ML033250186

Draft - Section C Operating

ML033250186
Person / Time
Site:	Indian Point
Issue date:	08/05/2003
From:	Christman R Entergy Nuclear Northeast
To:	Conte R NRC/RGN-I/DRS/OSB
Conte R
References
50-247/03-301 50-247/03-301
Download: ML033250186 (75)

Text

Appendix D Scenario Outline Form ES-D-1 Event No.

v Malf. No.

Facility:

I P2 Scenario No.:

4 Op Test No.:

1 1

2 3

4 5

6 Examiners:

Candidates:

CR5 RO PO R (RO)

Reduce load N (BOP)

N (CRS)

MAL-C (ALL)

Rod P-6 Dropped Rod during rod motion CRF002AV MOT-C (ALL) 21 Condensate Pump Failure CFWOO1 B MAL-SGN004A RLY-PPL487 C (RO)

M (ALL)

Steam Line Rupture Downstream of MSIVs. Reactor trip required.

Failure of automatic actuation of Safety Injection. Manual initiation required.

RLY-PPL488 PLP-RHR022 M (ALL)

RCS Leak Outside of VC Initial Conditions: 50% power MOL 21 Charging Pump 00s 21 CCW Pump 00s Small SG Tube Leak < 5 GPD Turbine 21 rupture disc is leaking. Reduce Power to 250 MWe at 200 MWe per hour and remove Main Turbine and Generator from service Manually actuate at least one train of SIS-actuated safeguards before any of the following:

Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRP Completion of step 5.a of ES-0.1 Turnover:

Critical Tasks:

Trip all RCPs prior to completion of E-0 step 12 Isolate the LOCA outside of containment before transition out of ECA-1.2

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Event Description

Scenario Event Description IP2 Simulator Scenario 4 v

The team will assume the shift and continue with a load reduction in progress in accordance with POP-3.1, beginning at step 4.14.

When rod motion occurs, Control Rod P-6 will ratchet into the core due to a moving gripper failure, requiring the load reduction to be stopped and the condition evaluated IAW AOP-ROD-1.

When the plant is stable, a bearing failure on 21 Condensate Pump will occur. The team will start the standby Condensate Pump IAW AOP-FW-1, Loss of Feedwater.

When SG Levels are stable, a Steam Line Rupture downstream of the MSlVs will occur, requiring a reactor trip. Subsequently, Automatic SI actuation will fail to occur when demanded, requiring manual actuation. Simultaneous with reactor trip, a rupture will occur on the RHR discharge header outside of containment.

EOP flow path: E ECA-1.2 - E-1

Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 4 v

Reset simulator to IC-226 (PW nanolOO7)

Place diskette in A drive Click the button to run batch file New#?.bat and verify that the following malfunctions are 21 Charqinq Pump 00s:

21 CCW Pump 00s:

IRF LOA-EPS010 (-1 0) OUT Place pump control switch in TPO and apply danger tag IRF LOA-EPS013 (-1 0) OUT Place pump control switch in TPO and apply danger tag Auto SI Master Relays Stuck Contacts IMF RLY-PPL487 (-1 0) 2 IMF RLY-PPL488 (-1 0) 2 MAL-CRF002AV P6 Dropped Rod IMF MAL-CRF002AV (-1 0) 1 BRG I Failure Condensate Pump 21 MTR IMF MOT-CFW001 B (2 0) 0.000 600 0.000 Event trigger #2 SIG 21 HDR LEAK DNSTRM CHK VLV MAL-SGNOO4A L

Event trigger #3 RHR PUMP DISCHARGE HDR Leak IMF FLX-RHR008 (30 0) 0.000 0 0.000 IRF PLP-RHR033 (30 0) 100.000 0 IRF PLP-RHR022 (30 0) 100.000 0 Event trigger #30 on reactor trip Materials needed for scenario:

0 0

GraphBook 0

Tags for tagged equipment 0

Reactivity Summary Sheet POP-3.1 marked up to step 4.14 Note: None

v 0

a a

e a

a a

Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Turnover Information Scenario 4 The plant is at 50% power, steady state conditions exist.

Middle of Life, Cb is 1029 ppm.

EFPD = 340 Control Bank D = 195 steps Tavg = 553.5 O F RCS Pressure = 2235 psig Pressurizer Level = 42%

A small Steam Generator Tube Leak exists on 23 SG, less than 5 gallons per day.

Risk Assessment = GREEN Daily Risk Factor = 0.94 The followinq equipment is out of service:

a 21 Charging Pump. Return expected in approximately 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

21 Component Cooling Water Pump. Return to service in approximately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

Team instructions:

The Main Turbine 21 Rupture Disc is leaking approximately 12 SCFM.

In accordance with POP-3.1, continue to shut down at a rate of 200 MWe per hour and remove the Main Turbine and Generator from service.

Appendix D 0 pe rator Act ion Form ES-D-2 Page 5

of Op Test No.:

Scenario#

4 Event#

1 Event

Description:

Reduce Load CRS RO RO RO BOP RO RO Note: Proceed to event 2 when rod motion causes the dropped/misaligned rod malfunction to occur.

Refers to POP 3.1 Note: CRS may review previously performed steps in the POP to verify that they have been completed.

BORATE per SOP 3.2, Reactor Coolant System Boron Concentration Control, as necessary to maintain control banks above insertion limits required by GRAPH RPC-6, Cycle 14 Core Operating Limits Report.

Note: Actions for boration are on pages 7 of this scenario guide necessary, PLACE rod control in MANUAL to maintain rods above the Insertion Limit.

MAINTAIN delta flux within the target band.

MONITOR condenser sextants for sodium increase.

dERlFY TAVE AND Pressurizer Level are maintained on irogram per Graph RCS-2, Pressurizer Level V.S. TAVE.

VIAlNTAlN steam generator levels between 40 and 50 percent

\\]arrow Ranae.

Amendix D Ooerator Action Form ES-D-2 RO Event

Description:

Reduce Load Time 1

Position I

Applicant's Actions or Behavior NULL manual setpoint on feedwater regulating valve control to facilitate rapid transfer from AUTOMATIC to MANUAL control.

NOTE WHEN erratic governor operation is observed, governor oil pressure may be raised above the controlling load limit to avoid adverse Main Turbine operation.

i, RO INITIATE load decrease using either of the following as directed by CRS:

o Governor control o Load Limit control

Appendix D Operator Action Form ES-D-2 Scenario#

4 Event#

1 1

Op Test No.:

Event

Description:

Reduce Load Refers to SOP-3.2 for boration RO DETERMINE RCS Boron concentration from reactor coolant sample analysis.

RO o

analysis following concentration adjustment is NOT yet available, ESTIMATE Boron concentration based on latest readings.

NOTE Determinations should be based upon rod position, RCS Boron concentration, Xenon level variations, incremc 7 ita1 Boron and rod worth, and operating experience.

DETERMINE magnitude of increase in Boron concentration necessary to accomplish desired reactivity change using one or more of the following references:

o GRAPH CVCS-SA, Boration Nomograph for Hot RCS o GRAPH CVCS3B, Boration Nomograph for Cold RCS o GRAPH CVCS-6, Boration - Dilution Tables o GRAPH RV-2, Total Power Defect (PCM) as a Function of Power and Boron Concentration at MOL o GRAPH RV-3, Differential Boron Worth (Hot Zero Power) at MOL o GRAPH RV-4, Total Temperature Defect (PCM) as a Function of Temperature and Boron Concentration at MOL o GRAPH RV-9, IP2 Cycle 15 Reactivity Equivalents o POP 1.2, Reactor Startup o WCR 1, Reactivity Summary IF the change in RCS Boron concentration is anticipated to be greater than or equal to 25 ppm, OPERATE Pressurizer heaters to open spray valve.

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Appendix D Operator Action Form ES-D-2 RO Scenario#

4 Event#

1 VERIFY BATPs shift to fast speed.

RO RO RO RO RO RO RO ESTIMATE total volume of boron required for boration from boration graphs or references listed in step 4.5.2.

PLACE the RCS Makeup Control switch to STOP.

SET Boric Acid Integrator to amount determined in step 4.5.3.

PLACE the RCS Makeup Mode Selector switch to BORATE.

FCV-1 IOA, Boric Acid Flow Control, may be left in AUTO or placed in MANUAL as directed by CRS.

VERIFY boric acid transfer pumps are in AUTO.

PLACE the RCS Makeup Control switch to START.

I IF in manual, ADJUST FCV-11 OA, Boric Acid Flow Control, to obtain desired boric acid flow rate (may be greater than meter range).

Y c

Appendix D 0 pe rat o r Act ion I

I Form ES-D-2 Page Of 4 Op Test No.:

1 Scenario#

4 Event#

1 Event

Description:

Reduce Load Time 1

Position I

Applicant's Actions or Behavior 1

w RO RO RO RO RO IF desired to maximize Boron flow, CLOSE the appropriate BATP recirculation va Ive.

o HCV-104 Inlet Inlet o HCV-105 CVCS/Boric Acid Tank 22 BA CVCS/Boric Acid Tank 21 BA MONITOR Nuclear Instrumentation, Rod position, and RCS temperature closely during any reactivity changes.

WHEN boration operation has been completed, PERFORM the following:

PLACE the RCS Makeup Control switch to STOP.

PLACE the Makeup Mode Selector switch to MANUAL.

ADJUST FCV-1 IOA, Boric Acid Flow Control, dial setting to the new RCS Boron concentration per applicable CVCS Graph:

GRAPH CVCS-IA, Blended Makeup - (0-500) with 120 Gpm PW GRAPH CVCS-1 B, Blended Makeup - (0-2000) with 120 Gpm PW GRAPH CVCS-1 C, Blended Makeup with Various PW Flows dERIFY FCV-110A control switch in AUTO.

?LACE the RCS Makeup Control switch to START.

Appendix D Operator Action Form ES-D-2 RO

~

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Op Test No.:

1 Scenario#

4 Event#

I Page 10 of Event

Description:

Reduce Load VERIFY approximately 30 gallons of blended makeup flows through blender.

Time Position 1

Applicant's Actions or Behavior L

PLACE RCS Makeup Control switch to STOP.

RO RO RO CRS SELECT AUTO on RCS Makeup Mode Selector switch.

PLACE the RCS Makeup Control switch to START.

IF Reactor is shutdown, REQUEST a sample for RCS Boron concentration within 30 minutes of completing the boration.

RO LOG amount of boric acid added to system for boration in CCR Log Book.

I 1

When rod motion occurs, proceed to event 2

Appendix D Operator Action Form ES-D-2 L

Event

Description:

MisalignedlDropped Control Rod P-6 Time A

Position I

Applicant's Actions or Behavior Booth Instructor: When rod motion occurs, Control Rod P-6 should ratchet into the core.

Note: The more Control Bank D inserts the more deviation rod P-6 will experience.

Indications received:

Alarm SF 2-7 Control Rod or Power Distribution Trouble Alarm FC 2-4 NIS Power Range Channel Deviation 3%

Control Rod P-6 IRPI indicates lower than the rest of Control Bank D PES alarms for Rod to Bank deviation and Rod to Rod deviation Implements AOP-ROD-1 Rod Control and Indication Systems Malfunctions Determines continuous unwarranted rod motion is NOT occurring.

Determines that indication of a dropped or misaligned rod or IRPl failure exists.

Diagnoses malfunction as a misaligned control rod

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

1 Scenario# -

4 Event#

2 Page 12 of Event

Description:

Misaligned/Dropped Control Rod P-6 Time I

Position I

Applicant's Actions or Behavior I

Ro CRS Places rod control in MANUAL Refers to the following Technical Specifications 0

3.1 0.3, Quadrant Power Tilt Limits 0

3.10.5, Rod Misalignment Limitations 0

3.10.7, inoperable Rod Limitations Notify I&C to investigate for cause of misaligned rod Determines actual position of misaligned rod Booth Operator: Call as I&C and inform that time compression is being utilised.

I&C has determined that the cause of the failure was a blown fuse and the fuse has been replaced.

Initiates a CR to document malfunction Determines that affected rod is below remainder of rods in its group.

Appendix D Operator Action Form ES-D-2 Event

Description:

Misaligned/Dropped Control Rod P-6 BOP Obtains the following from Reactor Engineer:

Booth Operator: Respond as RE that reactor should stay at or below current power level for rod withdrawal, and no rate limitation on withdrawal.

When ready to realign the rod, or at Lead Evaluators discretion, proceed to Event 3

L Appendix D Operator Action Form ES-D-2 Event

Description:

21 Condensate Pump Trips I

Time 1

Position I

Applicant's Actions or Behavior I

Booth Instructor: When directed by lead evaluator, insert the following command:

TRG!2, Actuates event trigger 2:

BRG 1 Failure Condensate PumD 21 MTR IMF MOT-CFW001 B (2 0) 100 600 0.000 Indications available:

Increasing amps on panel SC meter for 21 Condensate Pump Amps 21 MBFP speed slowly increases Alarm SE 3-2 Bearing Monitor after about 3 minutes 21 Condensate Pump trips after about 4.5 minutes After pump trip:

S/G levels decrease Multiple S/G level alarms 21 MBFP Low Suction Pressure Cutback actuates Diagnoses 21 Condensate Pump malfunction BOP I

1 NOTE: The CRS may direct the BOP operator to manually trip 21 Condensate pump due to indications of failure.

1 Ro 1

CRS Direct performance of immediate actions of AOP-FW-1 Loss of Feedwater Checks if any MBFP is operating (yes)

Announces immediate actions complete Reviews Immediate actions using the procedure Determine that a Condensate Pump has tripped

Appendix D Operator Action Form ES-D-2 BOP Scenario#

4 Event#

3 Determine that 22 Condensate pump is not running Start 22 Condensate Pump 1 Event

Description:

21 Condensate Pump Trips Ro I

Time 1

Position

]I Applicant's Actions or Behavior I

Check if load reduction is necessary to maintain FF>SF and MBFP suction pressure >310 (expected result is no load reduction necessary)

Check Tave maintained on program RO Check if MBFP suction pressure cutback is actuating RO I

I Evaluator Note: Continue with Event 4 when SG levels are increasing with FF>SF, or at the discretion of the lead evaluator

Appendix D Operator Action Form ES-D-2 TEAM CRS 1 Event

Description:

Steam Line Rupture, Auto SI Actuation Failure, LOCA Outside Containment 1

Determine reactor trip required.

Direct reactor trip and entry to E-0, Reactor Trip or Safety Injection I

Time I

Position I

Applicant's Actions or Behavior 1

Booth Instructor: When directed, insert the following command:

TRG!3, Actuates Event Trigger 3 S/G 21 HDR LEAK DNSTRM CHK VLV IMF MAL-SGN004A (3 0) 25 180 0.000 Actuates when reactor trip breakers open:

RHR PUMP DISCHARGE HDR Leak IMF FLX-RHR008 (30 0) 100 0.00 0 IRF PLP-RHR033 (30 0) 100.000 0 IRF PLP-RHR022 (30 0) 100.000 0 Indications available:

Reactor Power Increases Turbine Load Decreases S/G levels increase ALARM SA 3-2, PZR Low Pressure 2185 ALARM SA 3-3, PZR Low Level Auto Reacfor Trip SI First Out Alarm Verify reactor trip RO Verify Turbine Trip RO Verify Power to 480 V Buses BOP

Appendix D Operator Action Form ES-D-2 RO Scenario#

4 Event#

4,5,6 Steam Line Rupture, Auto SI Actuation Failure, LOCA Outside Containment Event

Description:

Check RCP Seal Cooling Starts 22 Service Water Pump Manually actuate at least one train of SIS-actuated safeguards before any of the following:

0 Transition to any E-I series, E-2 series, or E-3 series procedure or transition to any FRP 0 Completion of step 5.a of ES-0.1 Critical Task:

,1--

Critical RO 1 CRS/BOP RO 1

Ro Check if SI is actuated (no)

Determines that SI is required but not actuated.

PERFORMS Manual SI actuation by depressing both manual SI actuation pushbuttons on panel SB-2 CRS directs BOP to perform E-0 Attachment 1 Verify AFW Pumps Running (yes)

Verify total AFW flow greater than 400 gpm (yes)

Verify SI System Flow Places one RHR pump to pullout

Appendix D Operator Action Form ES-D-2 RO Scenario#

4 Event#

4, 5, 6 Page 18 of Steam Line Rupture, Auto SI Actuation Failure, LOCA Outside Containment Event

Description:

Check PRZR PORVs and Spray valves closed Check RCS Temperatures RO Critical Task Trip all RCPs prior to completion of E-0 step I 2 Critical

?=

CRS/BOP +

CRS Check if RCPs should be stopped Check SI pumps -At Least One Running Checks subcooling less than 23°F.

PERFORMS - Stops all RCPs Check if any SG is faulted (no)

Check if SG tubes are Intact (yes)

Check if RCS is intact (yes)

NOTE: All containment parameters are normal Check if SI should be terminated (no)

Check if Attachment 1 is complete.

_ _ ~

Initiate monitoring of CSF Status trees

TEAM Appendix D Operator Action Form ES-D-2 Diagnose cause of abnormal PAB Radiation levels due to a Loss of RCS inventory outside of contaiment Op Test No.:

1 Scenario #

4 Event#

4, 5, 6 Page 19 of 25 Event

Description:

Steam Line Rupture, Auto SI Actuation Failure, LOCA Outside Containment Time 1

Position I

Applicant's Actions or Behavior CRS RO Reset SI RO Transition to ECA-1.2, LOCA Outside Containment Verify Proper valve alignment (all in correct position)

Check if RHR Pumps should be stopped (yes)

RO Check SG Levels RO Check PAB Radiation - Normal (NO)

RO Verify SI has been reset CRS/RO Reset Containment isolation Phase A and Phase B BOP Establish Instrument Air to Containment BOP

Appendix D Operator Action Form ES-D-2 I

I Event

Description:

Steam Line Rupture, Auto SI Actuation Failure, LOCA Outside Containment

_ _ ~

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I T i m e Position I Applicant's Actions or Behavior I

Critical Task:

Isolate the LOCA outside containment before transition out of ECA-1.2 Critical Task TEAM RO CRS Try to identify and Isolate Break Sequentially close and open the following valves (or sets of valves) and monitor for an RCS pressure increase 0

RHR Pump cold leg injection valves MOV-746 and MOV-747.

Determines that the Leak is isolated when MOV-746 and MOV-747 are closed.

Check if break is isolated (yes)

Determines RCS pressure is increasing Transitions to E-I. Loss of Reactor or Secondarv Coolant Terminate scenario when transition is announced to -I

BOP Appendix D Operator Action Form ES-D-2 Check 345 KV MO Disc Switch F7 Open (no)

Checks generator output breakers - OPEN 1

Scenario #

4 Event#

Page 21

- O f "I Op Test No.:

Event

Description:

, Automatic Action Verification I

Time I

Position I

Applicant's Actions or Behavior Y

Note This attachment must be terminated upon CRS transition to ECA-0.0, Loss of All AC Power.

BOP Note Verify proper Charging system operation:

a. Start at least one charging pump in manual at maximum speed

b. Align charging pump suction to the RWST Open charging pump suction valve from RWST Close charging pump suction valve from VCT 0 LCV-112c Place RCS Makeup Control switch to STOP o LCV-112B o Notify CRS of any automatic actions that failed to occur during performance of this attachment o Ec re Iuipment found misaligned due to operator action should NOT be 3ositioned.

\\-

Appendix D Operator Action Form ES-D-2 1

Scenario #

4 Event#

Page 22 of Op Test No.:

Event

Description:

, Automatic Action Verification Time I

Position I Applicant's Actions or Behavior BOP BOP BOP BOP Check status of 480 volt busses:

I. All 480V busses - ENERGIZED BY OFF-SITE POWER

2. Dispatch NPO to reset:

0 All lighting 0

MCC24A 0

MCC27A 0

MCC29A

1. Stop all Condensate Pumps Verify FW Isolation:

o Main Boiler Feed Pumps - TRIPPED o Main Boiler Feed Pump Discharge Valves o FW Regulating valves - CLOSED o RN Stop Valves - CLOSED o SG Blowdown Isolation Valves - CLOSED

- CLOSED Check if Main Steam Lines should be isolated:

a. Check for either:

0 High Steam Line flow with EITHER Tave less than 541 deg F OR Steam line pressure less than 525 psig.

OR Containment pressure - EVER GREATER THAN 24 psig

b. Verify MSlVs - CLOSED derify proper Service Water System operation:

I. Three Service Water Pumps - Running on Essential Header

2. Service Water valves from Diesel Generator - OPEN

Appendix D Operator Action Form ES-D-2 1

Op Test No.:

I 1

Scenario #

4 Event#

Page 23 of 25 I c'

Event

Description:

, Automatic Action Verification Time 1

Position I

Applicant's Actions or Behavior BOP BOP BOP BOP Verify SI system pumps running:

a. Three SI pumps - RUNNING

b. 22 SI pump discharge isolation MOV-851A

c. Two RHR pumps - RUNNING AND MOV-851 B - OPEN Verify proper emergency SI System valve alignment:

a.

b.

C.

SI pump cold leg injection valves - OPEN o 856A o 856E o 856C o 856D RHR HX CCW outlet valves - OPEN o 822A o 822B RHR HX MOVS -OPEN o 746 0 747 Verify Containment Fan Coolers - IN SERVICE:

a. Five fan coolers - RUNNING

b. NORM OUT valves - OPEN

c. TCV-1104 and TCV-1105 - BOTH OPEN Verify AFW flow to all SGs

Appendix D Operator Action Form ES-D-2 BOP BOP

1. Containment Purge Valves - CLOSED 0

FCV-1170 0

FCV-1171 0

FCV-1172 0

FCV-I173 0

PCV-1190 0

PCV-1191 0

PCV-1192

2. Containment Pressure Relief Valves - CLOSED Note

of Phase A valves Verify Containment Isolation Phase A

1. Phase A -ACTUATED 0 Train A master relay CAI (above rack E) 0 Train B master relay CA2 (above rack F) 0 IVSW valves - OPEN 0

1410 0

1413

2. Phase A valves - CLOSED 0

SOV-3518 0

SOV-3519 0 WCP valves - OPEN:

0 PCV 1238 0

PCV 1239 0

PCV1240 0

PCV 1241

3. Place personnel and equipment hatch solenoid control switches to INCIDENT on SM panel

4. Dispatch NPO to periodically check 0

IVSW Tank 0

Level - GREATER THAN 92%

0 Pressure - GREATER THAN 57 PSlG 0 WCP header pressures - GREATER THAN 52 PSlG

Appendix D Operator Action Form ES-D-2 Scenario#

4 Event#

Page 25 of, Automatic Action Verification Event

Description:

Time 1

Positih Applicant's Actions or Behavior I

Evaluator note: The following step is intended for High Containment pressure condition. It will not be performed if conditions aren't met

~

BOP BOP Check if Containment Spray should be actuated:

1. Containment Pressure - EVER GREATER THAN 24 PSlG

2. Verify spray pumps - RUNNING

3. Verify spray pump discharge valves - OPEN 0

MOV-866A 0

MOV-866B 0

MOV-866C 0

MOV-866D

4. Verify Containment Isolation Phase B valves -

CLOSED

5. STOP all RCPs

6. Verify IVSW Isolation Valves - OPEN 0

7864 0

7865 0

7866 0

7867 derify CCR Air Conditioner Train A and B - RUNNING IN NCIDENT MODE 2 Jotify CRS that Attachment 1 is complete

u Appendix D Scenario Outline Form ES-D-1 Facility:

I P2 Scenario No.:

5 Op Test No.:

1 Event No.

1 2

Examiners:

Candidates:

CRS RO PO Malf. No.

Event Type*

Event Description R (RO)

Increase Load N (BOP)

N (CRS)

XMT-I (RO)

PT-455 PFZR Pressure Controlling Channel fails high RCS028A Initial Conditions:

Turnover:

3 MAL-C (ALL) 4 FLX-CFWO50 M (ALL)

EPS007D Zritical Tasks:

Loss of 480V Bus 6A Feed water Header leak inside containment 15% power MOL 5

The plant tripped 76 hours8.796296e-4 days <br />0.0211 hours <br />1.256614e-4 weeks <br />2.8918e-5 months <br /> ago due to a switchyard fault. Repairs have been completed and plant startup is in progress IAW POP 1.3 at step 4.53.

Continue with the plant startup at a rate of 200 MW per hour.

M (ALL)

Loss of all AC power Establish at least 400 gpm AFW flow to the SGs before SG dry-out occurs (WR level less than 14%)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Description IP2 Simulator Scenario 5 L

The team will assume the shift and continue with a plant startup in progress in accordance with POP-I.3, beginning at step 4.53.

During the power increase, PRZR Pressure Controlling Transmitter PT-455 will fail high requiring manual control of PRZR Pressure IAW AOI-28.0 and AOI-28-5. The CRS will refer to Technical Specifications.

480V AC Bus 6A will fault requiring implementation of AOI-27.1.13. The team will perform immediate operator actions that include starting a Charging Pump, and starting a Service Water Pump on the essential header. Bus 6A will not be recovered due to failure.

A rupture of the feed water piping to 21 SG inside of containment will result in a reactor trip and safety injection actuation. Simultaneous to the reactor trip, a fault will occur on the Station Auxiliary Transformer resulting in a loss of offsite power. 21 EDG will start, but its output breaker will not close. 22 EDG will fail to start. 23 EDG will start but cannot be used to energize faulted bus 6A. The team will diagnose a loss of all AC power and transition to ECA-0.0.

During execution of ECA-0.0, Bus 5A will be energized from the 13.8KV power source. The scenario will be terminated when transition to ECA-0.2 is announced.

EOP flow path: E ECA-0.0 - ECA-0.2

Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 5 R

Place diskette in A drive Click button to run batch file NeM2.bat and verify that the following malfunctions are t simulator to IC-227(PW nano1007)

C-'

bat Ne-2.bat PT-455 PZR PRESS CH.l fails hiqh 480V Bus 6A Fault Feedwater Header Leak in VC EDG 21 Output Breaker Failed As-Is EDG 22 Air Start Failure LOA to transfer BA Pumps

._I Triqqer to Close Seal Water MOVs Triqqer to open Bus 5A MCC breakers Materials needed for scenario:

XMT-RCS028A (1 0) 2255 60 2235 Event trigger # I IMF MAL-EPS007D (2 0) TRUE Event Trigger #2 IMF FLX-CFWOSO (3 0) 25 900 0.000 Event Trigger #3 IMF BKR-DSG001 (-1 0) 5 IMF MAL-DSG003B (-1 0) TRUE IRF LOA-CVC093 (30 0) 0.000000 0 IRF LOA-CVCO84 (30 2) 100.000 5 Event trigger #30 IMF MOV-CVC002 (29 0) 2 IMF MOV-CVC005 (29 5) 2 IMF MOV-CVCOO6 (29 IO) 2 IMF MOV-CVC007 (29 15) 2 IMF MOV-CVC008 (29 20) 2 IMF MOV-CCWOO4 (29 30) 2 Event trigger #29 IRF LOA-EPS052 (28 0) TRIP IRF LOA-EPS049 (28 5) TRIP IRF LOA-EPS053 (28 IO) TRIP IRF LOA-EPS755 (28 15) TRIP Event trigger #28 Graph Book POP-I.3 marked up to step 4.53 Note: None

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Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Turnover Information Scenario 5 0

The plant is at 15% power, 93 MWe gross, Xenon is increasing.

Middle of Life, Cbis 992 PPM.

0 Control Bank D = 151 steps 0

Tavg = 548.5OF RCS Pressure = 2235 psig Pressurizer Level = 38%

0 Risk Assessment = GREEN 0

Daily Risk Factor = 0.94 The followins eauipment is out of service:

0 None u

Team instructions:

0 In accordance with POP-I.3, continue from step 4.53 to start up at a rate of 200 MWe per hour

Appendix D Operator Action Form ES-D-2 Event

Description:

Increase Load RO RO RO RO RO RO Refers to-POP 3.1 Note: CRS may review previously performed steps in the POP to verify that they have been completed.

Withdraw Control Rods as necessary to MAINTAIN delta flux within the target band and Tave on program DILUTE per SOP-3.2, Reactor Coolant System Boron Concentration Control, as necessary to maintain delta-Flux within the target band and Tave on program.

Note: Actions for DILUTION are on pages 6 of this scenario guide VERIFY TAvF AND Pressurizer Level are maintained on program per Graph RCS-2, Pressurizer Level V.S. TAVE.

MAINTAIN steam generator levels between 40 and 50 percent Narrow Range.

NULL manual setpoint on feedwater regulating valve control to facilitate rapid transfer from AUTOMATIC to MANUAL control.

INITIATE load increase using either of the following as directed by CRS:

o Governor control o Load Limit control

Appendix D Operator Action Form ES-D-2 Scenario #

5 Event#

1 Refers to SOP-3.2 for dilution RO DETERMINE RCS Boron concentration from reactor coolant sample ana lysis.

RO o

analysis following concentration adjustment is NOT yet available, ESTIMATE Boron concentration based on latest readings.

NOTE Determinations should be based upon rod position, RCS Boron concentration, Xenon level variations, incremental Boron and rod worth, and operating experience.

DETERMINE magnitude of decrease in Boron concentration necessary to accomplish desired reactivity change using one or more of the following references:

RO o GRAPH CVCS-6, Boration - Dilution Tables o GRAPH RV-2, Total Power Defect (PCM) as a Function of Power and Boron Concentration at MOL o GRAPH RV-3, Differential Boron Worth (Hot Zero Power) at MOL o GRAPH RV-4, Total Temperature Defect (PCM) as a Function of Temperature and Boron Concentration at MOL o GRAPH RV-9, IP2 Cycle 15 Reactivity Equivalents o POP 1.2, Reactor Startup o WCR 1, Reactivity Summary IF the change in RCS Boron concentration is anticipated to be greater than or equal to 25 ppm, OPERATE Pressurizer heaters to open spray valve.

ESTIMATE total volume of PW required-for diktionfrom-grphs

Appendix D Operator Action Form ES-D-2 Event

Description:

Increase Load RO or references listed in step 4.5.2.

SET Primary Water Integrator to amount determined in step 4.5.3.

PLACE the RCS Makeup Control switch to STOP.

RO RO MONITOR Nuclear Instrumentation, Rod position, and RCS temperature closely during any reactivity changes.

PLACE the RCS Makeup Mode Selector switch to DILUTE.

RO PLACE the RCS Makeup Control switch to START.

RO WHEN dilution operation has been completed, PERFORM the following:

PLACE the RCS Makeup Control switch to STOP.

PLACE the Makeup Mode Selector switch to MANUAL.

ADJUST FCV-11 OA, Boric Acid Flow Control, dial setting to the new RCS Boron concentration per applicable CVCS Graph:

GRAPH CVCS-IA, Blended Makeup - (0-500) with 120 Gpm PW GRAPH CVCS-1 B, Blended Makeup - (0-2000) with 120 Gpm PW GRAPH CVCS-1 C, Blended Makeup with Various PW Flows

Appendix D Operator Action Form ES-D-2 1

Scenario#

5 Event#

1 Op Test No.:

I Ro

---I SELECT AUTO on RCS Makeup Mode Selector switch.

PLACE the RCS Makeup Control switch to START.

LOG amount of PW added to system for dilution in CCR Log Book.

When reactor power has been changed by approximately IO%, or at the discretion of the lead evaluator, proceed to event 2.

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

1 Scenario#

5 Event#

2 Event

Description:

PRZR PRESS CHI FAILS HIGH I

Time I

Position I

Applicant's Actions or Behavior I

Booth Instructor: When directed by lead evaluator, click button to insert the following command:

TRG!I, Actuates event trigger 1:

PT-455 PZR PRESS CH.l fails hish XMT-RCS028A (1 0) 2255 60 2235 Indications received:

Pressurizer Pressure Channel I indication increases to 2255 over 60 seconds Spray valves modulate open Actual Pressurizer Pressure decreases Alarm SA 3-2 PRZR Low Pressure 2785 PSlG RO CRS RO Diagnoses Pressurizer pressure control system malfunction Directs RO to perform immediate operator actions of AOI-28.0, Instrument Failures (NOTE: bulleted steps may be performed in any order)

Performs Immediate Actions from memory.

Verifies the following controls:

0 Turbine Load - Stable 0

Rod Control - Stable 0

PRZR Pressure Control - NOT STABLE Determines S/G control is not affected Places PRZR Pressure master controller or individual spray valve controllers in manual and closes spray valves 0

PRZR Level Control - Stable 0

MBFP Speed - Normal 0

S/G Levels - Normal.

0 S/G Pressure Control - Normal Announces Immediate Actions Complete

Appendix D Operator Action Form ES-D-2 CRS Scenario #

5 Event#

2 Directs review of immediate Operator Actions using the procedure.

BOP Performs Alarm Response Procedures for annunciators in alarm Diagnose PRZR Pressure Channel 1 instrument malfunction RO RO Transition to AOl-28.5 Pressurizer Pressure Channel Fails High CRS Manually controls Pressurizer Pressure at 2235 or within the band directed by the CRS Determine that the failed channel is the controlling channel RO BOP Verifies Pressurizer Pressure control is in MANUAL RO Places P/455A Pressurizer Pressure Defeat Switch in rack B6 to Defeat 1&4 RO CRS

~~

Return Pressurizer Pressure control to AUTO Determine that placing bistable trip switches to trip for affected channel will not cause a reactor trip.

Appendix D Operator Action Form ES-D-2 1

Scenario#

5 Event#

2 Page -

11 of 18 I Op Test No.:

Event

Description:

PRZR PRESS CHI FAILS HIGH BOP 1

CRS Trips bistable trip switches in Red A-4 rack 0

PC-455B Hi Press Trip 0

PC-455A Lo Press Trip 0

PC-455C UnblockSI 0 TC-411A Overtemp Trip 0

PC-455E SI (Alarm and proving lamp)

(Alarm and proving lamp)

(Alarm and proving lamp)

(No alarm, no light)

(Alarm and proving lamp)

Refers to Technical Specification Tables 3.52 andT.5-3 Proceed to event 3 when bistables have been tripped, or at the discretion of the lead evaluator.

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

Scenario #

5 Event#

3 Event

Description:

Loss of 480V Bus 6A Booth Instructor: When directed by lead evaluator, insert the following command:

TRG!2, Actuates event trigger 2:

480V Bus 6A Fault IMFMAL-EPS007D (2 0) TRUE Indications received:

21 and 22 EDGs start. 22 EDG Fails to start Mulfiple Alarms associated with deenergized 480V bus and breaker trips.

Deenergized equipment powered from bus 6A including the running charging pump Bop 1

CRS 1

RO I

I CRS Diagnoses 480V Bus 6A de-energized Directs RO and BOP to perform immediate operator actions of AOI-27.1.13, Loss of a 480 V Bus Check Charging Pumps Determine that no Charging Pumps are running Starts 21 or 22 Charging pumps Checks Service Water Pumps Determines that ESW header pressure is low Starts 24 SW Pump Checks RCS temperature > 200°F Checks CRDM fans - At Least three running (expect 4 running)

Announces Immediate Actions Complete Directs review of immediate actions using the procedure

Appendix D Operator Action Form ES-D-2 Event

Description:

Loss of 480V Bus 6A TEAM Booth instructor: Click button to swap inservice boric acid pumps, when Nuke Side NPO is dispatched.

Swaps BAT Pumps by activating trigger 30 I

Place control switches for bus 6A loads in pullout and OPEN bus 6A MCC Feeder breakers Diagnose 480 Volt Bus 6A De-energized BOP BOP

~~

Determine Bus 6A Lockout Status light is not lit BOP Dispatch NPO to perform visual inspection of switchgear for Bus 6A equipment Booth Instructor: NPO should report that Bus 6A has apparently suffered a catastrophic failure. Report that the back of Bus 6A switchgear is deformed and paint is blistered and smell of acrid odor.

Determine that amber light for breaker 52/6A is lit BOP Dispatch NPO to shutdown 23 EDG BOP INITIATE Technical Specification Shutdown CRS I

I rlote: Proceed to event 4 when the team has determined that a shutdown is

,equired, or at the lead evaluator's discretion.

Appendix D Operator Action Form ES-D-2 Event

Description:

Attachment I, Automatic Action Verification RO Booth Instructor: When directed by lead evaluator, insert the following command:

TRG!3, Actuates event trigger 3:

Feedwater Header Leak in VC IMF FU-CFWO50 (3 0) 25.000 900 0.000 Diagnoses 21 SG Level decreasing rapidly and containment conditions degrading Indications available:

Containment Sump level alarms on panel SB-1 Containment Humidity alarm on panel SM 27 SG Feed Flow decreases and 21 SG Level decreases Auto reactor trip if no manual trip actuated.

Auto SI on High Containment Pressure and Steam Line Delta-P CRS Following Trip Loss of Offsite Power occurs Loss of All 480 V busses Direct performance of immediate actions of E-0. Reactor Trip or Safety Injection I

I NOTE: The CRS may direct the RO to manually trip the reactor due to rapidly deteriorating plant transient.

Verifies Reactor Tripped RO Verifies Turbine Tripped RO Checks Status of 480V Busses Determines that no 480V Bus is energized Announces to team that transition to ECA-0.0 is required

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

Scenario #

5 Event#

4.5, 6 Page 15 of Event

Description:

, Automatic Action Verification 1

CRS I

Ro Critical task Directs team to perform immediate actions of ECA-0.0, Loss of All AC Power Verify Reactor Trip Verify Turbine Trip Announce immediate actions complete Verify immediate actions using the procedure Check if RCS is isolated 0

Checks PORVS closed 0

0 Checks letdown isolation valves closed Checks excess letdown isolation valve closed Establish at least 400 gpm AFW flow to the SGs before SG dry-out occurs (WR level less than 14%)

q-z Critical Verify AFW Flow - Greater than 400 GPM 0

Manually open PCV-1139 Steam Supply regulator Valve to start 22 AFW Pump 0

Manually align 22 AFWP FCVs as necessary 0 Adjust HCV-1118 Steam Supply Speed Control valve

Appendix D Operator Action Form ES-D-2 Scenario#

5 Event#

4,5,6, Automatic Action Verification Event

Description:

I Time 1

Position 1

Applicant's Actions or Behavior

'I Booth lnsi BOP BOP/CRS uctor: NPC Try to restore power to any 480V bus 0

Check EDGs running (22 not running, 21 EDG running) 0 Attempt to close 21 EDG output breaker (will not close) 0 Dispatch NPO to emergency start 22 EDG 0

Locally trip running EDGs (Note, they will probably be auto tripped before this step is performed due to lack of SW cooling) 0 Attempt to manually energize 480V bus using any available power supply per A01-27.1.I and AOI-27.1.13 Determine that 480 Bus cannot be readily energized from CCR iispatched to start 22 EDG reports that both air start motors appear to be mechanically bound. 22 EDG will not start. NPO will contact work control for assistance.

Booth Instructor: When asked, DO reports that 13.8 KV power is available from 13W92 Evaluator Note: When power is restored to any 480V bus, then recovery actions should continue starting with step 24 of ECA-0.0 CRS Place Equipment in Pullout:

0 CSPumps 0 SI Pumps 0

FCUs 0

Motor Driven AFW Pumps 0 Turning Gear Oil Pump 0

Bearing Oil Pump 0 Turbine Auxiliary Oil Pump 0

CCWPumps 0

RHRPumps Dispatch Personnel to Locallv Restore AC Power

Appendix D Operator Action Form E S T 2 CRS Op Test No.:

1 Scenario #

5 Event#

4,5,6 Page 17 of 18 Event

Description:

, Automatic Action Verification I

I Time I

Position I

Applicant's Actions or Behavior Check 13.8KV feeder 13W92 ENERGIZED (yes)

BOP CRS/BOP Place 52/SS5 and 52/EG1 in Pullout Attempt to restore power to busses per the following while continuing with step 8:

0 AOI-27.0 Diagnosis and Response to Electrical Failure 0

SOP-27.1.3 Operation of 13.8KV System 0 AOI-27.1.1 Loss of Normal Station Power 0 AOI-27.1.13 LOSS Of 48OV BUS BOP Critical Task Isolate RCP Seal Injection before starting a Charging Pump.

Energize Bus 5A from 13.8KV via 52/GT25 Direct NPO to remove control power fuses for 52/5A and manually close breaker 52/5A Critical Task TEAM Dispatch personnel to locally close valves to isolate RCP Seals and Place valve Switches to CLOSED position 0

0 0

MOV-222 RCP seal return isolatin valve outside containment MOV-250A-D, RCP seal injection isolation valves outside containment MOV-789, RCP thermal barrier CCW return isolation valve outside containment I

Booth Operator: When NPO directed to Isolate RCP seals, click the button:

When NPO directed to open MCC breakers on Bus 5A, click this button:

Appendix D Operator Action Form ES-D-2 BOP c

Close 52/SS5.

Inform team that Bus 5A is energized L-CRS Op Test No.:

Scenario#

5 Event#

4,5,6, Automatic Action Verification Determine that ECA-0.0 Step 24 should be performed per step 6 CAUTION.

Booth Instructor: When NPO dispatched, click to execute Remove control power fuses breaker 52/5A RO I Manually control SG atmospheric Steam Dumps to stabilize SG Pressures I CRS Press 86l5A reset pushbutton and verify white light is on BOP Select Recovery Procedure Determine transition to ECA-0.2 (expected)

I Verify Service Water system operation BOP Verify the following equipment is loaded onto bus 5A 0

MCC26A 0

MCC29A 0 21 Battery Charger BOP 1

1 o 21 Static Inverter on alternate power I

Note: Team will be unable to close breaker for MCC 29A due to blackout relay not reset.

Booth Operator: If NPO dispatched to reset MCC29A, inform the CCR that MCC29A breaker will not close.

I I Terminate scenario when transition from ECA-0.0 is announced.

Appendix D Scenario Outline Form ES-D-1 Event No.

1 2

Facility:

I P2 Scenario No.:

1 Op Test No.:

1 Examiners:

Candidates:

CRS RO PO Malf.

Event No.

Type*

Event Description R (RO)

Reduce power N (BOP)

N (CRS)

CNH c (RO)

MFRV fails closed slowly in AUTO PCS8D C(CRS)

Initial Conditions:

4 I ATS7B I C (ALL)

Turnover:

Critical Tasks:

Feedwater Pump trip requiring rapid load decrease to 700 MWe 100% power MOL 21 Charging Pump 00s 21 CCW Pump 00s Small SG Tube Leak Reduce load to 900 MWe to remove 23 Condensate Pump from service within 60 minutes Manual reactor trip prior to completion of E-0, step 1 Initiate Bleed and Feed Cooling so that the RCS depressurizes sufficiently to obtain SI flow 5 GPD 7

RX.TR I P MOC C (BOP) 21 MDAFW fails to start AFWI 1 Pressurizer level channel fails high 1 :!:20A 1 I(ALL) 3 5

I ATS7A I M (ALL)

I Feedwater pump trip. Reactor trip required.

Auto reactor trip failure. Manual trip required I BAT ESR.FAIL. I c(Ro)

I 8

1 MOT 1 C(B0P) 1 21 MDAFW trips AFWI 9

I ATS5C I

I TDAFW trips (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Scenario Event Description IP2 NRC Simulator Scenario I The team assumes the shift and initiates a power reduction IAW POP-3.1. The OTC will commence RCS boration and the BOP will slowly reduce generator load.

23 MFRV controller fails in automatic. The controller must be placed in manual IAW A01 28.0 and/or AOI 21.I.I, and 23 SG level restored to the normal control band. The CRS will refer to Tech Specs.

Pressurizer level channel 460 (controlling channel) will fail high. The team will respond IAW AOI-28.0 and AOI-28.7. The OTC will operate charging pumps and pressurizer heaters manually while the BOP defeats the failed channel inputs and the CRS refers to Technical Specifications.

Subsequently, 22 MBFP will trip, requiring a plant runback to e745 MWe IAW AOI-21.I

.I. 23 SG level must be controlled manually and normal boration will be performed for AFD control. If Rod Insertion Limits are exceeded, the OTC will commence Emergency Boration.

When the plant is stabilized, 21 MBFP will trip, requiring a reactor trip. The reactor must be tripped manually IAW AOI-21. I.I, because automatic reactor trip is not functional.

Subsequent AFW failures result in the requirement to transition to FR-H.l, and restore Heat Sink using Bleed and Feed.

EOP flow path: E ES-0.1 - FR-H.l

Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 1 21 Charging Pump 00s:

LOA EPSIO RACKED OUT Place pump control switch in TPO 21 CCW Pump 00s:

LOA EPSI 3 RACKED OUT Place pump control switch in TPO AUTO reactor trip failure:

21 ABFP fail to auto start:

Run Batch File ESR.FAIL.RX.TRIP MOC AFWI OPTION 4 AUTO CLOSE FAILURE 23 ABFP trips upon starting:

MOT AFW2A OPTION 2 AFW 23 SHAFT SEIZURE Materials needed for scenario:

POP-3.1 0

GraphBook 0

Tags for tagged equipment 0

Reactivity Summary Sheet Allow team to begin scenario brief approximately 30 minutes prior to entering simulator Note: None Scenario built from IC 3

Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Turnover Information Scenario 1 The plant is at 100% power, steady state conditions exist.

Middle of Life, Cbis 862 ppm.

EFPD = 340 Control Bank D = 214 steps Tavg = 559OF RCS Pressure = 2235 psig Pressurizer Level = 45%

A small Steam Generator Tube Leak exists on 23 SG, less than 5 gallons per day.

Risk Assessment = GREEN Daily Risk Factor = 0.94 The following equipment is out of service:

21 Charging Pump 00s for oil change. Return expected in approximately 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

21 Component Cooling Water Pump. Return to service in approximately 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

Team instructions:

23 Condensate Pump has high vibration.

In accordance with POP-3.1, reduce generator load to 900 MWe at a rate of 100 MWe per hour and remove 23 Condensate Pump from service.

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

1 Scenario #

1 Event#

1 Page 5 of 32 1 Event

Description:

Reduce Power -

I Time I[

Position

)[

Applicant's Actions or Behavior CRS CRS CRS CRS OTC OTC OTC Refers to POP 3.1 IF reducing Reactor Power for a maintenance support function, the SM SHALL DETERMINE the desired Reactor Power level OR Turbine load (MWe) to maintain while repairs are made/troubleshooting is performed Evaluator Note: 900 MWe indicated on turnover REQUEST Test Group to determine if Pressurizer Level instrumentation must be re-calibrated.

Evaluator cue: If asked, no re-calibration necessary VERIFY LCV-1129, Excess Condensate Return to CST, is closed, AND isolated locally per SOP 20.2, Condensate System Operation.

BORATE per SOP 3.2, Reactor Coolant System Boron Concentration Control, as necessary to maintain control banks above insertion limits required by GRAPH RPC-6, Cycle 14 Core Operating Limits Report.

IF necessary, PLACE rod control in MANUAL to maintain rods above the Insertion Limit.

MAINTAIN delta flux within the target band.

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

1 Scenario #

1 Event#

1 Page 6 of 32 Event

Description:

Reduce Power Time Applicants Actions or Behavior TEAM BOP OTC OTC OTC CRS IF PlCS is NOT operable, PERFORM the following after load changes greater than 10% per AOI 29.12, Loss of PlCS Computer:

o Quadrant Power Tilt Calculation using DSR-4B, Quadrant Power Tilt Calculation Sheet (Technical Specification 3. I O. IO).

o Log individual rod position indications using DSR-3, Rod Position Verification Log Sheet (Technical Specification 3.10.9).

MONITOR condenser sextants for sodium increase.

VERIFY TAVE AND Pressurizer Level are maintained on program per Graph RCS-2, Pressurizer Level V.S. TAvE.

MAINTAIN steam generator levels between 40 and 50 percent Narrow Range.

NULL manual setpoint on feedwater regulating valve control to ~

facilitate rapid transfer from AUTOMATIC to MANUAL control.

NOTIFY nuclear and conventional NPOs that load reduction is in progress.

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

1 Scenario #

1 Event#

1 Page 7 of 32 Event

Description:

Reduce Power Time 11 Position 11 Applicants Actions or Behavior CRS DIRECT NPOs to perform the following during load reduction:

MONITOR Main Turbine Oil Temperatures MONITOR Hydrogen Seal Oil Temperatures MONITOR MBFP Oil Temperatures BALANCE Heater Drain Tank Pump flows between the pump in Auto and Manual per SOP 19.1, Extraction Steam And Heater Drain Systems Operation.

IF SJAEs are in service, MAINTAIN Steam pressure per SOP 20.1, Condenser Air Removal System Operation, AND periodically CHECK SJAEs for backfiring.

IF FCV-1120, Flowpath A Controller Stop, is in MANUAL, ADJUST to maintain FCV-1113, Gland Steam Condenser Minimum Flow Control Valve, closed.

NOTE WHEN erratic governor operation is observed, governor oil pressure may be raised above the controlling load limit to avoid adverse Main Turbine operation.

I I

INITIATE load decrease using either of the following as directed by CRS:

o Governor control o Load Limit control Refers to SOP-3.2 for boration DETERMINE RCS Boron concentration from reactor coolant sample analysis.

o E analysis following concentration adjustment is NOT yet available, ESTIMATE Boron concentration based on latest readings.

Appendix D 0 pe rat0 r Act ion Form ES-D-2 OTC Op Test No.:

1 Scenario #

1 Event#

1 Page 8 of 32 IF the change in RCS Boron concentration is anticipated to be greater than or equal to 25 ppm, OPERATE Pressurizer heaters to open spray valve.

Event

Description:

Reduce Power Applicant's Actions or Behavior OTC NOTE Determinations should be based upon rod position, RCS Boron concentration, Xenon level variations, incremental Boron and rod worth, and operating experience.

DETERMINE magnitude of increase in Boron concentration necessary to accomplish desired reactivity change using one or more of the following references:

ESTIMATE total volume of boron required for boration from boration graphs or references listed in step 4.5.2.

GRAPH CVCS-3A, Boration Nomograph for Hot RCS GRAPH CVCS-3B, Boration Nomograph for Cold RCS GRAPH CVCSS, Boration - Dilution Tables GRAPH RV-2, Total Power Defect (PCM) as a Function of Power and Boron Concentration at MOL GRAPH RV-3, Differential Boron Worth (Hot Zero Power) at MOL GRAPH RV-4, Total Temperature Defect (PCM) as a Function of Temperature and Boron Concentration at MOL GRAPH RV-9, IP2 Cycle 15 Reactivity Equivalents POP 1.2, Reactor Startup WCR 1, Reactivity Summary PLACE the RCS Makeup Control switch to STOP.

OTC SET Boric Acid Integrator to amount determined in step 4.5.3.

OTC

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

1 Scenario #

1 Event#

1 Page 9 of 32 Event

Description:

Reduce Power Time

]I Position 11 Applicant's Actions or Behavior OTC OTC OTC OTC PLACE the RCS Makeup Mode Selector switch to BORATE.

FCV-11 OA, Boric Acid Flow Control, may be left in AUTO or placed in MANUAL as directed by CRS.

VERIFY boric acid transfer pumps are in AUTO.

PLACE the RCS Makeup Control switch to START.

NOTE BATPs shifting to fast speed is verified by both counter operation and by the respective fast speed lights illuminating.

OTC OTC OTC VERIFY BATPs shift to fast speed.

IF in manual, ADJUST FCV-I I OA, Boric Acid Flow Control, to obtain desired boric acid flow rate (may be greater than meter range).

IF desired to maximize Boron flow, CLOSE the appropriate BATP recirculation valve.

o HCV-104 Inlet Inlet o HCV-105 CVCS/Boric Acid Tank 22 BA CVCS/Boric Acid Tank 21 BA Note: Likelv will NOT be desired

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

1 Scenario #

1 Event#

1 Page 10 of 32 Event

Description:

Reduce Power -

Time 11 Position 11 Applicant's Actions or Behavior

~

OTC OTC OTC OTC OTC OTC OTC MONITOR Nuclear Instrumentation, Rod position, and RCS temperature closely during any reactivity changes.

WHEN boration operation has been completed, PERFORM the following:

o PLACE the RCS Makeup Control switch to STOP.

o PLACE the Makeup Mode Selector switch to MANUAL.

o ADJUST FCV-I 1 OA, Boric Acid Flow Control, dial setting to the new RCS Boron concentration per applicable CVCS Graph:

o GRAPH CVCS-IA, Blended Makeup - (0-500) with 120 Gpm PW o GRAPH CVCS-1 B, Blended Makeup - (0-2000) with 120 Gpm PW o GRAPH CVCS-IC, Blended Makeup with Various PW Flows VERIFY FCV-1 I OA control switch in AUTO.

PLACE the RCS Makeup Control switch to START.

VERIFY approximately 30 gallons of blended makeup flows through blender.

PLACE RCS Makeup Control switch to STOP.

SELECT AUTO on RCS Makeup Mode Selector switch.

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

1 Scenario #

1 Event#

1 Page 11 of -

32 Event

Description:

Reduce Power Time 11 Position 11 Applicants Actions or Behavior IF Reactor is shutdown, REQUEST a sample for RCS Boron concentration within 30 minutes of completing the boration.

PLACE the RCS Makeup Control switch to START.

OTC OTC LOG amount of boric acid added to system for boration in CCR Log.

At Lead Evaluators discretion, proceed to Event 2

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

1 Scenario #

1 Event#

2 Page 12 of 32 Event

Description:

MFRV Fails Closed Slowly Booth Instructor: When directed, insert the following command:

CNH PCS8D RAMP START 65 RAMP TIME 300 SEVERITY 25 Expected alarm:

FBF 1-1, STM GENERATOR LEVEL CONTROL DEVIATION CRS OTC

~

~

OTC OTC Refer to AOI 28.0, Instrument Failures, or 21.1.1, Loss of Feedwater Note: The following 2 steps are the actions of AOI-28.0 VERIFY The Following Controls:

o Turbine load - STABLE o Rod Control - STABLE o PRZR pressure control - NORMAL o PRZR level control - NORMAL o MBFP Speed - NORMAL o S/G levels - NORMAL (NO) o S/G pressure control - NORMAL Place 23 MFRV in MANUAL and restore SG level CHECK PRZR instrumentation - NORMAL:

o PRZR pressures o PRZR levels

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

1 Scenario #

1 Event#

2 Page 13 of 32 Event

Description:

MFRV Fails Closed Slowly Time I(

Position 11 Applicant's Actions or Behavior OTC OTC CRS CRS CRS CRS CHECK S/G instrumentation - NORMAL o S/G levels (All 23 SG level indication will be low, but not instrument failure. Due to controller failure) o S/G pressures o S/G feedwater flow o S/G steam flows CHECK RCS instrumentation:

o CHECK RCS loop temperatures:

o Loop Tavg - NORMAL o Actual loop AT - NORMAL o CHECK Power Range Channels - NORMAL o CHECK RCS coolant loop flow channels - NORMAL CHECK Turbine first stage pressure - NORMAL CHECK Containment pressures - NORMAL Return to procedure and step in effect.

Note: CRS may have called I&C to determine failure.

Otherwise, would refer to AOI-21.I.I, steps below Note: The following steps are the actions of AOI-21.1.1. The team may use either procedure to stabilize level prior to diagnosing the failure E Main Feed Regulator Valve(MFRV) has failed, GO TO Section 5.7

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

1 Scenario #

1 Event#

2 Page 14 of 32 Event

Description:

MFRV Fails Closed Slowly Time (1

Position 11 Applicants Actions or Behavior OTC OTC CRS OTC OTC CRS TRANSFER failed MFRV to MANUAL and RESTORE normal level POSITION MBFP recirculation valve switch at the direction of the CRS o FCV-1115 21 MBFP Recirc Vlv o FCV-I 116 22 MBFP Recirc Vlv IF SG Levels can be stabilized, GO TO step 5.13 to stabilize plant ADJUST TURBINE LOAD AS DIRECTED BY T F S M :

o VERIFY that both PORV block valves (MOV-535 and MOV-536) are closed.

VERIFY that the MBFP recirculation valve switches are in AUTO o

FCV-1115 21 MBFP Recirc Vlv o

FCV-1116 22 MBFP Recirc Vlv ESTABLISH plant conditions as directed by the SM Evaluator note: If requested by CRS, Shift Manager directs continuing plant shutdown once plant conditions are stable.

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

1 Scenario # -

1 Event#

2 Page 15 of 32 Event

Description:

MFRV Fails Closed Slowly Time

)I Position 11 Applicant's Actions or Behavior When plant conditions are stable with 23 Feedwater Regulating valve in Manual and SG level within 5% of normal band, proceed to Event 3

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

1 Scenario #

1 Event#

3 Page 16 of 32 Event

Description:

Pressurizer Level Channel Fails High Booth Instructor: When directed, insert the following command; XMT RCSZOA SEVERITY 100 RAMP TIME 180 Expected alarms:

FBF 4-5, LOW CHARGING FLOW SAF 1-3, PRZR HIGH LEVEL SAF 2-3, PRZR HIGH LEVEL CHANNEL TRIP (After approximately 2 minutes)

CRS OTC OTC CRS Refer to AOI-28.0, Instrument Failures VERIFY The Following Controls:

o Turbine load - STABLE o Rod Control - STABLE o PRZR pressure control - NORMAL o PRZR level control - NORMAL (NO) o MBFP Speed - NORMAL o S/G levels - NORMAL o S/G pressure control - NORMAL Place Charging Pump Speed control in manual CHECK PRZR instrumentation - NORMAL o PRZR levels o GO to A01 28.7 (Fails High), PRZR LEVEL CHANNEL FAILURE (LI-460)

Note: If requested to peer check procedure transition, concur with whatever transition the CRS recommends.

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

1 Scenario #

1 Event#

3 Page 17 of -

32 Event

Description:

Pressurizer Level Channel Fails High Time 11 Position 11 Applicants Actions or Behavior OTC BOP OTC OTC BOP CRS IF failed Channel is controlling Pressurizer level o TURN OFF any unnecessary Pressurizer back-up heaters (Note: Heaters may have been placed in ON previously for the RCS boration) o PLACE charging pump speed control in MANUAL o CONTROL Pressurizer level in normal band. (Refer to Graph, RCS-2, PRESSURIZER LEVEL vs. TAVE, in Graph Book).

In Foxboro rack B6, PLACE Pressurizer Level Defeat switch (L 460A) to DEFEAT #, for affected channel Alarms clear:

SAF 1-3, PRZR HIGH LEVEL FBF 4-5, FBF 4-5, LOW CHARGING FLOW RETURN charging pump speed control to AUTOMATIC RETURN Pressurizer bulk heater control to AUTOMATIC MANUAL as directed by SOP 1.4, Pressurizer Pressure Control Note: May leave heaters on due to previous RCS boration PLACE Hi Level Trip Bistable Trip switch for affected channel in TRIP o 460, Rack A-12, WHITE VERIFY requirements of Technical Specification in Table 3.5-2 are met.

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

1 Scenario #

1 Event#

3 Page 18 of Event

Description:

Pressurizer Level Channel Fails High Time

\\I Position 11 Applicant's Actions or Behavior When Channel is removed from service, Proceed to Event 4

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

1 Scenario#

1 Event#

4 Page 19 of 32 Event

Description:

Feedwater Pump Trip Requiring Rapid Load Decrease to 700 MWe Booth Instructor: When directed, insert the following command:

MAL ATS7B 22 MBFP trip Indications available:

o Multiple alarms received, including:

o o

FBF 3-8, 22 MBFPT TURBINE TRIP SEF 3-8, TURBINE RUNBACK ACTUATED o Control Rod insertion in AUTOMATIC o AUTOMATIC Turbine Runback Refer to AOI-21.1.1, Loss of Feedwater CRS Note: The following 3 steps are Continuous Actions IF Reactor Power is above 4 percent AND AFW pumps are the only source of feed to the steam generators, TRIP the reactor and GO TO E-0, Reactor Trip or Safety Injection.

CRS IF Reactor Power is at pumps are the only source of feed to the steam generators, REDUCE Reactor Power to 3 percent, so all steam generator levels can be maintained above 9 percent level.

below 4 percent AND AFW CRS IF level in any single Steam Generator goes below 9 percent on 2 of 3 indicators, TRIP the reactor and GO TO E-0, Reactor Trip or Safety Injection.

CRS

Appendix D Operator Action Form ES-D-2 OTC 20 of 32 (1

I Op Test No.:

1 Scenario #

1 Event#

4 Page -

IF necessary, PLACE MBFP Master Speed controller in manual and INCREASE speed to match Feed Flow to Steam Flow Event

Description:

Feedwater Pump Trip Requiring Rapid Load Decrease to 700 MWe TEAM IF one MBFP has tripped, GO TO Section 5.3 IF Turbine Load greater than 745 MWe, VERIFY automatic turbine runback has reduce Turbine Load to approximately 745 MWe 0 --

IF NOT, REDUCE Turbine Load to approximately 745 MWe using Load Limits (preferred) or Governor NOTE The recirculation valve should remain closed UNTIL load has been stabilized VERIFY the Recirculation Valve for tripped MBFP is closed OTC IF necessary, ADJUST turbine load to MATCH Steam flows to Feedwater flows and MAINTAIN Steam Generator levels on program OTC Note: May also place FRV controllers in MANUAL per step 4.12 to control SG levels CAU TI 0 N DO NOT exceed 5500 rpm or 98 percent Startup signal, whichever is reached first VERIFY control rods are in AUTO OTC

Appendix D Operator Action Form ES-D-2

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Op Test No.:

1 Scenario #

1 Event#

4 Page 21 of 32 Event

Description:

Feedwater Pump Trip Requiring Rapid Load Decrease to 700 MWe Time 11 Position 11 Applicants Actions or Behavior Note:

OTC BOP BOP BOP OTC OTC CRS IF rods are NOT responding, manually DRIVE rods in to control temperature VERIFY that the standby condensate pump is running VERIFY that 21 and 23 ARN Pumps are running o 21 ABFP NOT running o 23 ABFP is tripped (Yellow light)

VERIFY that the SGBD Isolation Valves are closed VERIFY that the turbine runback has terminated, as follows o

Load Limit oil pressure stable o TURBINE RUNBACK ACTUATED alarm on Panel SEFWindow 3-8) extinguished IF the runback has NOT terminated, PLACE the Loss of MBFP Turbine Runback Control Switch in DEFEAT (Panel FAF).

Determine Delta-I is out of the envelope and refer to Technical Specification 3.1 0.2.6 When SAF 3-9, APPROACHING ROD INSERTION LIMIT 12.5 alarm is received, team should refer to the Annunciator Response and place Rod Control in MANUAL When plant is stable, or at Lead Evaluators discretion, proceed to Event 5

Appendix D Operator Action Form ES-D-2 Page 22 of 32 1 Op Test No.:

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Event

Description:

I Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

500th Instrucfor: When direcfed, insert the following command:

VIAL ATS7A 21 MBFP Trip MOT AFWIA OPTION 2 SHAFT SEIZURE 21 ABFP May refer to AOI-21.1.1 CRS Direct entry to E-0, Reactor Trip or Safety Injection CRS Critical Task:

Initiate Manual Reactor Trip prior to completion of E-0, Step I CRITICAL TASK OTC OTC BOP Verify reactor trip:

o Trip breakers open o Flux decreasing o Rod bottom lights lit o Rod position indicators all less than 7.5 inches Manual Reactor Trip required. Automatic reactor trip failed Verify Turbine Trip o All stop valves closed Verify power to 480 Volt busses:

o At least one energized:

o 2Aand3A o 5A o 6A o All Energized

Appendix D Operator Action Form ES-D-2 Page 23 of 32 -1 Op Test No.:

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Event

Description:

Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

Check if SI is actuated:

o SI annunciator lit(N0) o Any SI pumps running(N0)

OR Check if SI is required (NO)

GO to ES-0.1 Reactor Trip Response Cue: Concur with CRS request for transition peer check Check RCS temperature stable at or trending to 547OF Check Generator Output breaker open Verify 480 volt busses energized by offsite power Check pressurizer level control:

o Level greater than 18%

o Charging and Letdown in service o Any CCW pump running o Level trending to 37%

Appendix D Operator Action Form ES-D-2

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CRS Page 24 of 32 1 Op Test No.:

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Determine Red Path exists on Heat Sink CSF status tree.

Direct transition to FR-H.1, Loss of Heat Sink Event

Description:

Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

Time (1

Position 11 Applicant's Actions or Behavior Check pressurizer pressure control:

o o Trending to 2235 psig Pressure greater than 1840 psig I

OTC I I

I Booth Instructor: When directed, inserf the following command:

MAL ATSSC 22 ABFP trip Note:

STA Surrogate will provide cue that Heat Sink CSF is RED.

Check if secondary heat sink is required:

o RCS pressure greater than any non-faulted SG pressure o RCS temperature greater than 35OOF OTC I

I CAUTION o

If average of the 3 lowest wide range SG levels is less than 41% (54% Adverse containment) due to loss of secondary heat sink, RCPs should be tripped and steps 9 - 15 should be immediately initiated for bleed and feed o City Water for AFW pumps will be necessary if CST level decreases to less than 2ft o

Radiation levels and harsh environment conditions should be evaluated prior to performing local actions Determine Bleed and Feed criteria is met TEAM Trip RCPs OTC

Appendix D 0 pe rat0 r Act ion Form ES-D-2 I

C Op Test No.:

W 1

Scenario #

1 Event#

5, 6, 7, 8,9 Page 25 of 32 1 Event

Description:

Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

Time Applicant's Actions or Behavior Critical Task:

Initiate Bleed and Feed Cooling of the RCS so that the RCS depressurizes sufficiently to obtain SI flow CRITICAL TASK OTC/BOP

~~

OTC/BOP Actuate SI o Train A o Train B Verify RCS Feed path o Check All SI pumps running o 22 SI pump discharge isolation MOV-85lA and MOV-851 B open o Check proper emergency SI valve alignment for operating pumps:

o SI pump cold leg injection valves open (856A, B, o

RHR HX CCW outlet valves open (822NB) o RHR HX Motor operated valves open (746/747) c, D) o Check feed path established CAUTION o

If offsite power is lost after SI resetxhen manual action may be required to restart safeguards equipment o Placing key switches to DEFEAT will prevent auto SI actuation

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

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Event

Description:

Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

Time 11 Position I[

Applicant's Actions or Behavior OTC/BOP BOP Reset SI o Check all CCW pumps running (21 CCW pump in TPO as part of setup) o Place controls for main and bypass feedwater regulating valves to close o Verify automatic safeguards actuation key switches on panel SB-2 in DEFEAT position o Train A SIA-1 o Train B SIA-2 o One at a time, depress safety injection reset buttons o TrainA o Train B o Verify Train A and B reset Reset Containment isolation phase A and Phase B Place IVSW switches to open on SN panel (1410, 1413, 3518, 3519)

Place CNTMT RAD MON WCPS valves control switch to open on SN panel Verify personnel and equipment hatch solenoid control switches to incident on SM panel Place control switches for all remaining Phase A isolation valves to close on SN panel One at a time, depress Phase A reset pushbuttons o CI Phase A Train A o CI Phase A Train B Verify Train A and B reset

Appendix D Operator Action Form ES-D-2 Page 27 of 32 Op Test No.:

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Event

Description:

Feedwater Pump Trip. Reactor Trip Required. Auto Reactor Trip Failure.

Manual Trip Required. TDAFW Trips; MDAFW Fails to Start; MDAFW Trips.

Time 11 Position 11 Applicant's Actions or Behavior CRITICAL TASK BOP BOP OTC OTC OTC/BOP Check Phase B actuated (NO)

Establish Instrument Air to Containment o Open PCV-1228 Establish RCS Bleed Path o Verify power to PRZR PORV Block Valves available o Verify PRZR PORV Block Valves both open o Open both PORVs o Monitor PORV Nitrogen alarms Verify adequate bleed path o Both PORVs open o Both PORV block valves open

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Perform steps 1-9 of E-0, Reactor Trip or Safety Injection Note:

Step 5 of E-0 directs use of Attachment I, Automatic Action verification. The steps of this attachment are included beginning on page 28 of this scenario guide Terminafe scenario when RCS Bleed and Feed is esfablished and verified

Appendix D Operator Action Form ES-D-2 I

I II Scenario#

All Event#

Page 28 of 32 1 Op Test No.:

1 Y

Event

Description:

E-0, Attachment 1, Automatic Action Verification Note -

This attachment must be terminated upon CRS transition to ECA-0.0, Loss of All AC Power.

BOP

a. Start at least one charging pump in manual at maximum speed

b. Align charging pump suction to the RWST Open charging pump suction valve from RWST Close charging pump suction valve from VCT

1. LCV-112c Place RCS Makeup Control switch to STOP

1. LCV-112B Note o Notify CRS of any automatic actions that failed to occur during performance of this attachment o Equipment found misaligned due to operator action should NOT be repositioned.

Check generator output breakers - OPEN Check status of 480 volt busses:

a. All 480V busses - ENERGIZED BY OFF-SITE POWER

b. Dispatch NPO to reset:

o All lighting o MCC24A o MCC27A o MCC29A

c. Stop all Condensate Pumps

Appendix D Operator Action Form ES-D-2 I

II Op Test No.:

1 Scenario#

All Event#

Page 29 of 32 Event

Description:

E-0, Attachment 1, Automatic Action Verification

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BOP BOP BOP BOP Verify FW Isolation:

o Main Boiler Feed Pumps - TRIPPED o

Main Boiler Feed Pump Discharge Valves o FW Regulating valves - CLOSED o FW Stop Valves - CLOSED o SG Blowdown Isolation Valves - CLOSED

-CLOSED Check if Main Steam Lines should be isolated:

a. Check for either:

0 High Steam Line flow with EITHER Tave less than 541 deg F OR Steam line pressure less than 525 psig.

OR Containment pressure - EVER GREATER THAN 24 psig

b. Verify MSlVs - CLOSED Verify proper Service Water System operation:

a. Three Service Water Pumps - Running on Essential Header

b. Service Water valves from Diesel Generator -

OPEN Veify SI system pumps running:

a. Three SI pumps - RUNNING

b. 22 SI pump discharge isolation MOV-85lA

c. Two RHR pumps - RUNNING AND MOV-851 B - OPEN

Scenario#

All Event#

Page 30 of 32 E-0, Attachment I, Automatic Action Verification Op Test No.:

1 Event

Description:

Time (1

Position 11 Applicant's Actions or Behavior BOP BOP BOP BOP Verify proper emergency SI System valve alignment:

a. SI pump cold leg injection valves - OPEN o 856A o 856E o 856C o 856D

b. RHR HX CCW outlet valves - OPEN o 822A o 822B RHR HX MOVS - OPEN o 746 0 747 C.

Verify Containment Fan Coolers - IN SERVICE:

a. Five fan coolers - RUNNING

b. Charcoal Filter valves - OPEN

c. Fan normal discharge valves - CLOSED

d. TCV-I 104 and TCV-1105 - BOTH OPEN Verify A W flow to all SGs Verify Containment Ventilation Isolation:

a. Containment Purge Valves - CLOSED o

FCV-1170 o FCV-1171 o FCV-1172 o FCV-1173

b. Containment Pressure Relief Valves -

CLOSED PCV-1190 PCV-1191 PCV-1192

Appendix D Operator Action Form ES-D-2 Scenario#

All Event#

Attachment I Page 31 of 32 E-0, Attachment 1, Automatic Action Verification 1 -

Op Test No.:

Event

Description:

Time 11 Position Applicant's Actions or Behavior Note provides a list of Phase A valves BOP Verify Containment Isolation Phase A

a.

b.

C.

d.

e.

f.

Phase A - ACTUATED o Train A master relay CAI (above rack E) o Train B master relay CA2 (above rack F)

Phase A valves - CLOSED IVSW valves - OPEN o

1410 o

1413 o SOV-3518 o SOV-3519 WCP valves - OPEN:

o PCV1238 o PCV 1239 o PCV 1240 o PCV 1241 Place personnel and equipment hatch solenoid control switches to INCIDENT on SM panel Dispatch NPO to periodically check o IVSWTank 0

0 Pressure - GREATER THAN Level - GREATER THAN 92%

57 PSIG o WCP header pressures - GREATER THAN 52 PSlG Evaluator note: The following step is intended for High Containment pressure condition. It will not be performed if conditions aren't met

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

1 Scenario#

All Event#

Page 32 of 32 Event

Description:

E-0, Attachment 1, Automatic Action Verification Time 11 Position 11 Applicants Actions or Behavior BOP BOP Check if Containment Spray should be actuated:

a.

b.

C.

d.

e.

f.

Containment Pressure - EVER GREATER THAN 24 PSlG Verify spray pumps - RUNNING Verify spray pump discharge valves - OPEN o MOV-866A o MOV-866B o MOV-866C o MOV-866D Verify Containment Isolation Phase B valves STOP all RCPs Verify IVSW Isolation Valves - OPEN o 7864 o 7865 o 7866 o 7867

- CLOSED Verify CCR Air Conditioner Train A and B - RUNNING IN INCIDENT MODE 2 Notify CRS that Attachment 1 is complete BOP