ML031190727

Draft - Section C Operating

ML031190727
Person / Time
Site:	Indian Point
Issue date:	04/01/2003
From:	Wilson F Entergy Nuclear Northeast
To:	Conte R NRC/RGN-I/DRS/OSB
Conte R
References
50-247/03-301 50-247/03-301
Download: ML031190727 (84)

Text

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

IP2 Scenario No.:

1 Op Test No.:

1 Examiners:

Candidates:

CRS RO PO Initial Conditions:

100% power MOL 21 Charging Pump OOS 21 CCW Pump OOS Small SG Tube Leak < 5 GPD Turnover:

Reduce load to 900 MWe to remove 23 Condensate Pump from service within 60 minutes Critical Tasks:

Manual reactor trip Initiate Bleed and Feed Cooling Event Malf.

Event No.

No.

Type*

Event Description 1

R (RO)

Reduce power N (BO0P)

N (CRS) 2 CNH C (RO)

MFRV fails closed slowly in AUTO PCS8D C (CRS) 3 XMT I (ALL)

Pressurizer level channel fails high RCS20A 4

ATS7B C (ALL)

Feedwater Pump trip requiring rapid load decrease to 700 MWe 5

ATS7A M (ALL)

Feedwater pump trip. Reactor trip required.

6 BAT C (RO)

Auto reactor trip failure. Manual trip required ESR.FAIL.

RX.TRIP 7

MOC C (BOP) 21 MDAFW fails to start 8

MOT C (BOP) 21 MDAFW trips AFW I 9

ATS5C TDAFW trips (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description IP2 NRC Simulator Scenario 1 The crew assumes the shift and initiates a power reduction IAW POP-3.1. The RO will commence RCS boration and the BOP will slowly reduce generator load.

23MFRV controller fails in automatic. The controller must be placed in manual IAW AOl 28.0 and/or AOl 21.1.1, 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 crew will respond IAW AOI-28.0 and AOI-28.7. The RO 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 <745 MWe IAW AO1-21.1.1. 23 SG level must be controlled manually and normal boration will be performed for AFD control. If Rod Insertion Limits are exceeded, the RO 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-21.1.1, because automatic reactor trip is not functional.

Subsequent AFW failures result in the requirement to transition to FR-H.1, and restore Heat Sink using Bleed and Feed.

EOP flow path: E ES-0.1 - FR-H.1 Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 1 21 Charginq Pump OOS:

LOA EPS10 RACKED OUT Place pump control switch in TPO 21 CCW Pump OOS:

AUTO reactor trip failure:

21 ABFP fail to auto start:

23 ABFP trips upon startin:

LOA EPS13 RACKED OUT Place pump control switch in TPO Run Batch File ESR.FAIL.RX.TRIP MOC AFW1 OPTION 4 AUTO CLOSE FAILURE MOT AFW2A OPTION 2 AFW 23 SHAFT SEIZURE Materials needed for scenario:

POP-3.1 Graph Book Tags for tagged equipment Reactivity Summary Sheet Allow crew to begin scenario brief approximately 30 minutes prior to entering simulator Note: None Scenario built from IC 3 Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario#

1 Event#

1 Page 5

of 29 Event

Description:

Reduce Power l

Time Position Applicant's Actions or Behavior CRS Refers to POP 3.1 IF reducing Reactor Power for a maintenance support function, the SM SHALL DETERMINE the desired Reactor Power level CRS 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 CR instrumentation must be re-calibrated.

CRS Evaluator cue: If asked, no re-calibration necessary VERIFY LCV-1 129, Excess Condensate Return to CST, is CRS 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 OTC above insertion limits required by GRAPH RPC-6, Cycle 14 Core Operating Limits Report.

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

RO 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 29 Event

Description:

Reduce Power Time Position Applicant's Actions or Behavior IF PICS is NOT operable, PERFORM the following after load changes greater than 10% per AOI 29.12, Loss of PICS Computer:

o Quadrant Power Tilt Calculation using DSR-4B, Quadrant Power Tilt Calculation Sheet (Technical CREW Specification 3.10.10).

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

BOP MONITOR condenser sextants for sodium increase.

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

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

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

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

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

1 Scenario #

1 Event #

1 Page 7

of 29 Event

Description:

Reduce Power Time Position Applicant's Actions or Behavior DIRECT NPOs to perform the following during load reduction:

o MONITOR Main Turbine Oil Temperatures o

MONITOR Hydrogen Seal Oil Temperatures o

MONITOR MBFP Oil Temperatures o

BALANCE Heater Drain Tank Pump flows between the pump in Auto and Manual per SOP 19.1, Extraction CRS Steam And Heater Drain Systems Operation.

o IF SJAEs are in service, MAINTAIN Steam pressure per SOP 20. 1, Condenser Air Removal System Operation, AND periodically CHECK SJAEs for backfiring.

o IF FCV-1 120, 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.

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

BOP o

Governor control o

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

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

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

1 Scenario #

1 Event #

1 Page 8

of 29 Event

Description:

Reduce Power Time Position Applicant's Actions or Behavior 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:

o GRAPH CVCS-3A, Boration Nomograph for Hot RCS o

GRAPH CVCS-3B, 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 OTC 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 OTC greater than or equal to 25 ppm, OPERATE Pressurizer heaters to open spray valve.

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

OTC PLACE the RCS Makeup Control switch to STOP.

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

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

1 Scenario #

1 Event #

1 Page 9

of 29 Event

Description:

Reduce Power Time Position Applicant's Actions or Behavior OTC PLACE the RCS Makeup Mode Selector switch to BORATE.

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

OTC VERIFY boric acid transfer pumps are in AUTO.

OTC 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.

II OTC VERIFY BATPs shift to fast speed.

IF in manual, ADJUST FCV-1 10A, Boric Acid Flow Control, to OTC obtain desired boric acid flow rate (may be greater than meter range).

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

OTCo HCV-104 CVCS/Boric Acid Tank 22 BA OTC Inlet o

HCV-105 CVCS/Boric Acid Tank 21 BA Inlet

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

1 Scenario#

1 Event#

1 Page 10 of 29 Event

Description:

Reduce Power Time D Position Applicant's Actions or Behavior MONITOR Nuclear Instrumentation, Rod position, and RCS OTC 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-1 1 OA, Boric Acid Flow Control, dial setting to the new RCS Boron concentration per OTC applicable CVCS Graph:

o GRAPH CVCS-1A, Blended Makeup - (0-500) with 120 Gpm PW o

GRAPH CVCS-1 B, Blended Makeup - (0-2000) with 120 Gpm PW o

GRAPH CVCS-1C, Blended Makeup with Various PW Flows OTC VERIFY FCV-1 1 OA control switch in AUTO.

OTC PLACE the RCS Makeup Control switch to START.

VERIFY approximately 30 gallons of blended makeup flows OTC through blender.

OTC PLACE RCS Makeup Control switch to STOP.

OTC SELECT AUTO on RCS Makeup Mode Selector switch.

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

1 Scenario #

1 Event #

1 Page 11 of 29 Event

Description:

Reduce Power Time Position Applicant's Actions or Behavior OTC PLACE the RCS Makeup Control switch to START.

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

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

At Lead Evaluator's discretion, proceed to Event 2

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

1 Scenario#

1 Event#

2 Page 12 of 29 Event

Description:

MFRV Fails Closed Slowly Time Position I

Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

CNH PCS8D RAMP START 65 RAMP TIME 300 SEVERITY 25 Refer to AOI 28.0, Instrument Failures, or 21.1. 1, Loss of CRS Feedwater Note: The following 2 steps are the actions of AOI-28.0 VERIFY The Following Controls:

Turbine load - STABLE Rod Control - STABLE OTC PRZR pressure control - NORMAL PRZR level control - NORMAL MBFP Speed - NORMAL S/G levels - NORMAL OTC Place 23 MFRV in MANUAL and restore SG level Note: The following steps are the actions of AO1-21.1.1. The crew may use either procedure to stabilize level prior to diagnosing the failure IF Main Feed Regulator Valve(MFRV) has failed, CRS GO TO Section 5.7 TRANSFER failed MFRV to MANUAL and RESTORE OTC normal level

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

1 Scenario#

1 Event#

2 Page 13 of 29 Event

Description:

MFRV Fails Closed Slowly Time Position Applicant's Actions or Behavior POSITION MBFP recirculation valve switch at the direction of the CRS OTC o FCV-1115 21 MBFP RecircV`v o FCV-1116 22 MBFPRecircVlv IF SG Levels can be stabilized, GO TO step 5.13 to CRS stabilize plant ADJUST TURBINE LOAD AS DIRECTED BY THE SM:

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

VERIFY that the MBFP recirculation valve switches are in AUTO CREW o

FCV-1115 21 MBFP RecircVlv o

FCV-1 116 22 MBFP Recirc Viv ESTABLISH plant conditions as directed by the SM:

o SHUT DOWN the Reactor per POP 3.1, Plant Shutdown from Full Power Operation to Zero Power Condition

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

1 Scenario #

1 Event #

3 Page 14 of 29 Event

Description:

Pressurizer Level Channel Fails High Time Position I

Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

XMT RCS20A SEVERITY 100 RAMP TIME 180 CRS Refer to AOI-29.0, Instrument Failures VERIFY The Following Controls:

Turbine load - STABLE Rod Control - STABLE OTC PRZR pressure control - NORMAL PRZR level control - NORMAL MBFP Speed - NORMAL S/G levels - NORMAL OTC Place Charging Pump Speed control in manual CHECK PRZR instrumentation - NORMAL CRS o

PRZR levels o

GO to AOI 28.7 (Fails High), PRZR LEVEL CHANNEL FAILURE IF failed Channel is controlling Pressurizer level o TURN OFF any unnecessary Pressurizer back-up heaters OTC 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).

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

1 Scenario #

1 Event #

3 Page 15 of 29 Event

Description:

Pressurizer Level Channel Fails High Time Position Applicant's Actions or Behavior In Foxboro rack B6, PLACE Pressurizer Level Defeat switch (L BOP 460A) to DEFEAT #, for affected channel OTC RETURN charging pump speed control to AUTOMATIC RETURN Pressurizer bulk heater control to AUTOMATIC OR OTC MANUAL as directed by SOP 1.4, Pressurizer Pressure Control PLACE Hi Level Trip Bistable Trip switch for affected channel in TRIP BOP o 460, Rack A-12, WHITE VERIFY requirements of Technical Specification in Table 3.5-2 CRS are met.

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 16 of 29 Event

Description:

Feedwater Pump Trip Requiring Rapid Load Decrease to 700 MWe Time Position Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL ATS7B CRS Refer to A01-21. 1. 1, Loss of Feedwater CRS 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 CREW o

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 OTC VERIFY the Recirculation Valve for tripped MBFP is closed IF necessary, ADJUST turbine load to MATCH Steam flows to OTC Feedwater flows and MAINTAIN Steam Generator levels on program CAUTION DO NOT exceed 5500 rpm or 98 percent Startup signal, whichever is reached first IF necessary, PLACE MBFP Master Speed controller in manual OTC and INCREASE speed to match Feed Flow to Steam Flow

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

1 Scenario#

1 Event#

4 Page 17 of 29 Event

Description:

Feedwater Pump Trip Requiring Rapid Load Decrease to 700 MWe Time Position Applicant's Actions or Behavior OTC VERIFY control rods are in AUTO IF rods are NOT responding, manually DRIVE rods in to control OTC temperature BOP VERIFY that the standby condensate pump is running BOP VERIFY that 21 and 23 AFW Pumps are running BOP VERIFY that the SGBD Isolation Valves are closed VERIFY that the turbine runback has terminated, as follows OTC o

Load Limit oil pressure stable o

TURBINE RUNBACK ACTUATED alarm on Panel SEF(Window 3-8) extinguished IF the runback has NOT terminated, PLACE the Loss of MBFP OTC Turbine Runback Control Switch in DEFEAT (Panel FAF).

When plant is stable, or at Lead Evaluator's discretion, proceed to Event 5

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

1 Scenario#

1 Event#

5,6,7,8,9 Page 18 of 29 Event

Description:

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

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

Time Position Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL ATS7A MOT AFW1 A OPTION 2 SHAFT SEIZURE CRS May refer to AO1-21.1.1 CRS Direct entry to E-0, Reactor Trip or Safety Injection Verify reactor trip:

o Trip breakers open OTC o

Flux decreasing o

Rod bottom lights lit o

Rod position indicators all less than 7.5 inches Verify Turbine Trip OTC o

All stop valves closed Verify power to 480 Volt busses:

o At least one energized:

o 2A and 3A BOP o 5A o 6A o All Energized

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

1 Scenario #

1 Event#

5, 6, 7, 8, 9 Page 19 of 29 Event

Description:

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

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

Time Position Applicant's Actions or Behavior Check if Si is actuated:

OTC/BOP o

SI annunciator lit OR o

Any SI pumps running CREW Check if SI is required (NO)

CRS GO to ES-0.1 Reactor Trip Response OTC Check RCS temperature stable at or trending to 5470F OTC Check Generator Output breaker open BOP Verify 480 volt busses energized by offsite power Check pressurizer level control:

0 Level greater than 18%

OTC o

Charging and Letdown in service Any CCW pump running a

Level trending to 37%

Check pressurizer pressure control:

OTC o

Pressure greater than 1840 psig o Trending to 2235 psig

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

1 Scenario #

1 Event #

5, 6, 7, 8, 9 Page 20 of 29 Event

Description:

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

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

Time Position Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL ATS5C Determine Red Path exists on Heat Sink CSF status tree.

CRS Direct transition to FR-H.1, Loss of Heat Sink Check if secondary heat sink is required:

OTC o

RCS pressure greater than any non-faulted SG pressure o

RCS temperature greater than 3500F 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 CREW Determine Bleed and Feed criteria is met OTC Trip RCPs Actuate SI OTC/BOP o

Train A o

Train B

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

1 Scenario #

1 Event #

5, 6, 7, 8, 9 Page 21 of 29 Event

Description:

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

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

Time Position Applicant's Actions or Behavior Verify RCS Feed path o Check All SI pumps running o

22 SI pump discharge isolation MOV-851A and MOV-851 B open OTC/BOP o

Check proper emergency SI valve alignment for operating pumps:

o SI pump cold leg injection valves open o

RHR HX CCW outlet valves open o

RHR HX Motor operated valves open o

Check feed path established CAUTION o

If offsite power is lost after SI reset, then manual action may be required to restart safeguards equipment o

Placing key switches to DEFEAT will prevent auto Sl actuation Reset SI o

Check all CCW pumps running o

Place controls for main and bypass feedwater regulating valves to close o

Verify automatic safeguards actuation key switches on OTC/BOP panel SB-2 in DEFEAT position o Train ASIA-1 o Train B SIA-2 o

One at a time, depress safety injection reset buttons o

Train A o

Train B o Verify Train A and B reset

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

1 Scenario #

1 Event #

5, 6, 7, 8, 9 Page 22 of 29 Event

Description:

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

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

Time Position Applicant's Actions or Behavior Reset Containment isolation phase A and Phase B o

Place IVSW switches to open on SN panel o

Place CNTMT RAD MON WCPS valves control switch to open on SN panel o Verify personnel and equipment hatch solenoid control BOP switches to incident on SN panel o

Place control switches for all remaining Phase A isolation valves to close on SN panel o

One at a time, depress Phase A reset pushbuttons o

Cl Phase A Train A o

Cl Phase A Train B o Verify Train A and B reset BOP Check Phase B actuated (NO)

Establish Instrument Air to Containment BOP o

Open PCV-128 Establish RCS Bleed Path o

Verify power to PRZR PORV Block Valves available OTC o

Verify PRZR POPRV Block Valves both open o

Open both PORVs o

Monitor PORV Nitrogen alarms Verify adequate bleed path OTC o

Both PORVs open o

Both PORV block valves open

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

1 Scenario #

1 Event #

5, 6, 7, 8, 9 Page 23 of 29 Eve~nt

Description:

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

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

Time Position Applicant's Actions or Behavior

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

1 Scenario #

All Event #

Page 24 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Note This attachment must be terminated upon CRS transition to ECA-0.0, Loss of All AC Power.

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 BOP RWST

1. LCV-112B Close charging pump suction valve from VCT

1. LCV-1 12C Place RCS Makeup Control switch to STOP 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.

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

1 Scenario #

All Event #

Page -25 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Check status of 480 volt busses:

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

b. Dispatch NPO to reset:

BOP o

All lighting o

MCC 24A o

MCC 27A o

MCC 29A

c. Stop all Condensate Pumps Verify FW Isolation:

o Main Boiler Feed Pumps - TRIPPED o

Main Boiler Feed Pump Discharge Valves BOP

-CLOSED o

FW Regulating valves - CLOSED o

FW Stop Valves - CLOSED o

SG Blowdown Isolation Valves - CLOSED Check if Main Steam Lines should be isolated:

a. Check for either:

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

OR Containment pressure - EVER GREATER THAN 24 psig

b. Verify MSIVs - CLOSED

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

1 Scenario #

All Event#

Page 26 of 29 Event

Description:

, Automatic Action Verification Time s

Position Applicant's Actions or Behavior Verify proper Service Water System operation:

a. Three Service Water Pumps - Running on BOP Essential Header

b.

Service Water valves from Diesel Generator -

OPEN Verify Si system pumps running:

a. Three SI pumps - RUNNING BOP

b. 22 Si pump discharge isolation MOV-851A AND MOV-851 B-OPEN

c. Two RHR pumps - RUNNING Verify proper emergency SI System valve alignment:

a.

SI pump cold leg injection valves - OPEN o

856A o

856E o

856C BOP a 856D

b.

RHR HX CCW outlet valves - OPEN o

822A o

822B

c.

RHR HX MOVs - OPEN o

746 o

747 Verify Containment Fan Coolers - IN SERVICE:

a.

Five fan coolers - RUNNING BOP

b. Charcoal Filter valves - OPEN

c. Fan normal discharge valves - CLOSED

d. TCV-1 104 and TCV-1 105 - BOTH OPEN BOP Verify AFW flow to all SGs

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

1 Scenario #

All Event #

Page 27 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Verify Containment Ventilation Isolation:

a. Containment Purge Valves - CLOSED o

FCV-1170 o

FCV-1171 o

FCV-1172 BOP o

FCV-1173

b. Containment Pressure Relief Valves -

CLOSED PCV-1190 PCV-1191 PCV-1192 Note provides a list of Phase A valves

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

1 Scenario#

All Event#

Attachment I Page 28 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Verify Containment Isolation Phase A

a.

Phase A - ACTUATED o Train A master relay CA1 (above rack E) o Train B master relay CA2 (above rack F)

b. Phase A valves - CLOSED

c.

IVSW valves - OPEN o

1410 o

1413 o

SOV-3518 o

SOV-3519

d. WCP valves - OPEN:

o PCV 1238 BOP o

PCV 1239 o

PCV 1240 o

PCV 1241

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

f.

Dispatch NPO to periodically check o

IVSW Tank o

Level - GREATER THAN 92%

o Pressure - GREATER THAN 57 PSIG o WCP header pressures - GREATER THAN 52 PSIG 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 #

Ail Event #

Page 29 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Check if Containment Spray should be actuated:

a.

Containment Pressure - EVER GREATER THAN 24 PSIG

b. Verify spray pumps - RUNNING

c. Verify spray pump discharge valves - OPEN o

MOV-866A o

MOV-866B o

MOV-866C BOP o

MOV-866D

d. Verify Containment Isolation Phase B valves

- CLOSED

e. STOP all RCPs

f.

Verify IVSW Isolation Valves - OPEN o

7864 o

7865 o

7866 o

7867 Verify CCR Air Conditioner Train A and B - RUNNING IN BOP INCIDENT MODE 2 BOP Notify CRS that Attachment 1 is complete

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

IP2 Scenario No.:

2 Op Test No.:

1 Examiners:

Candidates:

CRS RO PO Initial Conditions:

100% power MOL 21 Charging Pump OOS 21 CCW Pump OOS Small SG Tube Leak < 5 GPD Turnover:

Turbine 21 rupture disc is leaking. Reduce Power to 250 MWe at 200 MWe per hour and remove Main Turbine and Generator from service Critical Tasks:

Manual Turbine Trip Initiate Emergency Boration Event Malf. [ Event No.

No.

Type*

Event Description 1

R (RO)

Reduce load N (BOP)

N (C RS) 2 XMT I (CRS)

First Stage Shell Pressure PT-412B fails low MSS054A 3

CCW1 C

CCW Pump Trip. Standby does not automatically start CCW2 (BOP/CRS)

CCW3 4

CVC6 C (ALL)

RCP TBHX leak. RCP vibration CCW8 RCP7A 5

RCP21 M (ALL)

RCP sheared shaft; ATWS PPL3-4 6

TCAI-6 C (RO)

Turbine Trip failure PPL43-48 7

CVC9 C (ALL)

Boration failure

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description IP2 Simulator Scenario 2 The crew will assume the shift and initiate a load decrease in accordance with POP-3.1.

First Stage Shell Pressure transmitter PT-41 2B will fail low. The crew will place steam dumps in Pressure Control Mode and trip SI steam flow bistables IAW AOI-28.0 and AOI-28.14. The CRS will refer to Technical Specifications.

A running CCW pump will trip. The standby pump will have to be manually started. The crew will respond IAW AO1-4.1.1. Subsequently, a TBHX leak will develop, and action to isolate the TBHX leak will be taken IAW AOI-4.1.2.

During the TBHX tube leak, RCP vibration will rise, eventually resulting in failure of the RCP shaft. The crew will respond using AOl-1.3. A reactor trip will be required, but will not automatically occur.

The RO will attempt to manually trip the reactor, but the reactor will not trip. The turbine must be manually tripped, and emergency boration will fail, requiring an alternate method for emergency boration.

Safety Injection will actuate due to lowering RCS pressure. The crew will perform the necessary actions for SI actuation along with FR-S.1 action.

EOP flow path: E FR-S.1 - E ES-1.1 Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 2 21 Charqing Pump OOS:

21 CCW Pump OOS:

23 CCW Pump auto start fail:

LOA EPS10 1,0,D Place pump control switch in TPO LOA EPS13 1,0,D Place pump control switch in TPO MOC CCW3 Option 4 Fail Reactor trip breakers as is:

Fail Rod Drive MG Set breaker as is:

Fail MOV-333 Closed:

Fail Auto turbine trip:

BKR PPL003 Option 5 BKR PPL004 Option 5 BKR CRF1 Option 5 BKR CRF2 Option 5 BKR EPS31 Option 5 BKR EPS32 Option 5 MOV-CVC9 Option 5 Run Batch files FAIL.AUTO.TURB.TRIPS.BAT MAN.TURB.TRIP.ENABLE. BAT Materials needed for scenario:

POP-3.1 Graph Book Tags for tagged equipment Reactivity Summary Sheet Allow crew to begin scenario brief approximately 30 minutes prior to entering simulator Note: None Scenario built from IC 2 Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Turnover Information Scenario 2 The plant is at 100% power, steady state conditions exist.

Middle of Life, Cb is 862 ppm.

EFPD = 340 Control Bank D = 220 steps Tavg = 5591F 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. 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 />.

Crew instructions:

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

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

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

1 Scenario #

2 Event #

1 Page 5

of 27 Event

Description:

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

Note: Calibration not required VERIFY LCV-1 129, Excess Condensate Return to CST, is CRS 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 OTC above insertion limits required by GRAPH RPC-6, Cycle 14 Core Operating Limits Report.

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

OTC MAINTAIN delta flux within the target band.

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

1 Scenario#

2 Event#

1 Page 6

of 27 Event

Description:

Reduce Load Time Position plicant's Actions or Behavior IF PICS is NOT operable, PERFORM the following after load changes greater than 10% per AOl 29.12, Loss of PICS Computer:

o Quadrant Power Tilt Calculation using DSR-4B, Quadrant Power Tilt Calculation Sheet (Technical CREW Specification 3.10.10).

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

BOP MONITOR condenser sextants for sodium increase.

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

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

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

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

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

1 Scenario #

2 Event #

1 Page 7

of 27 Event

Description:

Reduce Load Time Position Applicant's Actions. or Behavior DIRECT NPOs to perform the following during load reduction:

o MONITOR Main Turbine Oil Temperatures o

MONITOR Hydrogen Seal Oil Temperatures o

MONITOR MBFP Oil Temperatures o

BALANCE Heater Drain Tank Pump flows between the pump in Auto and Manual per SOP 19.1, Extraction CRS Steam And Heater Drain Systems Operation.

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

o IF FCV-1 120, Flowpath A Controller Stop, is in MANUAL, ADJUST to maintain FCV-1 113, 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.

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

OTC o

Governor control o

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

OTC o

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

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

1 Scenario#

2 Event#

1 Page 8

of 27 Event

Description:

Reduce Load Time Position Applicant's Actions or Behavior 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:

o GRAPH CVCS-3A, Boration Nomograph for Hot RCS o

GRAPH CVCS-3B, 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 OTC 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 I

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

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

OTC PLACE the RCS Makeup Control switch to STOP.

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

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

1 Scenario #

2 Event #

1 Page 9

of 27 Event

Description:

Reduce Load Time Position Applicant's Actions or Behavior OTC PLACE the RCS Makeup Mode Selector switch to BORATE.

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

OTC VERIFY boric acid transfer pumps are in AUTO.

OTC PLACE the RCS Makeup Control switch to START.

_ I

_I I__

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

OTC VERIFY BATPs shift to fast speed.

IF in manual, ADJUST FCV-1 1 OA, Boric Acid Flow Control, to OTC obtain desired boric acid flow rate (may be greater than meter OTO range).

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

OTCo HCV-104 CVCS/Boric Acid Tank 22 BA OTC Inlet o

HCV-105 CVCS/Boric Acid Tank 21 BA Inlet

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

1 Scenario#

2 Event#

1 Page 10 of 27 Event

Description:

Reduce Load Time Position A

licant's Actions or Behavior MONITOR Nuclear Instrumentation, Rod position, and RCS OTC 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-1 1 OA, Boric Acid Flow Control, dial setting to the new RCS Boron concentration per OTC applicable CVCS Graph:

o GRAPH CVCS-1A, Blended Makeup - (0-500) with 120 Gpm PW o

GRAPH CVCS-1B, Blended Makeup - (0-2000) with 120 Gpm PW o

GRAPH CVCS-1 C, Blended Makeup with Various PW Flows OTC VERIFY FCV-11 OA control switch in AUTO.

OTC PLACE the RCS Makeup Control switch to START.

VERIFY approximately 30 gallons of blended makeup flows OTC through blender.

OTC PLACE RCS Makeup Control switch to STOP.

OTC SELECT AUTO on RCS Makeup Mode Selector switch.

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

1 Scenario#

2 Event#

1 Page 11 of 27 Event

Description:

Reduce Load L-Time I

Position Applicant's Actions or Behavior OTC PLACE the RCS Makeup Control switch to START.

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

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

At Lead Evaluator's discretion, proceed to Event 2

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

1 Scenario#

2 Event#

2 Page 12 of 27 Event

Description:

First Stage Shell Pressure PT-412B Fails Low Time Position pplicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

XMT MSS054A SEVERITY 0 RAMP TIME 120 CRS Refers to AO1-28.0, Instrument Failures VERIFY The Following Controls:

o Turbine load - STABLE o

Rod Control - STABLE OTC o

PRZR pressure control - NORMAL o

PRZR level control - NORMAL o

MBFP Speed - NORMAL o

S/G levels - NORMAL Note: The instrumentation steps can be performed in any order CHECK PRZR instrumentation - NORMAL:

OTC o

PRZR pressures o

PRZR levels CHECK S/G instrumentation - NORMAL o

SIG levels OTC o

S/G pressures o

S/G feedwater flow S/G steam flows

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

1 Scenario #

2 Event#

2 Page 13 of 27 Event

Description:

First Stage Shell Pressure PT-412B Fails Low Time Position Applicant's-Actions or Behavior CHECK RCS instrumentation:

o CHECK RCS loop temperatures:

o Loop Tavg - NORMAL OTC 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 CRS o

Go to AOI 28.14, 1 ST STAGE PRESSURE CHANNEL FAILURE SET steam dump pressure controller for 1005 psig (83%)

OTC steam pressure OTC MOVE steam dump control selector switch to Pressure Mode MINIMIZE transients which will cause Tavg to increase above CREW 5590F DETERMINE IF tripping Steam Flow Si bistable trip switches CRS/BOP will cause an Si

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

1 Scenario#

2 Event #

2 Page 14 of 27 Event

Description:

First Stage Shell Pressure PT-412B Fails Low Time N

Position Applicant's Actions or Behavior IF tripping Steam Flow SI bistables will NOT cause an SI, THEN TRIP bistable for the failed channel BOP o

Loop 1B High SF SI (White A-11) o Loop 2B High SF SI (White A-10) o Loop 3B High SF SI (White A-1i1) o Loop 4B High SF SI (White A-10)

IF it has been determined that the failed component will not effect rod control and/or steam dumps, they may be returned to AUTOMATIC per CR/SM direction CREW o

RETURN rod control to AUTOMATIC o

RESET loss of load interlock o

ENSURE steam dump controller is returned to temperature mode When Hi Steam Flow bistables have been tripped or at Lead Evaluator's discretion, proceed to Event 3

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

1 Scenario#

2 Event#

3 Page 15 of 27 Event

Description:

CCW Pump Trip.

Time PoiinApplicant's Actions or Behavior Booth Instructor: When directed, insert the following commands:

MOT CCW2 Option 2 CCW pump 22 shaft seizure HTX CVC6 Option I VALUE 50 RAMP 15:00 TBHX LEAK SLF RCP7A VALUE 10 RAMP 10:00 21 RCP HIGH VIBRATION WITH 5 MINUTE DELAY Note: Allow entry to A01-4. 1.2, Leakage into CCW system, prior to initiating the vibration alarm. Either select an appropriate timer or wait until after procedure is in use.

CRS Refers to AOI-4. 1.1, Loss of Component Cooling VERIFY CCW Pump discharge pressure is greater than 80 psig with one pump in service or greater than 107 psig with two pumps in service o

IF NOT, START additional CCW Pumps as necessary BOP to provide the required CCW flow o IF CCW Pump discharge pressure can NOT be maintained greater than 107 psig with two pumps in service, INITIATE a plant shutdown in accordance with Technical Specification 3.3.E.2 VERIFY the requirements of Technical Specification 3.3.E.1 or CRS 3.3.E.2 are met.

Event 4 is initiated on timer from this event. Proceed to Event 4 when alarms are received for TBHX leakage.

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

1 Scenario#

2 Event#

4 Page 16 of 27 Event

Description:

RCP TBHX Leak. RCP Vibration Time Position Applicant's Actions or Behavior Initiated on timed sequence from previous event.

CRS Refer to AOI-4.1.2, Leakage into Component Cooling System VERIFY automatic actions in Section 3 have occurred BOP o

If CC Surge tank level is increasing, close RCV-017 CRS DIRECT NPO to CLOSE 831, Surge Tank Makeup Valve NOTE 835 Surge Tank Relief Valve is set at 52 psig MONITOR CCW Surge Tank Pressure / Level AND WHUT BOP Level to detect lifting of 835, Surge Tank Relief Valve

_ I _

_ I II__

NOTE IF the leaking component is known, Operator may go directly to appropriate Attachment with approval of the SWS, to isolate the in-leakage If surge tank level is increasing, isolate sources of leakage one at a time using the following attachments:

CREW o Attachment 1, RCP Thermal Barrier Evaluator note: Attachment 1 is included at end of scenario guide.

Proceed to Event 5 when attachment I is complete or at Lead Evaluator's discretion

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

1 Scenario#

2 Event#

5,6,7 Page 17 of 27 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time I

Position I

Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MOT RCP5 OPTION 1 21 RCP Shaft break REMOVE CCW Pump 23 AUTO START FAILURE (MOC CCW3)

CREW Determine reactor trip required. Reactor did not trip.

Direct reactor trip and entry to E-0, Reactor Trip or Safety CRS Injection Verify reactor trip OTC o Attempt to manually trip reactor Direct entry to FR-S. 1, Response to Nuclear Power CRS Generation/ATWS Verify reactor trip o

Attempt to manually trip the reactor CREW o Manually insert control rods o

Dispatch NPO to locally trip reactor trip breakers or MG set breakers Critical Verify Turbine trip Task OTC o

Manually trip the turbine BOP Check AFW pumps running

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

1 Scenario #

2 Event #

5, 6, 7 Page 18 of 27 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position Applicant's Actions or Behavior Initiate emergency boration BOP o

Start Charging pumps o

Open MOV-333 (Will not Open)

Critical Align one of the following flowpaths Task o

RWST flow path o

Open LCV-112B o

Close LCV-1 12C o

Place Makeup control switch to STOP BOP o

Establish maximum charging flow OR o

Normal boration flow path o

FCV-110in MANUAL o

Both boric acid pumps in high speed o

Adjust FCV-110 for maximum flow Booth Instructor: When boration is initiated, remove Reactor trip malfunctions to allow rods to drop OTC Check PRZR pressure less than 2335 psig CAUTION Radiation levels and harsh environment conditions should be evaluated prior to performing local actions Verify containment ventilation isolation BOP o

Containment Purge valves closed o

Containment pressure relief valves closed

_I I

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

1 Scenario #

2 Event #

5, 6, 7 Page 19 of 27 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position Applicant's Actions or Behavior CAUTION If an SI signal exists or occurs, steps 1-9 of E-0 should be performed while continuing with this procedure BOP Perform Steps 1-9 of E-0, Reactor Trip or Safety Injection While determining whether the RCPs have CCW cooling, the BOP may determine that CCW flow is insufficient to maintain long term thermal barrier cooling. He may decide to trip RCPs, but is not required to, because minimal cooling will be available at this time.

Check if the following trips have occurred OTC o

Reactor trip o

Turbine trip o

Dispatch NPO to open MG set output breakers I

_ I I_

I CAUTION City Water for AFW pumps will be necessary if CST level decreases to less than 2 feet Check SG levels OTC o

NR level in at least one SG greater than 10%

o Control feed flow to maintain 10-50%

Verify dilution paths isolated OTC o

FCV-111Aclosed o

Fl-1 1 no flow indicated

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

1 Scenario #

2 Event #

5, 6, 7 Page 20 of 27 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position Applicant's Actions or Behavior Check for reactivity insertion from uncontrolled cooldown o

Check RCS temperature decreasing in an uncontrolled OTC manner o

Check any SG pressure decreasing in an uncontrolled manner o

Stop controlled cooldown BOP Check core exit TCs less than 12000F OTC Verify reactor subcritical CRS Return to E-0, step 1 Evaluator Note: E-0, Steps 1-9 should be in progress or complete. Attachment 1 actions from step 5 of E-0 are included at back of this guide. (page 22)

Check RCS temperature stable at or trending to 5471F (NO) o Stop dumping steam OTC Check PRZR PORVs and spray valves closed OTC Check if RCPs should be stopped (NO)

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

1 Scenario#

2 Event #

5, 6, 7 Page 21 of 27 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position plicant's Actions or Behavior Check if any SG is faulted OTC o Any SG depressurizing in an uncontrolled manner o Any SG depressurizing CREW Check if SG tubes are intact (YES)

CREW Check if RCS is intact (YES)

CREW Check if SI should be terminated (YES)

CRS Direct transition to ES-1.1, SI Termination Terminate scenario when transition is announced to ES-1. 1

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

1 Scenario #

All Event #

Page 22 of 27 Event

Description:

, Automatic Action Verification me Position Applicant's Actions or Behavior Note This attachment must be terminated upon CRS transition to ECA-0.0, Loss of All AC Power.

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 BOP RWST o

LCV-1 12B Close charging pump suction valve from VCT o

LCV-112C Place RCS Makeup Control switch to STOP 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.

breakers - OPEN

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

1 Scenario#

All Event#

Page 23 of 27 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Check status of 480 volt busses:

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

b. Dispatch NPO to reset:

BOP o All lighting BOP o

MCC 24A o

MCC 27A o

MCC 29A

c. Stop all Condensate Pumps Verify FW Isolation:

o Main Boiler Feed Pumps - TRIPPED o

Main Boiler Feed Pump Discharge Valves BOP

- CLOSED o

FW Regulating valves - CLOSED o

FW Stop Valves - CLOSED o

SG Blowdown Isolation Valves - CLOSED Check if Main Steam Lines should be isolated:

a. Check for either:

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

OR Containment pressure - EVER GREATER THAN 24 psig

b. Verify MSIVs - CLOSED

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

1 Scenario#

All Event#

Page 24 of 27 Event

Description:

, Automatic Action Verification TIIme Position Applicant's Actions or Behavior Verify proper Service Water System operation:

a. Three Service Water Pumps - Running on BOP Essential Header

b. Service Water valves from Diesel Generator -

OPEN Verify SI system pumps running:

a. Three SI pumps - RUNNING BOP

b. 22 SI pump discharge isolation MOV-851A AND MOV-851 B - OPEN

c. Two RHR pumps - RUNNING Verify proper emergency SI System valve alignment:

a. SI pump cold leg injection valves - OPEN o

856A o

856E o

8560 o

856D BOP

b. RHR HX CCW outlet valves - OPEN o

822A o 822B

c. RHR HX MOVs - OPEN o

746 o

747 Verify Containment Fan Coolers - IN SERVICE:

a. Five fan coolers - RUNNING BOP

b. Charcoal Filter valves - OPEN

c. Fan normal discharge valves - CLOSED

d. TCV-1 104 and TCV-1 105 - BOTH OPEN

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

1 Scenario #

All Event #

Page 25 of 27 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior BOP Verify AFW flow to all SGs Verify Containment Ventilation Isolation:

a. Containment Purge Valves - CLOSED o

FCV-1170 o

FCV-1171 o

FCV-1172 BOP o

FCV-1173

b. Containment Pressure Relief Valves -

CLOSED PCV-1190 PCV-1191 PCV-1192 Note provides a list of Phase A valves

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

1 Scenario #

All Event #

Page 26 of 27 Event

Description:

, Automatic Action Verification Time Position Applicants Actions or Behavior Verify Containment Isolation Phase A

a. Phase A - ACTUATED o

Train A master relay CA1 (above rack E) o Train B master relay CA2 (above rack F)

b. Phase A valves - CLOSED

c. IVSW valves - OPEN o

1410 o

1413 o

SOV-3518 o SOV-3519

d. WCP valves - OPEN:

o PCV 1238 BOP o

PCV 1239 o

PCV 1240 o

PCV 1241

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

f. Dispatch NPO to periodically check o

IVSW Tank o

Level - GREATER THAN 92%

a Pressure - GREATER THAN 57 PSIG o

WCP header pressures - GREATER THAN 52 PSIG 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 27 of 27 Event

Description:

, Automatic Action Verification Time PoiinAplicant's Actions or Behavior Check if Containment Spray should be actuated:

a.

Containment Pressure - EVER GREATER THAN 24 PSIG

b. Verify spray pumps - RUNNING

c. Verify spray pump discharge valves - OPEN o

MOV-866A o

MOV-866B o

MOV-866C BOP o MOV-866D

d. Verify Containment Isolation Phase B valves

-CLOSED

e. STOP all RCPs

f.

Verify IVSW Isolation Valves - OPEN o

7864 o

7865 o

7866 o 7867 Verify CCR Air Conditioner Train A and B - RUNNING IN BOP INCIDENT MODE 2 BOP Notify CRS that Attachment 1 is complete

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

IP2 Scenario No.:

3 Op Test No.:

1 Examiners:

Candidates:

CRS RO PO Initial Conditions:

6% power BOL Plant startup in progress Turnover:

Raise power and synchronize the Main Generator Critical Tasks:

Stop SI pumps Isolate ruptured SG Event Malf.

Event vNo.t No.

Type*

Event Description 1

R (RO)

Raise reactor power. Synchronize Main Generator N (BOP)

N (CRS) 2 XMT I (ALL)

Tcold instrument fails high RCS036A 3

RCS14C C (ALL)

Steam Generator Tube Leak 4

RCS14C M (ALL)

SGTR 5

XMT C (RO)

Atmospheric Dump valve on ruptured SG fails open SGN43 6

SWI C (BOP)

CIA fails to reset. Manual action to bypass and reset CIA PPLO30B

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description IP2 Simulator Scenario 3 The crew will assume the shift to raise power and synchronize the Main Generator to the grid lAW POP-1.3 and SOP-26.4.

When the generator is on-line, a Tcold instrument will fail high. lAW AO1-28.0 and 28.1, the RO will place the running Charging Pump in manual, the BOP will trip bistables, and the CRS will refer to Technical Specifications.

When the plant is stable, a steam generator tube leak will develop, requiring action IAW AOI-1.2. Leak rate is quantified, secondary systems are isolated, and the crew will begin a plant shutdown lAW POP-3.1 based on excessive SG tube leakage. The CRS will again refer to Technical Specifications.

While the crew is shutting the plant down, the tube leak will increase in severity. The crew will determine that pressurizer level cannot be maintained, and a reactor trip will be required.

When the reactor trips, one Atmospheric Dump Valve will fail open, requiring manual action to close it to minimize the radioactive release to atmosphere. Additionally, CIA will fail to reset.

The crew must bypass and manually reset CIA to provide instrument air to containment, avoiding RCS depressurization using PORVs EOP flow path: E E ES-3.1 Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Setup Scenario 3 No equipment Out of Service CIA Reset Failure:

SWI PPLO30B 1 Materials needed for scenario:

POP-1.3 SOP-26.4 Graph Book Reactivity Summary Sheet Allow crew to begin scenario brief approximately 30 minutes prior to entering simulator Note: None Scenario built from IC 20 Indian Point Unit 2 2003 NRC Initial License Examination Simulator Scenario Turnover Information Scenario 3 The plant is at 6% power, ready to synchronize the Main Generator.

Beginning of Life, Cbis 1275 ppm.

EFPD = 100 Control Bank D = 157 steps Tavg = 5471F RCS Pressure = 2235 psig Pressurizer Level = 37%

Risk Assessment = GREEN Daily Risk Factor = 0.83 The following equipment is out of service:

None Crew instructions:

In accordance with POP-1.3 and SOP-26.4, synchronize the Main Generator and prepare to raise load to 100%.

POP-1.3 is complete through step 4.32 SOP-26.4 step 4.6.7 in progress D.O has confirmed that the switchyard is properly aligned and all grounds removed D.O directs you to synchronize using breaker 7 and close breaker 9 when ready in accordance with procedure Generator is to be synchronized in MANUAL Appendix D Operator Action Form ES-D-2 Op Test No.:

1 Scenario #

3 Event #

1 Page 5

of 29 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior CRS Refer to POP-1.3 SYNCHRONIZE the Generator to the bus and CONTINUE with SOP 26.4, Turbine Generator Startup, Synchronizing, Voltage BOP Control and Shutdown, "Initial Loading of the Generator and Closing of the Second Generator Output Breaker", section REQUEST the DO to indicate which generator breaker CRS (7 or 9) is to be used for synchronizing PLACE Bkr 7 or 9 Sync Pot Control Selector switch in the BOP appropriate position BOP VERIFY Synchroscope Switch is in MAN CAUTION At synchronization, the Main Transformer Secondary voltage should be 8 to 20 KV greater than system voltage UNLESS directed otherwise by the DO, slowly ADJUST the AC regulator UNTIL 346 to 358 KV (nominally 350 KV) on BOP the high side of the generator main power transformers has been established ADJUST Turbine speed UNTIL the Synchroscope is BOP observed to be rotating slowly in the fast direction

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

1 Scenario #

3 Event #

1 Page 6

of 29 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior NOTE Manual synchronization of the Generator may be required because the Auto-Synchronizing Circuitry has been determined to be inoperable BOP VERIFY Synchroscope Switch is in MAN WHEN the Synchroscope is between one minute BOP BEFORE 12, and 12 O'clock (top center), CLOSE the selected generator breaker CRS NOTIFY the SO that Unit 2 is synchronized to the bus CRS RECORD the time in the CRS log book

_ I I_

I CAUTION Do NOT operate the Main Generator above 40 MWe with 6.9 KV Buses 1 through 4 in parallel with the Station Auxiliary Transformer and the Unit Auxiliary Transformer VERIFY Generator output voltage is within the capability CREW limits in Graph EL-1, Capability Curve Voltage Regulator in Service and Out of Service NOTE o

Refer to Graph EL-3, Generator Load Changing Curves.

o The maximum Generator H2 heat up rate is 10C/hr (18'F/hr.)

l I

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

1 Scenario#

3 Event#

1 Page 7

of 29 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior COMMENCE turbine generator load increase as plant BOP conditions allow As Generator load increases, VERIFY all phase ammeters BOP approximately equal As directed by the DO, ADJUST Generator AC regulator to BOP obtain Reactive loading (VARS)

Booth Instructor: If asked, D. 0. requests 50 MVARs OUT until Generator load is 200 MWe NOTE o

Load pickup to obtain 30 to 40 MWe Turbine Generator load should be done slowly, minimizing the effects of swell on SG level and to avoid exceeding the POWER ABOVE P-10 Permissive setpoint.

o The load increase to 40 MWe should be done at a rate at which the operator is comfortable (approximately 10 to 15 minutes).

o Crossover steam temperature increases SHALL NOT exceed 750F/hr.

BOP ADJUST Governor for 30 to 40 MWe Turbine Generator load ALIGN the 25000 Speedomax Bearing Temperature Monitor BOP per Operator Aid 97-02, as directed by the CRS Note: May N/A this step

_ [I _

I _______

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

1 Scenario #

3 Event #

1 Page 8

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Description:

Raise reactor power. Synchronize Main Generator.

Time Position plicant's Actions or Behavior WHEN closure of the other generator output breaker is to be performed, PLACE the Synchroscope Switch to MAN, BOP and PLACE Bkr 7 or 9 Sync Pot Control Selector Switch in the appropriate position CAUTION o

The Synchroscope should NOT rotate when the second breaker is selected, since there should be no phase difference across the breaker.

o If the Synchroscope is rotating, do NOT close second breaker BOP CLOSE the second breaker with the DO's permission WHEN Reactor power level exceeds 10 percent as indicated by the LOW POWER PERMISSIVE BLOCK NOT ENGAGED alarm and illumination of the POWER ABOVE P-10 light o

BLOCK the intermediate range trip and rod stop o

OBSERVE the INTERMED RANGE TRIP BLOCKED OTC light is illuminated o

BLOCK the low power range trip o

OBSERVE the LOW PWR RANGE TRIP BLOCKED light is illuminated o VERIFY the LOW POWER PERMISSIVE BLOCK NOT ENGAGED Alarm clears INITIATE Steam Generator Blowdown per SOP 7.1, Steam BOP Generator Blowdown System Operation CAUTION If the Main Generator is carrying greater than 40 MWe, do NOT transfer the auxiliary loads

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

1 Scenario #

3 Event #

1 Page 9

of 29 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior PRIOR to exceeding 40 MWe, TRANSFER Bus Sections 1 BOP through 4 from the Station Auxiliary Transformer to the Unit Auxiliary Transformer per SOP 27.1.4, 6900 Volt System

_ I. __

I _

_ I When busses are transferred or at Lead Evaluator's discretion, proceed to Event 2

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

I Scenario #

3 Event #

2 Page 10 of 29 Event

Description:

Tcold Instrument Fails High Time Position Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

XMT RCS036A FIXED OUTPUT: TE-411 B RCS LOOP 21 COLD LEG TEMP 600 CRS Refers to AOI-28.0, Instrument Failures VERIFY The Following Controls:

o Turbine load - STABLE o

Rod Control - STABLE CREW o

PRZR pressure control - NORMAL o

PRZR level control - NORMAL o

MBFP Speed - NORMAL o

S/G levels - NORMAL CHECK PRZR instrumentation - NORMAL:

CREW o

PRZR pressures o

PRZR levels CHECK S/G instrumentation - NORMAL o

S/G levels CREW 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 CREW o

Actual loop AT - NORMAL o

CHECK Power Range Channels - NORMAL a

CHECK RCS coolant loop flow channels - NORMAL

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

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3 Event #

2 Page 11 of 29 Event

Description:

Tcold Instrument Fails High Time Position Applicant's Actions or Behavior GO to AOl 28.1, NARROW RANGE HOT/COLD LEG CRS TEMPERATURE CHANNEL FAILS HIGH/LOW OTC PLACE Rod Control bank selector switch in MAN OBSERVE actual insertion limits. (REFER to GRAPH RPC-6, CRS Cycle 15 Core Operating Limits Report)

OTC PLACE charging pump speed control in MANUAL CONTROL Pressurizer level in Normal band. (Refer to GRAPH OTC RCS-2, Pressurizer Level Program vs. Tave, in the Graphs Book)

In Foxboro Rack D10, PLACE T AVE DEFEAT switch (T/412A BOP OR T/41 2B) to DEFEAT LOOP #, for affected loop In Foxboro Rack B8, PLACE DELTA-T DEFEAT switch BOP (T/411 A OR T/41 1 B) to DEFEAT LOOP #, for affected loop PLACE Rod Control Bank selector switch in AUTO, UNLESS OTC directed otherwise by the CRS OTC RETURN charging pump speed control to AUTOMATIC

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

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3 Event #

2 Page 12 of 29 Event

Description:

Tcold Instrument Fails High Time Position Applicant's Actions or Behavior REFER to Technical Specification Tables 3.5-2, 3.5-3, 3.5-4 CRS AND Bistable Trip status lights on Panel SO to determine if tripping Bistable trip switches will cause a Reactor Trip IF tripping the Bistable Trip Switches will NOT cause a Reactor BOP Trip, THEN TRIP the appropriate Loop Bistable trip switches per Table 1, List of Loop Temperature Bistable Trip Switches

_ ~I _

1 When bistables are tripped or at Lead Evaluator's discretion, proceed to Event 3

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

1 Scenario#

3 Event#

3 Page 13 of 29 Event

Description:

Steam Generator Tube Leak

[

Time ll Position ll Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL RCS14C ACT,0.005,0,0,0,D NOTE o

IF at any time while in this procedure, steam generator leak rate increases above the next action level as specified in Step 2 of FOLDOUT PAGE, this procedure SHALL be re-entered at Step 3 o

IF Attachment 8 is used for Leak Rate Estimation, it shall be performed at 15 minute intervals until the leakrate is stable for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (<10% increase during a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period), then the time interval may be relaxed to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> IF a significant increase is observed on R-45, PERFORM the following CRS o

NOTIFY Health Physics o

PERFORM Leak Rate Estimate per Attachment 8 Booth Instructor Note: If requested for leak rate attachment calculation, air In-Leakage is 12 SCFM. RCS activity is 0.06 pCi/cc IF steam is available on the secondary side, DIRECT Chemistry to perform Leak Rate Calculation CRS o

MAINTAIN steady state conditions while Chemistry performs Leak Rate Calculation o

PERFORM Attachment 5, Page, at least once every 15 minutes

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

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3 Event #

3 Page 14 of 29 Event

Description:

Steam Generator Tube Leak Time Position plicant's Actions or Behavior NOTE o

The leak rates specified in Step 3 apply to leakage in any one steam generator.

IF it is not practical to assign the leakage to an individual steam generator, all leakage should be assumed to be from one steam generator o

WHEN available, the Nitrogen 16 Monitor SHALL be used for the initial determination of leak rate. (Note: N-16 not available below 30% power)

CHECK Primary To Secondary Leak Rate CREW o

Leak Rate - GREATER THAN 5 GPD CREW Leak Rate - GREATER THAN OR EQUAL TO 30 GPD NOTE IF steam generator leak rate is greater than 75 gpd AND has increased by 30 gpd or more in last hour, monitored in at least 30 minutes intervals, Reactor Power should be reduced to less than 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and placed in hot shutdown within 2 additional hours Leak Rate - GREATER THAN 75 GPD AND INCREASED BY CREW 30 GPD IN LAST HOUR MONITORED IN AT LEAST 30 MINUTES INTERVALS NOTE IF performing a Rapid Plant Shutdown, Chemistry HOLD for sampling is NOT required I

I Booth Instructor Note: Approximately 15 minutes after call for Chemistry sample, report that leak rate estimation per Chemistry sample results indicate a leak rate of 80 GPD.

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

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3 Event#

3 Page 15 of 29 Event

Description:

Steam Generator Tube Leak Time Position Applicant's Actions or Behavior PERFORM a rapid plant shutdown using POP 3.1, Plant Shutdown from Full Power Operation to Zero Power Condition, CREW concurrently with the rest of this procedure such that reactor power is less than 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND in hot shutdown within 2 additional hours.

When decision is made to shut down the unit, proceed to Event 4

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

1 Scenario #

3 Event #

4, 5, 6 Page 16 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time ll Position I

Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL RCS14C ACT,5,0,0,0,D XMT SGN43 1,1400,600,0,C,JBKRTA.EQ.0 CRS Direct entry to E-0, Reactor Trip or Safety Injection OTC Verify reactor trip OTC Verify turbine trip BOP Verify power to 480 V busses OTC Check if SI is actuated Perform attachment 1 while continuing with this procedure BOP (Attachment I actions begin on page 24 of this scenario guide)

OTC Verify AFW pumps running OTC Verify total AFW flow greater than 400 GPM

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

1 Scenario #

3 Event #

4, 5, 6 Page 17 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior CAUTION RCS pressure should be monitored. If RCS pressure decreases in an uncontrolled manner to less than 320 psig any RHR pump placed in PULLOUT must be manually started to supply water to the RCS Verify SI system flow o

RCS pressure less than 1660 psig OTC o

SI pump flow indicated o

RCS pressure less than 320 psig (NO) o Place one RHR pump in PULLOUT Check RCP seal cooling o 3 CCW pumps running o

CCW flow to RCP thermal barriers normal OTC o

Service Water system aligned for 3 header operation o

Locally verify SWN-4 and SWN-5 closed o

Start one Service Water pump on Non-Essential header on bus supplied by off-site power CAUTION If adverse containment conditions exist, use wide range cold leg temperatures to determine RCS temperature Check RCS temperature stable at or trending to 5470F (NO)

OTC o

Manually close Atmospheric Dump valve for 23 SG (Failed open due to failed pressure transmitter)

OTC Check PRZR PORVs and spray valves closed

__ I _ K

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

1 Scenario #

3 Event#

4, 5, 6 Page 18 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior OTC Check if RCPs should be stopped (NO)

Check if any SG is faulted OTC o Any SG depressurizing in an uncontrolled manner o Any SG depressurizing CREW Check if SG tubes are intact (NO)

CRS Direct transition to E-3, Steam Generator Tube Rupture

_ I

_ I I__

CAUTION FRPs should NOT be implemented prior to completion of E-0, Reactor Trip or Safety Injection, Attachment 1, Automatic Action Verification CAUTION Radiation levels and harsh environment conditions should be evaluated prior to performing local actions Identify Ruptured SG OTC o

23 SG ruptured CAUTION o

If the turbine driven AFW pump is the only source of feed flow, steam supply to the turbine driven AFW pump should be maintained from one SG o

At least one SG must be maintained available for RCS cooldown 1

I

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

1 Scenario#

3 Event #

4, 5, 6 Page 19 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Critical Isolate flow from ruptured SG Task (Isolation o

Atmospheric Dump valve in AUTO set at 74%

actions)

OTC o

Atmospheric Dump valve closed Note: In manual due to transmitter failure Check 22 and 23 SGs intact (NO)

OTC o

Dispatch NPO to close MS-42 steam to TDAFW pump BOP Verify blowdown isolation valves from 23 SG closed Dispatch NPO o

Close steam traps upstream of ruptured SG MSIV CRS o

Verify ruptured SG MSIV bypass closed Close ruptured SG MSIV CAUTION If any ruptured SG is faulted, feed flow to that SG should remain isolated during subsequent recovery actions unless needed for RCS cooldown Check ruptured SG NR level greater than 10%

OTC o

Stop feed flow to 23 SG I_

I CAUTION Isolation of the ruptured SG steamlines from the intact SG steamlines including trip of turbine driven AFW pump or closing the steam supply valve to turbine driven AFW pump from the ruptured SG should be completed before continuing with step 5 I

I

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

1 Scenario #

3 Event #

4, 5, 6 Page 20 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior OTC Verify ruptured SG pressure greater than 440 psig CAUTION o

If RCPs are NOT running, the following steps may cause a false F.0.4, Integrity Status Tree, indication for the ruptured loop. Disregard this ruptured loop Tcold indication until after performing step 27 o

To prevent steamline isolation, steam dump to condenser should NOT exceed 0.5E6 Ibm/hr per SG Initiate RCS cooldown o

Determine required core exit temperature o

Dump steam to condenser from intact SGs at maximum OTC rate not to exceed 0.5E6 Ibm/hr per SG o

Condenser available o

Steam Dump control to manual with zero output o

Place steam dump in pressure control o

Stop cooldown when desired temperature is achieved Check intact SG NR levels greater than 10%

OTC o

Control feed to maintain 10-50% NR level Check PRZR PORVs and Block Valves o

Power available to block valves OTC o

PORVs closed o

At least one block valve open o

Open one block valve

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

1 Scenario #

3 Event #

4, 5, 6 Page 21 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior CAUTION o

If offsite power is lost after Si reset, then manually action may be required to restart safeguards equipment o

Placing key switches to DEFEAT will prevent auto Si actuation BOP Reset Si Reset CIA BOP a

Must manually reset train 'A' relay.

BOP Establish Instrument Air to containment

_ ~I _

_ I _

CAUTION RCS pressure should be monitored. If RCS pressure decreases in an uncontrolled manner to less than 320 psig any RHR pump placed in PULLOUT must be manually started to supply water to the RCS Check if RHR pumps should be stopped BOP o

Stop RHR pumps and place in auto CAUTION If RWST level decreases to less than 15 feet, charging pumps which are started or running should be monitored for loss of suction which may result in pump damage Establish charging flow OTC o

At least one charging pump running o

Align suction to RWST o

Establish maximum flow

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

1 Scenario#

3 Event #

4, 5, 6 Page 22 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Check if RCS cooldown should be stopped OTC o

Core exit TCs less than required OTC Check ruptured SG pressure stable or increasing OTC Check RCS subcooling based on CETs greater than required Depressurize RCS to minimize break flow and refill pressurizer o

Normal spray available o

Depressurize until pressurizer level is 71%,

OTC OR o

RCS pressure less than SG pressure and PRZR level greater than 14%

OR o

RCS subcooling less than required OTC Stop depressurization I

_ I

_ I I_____

CAUTION SI must be terminated when SI termination criteria are satisfied to prevent overfilling the ruptured SG II

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

1 Scenario#

3 Event #

4, 5, 6 Page 23 of 29 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Check if SI flow can be terminated o

RCS subcooling greater than required on table OTC o

Secondary heat sink, either 400 gpm AFW flow or 10%

NR in at least one SG o

RCS pressure stable or increasing o

PRZR level greater than 14%

Critical OTC Stop SI pumps and place in AUTO Task Terminate scenario when SI pumps are secured

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

1 Scenario #

All Event #

Page 24 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Note This attachment must be terminated upon CRS transition to ECA-0.0, Loss of All AC Power.

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 BOP W1.

LCV-1 12B Close charging pump suction valve from VCT

1. LCV-1 12C Place RCS Makeup Control switch to STOP 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.

put breakers - OPEN

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

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All Event #

Page 25 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Check status of 480 volt busses:

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

b. Dispatch NPO to reset:

BOP o

All lighting o

MCC 24A o

MCC 27A o

MCC 29A

c. Stop all Condensate Pumps Verify FW Isolation:

o Main Boiler Feed Pumps - TRIPPED o

Main Boiler Feed Pump Discharge Valves BOP

-CLOSED o

FW Regulating valves - CLOSED o

FW Stop Valves - CLOSED o

SG Blowdown Isolation Valves - CLOSED Check if Main Steam Lines should be isolated:

a. Check for either:

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

OR Containment pressure - EVER GREATER THAN 24 psig

b. Verify MSIVs - CLOSED

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

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All Event #

Page 26 of 29 Event

Description:

, Automatic Action Verification Time 1

Position Applicant's Actions or Behavior Verify proper Service Water System operation:

a. Three Service Water Pumps - Running on BOP Essential Header

b. Service Water valves from Diesel Generator -

OPEN Verify Si system pumps running:

a. Three Si pumps - RUNNING BOP

b. 22 SI pump discharge isolation MOV-851A AND MOV-851 B - OPEN

c. Two RHR pumps - RUNNING Verify proper emergency SI System valve alignment:

a. Si pump cold leg injection valves - OPEN o

856A o

856E o

856C BOP o 856D

b. RHR HX CCW outlet valves - OPEN o

822A o

822B

c. RHR HX MOVs - OPEN o

746 0

747 Verify Containment Fan Coolers - IN SERVICE:

a. Five fan coolers - RUNNING BOP

b. Charcoal Filter valves - OPEN

c. Fan normal discharge valves - CLOSED

d. TCV-1 104 and TCV-1 105 - BOTH OPEN BOP Verify AFW flow to all SGs

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

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All Event #

Page 27 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Verify Containment Ventilation Isolation:

a. Containment Purge Valves - CLOSED o

FCV-1170 o

FCV-1171 o

FCV-1172 BOP o

FCV-1173

b. Containment Pressure Relief Valves -

CLOSED PCV-1190 PCV-1191 PCV-1192 Note provides a list of Phase A valves

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

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Page 28 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Verify Containment Isolation Phase A

a. Phase A - ACTUATED o

Train A master relay CA1 (above rack E) o Train B master relay CA2 (above rack F)

b. Phase A valves - CLOSED

c.

IVSW valves - OPEN o

1410 o

1413 o

SOV-3518 o

SOV-3519

d. WCP valves - OPEN:

o PCV 1238 BOP o

PCV 1239 o

PCV 1240 o

PCV 1241

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

f.

Dispatch NPO to periodically check o

IVSW Tank o

Level - GREATER THAN 92%

o Pressure - GREATER THAN 57 PSIG o

WCP header pressures - GREATER THAN 52 PSIG 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.:

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Page 29 of 29 Event

Description:

, Automatic Action Verification Time Position Applicant's Actions or Behavior Check if Containment Spray should be actuated:

a. Containment Pressure - EVER GREATER THAN 24 PSIG

b. Verify spray pumps - RUNNING

c. Verify spray pump discharge valves - OPEN o

MOV-866A o

MOV-866B o

MOV-866C BOP o

MOV-866D

d. Verify Containment Isolation Phase B valves

- CLOSED

e. STOP all RCPs

f. Verify IVSW Isolation Valves - OPEN o

7864 o

7865 o

7866 o

7867 Verify CCR Air Conditioner Train A and B - RUNNING IN BOP INCIDENT MODE 2 BOP Notify CRS that Attachment 1 is complete