2K2 LOUT EXAM MATERIALS SIMULATOR EXAM SI~MO1 EXAMINATION · 2012. 11. 18. · ID Number: 2K2...

2K2 LOUTEXAM MATERIALS

SIMULATOR EXAM

SI~MO1

EXAMINATION

08112102 - 08115/02

MILLSTONE POWER STATION A

NRC SIMULATOR EXAM GUIDE APPROVAL SHEET

IExam Title:

Revision:

ATWS with Faulted SIG

0

ID Number: 2K2 NRC-001

This document is the property of Millstone Power Station, which controls its

distribution. Further transfer, copying, and modification of this document are

strictly prohibited without the written consent of Millstone Power Station.

H - /I

Submitted by:

Validated by:

Approved by:

Approved by:

Technvcloper

Technical Reviewer

2/13/02Date

6//7/ot

Date

Date

DaeC

,Operation Manager (Optional)

Training Supervisor

f

A; a e'�;w '1�. 11111 , ,� & "far6� -4241;& W.,,qfil" ,, "i- 1.19 0 ' I'M , N V

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SECTION 2

SIMULATOR EXAM GUIDE

TABLE OF CONTENTS

SECTIONS LISTED IN ORDER

1. Cover Page

2. Table of Contents

3. Exam Overview

4. Evaluation Guide

5. Scenario Initial Conditions Sheet

6. Scenario Validation Checklists

7. Reference and Task Tracking

8. Scenario Attributes Checklist

Attachments

- NUTIMS Module Report

-ST OP .T - iZ AC, X, VITo , Y

SECTION 3

EXAM OVERVIEW

Title: ATWS with Faulted S/G

ID Number: 2K2 NRC-001 Revision: 0

Exam Brief:

1. The plant is at 50% power, EOL steady state operations with all control systems inautomatic. The "A" PORV is out of service due to an electrical short in the control circuitry.The crew is directed to hold power at 50% and to Pump the Containment Drains TransferTank in accordance with OP 3335A, Reactor Plant Gaseous Drains, section 4.4.

After the CDTT has been pumped a partial Loss of RCP B Cooling Water Supply willoccur. The following alarms will actuate as their setpoints are reached: RCP B THERMALBARRIER FLOW LOW (MB4B, 3-4A), RCP B COOLER SPLY PRES LOW (MB4B, 3-4B).The crew will primarily use MB4B, 3-4B to respond to this condition. Thrust bearingtemperatures will remain <1950 so a rapid downpower and reactor trip will not be

implemented.After the partial Loss of RCP B Cooling Water has been addressed, a Loss of

Instrument Bus VIAC-3 will occur. The crew will respond using AOP 3564, Loss of OneProtective System Channel. Once the US has referred to Tech Specs (step 6), the nextevent will occur.

The A Main Feed Regulating valve will fail closed over 1 minute. The BOPoperator should attempt to take manual control of the valve but that will be ineffective.Once the crew realizes that S/G lo-lo is inevitable they should decide to trip the reactorin anticipation.

The reactor trip will not occur automatically, MB4 nor MB7 trip switches will work, and32N will not be able to be de-energized. The crew will enter FR-S.1, Response to NuclearPower Generation/ATWS. When attempting to align a boration flowpath the normal chargingflow control valve will not open requiring the use of the safety grade boration. At step 6 thePEO will successfully open the reactor breakers locally. When E-0 steps 1-14 are checked,the RO will discover that the SIH (HPSI) components did not actuate and will have to bemanually started or aligned [Critical Task]. During the initial ATWS transient a Main SteamLine D Rupture Inside CTMT occurs. MSI Fails to Auto Actuate and will have to be manuallyactuated by the crew at least by step 13 of FR-S.1 path [Critical Task].

The crew will proceed through FR-S. 1 to completion and then transition to E-0 step 15(SI verification done within FR-S.1) and then to E-2, Faulted Steam Generator Isolation, at E-0 [Critical Task], step 24. Conditions may require performing FR-Z.1.

The scenario will end when the crew decides to make the transition to E-1.

2. The SM should classify this event as a Site Area Emergency- Charlie Two due to FR-S.1 beingentered directly from E-0 (ES1).

3. Plant/Simulator differences that may affect the scenario are: NONE

4. Duration of Exam: 60 minutes

SECTION 4

EVALUATION GUIDE

ATWS with Faulted S/GTitle:


All Control Room Conduct, Operations and Communications shall be in accordance with

MP-14-MMM.

"Review the Simulator Operating Limits(design limits of plant) and the SimulatorModeling Limitations and Anomalous Response List prior to performing this examscenario on the simulator. The evaluators should be aware if any of these limitationsmay be exceeded." (NSEM 6.02)

Section 4Page 1 of 61

SIMULATOR PROBLEMS DURING EXAMS

It is the responsibility of the Instructors in the simulator to insure that exam interruptions have aminimum negative impact on the Crew and the examinations we provide.

Be aware that at all times the Operators should treat the simulator as if it were the plant andyou too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the examin progress (computer fault, etc.) the Instructor should:

1. Place the simulator in FREEZE if possible.

2. Announce to the Crew that there is a simulator problem.

3. Request that the Crew leave the simulator control room. (The Crew should leavethe simulator for problems which involve major switch alignments).

4. Deal with the problem (reboot, call STSB, etc.)

5. After the Instructors believe the simulator is restored to service, the Crew should betold how the exam will continue. If it is possible and felt to be acceptable to theevaluators, the examination can begin where it left off with an update on plantparameters and each Crew member is prepared to restart. If the examination willnot begin where it left off, the crew should be told how and where the exam willbegin again.

6. Once the Crew has been told how and where the exam will begin, have the crewconduct a brief so that the Instructor and evaluators can insure that the crew has allthe necessary information to continue with the scenario.

7. Once all Crew members, Instructors and evaluators are satisfied that they have thenecessary information to continue the scenario, place the simulator in RUN andannounce to the Crew that you have continued the evaluation session.


SECTiuN 4

Lesson Title: ATWS with Faulted S/G

ID Number: 2K2 NRC-001 Revision: 0Task

Time IDA/Malf Instructor Information/Activity Assign Expected Action Standard

Simulator Setup Instructions:

1. HANG Exam Placards on the simulator doors.

2. START the Sun Workstation.

a. IF the Sun Workstation is running THEN go to SIM ACTIVE.

3. PLACE Recorder Power to ON.

4. VERIFY that the current approved training load is loaded.

5. REMOVE the step counter OVERRIDE and allow the counters to step out during the IC reset.

6. RESET to IC 89: TEMP IC 2K2NRC-LOUT-001 (based on IC 22)

7. ADJUST the various pot settings to the valued specified by the chart in the simulator booth or Notepad for the selected IC.

8. PLACE Simulator to RUN.

9. RESET the Plant Calorimetric at the Instructor Station PPC by Pressing "SHIFT LEFT" and "F6" simultaneously.

10. ENSURE Simulator fidelity items cleared.

a. CHECK the STEP COUNTERS at correct position for plant conditions.

b. PLACE 5 tiles under the DEMINS IN SERVICE lamacord label on MB6.

c. PLACE the Main Turbine on the LOAD LIMITER and ENSURE Standby Load Set MATCHED if conditions require.

d. PLACE the Westronic (5) and Gammametrics (2) recorders in active/run by depressing up or down arrow for each.

e. CLEAR DCS alarms on MB7 and BOP console.

f. VERIFY annunciator, "COMPUTER FAILURE" (MB4C, 1-1 1), is NOT LIT.


(SECTiuN 4




g. ENSURE NSSS Picture 1, MODES 1, 2, 3, 4; Burnup and Cb match lesson plan AND Cb sample date < 3 days old.

1. See laminated directions on clipboard in Sim booth.

2. RESET Computer Terminals to At Power displays if 100% power IC.

a. MB2, (AY6), CVCS Data Trend, 1 minute update, CHS-F132 (40-120), CHS-L112 (40-80), CHS-F121 (40-80), RCS-L461 (40-80)

b. MB4, (AY1), At Power Data Trend, 15 second update, CVQRPI, (3391-3428), CVQRPHRUN (3409-3413), CVQRP (3409-3413), RCL-

T412*, (585-588)

c. MB4, (AY4), NSSS Picture 1, MODES 1, 2, 3, 4

d. BOP Console (AY5A), BOP Picture 26, Circ Water

e. STA Console, (AY3), NSSS Picture 15, RCP Seals

13. RESET Rad Monitor Screen to Status Grid.

14. OVERRIDE the annunciators that will be lit longterm in the CR, (as listed in the "Lit CRP Annunciators" section of the MP3 daily Status Report

hanging near instructor booth door).

15. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under "Equipment

OOS."

16. LOCK the Simulator Room front door.

17. HANG a Caution Tag on 3RCS*MV8000A stating, "Caution Tag 3RCS*MV8000A Closed and de-energized lAW Tech Spec 3.4.4, action b"

18. With SIM in RUN momentarily push 3DGS*CTV24 open/auto

19. ENSURE 3RCS*8000A in CLOSE position


(SECTION 4

(


Revision: 0ID Number: 2K2 NRC-001Task

AnnianTr:- lr/A Iftflf lnc~itr-ufnr InfnrmntinnlAr-livitv Expected Action StandardI 1111W I Lfrl M43 I I . - .

PLACE THE FOLLOWING EQUIPMENT OOS: STANDARD 2K2NRC EXAM EQUIPMENT

Ensure CDTT Level Raised (-1000 gallons) to allow pumping during NORMAL Evolution

Initial Malfunctions

1/01/01/01/01/0

(RC)(RC)(RC)(RC)(RC)

3RCS*PCV455A3RCS*PCV455A3RCS*PCV455A3RCS*MV8000A3RCS*MV8000A

A PORVA PORVA PORVA PORVA PORV

OPEN - OFFGREEN - OFFRED - OFFGREEN - FALSERED - FALSE

Block ValveBlock Valve

I/O (ED)I/O (ED)

1 -3NJSACB-BF1-3NNSACB-BF

TRIP - OFFTRIP - OFF

32N Fails to Trip32N High Side Fails to Trip

MALFMALFMALFMALFMALF

MALF

MALFMALF

RP09ARP09BRP10ARP1OBRP11E

CV18

RP08ARP08B

Reactor Fails to Manually Trip from MB4Reactor Fails to Manually Trip from MB7'A' Train Reactor Fails to Auto Trip'B' Train Reactor Fails to Auto TripAuto Actuation Failure: HPSI

Charging Flow Control Failure

MSI Train A Fails to Auto ActuateMSI Train B Fails to Auto Actuate

0% BT1 3

MALF MS01D Main Steam Line D Rupture Inside CTMT 20% 60 second ramp BT1


(SECTION 4

Lesson Title: ATWS with Faulted


Time IDA/MalfTask

Assian

Revision: 0

StandardI nctriuctr I nformatinn/Artivitv Expected Action-

Event

MALF

MALF

MALF

Malfunctions

CC03B

ED08C

FW08A

Loss of RCP B Cooling water Supply

Loss of Instrument Bus VIAC-3

A S/G FRV Failure

40% ramp 30 seconds

ramp 60 seconds

RSCU 1

RSCU 2

RSCU 30%

Lead Examiner: Refer to the "Briefing Script for the Operational Exam" and brief the crew.


SECTiON 4



AssianTime- InAIMInf Inctritetnr InfnrmatinnIArtivitv Expjected Action StandardI1W Iu vnlwa# I..~vs....-....... ,. a___

T+1 EVENT 1: Pump the ContainmentDrains Transfer Tank

OP3335A Reactor Plant GaseousDrains, Rev. 7

[Normal Evolution]

REMOTE When directed as PEO use Remote toopen 3DGS-V949. Delay 3 minutes

WOROI before reporting back.

RO IF CDTT is being pumped to the boronrecovery tanks, UNLOCK and OPEN3DGS-V949, gaseous drains to boronrecovery isolation.

OPEN the following:

* 3GSN*CTV105, "N2 TO PRT"

OP 3335AStep 4.4.1

RO OP 3335AStep 4.4.2

* 3GSN*CV8033, "N2 TO PRT"

RO IF CDTT is being pumped to theradioactive gaseous waste degasifier,PEFORM the following:

OP 3335AStep 4.4.3

a. SELECT "DRAINS DEGAS" on thedegasifier function selector switch(MB3).

b. Go To step 4.4.4.


SECTIuN 4(,



AssianTrn-- IfA M~UIf Incfriirtnr Infnrmntinn/Activitv ExDected Action StandardI mimic *s.,,-# ,w,~54, . - . - -

RO START one containment drainstransfer pump (MB1)

* 3DGS-P1A, "CTMT DRAINSPPS`""A"

* 3DGS-P1B, "CTMT DRAINSPPS'"B"

OP 3335AStep 4.4.4

RO IF the low pressure N2 regulator isbypassed, CYCLE one of the followingas necessary to maintain pressurebetween 16 and 21 psia, as read onDGS-PI29 (MB1).

* 3GSN*CTV105, "N2 TO PRT"

* 3GSN*CV8033, "N2 TO PRT"

OP 3335AStep 4.4.5

RO WHEN CDTT level is less than 300gallons, STOP the containment drainstransfer pump (MB1)

* 3DGS-P1A, "CTMT DRAINSPPS""A"

* 3DGS-Pl B, "CTMT DRAINSPPS""B"

OP 3335AStep 4.4.6


!SECTION 4

(,


Revision: 0ID Number:

Tinsa

2K2 NRC-001Task

AssianIItAIRA M If Inftrir-tnr Infnrmqatinn/Activitv Expected Action StandardI 1111V 1LOPlllve"l -ltO L ll ElE lV-A l X ____ ___

RO IF CDTT was being pumped to theradioactive waste degasifier, SELECT"LETDOWN DEGAS" on the degasifierfunction selector switch (MB3).

OP 3335AStep 4.4.7

RO

RO

CLOSE 3GSN*CTV105 and3GSN*CV8033, "N2 TO PRT".

IF CDTT was being pumped to theboron recovery tanks, CLOSE andLOCK 3DGS-V949, gaseous drains toboron recovery isolation.

OP 3335AStep 4.4.8

OP 3335AStep 4.4.9

.

T= normalevolution inprogress

MALFCC03B4Al0 /n

EVENT 2: Partial Loss of RCP BCooling Water Supply

_ .- i

ram 30 NOTE: Modify MALF to about 55%ramp after annunciator received and asseconds necessary to maintain RCP bearing

RSCU1 temperatures less than 1950 F.

ARP OP3353.MB4B, 3-4B Rev. 004RCP B COOLER SUPPLY PRES LO

US IF a loss of RPCCW has occured, GoTo AOP 3561, "Loss of Reactor PlantComponent Cooling Water"

OP3353.MB4B, 3-4B

Step 1


(SECTION 4

(



AssianTi ma InAIMnif Instrrftnr Infnrmation/Activitv Expected Action Standardla 1111 an eA _A..... ;

RO CHECK the following parameters(MB1):

* 3CCP-FI1 5B, RPCCW containmentsupply flow, 600 to 1000 gpm

* 3CCP*MOV45B, Train B RPCCWsupply containment isolation, open

* 3CCP*AOV179A, Train A RPCCWheader division valve, closed

* 3CCP*AOV179B, Train B RPCCWheader division valve, closed

* 3CCP*AOV1 80A, Train A RPCCWheader division valve, closed

* 3CCP*AOV180B, Train B RPCCWheader division valve, closed

OP3353.MB4B, 3-4B

Step 2


(.SECTiON 4



Time IDA/MalfTask

AssianIncfriirftnr Infnrmatinn1Antivitvt vv..w- . ... ,

RO

F

Expected Action

MONITOR the following RCP B thrustbearing and radial bearing temperaturecomputer points ("RCP Status," NSSS,picture 15)

* RCS-T480A, RCP B upper thrustbearing

* RCS-T484A, RCP B upper radialbearing

* RCS-T480B, RCP B lower thrustbearing

* RCS-T484B, RCP B lower radialbearing

Revision: 0

Standard

OP3353.MB4B, 3-4B

Step 3


SEC1 ioN 4f



AssianThea- I A IRAM.If Inatrm-tr InfnrmatinnlActivitv Expected Action StandardI 1IIW ELAMIWIGAIN . … J_ *_--_T

T= Step 4 MODIFYMALFCC03B

to 55%

RSCU 1

Modify, asnecessaryto keep

thrustbearingtempsless than1950F

NOTE: To Instructor, for thismalfunction, as "valve" increasesseverity of malfunction decreases.

USE NSSS picture 15 to monitor RCPseal temperatures and

USE Real-Time trend RCS-T480A tomonitor RCP bearing temperatures

RO IF at any time any RCP B thrustbearing or radial bearing temperaturecomputer point is greater than 195 0F,PERFORM the following:

OP3353.MB4B, 3-4B

Step 4

IF reactor power is greater than P-8(37%) PERFORM the following:

1. TRIP the reactor

2. STOP RCP B

3. Go To E-0, "Reactor Trip or SafetyInjection"

Refer to AOP 3554, "RCP Trip orStopping an RCP at Power", andREMOVE RCP B from service.

NOTE: When the US calls either thesystem engineer, the OPS manager orthe Duty Officer RECOMMEND thatthey reduce power per AOP 3575,Rapid Downpower, at 1 %/min toremove the RCP from service.

Refer to Technical Specifications, andDETERMINE Limiting Condition forOperation

OP3353.MB4B, 3-4B

Step 5


alSECTION 4

I'



AssianTim^ InAM1nIf Inctrniltnr Infnrmatinn1Artivitv Exoected Action StandardI vII lC 5|51*5fl -, - -- _

EVENT 2a: Rapid Downpower toRemove RCP

[Reactivity Manipulation]

AOP 3575, Rapid Downpower,

Rev. 7

* A CONVEX requested emergencygeneration reduction should becompleted within 15 minutes ofnotification.

AOP 3575Step 1NOTE

* If a unit shutdown is required, thetarget power level should bebetween 20% and 25% reactorpower.

* If at any time ROD CONTROLBANKS LIMIT LO - LO (MB4C 4 - 9) annunciator is received, DO NOTgo to AOP 3566, ImmediateBoration. Immediately perform step9.

CREW Determine Power Reduction Rate(%/min).

US Check desired power reduction rate -LESS THAN OR EQUAL TO 5%/min.

RO/ Perform the following for an immediateBOP turbine unloading:

AOP 3575Step 1

AOP 3575Step 1.a

AOP 3575Step 1.aRNO


fI (SECTION 4



AssianTim&% I nA/Mlf Instriirtnr Infnrmation/Activitv ExDected Action StandardI. .._. ...1..-----. ...... ..- _-_… -n- _

RO

BOP

Us

US

US

1) Place rod control SEL switch inAUTO.

2) Rotate LOAD LIMIT SET to reduceturbine load the desired amount upto a 480 MWe reduction.

3) Proceed to Step 5

Check power reduction - CONVEXREQUESTED

Perform load reduction at 5%/min andProceed to Step 1.d.

AOP 3575Step 1.b

AOP 3575Step 1.bRNO

CREW Perform load reduction at 5% min andProceed to step 2.

AOP 3575Step 1.c

AOP 3575Step 1.d

CREW Determine power reduction rateusing Table.

Total Power Change (A%)I- -,I I

10% 20% 30% 40% 50% 60% 70% 80%Il t . I I

315F 1 3 3 5 5 5

30 0.5 1 1 3 3 3 3 3

45 0.5 0.5 1 1 3 3 3 3


I

SECTIUN 4



AssiqnTime InA/Malf Instructor Information/Activitv Expected Action Standard

60 i 0.5 0.5 1 1 1 3 3

Time to 75 0.5 0.5 1 1 1 _1 ;_

Reduce 90 0.5 0.5 0.5 1 1 1 1

Power 105 0.5 0.5 0.5 0.5 1 1 1

(min) 120 0.5 0.5 0.5 0.5 1 1

135 0.5 0.5 0.5 0.5 1 1

150 0.5 0.5 0.5 0.5 0.5 1

160 _ _ 0.5 0.5 0.5 0.5 0.5 0.5

US

RO

RO

CREW

Check Rod Control In AUTO.

Place rod control SEL switch inAUTO and Proceed to NOTE prior toStep 3.

IF automatic rod control NOTavailable, THEN Move rods in MANas necessary to maintain Tavg within

+50F of Tref.

Align EHC Panel

AOP 3575Step 2

AOP 3575Step 2 RNO

AOP 3575Step 3


(SECTiuN 4

I:



AssianTiara InA/Minlf nctrmletor Wnfrmatinn/Artivitv Expected Action StandardI I IIt IEOF5i"Iu -v -. . .

US

US

US

BOP

BOP

BOP

BOP

Check turbine OPERATING MODE -MANUAL

Proceed to step 4.

Check LOAD LIMIT LIMITING light -LIT

Proceed to step 3.e.

Intermittently Press DECREASELOAD pushbutton until LOAD LIMITLIMITING light - NOT LIT

Rotate LOAD LIMIT SET adjust knobat least one full turn in raise direction

Select DECREASE LOADING RATEto ON

Select LOAD RATE LIMIT % MIN torequired power reduction rate (%min)

If at any time the power reductionrate or target power level must bechanged, Return to step 1.

AOP 3575Step 3.a

AOP 3575Step 3.aRNO

AOP 3575Step 3.b

AOP 3575Step 3.bRNO

AOP 3575Step 3.c

AOP 3575Step 3.d

AOP 3575Step 3.e

AOP 3575Step 3.f

AOP 3575Step 4NOTE


(SECTION 4



Time IDA/Malf Instructor Information/ActivityTask

Assign

US/RO

RO

F

Expected Action

Verify Power Reduction Rate

Check power reduction rate 5% MIN

Perform the applicable action:

Revision: 0

Standard

AOP 3575Step 4

AOP 3575Step 4.a

AOP 3575Step 4.aRNO

* IF power reduction rate is 3%min,

THEN

Proceed to step 5.

* IF power reduction rate is LESSTHAN 3% min,

THEN

Proceed to NOTE prior step 6.

Check power reduction - REQUIREDTO STABILIZE PLANT

Proceed to step 5.


RO

RO

AOP 3575Step 4.b

AOP 3575Step 4.bRNO

AOP 3575Step 4.c


I'

SECTION 4



AssianTime^ InAIMinIf I nctriuetor I nformatinn/Artivitv Expected Action StandardI IS ._

RO Initiate Rapid Boration

Verify RCS makeup system in -AUTO

Perform the following:

AOP 3575Step 5

AOP 3575Step 5.a

AOP 3575Step 5.aRNO

1. Select AUTO on the reactorcoolant makeup select switch.

2. Select START on the reactorcoolant makeup start switch.

START one boric acid transfer pump. AOP 3575Step 5.b

Proceed to step 5.d.

OPEN emergency boration valve(3CHS*MV8104).

Verify direct boric acid flow (3CHS-FI183A) - INDICATED.

Perform the following to initiategravity boration:

RO

AOP 3575Step 5.bRNO

AOP 3575Step 5.c

AOP 3575Step 5.d

AOP 3575Step 5.dRNO


SECTIUN 4




1. Place the charging line flowcontrol valve in MAN.

2. OPEN at least one gravity feedboration valve.

3. CLOSE at least one VCT outletisolation valve.

4. Limit net charging flow to the RCSto LESS THAN 75 gpm (charging +seal injection - RCP seal return).

5. Adjust charging line flow controlvalve as required.

IF gravity boration flow can NOT beestablished,

THEN

TRIP the reactor and Go to E - 0,Reactor Trip or Safety Injection.

6. Proceed to step 5.f.

OPEN charging line flow control AOP 3575valve, to match boric acid flow Step 5.e(3CHS-FI 183A)

RO Record time boration started AOP 3575

Time Step 5.f


(. SEC1I oN 4



AssianTombs IMAIMAlf Inctrniftnr Infnrmatinn/Activitv Expected Action StandardI1m IU*115t*1fl

Energize all PZR heaters.

Determine required boric acidaddition by multiplying total powerchange (A%) by 15 (gal/%) =gal.

Determine required time to borate bydividing required gallons of boric acidby the direct boric acid flowrate (net

charging flow rate if using gravityboration) _ min.

Check turbine load decrease - INPROGRESS OR COMPLETED.

Proceed to NOTE prior to Step 7.


AOP 3575Step 5.g

AOP 3575Step 5.h

AOP 3575Step 5.i

AOP 3575Step 5.j

AOP 3575Step 5.jRNO

AOP 3575Step 5.k

US

US

US


(SECTION 4



AssianTime I nf IM2nIf Inctri.ttnr Infnrmation/Activitv ExDected Action StandardIII , ; iWtA, ..- . *5- - - - ._

CREW

US

US/RO

RO

Boric acid total volume addition andflow rates are based onapproximations. Adjustments shouldbe made to these values asnecessary to ensure the reactorreaches the desired end state of:

* Tavg on program

* Rods above the Rod InsertionLimit

* AFD on or above the target value

Align RCS Makeup System ForBoration.

Determine required boric acidaddition by multiplying total powerchange (A%) by 15(gal/%) =gal.

Set the boric acid batch counter tototal gallons of boric acid required.

Check power reduction rate- AT0.5%/min.

Adjust boric acid blend flow controllerpot setting to 3.75 (15 gpm) andProceed to Step 6.e.

AOP 3575Step 6

AOP 3575Step 6.a

AOP 3575Step 6.b

AOP 3575Step 6NOTE

US

RO

AOP 3575Step 6.c

AOP 3575Step 6.cRNO


( (SECTION 4



AssianTima MAIMnIf Instruictnr Information/Activitv ExDected Action Standard- -- - -- --

RO Adjust boric acid blend flow controllerpot setting to 1.9 (7.5 gpm).

RO Select BORATE on the reactorcoolant makeup select switch.

RO Select START on the reactor coolantmakeup start switch.

RO Verify boric acid flow - INDICATED

US Return to step 5.

RO Energize all PZR heaters.

RO If a unit shutdown is beingperformed, the final MWe loadshould be approximately 230 MWe.

US/BOP Initiate Load Reduction.

BOP Check turbine OPERATING MODE -MANUAL

BOP Unload turbine at required rate usingthe STANDBY LOAD SET pot andProceed to step 7.e.

AOP 3575Step 6.d

AOP 3575Step 6.e

AOP 3575Step 6.f

AOP 3575Step 6.g

AOP 3575Step 6.gRNO

AOP 3575Step 6.h

AOP 3575Step 7NOTE

AOP 3575Step 7

AOP 3575Step 7.a

AOP 3575Step 7.aRNO


( (SECTIUN 4



AssianThea MI Qftfilf Inatriu-tnr Infnrmatinn/Artivitv Expected Action StandardI me11W ILI W1 IWEICINI - -- - _

BOP

BOP

BOP

BOP

BOP

BOP

US

BOP

US/RO

Check rapid or gravity boration - INPROGRESS


Check LOAD RATE LIMIT % MIN setat - 3% OR 5%.LIMITING light - LIT.

Select LOAD RATE LIMIT % MIN to3% or 5%.

Utilizing DECREASE LOADpushbutton, Adjust LOAD SET todesired final MWe (target powerlevel)

Check power reduction - CONVEXREQUESTED.

Inform CONVEX of load reductionrate (MWe/min) and final MWe level.

Maintain initial MVAR loading duringpower reduction, unless directedotherwise.

Check boration - IN PROGRESS

AOP 3575Step 7.b

AOP 3575Step 7.bRNO

AOP 3575Step 7.c

AOP 3575Step 7.cRNO

AOP 3575Step 7.d

AOP 3575Step 7.e

AOP 3575Step 7.eRNO

AOP 3575Step 7.f

AOP 3575Step 7.g


( ISECTiuN 4

(



AqsianTown rlA IRAIf Inoerm ujtr Infnrmntinn/At-tivitv Exoected Action StandardI 1111W 1L.IrWaviall 111�1.

T= AFTERRCPdownpowerandExaminerConcurs

MALFED08C

EVENT 3: Loss of Instrument BusVIAC-3

RSCU 2

AOP 3564, Loss of One ProtectiveSystem Channel, Rev. 8

US Loss of VIAC-1 (2) results in dieselgenerator sequencer A(B) being de-energized. If an ESF actuation takesplace during this condition, thefollowing items will not occurautomatically.

AOP 3564Step 1CAUTION

RO Determine Plant Status AOP 3564Step 1

Check reactor status - TRIPPED AOP 3564Step la

Proceed to Step 2 AOP 3564Step laRNO

CREW Check the Following ControlSystems:

AOP 3564Step 2

* Verify rod control - OPERATINGNORMALLY IN AUTO


(f (.

SECTION 4



As-innY;.- IlAIMlkIf Inftriirntr Infnrmatinn/Atctivitv ExDected Action StandardI III IV IuIwc sLoPuvmv 1111se sr-| -II.. .

* Verify SG level - OPERATINGNORMALLY IN AUTO

* Verify PZR level - OPERATINGNORMALLY IN AUTO

* Verify PZR pressure - OPERATINGNORMALLY IN AUTO

Perform the following: AOP 3564Step 2RNO

a. Place the affected controller inMANUAL.

b. Stabilize plant parameters.

c. Defeat the failed channel input.

d. Return the affected controller toAUTO.

Verify Normal Letdown - IN SERVICE

Verify Cold Overpressure ProtectionSystem - BLOCKED

Block the affected Train of ColdOverpressure Protection System

RO

RO

AOP 3564Step 3

AOP 3564Step 4

AOP 3564Step 4RNO


SECTION 4



AeminnT:� *IA IRAl-L1 Incr.rtr nfrormntio~n1Aritifxtv Exoected Action StandardI ime *I.,UMuV~i IEI 1.1LI'%,LA1 I..,

RO Verify VCT Level (3CHS*LTI12)Using Computer Point 3CHS-L 112 -CONTROLLING NORMALLY

AOP 3564Step 5

[Tech Specs] US Refer to the Following TechnicalSpecifications for ApplicableActions:

AOP 3564Step 6

* If in Mode 2 and LESS THAN 1 0-'IR amps, 3.3.1 Reactor Trip SystemInstrumentation:

Action 4 (FU 6-a)Action 8 (FU 17.a)

* 3.3.1 Reactor Trip SystemInstrumentation Action 8 (FU 17.b)

3.3.2 Action 17, the operable channelis placed in the bypass condition

* 3.3.2 ESF Actuation SystemInstrumentation:

Action 16 (FU 7.d)Action 17 (FU 2.c & 3.b.3)Action 18 (FU 7.e)Action 20 (FU 8.a & 8.b)**entry into T/S 3.0.3 required

* If in Mode 5 or 6, 3.3.2 ESFActuation System InstrumentationAction 26 (FU 3.c)


!,SECT IUN 4

l'


ID Number:

Time

2K2 NRC-001 Revision: 0Task

AssianInA/Malf Instructor Information/Activitv Expected Action Standard

* If in Modes 4, 5 or 6, 3.4.9.3Overpressure Protection Systems

* 3.8.3.1 and 3.8.3.2, Onsite PowerDistribution

3.8.3.1.e Action b, re-energize the ACvital bus within 2 hours or be in HOTSTANDBY within the next 6 hours andin COLD SHUTDOWN within thefollowing 30 hours.

NOTE: If PEO and/or Maintenance aredispatched to investigate VIAC they willfind it de-energized and Maintenancewill find the 150A input fuse blown.Report that they will begin procurementand replacement procedures. (Foundon EE-1BA)

RO Check All Vital 120 VAC InstrumentBuses - ENERGIZED

AOP 3564Step 6

T= VIAC MALF EVENT 4: Feed Reg Valve Failure

Tech Specs FWO08A NOTE: Loss of control at the Feedaddressed 0% 60 sec Station will require an anticipatory

ramp reactor trip

RSCU 3

T= AOP3571, Aft. Bstep 4

MALFI/Os 32NRP09A/BRP10A/B

EVENT 5: ATWS; 32N Fails toDe-energize


(SECt iuN 4



AssianTi m InAiMnif Inc~triutnr Infnrmatinn/Activitv Expected Action Standard3 1111� .--- - -- j

FR-S.1, Response to NuclearPower Generation/ATWS, Rev. 16

US * If RHR is in service, all referencesto AFW are NOT applicable.

* Immediate Boration (step 4, 5 and6) may be performed in parallelwith steps 1*, 2*, or 3, provided thatefforts to initiate ImmediateBoration do not preclude or delaycompletion of steps 1*, 2*, or 3.

Verify Reactor Trip

EOP 35FR-S.1Step 1NOTE

EOP 35FR-S. 1Step 1*

RO

* Check reactor trip and bypassbreakers - OPEN

* Check rod bottom lights - LIT

* Check neutron flux - DECREASING

RO TRIP the reactor. EOP 35FR-S.1Step 1*RNO

IF the reactor will NOT trip,

THEN

Drive rods in (AUTO or MANUAL).


I'SECTION 4

(.


ID Number:

Time


AssiqnIDA/Malf Instructor Information/Activitv Expected Action Standard

BOP Verify Turbine Trip

Check all turbine stop valves -CLOSED

Verify AFW Pumps Running

EOP 35FR-S.1Step 2*

EOP 35FR-S.1Step 2.a

EOP 35FR-S.1Step 3

BOP

* Check MD pumps - RUNNING

* Check TD pump - RUNNING, IFNECESSARY

reactor tripMALFCV1 8

EVENT 6: Charging Flow ControlFailure

RO Initiate Immediate Boration of RCS EOP 35 FR-S.1 Step 4

Check SI - NOT ACTUATED

Check one charging pump - RUNNING

START one charging pump.


EOP 35FR-S. 1Step 4.b

EOP 35FR-S.1Step 4.bRNO


( aSECI-ON 4


ID Number:

Timg%


AssicinIDAIMnif Inqtrictor Information/Activitv Expected Action StandardI . -1 .1 . .-. .

Align boration path:

1) START at least one boric acidtransfer pump

2) OPEN emergency boration valve(3CHS*MV81 04)

Check normal charging flow pathaligned:

1. Charging flow control valve - OPENOR THROTTLED

AND

CAPABLE OF BEINGTHROTTLED

EOP 35FR-S. 1Step 4.c

EOP 35FR-S.1Step 4.d

2) Charging header loop isolationvalve (3CHS*AV8146 or3CHS*AV8147) - OPEN

3. Charging header isolation valves -OPEN

* 3CHS*MV8106

* 3CHS*MV8105


!i'

SEC ION 4



Assiane.--d InA/Mmif Inctriuctr Infnrmation/Activitv Expected Action StandardI IIIU *L1I**1V *..tA.. .. -. .

Position valves as required. EOP 35FR-S.1Step 4.dRNO

NOTE: Proceed To step 5 IF a controllable normal charging flowpath can NOT be established, THENProceed to step 5.

RO Align Safety Grade Boration Path

Check busses 34C and 34D - BOTHENERGIZED

OPEN charging header flow controlvalve (3CHS*HCV190A)

open CHARGING HEADER BYPASSISOLATION (3CHS*MV8116)

CLOSE charging flow control outletisolation (3CHS*MV8106)

EOP 35FR-S. 1Step 5


EOP 35FR-S.1Step 5.b

EOP 35FR-S.1Step 5.c

EOP 35FR-S.1Step 5.d


(SEC;, ION 4

f


Revision: 0ID Number: 2K2 NRC-001

Task


T= FR-S.1 REMOVE NOTE: Call back as PEO as report Proceed to step 6 EOP 35

step 5 RP09A/B reactor trip breakers open. FR-S.1

complete RP10A/B Step 5.e

NOTE: RP02A/B may not beINSERT necessaryRP02A/B

T= FR-S.1 MALF EVENT 7: Main Steam Line D RO Verify Boration Flow EOP 35

step 6 MS01D, Rupture Inside CTMT FR-S. 1

20%, 60 Step 6

secondramp

T= Initial MALFRP08

EVENT 8: MSI Fails to AutoActuate

Check PZR pressure - LESS THAN2350 psia

Check normal charging flow path -ALIGNED




1i:

SEC riON 4



AssianTime- IfA/Mnlf Inc~triirtnr Infnrmation/Activitv Expected Action StandardI 11111W .. -.. ---- - -- j


* IF Si actuated, THEN Proceedto step 7.

* IF a safety grade boration flowpath is established, THEN

1. Using GA-14, Establish reactorvessel head vent letdown to thePRT.

2. Proceed to step 7.

Check the Following Has Occurred

Verify reactor trip breakers - OPEN

Verify turbine trip

Check If Si Is Actuated

EOP 35FR-S.1Step 6.bRNO

US EOP 35FR-S.1Step 7



RO EOP 35FR-S.1Step 8

EOP 35FR-S.1Step 8.a.

Verify SAFETY INJECTIONACTUATION annunciator (MB4D 1-6or MB2B 5-9) - LIT


¢ ¢SEC s ION 4



AssianTim. IFIA/Mnlf Instrirtnr Infnrmatinn/Activitv Expected Action StandardI 1111�- ---- - -- J -- - -

[Critical Task]

Establish flow from at least one SIpump before completion of the checkof E-0, steps 3-14 in FR-S.1.

Manually actuate MSI or close MSIV'sbefore completion of FR-S.1 step 13.

NOTE: Crew should notice MSI isrequired and actuate when reviewingStep 10 of E-0.

Verify steps 3-14 of E-0, Reactor Tripand Safety Injection

EOP 35FR-S.1Step 8.b.

BOP Check AFW Suction Source

Check DWST level - LESS THAN80,000 gal

Proceed to step 10 and,

IF DWST level decreases to LESSTHAN 80,000 gal,

EOP 35FR-S.1Step 9


EOP 35FR-S. 1Step 9.a,RNO

THEN Perform step 9.b

BOP Check SG Levels EOP 35FR-S.1Step 10


SEC, ION 4




Verify NR level in at least one SG - EOP 35GREATER THAN 8% (42% ADVERSE FR-S.1CTMT) Step 10.a

Perform the following: EOP 35

1. Verify total feed flow is GREATER Step 10.aTHAN 1150gpm RNO

IF the flow is LESS THAN 1150gpm THEN

START pumps and Align valves asnecessary.

2. Maintain total feed flow GREATERTHAN 1150 gpm until NR level isGREATER THAN 8% (42%ADVERSE CTMT) in at least oneSG.

Control feed flow to maintain NR level EOP 35between 8% and 50% (42% and 50% FR-S.1ADVERSE CTMT) Step 10.b

High Radiation Area Key and Locked EOP 35Valve Key are required for FR-S.1performance of some local actions in Step 11the following step. NOTE


(SECTION 4


ID Number:

Timn


AssianInAIMnif Instrurctnr Information/Activitv Expected Action StandardI to I I- .. .- _. - - __ . .. - - - - - - ___ __ - - __ - - - __ - - -1 . -

RO/US/PEO

Verify All Dilution Paths Isolated

* Check primary makeup water toblender (3CHS*FCV1 1 1A) -CLOSED

EOP 35FR-S.1Step 11

NOTE: As US request wait 3 minutesand report chemical mix tank outletisolation valve (3CHS*V317) -CLOSED and manual dilution valve(3CHS*V305) - CLOSED

* Locally check chemical mix tankoutlet isolation valve (3CHS*V317)- CLOSED

* Locally check manual dilution valve(3CHS*V305) - CLOSED

* Check BTRS - OFF ANDBYPASSED

CREW Check for Reactivity Insertion FromUncontrolled RCS Cooldown.

* RCS temperature - DECREASINGIN AN UNCONTROLLED MANNER

OR

* Any SG pressure - DECREASINGIN AN UNCONTROLLED MANNER

EOP 35FR-S.1Step 12


( lSECTION 4



AssiqnTima IMAIM2af Instructor Information/Activitv Expected Action Standard

[Critical Task] Manually actuate MSIor close MSIV's before completion ofFR-S.1 step 13.

BOP Check MSIVs and MSIV BypassValves - CLOSED

EOP 35FR-S. 1Step 13

EOP 35FR-S. 1Step 13RNO

CLOSE valves.

BOP Identify Faulted SGs EOP 35FR-S.1Step 14

Check pressures in all SGs:

* ANY SG PRESSUREDECREASING IN ANUNCONTROLLED MANNER

OR

* ANY SG COMPLETELYDEPRESSURIZED


US * At least one SG must bemaintained available for RCScooldown.

EOP 35FR-S.1Step 15CAUTION


(SEC ION 4




* If all SGs are faulted, at least 100gpm feed flow should bemaintained to each SG.

* If the TD AFW pump is the onlyavailable source for feed flow, asteam supply to the TD AFW pumpmust be maintained from at leastone SG.

BOP Isolate Each Faulted SG EOP 35FR-S.1Step 15

* Isolate main feedline

* Isolate AFW flow

* CLOSE steam supply isolationvalve to TD AFW pump

* Verify SG atmospheric dump valve- CLOSED

* Verify SG atmospheric dumpbypass valve - CLOSED

* Verify SG blowdown isolation valve-CLOSED

* Verify SG chemical feed isolationvalve - CLOSED


SEC; & ON 4



AssianTinan InA1iMnIf InctrUidtr Infnrmatinn/Activitv Expected Action StandardI ,,,,*: *5luW.- . .. ...... U. ... . ---. .. ., _ ..........---.--- ,

US/RO Check Core Exit TCs - LESS THAN12000F

EOP 35FR-S.1Step 16

EOP 35FR-S.1Step 17

RO Verify Reactor Subcritical

* Check power range channels -LESS THAN 5%

* Check intermediate range channels- NEGATIVE STARTUP RATE

US Verify No Fuel Damage

Request Chemistry obtain RCSsamples

Request the ADTS obtain samplesusing any means possible.

Using MP-26-EPI-FAP06,"Classification and PARs," Evaluate forincident classification

EOP 35FR-S. 1Step 18


EOP 35FR-S. 1Step 18.aRNO



fSEC-I ION 4

!

Lesson Title: ATVVS with Faulted S/G


AnsianT.:_ IMA /RM-14 Inctriu,4 ,r InfnrmntinnIAftivitv Expected Action StandardI 1111t: Rimilviall 1111-0t.1%A�1%W. .

US Verify Security Has Checked SLCRSDoors - CLOSED

Request status of SLCRS doors fromSecurity.

EOP 35FR-S.1Step 19

EOP 35FR-S.1Step 19RNO

EOP 35FR-S. 1Step 20CAUTION

EOP 35FR-S.1Step 20

US Boration shall continue duringsubsequent actions until adequateshutdown margin is obtained.

Go to Procedure and Step in Effectand Initiate Monitoring of the CSFStatus Trees

NOTE: Depending on the pace of thecrew the transition may be to FR-Z.1,Response to High CTMT Pressure,page 56 of this Sim Guide

US

E-0, Reactor Trip or SafetyInjection, Rev. 21

RO Determine If ADVERSE CTMTConditions Exist

E-0, Step 15

* Ctmt temperature GREATERTHAN 180 0F

OR

* Ctmt radiation GREATER THANO0 R/hr


SECTIION 4



TaskAnqianT:�_ IrA IRA-IS 1nfrrm!nfinn1ArfiVifV ExDected Action Standard

I Ime II.I.M11VICIII It 117 1.1 " %, %.W I I... .....

CREW DO NOT use ADVERSE CTMTparameters.

E-0,Step 15,RNO

RO Verify ECCS Flow E-0, Step 16

RO

RO

US

Check charging pumps -

FLOW INDICATED

START pumps and Align valves.

Check RCS pressure - GREATERTHAN 1650 psia (1950 psiaADVERSE CTMT)

Proceed to Step 16.d

Proceed to step 17.

Check SI pumps - FLOW INDICATED


Check RCS pressure - LESS THAN300 psia (500 psia ADVERSE CTMT)

E-0,Step 16.a

E-0,Step 16.a,RNO

E-0,Step 16.b

E-0,Step 16.b,RNO

E-0,Step 16.c

E-0,Step 16.d

E-0, Step16.d RNO

E-0,Step 16.e


(.

SEC | ION 4



TaskAssinnI narsurtr nfnrrmnfirn1Art-iviftr Expected Action Standard

_ h IErA IRA -1Z

lime IUIAIIVIdUII IIEZLIU%.,LJE A__. ro d

Proceed to step 17.

Check RHR pumps - FLOWINDICATED.


E-0,Step 16.eRNO

E-0,Step 16.f

E-0,Step 16.fRNO

CREW should perform a short briefand come out of "Master Silence" atthe completion of Step 16.

BOP Verify Adequate Heat Sink E-0, Step 17

Check NR level in at least one SG -GREATER THAN 8% (42% ADVERSECTMT)

Proceed to Step 17.d.

E-0,Step 17.a

Us

BOP

US

BOP

E-0,Step 17.a,RNO

Control feed flow to maintain NR level- BETWEEN 8% and 50% (42% and50% ADVERSE CTMT)

E-0,Step 17.b

Proceed to Step 18. E-0,Step 17.c

Verify Total AFW Flow - GREATERTHAN 530 gpm

E-0,Step 17.d


i: SEC i iON 4



TaskAqqinnleer~rarIn-Frnnrmirtnn/A9-fivit Expected Action Standard

_ D II5 A SREX1;I ime *LILU.IVU.aLV IIIEtJE v s.. _ --

BOP

us

BOP


E-0,Step 17.d,RNO

IF AFW Flow GREATER THAN 530gpm can NOT be established,

THEN

Initiate monitoring of CSF StatusTrees and Go to FR-H.1, Response toLoss of Secondary Heat Sink.

Verify AFW Valve Alignment -PROPER EMERGENCY ALIGNMENT

E-0, Step 18

Align valves E-0,Step 18,RNO

RO Verify ECCS Valve Alignment -PROPER EMERGENCY ALIGNMENT

E-0, Step 19


US Check Plant Status E-0, Step 20

BOOTHINST

NOTE When asked, REPORT that "allSLCRS doors indicate closed."

Verify SLCRS doors - CLOSED E-0,Step 20.a


SECTION 4(



AssianT.;- If~lAIMif Ina-triiitnr Informntinn/Artivitv Expected Action StandardI IIIU - -- -

US

RO

RO

RO

RO

Request Security Close all SLCRSdoors.

Check CONTROL BUILDINGISOLATION annunciator (MB4D 3-6) -LIT

Check if CBI is required

* Ctmt pressure GREATER THAN18 psia

OR

* Control Building radiation monitorin alarm

OR

E-0,Step 20.a,RNO

E-0,Step 20.b

E-0,Step 20.b,RNO

RO

* Si manually actuated

IF CBI required,

THEN

Initiate CBI.


SECTION 4



AnnianTo; MnA IRA-lf In&4vctr ipre Infnrmntinn/Artivitv Expected Action StandardI meIIW ILJIPIIVIOII , u imLI -.... ... _..- _

US

RO

RO

BOP

BOP

IF CBI is NOT required,

THEN

Proceed to Step 21.

Verify ESF Group 2 CBI lights - LIT

Align HVAC components as necessaryfor minimum safety function.

Verify control building purge supplyfan and purge exhaust fan - NOTRUNNING


E-0,Step 20.c

E-0,Step 20.c,RNO

E-0,Step 20.d

E-0,Step 20.d,RNO

* Stop purge supply fan.

* Stop purge exhaust fan.

* Locally Close instrument airisolations

* 31AS-V725 (CB 47' IRRstairwell)



(SEC i ION 4



AssianTima MAIn^Mnif Instructor Information/Activitv Expected Action StandardI We I11Uc ..... ........ _.._.. __-. ... - .--

* 31AS-V644 (CB 66' west wall)

* Locally Close instrument airisolation valve for 3HVC-AOD134

Control building air bank isolationvalves - OPEN (after 60 seconds)

OPEN valves

BOP

BOP

BOP

E-0,Step 20.e

E-0,Step 20.e,RNO

IF at least one air bank isolation valvecan NOT be opened,

THEN

Locally throttle Open at least onepair of air bank isolation bypassvalves to maintain 0.125 incheswater at Control Building APindicator on VP1.

* 3HVC*V750 and 3HVC*V751


BOP STOP kitchen exhaust fan E-0,Step 20.f


f.SEC i iON 4

(



TaskAssicnTi me InAlnM2if Instructnr Information/Activitv Expected Action StandardI 1111�

BOOTHINST

NOTE When called, WAIT 3 - 5 min, ThenREPORT "All Control Buildingpressure boundary doors are Closedand Dogged."

PEO Close and Dog (as applicable) ControlBuilding pressure boundary doors.

E-0,Step 20.g

RO Check RCS Temperature E-0, Step 21

Verify RCS cold leg WR temperature -BETWEEN 5500F and 5600 F

US Perform the applicable action:

E-0,Step 21.a

E-0,Step 21.a,RNO

US

* IF temperature is GREATERTHAN 550 0F AND 560 0F, THEN

1) Dump steam to the condenser,if available OR Dump steam toatmosphere.

2) Proceed to Step 22.

* IF the temperature is LESS THAN5500

THEN

Proceed to Step 21c.


(l (SECTION 4



AssicnTime InlAiMaif Instruictor Information/Activitv Expected Action Standard

US

BOP

BOP

BOP

Proceed to Step 22

Maintain total feed flow BETWEEN530 and 600 gpm until NR level isGREATER THAN 8% (42% ADVERSECTMT) in at least one SG

CLOSE SG atmospheric dump anddump bypass valves

Check the following valves - CLOSED

* MSIVs

* MSIV bypass valves


1. Place both condenser steam dumpinterlock selector switches to OFF.

2. IF unexpected cooldowncontinues, THEN

E-0,Step 21.b

E-0,Step 21.c

E-0,Step 21.d

E-0,Step 21.e

US

BOP

BOP

E-0,Step 21.e,RNO

CLOSE the MSIVs and MSIVbypass valves.

RO Check PZR Valves E-0, Step 22


(ISECTION 4



AsifinT;^- nA 1M1fi Intrni.tnr Infnrmftinn/Aectivitv ExDected Action StandardI HIM MV-MI ldll 1 II> u-vA ss||s4, rw- *s... .. ______

Verify PORVs - CLOSED

RO

RO

RO

RO

RO

RO

RO

IF PZR pressure LESS THAN 2350psia, THEN CLOSE PORVs.

IF any PORV can NOT be closed,THEN CLOSE its block valve.

IF block valve can NOT be closed,THEN Initiate monitoring of CSFStatus Trees and Go to E-1, Loss ofReactor or Secondary Coolant.

Verify normal PZR spray valves -CLOSED

IF PZR pressure LESS THAN 2270psia THEN CLOSE valves.

IF valves can NOT be closed, THENSTOP RCPs 1 and 2

E-0,Step 22.a

E-0,Step 22.a,RNO

E-0,Step 22.b

E-0,Step22.b,RNO

Verify PZR safety valves - CLOSED E-0,Step 22.c


(SEC i ION 4

(



TaskAQsinn Exoected Action StandardT: Ad IM A 1MIf

I ime IUtIjIVIdII I5IlLI1U%.LJUI I * . -ore

US IF PZR pressure decreasing in anuncontrolled manner, THEN initiatemonitoring of CSF Status Trees andGo to E-1, Loss of Reactor orSecondary Coolant

Check PORV block valves - OPEN

OPEN energized block valves.

To prevent damage to the RCPseal(s), seal injection flow should bemaintained to all RCPs.

E-0,Step 22.c,RNO

E-0,Step 22.d

E-0,Step 22.d,RNO

E-0,Step 23,CAUTION

CREW

RO Check If RCPs Should Be Stopped E-0, Step 23

Verify RCPs - ANY RUNNING

Proceed to step 24.

E-0,Step 23.a

E-0,Step 23.a,RNO.

RO Verify RCS pressure - LESS THAN1500 psia (1800 psia ADVERSECTMT)

EOP 35 E-0, Step 23.b


A

SEC; ION 4(.



TaskArminnT i_ A nrA IRU19 In~rss^t.r nfnrmftfiron1Adrfixvfx Exnected Action Standard

I ime I~iUIMMai IEIZ1U ULJE IEI'I IE-II*- - - -- --

US

RO

US

RO

Proceed to Step 24

Verify charging or Si pumps - ATLEAST ONE RUNNING

Proceed to Step 24

STOP all RCPs

E-0,Step 23.b,RNO

E-0,Step 23.c

E-0,Step 23.cRNO

E-0,Step 23.d

BOP/RO Check If SG Secondary BoundariesAre Intact

Check pressure in all SGs

E-0, Step 24

E-0,Step 24.a

* NO SG PRESSUREDECREASING IN ANUNCONTROLLED MANNER

* NO SG COMPLETELYDEPRESSURIZED

US Initiate monitoring of CSF StatusTrees and Go to E-2, Faulted SteamGenerator Isolation.

E-0,Step 24.aRNO


(SECTION 4

(



TaskAQqinnl~etffrnr nform-wnfirn1A&-*ivit Expected Action Standard_ _ I1.A IRA 15

I rne W/AltIU'.,L'E - --.. -5-

E-2, Faulted Steam GeneratorIsolation, Rev. 9

US At least one SG must be maintainedavailable for RCS cooldown.

E-2 CAUTION

US

US

Any faulted SG or secondary breakshould remain isolated duringsubsequent recovery actions unlessneeded for RCS cooldown or sampling isrequired.

If RWST level decreases to LESS THAN520,000 gal, Go to ES-1.3, Transfer toCold Leg Recirculation, to align theECCS system.

BOP Check Main Steam Isolation And

US Bypass Valves - CLOSED

US Check at least one SG boundaryintact.

RO/ BOP Check pressures in all SGs - AT LEASTONE STABLE OR INCREASING

US Identify Faulted SGS

RO/ BOP Check pressure in all SGs

ANY SG PRESS DECREASING IN ANUNCONTROLLED MANNER

OR

E-2, Step 1

E-2, step 2

E-2, step 2.a

E-2, Step 3

E-2, Step 3.a


(SECTION 4

(



Timem InAiMnif

Revision: 0

TaskAssicnInstnrutor Information/Activitv Expected Action Standard

2, Step 4s - vrzl .- .. I

[Critical Task] Isolate the faultedS/G before transition out of E-2

RO/BOP

RO/BOP

ANY SG COMPLETELYDEPRESSURIZED

If the TD AFW pump is the only availablesource of feed flow, a steam supply tothe TD AFW pump must be maintainedfrom at least one steam generator

Isolate each faulted SG.

* Isolate main feed line

* TRIP TD FW pumps

* Place MD FW pump in PULL-TO-LOCK

* Isolate AFW flow path

* CLOSE steam supply isolation valveto TD AFW pump

* Verify SG atmospheric dump andbypass valves - CLOSED

* Verify SG blowdown isolation valve -CLOSED

* Verify SG blowdown sampleisolation valve - CLOSED

* Verify SG chemical feed isolationvalve - CLOSED

E-2, Step 4CAUTION

E-2, step 4


(

SEC;i ION 4



AssianTima^ InAIMnif Incfnier-Mr Infnrmatinn/Activitv Expected Action StandardI * * I I1U *9 f u t . .a . . . .#. -

* Using table, Verify main steam linedrains upstream of MSIVs and TDAFW pump - CLOSED

SG A SG B SG C SG D

3DTM*AOV29A 3DTM*AOV29B 3DTM*AOV29C 3DTM*AOV29D

3DTM*AOV61A 3DTM*AOV61B 3DTM*AOV61C 3DTM*AOV61D

3DTM*AOV63A 3DTM*AOV63B 3DTM*AOV63D

3DTM*AOV64A 3DTM*AOV64B 3DTM*AOV64D

RO/ BOP/US

Close valve(s) or isolation valve(s).

IF flow path(s) can NOT be isolated,THEN Dispatch an operator to locallyClose valve(s) using Attachment A forguidance

E-2 Step 4RNO

NOTE: IF crew performs S/G isolationin E-2 TERMINATE the exam aftercompletion of step 4 of E-2 AND FR-Z.1 (if conditions require)


!SEC;, iON 4

(.



TaskAqqinnInerrtgr nfnrrmntirn1A#-tiAit Exoected Action Standard_ _ InrA IRXl-1

I Ime IlUA/Wl4l IIlbI UY.LIW IIIIEaJI * ' - -

FR-Z.1, Response to CTMT HighPressure, Rev. 11

NOTE: If the crew anticipates highCTMT pressure they may not bedirected to perform FR-Z.1

US/RO Check if CDA Required

RO Check CTMT pressure GREATERTHAN 23 psia

US

RO

US

RO

RO

RO

Verify Annunciator "CTMT DEPRESACTUATION" (MB2B 5-5)-LIT

Verify CIB

Check ESF Group 2 columns 2Through 10 - LIT

Verify CIB

Check RPCCW Ctmt supply and returnheader isolation valves - CLOSED

Check RPCCW pumps - STOPPED

STOP all RCPs

If ECA-1.1, Loss of EmergencyCoolant Recirculation, is in progress,Ctmt spray should be operated asdirected in ECA-1.1 rather than steps3, 4, and 7

FR-Z.1,Step 1

FR-Z.1,Step 1.a

FR-Z.1,Step 1.b

FR-Z.1,Step 2

FR-Z.1,Step 2.a

FR-Z.1,Step 3

FR-Z.1,Step 3.a

FR-Z.1,Step 3.b

FR-Z.1,Step 3.c

FR-Z.1,Step 4CAUTION


(SEC I-ION 4

(



Time IDA/Malf

TaskAssinn1--4-tn^r#r I nferrMntirsn/Ae-fivifV

111Q ,L Mu L J ,I,,v, v *

US

RO

RO

RO[Critical Task]

Expected Action

Verify Quench Spray SystemOperation

Check annunciator RWST EMPTYQSS PP OFF (69,331 gal)(MB2A 5-2)not lit)

Verify quench spray pumps -RUNNING

START pumps.

Verify quench spray pump dischargevalves (3QSS*MOV34A and3QSS*MOV34B) - OPEN

OPEN valves.

STOP All Main Circulating WaterPumps

Check Containment Ventilation

* Verify CAR fans - STOPPED

* Verify CRDM fans - STOPPED

Revision: 0

Standard

FR-Z.1,Step 4

FR-Z.1,Step 4.a

FR-Z. 1,Step 4.b

FR-Z.1,Step4.b,RNO

FR-Z.1,Step 4.c

FR-Z. 1,Step 4.c,RNO

FR-Z.1,Step 5

FR-Z.1,Step 6

RO

[Critical Task] RO

BOP

BOP


EVALUATION GUIDE

Title: ATWS with Faulted S/G


Time IDA/Malf Instructor Information/Activity Assign Expected Actions Standard

US Verify Recirculation Spray System FR-Z.1,Operation Step 7

RO Check annunciator CTMT RECIRC FR-Z.1,PUMP AUTO START SIGNAL on Step 7.a(MB2B 1-8) - LIT

US Proceed to step 9 and, WHEN 11 FR-Z.1,minutes have elapsed since CDA Step 7.a,initiation, THEN Perform steps 7b RNOthrough 7e.

RO Check recirculation spray pumps - FR-Z.1,RUNNING Step 7.b

RO Proceed to step 7.d FR-Z.1,Step 7.bRNO

RO Proceed to step 7.f FR-Z.1,Step 7.c

RO Check Ctmt WR sump level is FR-Z.1,GREATER THAN 1.5 feet Step7.d

RO START recirculation spray pumps FR-Z. 1,Step 7.e

RO Check recirculation spray pump suction FR-Z.1,isolation valves - OPEN Step 7.f

RO Verify recirculation spray pump FR-Z.1,discharge isolation valves - OPEN Step 7.g


(EVALUNI iON GUIDE

(

Title:

ID Number:

Time

ATWS with Faulted S/G

2K2 NRC-001

IDA/Malf InstrTask

uctor Information/Activity-

Assign Expected Actions

RO Check recirculation spray - FLOWINDICATED IN AT LEAST ONE TRAIN

RO Proceed to step 9

RO Verify ESF Group 4 Lights - LIT

CREW Operate components as necessary forminimum safety function.

US/ BOP Verify Main Steam Line Isolation

* Check MSIVs and MSIV bypassvalves - CLOSED

* Check ESF Status Group 3 lights -LIT

BOP Initiate MSI.

Revision: 0

Standard

FR-Z. 1,Step 7.h

FR-Z.1,Step 7.1

FR-Z.1,Step 9

FR-Z.1,Step 9,RNO

FR-Z.1,Step 10

FR-Z.1,Step 10,RNO

FR-Z. 1,Step 1 1

BOP/RO Verify Main Feedwater Isolation

* Verify MD AND TD FW pumps -TRIPPED

* Verify FW isolation trip valves -CLOSED


EVALUA I iON GUIDE

/

Title:

ID Number:

Time

ATWS with Faulted S/G

2K2 NRC-001

IDA/Malf InstrTask

Assian

Revision: 0

Standardi inftor 1nfnrmnfinn/Act.ivitv,~L -s-s, ,,,v, cvs.,\k .}.._U

US

US

US

BOP/RO

US

Expected Actions

* Verify SG feed regulating valves -CLOSED

* Verify SG feed regulating bypassvalves - CLOSED

At least one SG must be maintainedavailable for RCS cooldown.

If all SGs are faulted, at least 100 gpmfeed flow should be maintained to eachSG.

Check If Auxiliary Feedwater FlowShould Continue To All SGs




Go to Procedure and Step In Effect

FR-Z.1,Step 12,CAUTION

FR-Z.1,Step 12,CAUTION

FR-Z.1,Step 12

FR-Z.1,Step 12.a

FR-Z.1,Step 13

TERMINATE UPON Completion of FR-Z.1 AND Isolation of SIG (either in E-0, E-2, or FR-Z.1).


SECTION 4


EVALUATION GUIDE

I. SUMMARY

The following Critical Tasks are covered in this exam:

TASK DESCRIPTION TASK # K/A >I= 3.0 BASIS FOR SELECTION

Establish flow from at leastone Si pump beforecompletion of the check ofE-0, steps 1-14 in FR-S.1.

Manually actuate MSI orclose MSIV's beforecompletion of FR-S.1 step13.

Isolate the faulted S/Gbefore transition out of E-2

E-0-J 007 EA2.024.3/4.6

E-0-P 040 AA2.044.5/4.7

E-2-A 040 AA1.044.34.3

Failure to manually start atleast one intermediate -head ECCS pump underthe postulated conditionsconstitutes "mis-operationor incorrect crewperformance which leads todegraded ECCS capacity."

Failure to close the MSIVschallenges the CSFsbeyond those irreparablyintroduced by thepostulated conditions andconstitutes a"demonstrated inability bythe crew to recognize afailure of the auto actuationof an ESF system."

Failure to isolate a faultedSG that can be isolatedcauses challenges to CSFsbeyond those irreparablyintroduced by thepostulated conditions.

Note: ri Used to designate critical tasks. Should alsobe incorporated into column 3 or 4 ofInstructor Guide.


SECTION 4

Title: ATWS with Faulted SIG

ID Number: 2K2 NRC-001 Revision: 0EVALUATION GUIDE


SECTION 5

SCENARIO INITIAL CONDITIONS


Reactor Power: 50%, steady state Xenon

Operating History: 450 days on line

RCS Boron: 300 ppm

Core Burnup: 18,600 MWD/MTU

Condensate Demins:

Evolutions in Progress:

Major Equipment OOS:

5 demins in service

NONE

"A" PORV is inoperable due to an electrical short in thecontrol circuitry. It has been out of service for 8 hours.Electrical maintenance estimates that the valve will bereturned to service within 24 hours.

The following Tech Specs are applicable:Tech Spec 3.4.4, action b3TRM 7.4.1 action a.1 and a.3 for both the A PORV andthe block valve 3RCS*MV8000A

Crew Instructions:

The unit downpowered in response to a severe weather threat. The next shift will beginthe power increase. Maintain the plant at 50% power. Intake conditions are now Green.

The crew is directed to Pump the Containment Drains Transfer Tank in accordance withOP 3335A, Reactor Plant Gaseous Drains, section 4.4.

Plant/Simulator Differences:

* Real Time and Simulator Rad Monitor historical data not valid prior to the beginning ofthis exercise.

* Auto-log terminals need to be refreshed after entry is made.

* If not using the speed dial option on the phone system, the operator must dial either #3333or #3334 to reach the person/department they desire.

* The following PPC programs do not function on the simulator:

* Samarium Follow* Xenon Follow* Sequence of Events


SECTION 6

VALIDATION CHECKLIST



Remote functions:

All remote functions contained in the guide are certified.

Malfunctions:

All malfunctions contained in the guide are certified.

Initial Conditions:

The initial condition(s) contained in the guide are certified or have been developed from certified

IC's in accordance with NSEM-4.02.

Simulator Operating Limits:

The simulator guide has been evaluated for operating limits and/or anomalous response.

Test Run:

The scenario contained in the guide has been test run and validated (validation sheet

completed, next page)on the simulator. Simulator response is reasonable and as expected.

Examination Scenario Review

The dynamic examination review checklist is complete. (This is not required unless the exam

will be used as an Annual Exam, then NUREG 1021 requirements apply.)

11/20/2001

Technical Reviewer Date


SECTION 7

REFERENCE AND TASK TRACKING

ATWS with Faulted SIGTitle:


I. References:

OP3335A

ARP MB4B, 3-4B

AOP*3575

AOP*3564

EOP*E-0

EOP*E-2

EOP*FR-S. 1

EOP*ERGEXE

EOP* Step DOC

EOP*ERGHP

FAP06*01

NUREG*1021 rev 8

Reactor Plant Gaseous Drains

RCP B Cooler Supply Pressure Low

Rapid Downpower

Loss of One Protective System Channel

Reactor Trip or Safety Injection

Faulted Steam Generator Isolation

Response to Nuclear Power Generation I ATWS

Westinghouse Owners Group Executive Document

MP3 step deviation Document

Westinghouse Owners Group Background Document

Event Assessment, Classification and Reportability

Examiners Standards

I


Initial Dynamic Simulator Scenario

NUREG-1021, Appendix D, Attachment 1



I. Summary:

Facility: Millstone 3 PWR:_ Scenario No: 2K2NRC-001 Op-Test No: 2K2

Examiners:_ Operators:

Initial Conditions: IC-22; 50% power, end of life

The "A" PORV is out of service due to an electrical short in the control circuitry

Event Malf. Event Event DescriptionNo: No. Type *

I N(US) Pump the Containment Drains Transfer Tank

2 CC03B C(RO) Partial Loss of RCP B Cooling water Supply

2a R(ALL) Rapid Downpower to Remove RCP

3 ED08C C(ALL) Loss of Instrument Bus VIAC-3

4 FW08A I(BOP) A S/G Feed Reg Valve Failure5 I/Os 32N M(ALL) AT\NS; 32N Fails to De-energize

RP09A/BRP10A/B

6 CV18 C(RO) Charging Flow Control Failure

7 RP11 E C(RO) SIH Fails to Align on SIS

8 MS01 D M(ALL) Main Steam Line D Rupture Inside CTMT

9 RP08 I(US/ MSI Fails to Auto ActuateBOP)

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


SECTION 8MILLSTONE UNIT 3

SIMULATOR SCENARIO ATTRIBUTES CHECKLISTFORM ES-301-4

Exam Title: ATWS with Faulted S/G


Assessor: Steve Jackson

QUALITATIVE ATTRIBUTES

_Y_1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out of

service, but it does not cue the crew into expected events.

_Y_2. The scenario consists mostly of related events.

_Y_3. Each event description consists of:

- the point in the scenario when it is to be initiated- the malfunctions(s) that are entered to initiate the event

- the symptoms/cues that will be visible to the crew- the expected operator actions (by shift position)- the event termination point (if applicable)

_Y_4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenario

without a credible preceding incident such as a seismic event.

_Y_5. The events are valid with regard to physics and thermodynamics.

_Y_6. Sequencing/timing of events is reasonable, and allows for the examination team to obtain

complete evaluation results commensurate with the scenario objectives.

_N/A_7. If time compression techniques are used, scenario summary clearly so indicates. Operators have

sufficient time to carry out expected activities without undue time constraints. Cues are given.

_Y_8. The simulator modeling is not altered.

_Y__9. The scenario has been validated. Any open simulator performance deficiencies have been

evaluated to ensure functional fidelity is maintained while running the scenario.

Y__10. Every operator will be evaluated using at least one new or significantly modified scenario. All other

scenarios have been altered IAW Section D.4 of ES301

Y_11. All individual operator competencies can be evaluated, as verified using form ES-301-6.

Y_12. Each operator will be significantly involved in the minimum number of transients and events

specified on Form ES-301-5. (Form submitted with simulator scenarios).

Y__13. Level of difficulty is appropriate to support licensing decisions for each crew position.




Lesson Title: ATWS


Note: Following criteria list scenario traits that are numerical (QUANTITATIVE) in nature.

01. Total Malfunctions (TM) - Include EM's- 5 to 8 requiredLoss of RCP B Cooling water Supply, Charging Flow Control Failure, MSI Fails to

Auto Actuate, Main Steam Line D Rupture Inside CTMT, Loss of Instrument Bus VIAC-3, A

SIG Feed Reg Valve Failure, SIH Fails to Align on SIS

02. Malf s after EOP entry (EM's)- 1 to 2 required

SIH Fails to Align on SIS, MSI Fails to Auto Actuate,

03. Abnormal Events (AE)-2 to 4 required

Loss of RCP B Cooling water Supply, Loss of Instrument Bus VIAC-3, A S/G Feed Reg

Valve Failure

04. Major Transients (MT)-1 to 2 required

ATWS/32N Fails to De-energize, Main Steam Line D Rupture Inside CTMT

05. EOP's (EU) entered/requiring substantive actions 1 to 2 required

E-O, E-2

06. EOP Contingencies requiring substantive actions [ECAs/FRs](EC) 0 to2 required

FR-S.1, FR-Z.1

07. Critical Task (CT) - 2 to 3 required

E-0-J: Establish flow from at least one Si pump before completion of thecheck of E-0, steps 1-14 in FR-S. 1.

E-0-P: Manually actuate MSI or close MSIV's before completion of FR-S. 1step 10.

E-2-A: Isolate the faulted S/G before transition out of E-2

08. Approximate Scenario Run Time: 45 to 60 min. (One scenario mayapproach 90 minutes)

Total: 7

Total: 2

Total: 3

Total: 2

Total: 2

Total: 2

Total: 3

Total: 70 min

09. EOP run time: Total: 40 min

10. Technical Specifications are exercised during the scenario. (Y/N)_Y_

NOTES: Reactivity Manipulation: Rapid Downpower to Remove RCP



SIMULATOR EXAM

SIM-002

EXAMINATION

08/12/02 - 08/15102

MILLSTONE POWER STATION ANRC SIMULATOR EXAM GUIDE APPROVAL SHEET

Exam Title:

Revision:

SGTR WITHOUT PZR PRESSURE CONTROL

0


This document is the property of Millstone Power Station, which controls itsdistribution. Further transfer, copying, and modification of this document are


e I4SK S.1'�z�- 4 1--610'04"s " , 'I.� . VqQ-."

OR -PII'l-fiWiP ! EF'."'g 0 iI-wp� I

SECTION 2


TABLE OF CONTENTS


1. Cover Page


3. Exam Overview

4. Evaluation Guide





Attachments


~TO ACe. .R ........... !

SECTION 3

EXAM OVERVIEW

Title: SGTR WITHOUT PZR PRESSURE CONTROL


Exam Brief:

1. The plant is at 100% power, EOL steady state operations with all control systems in

automatic. The "A" PORV is out of service due to an electrical short in the control circuitry.

The crew is initially directed to reduce CTMT pressure to 13.80 psia using OP 3313E,

Containment Vacuum, section 4.2. After the evolution has commenced, the Digital Rod

Position Indication system will experience a Data A failure on rod D12. AOP 3552,

Malfunction of the Rod Drive System with Attachment C will direct the crew's actions. Tech

Specs should be reviewed for this malfunction.After Tech Specs have been reviewed, a tube leak will occur on the "C" S/G. A small

increase in charging flow and radiation alarms on ARC21, Air Ejector Rad Monitor, and N-16

alarms will indicate the problem to the crew. The crew may use the guidance in AOP 3573,

Radiation Monitor Response, or may go directly to AOP 3555, Reactor Coolant System Leak.

AOP 3555 and the N-16 ARP will direct the crew to AOP 3576, Steam Generator Tube Leak.

Conditions are present to require a power reduction to be in MODE 3 within 6 hours (AOP

3576 step 9.j).When the power reduction is underway a Rod Bank CB-D Continuous Rod Insertion

will occur. The crew should place the control rod bank SEL switch in MAN and when this

does not stop rod motion, trip the reactor and go to E-0, Reactor Trip or Safety Injection. At

the time of the reactor trip the SIG leak will worsen into a SGTR [Critical Task -2: Isolate

Steam and Isolate Feed] and a loss of Offsite power will occur. The EDGs will both start

and provide power to the emergency buses but offsite power will not return during the

scenario. The C Service Water pump will trip at the reactor trip and the A SWP will not

automatically start. Manual action will be required to start the A Service Water pump [Critical

Task]. The crew should proceed through E-0 and transition to E-3, Steam Generator Tube

Rupture. At step 3.i of E-3 the "C" MSIV will not close and the RNO will be implemented.

Time compression techniques are used to complete Attachment A referenced in the step 3.1.

At step 18 of E-3 the crew will be unable to depressurize the RCS due to one PORV out of

service (initial condition), one PORV failing to open, and auxiliary spray unavailable due to the

CTMT Instrument Header isolation valve, 31AS*MV72, failing to open. This will require the

crew to transition to ECA-3.3, SGTR Without Pressure Control.The scenario will end when the crew has completed step 8 of ECA-3.3.

2. The SM should classify this event as a Alert - Charlie One due to Loss of RCS Barrier

(RCB4).



SECTION 4

EVALUATION GUIDE

SGTR WITHOUT PZR PRESSURE CONTROLTitle:


All Control Room Conduct, Operations and Communications shall be in accordance withMP-14-MMM.




It is the responsibility of the Instructors in the simulator to insure that exam interruptions have a

minimum negative impact on the Crew and the examinations we provide.

Be aware that at all times the Operators should treat the simulator as if it were the plant and

you too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the exam

in progress (computer fault, etc.) the Instructor should:



3. Request that the Crew leave the simulator control room. (The Crew should leave

the simulator for problems which involve major switch alignments).


5. After the Instructors believe the simulator is restored to service, the Crew should

be told how the exam will continue. If it is possible and felt to be acceptable to

the evaluators, the examination can begin where it left off with an update on

plant parameters and each Crew member is prepared to restart. If theexamination will not begin where it left off, the crew should be told how andwhere the exam will begin again.

6. Once the Crew has been told how and where the exam will begin, have the crewconduct a brief so that the Instructor and evaluators can insure that the crew hasall the necessary information to continue with the scenario.

7. Once all Crew members, Instructors and evaluators are satisfied that they havethe necessary information to continue the scenario, place the simulator in RUN

and announce to the Crew that you have continued the evaluation session.


( (#(SECTION 4



TaskTime IDA/Malf Instructor Information/Activity Assign Expected Action Standard








6. RESET to IC 90: TEMP IC 2K2NRC-LOUT-002 (based on IC 21)



9. ADJUST MWt using Turbine Load Set to 3411, (+)O, (-)3 IF using 100% power IC.









,X

SECI iUN 4



Task


f. VERIFY annunciator, "COMPUTER FAILURE" (MB4C, 1-11), is NOT LIT.


1) See laminated directions on clipboard in Sim booth.


a. MB2, (AY6), CVCS Data Trend, 1 minute update, CHS-F132 (40-120), CHS-L112 (40-80), CHS-F121 (40-80), RCS-L461 (40-80)

b. MB4, (AY1), At Power Data Trend, 15 second update, CVQRPI, (3391-3428), CVQRPHRUN (3409-3413), CVQRP (3409-3413), RCL-

T412*, (585-588)





14. OVERRIDE the annunciators that will be lit longterm in the CR, (as listed in the "Lit CRP Annunciators" section of the MP3 daily Status Report

hanging near instructor booth door).

15. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under

"Equipment OOS."


17. HANG a Caution Tag on 3RCS*MV8000A stating, "Caution Tag 3RCS*MV8000A Closed and de-energized IAW Tech Spec 3.4.4. action b"

18. HANG DRPI Console picture/diagram (A+B switch position) on Main Board Door directly behind MB4.


fSECTiUN 4

Title:

ID Number:

Time


2K2 NRC-002

IDA/Malf Instructor Information/Actii

Revision: 0

TaskAccinnliti, Exnected Action Standard

- -


(SECTION 4


(

Title:


TaskAssianTime InA/Malf Instructor Information/Activitv Expected Action Standard

-1

PLACE THE FOLLOWING EQUIPMENT OOS: STANDARD 2K2NRC EXAM EQUIPMENT


1/01/01/01/01/01/0

(RC)(RC)(RC)(RC)(RC)(RC)

3RCS*PCV455A3RCS*PCV455A3RCS*PCV455A3RCS*PCV4563RCS*MV80003RCS*MV8000

A PORVA PORVA PORVB PORVA PORV Block ValveA PORV Block Valve

OPEN - FALSEGREEN - FALSERED- FALSEOPEN - FALSEGREEN - FALSERED- FALSE

MALF

MALF

SG01C

ED01

Steam Generator "C" Tube Rupture

Loss of Offsite Power

50% 30 second ramp BT1

BT1

I/O (IA) 31AS*MOV72 IAS CTMT Isolation OPEN - FALSE BT1

MALF

MALFMALF

MS12C

SW01CSW02A

MSIV "C" Stuck Open

Service Water Pump C TripsService Water Pump A Fails to Auto Start

BT1


SECTION 4



(.

Revision: 0

TaskAssianTima IMAIM2If Instructor Information/Activitv Expected Action Standard

Event Malfunctions

MALF

MALF

MALF

RD1 0-59

SG03C

RD021 (eye)

Control Rod Position Failure Data A - Rod D12

Steam Generator "C" Tube Leak 100% (46 gpm)

Rod Bank CB-D Continuous Rod Insertion

60 second ramp

RSCU 1

RSCU 2

RSCU 3



(SECTION 4



TaskAssiqnTime IDA/Malf Instructor Information/Activity Expected Action Standard

T+1 EVENT 1: Reduce CTMT Pressure

OP3313E CTMT Vacuum, Rev. 8

US

US

RO

Do not reduce containment pressure below13.75 psia if a CTMT entry is anticipated

One CTMT vacuum pump is operatedperiodically to maintain 3LMS*PI24A and3LMS*PI24B containment pressure 13.7 to13.9 psia, (MB2)

IF using 3CVS-PlA, containment vacuumpump A, PERFORM the following:

OP331 3EStep 4.2.1CAUTION

OP331 3EStep 4.2.1NOTE

OP331 3EStep 4.2.1

RO

RO

RO

OPEN 3CVS*CTV20A, "CTMT VAC PP"(MB1)

OPEN 3CVS*CTV21A, "CTMT VAC PP"(MB1)

START 3CVS*P1A, "CTMT VAC PP'S""1A" (MB2)

OP331 3EStep 4.2.1.a

OP331 3EStep 4.2.1.b

OP331 3EStep 4.2.1.c

T= normalevolutioncommenced

MALFRD1 0-59

EVENT 2: Control Rod PositionFailure Data A - Rod D12

RO


(SECT iON 4



Time IDA/Malf

RSCU #1

.

Instructor Information/Activity

AOP 3552 Rev. 3MALFUNCTION OF THE RODDRIVE SYSTEM

TaskAssign

CREW

RO

RO

CREW

US

US

US

US

RO

Expected Action

Stabilize Plant Conditions

Place control rod bank SEL switch in MAN

Verify - NO RODS MOVING

Stop any power increase or decreaseevolutions in progress.

Verify Tavg - Tref deviation - LESS THAN

OR EQUAL TO 1.50F

Verify TURB LOAD REJECTION ARM C-7(MB4D 6-6) annunciator - NOT LIT

Borate or Dilute as necessary to maintainTavg within 1.50F of Tref

Check No Rod Dropped

Verify RPI URGENT FAILURE (MB4C 4-10) annunciator - NOT LIT

Check rod bottom lights - NONE LIT

Revision: 0

Standard

AOP 3552Step 1

AOP 3552Step 1.a

AOP 3552Step 1.b

AOP 3552Step 1.c

AOP 3552Step 1.d

AOP 3552Step 1.e

AOP 3552Step 1.f

AOP 3552Step 2

AOP 3552Step 2.a

AOP 3552Step 2.b


I.SECTION 4


(


TaskAssianTimu IMAIMnif Instrumtnr Infnrmation/Activitv ExDected Action Standard9 llE VIll>l | .-. .... __.._.. .-- .. _., __,___ _

us Check No Rod Position IndicationMalfunctions

AOP 3552Step 3

Verify DRPI power available

* Any DRPI display light lit

Verify status of following annunciators:

AOP 3552Step 3.a

AOP 3552Step 3.b

NOTE: Annunciator IS LIT RPI NON URGENT FAILURE(MB4C 3-10) annunciator - NOTLIT

* RPI URGENT FAILURE (MB4C 4-10) annunciator - NOT LIT

Determine rod position indicationmalfunction using Attachment C.

NOTE: US will most likelytransition to the Attachment at thisstep

US AOP 3552Step 3, RNO

Verify status of DRPI display alarms: AOP 3552Step 3.c

* URGENT ALARM - NOTFLASHING

NOTE: DATA A IS Flashing DATA A FAILURE - NOTFLASHING


SECTION 4


I


TaskAssianTime InAiM2nIf Instrutiror Infnrmation/Activitv Expected Action Standard

I 11111U ---. - -- j

* DATA B FAILURE - NOTFLASHING

* Rod GW- NONE FLASHING

* CENTRAL CONTROL FAILURElights - NONE LIT

Determine rod position indicationmalfunction using Attachment C.

Check DRPI Power Supply

US AOP 3552Step 3, RNO

AOP 3552, ATTACHMENT C

RO

US

RO

Verify DRPI display lights - NONE LIT

AOP 3552 AttC Step 1

AOP 3552 AttC Step 1.a

AOP 3552 AttC Step 1.a,RNO

Proceed to Step 2.

A DRPI URGENT ALARM indicates one ofthe following:

AOP 3552Attachment CStep 2, Note

* Error in both data A AND data Bfrom detector/encoder cards.

* Codes from data A and data Bdiffer by GREATER THAN 1 bit


l'I (

SECTiuN 4



TaskAssianTr.," IlAiMinIf Inctriu-tor Infnrmation/Activitv Expected Action Standard

I11111 vIll~ Lf.| ...... i....#.. ,.__,,_,

* The binary sum of data A and dataB data exceeds 38.

RO

US

US

US

US

RO

RO

Check For DRPI Urgent Alarm

Verify DRPI display URGENT ALARMlights - FLASHING

Proceed to NOTE prior to Step 3

* Loss of Data A will result in DRPIhalf-accuracy of +10 and -4 stepsfor affected rods.

* Loss of Data B will result in DRPIhalf-accuracy of +4 and -10 stepsfor affected rods.

Check For DRPI Non-Urgent Alarm

Verify RPI NON URGENT FAILURE(MB4C 3-10) annunciator - LIT

Verify DRPI Display DATA A FAILURE ORDATA B FAILURE lights - FLASHING



AOP 3552AttCStep 2.a,RNO

AOP 3552 AttC Step 3,Note



AOP 3552 AftC Step 3.a

AOP 3552 AttC Step 3.b


SEC! 1UN 4



TaskAssianTima- InflMnif Inctrmietnr InfnrmationlActivitv Expected Action Standard

I11111U vllz a-......- %,w ........a_.<

NOTE: If asked or if boardoperator is sent to DRPI cabinet,"ACCURACY MODE switch is inA+13"

RO Verify ACCURACY MODE selector switch(back of DRPI cabinet) - A + B POSITION

AOP 3552 AttC Step 3.c

RO Identify affected rod(s) as follows:

* General Warning (GM) lightflashing

Verify affected rod(s) indicates within ± 12steps of associated group Step counterdemand height

AOP 3552 AttC Step 3.d

AOP 3552 AttC Step 3.e

RO

NOTE: When requestedacknowledge direction and after 1minute REPORT that theACCURACY MODE switch is in BONLY position

RO Perform the applicable action: AOP 3552 AttC Step 3.e,RNO* IF DRPI display DATA A FAILURE

lights flashing, THEN

1) Place ACCURACY MODE selectorswitch (back of DRPI cabinet) in B ONLYposition.

2) Proceed to Step 3.g

Verify affected rod(s) indicated within ± 12steps of associated group Step counterdemand height

RO AOP 3552 AttC Step 3.g


Title:

SECTION 4


(


TaskAssianTime- InAIMlif Inttrunrfnr Infnrmation/Activitv ExDected Action Standard

I loil vsnz,,,,,,,.,..Z,_ ,_ _

NOTE: After notified as l&C informthe US that it is okay to return therods to Automatic. Once the rodsare in auto then...

Notify I & C AOP 3552 AttC Step 3.h

Proceed to Event 3

US

US

RO

US

US

US

A Central Control Card failure does notimpair system operation since the threecards are redundant, handling both data Aand data B.

Check For Central Control Card Failure

Verify DRPI display any CENTRALCONTROL FAILURE 1 2 3 light - LIT


In "half accuracy" operation, the affectedrod position will be indicated by every otherLED as the rod is raised or lowered.

Perform Follow-up actions




AOP 3552 AttC Step 4.a,RNO




( (SECTION 4



TaskAssiqnTime IDA/Malf Instructor Information/Activitv Expected Action Standard

T=completestep 3 ofAOP3552, Aft.C androds inauto

MALFSG03C

100%

EVENT 3: Steam Generator "C"Tube Leak

NOTE: Crew can enter AOP 3573,AOP 3555 (pg. 15), or AOP 3576(pg. 16) based on MALFindications.

AOP 3573, Radiation MonitorAlarm Response, Rev. 12

US If alarms are actuated on both area andprocess monitors, the applicable steps inthis procedure for each alarm may beperformed concurrently.

Check Initiating Monitor - AN AREAMONITOR

AOP 3573,Step 1,NOTE

AOP 3573,Step 1

RO

US

US

RO

RO

Proceed to step 3. AOP 3573,Step 1 RNO

Identify Affected Process UsingAttachment A

Check initiating process monitor - INALARM

Verify automatic actuations stated inAttachment A - OCCURRED

AOP 3573,Step 3

AOP 3573,Step 3.a

AOP 3573,Step 3.b


Title:

SECTIUN 4



TaskAsctinnAt: i_ IFrA IRN-1I l~etrtnr Ifnrr"mftin1A*tivitv Exoected Action Standard

l ime IlUA/IElldI EHOI MLL'JtU I **** ~ ac i * ..y r , -ads -

Monitor Sample Stream/Possible Automatic/SubsequentActions

ARC21-1 Condenser air ejector discharge to Monitorradioactive gaseous waste. radiation

monitorsPossible indication of primary to MSS75 -

secondary leakage. MSS79 and

SSR08 forpossible 1°to 20 leak.

Takeappropriateaction usingAOP 3555,ReactorCoolantLeak.

AOP 3555, Reactor CoolantSystem Leak, Rev. 14

RO Check PZR Level - DECREASING AOP 3555Step 1

Proceed to NOTE prior to step 7

CREW Steps 7 through 17 may be performed inany order.

AOP 3555Step 1 RNO

AOP 3555Step 7,NOTE


(SECTiuN 4



TaskAssignTime IDA/Malf Instructor Information/Activity Expected Action Standard

US

US

US

RO

Determine Leak Rate Using One OrMore Of the Following:

* Computer program 3J3

* Inventory balance

* VCT level trend

Check If SG Tubes Are Intact

Verify trend history and alarm status ofradiation monitors:

* Main steamline - NORMAL

* Condenser air ejector - NORMAL

* SG blowdown - NORMAL

Go to AOP 3576, Steam Generator TubeLeak.

Foldout Page must be open.

Verify PZR Level

Check PZR Level - DECREASING

AOP 3555Step 7

AOP 3555Step 8

AOP 3555Step 8.a

AOP 3555Step 8 RNO

3576 Step 1NOTE

3576 Step 1

3576Step 1.a

AOP 3576: Steam GeneratorTube Leak, Rev. 001

US

RO


( (SECTION 4




Proceed to step 2. 3576Step 1.aRNO

US

US

Notify Chemistry 3576 Step 2

Request Chemistry perform SP 3861,"Primary to Secondary Leak RateDetermination," to:

3576Step 2.a

NOTE: Time and call back in 30minutes: Confirm "C" leak -20gpm

1. Determine the presence of primary tosecondary leakage.

2. Determine the leak rate.

3. Identify the leaking SG.

Note: There are 2/5 conditionswhich satisfies the step action.Crew should proceed

US

US/RO

SG tube leakage can be interpreted as"verified" when any two of the bulletedsubsteps of step 3 are satisfied.

Verify Primary To Secondary Leakage

* Check trend history and alarm status ofcondenser air ejector radiation monitor- NOT NORMAL

3576 Step 3NOTE

3576 Step 3

3576 Step 3Note: This condition exists

* Check trend history and alarm status ofsteam generator blowdown radiationmonitor - NOT NORMAL


(SECTION 4



Time IDA/Malf Instructor Information/Acti

Revision: 0

vityTask

Assign

Note: This condition exists

Note: This condition exists

Expected Action

* Check trend history and alarm status ofmain steam line radiation monitors -NOT NORMAL

* Check Chemistry grab sample -INDICATESPRESENCE OF PRIMARYTO SECONDARY LEAKAGE

* Check trend history and alarm status ofN16 monitors - NOT NORMAL

Perfom Monitoring of N16 MonitorTrends

Initiate monitoring of N16 monitor trends

Verify SG Blowdown Status

Check if blowdown should be isolated

Condenser air ejector radiation monitor -IN ALERT OR ALARM

Standard

RO

RO

3576 Step 4

3576Step 4.a

3576 Step 4

3576Step 5.a

OR

Steam generator blowdown radiationmonitor - IN ALARM

OR

Section 4Page 19of71

( (SECTIUN 4



TaskAssianYTim InAIMnlf I nstriuetMr I nfrmatinn/Activitv Expected Action Standard

I .,,,IU -... ...... .. , - - -,

Chemistry grab sample indicates primaryto secondary leakage - GREATER THANOR EQUAL TO 75 gpd

OR

N16 monitor in ALERT or HIGH

RO Check SG blowdown isolation valves -CLOSED

* 3BDG-CTV22A

* 3BDG-CTV22B

* 3BDG-CTV22C

* 3BDG-CTV22D

CLOSE valves.

Proceed to step 6.

3576Step 5.b

RO

US

3576Step 5.bRNO

3576Step 5.c

US

BOP

Limit Effects Of SecondaryContamination

Check auxiliary steam - SUPPLIED FROMMAIN STEAM

3576 Step 5

3576Step 6.a


Title:

SECTIUN 4


C



REMOTE NOTE: When directed as PEO,MSR01 use REMOTE MSR01 To start

Aux Boiler.

US/PEO Using OP 3331A, "Auxiliary Boiler, Steamand Condensate" Perform the following:

3576Step 6.b

1. Startup of auxiliary boiler A (B)

2. Shift auxiliary steam from main steamto auxiliary boiler system.

US/PEO Locally Close the condenser level controlvalve outlet isolation (3CNS-V12)

3576Step 6.c

3576Step 6.d

US Request HP determine if personnel shouldbe evacuated from affected areas

* Turbine Bldg (north end)

* Secondary sample sink

* CPE

* MS Valve Bldg

Evacuate personnel from affected areas 3576Step 6.e

NOTE: Not desired to implementC OP 200.11. INFORM US thatSTA will perform and notify US ofany required actions.

US Refer to C OP 200.11, "Operation of aCross Contaminated System," andPerform any required actions

3576Step 6.f


(i (SECTION 4



TaskAssian* *mu InAIMnlf Intruirtnr Infnrmation/Activitv Expected Action Standard

I 1lult vii ~ v| . |} _.<

US Check If Unit Shutdown Should BeInitiated

3576 Step 7

Check any of the following: 3576Step 7.a

Note: This condition exists RO * Condenser air ejector radiation monitor- IN ALERT OR ALARM

OR

* Chemistry grab sample indicatesprimary to secondary leakage in anySG - GREATER THAN OR EQUAL TO75 gpd

OR

* Condenser air ejector radiation monitorcorrelation to leak rate (gpd) indicatesprimary to secondary leakage -GREATER THAN OR EQUAL TO 75gpd

OR

* N16 monitor in ALARM

NOTE: Inform US that the SM willperform this task.

US Evaluate event using MP-26-EPI-FAP06-003, Unit 3 Emergency Action Levels(Barrier Failure)

3576Step 7.b


(IISECTION 4


(


TaskAssignT~rim MAIM2If Instructnr Information/Activitv Expected Action Standard

I 1819a .... q.. .......... .. .. __w ....

US

US

Check plant status - MODE 1 OR 2

Proceed to step 9.

3576Step 7.c

3576Step 7.d

3576 Step 9NOTE

US * The shutdown times provided are EPRIrecommendations and should not beachieved at the cost of plant stability orintentional reactor trip.

* If a unit shutdown is initiated based ona condenser air ejector or N16 monitorALERT or ALARM condition andsubsequent Chemistry calculationsindicate actual leakage does not meetor exceed a shutdown criterion, thenthe shutdown may be suspended.

* The rate of increase limit does notapply to leak rate spikes followed bydecreasing leak rates.

* Plant shutdown may be accomplishedusing AOP 3575, "Rapid Downpower,"or appropriate General OperatingProcedures as determined necessary.


( (SECtIuN 4



TaskAssignTime IDA/Malf Instructor Information/Activitv Expected Action Standard

[Tech Specs]

NOTE TO EVALUATOR: IF TechSpecs are not reviewed at thispoint, follow-up with US at end ofscenario (procedure does notspecifically direct Tech Specreview).

LCO 3.4.6.2.b & c, action b

US Perform Unit Shutdown 3576 Step 9

Verify a leakage rate of increase limit met: 3576Step 9.a

NOTE: The leak is about 40 gpm.This should be obvious to the

crew and they should answer yesat this step and continue to step9.b..IF they pause at this stepREPORT as Chemistry that initialindications are that the leak is > 20gpm.

* Check leakage increased in any SG by- GREATER THAN OR EQUAL TO 15gpd IN A 30 min PERIOD

OR

* Check condenser air ejector radiationmonitor RATE OF CHANGE ALARM -IN ALARM FOR 30 min

OR


SECTIuN 4



TaskTime IDA/Malf Instructor Information/Activity Assign Expected Action Standard

* Check N16 S/G Leak Detection Status(PPC) HIGH RATE (75 GPD & 15 GPDRISE IN 30 MIN) - IN ALARM

Proceed to step 9.d 3576Step 9.b

RO Check power level - GREATER THAN 357650% Step 9.d

US Initiate power reduction to be LESS THAN 357650% within 1 hour (downpower rate of Step 9.e3%/6/min or 5%/6/min recommended)

T= When EVENT 3a: Rapid Downpowerdirected due to S/G Tube Leak (AOPby AOP 3576)3576 [Reactivity Manipulation]

* A CONVEX requested emergency AOP 3575generation reduction should be Step 1completed within 15 minutes of NOTEnotification.

* If a unit shutdown is required, thetarget power level should be between20% and 25% reactor power.

* If at any time ROD CONTROL BANKSLIMIT LO - LO (MB4C 4 - 9)


( (SECTION 4



TaskAssignTime IDA/Malf Instructor Information/Activitv Expected Action Standard

annunciator is received, DO NOT go toAOP 3566, Immediate Boration.Immediately perform step 9.

AOP 3575 Rev. 7 CREW

US

US

Determine Power Reduction Rate(%/min).

Check desired power reduction rate -LESS THAN OR EQUAL TO 5%/min.

Check power reduction - CONVEXREQUESTED

AOP 3575Step 1

AOP 3575Step 1.a

AOP 3575Step 1.b

US Proceed to Step 1.d. AOP 3575Step 1.bRNO


AOP 3575Step 1.d

Total Power Change (A%)

10% 20% 30% 40% 50% 60% 70% 80%70% 80%____________ L .1. I .L. 4 4 4

115 3 3 3 5 5 5

30 0.5 1 1 3 3 3 3 3

45 0.5 0.5 1 1 3 3 3 3


(SECTION 4




Time to

Reduce

Power

(min)

60 0.5 0.5 1 1 1 3 3

75 0.5 0.5 1 1 1 1 3

90 0.5 0.5 0.5 1 1 1 1

105 0.5 0.5 0.5 0.5 1 1 1

120 0.5 0.5 0.5 0.5 1 1

135 0.5 0.5 0.5 0.5 1 1

150 _ 0.5 0.5 0.5 0.5 0.5 1

160 I 0.5 1 0.5 1 0.5 0.5 10.5 0.5

US

CREW

US

US

Check Rod Control In AUTO.

Align EHC Panel


Check LOAD LIMIT LIMITING light - LIT

AOP 3575Step 2

AOP 3575Step 3

AOP 3575Step 3.a

AOP 3575Step 3.b


(SECT1UN 4


!

Title:



BOP

BOP

BOP

BOP

US/RO

RO

Proceed to step 3.e. AOP 3575Step 3.bRNO

Intermittently Press DECREASE LOADpushbutton until LOAD LIMIT LIMITINGlight - NOT LIT

Rotate LOAD LIMIT SET adjust knob atleast one full turn in raise direction

Select DECREASE LOADING RATE toON

Select LOAD RATE LIMIT % MIN torequired power reduction rate (% min)

If at any time the power reduction rate ortarget power level must be changed,Return to step 1.




AOP 3575Step 3.c

AOP 3575Step 3.d

AOP 3575Step 3.e

AOP 3575Step 3.f

AOP 3575Step 4NOTE

AOP 3575Step 4

AOP 3575Step 4.a

AOP 3575Step 4.aRNO


Title:

ID Number:

Time

EVALUAI iON GUIDESGTR WITHOUT PZR PRESSURE CONTROL


IDA/Malf Instructor Information/Activity Assign

RO

RO

RO

RO

Expected Actions

* IF power reduction rate is 3% min,

THEN

Proceed to step 5.

Proceed to step 5.


Initiate Rapid Boration

Verify RCS makeup system in - AUTO

START one boric acid transfer pump.



OPEN charging line flow control valve, tomatch boric acid flow (3CHS-FI 183A)

Record time boration started

Time

(

AOP 3575Step 4.bRNO

AOP 3575Step 4.c

AOP 3575Step 5

AOP 3575Step 5.a

AOP 3575Step 5.b

AOP 3575Step 5.c

AOP 3575Step 5.d

AOP 3575Step 5.e

AOP 3575Step 5.f

Standard


alEVALUATION GUIDE



AssiqnTime IDA/Malf Instructor Information/Activity Expected Actions Standard

Energize all PZR heaters. AOP 3575Step 5.g

Determine required boric acid addition bymultiplying total power change (A%) by 15(gal/%) = _ gal.

Determine required time to borate bydividing required gallons of boric acid bythe direct boric acid flowrate (net chargingflow rate if using gravity boration) -

min.




US

US

US

AOP 3575Step 5.h

AOP 3575Step 5.i

AOP 3575Step 5.j

AOP 3575Step 5.jRNO

AOP 3575Step 5.k


Title:

(EVALUATION GUIDE


i.


AssianTimn IflAIRM If I nstri irctr I nfnrmation/Activitv Expected Actions StandardaIt I 1lIv -v1ll .svvv zw bev - .. Oa - - ....- . .r.--- 1-----

CREW Boric acid total volume addition and flowrates are based on approximations.Adjustments should be made to thesevalues as necessary to ensure the reactorreaches the desired end state of:

AOP 3575Step 6NOTE

US

US/RO

RO

US

RO

RO

RO

* Tavg on program

* Rods above the Rod Insertion Limit

* AFD on or above the target value

Align RCS Makeup System ForBoration.

Determine required boric acid addition bymultiplying total power change (A%) by15(gal/%) = _ _gal.

Set the boric acid batch counter to totalgallons of boric acid required.

Check power reduction rate- AT 0.5%/min.

Adjust boric acid blend flow controller potsetting to 3.75 (15 gpm) and Proceed toStep 6.e.

Adjust boric acid blend flow controller potsetting to 1.9 (7.5 gpm).

Select BORATE on the reactor coolantmakeup select switch.

AOP 3575Step 6.b

AOP 3575Step 6.c

AOP 3575Step 6.cRNO

AOP 3575Step 6.d

AOP 3575Step 6.e


AOP 3575Step 6

AOP 3575Step 6.a

(EVALUAI ION GUIDE


i

Title:


AssiqnTime InA/MIMlf Instructor Information/Activity Expected Actions Standard,,,,, ,a, . m., .. . ___._ ............... _ ..... ... ......... .. .. ,

RO

RO

US

RO

RO

Select START on the reactor coolantmakeup start switch.

Verify boric acid flow - INDICATED

Return to step 5.


If a unit shutdown is being performed, thefinal MWe load should be approximately230 MWe.

Initiate Load Reduction.


Check rapid or gravity boration - INPROGRESS


Check LOAD RATE LIMIT % MIN set at -3% OR 5%.LIMITING light - LIT.

US/BOP

AOP 3575Step 6.f

AOP 3575Step 6.g

AOP 3575Step 6.gRNO

AOP 3575Step 6.h

AOP 3575Step 7NOTE

AOP 3575Step 7

AOP 3575Step 7.a

AOP 3575Step 7.b

AOP 3575Step 7.bRNO

AOP 3575Step 7.c


BOP

BOP

BOP

BOP

(EVALUA! iON GUIDE


(,

Title:


AssignTime IDA/Malf Instructor Information/Activity Expected Actions Standard

BOP

BOP

BOP

US

BOP

US/RO

US

Select LOAD RATE LIMIT % MIN to 3% or5%.

Utilizing DECREASE LOAD pushbutton,Adjust LOAD SET to desired final MWe(target power level)

Check power reduction - CONVEXREQUESTED.

Inform CONVEX of load reduction rate(MWe/min) and final MWe level.

Maintain initial MVAR loading during powerreduction, unless directed otherwise.

Check boration - IN PROGRESS

Return to step 5.

AOP 3575Step 7.cRNO

AOP 3575Step 7.d

AOP 3575Step 7.e

AOP 3575Step 7.eRNO

AOP 3575Step 7.f

AOP 3575Step 7.g

AOP 3575Step 7.gRNO

T= powerreductioninprogress

MALFRD021

EVENT 4: Rod Bank CB-DContinuous Rod Insertion

RSCU3


( (:EVALUATION GUIDE


ID Number:

Time


AssignIDA/Malf Instructor Information/Activity Expected Actions Standard

AOP 3552 MALFUNCTION OFTHE ROD DRIVE SYSTEM, Rev.3

CREW Stabilize Plant Conditions AOP 3552Step 1

RO

RO

CREW

Place control rod bank SEL switch in MAN

Verify - NO RODS MOVING

TRIP the reactor and Go to E-Q, ReactorTrip or Safety Injection.

AOP 3552Step 1.a

AOP 3552Step 1.b

AOP 3552Step 1.bRNO

MALFSG01C50%ED01

EVENT 5: SGTR with Loss ofOffsite Power

E-O, Reactor Trip or SafetyInjection, Rev. 21

Crew Go to E-0, Reactor Trip or Safety Injection.

* Foldout page must be open E-0, Step 1,NOTE

* ADVERSE CTMT defined asGREATER THAN 180 0F or GREATERTHAN 105 R/hr in containment.

* The reactor can be interpreted as"tripped" when any two of threebulleted substeps of Step 1.* aresatisfied.


(aEVALUATION GUIDE


1

Title:


AssiqnTime IDA/Malf Instructor Information/Activity Expected Actions Standard

RO

BOP

BOP

BOP

US

RO

US

Verify Reactor Trip



* Check neutron flux - DECREASING

Verify Turbine Trip

Check all turbine stop valves - CLOSED

Verify Power to AC Emergency Busses

Check busses 34C and 34D -

BOTH ENERGIZED


Verify SAFETY INJECTION ACTUATIONannunciator - (MB4D 1-6 or MB2B 5-9) -LIT

Check if Si is required

E-0, Step 1

E-0, Step 2

E-0,Step 2.a

E-0, Step 3

E-0,Step 3.a

E-0, Step 4

EOP 35 E-0,Step 4.a

E-0, Step 47RNO

* CTMT pressure GREATER THAN 18psia

OR

* RCS pressure LESS THAN 1890 psia


(EVALUAI ION GUIDE



AssianTime IDA/Malf Instructor Information/Activity Expected Actions Standard. | . .. ..... % .. _ _. _. ... ... ...... _ .. ... .. .... ... ,I,

OR

* PZR level LESS THAN 16%

OR

* RCS subcooling LESS THAN 320F

OR

* SG pressure LESS THAN 660 psig

IF Si is required, THEN initiate Si andProceed to step 5

MALFSW01ASW02C

EVENT 6: Service WaterPumps Fail to Auto Start

[Critical Task] Manually start theB Train Service Water Pumpbefore transitioning from E-0.

NOTE: If the A SWP does not starton the first time REPORT as PEOor Maintenance, if requested, andrecommend a second attempt.

RO

RO

RO

Verify Service Water Pumps - AT LEASTONE PER TRAIN RUNNING

E-0, Step 5

START pumps E-0, Step 5RNO

Verify Two RPCCW Pumps - ONE PERTRAIN RUNNING

E-0, Step 6

RO Verify ECCS Pumps Running

* Check SI pumps - RUNNING

* Check RHR pumps - RUNNING

E-0, Step 7


(EVALUAi iON GUIDE


(

Title:



* Check two charging pumps -RUNNING

NOTE: Crew may identify rupturedS/G early and take critical taskaction in advance of proceduraldirection.

BOP Verify AFW Pumps Running E-0, Step 8

[Critical Task] Identify rupturedS/G and Isolate AFW beforenarrow range level reaches 29%.

Check MD pumps - RUNNING

Check turbine - driven pump - RUNNING,IF NECESSARY

E-0,Step 8.a

E-0,Step 8.b

BOP Verify FW Isolation

* Check SG feed regulating valves -CLOSED

* Check SG feed regulating bypassvalves - CLOSED

* Check FW isolation trip valves -CLOSED

* Check MD FW pump - STOPPED

* Check TD FW pumps - TRIPPED

E-0, Step 9


(.EVALUATION GUIDE


(

Title:

ID Number:

Time

2K2 NRC-002

IDA/Malf

Revision: 0Task

AssignInstructor Information/Activity Expected Actions Standard

BOP

* Check SG blowdown isolation valves -CLOSED

* Check SG blowdown sample isolationvalves - CLOSED

* Check SG chemical feed isolationvalves - CLOSED

Check If Main Steam Lines Should BeIsolated

Check Ctmt pressure GREATER THAN 18psia

OR

Any SG pressure LESS THAN 660 psig

Proceed to Step 11

Check if CDA Required

Check Ctmt pressure is GREATER THAN23 psia

E-0, Step 10

E-0,Step 10.a

E-0,Step 10.a,RNO

E-0, Step 11

E-0,Step 1 1.a

RO

OR

Ctmt spray is initiated


EVALUATION GUIDESGTR WITHOUT PZR PRESSURE CONTROL

f

Title:


AssionTime- IrlA /AnIf tri nftrnr Infnrmftieon/Activitv Expected Actions StandardI 1111V IL-Ii-VIVIG111

US Proceed to Step 12. E-0,Stepl 1,a,RNO

BOP

BOP

Verify CAR Fans Operating InEmergency Mode

E-0, Step 12

Check CAR fan status: E-0,Step 12.a

BOP

RO

RO

* CAR fans A and B - RUNNING

* CAR fan C - STOPPED

START/STOP CAR fans as necessary.

Verify RPCCW Ctmt supply and returnheader isolations - OPEN

Verify Train A and B RPCCW supply andreturn to chill water valves - OPEN

E-0,Step 12.a,RNO

E-0,Step 12.b

E-0,Step 12.c

E-0, Step 13

E-0,Step 13.a

RO

RO

Verify CIA

Check ESF Group 2 status columns 2through 10 - LIT

Verify Proper ESF Status PanelIndication

RO E-0, Step 14

* Verify ESF Group 1 lights - OFF


Title:EVALUAI iON GUIDE



AssianTimn~ I AIM K f Inctri ictnr Inform~ation/Activitv Expected Actions Standard111110 *-lUI-A,

* Verify ESF Group 2 lights - LIT

RO/BOP Align component(s) as necessary forminimum safety function.

E-0,Step 14,RNO


E-0, Step 15

* Ctmt temperature GREATER THAN1800F

OR

* Ctmt radiation GREATER THAN 105R/hr

DO NOT use ADVERSE CTMTparameters.

CREW E-0,Step 15,RNO



FLOW INDICATED

E-0,Step 16.a

E-0,Step 16.b

RO

US

Check RCS pressure - GREATER THAN1650 psia (1950 psia ADVERSE CTMT)

Proceed to Step 16.d E-0,Step 16.b,RNO


( (EVALUM iON GUIDE



A--ionTiff- I rA /hAn If I nctri jit-r I nfnrmntinn/Artivitv ExDected Actions StandardI 111lU 1I1Vt\/V1G1l --- 1;>t ---vi allvEcvApzv- U -

Proceed to step 17.

Check Si pumps - FLOW INDICATED


Check RCS pressure - LESS THAN 300psia (500 psia ADVERSE CTMT)

Check RHR pumps - FLOW INDICATED.

E-0,Step 16.c

E-0,Step 16.d

E-0, Step16.d RNO

E-0,Step 16.e

E-0,Step 16.f

BOP Verify Adequate Heat Sink E-0, Step 17


E-0,Step 17.a

US

BOP

US

BOP

Proceed to Step 17.d. E-0,Step 17.a,RNO

Control feed flow to maintain NR level -BETWEEN 8% and 50% (42% and 50%ADVERSE CTMT)

E-0,Step 17.b


Verify Total AFW Flow - GREATER THAN530 gpm

E-0,Step 17.d


Title:EVALUATION GUIDE


(

ID Number:

Tim-


AssianInA/Mnlf Instructor Information/Activitv Expected Actions Standard

BOP

RO

US

Verify AFW Valve Alignment - PROPEREMERGENCY ALIGNMENT

Verify ECCS Valve Alignment - PROPEREMERGENCY ALIGNMENT

Check Plant Status

E-0, Step 18

E-0, Step 19

E-0, Step 20

BOOTHINST

NOTE When asked, REPORT that "allSLCRS doors indicate closed."

Verify SLCRS doors - CLOSED E-0,Step 20.a

RO

RO

RO

Check CONTROL BUILDING ISOLATIONannunciator (MB4D 3-6) - LIT


* Ctmt pressure GREATER THAN 18psia

OR

* Control Building radiation monitor inalarm

E-0,Step 20.b

E-0,Step 20.b,RNO

RO

OR

RO

US

* Si manually actuated

IF CBI required, THEN initiate CBI.

IF CBI is NOT required, THEN proceed toStep 21.


(EVALUATION GUIDE


ID Number:

Time



RO

RO

BOP

BOP

BOP



Verify control building purge supply fanand purge exhaust fan - NOT RUNNING

Control building air bank isolation valves- OPEN (after 60 seconds)

STOP kitchen exhaust fan

E-0,Step 20.c

E-0,Step 20.c,RNO

E-0,Step 20.d

E-0,Step 20.e

E-0,Step 20.f

BOOTHINST

NOTE When called, WAIT 3 - 5 min,Then REPORT "All ControlBuilding pressure boundary doorsare Closed and Dogged."


E-0,Step 20.g


Verify RCS cold leg WR temperature -BETWEEN 5500F and 5600F

E-0,Step 21.a

E-0,Step 21.a,RNO

US Perform the applicable action:

* IF temperature is GREATER THAN550 0F AND 5600F, THEN


(.

EVALUAl ION GUIDESGTR WITHOUT PZR PRESSURE CONTROLTitle:


AssianTime IDA/Malf Instructor I nformation/Activitv Expected Actions Standard

1) Dump steam to the condenser, ifavailable OR Dump steam toatmosphere.

2) Proceed to Step 22.

* IF the temperature is LESS THAN550°, THEN proceed to Step 21 c.

US

US

BOP

BOP

BOP

Proceed to Step 22 E-0,Step 21.b

Maintain total feed flow BETWEEN 530and 600 gpm until NR level is GREATERTHAN 8% (42% ADVERSE CTMT) in atleast one SG

CLOSE SG atmospheric dump and dumpbypass valves

Check the following valves - CLOSED

E-0,Step 21.c

E-0,Step 21.d

E-0,Step 21.e

* 5s

* MSIV bypass valves

US Perform the following: E-0,Step 21.e,RNO

BOP Place both condenser steam dumpinterlock selector switches to OFF.

E-0,Step 21.e.1,RNO


Title:

ID Number:

Time

EVALUi ION GUIDESGTR WITHOUT PZR PRESSURE CONTROL



BOP

RO

RO

RO

RO

CREW

RO

Expected Actions

IF unexpected cooldown continues, THENCLOSE the MSIVs and MSIV bypassvalves.

Check PZR Valves


Verify normal PZR spray valves - CLOSED

Verify PZR safety valves - CLOSED

Check PORV block valves - OPEN

To prevent damage to the RCP seal(s),seal injection flow should be maintained toall RCPs.

Check If RCPs Should Be Stopped

Verify RCPs - ANY RUNNING

Proceed to step 24.

Standard

E-0,Step 21.e.2,RNO

E-0, Step 22

E-0,Step 22.a

E-0,Step 22.b

E-0,Step 22.c

E-0,Step 22.d

E-0,Step 23,CAUTION

E-0, Step 23

E-0,Step 23.a

E-0,Step 23.a,RNO.

(




l


AssignTime IDA/Malf Instructor Information/Activity Expected Actions StandardVerify RCS pressure - LESS THAN 1500

RO

US

RO

US

RO

Verify RCS pressure - LESS THAN 1500psia (1800 psia ADVERSE CTMT)

Proceed to Step 24

Verify charging or SI pumps - AT LEASTONE RUNNING

Proceed to Step 24

STOP all RCPs

E-0,Step 23.b

E-0,Step 23.b,RNO.

E-0,Step 23.c

E-0,Step 23.c,RNO

E-0,Step 23.d

E-0, Step 24BOP/RO Check If SG Secondary Boundaries AreIntact


* NO SG PRESSURE DECREASING INAN UNCONTROLLED MANNER


Check If SG Tubes Are Intact

E-0,Step 24.a

BOP E-0, Step 25


( (EVALUATION GUIDE




RO Sample all SGs for activity E-0,Step 25.a

1. RESET SG blowdown sampleisolation

2. OPEN SG blowdown sample isolationvalve(s)

3. Request Chemistry obtain activitysamples using HP coverage

BOP Check steam generator levels - NO SG E-0,LEVEL INCREASING IN AN Step 25.bUNCONTROLLED MANNER

US Initiate monitoring of CSF Status Trees E-0,and Go to E-3, Steam Generator Tube Step 25.b,Rupture. RNO

Verify trend history and alarm status of E-0,radiation monitors Step 25.c

* Main steam line - NORMAL



Initiate monitoring of CSF Status Trees E-0,and Go to E-3, Steam Generator Tube Step 25.cRupture RNO


KEVALUA-I ION GUIDE



AssianTime InA/Mnlf Instructor Information/Activity Expected Actions Standard. I.- --- -1

RO Verify trend history and alarm status ofradiation monitors

MALFSG01C

E-3: Steam Generator TubeRupture, Rev. 17

US To prevent damage to the RCP seal(s),seal injection flow should bemaintained to all RCPs.

E-3 Step 1CAUTION

US * Foldout page must be open

* The RCP trip criteria is onlyapplicable until a controlledcooldown is initiated in step 6.

Check If RCPs Should Be Stopped

E-3, Step 1,NOTE

E-3, Step 1RO

Check RCPs - ANY RUNNING E-3,Step 1.a

Proceed to step 2. E-3,Step 1.a,RNO

Verify RCS pressure - LESS THAN 1500psia (1800 psia ADVERSE CTMT)

Proceed to step 2.

E-3,Step 1.b

E-3,Step 1.b,RNO

Verify charging or safety injection pumps -AT LEAST ONE RUNNING

E-3,Step 1.c

STOP all RCPs E-3,Step 1.d


Title:EVALUA) iON GUIDE


f


A--ionT;:_ IMA IfA-1F I rLtri irtnr Infnrmnfinn/Ac--tixvitv Expected Actions StandardI IIII IlUAIVIdII 1l 11QL k IU LW. 11I * 11t*SS-,*'-r

[Critical Task] Identify rupturedS/G and Isolate AFW beforenarrow range level reaches 29%.

BOP Identify Ruptured SGs

* Unexpected increase in any SG level

E-3, Step 2

OR

* High radiation from any SG steam lineas indicated by the trend history oralarm status

OR

* High radiation from any SG sample

* If the TD AFW pump is the onlyavailable source for feed flow,steam supply to the TD AFW pumpmust be maintained from at leastone SG.

US E-3, Step 3,CAUTION

* At least one SG must be maintainedavailable for RCS cooldown.

BOP Isolate Flow From Each Ruptured SG E-3, Step 3

Verify each ruptured SG atmosphericdump valve controller - IN AUTO AT 1125psig

Check each ruptured SG atmosphericdump valve - CLOSED

E-3, Step3.a

E-3,Step 3.b

RO


EVALUATION GUIDESGTR WITHOUT PZR PRESSURE CONTROL

i'

Title:


AssianTima InA/Malf Instructor Information/Activitv Expected Actions Standard| dvvc f-- OBw-- -I

Check each ruptured SG atmosphericdump bypass valve - CLOSED.

CLOSE each ruptured SG steam supplyisolation valve to TD AFW pump.

E-3,Step 3.c

E-3, Step3.d

* 3MSS*MOV17A

* 3MSS*MOV17B

* 3MSS*MOV17D

Verify each ruptured SG blowdownisolation valve - CLOSED

CLOSE valves.

Verify each ruptured SG blowdown sampleisolation valve - CLOSED

CLOSE valves

Verify each ruptured SG chemical feedisolation valve - CLOSED

CLOSE valves

E-3,Step 3.e

E-3,Step 3.e,RNO

E-3, Step3.f

E-3,Step 3.f,RNO

E-3,Step 3.g

E-3,Step 3.g,RNO


(.

EVALUATION GUIDESGTR WITHOUT PZR PRESSURE CONTROLTitle:


AssianTime IDA/Malf Instructor I nformation/Activitv Expected Actions StandardI

Using table, CLOSE the main steam linedrains upstream of MSIVs and TD AFWpump for the ruptured SG(s)

E-3,Step 3.h

SG A SG B I SG C SG D

3DTM*AOV29A

3DTM*AOV61A

3DTM*AOV63A

3DTM*AOV64A

3DTM*AOV29B

3DTM*AOV61 B

3DTM*AOV63B

3DTM*AOV64B

3DTM*AOV29C

3DTM*AOV61 C

3DTM*AOV29D

3DTM*AOV61 D

3DTM*AOV63D

3DTM*AOV64D, _

_ _

EVENT 7: MSIV on Ruptured S/GFails to Close

BOP CLOSE each ruptured SG MSIV and MSIVbypass valve.

E-3,Step 3.i

Perform the following: E-3, Step3.i RNO[Critical Task] Isolate steam flow from

ruptured S/G before a transition to ECA-3.1 occurs at step 3 of E-3 (MSIV failed).

NOTE: Perform this step when directedas PEO and Report when the crewreaches Step 5 Caution. (This is a TimeCompression technique to supportprocedure flow).

1. CLOSE all remaining SG MSIVs andMSIV bypass valves.

2. Close all valves listed on AttachmentA.

3. Use the intact SG atmospheric dumpvalves to dump steam, for RCStemperature control or cooldown.

IF any ruptured SG can NOT beisolated from at least one intact SG,THEN Go to ECA-3.1, SGTR with Lossof Reactor Coolant - SubcooledRecovery Desired.


Title:EVALUAI ION GUIDE


(


AssionTime- r) A /tAn If I nctni I-tnr I nfnrmntinn/Artivitv ExDected Actions StandardI III I; .... 1, .L. . -- r

-US

BOP

If any ruptured SG is faulted, feed flowto that SG should remain isolatedduring subsequent recovery actionsunless the SG is needed for RCScooldown.

Check Ruptured SG Level

Verify one of the following is satisfied:

* Ruptured SG WR level - GREATERTHAN 67% (95% ADVERSE CTMT)

OR

* Ruptured SG NR level - GREATERTHAN 8% (42% ADVERSE CTMT)

Isolate feed flow to ruptured SGs.

E-3, Step 4,CAUTION

E-3, step 4

E-3,Step 4.a

E-3,Step 4.b

NOTE: When the Crew reaches this stepreport as the PEO that the step iscomplete (This is a Time Compressiontechnique to support procedure flow).

Steps 3.d and 3.i for isolating the rupturedSG must be completed prior to continuingto step 5.

E-3, Step 5,CAUTION

BOP Check Ruptured SGs Pressure -GREATER THAN 530 psig

E-3, step 5


Title:EVALUM iON GUIDE


(


AssianTime IDA/Malf Instructor Information/Activity Expected Actions StandardI

US

US

If RCPs are NOT running, the followingsteps may cause a false entry into theINTEGRITY Status Tree for the affectedloop. Disregard the affected loop Tcindication until after performance of step27.

* To allow steam dump operation tocontinue during a controlled cooldown,ensure the Low-Low Tavg interlock isbypassed at 5530F.

E-3, Step 6CAUTION

E-3, Step 6NOTE

* Ensure Low Steam Line Pressure Si isblocked when pressurizer pressure isLESS THAN 2000 psia.

* After the Low Steam Line Pressure SIsignal is blocked, MSI will occur if thehigh steam pressure rate setpoint isexceeded.

US/RO/PEO

Initiate RCS Cooldown E-3, Step 6

Check RCPs -ANY RUNNING E-3, Step6.a

Proceed to step 6.c. E-3,Step 6.a,RNO




(S



Locally, Place the eight RCP overcurrenttrip switches (43PP and 43PB) in theCOLD position using CO key Locker Key#7

E-3,Step 6.b

Determine required core exit temperaturewithout interpolatina (use lower pressure)

E-3,Step 6.c

NOTE: If the Plant ProcessComputer has been lost use one ofthe following to report CETCs andsubcooling values as requested:

* IDT Pages

* "Max Fuel Temp" on InstructorConsole

* Steam Tables (for subcooling)

Lowest Ruptured SG Core Exit TemperaturePressure (psig) (OF)

NORMAL ADVERSE

1285 537 513

1185 526 502

1085 515 489

985 502 475

885 488 459

785 474 443

685 457 423

585 449 426

530 435 410

Dump steam to condenser from intact SGs atmaximum rate

E-3, Step 6.d


( ( (fEVALUATION GUIDE




1. Verify the following:

* Intact SG MSIVs - OPEN

* Annunciator "CONDENSER AVAILFOR STM DUMP C-9" (MB4D 5-6) -LIT

2. Adjust steam pressure controller toobtain zero output in MANUAL

3. Transfer condenser steam dumpsto Steam Pressure Mode

4. Place both condenser steam dumpinterlock selectors - ON

5. Adjust steam pressure controller todump steam to condenser

Dump steam to atmosphere from intact E-3,SGs at maximum rate using SG Step 6.datmospheric dump valves. RNO

Verify core exit TCs - LESS THAN E-3,REQUIRED TEMPERATURE Step 6.e


( {l:EVALUAM ION GUIDE



AssianTime InA/Mqlf Instructor Information/Activitv Expected Actions Standard

Proceed to NOTE prior to step 7 and,

WHEN

Core exit TCs less than requiredtemperature,

THEN

E-3,Step 6.eRNO

Perform steps 6.f and 6.g

Stop RCS cooldown E-3, Step 6.f

Maintain core exit TCs - LESS THANREQUIRED TEMPERATURE

E-3,Step 6.g

E-3, Step 7,NOTE

To aid in identifying previously undetectedsteam generator tube failures, the widerange SG level indication should be usedif the narrow range level is off scale.

BOP Check Intact SG Levels E-3, step 7

Verify NR level - GREATER THAN 8%(42% ADVERSE CTMT)

Maintain total feed flow GREATER THAN530 gpm until NR level is GREATERTHAN 8% (42% ADVERSE CTMT) in atleast one SG.

Control feed flow to maintain NR levelbetween 8% and 50% (42% and 50%ADVERSE CTMT)

E-3,Step 7.a

E-3,Step 7.a,RNO

E-3,Step 7.b


(EVALUA X ION GUIDE


(,Title:



US

RO

If any PZR PORV opens because of highPZR pressure, step 8.a should berepeated when pressure decreases toLESS THAN 2350 psia.

Check PZR PORVs And Block Valves

E-3, Step 8,CAUTION

E-3, Step 8


Verify PORV block valves - AT LEASTONE OPEN

E-3,Step 8.a

E-3,Step 8.b

E-3, Step 9CAUTION

RO

* If offsite power is lost after SI reset,manual action to restart safeguardsequipment may be required.

* DO NOT reset CDA if recirculationspray pumps are required and havenot automatically started.

RESET ESF Actuation Signals IfRequired

* SI

* CDA

* CIA

* CIB

. LOP

E-3, Step 9




(


A--ionTimo- II-A hAnIf Inctri irfnr Infnrmntinn/Artivitv Expected Actions StandardI 1111:V I LJ'VIVIUII --- - -..

NOTE: If crew calls anymaintenance department,IAS*MOV72 is mechanically stuckshut.

RO Establish Instrument Air to Ctmt E-3, Step 10

Check instrument air compressors - ATLEAST ONE RUNNING

START one instrument air compressor

E-3,Step 10.a

E-3,Step 10.a,RNO

NOTE: RO will be unable tocomplete this step

OPEN instrument air Ctmt isolation valves E-3,Step 10.b

US/PEO RESTORE MCC 32-3T E-3, Step 11

Check Emergency Bus 34C ENERGIZED

Proceed to the caution prior to step 12and,

WHEN

Power restored to emergency bus 34CTHEN

perform step 1 b

E-3,Step 1 la

E-3,Step I laRNO

T+ 5minutes ofrequest

EDR18

EDR44

Resets 32-3T and Using GA-1, Energize MCC32-3T E-3,Step 1l.b

clears inverter 6 alarms


(EVALUATION GUIDE


(

Title:



US

RO

To provide adequate ECCS flow, RCSpressure should be monitored toensure that the RHR pumps aremanually restarted if pressuredecreases to LESS THAN 300 psia (500psia ADVERSE CTMT).

Check If RHR Pumps Should BeStopped

Verify RCS pressure - GREATER THAN300 psia (500 psia ADVERSE CTMT)

Proceed to CAUTION prior to step 13.

STOP RHR pumps and Place in AUTO

E-3,Step 12,CAUTION

E-3, Step 12

E-3,Step 12.a

E-3,Step 12.a,RNO

E-3,Step 12.b

US Check If Cooldown Should Be Stopped E-3, Step 13

Check Cooldown - IN PROGRESS E-3,Step 13.a

Proceed to step 1 3.d E-3,Step 13.a,RNO

Maintain core exit TCs - LESS THANREQUIRED TEMPERATURE

E-3,Step 13.d


( (EVALUAMI iON GUIDE



Aq-cini--.4-. ,,-r Infe4rmnfinn/A e%4fiit Expected Actions StandardT:_ I rARA 1-^19li me Mit-vIVlalT i11LbUt.,LU Iiaillatily{zl- t

BOP

US/RO

RO

Check Ruptured SGs Pressure -STABLE OR INCREASING

Check RCS Subcooling Based on CoreExit TCs - GREATER THAN 520F (1350FADVERSE CTMT)

Depressurize RCS To Minimize BreakFlow and Refill PZR

E-3, Step 14

E-3, Step 15

E-3, Step 16

Verify normal PZR spray - AVAILABLE

Proceed to CAUTION prior to step 17.

E-3,Step 16.a

E-3,Step 16.aRNO

E-3,Step 17,CAUTION

US * The PRT may rupture if a PZR PORVis used to depressurize the RCSresulting in abnormal containmentconditions.

* Cycling of the PZR PORVs should beminimized.

US If RCPs are NOT running, the upper headregion may void during RCSdepressurization resulting in a rapidlyincreasing PZR level.

E-3,Step 17,NOTE


Title:

ID Number:

Time

EVALUAi ION GUIDESGTR WITHOUT PZR PRESSURE CONTROL



1/0 EVENT 8: Inability to De- RO3RCS* pressurize RCSPCV456

OPEN -FALSE

Expected Actions

Depressurize RCS Using PZR PORV toMinimize Break Flow And Refill PZR

.

=Standard

E-3, Step 17

Check PZR PORVs - AT LEAST ONEAVAILABLE

Proceed to step 17.e.

Establish auxiliary spray:

1. Verify at least one Si pump - RUNNING

2. Verify at least one charging pump -RUNNING

3. CLOSE charging header loop isolationvalves (3CHS*AV8146 and3CHS*AV8147)

4. Fully OPEN charging line flow controlvalve

5. OPEN charging header isolation valves(3CHS*MV8106 and 3CHS*MV8105)

E-3,Step 17.a

E-3,Step 17.a,RNO

E-3,Step 17.e

E-3,Step 17.e.1

E-3,Step 17.e.2

E-3,Step 17.e.3

E-3,Step 17.e.4

E-3,Step 17.e.5


(:EVALUATION GUIDE


ID Number:

Time

2K2 NRC-002

IDA/Malf

Revision: 0Task


6. Unlock and OPEN auxiliary spray valve(3RCS*AV81 45)

7. CLOSE both charging pump cold leginjection valves

8. Verify Auxiliary Spray - ESTABLISHED

* Charging header flow

* PZR Pressure - DECREASING


E-3,Step 17.e.6

E-3,Step 17.e.7

E-3,Step 17.e.8

E-3,Step 17.e.8RNO

a) OPEN both charging pump cold leginjection valves.

b) CLOSE auxiliary spray valve.

c) CLOSE charging header isolationvalves.

d) Go to ECA - 3.3, SGTR WithoutPressurizer Pressure Control.

Foldout page must be open.ECA-3.3: SGTR WITHOUTPRESSURE CONTROL, Rev. 12

US EOP 35ECA-3.3Step 1, Note


(EVALUATION GUIDE



AssianTime IDA/Mnlf Instructor Information/Activitv Expected Actions Standard-- -- ---1 - - -

RO Check Ruptured SG(s) Level

Check Ruptured SGs Narrow Range Level -LESS THAN 80% (54% ADVERSE CTMT)

EOP 35ECA-3.3Step 1

EOP 35ECA-3.3Step 1.a

US RCPs should be operated in the followingorder of priority to ensure optimum PZRspray flow:

EOP 35ECA-3.3Step 2, Note

First: RCP 2

Second: RCP 1 and one other RCP

RO Try To Establish Normal PZR Spray

Check RCP status - AT LEAST ONERUNNING IN EITHER LOOP 1 OR LOOP 2

Using GA-6, START the preferred RCP(s)

IF the preferred RCP(s) can NOT be started,

THEN

EOP 35ECA-3.3Step 2


EOP 35ECA-3.3Step 2.a,RNO

Proceed to step 3.


(IEVALUAI ION GUIDE


i,

Title:

ID Number:

Time

2K2 NRC-002

IDA/Malf

Revision: 0Task


RO Try To Restore PZR PORV

Establish conditions for opening a PZRPORV:

Check PZR PORV power available

Check PZR PORV block valve open

Check PZR PORV - AT LEAST ONEAVAILABLE

Proceed to step 4.

EOP 35ECA-3.3Step 3


EOP 35ECA-3.3Step 3.a.1



EOP 35ECA-3.3Step 3.a,RNO

RO Try To Establish Auxiliary Spray

Verify SI pumps - BOTH RUNNING

EOP 35ECA-3.3Step 4



( (EVALUA-i ION GUIDE




Verify charging pumps - AT LEAST ONERUNNING

EOP 35ECA-3.3Step 4.b

EOP 35ECA-3.3Step 4.c

NOTE: These steps wereattempted in E-3. It is expectedthat the crew will not attempt themagain without a change inconditions.

Establish auxiliary spray:

Proceed to step 5. EOP 35ECA-3.3Step 4.c,RNO

CLOSE charging header loop isolation valves(3CHS*AV8146 and 3CHS*AV8147)

CLOSE charging line flow control valve

OPEN charging header isolation valves(3CHS*MV8106 and 3CHS*MV8105)

Unlock and OPEN auxiliary spray valve(3RCS*AV8145)

EOP 35ECA-3.3Step 4.cl

EOP 35ECA-3.3Step 4.c.2




EVALUA I ION GUIDETitle: SGTR WITHOUT PZR PRESSURE CONTROL



Slowly Open charging line flow control valve EOP 35to establish auxiliary spray flow ECA-3.3

Step 4.c.5

CLOSE both charging pump cold leg injection EOP 35valves ECA-3.3

Step 4.c6

Go to E-3, Steam Generator Tube Rupture, EOP 35step 17.b ECA-3.3

Step 4.d

BOP Check Intact SG Levels EOP 35ECA-3.3Step 5

Verify NR level - GREATER THAN 8% (42% EOP 35ADVERSE CTMT) ECA-3.3

Step 5.a

Maintain total feed flow GREATER THAN EOP 35530 gpm until NR level is GREATER THAN ECA-3.38% (42% ADVERSE CTMT) in at least one Step 5.a,SG. RNO

Control feed flow to maintain NR level - EOP 35BETWEEN 8% and 50% (42% and 50% ECA-3.3ADVERSE CTMT) Step 5.b

IF NR level in any intact SG continues to EOP 35increase in an uncontrolled manner, THEN ECA-3.3Go to E-3, Steam Generator Tube Rupture. Step 5.b,

RNO


( (/EVALUAI ION GUIDE




RO Check PZR Level - GREATER THAN 16% EOP 35(50% ADVERSE CTMT) ECA-3.3

Step 6

US/RO Check If ECCS Flow Can Be Terminated EOP 35ECA-3.3Step 7

Verify RCS subcooling based on core exit EOP 35TCs - GREATER THAN 320F (1 150F ECA-3.3ADVERSE CTMT) Step 7.a

Verify secondary heat sink EOP 35ECA-3.3Step 7.b

* Total feed flow to SGs - GREATER THAN530 gpm AVAILABLE

OR

* NR level in at least one intact SG -GREATER THAN 8% (42% ADVERSECTMT)

Check RVLMS plenum level - GREATER EOP 35THAN OR EQUAL TO 19% ECA-3.3

Step 7.c

Check ruptured SGs NR level - EOP 35

INCREASING IN AN UNCONTROLLED Step73d3MANNER


(EVALUATION GUIDE


A'Title:

ID Number:

Time



OR

OFF-SCALE HIGH

RO Stop ECCS Pumps EOP 35ECA-3.3Step 8

* STOP SI pumps and Place in AUTO

* STOP all but one charging pump andPlace in AUTO

TERMINATE UPON COMPLETION OF STEP 8 OF ECA-3.3. Verify ECCS Flow Not Required.


SECTION 4


EVALUATION GUIDE

I. SUMMARY


TASK DESCRIPTION TASK# K/A >1= 3.0 BASIS FOR SELECTION

Isolate steam flow fromruptured S/G before atransition to ECA-3. 1 occursat step 3 of E-3 (MSIVfailed).

Identify ruptured SIG andIsolate AFW before narrowrange level reaches 29%.

E-3-A 038 EA1.324.6/4.7

Failure to isolate theruptured SG causes a lossof differential pressurebetween the ruptured SGand the intact SGs and thecrew must transition to acontingency procedure that"...necessitates the crewtaking compensating actionwhich complicates theevent mitigationstrategy...."

Failure to stop reactorcoolant leakage into aruptured SG bydepressurizing the RCSneedlessly complicatesmitigation of the event andconstitutes a "significantreduction of safety marginbeyond that irreparablyintroduced by thescenario."

E-3-C(1)

038 EA1.014.514.4


TASK DESCRIPTION TASK # K/A >I= 3.0 BASIS FOR SELECTION

Manually start the A TrainService Water Pump beforetransitioning from E-0.

ECA-0.0--F

Failure to manually startthe SW pump under thepostulated plant conditionsmeans that the EDG isrunning without SW coolingleading to ahigh-temperature conditionthat can result in EDGfailure due to damagecaused by engineoverheating. Under thepostulated plant conditions,the running EDG is the onlyoperable EDG. Thus,failure to perform thecritical task constitutes"mis-operation or incorrectcrew performance thatleads to degradedemergency powercapacity."

Note: [*] Used to designate critical tasks. Should alsobe incorporated into column 3 or 4 ofInstructor Guide.


SECTION 4


ID Number: 2K2 NRC-002EVALUATION GUIDE

Revision: 0


SECTION 5

SCENP


Reactor Power:

Operating History:

RCS Boron:

Core Burnup:

Condensate Demins:

Evolutions in Progress:

Major Equipment OOS:

kRIO INITIAL CONDITIONS

REwvision: 0

100%

450 days on line

50 ppm

18,600 MWD/MTU

7 demins in service

NONE, A Train Protected, Intake Condition: GREEN

"A" PORV is inoperable due to an electrical short in thecontrol circuitry. It has been out of service for 8 hours.Electrical maintenance estimates that the valve will bereturned to service within 24 hours.

The following Tech Specs are applicable:

Tech Spec 3.4.4, action b3TRM 7.4.1 action a.1 and a.3 for both the A PORV andthe block valve 3RCS*MV8000A

Crew Instructions:

The crew is initially directed to reduce CTMT pressure to 13.80 psia by starting CTMTvacuum pump 3CVS-P1A using OP 3313E, Containment Vacuum, section 4.2.




* If not using the speed dial option on the phone system, the operator must dial either #3333or #3334 to reach the person/department they desire.

* The following PPC programs do not function on the simulator:



SECTION 6




Remote functions:


Malfunctions:


Initial Conditions:

The initial condition(s) contained in the guide are certified or have been developed from certifiedIC's in accordance with NSEM-4.02.



Test Run:

The scenario contained in the guide has been test run and validated (validation sheetcompleted, next page)on the simulator. Simulator response is reasonable and as expected.


The dynamic examination review checklist is complete. (This is not required unless the examwill be used as an Annual Exam, then NUREG 1021 requirements apply.)

11/20/2001Technical Reviewer Date


SECTION 7




I. References:

OP3313E

AOP 3552

AOP*3555

AOP*3575

AOP*3576

EOP*E-0

EOP*E-3

EOP*ECA-3.3

EOP*ERGEXE

EOP* Step DOC

EOP*ERGHP

FAP06*01

NUREG*1021 rev 8

Containment Vacuum

Malfunction of the Rod Control System

Reactor Coolant System Leak

Rapid Downpower

Steam Generator Tube Leak


Steam Generator Tube Rupture

SGTR Without Pressure Control





Examiners Standards






I. Summary:

Facility: Millstone 3 PWR:________ Scenario No: 2K2NRC-002 Op-Test No: 2K2Facility: Millstone 3 PWR:- Scenario No: 2K2NRC-002 Op-Test No: 21<2

Examiners:_ Operators:.


The "A" PORV is out of service due to an electrical short in the control circuitry

Event Malf. Event Event DescriptionNo: No. Type *1 N(ALL) Reduce CTMT Pressure2 RD10- C(RO) Control Rod Position Data A Failure

593 SG03C C(ALL) Steam Generator "C" Tube Leak

3a R(ALL) Rapid Downpower due to S/G Tube Leak (AOP 3576)4 RD021 C(RO) Rod Bank CB-D Continuous Rod Insertion5 SG01C M(ALL) Steam Generator "C" Tube Rupture

ED01 Loss of Offsite Power6 SW01A C(RO) A SWP Trips

SW02C C SWP Fails to Auto Start7 MS12C C(BOP) MSIV on Ruptured S/G Fails to Close

8 I/Os: M(ALL) Inability to De-pressurize RCSPCV455PCV456IAS*V72





Exam Title: SGTR WITHOUT PZR PRESSURE CONTROL




Y 1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out ofservice, but it does not cue the crew into expected events.

Y__2. The scenario consists mostly of related events.

Y__3. Each event description consists of:

- the point in the scenario when it is to be initiated- the malfunctions(s) that are entered to initiate the event- the symptoms/cues that will be visible to the crew- the expected operator actions (by shift position)- the event termination point (if applicable)

_Y_4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenariowithout a credible preceding incident such as a seismic event.


_Y_6. Sequencing/timing of events is reasonable, and allows for the examination team to obtaincomplete evaluation results commensurate with the scenario objectives.

_Y_7. If time compression techniques are used, scenario summary clearly so indicates. Operators havesufficient time to carry out expected activities without undue time constraints. Cues are given.


_Y_9. The scenario has been validated. Any open simulator performance deficiencies have beenevaluated to ensure functional fidelity is maintained while running the scenario.

_Y_10. Every operator will be evaluated using at least one new or significantly modified scenario. All otherscenarios have been altered lAW Section D.4 of ES301

_Y_11. All individual operator competencies can be evaluated, as verified using form ES-301-6.

_Y_12. Each operator will be significantly involved in the minimum number of transients and eventsspecified on Form ES-301-5. (Form submitted with simulator scenarios).

_Y_13. Level of difficulty is appropriate to support licensing decisions for each crew position.




Lesson Title: SGTR WITHOUT PZR PRESSURE CONTROL



01. Total Malfunctions (TM) - Include EM's- 5 to 8 required Total: 8PORV failed closed, CTMT IAS valve will not open, S/G Tube Leak / Rupture, DPRIData A Failure, Continuous Rod Insertion, Service Water Pumps Fail to Auto Start,Loss of Offsite Power, MSIV Fails Closed

02. Malf s after EOP entry (EM's)- 1 to 2 required Total: 2PORV failed closed, MSIV Fails Closed

03. Abnormal Events (AE)-2 to 4 required Total: 4Service Water Pumps Fail to Auto Start, S/G Tube Leak, DPRI Data A Failure,Continuous Rod Insertion

04. Major Transients (MT)-1 to 2 required Total: 2SIG Tube Rupture / Loss of Offsite Power

05. EOP's (EU) entered/requiring substantive actions 1 to 2 required Total: 2E-0, E-3

06. EOP Contingencies requiring substantive actions [ECAs/FRs](EC) 0 to Total: 12 required

ECA-3.3


E-3-A: Isolate feedwater flow to and steam flow from ruptured S/G beforea transition to ECA-3.1 occurs at step 3 of E-3. (MSIV fails)

E-3-C: Identify and Isolate ruptured S/G before narrow range levelreaches 29%.

ECA-O.O--F: Manually start the A Train Service Water Pump before transitioningfrom E-0.


09. EOP run time:

Total: 3

Total: 60 min

Total: 30 min


NOTES: Reactivity Manipulation: Rapid Downpower due to S/G Tube Leak



SIMULATOR EXAM

SIM-004

EXA:MINATION

08112/02 - 08/15/02

- - - - =

I

MILLSTONE NUCLEAR POWER STATION

LOIT NRC SIMULATOR EXAM GUIDE APPROVAL SHEET

Exam Title:

Revision:

ID Number:

INTER-SYSTEM LOCA

0

2K2NRC-004 (SPARE)

This document is the property of Millstone Power Station, which controls itsdistribution. Further transfer, copying, and modification of this document are


-F r *VXZ

SECTION 2


TABLE OF CONTENTS


1. Cover Page


3. Exam Overview

4. Evaluation Guide





Attachments


aAWLKt , a

SECTION 3

EXAM OVERVIEWTitle: INTER-SYSTEM LOCA

ID Number: 2K2NRC-004 Revision: 0

Exam Brief:

1. The plant is at 100% power, EOL steady state operations with all control systems inautomatic. The "A" PORV is out of service due to an electrical short in the control circuitry.After turnover the crew will shift running Charging Pumps as directed by the turnover per OP3304A, Charging and Letdown, Section 4.4.

After the normal evolution is complete, Power Range Nuclear Instrument (NI) Channel42 Lower Detector will fail high. Inward rod motion will occur and the appropriateannunciators will alarm. Rod Control should be placed in manual and the crew shouldrespond using AOP 3571, Instrument Failure Response. Once the failed channel has beendefeated Tave will be restored by moving the rods if necessary before they are returned toautomatic control.

Once Tech Specs have been address for the failed NI channel, a leak will develop inthe 6B Low Pressure Feedwater Heater. Feedwater Heater annunciators will alarm directingthe crew to AOP 3567, Operation with one Feedwater Heater String Isolated. The B HeaterDrain Pump will trip and the heater string will automatically isolate. The AOP responseincludes a plant downpower to 95% and verification of isolation of the heater string from theControl Room.

Once the crew has confirmed isolation of the affected LP heater, a leak (tube failure)of Reactor Plant Component Cooling Water (CCP) into the Upper Oil Reservoir of the "B"RCP will occur. CCP Surge Tank level, though slight, will discernibly decrease and, after afew minutes of leakage, an Oil Reservoir high level alarm will sound. The crew should takeaction per the ARP and AOP 3554, RCP Trip or Stopping a RCP at Power to attempt toreduce reactor power and take the affected RCP out of service. The crew may judge thatthey cannot take the plant offline quickly enough to prevent RCP damage and elect to trip theplant.

At the time of the trip, an Inter-System LOCA will occur. The crew should transitionthrough E-0 to step 27 and then to ECA-1.2, LOCA Outside CTMT. At some point in the EOPnetwork, depending on the speed of the crew, RCP trip criteria may be reached and shouldbe implemented [Critical Task]. SI will actuate or be actuated normally except that ESFBuilding Ventilation (RHR area ACUs) will fail to start. When the SI cold leg injection valve(3SIH*MV8835) is closed, the break will be isolated [Critical Task].

The scenario will be terminated upon transition to E-1, Loss of Reactor or SecondaryCoolant.

2. The SM should classify this event as a Site Area Emergency - Charlie Two due to a failureof two barriers (RCS & CTMT).



SECTION 4

EVALUATION GUIDE

INTER-SYSTEM LOCATitle:


All Control Room Conduct, Operations and Communications shall be in accordance withMP-14-MMM.




It is the responsibility of the Instructors in the simulator to insure that exam interruptions have aminimum negative impact on the Crew and the examinations we provide.

Be aware that at all times the Operators should treat the simulator as if it were the plant andyou too should treat it as much like the plant as possible when they are in the simulator.

As soon as the Instructors are aware of a simulator problem that will adversely affect the examin progress (computer fault, etc.) the Instructor should:



3. Request that the Crew leave the simulator control room. (The Crew should leavethe simulator for problems which involve major switch alignments).


5. After the Instructors believe the simulator is restored to service, the Crew shouldbe told how the exam will continue. If it is possible and felt to be acceptable tothe evaluators, the examination can begin where it left off with an update onplant parameters and each Crew member is prepared to restart. If theexamination will not begin where it left off, the crew should be told how andwhere the exam will begin again.

6. Once the Crew has been told how and where the exam will begin, have the crewconduct a brief so that the Instructor and evaluators can insure that the crew hasall the necessary information to continue with the scenario.

7. Once all Crew members, Instructors and evaluators are satisfied that they havethe necessary information to continue the scenario, place the simulator in RUNand announce to the Crew that you have continued the evaluation session.


SECTIuN 4

Lesson Title: INTER-SYSTEM LOCA

ID Number: 2K2NRC-004 Revision: 0Task









6. RESET to IC-92: TEMP IC 2K2NRC-LOUT-004 (based on IC-21)



9. ADJUST MWt using Turbine Load Set to 3411, (+)0, (-)3 IF using 100% power IC.









(S ( (SECTION 4




f. VERIFY annunciator, "COMPUTER FAILURE" (MB4C, 1-1 1), is NOT LIT.


1) See laminated directions on clipboard in Sim booth.


a. MB2, (AY6), CVCS Data Trend, 1 minute update, CHS-F1 32 (40-120), CHS-L1 12 (40-80), CHS-F1 21 (40-80), RCS-L461 (40-80)

b. MB4, (AY1), At Power Data Trend, 15 second update, CVQRPI, (3391-3428), CVQRPHRUN (3409-3413), CVQRP (3409-3413), RCL-T412*, (585-588)





14. OVERRIDE the annunciators that will be lit longterm in the CR, (as listed in the "Lit CRP Annunciators" section of the MP3 daily Status Reporthanging near instructor booth door).

15. IF placing equipment OOS, THEN perform the necessary switch manipulations and hang appropriate tags, as required, listed under"Equipment OOS."


17. HANG a Caution Tag on 3RCS*MV8000A stating, " 3RCS*MV8000A Closed and de-energized IAW Tech Spec 3.4.4, Action b"


(SECTION 4

(

Lesson Title: INTER-SYSTE

ID Number: 2K2NRC-004

Time IDA/Malf

0

:M LOCA

RevieTask

Instructor Information/Activity Assign Expected Action

PLACE THE FOLLOWING EQUIPMENT OOS: STANDARD 2K2 NRC EXAM EQUIPMENT

;ion: 0

Standard

1/01/01/01/01/0

MPMa

Ma

Ma

Ma

Ma


(RC) 3RCS*PCV455A A PORV OPEN - FALSE(RC) 3RCS*PCV455A A PORV GREEN - FALSE(RC) 3RCS*PCV455A A PORV RED - FALSE(RC) 3RCS*MV8000A A PORV Block Valve GREEN - FALSE(RC) 3RCS*MV8000A A PORV Block Valve RED - FALSE

kLF S106A RCS to Inter-System LOCA 1kLF S106B RCS to Inter-System LOCA (isolable) 1

LLF RP11 D Failure of Automatic Actuation of ESF Bldg. Ventilation

Event Malfunctions

1LF N109B Power Range NI Channel 42 Lower Detector Fails High

IF FW13N Low Pressure Feedwater Heater E6B Leak

1LF RC14B RCP B Upper Oil Reservoir Cooling Water Leak

00%00%

BT1BT1

I 100%

100%

100%

15 second ramp

15 second ramp

No ramp

RSCU #1

RSCU #2

RSCU #3. .



(SECTiON 4

(



AssignTime IDA/Malf Instructor Information/Activity Expected Action Standard

T = 0 EVENT 1: Shifting ChargingPumps

OP 3304A, Charging and Letdown,Rev. 28-01

Starting/Shifting Charging Pumps OP 3304A,Step 4.4

This Section Contains EOP RelatedMaterial

[Normal Evolution] Us

US

A computer display, showing all datarelevant to the operation of the pumpbeing started, should be used.

IF the associated alternate minimumflow relief valves (3CHS*RV851OA or3CHS*RV851 OB) lift, REQUEST IST toperform required testing andinspections. (* Ref. 6.4.6)

OP 3304A,Step 4.4.1NOTE

OP 3304A,Step 4.4.1

US/ RO/ IF starting or shifting to 3CHS*P3A,PEO charging pump A, PERFORM the

following:

a) Refer To OP 3330D, "ChargingPump Cooling," and VERIFYcharging pump cooling water is inoperation for 3CHS*P3A, chargingpump A.

OP 3304A,Step 4.4.4


(SECTIUN 4

(




NOTE: Throughout this procedure,when asked for local indications, allindications are normal as perprocedure.

PEO b) For 3CHS*P3A, charging pump A,CHECK lube oil reservoir level isbetween 1/3 and 2/3 full using3CHS*LG1A, A lube oil reservoirsite glass on pump (local).

PEO

RO

RO

RO

RO

c) PLACE 3CHS*P6A, charging pumpA auxiliary lube oil pump in "AUTO,"(local).

d) To align charging pump minimumflow recirculation valves for3CHS*P3A, charging pump A,OPEN the following (MB3):

* 3CHS*MV811 1A, "RECIRC DIS"

* 3CHS*MV8110, "RECIRC HDRISOL"

e) VERIFY a flow path from one of thefollowing sources to the chargingpumps:

* VCT

* RWST

* Boric acid tanks

f) START 3CHS*P3A, "CHG PP A,"(MB3).


( (a (SECTION 4




RO g) VERIFY minimum recirculation flowof 60 gpm as indicated on 3CHS-F75 (computer) or SHUTDOWNpump.

US/ RO h) IF any of the following conditionsoccur during the operation of thepump, SHUTDOWN the chargingpump:

* Pump operation changes fromsmooth to rough

* Oil temperature leaving the thrustbearing exceeds 1 550 F (local)

* Discharge pressure drops suddenlyas indicated on 3CHS*PI 117 (local)

* Auxiliary lube oil pressure dropsless than 15 psi (local)

* Pump running current exceeds88 amps (MB3)

US/ PEO i) CHECK the following parameters(locally):


( CSECTION 4




1) WHEN oil discharge pressure isgreater than 8 psig as indicated on3CHS*PI 1023A, VERIFYappropriate auxiliary lube oil pumpautomatically stops.

2) CHECK 3CHS-TI 1021A, auxiliarylube oil bearing outlettemperatures, are less than 1 550F(local).

3) CHECK 3CHS-PI 1023A, auxiliarylube oil filter outlet pressure,between 15 psig and 18 psig.

4) CHECK differential pressurebetween 3CHS-PI 1024A, auxiliarylube oil filter (3CHS*FLT1 1A) inlet,and 3CHS-PI 1023A, auxiliary lubeoil filter (3CHS*FLT1 1A) outlet,pressure indicators between 3 psidand 10 psid.

RO k) CHECK the following annunciators,not lit:

* MB3A 2-7, "CHARG PP A MOTORTEMP HI"

* MB3A 3-7, "CHARG PP A LUBEOIL PRESSURE LO"


(SECTIUN 4

(




* MB3A 5-9, "CHARG PP AUTOTRIP/OVERCURRENT"

* MB3B 3-1, "CHARG PP A OILCOOLER FLOW LO"

* MB3B 4-1, "CHARG PP A OILCOOLER TEMP Hi"

I) VERIFY the following chargingpump cubicle dampers positionedas required (VP1):

BOP

The ventilation supply lines to thecharging pump cubicles are isolated inwinter mode; no supply flow will occurwhen the inlet MODs are open.

* 3HVR*MOD5OA, ventilation supply,opened

* 3HVR*MOD49A, ventilationexhaust, opened

m) IF the charging pump was startedfor the purpose of shifting chargingpumps, PERFORM the following:

2) STOP the desired charging pump.

3) PLACE the applicable controlswitch to "AUTO."

OP 3304A,Step 4.4.4.1NOTE

RO

RO

RO


(I/I.

SECTIuN 4



AssignTime IDA/Malf Instructor InformationlActivity Expected Action Standard

RO

BOP

4) Refer To SP 3601 F.3," RCSLeakage-Controlled Leakage toRCP Seals," and PERFORMleakage determination.

n) WHEN the applicable pump isstopped, VERIFY the followingapplicable charging pump cubicledampers positioned as required(VP1):

Us

BOP

The ventilation supply lines to thecharging pump cubicles are isolated,therefore no supply flow will occurwhen the inlet MODs are open.

1) IF charging pump 3CHS*P3B wasstopped, VERIFY the followingclosed:

* 3HVR*MOD50B, ventilation supply

* 3HVR*MOD49B, ventilation exhaust

OP 3304A,Step 4.4.4.nNOTE

US/ PEO o) For the charging pump stopped,VERIFY the appropriate auxiliarylube oil pump automatically started:

CHS PUMP LUBE OIL PUMP INDICATOR3CHS*P36 3CHS*P6B 3CHS*PI 1023B


(SECTION 4

(




T=CHSpump shiftcomplete

MALFN109B100%15secramp

RSCU #1

EVENT 2: PR N1 42 UPPERDETECTOR FAILS HIGH

AOP 3571, Instrument FailureResponse, Rev.7

US Do not leave the rod selector switch inAUTO while diagnosing a relatedinstrument failure unless the reason forrod movement is a runback.

AOP 3571Step 1CAUTION

[Reactivity Manipulation - potential] US If a reactor trip occurs, immediately go toE-0, Reactor Trip or Safety Injection.

AOP 3571Step 1 NOTE

or

[instrument Malfunction - potential] RO Determine the initiating parameterand place the affected controller inMANUAL.

AOP 3571Step 1

CREW Stabilize the plant parameters. AOP 3571Step 2


(SECTION 4

I.




Us

US

It is desired that l&C personnel trip thebistables specified in this procedure. If,during off-hours, I&C personnel are notable to trip the necessary bistables withinthe time limitations required by theTechnical Specifications, OperationsDepartment personnel may trip thebistables using the guidance providedwithin this procedure.

Perform corrective actions usingappropriate attachment.

Instrument Failure

Power Range Nuclear InstrumentChannel Failure

AOP 3571Step 3 NOTE

AOP 3571Step 3

Attachment

D

AOP 3571 Rev. 7 Attachment D US Power Range Nuclear InstrumentChannel Failure

The following annunciators aresymptoms of a PZR pressure instrumentfailure:

PRESSURIZER PRESSURE Hi

PRESSURIZER PORV CHANNELPRESSURE Hi

MB4A 3-4

M B4A 4-3


(SECTIUN 4

(




PRESSURIZER PRESSUREDEVIATION

PRESSURIZER PRESSURE LO

PZR RELIEF VALVE DIS TEMP HI

PRESSURIZER SI CHANNELPRESSURE LO

PZR REL TK TEMP HI

PZR REL TK LEVEL HI-HI/HI1/LO

PZR REL TK PRESSURE HI

PZR PRES LO

PZR PRES HI

MB4A 4-4

MB4A 5-4

MB4A 3-5

MB4A 5-3

MB4A 2-2

MB4A 2-3

MB4A 2-4

MB4F 1,2,3,4-3

MB4F 1,2,3,4-4

LOOP 1,2,3,4 OVR TEMP AT

LOOP 1,2,3,4 OVR TEMP AT

PZR PORV PRES HI

PZR PRES LO

MB4F 1,2,3,4-5

MB4F 1,2,3,4-7

MB4F 1,2,3,4-13

MB2D1,2,3,4-5


(:SECTIUN 4

(




PZR PRES HI MB2D 1,2,3-6

Failure of two or more channels of PRinstrumentation may prevent P-1 0 fromresetting when power is reduced below10%. If P-10 fails to reset, the followingautomatic reactor trip signals are lost:

1. SR HIGH FLUX TRIP (1 05 CPS)

2. IR HIGH FLUX TRIP (25%)

3. PR HIGH FLUX LOW STPT TRIP(25%)

* The reactor operator must remainalert to any power increases whichwould necessitate a manual reactortrip.

* The Gamma Metrics NuclearInstrumentation System shall beused during the reactor shutdownin lieu of the source rangechannels.

AOP 3571Attachment DStep 1CAUTION

RO Defeat the failed channel input. AOP 3571Attachment DStep 1


SECTION 4(



AssignTime IDA/Malf Instructor Information/Activity Expected Action StandardStandard

At the detector current comparatordrawer, Turn the following switches tothe failed channel:

AOP 3571Attachment DStep 1 a

Rod Stop BypassUpper SectionLower SectionPower Mismatch Bypass.

At the comparator and rate drawer, Turnthe following switch to the failed channel:

Comparator Channel Defeat.

RO Restore TAVE - TREF error to within 10Fand Place rod control in automatic.

CREW When conditions have stabilized,observe MB board annunciators andparameters and immediately reportany unexpected or unexplainedconditions to the Shift Manager.

US Determine which Reactor ProtectionSystem bistable (s) requires tripping:

Place a check mark in the box above theappropriate channel that requires trippingon the last page of this Attachment.

AOP 3571Attachment DStep l b

AOP 3571Attachment DStep 2



AOP 3571Attachment DStep 4a


(SECTION 4


ID Number:

Time

2K2NRC-004 Revision: 0Task

AssignIDA/Malf Instructor Information/Activity Expected Action Standard

[Tech Specs]

LCO 3.3.1 (FU2)

Refer to Technical Specification 3.3.1and 4.2.4.2 and 4.2.1.1.1.b.

AOP 3571Attachment DStep 4b

SURV 4.2.4.2

NOTE: 4.2.1.1.1.b. not required if thecrew removes the affected channelfrom the AFD computer per AOP3571, Att. D, steps 6 & 7

Check the existing bistable status toensure a reactor trip will not occur whenthe failed channel is tripped.

Remove the appropriate control powerfuses for the affected channel.

AOP 3571Attachment DStep 4c

AOP 3571Attachment DStep 4d

REMOTESSeecolumn 3

NOTE: When requested act as l&CTechnician and trip bistables.

REMOTES

Request the l&C Department trip theappropriate bistables using AttachmentD and Attachment S.

AOP 3571Attachment DStep 4e

RXR107

RXR35

RXR06

RXR107

Door Open

OTDT 421 C

OTDT 421 D

Door Closed


(SECTIuN 4

!




Verify the appropriate bistable statuslights are lit.

AOP 3571Attachment DStep 4f

NOTE: If at any time during theperformance of this procedure, ifasked, as Reactor Engineering or UnitManagement, advice that NI powershould be used to determine reactorpower.

US Within one hour, Determine byobservation of the associatedpermissive annunciator window (s)that the following interlocks are intheir required state for the existingplant condition (Tech, Spec. 3.3.1,Action 8):


* Rx or turbine not at power P-7(MB4D 5-3)

* Three loop permissive P-8(MB4D 3-3)

* NIS power range P-9 permissive(MB4D 6-1)

* Reactor at power P-10(MB4D 4-3).

US / Perform the following to remove theCREW affected power range input to the AFD

computer (Program 3R5):

On the plant process computer, Selectthe NSSS menu, page 2.


AOP 3571Attachment DStep 6a


(SECTIUN 4

(


ID Number:

Time

2K2NRC-004 Revision: 0Task

AssignIDA/Malf Instructor Information/Activity Expected Action Standard

At the NSSS menu, Select "TiltingFactors" (F9).

Press the key (F5 through F8) thatcorresponds to the channel to beremoved.

Within one hour, if step 6 has notbeen performed, Refer to T/SSurveillance Requirement 4.2.1.1.1.b.

Request l&C Department performcorrective maintenance on failedinstrument.

AOP 3571Attachment DStep 6b

AOP 3571Attachment DStep 6c



US

US

T=NI failurecomplete andreactivitymanipulationcomplete.

MALFFW13N

EVENT #3: LP Feedwater Heater 6BLeak

RSCU #2

AOP 3567, Operation With OneFeedwater Heater String Isolated, Rev4

[Reactivity Manipulation]

CREW When removing a feedwater heaterfrom service during turbine operation,closely monitor turbine vibration,differential expansion, nuclear power,and feedwater heater temperaturesand pressures.

CREW Decrease Reactor Power To EQUALTO OR LESS THAN 95%

AOP3567Step 1CAUTION

AOP3567Step 1


(lSECTION 4




NOTE: The leak is in LP FeedwaterHeater E6B (6th Point, B Train)

CREW Identify Faulted Feedwater HeaterString

AOP3567Step 2

* Check feedwater heater levels -HIGH (with proper LCV operation)

NOTE: If PEO dispatched, reportabnormal noise and vibration

* Check feedwater heater - NOISEAND VIBRATION

* Check feedwater heaterperformance - DEGRADED

BOP OPEN Feedwater Heater BypassValve For The Affected FeedwaterHeaters

AOP3567Step 3

NOTE: This valve will be open

NOTE: This valve will be closed

For the low pressure heaters(3CNM-MOV88)

For the 1 st point heaters(3FWS-MOV17)

BOP Check 1st Point Feedwater HeaterBypass Valve (3FWS-MOV17) -OPEN

AOP3567Step 4

US

BOP

Proceed to step 7. AOP3567Step 4 RNO

Check LP Feedwater Heater BypassValve (3CNM-MOV88) - OPEN

AOP3567Step 7


(SECTION 4

(Lesson Title: INTER-SYSTEM LOCA

ID Number: 2K2NRC-004Task

Assign

Revision: 0

StandardTime IDA/Malf Instructor Information/Activity Expected Action

US

BOP

Isolate Steam Supply and Drains ForLP Feedwater Heaters

Check affected low pressure feedwaterheater string extraction steam supplyvalves - CLOSED

AOP3567Step 8

AOP3567Step 8.a

For String A For String B For String C

3ESS-MOV29A (E2A) 3ESS-MOV29B (E2B) 3ESS-MOV29C (E2C)



BOP CLOSE valves.

BOP Check affected low pressure feedwaterheater string extraction steam drainvalves - OPEN

For String A For String B For String C 13DTM-AOV46A (E2A) 3DTM-AOV46B (E2B) 3DTM-AOV46C (E2C)

AOP3567Step 8.aRNO

AOP3567Step 8.b

3DTM-AOV47A (E3A) 3DTM-AOV47B (E3B) 3DTM-AOV47C (E3C)


(SECTION 4

('



AssianTime IDA/Malf Instructor Information/Activitv Expected Action Standard

3DTM-AOV49A (E4A) 3DTM-AOV49B (E4B) 3DTM-AOV49C (E4C)

BOP

BOP

OPEN valves.

IF the low pressure feedwater heaterstring extraction steam drain valves willNOT open, THEN Open affected lowpressure feedwater heater stringextraction steam drain bypass valvesusing Attachment C.

Verify Affected SG Blowdown FlashTank Vent - CLOSED

For heater E4A3BDG-MOV21A

For heater E4B3BDG-MOV21 B

For heater E4C3BDG-MOV21 C

AOP3567Step 8.bRNO

AOP3567Step 9

BOP CLOSE valves. AOP3567Step 9 RNO


(SECTION 4

(

Exam Title: INTER-SYSTEM LOCA



BOP If a heater drain tank pump is stoppedwith the Main Feed System inoperation, closely monitor the mainfeed pump suction pressure, dischargepressure, and flow rate forabnormalities.

AOP3567Step 10NOTE

NOTE: See attached ARP MB6A, 5-7,to direct PEO actions on Heater DrainPump trip.

BOP Verify Affected 4th Point HeaterDrain Pump - TRIPPED

AOP3567Step 10

BOP STOP pump. AOP3567Step 10RNO

CREW Complete Isolation Of FeedwaterHeater String

AOP3567Step 11

AOP3567Step 11.a

BOP Check affected heater outlet isolationvalve - CLOSED

For string A3CNM-MOV70A

BOP

BOP

CLOSE valves. AOP3567Step 11.aRNO

Check affected heater inlet isolationvalve - CLOSED

AOP3567Step 11.b


(SSECTION 4

(




For string A3CNM-MOV49A

CLOSE valves.BOP AOP3567Step 11.bRNO

NOTE: Objective of the procedure met.Consult with Lead Examiner and

proceed ahead to Event 4.

CREW Perform Local Isolation of AffectedLP Feedwater

AOP3567Step 12

US

Us

Dispatch an operator to Perform thelocal actions to isolate the affectedfeedwater heater string usingAttachment B

WHEN the local actions specified inAttachment B are complete, THENProceed to step 13

Following the performance of theproceeding steps, the affectedfeedwater heater string is sufficientlyisolated for continued power operation.

AOP3567Step 12.a

AOP3567Step 12.b

AOP3567Step 13NOTE

CREW Verify MB Annunciators AndParameters - AS EXPECTED

Immediately notify the Shift Manager ofany unexplained or unexpectedconditions.

AOP3567Step 13

AOP3567Step 13RNO


I

SECT1UN 4(




CREW

CREW

US

CREW

Perform Follow-up Actions:

If desired, increase reactor power to100%

Repair affected feedwater heater string

Restore the affected 1st pointfeedwater heater to service byperforming the following:

AOP3567Step 14

AOP3567Step 14.a

AOP3567Step 14.b

AOP3567Step 14.c

Using OP 3321, "Main Feedwater,"Place the tube side of the affected HPfeedwater heater in service

Using OP 3320, "Feedwater HeaterDrains and Vents," Place the shell sideof the affected HP feedwater heater inservice

AOP3567Step 14.c 1)

AOP3567Step 14.c 2)

US Notify Plant Engineering (ISI Group)that the LP feedwater heater bypassline or the HP feedwater heater bypassline (MP3 Erosion/Corrosion Programlow usage lines) has been placed inservice

AOP3567Step 14.d


( (SECTiuN 4

(




T= AOP 3567substantiallycompleteANDExaminer'sCue.

MALFRC14B100%

EVENT 4: RPCCW Leak into RCPB Upper Oil Reservoir

RSCU #3

NOTE: The reservoir high level alarmwill sound after the malfunction hasbeen in about 4 minutes.

RO Check RCS-L477A, RCP C upper oilreservoir level computer point, to confirmalarm.

OP 3353.MB4BStep 1

CREW MONITOR the following RCP Ccomputer points:

OP 3353.MB4BStep 2

* RCS-T481A, RCP C upper thrustbearing temperature

* RCS-T481 B, RCP C upper thrustbearing temperature

* RCS-T485A, RCP C upper thrustbearing temperature

RO IF at any time RCP C thrust bearing orradial bearing temperature computerpoint is greater than 1950 F PERFORMthe following:

OP 3353.MB4BStep 3

* TRIP reactor

* STOP RCP C


(SECTION 4

(




* Go To E-0

US CHECK 3CCP-LI20B, RPCCW surgetank level, for indication of RPCCWleakage.

US The following steps requirescontainment entry.

CREW IF directed by the SM/US CHECK forRPCCW to RCP C lube oil leak.

US Refer to Tech Specs and DETERMINELCOs

OP 3353.MB4BStep 4

OP 3353.MB3BALARA Step 5

OP 3353.MB3BStep 5

OP 3353.MB3BStep 6

AOP 3554, Stopping an RCP atPower, Rev. 6

RO Check RCP Status - ALL PUMPSRUNNING.

AOP 3554Step 1

RO Check Reactor Power.

Verify THREE LOOP PERMISSIVE P-8annunciator (MB4D 3-3) - LIT.

AOP 3554Step 2

AOP 3554Step 2.a

NOTE: The rate at which temperatureis increasing should inspire the crewto use the Rapid Downpower

Go to one of the following to reducepower:

|e AOP 3575, "Rapid Downpower I

AOP 3554Step 2.aRNO

* OP 3204, "At Power Operation"


(SECTION 4

(




AOP 3575, Rapid Downpower, Rev.7 * A CONVEX requestedemergency generation reductionshould be completed within 15minutes of notification.

AOP 3575Step 1NOTE

[Reactivity Manipulation] * If a unit shutdown is required, thetarget power level should bebetween 20% and 25% reactorpower.

* If at any time ROD CONTROLBANKS LIMIT LO - LO (MB4C 4- 9 ) annunciator is received, DONOT go to AOP 3566, ImmediateBoration. Immediately performstep 9.

CREW

US

US

US

Determine Power Reduction Rate(%/min).

Check desired power reduction rate -LESS THAN OR EQUAL TO5%/min.

Check power reduction CONVEXREQUESTED

Proceed to Step 1.d.

AOP 3575Step 1

AOP 3575Step 1.a

AOP 3575Step 1.b

AOP 3575Step 1.bRNO


(SECTIoN 4

(.





AOP 3575Step 1.d

Total Power Change (A%)

10% 20% 30% 40% 50% 60% 70% =

15 1 3 3 3 5 5 5

30 0.5 1 1 3 3 3 3

45 0.5 0.5 1 1 3 3 3

60 0.5 0.5 1 1 1 3

Time to 75 0.5 0.5 1 1 1 1

Reduce 90 0.5 0.5 0.5 1 1 1 =

Power 105 0.5 0.5 0.5 0.5 1 1

(min) 120 0.5 0.5 0.5 0.5 1

135 0.5 0.5 0.5 0.5 1

150 0.5 0.5 0.5 0.5 0.5 =

160 0.5 0.5 0.5 0.5 0.5

US Check Rod Control In AUTO. AOP 3575Step 2


SECTIuN 4(.




CREW

us

US

BOP

BOP

BOP

Align EHC Panel


Check LOAD LIMIT LIMITING light -LIT

Intermittently Press DECREASELOAD pushbutton until LOAD LIMITLIMITING light - NOT LIT

Rotate LOAD LIMIT SET adjust knobat least one full turn in raise direction

Select DECREASE LOADING RATEto ON

Select LOAD RATE LIMIT % MIN torequired power reduction rate (%min)

AOP 3575Step 3

AOP 3575Step 3.a

AOP 3575Step 3.b

AOP 3575Step 3.c

AOP 3575Step 3.d

AOP 3575Step 3.e

AOP 3575Step 3.f

If at any time the power reductionrate or target power level must bechanged, Return to step 1.



US/RO

RO

AOP 3575Step 4NOTE

AOP 3575Step 4

AOP 3575Step 4.a


Title:

ID Number:

Time

EVALUATION GUIDE(

INTER-SYSTEM LOCA

2K2 NRC-004

IDA/Malf Instr

F

:uctor Information/ActivityTask

Assign

RO

RO

RO

RO

Expected Actions

Check power reduction - REQUIREDTO STABILIZE PLANT

Proceed to step 5.

Initiate Rapid Boration

Verify RCS makeup system in -AUTO

START one boric acid transfer pump.



OPEN charging line flow controlvalve, to match boric acid flow(3CHS-FI 183A)

Record time boration started

Time


Revision: 0

Standard

AOP 3575Step 4.b

AOP 3575Step 4.bRNO

AOP 3575Step 5

AOP 3575Step 5.a

AOP 3575Step 5.b

AOP 3575Step 5.c

AOP 3575Step 5.d

AOP 3575Step 5.e

AOP 3575Step 5.f

AOP 3575Step 5.g


(EVALUATION GUIDE

(..Title: INTER-SYSTEM LOCA



Determine required boric acidaddition by multiplying total powerchange (A%) by 15 (gal/%) =gal.

AOP 3575Step 5.h

Us

US

BOP

Determine required time to borate bydividing required gallons of boric acidby the direct boric acid flowrate (netcharging flow rate if using gravityboration) _ min.



The following step places one TDFW pump in manual while allowingthe other TD FW pump toautomatically unload during thedownpower.

AOP 3575Step 5.i

AOP 3575Step 5.j

AOP 3575Step 5.k

AOP 3575Step 8NOTE

NOTE: The degrading oil reservoircondition will eventually either impell theCrew to manually trip the Reactor ORthe RCP will seize and the Reactor willtrip on RCP Low Speed. It is notexpected that the crew will get muchfurther than Step 8 of AOP 3575 beforeone of these conditions occurs.

US/BOP Align One Feedwater Pump ForAutomatic Unloading

AOP 3575Step 8


Title:EVALU~i ION GUIDE

(INTER-SYSTEM LOCA



BOP Verify removing a feedwater pump AOP 3575from service during the downpower - Step 8.aDESIRED

T= MALF EVENT 4: RPCCW Leak into RCPDownpower RC14B C Upper Oil Reservoir - Ongoingunderway ongoingand reactivitymanipulationcomplete ifdone hereplusExaminer'sCue

EVENT 5: Inter-System LOCA

NOTE: US should go to "MasterSilence" before orderingreactor trip .

E-O, Reactor Trip or SafetyInjection, Rev. 21

RO

Crew

TRIP the reactor

Go to E-0, Reactor Trip or SafetyInjection.

* Foldout page must be open E-0, Step 1,NOTE

* ADVERSE CTMT defined asGREATER THAN 180 0F orGREATER THAN 105R/hr incontainment.


Title:EVALUA) iON GUIDE

INTER-SYSTEM LOCA



* The reactor can be interpreted as"tripped" when any two of threebulleted substeps of Step 1.* aresatisfied.

T= 3 minsof eventclassifiable

Floorinstructor

Prompt the SM to contact the backroom for the Shift Tech.

RO Verify Reactor Trip E-0, Step 1



* Check neutron flux -DECREASING

Verify Turbine Trip E-0, Step 2

Check all turbine stop valves -CLOSED

E-0,Step 2.a

BOP

BOP

US

Verify Power to AC EmergencyBusses

Check busses 34C and 34D -

BOTH ENERGIZED


E-0, Step 3

E-0,Step 3.a

E-0, Step 4

RO Verify SAFETY INJECTIONACTUATION annunciator - (MB4D 1-6or MB2B 5-9) - LIT

EOP 35 E-0, Step 4.a


(EVALUATION GUIDE

(Title: INTER-SYSTEM LOCA


AssignTime IDA/Malf Instructor Information/Activity Exoected Actions StandardStandard

US Check if SI is required E-0,Step 4.a,RNO

* CTMT pressure GREATER THAN18 psia

OR

* PZR pressure LESS THAN 1890psia

OR

* PZR level LESS THAN 16%

OR

* RCS subcooling LESS THAN 32 0F

OR

* SG pressure LESS THAN 660psig

IF SI is required,

THEN

Initiate SI and Proceed to step 5.


(EVALUATION GUIDE




IF Si is NOT required,

THEN

Initiate monitoring of CSF StatusTrees and Go to ES-0.1, ReactorTrip Response.

By observation of ESF Group 2 StatusPanel lights, Verify both trains of Si -ACTUATED

Manually Initiate SI.

RO

RO

RO

BOP

Verify Service Water Pumps - ATLEAST ONE PER TRAIN RUNNING

Verify Two RPCCW Pumps - ONEPER TRAIN RUNNING

Verify ECCS Pumps Running

* Check Si pumps - RUNNING

* Check RHR pumps - RUNNING

* Check two charging pumps -RUNNING

Verify AFW Pumps Running

E-0,Step 4.b

E-0,Step 4.b,RNO

E-0, Step 5

E-0, Step 6

E-0, Step 7

E-0, Step 8


EVALUAl iON GUIDEa,

Title: INTER-SYSTEM LOCA



Check MD pumps - RUNNING

BOP

BOP

Check turbine - driven pump -RUNNING, IF NECESSARY

Verify FW Isolation

* Check SG feed regulating valves -CLOSED

* Check SG feed regulating bypassvalves - CLOSED

* Check FW isolation trip valves -CLOSED

* Check TD FW pump - TRIPPED

* Check MD FW pumps - STOPPED

* Check SG blowdown isolationvalves - CLOSED

* Check SG blowdown sampleisolation valves - CLOSED

* Check SG chemical feed isolationvalves - CLOSED

Check If Main Steam Lines ShouldBe Isolated

E-0,Step 8.a

E-0,Step 8.b

E-0, Step 9

E-0, Step 10


Title:

ID Number:

Time

EVALUAl iON GUIDEINTER-SYSTEM LOCA

2K2 NRC-004

IDA/Malf InstrTask

Assiqnuctor Information/Activity------ ZL��

Expected Actions

Check Ctmt pressure GREATERTHAN 18 psia

OR

Any SG pressure LESS THAN 660psig

Verify MSIVs and MSIV bypass valves-CLOSED

Check ESF Group 3 lights - LIT.

Check if CDA Required

Check Ctmt pressure is GREATERTHAN 23 psia

OR

Ctmt spray - INITIATED

Proceed to Step 12.

Verify CAR Fans Operating InEmergency Mode

Check CAR fan status:

* CAR fans A and B - RUNNING

Revision: 0

Standard

E-0,Step 10.a

E-0,Step 10.b

E-0,Step 10.c

E-0, Step 11

E-0,Step 11.a

E-0,Stepl 1 ,a,RNO

E-0, Step 12

E-0,Step 12.a

RO

US

BOP

BOP


( (S (EVALUATION GUIDE




* CAR fan C - STOPPED

BOP START/STOP CAR fans as E-0,necessary. Step 12.a,

RNO

RO Verify RPCCW Ctmt supply and return E-0,header isolations - OPEN Step 12.b

RO Verify Train A and B RPCCW supply E-0,and return to chill water valves - Step 12.cOPEN

RO Verify CIA E-0, Step 13

RO Check ESF Group 2 status columns 2 E-0,through 10 - LIT Step 13.a

RO Initiate CIA. E-0,

IF ESF Group 2, columns 2 Step 13.a,through 10 are NOT lit, THEN

Using Attachment A Reposition valvesas necessary for minimum safetyfunction

RO Verify Proper ESF Status Panel E-0, Step 14Indication

* Verify ESF Group 1 lights - OFF

* Verify ESF Group 2 lights - LIT


(EVALUATION GUIDE




T= InitialMALF

MALFRP11D

EVENT 6: ESF Building VentilationFails to Auto Actuate

Align components for minimum safetyfunction.

E-0, Step 14RNO


E-0, Step 15

* Ctmt temperature GREATERTHAN 1800 F

OR

* Ctmt radiation GREATER THAN1 05 R/hr

CREW DO NOT use ADVERSE CTMTparameters.

E-0,Step 15,RNO


RO

RO


FLOW INDICATED


Check RCS pressure - GREATERTHAN 1650 psia (1950 psiaADVERSE CTMT)

E-0,Step 16.a

E-0,Step 16.a,RNO

E-0,Step 16.b


(EVALUAI iON GUIDE




US Proceed to Step 16.d

Proceed to step 17.

E-0,Step 16.b,RNO

CREW should perform a short briefand come out of "Master Silence" atthe completion of Step 16.

E-0,Step 16.c

Check Si pumps - FLOW INDICATED


Check RCS pressure - LESS THAN300 psia (500 psia ADVERSE CTMT)

Proceed to step 17.

Check RHR pumps - FLOWINDICATED.


E-0,Step 16.d

E-0, Step16.d RNO

E-0,Step 16.e

E-0,Step 16.eRNO

E-0,Step 16.f

E-0,Step 16.fRNO

BOP Verify Adequate Heat Sink


E-0, Step 17

E-0,Step 17.a


(EVALUA i ION GUIDE




Us

BOP

US

BOP

BOP

US

BOP

Proceed to Step 17.d. E-0,Step 17.a,RNO

Control feed flow to maintain NR level- BETWEEN 8% and 50% (42% and50% ADVERSE CTMT)

E-0,Step 17.b


Verify Total AFW Flow - GREATERTHAN 530 gpm


E-0,Step 17.d

E-0,Step 17.d,RNO

IF AFW Flow GREATER THAN 530gpm can NOT be established,

THEN

Initiate monitoring of CSF StatusTrees and Go to FR-H.1, Response toLoss of Secondary Heat Sink.

Verify AFW Valve Alignment -PROPER EMERGENCY ALIGNMENT

E-0, Step 18



EVALUATION GUIDEI,




RO Verify ECCS Valve Alignment -PROPER EMERGENCY ALIGNMENT

E-0, Step 19


US Check Plant Status E-0, Step 20

NOTE: When asked, REPORT that"all SLCRS doors indicate closed."

Verify SLCRS doors - CLOSED

Request Security Close all SLCRSdoors.

US

E-0,Step 20.a

E-0,Step 20.a,RNO

RO

RO

RO

RO

Check CONTROL BUILDINGISOLATION annunciator (MB4D 3-6) -LIT


E-0,Step 20.b

E-0,Step 20.b,RNO

* Ctmt pressure GREATER THAN18 psia

OR

* Control Building radiation monitorin alarm

OR


(EVALUATION GUIDE




RO

US

* SI manually actuated

IF CBI required,

THEN

Initiate CBI.

IF CBI is NOT required,

THEN

Proceed to Step 21.



Verify control building purge supplyfan and purge exhaust fan - NOTRUNNING


RO

RO

BOP

BOP

E-0,Step 20.c

E-0,Step 20.c,RNO

E-0,Step 20.d

E-0,Step 20.d,RNO

* Stop purge supply fan.

* Stop purge exhaust fan.

* Locally Close instrument airisolations


( ~((EVALUAliON GUIDE





* 3IAS-V726 (CB47' IRRstairwell)

* 31AS-V644 (CB 66' west wall)

Locally Close instrument airisolation valve for 3HVC-AOD134

BOP Control building air bank isolation E-0,valves - OPEN (after 60 seconds) Step 20.e

BOP OPEN valves E-0,Step 20.e,RNO

BOP IF at least one air bank isolation valvecan NOT be opened,

THEN

Locally throttle Open at least onepair of air bank isolation bypassvalves to maintain 0.125 incheswater at Control Building APindicator on VP1.




(EVALUAI iON GUIDE




BOP STOP kitchen exhaust fan E-0,Step 20.f

E-0,Step 20.g

NOTE: When called, WAIT 3 - 5 min,Then REPORT "All Control Buildingpressure boundary doors are Closedand Dogged."



Verify RCS cold leg WR temperature -BETWEEN 5501F and 5601F

Proceed to Step 22

E-0,Step 21.a

US E-0,Step 21.b

RO Check PZR Valves E-0, Step 22

RO

RO

RO


iF PZR pressure LESS THAN 2350psia, THEN CLOSE PORVs.

Verify normal PZR spray valves -CLOSED

Verify PZR safety valves - CLOSED

E-0,Step 22.a

E-0,Step 22.a,RNO

E-0,Step 22.b

E-0,Step 22.c


(EVALUATION GUIDE

(,Title: INTER-SYSTEM LOCA



CREW To prevent damage to the RCPseal(s), seal injection flow should bemaintained to all RCPs.

E-0,Step 23,CAUTION

[Critical Task] RO Check If RCPs Should Be Stopped E-0, Step 23

NOTE: Depending on the pace of thecrew through the EOP network thisstep may be performed here or lateras a continuous action.

Verify RCPs - ANY RUNNING E-0,Step 23.a

BOP/RO Check If SG Secondary BoundariesAre Intact


E-0, Step 24

E-0,Step 24.a



Ensure crew request activity sampleswith HP coverage

BOP Check If SG Tubes Are Intact E-0, Step 25

RO Sample all SGs for activity E-0,Step 25.a


( ~((EVALUATION GUIDE




1. RESET SG blowdown sampleisolation

2. OPEN SG blowdown sampleisolation valve(s)

3. Request Chemistry obtain activitysamples using HP coverage

BOP Check steam generator levels - NO E-0,SG LEVEL INCREASING IN AN Step 25.bUNCONTROLLED MANNER

US Initiate monitoring of CSF Status E-0,Trees and Go to E-3, Steam Step 25.b,Generator Tube Rupture. RNO

Verify trend history and alarm status of E-0,radiation monitors Step 25.c

* Main steam line - NORMAL



Initiate monitoring of CSF Status E-0,Trees and Go to E-3, Steam Step 25.cGenerator Tube Rupture RNO

RO Check If RCS Is Intact E-0, Step 26


(EVALUAI ION GUIDE

(,Title: INTER-SYSTEM LOCA



* Verify Ctmt radiation using3CMS*RE22 (pre-trip) - NORMAL

* Verify Ctmt radiation usingradiation monitoring grouphistogram (CTMT) - NORMAL

* Verify Ctmt pressure - NORMAL

* Verify Ctmt recirculation sumplevel - NORMAL

RO Check for RCS Leakage OutsideCTMT

E-0, Step 27

Check Auxiliary Building and ESFBuilding radiation (radiation monitoringgroup histograms)

Verify Auxiliary Building (AUX) -NORMAL

Verify ESF Building (ESF) - NORMAL

Verify SLCRS Building (SLCRS) -NORMAL

E-0,Step 27.a


EVALUAl iON GUIDETitle: INTER-SYSTEM LOCA



Check for Auxiliary Building or ESF E-0,Building flooding Step 27.b

1) Verify SUMP LEVEL HI lights(MB1) - NOT LIT

* ESF PIPE TNL

* ECCS PIPE CUB

* ESF RHR CUB

* ESF RSS CUB

2) Verify Annunciator SAFEGUARDSAREA FLOODING (MB1C 2-8) -NOT LIT

IF the cause is a loss of RCS E-0,inventory outside containment, THEN Step 27.b

RNOInitiate monitoring of CSF Status Tressand Go to ECA-1.2, LOCA OutsideContainment

ECA-1.2, LOCA Outside CTMT, US Determine Procedure Entry Point ECA 1.2,Rev. 7 And Perform The Applicable Action Step 1

US * IF the LOCA is in the AuxiliaryBuilding, THEN Proceed to Step 2.

US * IF the LOCA is in the ESFBuilding, THEN Proceed toCAUTION prior to Step 3.


( (1 (EVALUATION GUIDE




US Consult with the ADTS prior to ECA 1.2,dispatching personnel to locally Step 3operate RHR System valves. CAUTION

US/RO Verify Proper Valve Alignment In ECA 1.2,ESF Building Step 3

CLOSE valves. ECA 1.2,

IF the valves can NOT be closed, Step 3 RNOTHEN Locally Close valves forminimum safety function.Verify RHR suction isolation valves - ECA 3 a

CLOSED.Step 3.a

3RHS*MV8701A

3RHS*MV8701 B

3RHS*MV8701 C

3RHS*MV8702A

3RHS*MV8702B

3RHS*MV8702C

Verify RHR hot leg injection valve ECA 1.2,(3SIL*MV8840) - CLOSED. Step 3.b

Verify Si pump hot leg injection valves ECA 1.2,(3SIH*MV8802A and 3SIH*MV8802B) Step 3.c-CLOSED.


(EVALUATION GUIDE




US Try To Identify And Isolate Break

Turn the power lockout switch to ONfor the following valves (MB2R):

* RHR pump A cold leg injectionvalve (3SIL*MV8809A).

* RHR pump B cold leg injectionvalve (3SIL*MV8809B).

* Si cold leg injection valve(3SIH*MV8835).

CLOSE one of the following:

* RHR pump A cold leginjection valve(3SI L*MV8809A)

* RHR pump B cold leginjection valve(3SI L*MV8809B)

* SI cold leg injection valve(3SIH*MV8835)

Check RCS pressure - INCREASING

ECA 1.2,Step 4

ECA 1.2,Step 4.a

ECA 1.2,Step 4.b

T= Begins toclose 3SIH*MV8835

DELETEMALF

[Critical Task]

S106A

ECA 1.2,Step 4.c


EVALUAI iON GUIDETitle: INTER-SYSTEM LOCA



Perform the following: ECA 1.2,Step 4.cRNO

1. OPEN valve closed in step 4.b

2. IF all lines have been checked,THEN Proceed to step 4.d

3. Return to step 4.b

Turn the power lockout switch to OFF ECA 1.2,for the following valves (MB2R): Step 4.d

* RHR pump A(3S[L*MV8809A)

* RHR pump B(3SIL*MV88809B)

* SI injection (3SIH*MV8835)

Check If Break Is Isolated ECA 1.2,Step 5

Check RCS pressure - INCREASING. ECA 1.2,Step 5.a

Go to E-1, Loss of Reactor or ECA 1.2,Secondary Coolant. Step 5.b

TERMINATE UPON TRANSITION TO E-1, Loss of Reactor or Secondary Coolant.


SECTION 4


EVALUATION GUIDE

I. SUMMARY


TASK DESCRIPTION

Trip all RCPs so that anOrange Path on Core Coolingbased on core exit

thermocouples (718 F) doesnot occur when forcedcirculation in the RCS stops(Small Break LOCA).

NOTE: Critical task IFconditions occur which wouldrequire the tripping of theRCPs.

TASK#

E-1 -- C

K/A >1= 3.0

002.K5.143.814.2

BASIS FOR SELECTIONFailure to trip the RCPs under thepostulated plant conditions leads tocore uncovery and to fuel claddingtemperatures in excess of 22000F,which is the limit specified in theECCS acceptance criteria. Thus,failure to perform the taskrepresents "mis-operation orincorrect crew performance whichleads to degradation of.. .{the fuelcladding} ...barrier to fission productrelease" and to "violation of thefacility license condition."Failure to isolate a LOCA outsidecontainment (that can be isolated)degrades containment integritybeyond the level of degradationirreparably introduced by thepostulated conditions. It alsoconstitutes "mis-operation orincorrect crew performance whichleads to degradation of a barrier tofission product release" andeventually "to degradedECCS.. .capacity."

Isolate the LOCA outside

containment before transition

out of ECA-1.2

ECA-1 .2-- A

E04.EA1 .33.814.0

Note: r] Used to designate critical tasks. Should alsobe incorporated into column 3 or 4 ofInstructor Guide.


SECTION 4


ID Number: 2K2NRC-004 Revision: 0EVALUATION GUIDE


SECTION 5

SCENARIO INITIAL CONDITIONS

ID Number: 2K2NRC-004 RE

Reactor Power: 100%

Operating History: 450 day on line

RCS Boron: 50 ppm

Core Burnup: 18,600 MWD/MTU

Condensate Demins: 7 demins in service

Evolutions in Progress: NONE, A Train Protected, Intaki

Major Equipment OOS: "A" PORV is inoperable due to acontrol circuitry. It has been outElectrical maintenance estimatereturned to service within 24 hot

The following Tech Specs are ai

Tech Spec 3.4.4, action b3TRM 7.4.1 action a.1 and a.3 fithe block valve 3RCS*MV8000A

wvision: 0

a Condition: GREEN

in electrical short in theI of service for 8 hours.s that the valve will beirs.

pplicable:

or both the A PORV and

Crew Instructions:

Shift running Charging Pumps to the "A" CHS pump running per OP 3304A, Chargingand Letdown, Section 4.4.




° If not using the speed dial option on the phone system, the operator must dial either#3333 or #3334 to reach the person/department they desire.

° The following PPC programs do not function on the simulator:



SECTION 6




Remote functions:


Malfunctions:


Initial Conditions:

The initial condition(s) contained in the guide are certified or have been developed from certifiedIC's in accordance with NSEM-4.02.



Test Run:

The scenario contained in the guide has been test run and validated (validation sheetcompleted, next page)on the simulator. Simulator response is reasonable and as expected.


The dynamic examination review checklist is complete. (This is not required unless the examwill be used as an Annual Exam, then NUREG 1021 requirements apply.)

Technical Reviewer Date


SECTION 7




I. References:

AOP*3571

AOP*3567

AOP*3575

AOP*3554

EOP*E-0

EOP*ECA-1.2

EOP*ERGEXE

EOP* Step DOC

EOP*ERGHP

EPIP*EPIP 4400

NUREG*1021 rev 8

Instrument Failure Response

Operation with One Feedwater Heater String Isolated

Rapid Downpower

RCP Trip or Stopping an RCP at Power


LOCA Outside CTMT





Examiners Standards




INTER-SYSTEM LOCA

2K2NRC-004 Revision: 0

Title:

ID Number:

I. Summary:

Facility: Millstone 3 PWR: Scenario No: 2K2NRC-004 Op-Test No: 2K2

Examiners: Operators:


Event Malf. Event Event DescriptionNo: No. Type *1 None N(RO) Shift running CHS pumps using OP 3204A, Charging

and Letdown, Section 4.42 N109B I(RO) or Power Range NI Channel 42 Lower Detector Fails High

R(RO)3 FW1 3N C(ROI LP Feedwater 6B Heater Leak

BOP)R(ALL)

4 RC14B C(RO) RPCCW Leak into RCP B Upper Oil ReservoirR(ALL) Rapid Downpower per AOP 3575

5 S106A M(ALL) RCS to Si Inter-System LOCAS106B

6 RP11 D C(ALL) ESF Bldg Ventilation Fails to Automatically Actuate









_Y_1. The initial conditions are realistic, in that some equipment and/or instrumentation may be out ofservice, but it does not cue the crew into expected events.

_Y_2. The scenario consists mostly of related events.

_Y_3. Each event description consists of:

- the point in the scenario when it is to be initiated- the malfunctions(s) that are entered to initiate the event- the symptoms/cues that will be visible to the crew- the expected operator actions (by shift position)- the event termination point (if applicable)

_Y_4. No more than one non-mechanistic failure (e.g., pipe break) is incorporated into the scenariowithout a credible preceding incident such as a seismic event.


_Y_6. Sequencing/timing of events is reasonable, and allows for the examination team to obtaincomplete evaluation results commensurate with the scenario objectives.

_N/A_7. If time compression techniques are used, scenario summary clearly so indicates. Operators havesufficient time to carry out expected activities without undue time constraints. Cues are given.


_Y_9. The scenario has been validated. Any open simulator performance deficiencies have beenevaluated to ensure functional fidelity is maintained while running the scenario.

_Y__10. Every operator will be evaluated using at least one new or significantly modified scenario. All otherscenarios have been altered lAW Section D.4 of ES301

_Y__11. All individual operator competencies can be evaluated, as verified using form ES-301-6.

_Y__12. Each operator will be significantly involved in the minimum number of transients and eventsspecified on Form ES-301-5. (Form submitted with simulator scenarios).

_Y__13. Level of difficulty is appropriate to support licensing decisions for each crew position.







01. Total Malfunctions (TM) - Include EM's- 5 to 8 required

Power Range NI Fails High, Leak in LP Feedwater Heater, RCP Hi Motor Temp (CCPLeak to Oil Reservoir), Inter-System LOCA,, ESF Auto Actuation Failure (ESF BldgVentilation)

02. Malf's after EOP entry (EM's)- 1 to 2 required

ESF Auto Actuation Failure (ESF Bldg Ventilation), Inter-System LOCA

03. Abnormal Events (AE)-2 to 4 required

Power Range NI Fails High, Operation with One Feedwater String Isolated, RCP HiMotor Temp (CCP Leak to Oil Reservoir), ESF Auto Actuation Failure (ESF BldgVentilation)

04. Major Transients (MT)-1 to 2 required

Rapid Downpower/Plant Trip, Inter-system LOCA

05. EOP's (EU) entered/requiring substantive actions 1 to 2 required

E-O

06. EOP Contingencies requiring substantive actions [ECAs/FRs](EC) 0 to2 required

ECA-1.2, LOCA Outside CTMT


ECA-1.2 -- A Isolate the LOCA outside containment before transition out ofECA-2.1

E.1-C Trip all RCPs before Orange Path


Total: 5

Total: 2

Total: 4

Total: 2

Total: 1

Total: 1

Total: 2

Total: 60 min

09. EOP run time: Total: 30 min


NOTES: Reactivity Manipulation: Power Range High Failure/RCP High Temp


2K2 LOUT EXAM MATERIALS SIMULATOR EXAM SI~MO1 EXAMINATION · 2012. 11. 18. · ID Number: 2K2...

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Transcript of 2K2 LOUT EXAM MATERIALS SIMULATOR EXAM SI~MO1 EXAMINATION · 2012. 11. 18. · ID Number: 2K2...