ML14275A142

2014 DC Cook Nuclear Power Plant Initial License Examination Proposed Simulator Scenarios

ML14275A142
Person / Time
Site:	Cook
Issue date:	08/01/2014
From:	McNeil D R NRC/RGN-III/DRS/OLB
To:	Indiana Michigan Power Co
References
Download: ML14275A142 (38)

Text

Facility: __D C Cook______ Scenario No.: ____

1____ Op-Test No.: 2014301 Examiners: ____________________________ Operators:

_____________________________

____________________________

_____________________________

____________________________

_____________________________

Initial Conditions: 100% power Turnover: A 200 MW power decrease has been requested by the System Dispatcher. Both units are at 100% power. Event No. Malf. No.

Event Type* Event Description 1 U1_RCR16 C(ATC) TS Pressurizer Safety Valve Leak (SV45B 2gpm) 2 R Power Reduction 3 N Turbine Power Reduction 4 U1_ECP Stator Short C(ATC) TS East CCP fails on overcurrent 5 U1_RX33B I(BOP) Feedwater flow controller fails 6 U1_QTC302 175 over 5 Minutes I(ATC) Charging Letdown Header Temperature QTC

-302 fails high 7 U1_RC01A 60% M(ALL) Large break LOCA 8 U1_ED05E (Trg 1) M(ALL) Vital bus T11A Fails (On RX Trip) 9 U1_RP10A U1_RP11A U1_RP11C C(ATC) Auto/Manual SI Train A does not occur

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

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

1 Event

Description:

Safety Valve Leakage SV45

-B (2 gpm) Time Position Applicant's Actions or Behavior CREW Identify RCS Leakage US Direct entry into 1-OHP-4022-002-020, EXCESSIVE REACTOR COOLANT LEAKAGE ATC Performs the following actions, if directed:

1. Manually raises charging flow to maintain pressurizer level

. 2. Manually adjusts seal injection flow (6

-12 gpm / each RCP)

. 3. Reduces/isolates letdown flow to maintain pressurizer level

. 4. Attempts to determine RCS leak rate.

BOP Monitor Containment Pressure Determine RCS Leak Rate (~

2gpm) Check no leak into CCW Check for Primary to Secondary leak Crew Identify Source of Primary Leak and attempt to isolate source

Identify that leak is from Safety to PRT and cannot be isolated Crew 1. Check PRZ PORV and Safety valves for Leakage

2. Check PRT Conditions

3. Check Safety Valve Tailpipe Temperatures Crew May elect to Use 1

-OHP-4021-002-006 PRT Operations Attachment 4, Feed and Bleed of PRT to Reduce Pressure Or Temperature, to reduce PRT pressure US Check TS 3.4.13 Determine that the Unit has to be shutdown Contact Duty Operations Manager

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

2 Event

Description:

Power Reduction Time Position Applicant's Actions or Behavior US Directs RO to commence Rapid Power Reduction in accordance with 1-OHP 4022-001-006. RO Performs (Att. D) NORMAL BORATION

Verify charging is >

75 gpm CLOSE 1-QMO-225, EAST CCP Mini

-Flow (CCP ELO)

Place RC Makeup Blend control switch in STOP

. Place RC Makeup Blend Control Mode switch in BORATE

. Adjust BA Controller/Totalizer to the desired flow rate and amount. Place RC Makeup Blend control switch in START

. May take QRV

-303 to MANUAL/OPEN (as required) to maintain VCT level and pressure. 1-OHP 4022-001-006 Attachment D Table RO Commences power reduction:

Verify all PRZ backup heaters ON.

Ensures control rods in AUTO

. BOP Acts as peer checker for RO and verifies appropriate reactivity feedback.

RO Energize Pressurizer Backup Heaters

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

3 Event

Description:

Turbine Load Reduction Time Position Applicant's Actions or Behavior US Directs BOP to setup Turbine HMI for Load Reduction BOP Commences Turbine Power reduction:

• Places Main Turbine in MW IN

• Enters MW Load Target Into HMI

(~114 for 10%)

• Enters Ramp Rate into HMI (11.5 MW/MIN)

• Depress GO to lower turbine load (reactor power) using HMI.

BOP Monitors main electrical generator temperatures.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

4 Event

Description:

East CCP fails on overcurrent Time Position Applicant's Actions or Behavior ATC Recognizes and reports multiple annunciators on Panel #107, #108 and #109 which are indicative of a loss of charging capability.

Loss of charging flow Loss of letdown flow Loss of RCP seal injection flow Crew Identify Annunciator 109 Drop 11, EAST CCP MOTOR INSTANT TRIP in alarm US Directs RO to start the E CCP per annunciator response procedure(s):

1-OHP 4024-108 Drop 20, Charging Flow < Min Set Point 1-OHP 4024-109 Drop 21, West CCP Motor Instant Trip ATC Verify Breaker T11D7 trips.

Check Status of Letdown

Start 1-PP-50W-ALOP, West CCP Auxiliary Lube Oil Pump Verify the West CCP has a suction source available AND aligned ATC Performs the following as directed:

Starts W CCP Adjusts QRV

-200 and QRV

-251 flow to maintain RCP seal injection flow and pressurizer level.

Places normal letdown back in service in accordance with 1

-OHP-4021-003-001, Attachment 13.

ATC Restores normal letdown per 1

-OHP-4021-003-001 Attachment 13 as:

1. Places QRV

-302 in divert position.

2. Verifies orifice isolations closed (QRV

-160, 161 and 162).

3. Adjusts CRV

-470 controller to 50%. 4. Verifies open letdown isolation valves:

QCR-300 QCR-301 QRV-111 QRV-112 5. Adjusts QRV

-301controller to 50%.

6. Checks/adjusts charging flow to > 75 gpm.

7. Opens QRV

-161 or 162.

8. Adjusts QRV

-301 to maintain 160

- 350 psig.

9. Places QRV

-301 in AUTO.

10. Nulls and returns CRV

-470 controller to AUTO.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

4 Event

Description:

East CCP fails on overcurrent

11. Adjusts charging flow as required to maintain PRZ level.

12. Places PRZ level control in automatic (if desired).

13. Places QRV

-302 in normal (demineralizer) position when letdown temperature is stable.

US Refer to Technical Specifications and Technical Requirements Manual.

a. 3.5.2, ECCS

-Operating Refer to Technical Requirements Manual:

a. 8.1.1, Boration System

-Operating Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

5 Event

Description:

Feedwater Flow Controller Fails Low Time Position Applicant's Actions or Behavior Crew Recognize ANNUNCIATOR #115 Drop 53 Feedwater Controller Trouble Alarm BOP Reports malfunction and performs the immediate actions of OHP

-4022-IFR-001, Instrument Failure Response:

Verifies FRV

-220, SG 2 Feedwater Regulating Valve, controls in MANUAL.

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

US Direct crew response to alarm using 1-OHP-4024-115 BOP Recognize 1

-RU-10, Level Control 1

-FRV-220 as failed LOW Note that RU-10 (1-XL-192, Steam Generator Ome 2) Level Control System Signal Controller (flow control) has failed Note S/G level controller defaults to Manual At the panel: Determine affected controller by observing controller faceplate alarm light and/or audible alarm.

Press the Alarm Scroll key to silence the audible alarm (upper right hand corner of controller)

Press the "A" (Auto Function) key to acknowledge the alarm.

The window display adjacent to the "A" key will change to [ACK] or [CLR].

Press the R/L (Remote/Local) key or the Tag Key to return the faceplate to runtime to allow manual control if required.

Monitor Steam Generator levels and adjust as necessary.

Contact MTI to confirm failure mode and replace/repair controller.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.:

6 Event

Description:

CVCS Letdown Temperature Controller (QTC

-302) output fails HIGH. Time Position Applicant's Actions or Behavior RO Recognize and reports annunciator Panel 109 alarms which indicates a malfunction of CCW cooling to the letdown heat exchanger:

Drop 8, Letdown HX Outlet Temp High RO/BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

Places CRV

-470, Letdown Temperature Control valve, controller to MANUAL. Opens CRV

-470 and restores letdown temperature to normal.

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

NOTE: Since Indicated letdown temperature exceeds 185F, then crew may :

Isolate normal letdown Minimize charging flow Establish excess letdown RO Verifies letdown flow diverted to RC Filter Identifies that QTC

-302 has failed high

Determines condition NOT due to actual temperature US Initiates action to have MTI investigate problem with letdown temperature controller/indicator.

NOTE: QRV-302 Letdown Demineralizer Divert Valve will reposition based on QTS

-301. Diverts past Demins at 143F. This is a separate switch from the Controller & Instrument that has failed (QTC

-302).

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.: 7, 8, 9 Event

Description:

Large break LOCA Vital bus T11A Fails Auto SI Train A does not occur Time Position Applicant's Actions or Behavior RO/US Acknowledge Ann. 122, Drop 83 ICE CONDENSER DOORS OPEN.

Determines that a loss of reactor coolant is occurring based on the following:

Pressurizer Pressure and level change.

Containment radiation monitoring trend.

Containment pressure rise.

Containment sump level rise.

US Directs RO/BOP to verify/trip the reactor and perform the immediate actions of E-0, Reactor Trip or Safety Injection.

RO/BOP Performs the immediate actions of E

-0: Checks reactor trip.

Checks turbine trip.

Checks power to AC emergency buses. Notes : Vital Bus T11A De

-energized Checks safety injection status.

US Ensures immediate actions of E

-0 are completed US Directs subsequent actions of E

-0. RO/BOP Reviews E

-0 Foldout Page Criteria.

CREW Determines that Containment Pressure requires Steamline Isolation, Phase B Isolation, and CTS Actuation.

Verifies Steamlines Isolated.

Verifies CTS Actuation.

Aligns Lower Cont. Vent Fans.

CREW Manually stops all Reactor Coolant Pumps (RCPs) due to Phase B Isolation and/or RCS pressure lowering below 1300 psig.

BOP Manually controls AFW flow to maintain SG narrow range levels 14%

- 50% once one SG narrow range level is > 14%.

RO Reports that the E CCP is not running due to a previous failure RO/BOP Performs manual actions of E

-0 Attachment A (for Containment Phase A).

Crew Manually Aligns Safety Injection

- Train A.

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.: 7, 8, 9 Event

Description:

Large break LOCA Vital bus T11A Fails Auto SI Train A does not occur Critical Task

1. 1 -AND- Manually align valves to establish at least one train of isolation CREW Completes all actions of E

-0 through step 19 (Check If RCS Is Intact).

US Announces transition to E

-1, Loss Of Reactor Or Secondary Coolant (at step 19 of E-0). Note: The Crew may transition to OHP

-4023-ES-1.3, Transfer to COLD Leg Recirculation if the RWST is low enough prior to the E

-1 transition point (See Page 11 For actions).

Note: The Crew may momentarily enter 1

-OHP-4023-FR-P.1, Response To Imminent Pressurized Thermal Shock Condition, on a Red Path, then exit once RHR flow is verified.

RO/BOP Reviews E

-1 Foldout Page Criteria.

US Directs actions of E-1, Loss Of Reactor Or Secondary Coolant.

BOP Maintains SG narrow range levels 20%

- 50%. BOP Performs the following:

Resets Containment Isolation Phase A.

Notifies Chemistry to sample SGs for activity.

US Checks if SI Termination Criteria is MET:

RCS Subcooling >40F. Secondary Heat Sink (AFW Flow >240x103 or SG >14% [28% ADVERSE]).

RCS Pressure rising or stable.

Pressurizer Level >21% [25%ADVERSE].

US Check for CTS termination Critieria RCS pressure is <300 psig

- Wait for 24 Hours RO/BOP Performs the following as directed:

1. Resets both trains of Safety Injection.

2. Stops running Emergency Diesel Generators (EDG).

3. Dispatches operator to secure EDG jacket water pumps.

Applicants actions or behavior associated with ES

-1.3, Transfer To Cold Leg Recirculation

. US Announces transition to ES

-1.3, Transfer To Cold Leg Recirculation when RWST level < 30% per:

Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Crews XX Scenario No.:

01 Event No.: 7, 8, 9 Event

Description:

Large break LOCA Vital bus T11A Fails Auto SI Train A does not occur E-0, Foldout Page, Criteria 3 E-1, Foldout Page, Criteria 5 E-1, Step 13 US Directs actions of ES

-1.3, Transfer To Cold Leg Recirculation.

RO/BOP Resets both trains of Safety Injection.

RO/BOP Checks CCW return flow on each RHR Hx at 3000

-3500 gpm.

(may only perform for the East CCW HX)

RO/BOP Checks the following prior to switching over to cold leg recirc:

RWST level < 20% Cntmt water level > MIN RECIRC LEVEL US/RO Critical Task

1. 2 Directs/Performs switchover as follows:

NOTE: If RWST level < 9% then stop CCPs and SI pumps.

Stops and locks out East CTS pump Stops and locks out East RHR pump Checks East CTS and East RHR pumps stopped Initiates valve closure:

IMO-310, East RHR pump suction IMO-215, East CTS pump suction from RWST Stops and locks out West CTS pump Stops and locks out West RHR pump (OOS)

Checks West CTS and West RHR pumps stopped Initiates valve closure: IMO-320, West RHR pump suction IMO-225, West CTS pump suction from RWST Restore control power to l

-ICM-305, recirc sump to East RHR/CTS pumps Check 1-ICM-305 open 1-IMO-215 - Full Closed 1-IMO-310 - Full Closed Open 1-ICM-305 and check full open Start East RHR pump and East CST pump (if previously running)

Terminate Scenario when RHR/CTS pump is restarted.

Page 1 of 11 Facility: __D C Cook______ Scenario No.: ____

3____ Op-Test No.: 2014301 Examiners: ____________________________ Operators:

_____________________________

____________________________

_____________________________

____________________________

_____________________________

Initial Conditions: ___

EDG CD has been run following mechanical maintenance. The run is complete and the EDG is ready to be shutdown and placed in standby.

Turnover:

1-OHP-4021-032-001CD Attachment 2 is complete to step 4.4.2 and the diesel generator is ready to be shut down. Perform Step 4.4.3 through preparation for Restoring for OPERABILITY. U1 is at 92% power following turbine valve testing.

Event No. Malf. No.

Event Type* Event Description 1 N Secure the CD D/G 2 U1_NI10B 200 over 1 min I(ATC) TS Power range detector (NI

-42) fails high 3 R Power increase to restore power 4 U1_FW40A 100 C(BOP) Condenser Level Control failure (100%)

5 U1_BLP131 0 over 30sec I(ATC) TS Steam generator #3 BLP131 controlling level channel fails low 6 U1_MS02C 50% Major Steam line #3 break inside containment 7 U1_RP01A U1_RP01B C(ATC) Reactor trip failure (ATWS), Rods Drop when MG sets de

-energized 8 U1_RP09A U1_RP09B C(BOP) Feedwater isolation does not occur in automatic 9 U1_FW48C C(BOP) TDAFW pump does not start in auto

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

Appendix D Required Operator Actions Form ES-D-2 Page 2 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.:

1 Event

Description:

Secure the CD D/G and place in standby Time Time Time US Directs actions of 1-OHP-4021-032-001CD Attachment 2, DG1CD Operation On Safeguards Buses.

US Directs the following actions to realign condensate system: Secure EDG CD.

BOP Performs the following to EDG CD as directed:

1. Opens the following breakers:

T11D8 T11C3 2. Adjusts diesel speed using DG1CD GOVENOR CONTROL to 60 Hz.

3. Verifies DG1CD Start Gen & 69/4KV Voltmeter Sel switch in

- OFF. 4. Returns to Procedure Body Step 4.6:

CUE: Step 4.1.7 and 4.1.8 were not performed

5. Verifies T11D8, T11C3, and DGTCD

- OPEN 6. Verifies diesel UNLOADED for approximately 2 minutes

7. Stops DG1CD by placing DG1CD Stop

-Run control switch to STOP

8. Verifies green target at DG1CD Stop-Run control switch

Appendix D Required Operator Actions Form ES-D-2 Page 3 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 2&3 Event

Description:

Power range detector (NI

-42) fails high Time Position Applicant's Actions or Behavior ATC Recognizes and reports annunciators on Panel 110 which are indicative of a NI instrument failure (Drops 11, 13, 18, & 19).

ATC Reports malfunction and performs the immediate actions of OHP

-4022-IFR-001, Instrument Failure Response:

Checks for no turbine runback Ensures control rods are in manual with no rod motion US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

US Enters and directs actions of 1

-OHP-4022-012-003, Continuous Control Bank Movement procedure.

RO Performs the following as directed:

Checks for no turbine runback Ensures control rods are in manual with no rod motion Checks rod position above low

-low rod insertion limit Checks axial flux difference (AFD) within target band Initiates restoration of equilibrium conditions using either: Control rod movement Turbine load adjustment Identifies failed power range channel US Enters and directs actions of 1

-OHP-4022-013-004, Power Range Malfunction procedure.

Appendix D Required Operator Actions Form ES-D-2 Page 4 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 2&3 Event

Description:

Power range detector (NI

-42) fails high Time Position Applicant's Actions or Behavior ATC/BOP Performs the following as directed:

Verify Control Rods

- MANUAL Place Rod Stop Bypass Selector In Failed Channel Position Remove Affected Channel From Service By Placing Selector Switches To Failed Channel Position:

Comparator Channel Defeat Selector Upper Section Detector Current Comparator Defeat Selector Lower Section Detector Current Comparator Defeat Selector Power Mismatch Bypass Selector Check The Following Interlocks Are In The Required State For Existing Conditions:

P-7 P-8 P-10 Check AFD

- WITHIN TARGET BAND Verify Recorder Inputs

- SELECTED TO AN UNAFFECTED CHANNEL POSITION:

Delta-T Overtemperature Delta

-T Caution - Control Rods should not be placed in automatic until at least 5 minutes have elapsed after placing Power Mismatch Bypass Selector to failed channel. Return Power to Normal Place Control Rods In AUTOMATIC If Applicable US Directs actions to trip bistables associated with NI

-42 Power Range Malfunction per Attachment D of 1

-OHP-4022-013-004. US Refers to Tech Specs:

3.3.1 RTS Instrumentation (Table 3.3.1

-1, Functions 2a,2b, 3, 6 18c&d Conditions C, D, & L)

P-8 & P-10 must be verified in Correct Condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of channel failure.

Appendix D Required Operator Actions Form ES-D-2 Page 5 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.:

4 Event

Description:

Condenser Level Control failure (100%)

Time Position Applicant's Actions or Behavior Crew Respond to ANNUNCIATOR #116 RESPONSE: CONDENSATE:

Drop 2, Condenser A Hotwell Level Low Drop 12, Condenser B Hotwell Level Low Drop 22, Condenser C Hotwell Level Low US Direct BOP to Take Actions per 1-OHP-4024-116 Drop 2, 12, 22 BOP IF Hotwell Level Controller not operating properly, THEN control level manually.

Verify 1-CRV-155, Condensate Excess Letdown Valve and 1-CMO-155 Bypass Valve

- CLOSED. Throttle open 1-CMO-55, Cndst Makeup Valve Bypass, as required to maintain low level clear.

Appendix D Required Operator Actions Form ES-D-2 Page 6 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.:

5 Event

Description:

Steam generator #3 controlling level channel fails low Time Position Applicant's Actions or Behavior Crew Respond to ANNUNCIATOR #114 RESPONSE: STEAM GENERATOR 3 AND 4:

Drop 3: STEAM GEN 3 WATER LVL LOW DEVIATION Drop 4: STEAM GEN 3 WATER LEVEL LOW Drop 13: STEAM GEN 3 SF > FWF FLOW MISMATCH BOP Reports malfunction and performs the immediate actions of OHP

-4022-IFR-001, Instrument Failure Response:

Verifies FRV

-230, SG 3 Feedwater Regulating Valve, controls in MANUAL.

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

BOP Restore Steam Generator Narrow Range Level using Manual Control of Feedwater Regulating Valve 1

-FRV-230 Check Steam Generator Narrow Range Level

- Stable OR Trending to 44% :

US Enters and directs actions of 1-OHP-4022-013-013, Steam Generator Level Instrument Malfunction US Refers to the following TS:

• TS 3.3.1 RTS Instrumentation (Table 3.3.1

-1, Function 14

- Cond D).

• TS 3.3.2 ESFAS Instrumentation (Table 3.3.2

-1, Function 5b & 6c

- Cond D). Enters action statement that requires bistables to be tripped within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. US Direct actions to trip bistables per Attachment C

-2 of 1-OHP-4022-013-013.

Appendix D Required Operator Actions Form ES-D-2 Page 7 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 6, 7, 8, 9 Event

Description:

Steam line #3 break inside containment, Reactor trip failure (ATWS), Feedwater isolation does not occur in automatic, TDAFW pump does not start in auto Time Position Applicant's Actions or Behavior Crew Recognize containment pressure increase, and reactor trip requirements.

US Directs RO to Perform Reactor trip Enter 1-OHP-4023-E-0: Reactor Trip ATC Recognizes and reports failure of reactor to manually trip US Directs actions of FR

-S.1, Response to Nuclear Power Generation/ATWS:

ATC Critical Task #1 Performs the immediate actions of FR.S-1: 1. Checks reactor trip Automatically

/Manually insert control rods(must Insert Negative Reactivity through Inserting Control Rods or Emergency Boration)

BOP Performs the immediate actions of FR.S

-1: 1. Manually actuate AMSAC

2. Checks check Turbine Trip 3. Check AFW pumps running MDAFPs - Both Running TDAFP - did not start in automatic

- manually starts the TDAFP US Ensures immediate actions of FR.S

-1 are completed ATC Critical Task #1 Initiate Emergency Boration of RCS(must Insert Negative Reactivity through Inserting Control Rods or Emergency Boration)

CCPs - at least one running Initiate emergency boration o Start both boric acid transfer pumps in FAST speed o Open 1-QMO-41-. Emergency boration to CCP suction valve o Check emergency boration flow - GREATER THAN 44 GPM Check PRZ pressure LESS THAN 2335 PSIG Check Containment Isolation Valves Closed:

Appendix D Required Operator Actions Form ES-D-2 Page 8 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 6, 7, 8, 9 Event

Description:

Steam line #3 break inside containment, Reactor trip failure (ATWS), Feedwater isolation does not occur in automatic, TDAFW pump does not start in auto Time Position Applicant's Actions or Behavior Crew Check Containment Isolation valves VCR

-101-107, VCR-201-207 Closed Check SI Status

- Actuation status light

- NOT LIT As time permits, perform Steps 5 through 13 of E

-0 US Check if the following trips have occurred:

Reactor Trip

- Reactor Trip Breakers, Bypass breakers, Rod drive MG set output breakers Turbine Trip Dispatch Operator to Locally Trip Reactor CREW Check if Reactor is Subcritical

- Go to step 20 Continue Boration To Maintain Adequate Shutdown Margin During Subsequent Recovery Actions:

Determine shutdown margin using 1

-OHP-4021-001-012, Determination Of Reactor Shutdown Margin Return To Procedure And Step In Effect E

-0 US Transition to OHP

-4023-E-0 and direct actions Check Reactor Trip Check Turbine Trip Check Power to AC Busses

- At least ONE Energized AC Emergency Busses

- ALL Energized Check SI Status

- Status Light LIT BOTH CCP Leakoff valve "Safety Injection Signal" white lights

- LIT BOP Check Main Steamline Isolation NOT Required

- Verify all SG stop valves are closed ATC Check CTS actuated Check containment isolation Phase B is actuated Stop all RCPs Place lower containment vent Unit fans in OFF 1-HV-CLV-lA and 1-HV-CLV-3A 1-HV-CLV-2A and 1-HV-CLV-4A 1-HV-CLV-1B and 1-HV-CLV-3B 1-HV-CLV-2B and 1-HV-CLV-4B 5) Place control rod drive mech fans in STOP:

1-HV-CRD-3A 1-HV-CRD-3B 1-HV-CRD-4A 1-HV-CRD-4B Appendix D Required Operator Actions Form ES-D-2 Page 9 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 6, 7, 8, 9 Event

Description:

Steam line #3 break inside containment, Reactor trip failure (ATWS), Feedwater isolation does not occur in automatic, TDAFW pump does not start in auto Time Position Applicant's Actions or Behavior Crew Implement Attachment A (Page 27) While Continuing With This Procedure Check If Ruptured SG Is Suspected: SG narrow range levels

- NONE rising in an uncontrolled manner Check AFW pumps running

- MDAFPs - both running, TDAFP

- running Check Total AFW flow

- GREATER THAN 240x10 3 PPH Minimize Unnecessary RCS Cooldown:

Check SG narrow range level Greater than 14%

Control feed flow to maintain SG narrow range level between 14% and 50% Check AFW Pump Discharge valves

- OPEN or Throttled Check FW Isolation Main feed pumps

- BOTH TRIPPED Feed pump discharge valves

- CLOSED Feedwater regulating valves

- CLOSED Feedwater isolation valves

- CLOSED Check RCS Temperature:

No RCPs running

- RCS Cold leg temperatures stable at of trending to 547F RNO: Stop dumping steam Verify 1-DRV-407 CLOSED If cooldown continues, then control total feed flow If cooldown continued, then perform the following:

Trip all SG stop valves closed Verify SG stop valve dump valves are closed Check PRZ PORVs ad Spray Valves CLOSED PORV block valves at least one energized Block valves at least one open Check IF RCPs Should Be Stopped:

RCS Pressure less than 1300 PSIG ECCS pumps at least one running Stop all RCPs Check If SG Secondary Pressure Boundaries are Intact:

Pressure in all SGs NO SG pressure lowering in an uncontrolled manner NO SG completely depressurized RNO: Go to E

-2 Appendix D Required Operator Actions Form ES-D-2 Page 10 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 6, 7, 8, 9 Event

Description:

Steam line #3 break inside containment, Reactor trip failure (ATWS), Feedwater isolation does not occur in automatic, TDAFW pump does not start in auto Time Position Applicant's Actions or Behavior US Crew Announces entry into E

-2 Check SG Stop Valves CLOSED Check SG Stop Valve Dump Valves CLOSED Check if any SG secondary pressure boundary is intact Pressure in all SGs

- Any stable or rising Identify Faulted SG Check pressure in all SGs Any SG Pressure Lowering in an Uncontrolled Manner or Any SG Completely Depressurized Isolate Faulted SG:

Check feedwater valves for faulted SG CLOSED Check AFW valves for faulted SG CLOSED Check TDAFP steam supply valve for faulted SG CLOSED Check PORVs for faulted SG CLOSED Check blowdown isolation valve for faulted SG CLOSED Place 1-DRV-407, SG stop valves drain valve in CLOSED Check 1-DRV-407 CLOSED Check Steam line warming valves CLOSED Check CST Level Greater Than 15%

Check Secondary Radiation:

Reset containment isolation Phase A if Necessary Direct Chemistry to periodically sample all SGs for activity Check SG PORV radiation monitors Secondary radiation

- NORMAL Check If ECCS Flow Should Be Reduced RCS subcooling based on core exit TCs

- Greater than 40F Secondary heat sink:

Total feed flow to intact SGs

- Greater Than 240x10 3 PPH or Narrow range level in at least one intact SG

- Greater Than 14%

RCS pressure

- Stable or Rising PZR level

- Greater than 21%

Go to ES-1.1 Appendix D Required Operator Actions Form ES-D-2 Page 11 of 11 Op-Test No.: Crews XX Scenario No.:

03 Event No.: 6, 7, 8, 9 Event

Description:

Steam line #3 break inside containment, Reactor trip failure (ATWS), Feedwater isolation does not occur in automatic, TDAFW pump does not start in auto Time Position Applicant's Actions or Behavior US Transition to OHP

-4023-ES-1.1 SI Termination and Direct Actions US Direct operator to Reset SI SI will NOT Reset with trip Breakers Closed Implement SUP-016, Resetting SI in the SSPS Cabinets, while continuing with Step 2.

CREW Stop CCP Reestablish Air to Containment Verify Spray valves closed Check Air Pressure Open Containment Air Supply Valves Check RCS Pressure

- Rising Isolate BIT Verify QMO

-225 & 226 Open Close IMO

-255 & IMO

-256 Close ICM

-250 and ICM

-251 Establish Charging Flow Stop SI Pumps Stop RHR Pumps Verify RCS Pressure Stable Maintain RCS Temperature Restore Letdown per Sup 15 TERMINATE SCENARIO

Page 1 of 7 Facility: __D C Cook______ Scenario No.: ___

4_____ Op-Test No.:

2014301 Examiners: ____________________________ Operators:

_____________________________

____________________________

_____________________________

____________________________

_____________________________

Initial Conditions: 12% power, main generator has just been paralleled.

Turnover: The unit is at 12% power with the generator has just been paralleled to the grid. The unit was down powered to fix leak on the weld for FTR

-258, FW Disch Header Temperature tap.. The work is complete and the plant is returning to 100% power. Procedure 1

-OHP-4021-001-006, Power Escalation is complete up to step 4.2

8. Raise Power at 10%/hour to ~29%. Event No. Malf. No.

Event Type* Event Description 1 N Control Feed Flow In Manual 2 R Raise Power 3 U1_MPC253 to 740 I(ATC) Turbine impulse pressure instrument (MPC

-253) fails HIGH 4 U1_MPP222 1500 C(BOP) MPP 222 SG #2 PORV Pressure Channel 5 U1_FPC_250 A to 1 over 2 min I(BOP) Main Feedwater discharge pressure (FPC

-250A) fails Low 6 U1_RC10D 10% over 5 Min Major Small break LOCA in containment (150 gpm with a 5 min ramp) 7 U1_RP10A U1_RP10B I(ATC) Auto SI fails 8 U1_TC02 U1_TC03 C(BOP) Main turbine fails to trip 9 U1_RD0435 U1_RD0441 C(ATC) Two rods fail to Drop (H4 & H6) 10 U1_ECP Stator Short C(ATC) East CCP trips on overcurrent 3 minutes after the RXtrip * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Required Operator Actions Form ES-D-2 Page 2 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.: 1&2 Event

Description:

Control Feedwater Flow in Manual and Raise Power Time Position Applicant's Actions or Behavior US Direct the BOP to SG Levels ~40% to 48% using Manual Control of FRV210-240 and Main FW Pump Speed/DP BOP Adjust FRV210

- 240 to Maintain SG levels within Designated band Adjust Main FW Pump Speed / DP target to ensure adequate FW Discharge to SG DP Place FW Regulating Valves in Auto if FRVs are open far enough RO Calculates the dilution required per OHP-4021-005-002, Attachment 9, Boration or Dilution Volume Determination.

RO Briefs crew on reactivity plan for power escalation.

US Reviews / concurs with reactivity plan.

US Directs RO to commence Power Escalation in accordance with OHP-4021-001-006, Power Escalation (at step 4.77)

RO Performs DILUTION (batch add OR Continuous

): Place RC Makeup Blend control switch in STOP Place RC Makeup Blend Control Mode switch in DILUTE or ALT DILUTE Adjust PW to the desired flow rate and/or amount.

May close QRV

-451 if aligning to CCP Suction Only Place RC Makeup Blend control switch in START May take QRV

-303 to Manual and Open as required to maintain VCT Level and Pressure.

RO Commences escalation:

Raises turbine load (reactor power) using the DCS HMI.

Maintains Tavg/Tref deviation within limits by dilution and turbine load adjustments.

Ensures Axial Flux Difference (AFD) is maintained within target band by manual control rod movement as needed.

RO RO verifies appropriate reactivity feedback.

Appendix D Required Operator Actions Form ES-D-2 Page 3 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.:

3 Event

Description:

Turbine impulse pressure instrument (MPC

-253) fails HIGH Time Position Applicant's Actions or Behavior US BOP Assure plant is stable then direct RO or BOP to review Annunciator Response Procedures.

Respond to ANN Panel 111 Drop 20, Tavg Low Tavg<Tref Deviation Respond to ANN Panel 112 Drop 6, Main Turbine DCS Trouble RO/BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

US Identify failed MPC

-253 failed HIGH and go to OHP

-4022-013-016, Turbine First Stage Impulse Pressure Instrument Malfunction.

BOP Check For Failed Turbine First Stage Impulse Pressure Instrument: Notify Shift Manager of the instrument failure.

Channel 1, 1

-MPC-253 - Indicating High

, Go To RNO Perform the following:

Place AMSAC Bypass/Test Switch in Bypass/Test 101-AM-2 If Operating Steam Dumps in Tavg Mode

- Place steam dump control selector switches in OFF Verify P-13 Status

- PROPER for CURRENT PLANT CONDITIONS Record Time P

-13 Interlock Status verified US Initiates actions to trip bistables for MPC

-253 failure per Attachment A of 1

-OHP 4022-013-016. US Refers to ITS LCO:

1. 3.3.1 Reactor Trip System Instrumentation (Table 3.3.1

-1, Function 18e

- Cond L 2. 3.3.2 ESFAS Instrumentation (Table 3.3.2

-1, Function 4e

- Cond D) 3. TRM 8.3.6 ATWS Mitigation System Actuation Circuitry (AMSAC)

Appendix D Required Operator Actions Form ES-D-2 Page 4 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.:

4 Event

Description:

SG #22 PORV controller fails OPEN (50%) and will not Close in Manual Time Position Applicant's Actions or Behavior BOP Recognize and reports Annunciator Panel #114, Drop 24, 1

-MRV-243 OP OR HSD1 PANEL OVERRIDE alarm that indicates SG #4 PORV (MRV-243) has opened.

Panel 113 Drop 14 May also alarm.

RO/BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

Place SG PORV #4 in Manual and Closes #4 PORV. US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

Direct operator actions to determine cause, reclose SG #4 PORV, and monitor Reactor Power.

US Enters and directs actions of 1

-OHP-4022-013-012, Steam Generator Pressure Instrument Malfunction procedure.

BOP Performs the following actions as directed:

1. Checks SG PORVs closed.

2. Reports MPP

-242 has failed high.

3. Returns MFP P controller to auto (if placed in manual).

US Refers to TSs / TRM:

• TS 3.3.2 ESFAS Instrumentation (Table 3.3.2

-1, Function 1.e (1& 2) & 4.d - all Condition D)

• Trip bistables in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />

• TS 3.7.4, SG PORVs (Note: Only Manual Ops Required)

- N/A

• TRM 8.3.8. Radiation Monitoring Instrumentation (Table 8.3.8

-1, Function 2.b

- Condition C)

• Declares MRA

-1602 inoperable

• Restore in 7 days US Initiates actions to trip bistables associated with MPP

-242 Steam Generator Pressure Instrument Failure per Attachment D

-3 of 1-OHP-4022-013-012.

Appendix D Required Operator Actions Form ES-D-2 Page 5 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.:

5 Event

Description:

Main Feedwater discharge pressure (FPC

-250A & B) fails HIGH Time Position Applicant's Actions or Behavior BOP Recognizes and reports Ann.115 Drop 42, FPT DCS Trouble caused by FW DCS Screen Alarm Drop C

-16 m2C_ALM2016 FPC

-250A (B)

- MFP DISCH HDR PRESS

- XMTR DEVIATION and indications of a failure affecting main feedwater to all steam generators (SGs):

Main FW Pump Disch Pressure All SG levels raising All feedwater regulating valves closing Main feedwater pumps speed raising RO/BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

Verifies/Places both Main FW Pumps to speed control in manual and lowers output (MFW Pump Speed) to restore DP and match feedwater flow with steam flow and restore SG levels to program.

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

CREW Identifies that Main Feedwater Pump Discharge Pressure Transmitter FPC-250A has failed low.

BOP Verify the failed channel disabled and restore FWP Delta

-P. Monitors/adjusts MFP differential pressure to restore SG levels to program. RO Monitors nuclear power during feedwater transient.

Appendix D Required Operator Actions Form ES-D-2 Page 6 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.: 6,7,8,9,10 Event

Description:

Small break LOCA in containment (150 gpm with a 5 min ramp), Auto SI fails, Main Turbine Fails to Trip, Two Rods Fail to Drop, East CCP trips on overcurrent Time Position Applicant's Actions or Behavior CREW Acknowledges Ann. Panel 122, Drop 83, ICE CONDENSER INLET DOORS OPEN, alarm and/or RMS PPC Alarms on Panel 111 and determines that a loss of reactor coolant is occurring based on the following:

Pressurizer and VCT level change Charging and letdown flow mismatch Containment radiation monitoring trend Containment pressure rise Containment sump level rise US ATC Direct implementation of 1

-OHP-4022-002-020, EXCESSIVE REACTOR COOLANT LEAKAGE Monitor PRZ Level Maintain PRZ level by adjusting 1

-QRV-251 and 1

-QVR-200 as necessary Reduce or isolate letdown flow as necessary to maintain PZR level Close letdown valves Start second CCP If level cannot be maintained Trip the reactor and go to E

-0 US Directs entry into E

-0 ATC/BOP Performs the immediate actions of E

-0: Checks reactor trip.

( Announces that 2 rods not fully inserted.

) Checks turbine trip.

- (Auto Failed)

Manually trips the main turbine Acutate AMSAC Isolate Main Steam Lines Checks power to AC emergency buses.

Checks safety injection status.

US Ensures immediate actions of E

-0 are complete Directs subsequent actions of E

-0 Appendix D Required Operator Actions Form ES-D-2 Page 7 of 7 Op-Test No.: Crews XX Scenario No.:

04 Event No.: 6,7,8,9,10 Event

Description:

Small break LOCA in containment (150 gpm with a 5 min ramp), Auto SI fails, Main Turbine Fails to Trip, Two Rods Fail to Drop, East CCP trips on overcurrent 3 minutes after the trip Time Position Applicant's Actions or Behavior ATC Announces that 2 rods not fully inserted.

Manually trips the reactor

Announces East CCP trip May reset and attempts one restart.

Start West CCP Crew Manually Actuates Safety Injection Crew Completes all actions of E

-0 through step 19 (Check If RCS Is Intact). US Announces transition to E

-1, Loss Of Reactor Or Secondary Coolant (at step 19 of E

-0). Crew Reviews E

-1 Foldout Page Criteria.

Check if RCPs should be stopped Check If SG Secondary Pressure Boundaries Are Intact:

Check Intact SG Levels Check Secondary Radiation

Check PRZ PORVs and Block Valves US Checks if SI Termination Criteria is MET:

RCS Subcooling >40F. Secondary Heat Sink (AFW Flow >240x103 or SG >14% [28%

ADVERSE]).

RCS Pressure rising or stable.

Pressurizer Level >21% [25%ADVERSE].

NOTE: May transition to ES

-1.1 SI Termination based on the Small Leak Size CREW Check if Containment Spray Should be Stopped

- Check If RHR Pumps Should Be Stopped

- Check RCS And SG Pressures:

Check If DGs Should Be Stopped:

Page 1 of 9 Facility: __D C Cook______ Scenario No.: ___

5_____ Op-Test No.:

2014301 Examiners: ____________________________ Operators:

_____________________________

____________________________

_____________________________

____________________________

_____________________________

Initial Conditions: 79% power, Power reduction in progress.

Turnover: Unit is stable at 79% power and continuing a power reduction to take the unit off line. Currently performing Step 4.11.1 of 02

-OHP 4021.001.003, Power Reduction. Remove the North Condensate Booster pump from service

- was run for engineering data collection.

Event No. Malf. No.

Event Type* Event Description 1 N Remove North Condensate Booster from service 2 U1_QLC451 To 0% I(ATC) TS VCT level instrument (QLC

-451) fails low 3 R Power reduction 4 U1_MFC140 to 0 I(BOP) TS Steam flow channel (MFC

-140) fails low (Controlling) 5 U1_RCR20 to 5 C(ATC) Pressurizer PORV (NRC

-153) leaking (requires isolation)

- 5% open NOTE: Time compression may be used as the procedure requires a 15 minute wait time after unisolating each PORV.

6 U1_RC23D to 30 over 10 min Major Reactor Trip with S/G

1. 4 tube rupture (600 gpm (60%) ramp to 30% over 10 minutes

- raise to 60% on trip

) 7 U1_MS06D to 80% C(BOP) Steam generator safety valve (SV 3-4) opens

- 80% * (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

Appendix D Required Operator Actions Form ES-D-2 Page 2 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.:

1 Event

Description:

Shutdown the North Condensate Booster Pump Time Position Applicant's Actions or Behavior US Directs actions of 1

-OHP-4021-054-001, Attachment 2, Operation of Hotwell (HW) and Condensate Booster (CB) Pumps to stop the North CB pump

. BOP Performs the following to shutdown the CB pump as directed:

1. Verifies the following switches in NEUTRAL:

Standby Hotwell pump Standby TACW pump

2. Stops the North CB pump NOTE: Ann. 116, Drop 73

, CNDST BOOSTER PUMP DISCH PRESSURE LOW may annunciate during this evolution.

US Directs the following actions to realign condensate system:

Stop the North CB pump Notify chemistry of condensate system configuration change.

Appendix D Required Operator Actions Form ES-D-2 Page 3 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.:

2 Event

Description:

VCT level instrument (QLC

-451) fails low Time Position Applicant's Actions or Behavior Crew Acknowledge ANNUNCIATOR #109 RESPONSE: BORIC ACID, Drop 49 alarm, VOLUME CONTROL TANK LEVEL LOW RO/BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

Check VCT Level Channels

- BOTH LESS THAN 78%,

Check Auto VCT Makeup - NOT IN PROGRESS Place Reactor Coolant Makeup Blend Control to STOP/NEUTRAL:

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

US Directs entry into 1

-OHP-4022-013-017 ATC Check 1-QLC-451, VCT level channel failed

- Full scale Low 1-QLC-451 NOT trending with VCT pressure 1-QLC-452 reading expected VCT level Initiate makeup per 1

-OHP-4021-005-002, Operation of the Unit 1 Boric Acid Blender. If needed Verify pressurizer level control functioning properly.

Operate Boric Acid Blender In Manual As Required To Maintain VCT Level Greater Than 15% on 1

-QLC-452 US Refers to the Technical Requirements Manual (TRM):

TRM 8.1.1 Boration System

- Operating Condition A.1

- Restore to operable within 72 Hours (RWST to CVCS auto swapover)

Appendix D Required Operator Actions Form ES-D-2 Page 4 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.:

3 Event

Description:

Power reduction Time Position Applicant's Actions or Behavior RO Calculates boric acid addition per OHP

-4021-005-002, Attachment 9, Boration or Dilution Volume Determination.

RO Briefs crew on reactivity plan for power reduction.

US Reviews / concurs with reactivity plan.

US Directs RO to commence Power Reduction in accordance with OHP-4021-001-003. RO Energize Pressurizer Backup Heaters RO Performs BORATION:

Place RC Makeup Blend Control Switch in STOP.

Place RC Makeup Blend Control Mode Selector Switch in BORATE. Set desired batch on BA Flow Totalizer.

Adjust BA Flow Ctrl (RU

-33) to desired flow.

Place RC Makeup Blend Control Switch in START.

RO Commences power reduction:

• Lowers turbine load (reactor power) using HMI.

• Maintains Tavg/Tref deviation within limits by boration and turbine load adjustments.

• Ensures Axial Flux Difference (AFD) is maintained within target band by manual control rod movement as needed.

BOP/RO BOP acts as peer checker for RO during blender operations and RO verifies appropriate reactivity feedback.

BOP Monitors main electrical generator temperatures.

Appendix D Required Operator Actions Form ES-D-2 Page 5 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.:

4 Event

Description:

SG#4 Steam flow channel 1 (MFC

-140) fails low (Controlling)

Time Position Applicant's Actions or Behavior BOP Recognizes and reports annunciators on Panel #114 (Drops 41, 43, and 32) which are indicative of a steam flow instrument failure.

BOP Reports instrument malfunction and performs the immediate actions of OHP-4022-IFR-001, Instrument Failure Response:

Determine SG 4 level is lowering and that its Feedwater Regulating Valve (FRV

-240) is not responding as expected.

Notify US and takes manual control of FRV

-240. MANUAL. Stabilize SG 4 level in manual.

US Enters and directs actions of OHP

-4022-IFR-001, Instrument Failure Response procedure.

US Enters and directs actions of 1

-OHP-4022-013-014, Steam Flow Instrument Malfunction procedure.

BOP Performs the following actions as directed:

1. Restores SG 4 level using MANUAL control of FRV

-240. 2. Places MFP P controller in MANUAL and maintains pressure.

3. Reports MFC

-140 has failed high.

4. Places 1-FS-542C selector switch in channel 2 position.

5. Nulls and returns FRV-240 controller to AUTO.

6. Returns MFP P controller to AUTO.

US Refers to the following Tech Specs (TS):

TS 3.3.1 RTS Instrumentation (Table 3.3.1

-1) Condition A

- Refer to Table Function 15 Condition D

- Trip Bistables in 6 Hours TS 3.3.2 ESFAS Instrumentation (Table 3.3.2

-1) Condition A

- Refer to Table Function 4e Condition D

- Trip Bistables in 6 Hours US Initiates actions to trip bistables associated with MFC-140 failure per Attachment D

-1 of 1-OHP-4022-013-014.

Appendix D Required Operator Actions Form ES-D-2 Page 6 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.:

5 Event

Description:

PRZ PORV (NRV

-153) Leak by (5 gpm) Time Position Applicant's Actions or Behavior RO Recognizes Annunciators on Panel 1 08, Drop 24, PRZ PORV Disch Temp Hi, and Drop 31, PRZ PRT Press Hi/Lo, which are indicative of PORV leakage.

Note: Procedure OHP-4022-002-009 is written to identify the leaking valve and isolate it. The crew may determine that the Acoustic Monitor provides indication as to which valve is leaking and so may directly isolate the applicable PORV.

Time compression may be used as the procedure requires a 15 minute wait time after unisolating each PORV. If required, provide the crew that indications remain the same for PORV NRV-151 & NRV

-152. US Enters and directs operator action s per OHP-4022-002-009, Leaking PORV.

RO Performs actions as directed by US:

Closes PORV Block Valves as directed.

Reopens Block Valves and Monitor s PRT/Temperatures to determine which PORV is leaking. Monitors PORV Discharge Temperatures

. Monitors PRT.

Place PORV in Close when identified as leaking PORV.

Note: The crew may elect to implement OHP-4022-002-020, Excessive Reactor Coolant Leakage.

The Crew may perform actions of OHP

-4021-002-006, PRT Operations, to restore the PRT conditions if required.

US May Direct operator action per OHP-4022-002-020, RCS Leakage:

Check PRZ Level and adjust Charging as required.

Check VCT Level Determine RCS Leakrate Check PRZ PORV and Safety Valve Leakage US Refers to Tech Specs (TS)

TS 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

. Condition A - Closes Block Valve 1-NMO-153 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with power maintained to block valve.

May Refer to TS :

TS 3.4.12 Low Temperature Overpressure Protection (LTOP) System

- Mode 4 & 5 applicability TS 3.4.13, RCS Operational LEAKAGE

, if leak is not isolated.

RO Monitors PRZ pressure control system and ensures pressure remains at normal conditions (~2 085 psig).

Appendix D Required Operator Actions Form ES-D-2 Page 7 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.: 6,7 Event

Description:

Reactor Trip with S/G 14 tube rupture (600 gpm ), Steam generator safety valve (SV 3-4) opens

- 80% Time Position Applicant's Actions or Behavior RO/BOP Perform the following:

Recognizes and reports excessive charging flow demand as indicated by:

o Lowering Pressurizer level o Lowering Pressurizer pressure o PRZ level deviation alarm Recognize SG leakage based on RMS alarm on 1805 (GS Cond) and/or 1905 (SJAE) monitor.

US May enter and direct operator actions per OHP

-4022-002-021 SG Tube Leakage (or OHP

-4022-002-020, Excessive RCS Leakage):

Raise charging flow and isolate letdown Start the second CCP Maintain VCT level RO Recognizes and reports RCS leak rate greater than the capacity of charging pump

-OR- unable to maintain Pressurizer level/VCT level US Directs RO/BOP to manually trip the reactor and perform the immediate actions of E

-0, Reactor Trip or Safety Injection (based on RCS leak rate beyond charging system capability, may also initiate SI).

CREW Performs the immediate actions of E

-0: Checks reactor trip.

Checks turbine trip.

Checks power to AC emergency buses.

Checks safety injection status. Status light LIT BOP Critical Step Isolate Review Foldout Page Criteria Check Main Steamline Isolation NOT Required Check CTS NOT Required Implement Attachment A (Page 27) While Continuing With This Procedure Check If Ruptured SG is Suspected

- Recognize SG14 is Ruptured Close AFW Valves 1

-FMO-241 and 242 (When >14%)

Check AFW Pumps Running

Appendix D Required Operator Actions Form ES-D-2 Page 8 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.: 6,7 Event

Description:

Reactor Trip with S/G 14 tube rupture (600 gpm ), Steam generator safety valve (SV 3-4) opens

- 80% Time Position Applicant's Actions or Behavior SG AFW Flow Check Total AFW flow

- Greater than 240x10 3 PPH Minimize Unnecessary RCS Cooldown Check AFW Pump Discharge Valves

- Open or Throttled Check FW Isolation Check RCS Temperature Check PRZ PORVs and Spray valves Check if RCPs Should be stopped Check if SG Secondary Pressure Boundaries are Intact

- Recognize that the SG Safety Valve is OPEN Go To E-2, Faulted Steam Generator Isolation NOTE : Crew May transition to E

-2 first or May transition to E

-3 First and then Return to E

-2 US Direct entry into E

-2 Crew Critical Step Isolate SG #4 Steam Linefrom other SGs Check SG Stop Valves Closed Check SG Stop Valve Dump Valves Closed Check If any SG Secondary Boundary is Intact Identify Faulted SG Isolate Faulted SG Check CST Level

- Greater Than 15%

Check Secondary Radiation NOT Normal GO TO E-3, Steam Generator Tube Rupture, Step 1 US Direct enter into E

-3 Crew Check If RCPs Should be Stopped Identify Ruptured SG Isolate Flow From Ruptured SG Check Ruptured SG Level Check Ruptured SG

-Isolated From at Least One Intact SG Check Ruptured SG Pressure

- Greater Than 450 PSIG Enter RNO GO TO ECA

-3.1, SGTR With Loss of Reactor Coolant

- Subcooled Recovery Desired, Step 1

Appendix D Required Operator Actions Form ES-D-2 Page 9 of 9 Op-Test No.: Crews XX Scenario No.:

05 Event No.: 6,7 Event

Description:

Reactor Trip with S/G 14 tube rupture (600 gpm ), Steam generator safety valve (SV 3-4) opens

- 80% Time Position Applicant's Actions or Behavior US Directs entry into ECA

-3.1 Crew Reset SI Reset Containment Isolation Establish Control Air to Containment Trip All PZR Heaters Check If Containment Spray Should be Stopped Check Ruptured SG Level Check If RHR Pumps Should be Stopped Initiate Evaluation of Plant Status Check If SG Secondary Pressure Boundaries are Intact Check all faulted SG isolated Check All AC Buses

- Energized By Offsite Power Check Intact SG Levels