check Any TWO SIG Wide Range Levels less than 10%. [19%] (NO)

Continuous Action Step:

Check CST level Greater Than 10% (YES)

Verify all S/G Blowdown AND Sample 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 #

5 Event #

6, 7, 8, 9, 10, Page 27 of 29 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 Applicants 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 AFW Pump suction supply is available.

b.

Position the MDAFW Pump LOCAL/REMOTE Switch to LOCAL BOP c.

Attempt to start the MDAFW Pump as follows:

1)

Depress the MDAFW Pump local STOP Pushbutton 2)

Depress the MDAFW Pump local START Pushbutton 3)

Check MDAFW Pump STARTED (NO)

Place the LOCAL/REMOTE Switch to REMOTE.

BOP Check AFW Flow to S/Gs Greater than 300 gpm. (NO)

RO Stop ALL RCPs 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 29 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-744A/B fail to auto-open Time Position Applicants Actions or Behavior BOP RO BOP Check Condensate System IN SERVICE (YES)

Place ALL the Feedwater Isolation Key Switches in the OVRD/RESET 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)

c. Open the FRV Bypass Valves FCV-479 FCV-489 FCV-499

d. Check FW Flow Established (YES)

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 The Chief Examiner may terminate the scenario anytime after FW flow has been established to at least one SIG, or at his discretion.

SOP Check S/G Levels As Follows:

a.

Level InAt Least One S/G

- GREATER THAN 8% [18%] (NO)

Appendix D NUREG-1021, 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:

EQ Xenon Tavg:

565.8°F Bank D Rods 168 Steps EQUIPMENT UNDER CLEARANCE:

A MDAFW pump inoperable with breaker racked out 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.

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

Unit 2 Status Board I

Date:

iToday Time:

6:00:00 AM Cycle:

EFPD 448 Design 473.5 HUT Level %

Status CVCS-A 20 Filling CVCS-B 10 Standby VVHUT

NAME?

Filling Data Linked to P1 WGDTS Pressure PSIG Status A

J#NAME?

PSIG On cover B

NAME?PSlGn Service C

1

NAME?

PSIG Isolated D

NAME?

PSIG Standby Shutdown Requirement Temp Boron 1.77%=LKIK 547FHot 258 t7K/KTh5Jl 2.6% =LK/K LCoi7L 6%KIK N/A PORV Settings Setting Date POT IGP-3 Psig AT118I2010 3.21 B

1040 C

7/18/2010 3.44 1000 RCS Leakage 0.00 Unidentified Total 0.03 GPM Pi 0.02 Charging Leakoff 0

GPM Primary/Secondary 0

GPD Secondary Loss 17.3 GPM Hi Flux At Shutdown

Previous ARI Counts Setpoint

Nl-31 50 150 Normal Currents JPPER LOWER LARGET BAND 136

_L0.0212 5+!-

N-42 126 125 0.0212 5+!-

Nt 121 N-44T108 rii1-i POWERTRAX Rev# 2.1.0 RNP 1% APL 112.55 FANS TestlHrs Date/Tst HVE-IA!B 35640.6 3/8(10 HVE-19A/B 6928.3 5/3/10 512712010 19:45 7/6)2010 Refuel Canal Refuel Cavity SFP Canal 27 IMWD/MT:

15697 Design:

16590 Tank ILevel%

Status MonitorA 10 Standby Monitor B 38 Standby WCTA 37 Standby Standby WCIC9 Standby WCTD 10 Standby WCTE 9

Standby DEMINERALIZERS Resin jjRId MB A 2194 YES 7(17(2010 5/4/2010 MB B 2265 7/1712010 3/29/2010 CATION 1021 NO 9/17/2010 09 DEB A 0

NO New 2/3/2010 BB/201E 9/2312008 412212008 1950 Condenser Air Inleakage Target Value GPM SGBD A

13 CFM A

50 Flash Tank B

0 CFM B

50 With Heat Known CFM

- C Recovery Total 5

CFM N2 Flow 8

SCFM Status Effluent Radiation Monitor Setpoints Rad Current NUE Value Alert Value 200X Monitor Setpoint I

2X R-14C 1.OIE÷04 N/A 2.020E+04 R-20 40E+03Ii0 R-18 1.OOE+06 I

2.000E+08 2 000E+06 R-19A 1.05E÷04 1

2.100E÷0600_

R-19Bj9.72E+03 1.944E+06 1.944E+04 R-19C 9.58E+03 1.916E.06 1.916E+04 R-37 iii+o 1.706E+06 1.706E+04 Manually Entered Data Linked to Chem data base Boron PPM Date PPM Date PPM J]day 132 BAST-A 9/16/2010 21,535

NAME?

NAME?

21,032 SFP 9/1512010 2246

NAME?

NAME?

NAME?

Accum-A 8/30/2010 2211

NAME?

NAME?

Accum-B 8/30/2010 2206

NAME?

NAME?

j&30(2010 2230

NAME?

iAiE?

RHR 2221 SR 3.7.11.2 Last Completed Notes/Additional Data IC-17, 20, 22 EOL

a

ML120470364

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