Text

Final - Section C Operating
	ML031200432
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: ML031200432 (72)
	v • d • e

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 prior to ECA-2.1 entry or an ORANGE condition on the Integrity CSF Initiate Emergency Boration prior to completion of Step 4 of FR-S.1 Event Malf. Event No. No. Type* Event Description 1 R (OTC) Reduce load N (BOP)

N (CRS) 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 PPIL3-4 6 TCA1-6 C (OTC) 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 team will assume the shift and initiate a load decrease in accordance with POP-3.1.

First Stage Shell Pressure transmitter PT-412B will fail low. The team 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 team will respond IAW AOI-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 team will respond using AOl-1.3. A reactor trip will be required, but will not automatically occur.

The OTC 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 team 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 Charging Pump OOS: LOA EPS10 RACKED OUT Place pump control switch in TPO 21 CCW Pump OOS: LOA EPS13 RACKED OUT Place pump control switch in TPO 23 CCW Pump auto start fail: MOC CCW3 Option 4 Fail Reactor trip breakers as is: BKR PPL003 Option 5 BKR PPL004 Option 5 Fail Rod Drive MG Set breaker as is: BKR CRF1 Option 5 BKR CRF2 Option 5 BKR EPS31 Option 5 BKR EPS32 Option 5 Fail MOV-333 Closed: MOV-CVC9 Option 5 Fail Auto turbine trip: Run Batch files FAIL.AUTO.TU RB.TRI PS. BAT MAN.TURB.TRIP. ENABLE. BAT Materials needed for scenario:

POP-3.1

Graph Book e Tags for tagged equipment e Reactivity Summary Sheet Allow team 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 = 214 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:

0 21 Charging Pump. Return expected in approximately 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

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

Team 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 33 Event

Description:

Reduce Load Time Position Applicant's Actions or Behavior CRS Refers to POP 3.1 Note: CRS may call System Operator and also may direct OTC to develop a reactivity plan if not done prior to entering the simulator 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-1129, 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 above insertion limits required by GRAPH RPC-6, Cycle 14 OTC Core Operating Limits Report.

Note: Actions for boration are on pages 8 and 9 of this scenario guide 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 33 Event

Description:

Reduce Load Time Position F Applicant'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 TEAM 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 in progress.

CRS Note: Will call NPOs

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 1 Page 7 of 33 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 Steam And Heater Drain Systems Operation.

CRS 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: Will call NPOs 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 33 Event

Description:

Reduce Load Time ll Position 1 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.

I 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 Ib 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 33 Event

Description:

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

FCV-1 1OA, 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.

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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 1OA, 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-1 04 CVCS/Boric Acid Tank 22 BA OTC Inlet o HCV-105 CVCS/Boric Acid Tank 21 BA Inlet

___ b___ f______________

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 1 Page 10 of 33 Event

Description:

Reduce Load Time 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-11 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 10A 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 33 Event

Description:

Reduce Load 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 Book.

At Lead Evaluator's discretion, proceed to Event 2

Appendix D Operator Action Form ES-D-2 l Op Test No.: 1 Scenario# 2 Event# 2 Page 12 of 33 Event

Description:

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

XMT MSS054A SEVERITY 0 RAMP TIME 120 PT-412B Fails low Indications received:

SBF-2, 2-6, HIGH STEAM FLOW SI CHANNEL TRIP ALARM Loss of Load Interlock Reset lamp extinguished on panel FBF CRS Refers to AOI-28.0, Instrument Failures VERIFY The Following Controls:

o Turbine load - STABLE

,o Rod Control - STABLE OTC o PRZR pressure control - NORMAL C PRZR level control - NORMAL I a MBFP Speed- NORMAL o S/G levels - NORMAL o S/G pressure control - NORMAL Note: The instrumentation steps can be performed any order CHECK PRZR instrumentation - NORMAL:

OTC o PRZR pressures o PRZR levels CHECK S/G instrumentation - NORMAL o S/G levels OTC o S/G pressures o S/G feedwater flow o S/G steam flows

_ _I _ _ ______

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 2 Page 13 of 33 Event

Description:

First Stage Shell Pressure PT-412B Fails Low Time Position J 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 (NO)

CRS o Go to AOI 28.14, 1ST 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 TEAM 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 33 Event

Description:

First Stage Shell Pressure PT-412B Fails Low Time Position A licant's Actions or Behavior IF tripping Steam Flow SI bistables will NOT cause an SI, THEN TRIP bistable for the failed channel BOP a Loop 1B High SF SI (White A-i1) o Loop 2B High SF SI (White A-10) o Loop 3B High SF SI (White A-1 1) o Loop 4B High SF SI (White A-1 0)

Note: CRS MAY call I&C to determine cause

_ _ _ _ I __ _ _ _ _ _ __ _ _ _

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 33 Event

Description:

CCW Pump Trip. Standby pump does not automatically start Time l Position l Applicant's Actions or Behavior Booth Instructor: When directed, insert the following commands:

MOT CCW2A Option 2 CCW pump 22 shaft seizure HTX CVC6L VALUE 15 RAMP 15:00 TBHX LEAK Indications received:

Multiple alarms on Panel SG due to loss of CCW 22 CCW pump Amber and Green indicating lights are lit SA-1, 3-8, R-47 COMPONENT COOLING WATER HI RAID/TROUBLE (Time delayed)

CRS Refers to AOI-4.1.1, Loss of Component Cooling Note: The following step is continuously applicable If at any time, either of the following conditions are met:

o CCW flow is interrupted and CANNOT be restored within 2 minutes o RCP Motor Bearing temperature exceeds 2000 F Team Perform the following:

o Trip reactor o Trip all affected RCPs o Go to E-0, Reactor Trip or Safety Injection 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 to provide the required CCW flow (Note: Standby BOP Pump should have started automatically, but did NOT. Manual action required to start) 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 3 Page 16 of 33 Event

Description:

CCW Pump Trip. Standby pump does not automatically start Time Position " Applicant's Actions or Behavior 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 Scaanario # 2 Event # 4 Page 17 of 33 I Event

Description:

RC:P TBHX Leak. RCP Vibration Time i Position I Applicant's Actions or Behavior Note: Allow entry to A 01-4 1.2, Leakage into CCW system, priorto initiating the vibration alarm.

SLF RCP7A VALUE 10 RAMP 5:00 21 RCP HIGH VIBRATION WITH 5 MINUTE DELAY Indications available:

SA-1. 3-8, R-47 COMPONENT COOLING WATER HI RAD/TROUBLE Rising level in CCW Surge Tank Refer to AO1-4. 1.2, Leakage into Component Cooling System CRS VERIFY automatic actions in Section 3 have occurred BOP o if CC Surge tank levelis increasing, close RCV-017 DIRECT NPO to CLOSE 831, Surge Tank Makeup Valve CRS Note: Calls NPO. Also may dispatch an NPO to check 22 CCW pump breaker 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

_ _ _ _ ____ ____ l

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 4 Page 18 of 33 Event

Description:

RCP TBHX Leak. RCP Vibration Time D Position ] Applicant's Actions or Behavior NOTE IF the leaking component is known, Operator may go directly to appropriate Attachment with approval of the SM, to isolate the in-leakage If surge tank level is increasing, isolate sources of leakage one at a time using the following attachments:

TEAM o Attachment 1, RCP Thermal Barrier Note: The following actions are from A01-4.1.2, Attachment 1 NOTE o IF seal injection is maintained, RCP operation without thermal barrier cooling MAY continue for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

o For operation beyond 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , OBTAIN Operations Manager's approval.

o WHEN a component is isolated, MONITOR for possible pressure buildup on available indication.

IF FCV-625 AND 789 (Reactor Coolant Pump Thermal BOP Barrier Discharge Isolations) are open, OBSERVE RCP Thermal Barrier AP on Panel SAF. (NO)

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 4 Page 19 of 33 Event

Description:

RCP TBHX Leak. RCP Vibration Time Position Applicant's Actions or Behavior IF FCV-625 is closed PERFORM the following:

o OBSERVE RCP Thermal Barrier AP's while momentarily selecting OPEN on FCV-625.

o ALLOW FCV-625 to stroke open AND re-close TEAM automatically.

o IDENTIFY Reactor Coolant Pump Thermal Barrier with zero AP.

o MAKE a Containment entry per SAO-219 to ISOLATE RCP Thermal Barrier Return Stop on RCP identified Note:

CRS may also dispatch NPOs to locally check Thermal Barrier Heat Exchanger temperature and CCW heat exchanger temperatures, and adjust Service Water flow if necessary.

Note: When the RCP High Vibration is apparent, the following indications will be available:

SFF 3-6, 21 RCP HI VIBRATION 21 RCP Vibration will rise to 18.5 mils and stabilize OTC/BOP Refer to Alarm Response for 21 RCP High Vibration OBSERVE the Bently Nevada RCP Monitors AND OTC/BOP Recorder (YR-498A) on Rack C-9 to determine the vibration amplitude and trend for the affected RCP.

I I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 4 Page 20 of 33 Event

Description:

RCP TBHX Leak. RCP Vibration Time Position I Applicant's Actions or Behavior IF the vibrations reach a sustained value of 20 mils, PERFORM the following:

o IF the Reactor is critical, TRIP the Reactor.

TEAM o TRIP the affected RCP.

o GO TO E-0, Reactor Trip or Safety Injection.

Note: Maximum vibration reading should be 18.5 mils CRS Refer to AOI 1.3, Reactor Coolant Pump Malfunction Verify Reactor Trip NOT required (Vibration is below reactor CRS trip limit)

I _ _ _ _ _ I _ _ _ _ _ _ _ _ _ _ _ _ _ _

Proceed to Event 5 when the CRS determines that RCP vibration is below the limit for reactor trip requirement, 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 21 of 33 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position l 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)

Indications available:

Reactor Trip First Out Annunciator with NO automatic reactor trip Loop 21 RCP flow indication dropping and alarm TEAM 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 TEAM o Manually insert control rods a Dispatch NPO to locally trip reactor trip breakers or MG set breakers Will call NPO

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5, 6, 7 Page 22 of 33 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position l Applicant's Actions or Behavior Critical Task:

Manually initiate Turbine Trip prior to transition to ECA-2. 1 or an Orange path on the Integrity CSF Status Tree, whichever comes first Critical Verify Turbine trip Task OT OTC k o Manually trip the turbine BOP Check AFW pumps running Initiate emergency boration BOP o Start Charging pumps o Open MOV-333 (Will not Open)

Critical Task:

Establish Emergency Boration flow path prior to completion of FR-S. 1, Step 4 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-110inMANUAL o Both boric acid pumps in high speed a Adjust FCV-1 10 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 2 Event # 5, 6, 7 Page 23 of 33 Event

Description:

RCP Sheared Shaft; ATWS; Turbine Trip Failure; Boration Failure Time Position Applicant's Actions or Behavior 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

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CAUTION If an SI signal exists or occurs, steps 1-9 of E-0 should be performed while continuing with this procedure Perform Steps 1-9 of E-0, Reactor Trip or Safety Injection Note: The next 9 steps of this guide will be performed by the BOP BOP OR in progress until the crew transitions back to E-0.

The remaining steps of FR-S.1 resume in this guide on page 25 BOP Verify reactor trip (YES)

BOP Verify turbine trip (YES)

BOP Verify power to 480 V busses (YES)

BOP Check if SI is actuated (YES)

_ _ _ _ ~I _ _ _ I _ _ _ _ _ __ _ _ _ _ _

Appendix D OperatorAction Form ES-D-2 Op Test No.: 1 Scenario# 2 Event# 5, 6, 7 Page 24 of 33 Event

Description:

RCP Sheared Shaft, ATWVS; Turbine Trip Failure; Boration Failure Time -l Position Applicant's Actions or Behavior Perform attachment 1 while continuing with this procedure

BOP (Attachment 1 actions begin on page 28 of this scenario guide) iBOP Verify AFW pumps running BOP Verify total AFW flow greater than 400 GPM 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 l _ [ l_ _________

Verify SI system flow 0 RCS pressure less than 1660 psig (YES OR NO) 0 SI pump flow indicated 0 RCS pressure less than 320 psig (NO) o Place one RHR pump in PULLOUT BOP Note:

RCS pressure may be above or below 1660 psig at this point in the procedure. If it is above 1660 psig, SI flow should NOT be indicated.

Appendix D Operator Action Form ES-D-2

, Op Test No.: 1 Scenario # 2 Event # 5 6, 7 Page 25 of 33 Event

Description:

RCP Sheared Shaft; ATVVS, Turbin e Trip Failure; Boration Failure i Time l Position IL Applicant's Actions or Behavior Check RCP seal cooling 0 3 CCW pumps running (NO) 0 CCW flow to RCP thermal barriers normal(NO)

C Service Water system aligned for 3 header operation 0 Locally verify SWN-4 and SWN-5 closed 0 Start one Service Water pump on Non-Essential header BOP on bus supplied by off-site power While determining whether the RCPs have COW cooling, the BOP may determine that CCW flow is insufficient to I maintain long term thermal barrier cooling. He nay decide I to trip RCPs, but is not required to, because minimal cooling will be available at this time.

I I Check if the following trips have occurred o Reactor trip OTC o Turbine trip o Dispatch NPO to open MG set output breakers CAUTION City Water for AFW pumps will be necessary if CST level decreases to less than 2 feet

. I Check SG levels OTC o NR level in at least one SG greater than 10% (NO) o Control feed flow to maintain 10-50%

Verify dilution paths isolated OTC o FCV-111A closed o Fl-i 11 no flow indicated

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 2 Event # 5, 6, 7 Page 26 of 33 Event

Description:

RCP Sheared Shaft;, ATWNS; 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 12001F 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 28)

CAUTION If adverse containment conditions exist, use wide range cold leg temperatures to determine RCS temperature Check RCS temperature stable at or trending to 5470 F (NO)

OTC 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 27 of 33 Event

Description:

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

TEAM Check if RCS is intact (YES)

TEAM 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 # Attachment 1 Page 28 of 33 Event

Description:

Attachment 1, 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 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.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # All Event # Attachment 1 Page 29 of 33 Event

Description:

Attachment 1, 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

__ I ___ I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # All Event# Attachment 1 Page 30 of 33 Event

Description:

Attachment 1, Automatic Action Verification Time 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-l104 and TCV-1105 - BOTH OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # All Event # Attachment 1 Page 31 of 33 Event

Description:

Attachment 1, Automatic Action Verification Time Position plicant'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# Attachment 1 Page 32 of 33 Event

Description:

Attachment 1, 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 # All Event # Attachment 1 Page 33 of 33 Event

Description:

Attachment 1, 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.: 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 prior to water release from SGs Isolate steam flow from and feed flow to the ruptured SG prior to transition to ECA-3. 1 Event Malf. Event No. No. Type* Event Description IR (RO) Raise reactor power. Synchronize Main Generatorl N (BOP)

N (CRS) 2 XMVIT I (ALL) Tcold instrument fails high RC503 6A 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 team 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 AOI-28.0 and 28.1, the OTC 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 AOl-1.2. Leak rate is quantified, secondary systems are isolated, and the team will begin a plant shutdown IAW POP-3. 1 based on excessive SG tube leakage. The CRS will again refer to Technical Specifications.

While the team is shutting the plant down, the tube leak will increase in severity. The team 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 team 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 equioment Out of Service CIA Reset Failure: SWI CFW022A (SOV-1229 SJAE effluent isolation valve failed to AUTO position)

Materials needed for scenario:

POP-1 .3 0 SOP-26.4 e Graph Book Reactivity Summary Sheet Allow team to begin scenario brief approximately 30 minutes prior to entering simulator Note: None Scenario built from IC 20 Booth Instructor:

Set up monitor and trends to observe 23 SG mass as follows:

o ASGNTOT(3) Total mass o ASGNLTOT(3) Liquid mass o ASGNSTOT(3) Steam mass 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 = 156 steps

Tavg = 547 0F

RCS Pressure = 2235 psig

Pressurizer Level = 37%

Risk Assessment = GREEN

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

None Team 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 39 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 Note: The next 15 steps of this scenario guide cover generator excitation. Synchronization follows.

VERIFY DC and the AC are in the MINIMUM VOLTS BOP position (LEDs 8 Lit, 17 Lit - Figure 2).

BOP VERIFY all alarms on Panel FBF are clear.

BOP VERIFY 345 KV MO Disc. Switch F7-9 is CLOSED.

Indications available when exciting the generator:

FBF 4-6, GENERATOR MODE CHANGE, alarm SHF 4-1, UNIT AUX TRANSFORMER TAP CHANGER, will clear BOP SELECT DC regulator on the DC/AC selector switch.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 6 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

[ime I Position l Applicant's Actions or Behavior CAUTION During startup the maximum machine terminal voltage SHALL be 22 KV, at 1800 rpm.

NOTE Flashing the generator field requires the red FIELD EXCITATION ON button to be pressed twice.

o When the button is pressed for the first time, the field shorting breaker OPENS.

o When the button is released, the field shorting breaker RE-CLOSES.

o When pressed the second time, the field shorting breaker OPENS, and the field is FLASHED for approximately 15 seconds.

II BOP PRESS the Field Excitation OFF button.

PRESS and HOLD the Field Excitation ON button, and BOP VERIFY LED 1 is ON and LED 2 is OFF (Figure 2):

RELEASE the Field Excitation ON button, and VERIFY BOP LED 1 is OFF and LED 2 is ON.

PRESS and RELEASE the Field Excitation ON button BOP again.

BOP VERIFY LED 1 is ON and LED 2 is OFF.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 7 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position ll Applicant's Actions or Behavior OBSERVE the field amperage build up, as the field is BOP flashed for approximately 15 seconds.

CAUTION When using the DC regulator, the volts per hertz limits SHALL NOT be exceeded.

NOTE o The Nominal output voltage for the Generator is 22 KV.

o Power transformers are NOT equipped with tap-changing-under-load facilities.

o Regulation of bus voltage on the 345 KV side SHALL be maintained by controlling the Generator field.

RAISE DC voltage regulator UNTIL Generator terminal BOP voltage is 22 KV.

VERIFY the center status light is ILLUMINATED BOP o Power at the Ring Bus Side of 345 KV MO Disc F7-9 (Center)

NULL the AC regulator with the AC RAISE/LOWER BOP Switch (Transfer Volts Meter indicates 0).

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event # 1 Page 8 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position ] Applicant's Actions or Behavior CAUTION When using the AC regulator, the volts per hertz limits SHALL NOT be exceeded.

I I NOTE The DC voltage regulator setpoint automatically tracks the AC voltage regulator setpoint, facilitating a quick transfer to the DC mode, if required.

TRANSFER to the AC regulator by pushing AC/DC selector switch.

BOPO oOBSERVE Automatic Control Regulation LED is ILLUMINATED (LED 3 - Figure 2).

ADJUST Generator terminal voltage to 22 KV, using the BOP AC regulator.

Note: Synchronization steps begin below REQUEST the DO to indicate which generator breaker CRS (7 or 9) is to be used for synchronizing (7)

PLACE Bkr 7 or 9 Sync Pot Control Selector switch in the BOP appropriate position (7)

BOP VERIFY Synchroscope Switch is in MAN

_ _ _ _ ~~ _ 1 I1_ _ _ _ _ _ _ _ _ _ _ _ _

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 9 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior 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 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event# 1 Page 10 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

l Time j Position 1 Applicant's Actions or Behavior 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 limits in Graph EL-1, Capability Curve Voltage Regulator in Service and Out of Service NOTE NOTE o Refer to Graph EL-3, Generator Load Changing Curves.

o The maximum Generator H2 heat up rate is 10 0C/hr (18OF/hr.)

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 II

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 11 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

[~Time j Position Applicant's Actions or Behavior 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-1 0 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 750 F/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 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 Note:

SEF 4-11, 345 KV BREAKER NOT CLOSED alarm will clear 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event # 1 Page 12 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position F Applicant's Actions or Behavior 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 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 To transfer 6900V Bus 1 to Unit Auxiliary Transformer, PERFORM the following:

o VERIFY Unit Auxiliary Transformer and Station BOP Auxiliary Transformer are within 50 volts.

o IF voltages are NOT matched within 50 volts, GO TO Step to match voltage within 50 volts. (Should not be necessary)

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 13 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position F Applicant's Actions or Behavior PLACE 6900V Bus 1 synchroscope switch to BUS 1 -

BOP UNIT.

BOP VERIFY synchroscope at 12 o'clock.

BOP CLOSE Normal Feed Breaker UT-1.

BOP OPEN Bus 1-5 Tie Breaker UT1-ST5.

BOP PLACE 6900V Bus 1 synchroscope switch to OFF.

VERIFY Station Auxiliary Transformer AND Unit Auxiliary Transformer supplying voltage between 7.0 and 7.2 kV.

o PLACE the Station Auxiliary Transformer Tap Changer in MANUAL.

TEAM o Manually ADJUST Station Auxiliary Transformer Tap Changer to maintain supply voltage at 7.0 to 7.2 kV.

o RETURN the Tap Changer in AUTO.

Note: Bulleted items performed only if necessary

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 1 Page 14 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior To transfer 6900V Bus 2 to Unit Auxiliary Transformer, PERFORM the following:

o VERIFY Unit Auxiliary Transformer and Station BOP Auxiliary Transformer are within 50 volts.

o IF voltages are NOT matched within 50 volts, GO TO Step to match voltage within 50 volts. (Should not be necessary)

PLACE 6900V Bus 2 synchroscope switch to BUS 2 -

BOP UNIT.

1BOP VERIFY synchroscope at 12 o'clock.

1BOP CLOSE Normal Feed Breaker UT-2.

BOP OPEN Bus 2-5 Tie Breaker UT2-ST5.

BOP PLACE 6900V Bus 2 synchroscope switch to OFF.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 1 Page 15 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position ] Applicant's Actions or Behavior VERIFY Station Auxiliary Transformer AND Unit Auxiliary Transformer supplying voltage between 7.0 and 7.2 kV.

o PLACE the Station Auxiliary Transformer Tap Changer in MANUAL.

BOP o Manually ADJUST Station Auxiliary Transformer Tap Changer to maintain supply voltage at 7.0 to 7.2 kV.

o RETURN the Tap Changer in AUTO.

Note: Bulleted items performed only if necessary To transfer 6900V Bus 3 to Unit Auxiliary Transformer, PERFORM the following:

o VERIFY Unit Auxiliary Transformer and Station BOP Auxiliary Transformer are within 50 volts.

o IF voltages are NOT matched within 50 volts, GO TO Step to match voltage within 50 volts. (Should not be necessary)

PLACE 6900V Bus 3 synchroscope switch to BUS 3 -

BOP UNIT.

BOP VERIFY synchroscope at 12 o'clock.

BOP CLOSE Normal Feed Breaker UT-3.

BOP OPEN Bus 3-6 Tie Breaker UT3-ST6.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 1 Page 16 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time Position Applicant's Actions or Behavior BOP PLACE 6900V Bus 3 synchroscope switch to OFF.

VERIFY Station Auxiliary Transformer AND Unit Auxiliary Transformer supplying voltage between 7.0 and 7.2 kV.

o PLACE the Station Auxiliary Transformer Tap Changer in MANUAL.

BOP o Manually ADJUST Station Auxiliary Transformer Tap Changer to maintain supply voltage at 7.0 to 7.2 kV.

o RETURN the Tap Changer in AUTO.

Note: Bulleted items performed only if necessary To transfer 6900V Bus 4 to Unit Auxiliary Transformer, PERFORM the following:

o VERIFY Unit Auxiliary Transformer and Station BOP Auxiliary Transformer are within 50 volts.

o IF voltages are NOT matched within 50 volts, GO TO Step to match voltage within 50 volts. (Should not be necessary)

PLACE 6900V Bus 4 synchroscope switch to BUS 4 -

BOP UNIT.

BOP VERIFY synchroscope at 12 o'clock.

BOP CLOSE Normal Feed Breaker UT-4.

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event # 1 Page 17 of 39 Event

Description:

Raise reactor power. Synchronize Main Generator.

Time lPosition l Applicant's Actions or Behavior BOP OPEN Bus 4-6 Tie Breaker UT4-ST6.

BOP PLACE 6900V Bus 4 synchroscope switch to OFF.

VERIFY Station Auxiliary Transformer AND Unit Auxiliary Transformer supplying voltage between 7.0 and 7.2 kV.

o PLACE the Station Auxiliary Transformer Tap Changer in MANUAL.

BOP o Manually ADJUST Station Auxiliary Transformer Tap Changer to maintain supply voltage at 7.0 to 7.2 kV.

o RETURN the Tap Changer in AUTO.

Note: Bulleted items performed only if necessary

_ _ _ 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: 1 Scenario # 3 Event # 2 Page 18 of 39 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-411B RCS LOOP 21 COLD LEG TEMP 600 Indications available:

SAF 2-6, HIGH TAVE SAF 4-6, TAVE DEVIATION SAF 3-8, DELTA T DEVIATION FCF 4-6, TAVE TREF DEVIATION CRS Refers to AOI-28.0, Instrument Failures VERIFY The Following Controls:

o Turbine load - STABLE o Rod Control - STABLE (Checks rods in manual)

TEAMTEAMoOPZPRZR pressure control - NORMAL rsuecnrl-NRA o PRZR level control - NORMAL (NO) o MBFP Speed - NORMAL o S/G levels - NORMAL o S/G Pressure control - NORMAL OTC Places running Charging Pump in MANUAL CHECK PRZR instrumentation - NORMAL:

TEAM o PRZR pressures o PRZR levels

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 2 Page 19 of 39 Event

Description:

Tcold Instrument Fails High Time Position ll Applicant's Actions or Behavior CHECK SIG instrumentation - NORMAL o S/G levels TEAM 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 (NO)

TEAM o Actual loop AT - NORMAL (NO) o CHECK Power Range Channels - NORMAL o CHECK RCS coolant loop flow channels - NORMAL GO to AOI 28.1, NARROW RANGE HOT/COLD LEG CRS TEMPERATURE CHANNEL FAILS HIGH/LOW Note: If peer check requested for procedure transition, concur with whatever the recommendation the applicant makes 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 2 Page 20 of 39 Event

Description:

Tcold Instrument Fails High Time Position ] Applicant's Actions or Behavior 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 (T1412A BOP OR T/412B) to DEFEAT LOOP #, for affected loop In Foxboro Rack B8, PLACE DELTA-T DEFEAT switch BOP (T141 1A OR T/41 1B) to DEFEAT LOOP #, for affected loop PLACE Rod Control Bank selector switch in AUTO, UNLESS directed otherwise by the CRS OTC Will leave in MANUAL due to low poweristartup condition OTC RETURN charging pump speed control to AUTOMATIC 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 Determine that Bistable Trip switches will NOT cause a BOP reactor trip

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 2 Page 21 of 39 Event

Description:

Tcold Instrument Fails High Time Position Applicant's Actions or Behavior IF tripping the Bistable Trip Switches will NOT cause a Reactor Trip, THEN TRIP the appropriate Loop Bistable trip switches per Table 1, List of Loop Temperature Bistable Trip Switches BOP o TC-41 1A, Overtemperature Delta T trip RED A-4 o TC-411C, Overpower Delta T trip RED A-4 o TC-41 1D, Low Tave RED A-4 May contact Work Control and request assistance in CRS troubleshooting and repair.

(Booth Instructor acknowledge if called)

_ _ _ _ ~I _ _ _ I _ _ _ _ __ _ _ _ _ _

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 22 of 39 Event

Description:

Steam Generator Tube Leak, 23 SG, approximately 43 GPD Time j Position E Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command.

MAL RCS14C SEVERITY 0.005 SG Tube Leak 23 SG Indications available:

SAF-1, 2-5, R55C SG SYSTEM SAF-1, 3-9, R45 SJAE SAF-1, 3-7, R-49 SG BLOWDOWN CRS Enters AOl-1.2, Steam Generator Tube Leak Note:

BOP may direct NPO to check PCV-1227 closed per the ARP for SAF-1, 3-7. Booth Instructor call back and report valve closed 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (<10% increase during a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period), then the time interval may be relaxed to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months IF a significant increase is observed on R-45, PERFORM the following CRSo NOTIFY Health Physics o PERFORM Leak Rate Estimate per Attachment 8

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 3 Page 23 of 39 Event

Description:

Steam Generator Tube Leak, 23 SG, approximately 43 GPD Time I Position licant's Actions or Behavior Booth Instructor Note: If requested for leak rate attachment calculation, air In-Leakage is 12 SCFM. RCS activity is 0.06 pCi/cc Note: Expect approximately 45 GPD per the calculation. Should be >30GPD and <75 GPD IF steam is available on the secondary side, DIRECT Chemistry to perform Leak Rate Calculation o MAINTAINLeak steady state conditions while Chemistry CRS performs Rate Calculation o PERFORM Attachment 5, Page, at least once every 15 minutes 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 TEAM o Leak Rate - GREATER THAN 5 GPD (YES)

TEAM Leak Rate - GREATER THAN OR EQUAL TO 30 GPD (YES)

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 3 Page 24 of 39 Event

Description:

Steam Generator Tube Leak, 23 SG, approximately 43 GPD Time Position Applicant's Actions or Behavior 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and placed in hot shutdown within 2 additional hours Leak Rate - GREATER THAN 75 GPD AND INCREASED BY 30 GPD IN LAST HOUR MONITORED IN AT LEAST 30 TEAM MINUTES INTERVALS (NO)

CRS Refer to Technical Specification 3.1 .F for RCS leakage limits

___________ L ____________ I NOTE IF performing a Rapid Plant Shutdown, Chemistry HOLD for sampling is NOT required 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.

PERFORM a rapid plant shutdown using POP 3.1, Plant Shutdown from Full Power Operation to Zero Power Condition, TEAM concurrently with the rest of this procedure such that reactor power is less than 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 25 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time JE Position 11 Applicant's Actions or Behavior Booth Instructor: When directed, insert the following command:

MAL RCS14C SEVERITY 5% SGTR 23 SG XMT SGN43 OUTPUT FAILURE SEVERITY 1600 RAMP 600 23 SG 'C' PRESSURE CHANNEL (AFTER REACTOR TRIP)

Indications available:

Rapid decrease in pressurizer pressure and level Rapid rise in 23 SG level Multiple alarms Direct the following:

o Trip reactor CRS o Verify reactor trip o Manually initiate SI o 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 1 actions begin on page 34 of this scenario guide)

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 4, 5, 6 Page 26 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior OTC Verify AFW pumps running OTC Verify total AFW flow greater than 400 GPM 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 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 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 Il Check RCS temperature stable at or trending to 5471F (NO)

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

I I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 4, 5, 6 Page 27 of 39 Event

Description:

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

Check if any SG is faulted (NO)

OTC o Any SG depressurizing in an uncontrolled manner o Any SG depressurizing TEAM Check if SG tubes are intact (NO)

CRS Direct transition to E-3, Steam Generator Tube Rupture Note: If peer check is requested for procedure transition, concur with whatever is recommended CAUTION FRPs should NOT be implemented prior to completion of E-0, Reactor Trip or Safety Injection, Attachment 1, Automatic Action Verification OTC Check if RCPs should be stopped

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4, 5, 6 Page 28 of 39 Event

Description:

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

isolate Steam Flow from and Feed Flow to the ruptured SG prior to any transition to ECA-3.1 Critical Isolate flow from ruptured SG Task (Isolation actions) OTC o Atmospheric Dump valve in AUTO set at 74%

o Atmospheric Dump valve closed Note: In manual due to transmitter failure Check 22 and 23 SGs intact (NO) o Trip 22 ABFP BOP o Dispatch NPO to close MS-42 steam to TDAFW pump o When MS-42 closed, restart 22 ABFP if necessary (Not necessary)

BOP Verify blowdown isolation valves from 23 SG closed j

_ _ _ _ I1_ _ _ _ _ _ _ _ _ _ _ _ I

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# 3 Event# 4, 5, 6 Page 29 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Dispatch NPO o Close steam traps upstream of ruptured SG MSIV CRS o Verify ruptured SG MSIV bypass closed Close ruptured SG MSIV (23 SG)

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%

BOP o Stop feed flow to 23 SG o Places controller in MANUAL and adjusts closed F _ _ _ _ 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 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4, 5, 6 Page 30 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Initiate RCS cooldown Note: Refers to E-3 Step 6 table for value 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 (NO) o Open one block valve 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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4, 5, 6 Page 31 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Time Position Applicant's Actions or Behavior Reset CIA BOP o Must manually reset train 'A' relay using the Daisy Chain Bypass key.

BOP Establish Instrument Air to containment

__ __ __ Ii 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 Check if RCS cooldown should be stopped OTC o Core exit TCs less than required OTC Check ruptured SG pressure stable or increasing

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4, 5, 6 Page 32 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure l Time Position Aplicant's A Actions or Behavior 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 _ _ _ _ __ _ _ _ _ _

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

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario # 3 Event # 4, 5, 6 Page 33 of 39 Event

Description:

SGTR, Atmospheric Dump Valve on ruptured SG fails open; CIA reset failure Position RTime Applicant's Actions or Behavior Critical Task:

Stop Si pumps prior to water release from ruptured SG Atmospheric Dump valve Note: Booth operatorwill monitor SGs for water relieffrom ADV Task OTC Stop SI pumps and place in AUTO Terminate scenario when Si pumps are secured

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# All Event # Attachment 1 Page 34 of 39 Event

Description:

Attachment 1, Automatic Action Verification Time Position pplicant'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 BOP RWST ~1. LV12 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.: 1 Scenario # All Event # Attachment 1 Page 35 of 39 Event

Description:

Attachment 1, 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 # Attachment 1 Page 36 of 39 Event

Description:

Attachment 1, Automatic Action Verification Time 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 BOP o 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-l104 and TCV-1105 - BOTH OPEN BOP Verify AFW flow to all SGs

Appendix D Operator Action Form ES-D-2 Op Test No.: 1 Scenario# All Event # Attachment 1 Page 37 of 39 Event

Description:

Attachment 1, Automatic Action Verification Time Position Applicant's Actions or Behavior Verify Containment Ventilation Isolation:

a. Containment Purge Valves - CLOSED o FCV-1 170 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 1 Page 38 of 39 Event

Description:

Attachment 1, Automatic Action Verification Time 11Position ]~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 I

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 # Attachment 1 Page 39 of 39 Event

Description:

Attachment 1, 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

ML031200432

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