ML041070244

Applicant's Actions or Behavior

Diagnose high failure of either PZR Pressure Transmitter pTp-44 or

Master Controller.

-

1C-?38, P Z R LO PRESS

-

1C-D8, P

m

LO LVL

-

ICW, PRZR RELIEF TANK

PRESS

-

1C-A$, PRZR PRESS CONTR IllI BUTPUT

~

1D-H4, PRZR SITY VV PWR FGLDZF VV QPEN

BC-D7, PRZt PWR RELIEF LINE HI TEMP

1G-F3 & W 0VTE;MP DELTA T TURB R W M & ROD

STOP

MCB meter for pTp-444 reads maximum pressure

PRZR Master Controller goes to maximum output

P E R Spray valves go full open

Actual RCS pressure as indicated by MCB for FT-445

lowering rapidly

Indications:

-

PoRv 1455c QPnS

-

rakes actions IAW Am BC-A$ (Note: actions taken for any other

ARP will delay actions necessary to avoid a Rx Trip OH SI).

-

Place Master Controller in MANUAL. and lower output.

Verify closed or close 1-RC-PCV-1455C.

Verify closed or close PWZR spray valves.

Directs RO to control pressure U W 1-AP-3 1 .OO. Should note that

6-WC-PCV-1455C is inoperable while control is in manual. SRO

hould review TS 3.1.6. (TS 3.1.6.3 states that with ti PORV

noperable but capable of being manually cycled, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

ither restore to operable or close the block valve and maintain

lower to the block valve.)

Appendix D

Required Operator Actions

Form ES-D-2

@-Test NO.: 2004-301

Scenario No.: 1

pa@? 6 of 14

Position

a0

Applicants Actions QP Behavior

Maintains RCS pressure JAW 1-AP-31.00

Check RCS pressure lowering

Place I-CH-PC-1444J in MANUN-.

Decrease demand on PRZR Press Master Controller to raise

Close or verify closed PmR PORvs

Close Block Valve to isolate a PORV that will not close.

Turn QB] pressurizer heaters.

Close or verify closed 1-CH-HCV-1311,

Aux Spray

Isolation.

Check Aux Spray Line for leakage. (None should be

detected.)

Place spray valve controllers in MANUAL and adjust

demand to zero.

acs pressure.

Zheck Turbine load stable.

Provide notifications to OMOC, STA, and Shift Supervis~r.

Appendix D

Required Operator Actions

Fom E§-D-2

Qp-Test NO.: 2004-301

Scenario KO.: 1

h@?

9 of 14

EventNo.: 6

Event Description: IC Steam Generator tube le& with failure of Condenser Air Ejector

Rad Monitor auto actions. slowly ramp leak until Condenser Air Ejector Monitor

alarms.

Position

SRU

Applicant's Actions or Behavior

Diagnose IC Steam Generator Tube Leak as evidenced by

Condenser Air Ejector alarm.

A l m s :

-

16-BB, P

m

LO PRESS

~

1@-D8, PWZR LU LEVEL

~

1-RM-GS, C0NH)ENSER Aw EJECTOR

'UER'PIFAEURE

Indications:

-

Upscale om 1-SV-N-111

-

Upscale on 1-RM-RR- 15QB Pen 4

Verifies alarm reading greater than background or radiation level

has trended up by reading 1-SV-IPI-111 or 1-RM-RR-150B Pen 4.

Checks EWCS points using Group 80 Review:

-

RlRM204C, MS-RI-124

-

W1M205C, MS-WI-125

-

W1Rh1[206C9

MS-WZ-126

Monitor SG BIowdown Monitors:

-

I-SS-RI-112

-

I-SS-w-183

Directs verification of automatic actions associated with Condenser

Air Ejector a l m .

AP-16.00, Excessive WCS Leakage

Directs compensatory actions or physical positioning of TV-SV-

102 and TV-SV-103 per ARP I-WM-GE: Attachment 1.

Reposition TV-SV-102 and TV-SV-103 per ARP 1-RM-G8

4tFachrnent 1.

____~

-

Appendix D

Required Operator Actions

Form ES-D-2

Op-Test No.: 2004-301

Scenario No.: 1

Page 8 of 14

Position

Applicant% Actions or Behavior

Checks RCS ledate.

PRZW level lowering (slight)

Annunciator IlDB5, CHG PP TO REGEN FIX HI-LQ m

W

A discemable negative change in VCT level trend has developed.

Note: At this point, these indications will be inconclusive due to

small magnitude of leak.

Directs the following:

Performance of Q-BSP-RC-002, Steam Generator Primary

to Secondary Leakage Monitoring.

Performance of 1-OPT-RC-10.0, Reactor Coolant Leakage

- Computer Calculated.

AP-16.00 Step 3: Verify closed or close normal and excess

letdown isolations:

~

1-CH-LCV-146OA

1 -CH-LCV- 146QB

-

1-RC-HCV-1 S57A

-

1-RC-WCV-I 557B

-

1 -WC-HCV- 1557c

-

1-RH-HCV-1142

AP-16.00 Step 4: Verify PRZR level, PRZR pressure, and

RCS subcooling stable or rising. (Ideally they will be stable

or rising, but if they are not applicants may choose FQ

manually trip reactor and proceed to E-Q at this point).

AP-16.00 Step 3: Verify adequate makeup being supplied

by blender and Leak Rate > 50 gpm. (VCT level will be

going down and Leak Rate will be > 50 gpm. This is

another criteria for Rx Trip).

AH-16.00 Step 7: Align Charging Pump Suction to the

RWST:

-

Open 1-CHI-MOV-1 I15B

-

Open 1 -6H-MOV- 1 1 15D

-

Close I-CH-MOV-1115C

Close I-CW-MOV-H 11%

Manual Reactor Trip. Proceed to E-0.

_

~

Appendix D

Required Operator Actions

Fom ES-D-2

Op-Test XO.: 2004-301

Scenario No.: 1

Page 9 of 14

Event No.: 7 & 8

Event Description: BC Steam Generator tube rupture coincident with Loss of Offsite

Power. #1 EDG fails to auto start, requiring manual start from the Cont~~ol

Room.

Pssitior

AH

AB1

Applicant% Actions or Behavior

Diagnose requirements to trip Reactor. (Also see the previous

event, which will lead into this Event.)

A l m s :

-

1H-A7, STM GEN IC I

LVL

1C-B8, PRZR LO PIPESS

-

lC-D8, Pam LO LEVEL

-

1D-E5, CHG PP TO REGEN HX HI-LO FLOW

Indications (Pre-trip):

-

- Tavgstable

-

Charging line flow rising

-

PRZR pressure and level lowering

Lowefing feed flow to 1A SG

Rx trips on QTDT or ]Low PRZR Pressure

Rx trip and bypass breakers open

Rod bottom lights ape lit

Generator trip 30 seconds after Rx trip

HP & LB Heater Drain Pumps trip

Safety Injection on &ow PKiX pressure

Indications (POSt-trip):

-

- Turbine trip by RX Trip

-

Phase 1 isolation

-

AH1 rn pumps S t a t

Diagnose Loss of Offsite Power. This malfunction should he

triggered by Reactor Trip.

Alms:

~

-

1K-H4,4 KV Ei"vERG BUS TIE STUB BUS BKR T R P

1K-G6,4 KV RES BUS S U P BKR OPEN

1K-E7, CC PPS DBCH HDR LO PRESS

0-VSP-A3, DIESEL FzEgE PUMP AUTO START

ndications:

-

Breakers lSA1,15B1, 3SC31,15D1, 15E1, 15F1,15A2,

15B2, and 1.322 all open.

EDG 3 auto starts and energizes the emergency bus.

Emergency stub bus breakers open

AI1 station service loads are de-energized

-

RCPstrip

Appendix B

Required Operator Actions

Bp-Test NO.: 2004-301

Scenario No.: 1

Position

SRB

Applicants Actions OF Behavior

-

CCPumpstrip

Verify Reactor Trip (E-0, Step 1 - Immediate Action Step)

-

Manually trip Reactor

-

Check neutron flux lowering

Check all rod bottom lights lit

Check Reactor Trip and Bypass Breakers open

Verify Turbine Trip (E-& Step 2 - Immediate Action Step)

-

Manually trip Turbine

-

Verify all Turbine Stop Valves closed

Close MSR Steam Supply 1-MS-SOV-104

Verify Generator Output Breaker Open (30 see time

delay)

Verify both Emergency AC Buses energized (E-Q, Step 3 -

hmeciiate Action Step)

EBG #I &id not auto start. EDG must be manually started from

the Control Room. SRO should direct 1-M-10.07, Loss of Unit I

Power, to restore power to the AC Emergency Bus.

Verify both 4160 V Emergency Buses energized. (1-AP-10.07,

Step 2) - H Bus will not be energized. RNO directs operators to

Att. 1.

[f any EDG has failed to start, then: (I-A?-10.07, Att. E, Step 2)

- Put ED6 #1 in EXERCISE

Place EDG #1 in AUTO

If ED6 loads, then go to Step 6

-

St&tDG#1

-

f either Emergency Bus energizes and both of the fd8owm.g

iarnpers are not open, then initiate Att. 10: (1-AP-10.07, Step 6)

-

I-VS-MOD-103B

-

B-VS-MOD-103D

4tt. 10 centins instructions for battery room ventilation. Local

.ctions to open slide dampers, Battery Room 1A door, and

stabhh a fire watch.

Leturn to procedure step in effect. (1-M-10.07, Att. I, Step 8)

heck if SI initiated. (E-0, Step 4 - bmediate Action Step)

-

~~~~

Appendix D

Required Operator Actions

Form ES-D-2

@-Test No.. 2004301

Scenario No.: 1

Page 11 of 14

rime

Position

RQ/BOP

a0

d

Applicamt's Actions 01-

Behavior

Directs manual initiation of SI after Reactor Trip. Expect SRO

brief.

Manually initiates SI and verifies 1A-F3 and 1A-W annunciators

lit. (E-Q,

Step 4 - Immediate Action Step)

Verify Peedwater isolation. (E-0, Step 5)

-

MFW Bumps tripped

- Feed Reg Valves closed

-

SG Blowdown TVs closed

Feed Pump Discharge MOVs closed (l-FW-MOV-1SOA

6% B)

SG F W bypass Wow demand at z e r ~

Verify CTMT Isolation Phase I. (E-0, Step 6)

-

Phase I TVs closed

-

1-CH-MOV-1381 closed

-

l-SV-TV-102A closed

-

PAM isolation l-DA-TV-183A closed

- PAM isolation 1-DA-TV-103B closed

Verify AFW pumps running. (E-Q, Step 7)

-

MD A@w Pumps (time delayed)

"El AFW Pump (if necessary)

May discuss isolating AI;'w to IC SG with SRO at this time.

Verify SI Pumps running. (E-0, Step 8)

-

CHG Pumps running

-

LIISI Pumps running

heck Charging Pump Auxiliaries. (50,

Step 9)

-

CHG Pump CC Pump

-

CHG Pump SW Pump

Sheck Intake Canal level > 24 feet and being maintained. (E-0,

,tep 10)

heck Main Steam Line Isolation required. @-(I,

Step B I)

-

Check if any of the following annunciators have been lit.

~

E-F-10, HI STEAM FLOW SI - (should he off)

B-C-5, Hi HI CLS TWAIN B - (should he off)

-

B-C-4, HI HI CLS TRAIN A - (should be off)

-

lheck if CTMT Spray required (E-0, Step 12)

Appendix B

Required Operator Actions

Form ES-D-2

Bp-Test No.: 2004-301

Ssenario No.: 1

Page 12 of 14

Applicant's Actions or Behavior

(CTW Pressure should be near pre-event levels - RNO directs

operators to Step 13)

Verify SI flow: (E-0, Step 13)

- "SI

to Cold Legs > 0 pm:

-

I -SI-F?-1961

-

1 -SI-R-1962

-

1 -SI-R-1963

-

I -SI-R-1943 or 19434

Check three CHG Bumps running

Stop one CHG Pump and place in AUTO

Check RCS pressure > 185 psig (should be > 185 psi@

Stop one LHSI Pump and place in AUTO

Verify total AFW flow > 358 gpm (E-0, Step 14)

-

- Reset SI

-

- Verify SI reset

-

Check AFW MOVs open (IC SG may require manual alignment)

(E-0, Step 15)

Verify SI Valve Alignment IAW Att. 2 (BO, Step 14)

- Verify open or open CWG Pump Suction from RWST

MOVs

-

1-CH-MOV-1115B

-

I-CH-MOV-1115D

Verify closed or close CHG Pump Suction from VCT

MOVs

-

1-CH-MOV-1 I15C

-

l-CH-MOV-1115E

Verify closed or close CHG Line Isolation MOVs

-

I-CH-MOV- 12898

-

I-CH-MOV-1289B

Verify closed or close Letdown orifice isolation valves

-

I-CH-HCV- 12008

-

l-CH-HCV-120B

-

I -CH-HCV- 1 200C

Verify open or open HHSI to cold legs MOVs

-

I-SI-MOV-1867C

-

1-SI-MOV-1867D

Verify open or open LHSI suction from WWST MOVs

-

I-SI-MOV-I 8628

-

1-SI-MOV-B 862B

Verify open or open LHSI to cold legs MOVs

-

Appendix D

Required Operator Actions

Form ES-B-2

Op-Test NO.: 2004-301

Scenario No.: 1

Page 13 of 14

Time

Applicant's Actions or Behavior

I-SI-MBV-I 8698

I -SI-MBV- 18443

Verify ventilation alignment and AC power alignment MaW

Attachment 3 (E-0, Step 17) (E-0, An. 3 is attached)

(Only one switch to be manipulated on the Ventilation Panel)

Check RCS Avg Temp stable OH trending toward 547 9.

(E-0,

Step 18)

If e 547 'P, then stop dumping steam and reduce MW flow if SS

Levels permit (SG Levels > 12% in at least one SG). If cooldown

continues, then close MSTVs.

If > 547 OF, then dump stem via Atmospherics (LOSP -

condenser not available)

Check PFZR PQWVs and Spray Valves: (E-0, Step 19)

-

PRZR PORVs closed

-

PWZR Spray controls at zero demand (Spray valves

closed)

At least one PORV Block Valve open.

-

Check RCP Trip and Miniflow Recirc Criteria (E-0, Step 20)

- HHSI flow to Cold Legs > 0 g~ppn

-

RCS Subcooling < 30 F

WCS pressure < 1275 psig

If RCS Pressure < 1275 psig then close CHG Pump miniflow

recirc valves (1-CM-MOV-1275A Cpr B & C)

Check SG Not Faulted: @-Q Step 21)

Pressure in all SGs stable or rising

Pressure in all SGs > 100 psig

-

Check SG Tubes ruptured: [E-0, Step 22)

-

Condenser air ejector radiation > normai

SG Blowdown Radiation > normal

SG MS Radiation > normal

TD AFW Pinnap exhaust > normal

lA SG level increasing in an uncontrolled manner

Directs transition to E-3, Steam Generator Tube Rupture. (E-0,

Step 22)

Check RCP Trip and Miniflow Recirc Criteria (E-3, Step I)

- "SI flbw to Cold kegs > 0 gpm

Appendix D

Required Operator Actions

Op-Test NO.: 2004-301

Scenario No.: 1

Form ES-B-2

Page 14 of 14

If RCS Pressure < 1245 psig then close CHG Pump miniflow

recirc valves (1-CH-MOV-1275A 8r B B C)

-

Level rise

-

SG Blowdown monitor high

SC Main Steam Line Monitor high

Isolate IC SG (E-3, Step 3 - Critical Task)

Adjust 16: SG POWV controller to 1035 p i g

Verify 1C SG PORV closed

Verify IC! SG Blowdown TVs closed

Directs local closure of 1-MS-158 (161 supply to TD AFN

Pump)

-

Close IC SG MSTV

Isolation of 1C SG prior to exsting E-3 is a critical task.

Check ruptured SG Level > 12% (E-3, Step 4)

Flow to 116 SG must be maintained until level > 12%.

When level > I%%, AFW flow to IC S B shall be stopped.

Zheck P%RZ PORVs and Block Valves (E-3, Step 5)

Check power available to Block Valves

Check PRZR PORVs closed

Ensure at least one P E R PORV Block Valve open

-

heck if SG not faulted. @-39 Step 6)

Check pressure stable or rising in all SGs

Check pressure > BO psig in all 30s

-

heck IA B 1B (intact) SG levels (E-3, Step 7)

-

Any AR SG Level >12%

Check emergency buses both energized (RNO should p 1 ~ 1

need to be. performed if bus was restored by manually

starting #I EDG earlier in scenario. However, local

isolation of AFW header on H Bus may be necessary if H

Bus not energized. 1-Ew-141/ 156 / 171)

Control AFW flow to maintain 22 to 50% in I A 63c 1B

SGs

-

beset both trains of SI (E-3. Steo 8)

Appendix D

Required Operator Actions

Form ES-B-2

Op-Tesli NO.: 2084-301

Scenario No.: 1

Page 15 of 15

BQPIRO

SRQ

Appiicants Actions OF Behavior

Verify Instrument Air Available (E-3, Step 10)

-

Verify 1-IA-TV-108 open.

Check Annunciator WE6 not lit.

Check at Least one CThlT Instrument Air Compressor

running.

Align Condenser Air Ejector to CT,W (E-3- Step 11)

-

Verify 1-SV-TV-182 open

-

Verify 1-SV-TV-103 closed

-

Open 1-SV-TV-102A

Verify all AC buses energized by offsite power. (This will not be

the case. EDGs will be powering buses). @-3> Step 12)

3irect implementation of 1-AP-10.07. Loss of Unit 1 Power (if

lot already implemented). (E-3, step 12)

heck if LHSI Pumps should be stopped. (E-3, Step 13)

-

Check RCS pressure > 250 psig

Stop LHSI Pumps and piace in AUTO.

heck IC SG isolated from 1B and la SGs @-3, Step 14)

-

Check 1@ SO MSTV or NRV closed.

Check 1C SG pressure > 358 psig.

nitiate RGS Cooldown (E-3. Step 15)

-

Determine required core exit temperature (SW TIME):

-

Lowest Ruptured SG P Qpsig)

GET (OF)

1001 - 1085

495

901 - 1008

485

~

801 - 900

470

-

701 - 800

455

601 - 700

440

-

501 - 608

420

401 - 500

400

~

350 - 400

385

Place Steam Dump Mode Select Switch in Steam Pressure

Mode.

C O ~ ~ ~ O W R

at maximum rate using SG PORVs.

Check CETs Iess than required temperature

Maintain CETs less than required temperature

-

Stop COOldow~

-

Appendix B

Required Opemtor Actions

Form ES-D-2

Op-Test No.: 2004-381

Scenario No.: B

Page 16 of 16

'ime

ritiC&l

]Ea0

Applicant's actions or Behavior

This step should be completed prior to depressurizing.

Check ruptured SC pressure stable or rising (E-3, Step 14)

Check RcS subcooling based on CETs > 50 F

Depressurize RCS to minimize break flow and refill PRZR (E-3

Step 18)

-

Check nomd spray available and WCPs A & C running

(normal sprays will not be available and RCPs will be off)

- RNO directs to Step 19

Depressurize RCS using PRZR PORV to minimize break flow

and refiSl PRZR (53, Step 19 - Critical Task)

-

~

Check at least one PRZR PORV available

Open one PRZR PORV until any of the foliowing

conditions edst:

-

P U R Level > 49%

RCS Subcooling based on CETs < 30 "F

PWZR Level > 22% & RCS P < 1c SG P

~

. . .-

. . . . -. . . . . . -

SCENARIO CQh.TPI,ETE ONCE RCS IS TSEPRESSIIRLZED.

. . . -.

. . -.

. . . __

Appendix D

Scenario Outline

Fa rrn , ES-D- 1

e

Facility: Surry

Examiners:

Operators:

&gTAMbbiCb

2.. he3

Initial Conditions:

d A 3 L B as+- cce&cd/p 7-3

50% Reactor Power

Known leakage in 1A Steam Generator

Thunderstorms are approaching from the West

1-EH-P-MP2 (EHC Pump) is Tagged Out of Service for Thermal O ~ e r l ~ a d

Replacement

1 - 1.S h-3

TUtT?QVer:

Shift orders are to maintain power at 50%.

Description

MW

f 4 S - t

p.,

actuate. Manuai actuation from the control room is

Required Operator Actions

Scenario No.: 2

Form ES-D-2

Page 1 of 16

Appendix H)

Op-Test NO.: 2004-301

EventNo.: 1

Event Description: Bearing Cooling Water Pump trips and standby pump fails to auto

start.

I

f

Applicants Actions or Behavior

Acknowledges 1B-G2,

BC HElR LO Pressure.

Acknowledges 1K-D2,4KV BKR AUTO TRUP.

Identifies loss of I-BC-P-1B and failure of I-BC-P-IA to automatically start

on low system pressure.

Manually starts 1-BC-P-la.

Verifies running amps on 1-BC-P-IA and BC system low pressure alarm

clears.

Performs focus brief on the failure and actions in progress.

Directs BOP to dispatch Service BLDG operator to 1-BC-P-TBs breaker

1568.

Directs RO to dispatch Turbine BLDG operator to locally investigate

conditions at BC pumps.

Place control switch for 1-BC-P-1B in PTL position

Direct Electrical Maintenance to investigate breaker 15C8.

Notifies Shift Manager and direct initiation of Work Order.

Required Operator Actions

Scenario No.: 2

Appendix D

Op-Test NO.: 2004-301

Event No.: 2

Event Description: Letdown Divert Valve fails open

Form ES-D-2

Page 2 of 16

Applicants Actions or Behavior

Identifies normal make-up in progress to VCT.

~~

Identifies 1-CH-LCV-1115A diverted to PDT.

Identifies L -CH-LCV-l115A controller demand at 100% for unknown

reason

May utilize A W lD-Gl, VCT HI-LO L W for guidance based on normal

make-up flow ability to maintain VCT level.

Direct RO to place 1-CK-LCV-I B 15A controller in Manual rend reduce

demand to align 1 -@N-LCV- 1 1 15A to VCT position or place controi switch

for 1-CH-LCV-I 115A in N O M position.

Performs the directed action to align 1-CH-LCV-1 I1 514 back to VCT.

Performs a focus briefon the failure and actions in progress.

-

..... -

.....

. . . .

. . . -.

. . .-

Directs I & C: Maintenance te investigate the faiiure of 1-CI-I-1.W-11 I5A

contrsller.

Notifies Shift Manager and STA of failure and actions in progress.

Required Operator Actions

Scenario No.: 2

Appendix D

Op-Test No.: 2004-301

Event No.: 3

Event Description: Selected 1' Stage Turbine Pressure Transmitter fails low

I

SRQ

Applicant's Actions or Behavior

Acknowiedges annunciator 1 H-A4, Tavg > < T r d DEVIATION.

-. .-.

.

. .__

. ._ .

. __ . -.

. . . .- . . -

._ . . .-

Acknow!edges annunciator I H-H?, S l M I N J 3 W T W OPEN

Identifies control rods are stepping due to

Channel 3 Transmitter failure low.

Stage Turbine Pressure

Directs RO to place control rods in Manual.

Piaces control rods in Manual to stop the rod motion.

Identifies Main FRVs are reducing SG levels to the no load setpoint based

on Channel 3 failure.

Reviews annunciator response procedures for remaining of alarms

Reviews Tech Specs Section 3 7 and identifies TS Table 3 7-1 items 20 b 6t

20c requiring Operator Action #13, one-hour clock to verify permissives

status In addition, identifies TS Table 3 7-2 item le and TS Table 3 4-3

item 2a requiring Operator .4ctiOn #20, 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months dock to place channel in

trip

Performs focus brief on failure and actions in progress Discuss plant

impact with Stm Dump trip open signal and Main FRVs due to falure

Notifies I & C Maintenance to place channel in trip.

Directs RQ to perform I-QPT-KP-O0I, CHECK OF IT3%h4ISSIVE

STATUS LIGHTS P-6, P-'3, P-8, AND P-10, to verify permissive status

lights are correctly illuminated.

Pedorms 1-QPT-RP-O0I, CHECK OF PERMISSIVE. STATUS LIGHTS P-

6, P-7, P-8, AND P-10 and reports results of completed OPT to SRO.

Appendix D

Required Operator Actions

Form ES-D-2

Op-Test NO.: 2004301

Scenario KO,: 2

Page 4 of 16

Event No.: 3

Event Description: Selected 1' Stage Turbine Pressure Transmitter fails low

I

Applicant's Actions or Behavior

Directs BOP to swap instrumentation channels in accordance with perform

OF CN.4".

I, II,IlI, AND IV PROCESS AND PROTECTION

TESTING.

Performs 1 -0P-a-00 1 to swap instrumentation channels. Should note that

this procedure ndi not be completed before proceeding to next event

I -0P-RP-001, ALIGNING CONTROL SYSTEM FOR PEwFORhgANCE

~

Notifies Shift Manager and ST.4 of failure and actions in progress.

Appendix D

Required Operator Actions

Form ES-B-2

Op-Test NQ.: 2004-301

Scenario No.: 2

Page 5 of 16

Event N o . : H b

Event Description: Selected 1B Steam Generator Steam Flow Transmitter fails high

Identifies B SG Steam Flow channel failed high (1-MS-LT-lXXX).

Direst BOP to place B Main FRV in Mamual and restore B SG level.

Takes manual control of B Main FRV and reduces feedwater flow to

restore Ievel.

Reviews AM%.

Performs focus brief on failure and actions in progress.

Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 17

requiring Operator Action #6; identifies TS Table 3.7-2 item le and TS

Table 3.7-3 item 2a requiring Operator Action #20, 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months clock to place

channel in trip.

Notifies I & C Maintenance to place channel in trip

May elect to swap controlling Steam Plow channel to IV for B SG in

accordance with 1H-%, STM GEN IB LVL ERROR

- Return Ievel to program

-

Select redundant channel

- When level returned to normal, then place FRV in AUTO.

Notifies Shift Manager and STA of failure and actions in progress.

Required Operator Actions

Scenario No.: 2

Appendix 19

Bp-Te~t NO.: 2004-301

Event No.: 5

Event Description: Pressurizer Level Controller fails low

Form ES-D-2

Page 6 of 16

0 f d e ~

/A/$%aY&b

Applicants Actions or Behavior

Acknowledges annuciator lC-BS, PWR LO LVL.

Identifies CHG flow reduction.

Identifies CMG flow controller output demand at 0%.

Directs RO to take manual control of CHG flow and return CHG flow to

normal.

Takes CWG flow controller tu MWAk amd increases CEIG flow to

normal.

Notifies IRrC Maintenanw to investigate the failure.

Perform foms brief on failure and actions in progress.

Notifies Shift Manager and STA of failure and actions in progress.

Appendix D

Op-Test No.: 2004-301

Event No.: 6

Required Operator Actions

Scenario NQ.: 2

FOITTI

Page 7 of 16

Event Description: Tavg Taylor Math Unit fails low

Appendix D

Op-Test No.: 2004-301

Event No.: 7

Event Description: Turbine Governor Valve fails closed. Ramp in slow enough for

BOP to detect and respond.

Time

Required Operator Actions

Scenario No.: 2

FOP^ ES-B-2

Page 8 of 16

I

Appendix D

Required Operator Actions

F

o

~

Qp-Test No.: 2004-301

Scenario No.: 2

Page 9 of 16

Event No.: 8, 9, Br 10

Event Description: LBLOCA - Auto Reactor Trip, Turbine fails to trip, and both trains

of Safety Injection fail to automatically actuate. Manual actuation from the control room

is

&&N 0 u r p o r &L&

dL .p Ot-4

Time

RO/SRO

RQ/SRO

(Event 9)

ROISRB

RO/SRQ

Event 10)

AppBicsnts Actions or Behavior

Acknowledges annunicators.

Identifies decreasing RCS Pressure

Identifies automatic Reactor Trip and initiates 1-E-0 Immediate Actions.

Directs performance of 143-0 Immediate Actions.

Acknowledges annunciators while RO performs I-E-0 Immediate Actions.

Verifies Reactor Trip (EO> Step 1 - Immediate Action Step)

-

Manually trip Reactor

-

Check Neutron flux lowering

Check ail Rods On Bottom Light lit

Check Reactor Trip and Bypass Breakers open

Verify Turbine Trip (E-0, Step 2 - Immediate Action Step)

-

Identify that Turbine failed to automatically trip

Manually trip the turbine by pressing both Trip Pushbuttons

Identify all Turbine Stup Valves dose

Close MSR Steam Supply 1-MS-SOV-I04

Verify Generator Output Breaker open (39 second time delay)

Verify both Emergency A@ Buses energized (E-0, Step 3 - Immediate

Action Step)

Check if SI is actuated. (E-0, Step 4 - Immediate Action Step)

Identify that ST failed to automatically actuate.

e-

hlanualiy actuate both trains of SI d~~~~~~~ d e w h e 53

-

Verify LHSI pumps running

- Verify SI annunciators lit

-

A-F-3

-

A-F-4

Appendix 6)

Required Operator Actions

Bp-Test No.: 2004301

Scenario No.: 2

Form ES-D-2

Page 10 of 16

AipBicants Actions or Behavior

Verify FW Isolation. @-a, Step 5)

-

MFW pumps tripped

- Peed Reg valves closed

-

Phase I TVs closed

Feed pump discharge MQVs closed (l-PW-MBV-lSOA & B)

SG FW bypass flow demand at zero

Verify CTMT Isolation Phase T (E-0, Step 6)

-

1-CH-MQV-1381 closed

-

I-SV-TV-102A OS&

-

PAM Isolation vaives 1-BA-TV-103A closed

PAM Isolation valves I-DA-TV-IO3A closed

Verify AFW pumps Running (EO, Step 7 )

-

MD AFW Pumps running (time delayed)

TD AFW Pump running (time delayed)

Verify SI Pumps Running (E-0, Step 8)

-

CHG Pumps running

- LHSH Pumps running

Verify CHG Pump Auxiliaries (E-0, Step 9)

CHG Pump CG Pump running

CHG Pump SW Pump running

-

Check Intake Canal. (E-07 Step 10)

-

Leve1.24FT

- Levef being maintained by CW Pumps

heck if Main Stearnlines should be isolated (,E-(& Step I I)

Check if any ofthe following annunciabars have been lit

-

E-F-10, HI S T E M FLOW SI - (should be of%)

-

B-@-4, HI HI CLS TRAIN A - (should be on)

-

B-C-5, HI M CLS T W N B - (should be on)

Check either ofthe following actuated

-

Verify RWST crosstie valves open

-

1-SI-TV-102A & B open

-

2-SE-TV-262A & B open

Check RCS pressure < 185 PSIG - (should be yes)

-

Check MSTVs closed

-

Hi Steam flow SI - (should be no)

Header to line SI - (should be yes)

-

Appendix D

Required Operator Actions

Qp-Test NO.: 2004-301

Scenario No.: 2

F

o

~

ES-B-2

Page 11 of 16

Applicants Actions OF Behavior

Check if CTMT Spray Required. (E-0, Step 12)

-

TripallRCPs

-

Verify 63s pumps running

-

CTMT pressure has exceeded 23 &a

Manually initiate Hi Hi CLS

Check HSRS pumps running (Time Delayed)

Check OSRS pumps running (Time Delayed)

Initiate Attachment I, CLS Component Verification

Low PRZR pressure SI signal should be blocked when P M K pressure

decreases < 2000 psig

-

Blocks Low P U R pressure SI signal by using bIsck switches

High steam flow SI signal should be blocked when Taw decreases <

543°F

-

Bl~cks High steam flow SI signal by using the block switches

CHG pumps should be mn in the following order of priority: CI

B, A

Verify SI Flow. (E-0, Step 13)

-

HHSI to cold legs flow indicated

-

1 -SI-FI- 196 1

-

1-SI-FI-1962

-

1 -SH-FH- 1963

-

1 -SI-BP- 1943 or I943 A

Check three CHG Pumps running

Stop one GHG Pump and place in AUTO

Check WCS pressure

-

Reset SI

-

Identie LHSI flow indicated.

185 psig (should be < 185 psig)

Verify Total AFW flow

Check AFW MOVs open. (E-0, Step 15)

350 gpm [450 gpm]. (E-0, Step 14)

Veri@ SI Valve Alignment IAW Att. 2 (E-Q,

Seep 16)

-

Verify open GHG Pumps Suction from RWST MBVs

-

l-CM-MQV-1115B

1 -CH-MBV- 1 I 1 5D

Verify closed CHG Pump Suction from VCT MOVs

1 -CH-MOV- I I 156

1 -CH-MOV- 1 1 15E

-

Verify closed CHG Line Isolation MQVs

-

1 -@H-MOV- l289A

-

1 -@H-MOV- 1289B

Appendix B

Required Operator Actions

Form E§-D-2

Scenario No.: 2

Page 12 of 16

Position

RO/SWC

Unit 2

OPR

RO/SRQ

ROiSRQ

Appk?ant's Actions or ]Behavior

Verify SI Valve alignment IAW Att. 2. (50, Step 14) CQNTINLED

- Verify open HHSI to cold legs h/lBVs

-

l-SI-MBV-1867C

-

I-Si-MQV-I867D

Verify open LHST suction from RWST MOVs

-

I-SI-MOV-1862A

-

I-SB-MQV-1862B

-

Verify open LHSI to cold legs MaVs

-

1-SZ-MOV-1864A

-

I-SI-MMBV-1864B

Verify ventilation alignment and AC power alignment IAW Attachment 3

(E-0, Step 17) @-Q Att. 3 is attached)

(Qnly one switch to be manipulated on the Ventilation Panel)

Check RCS Avg Temp stable or trending towards 547'F. (E-0, Step 18)

- Identify

547'F

- Identifgr not dumping steam and control total feed flow. Maintain >

450 gpm [450 gpm] until NW IeveE > 12% [18%1] in at least one SG.

-

Identify MSTVs closed

Check PRZR PORVs and Spray Valves: (E-0, Step 19)

- PRZR PORVs closed

-

P U R Spray controls at zero demand (Spray valves closed)

At Ieast One PORV Block Valve open

heck RCP Trip and Miniflow Recirc Criteria. (E-0, Step 20)

HHSI flow to Cold legs indicated

RCS Subcooling e 3 0 T [85"F]

Stop ail RCPs

Identify RCS pressure

1275psig [I475 psiel

Close CHG Pump miniflow recirc valves (l-CH-MOV-l275A, W, Br C)

heck SG Not Faulted. @-Q> Step 2 1)

Pressures in all SGs stable for plant conditions

Pressures in all SGs

100 pig

heck SG Tube ruptured. (E-0, Step 22)

Condenser air ejector radiation - normal

SG Blowdown radiation - normal

SG hlS radiation - normal

TB M W Pump exhaust - normal

Appendix D

Required Operator Actions

Op-Test No.: 2004-301

Scenario No.: 2

Position

RO/SRO

SKO

STA

BOF!SRO

Form ES-D-2

Page 13 of 16

Applicant's Actions or Behavior

Check RCS Intact Inside CTMT. @-0? Step 23)

- CTMT radiation normal

- CTMT pressure > normal

-

CTMT RS sump level > normal

Directs transition to E-l, Loss ofReactor or Secondary Coolant

Identify Red Path on CSF Status F-4 Integrity requiring transition to FR-

P. 1

Directs transition to FR-P. 1, Response to Imminent Pressurized Thermal

Shock

Check RCS Pressure > 185 psig [250 psig] (FR-P.l, Step 1)

-

Directs transition to E-1, Loss of Reactor or Secondary Coolant

Check RCP Trip and Miniflow Recirc Criteria. @-I; Step 1)

-

Identify all RCPs stopped

-

Identify RCS pressure

1275psig 61475 psig]

-

Identify RCS Pressure < 185 psig [a50 pig]

Identifsr LHSI pump flow > 1000 gpm

E T U R N $0 procedure and step in effect.

HE-ISI f

l

~

to Cold legs indicated

RCS Subcooling < 30'F [85"F]

Identify CHG Pump miniflow recirc valves (l-CH-MQV-l295A, B, B

C) closed

Check SG Not Faulted. (El, Step 2)

-

Pressures in ali S a 100 psig

Pressures in all SGs stable far plant conditions

Zheck Intact SG Levels. (E-1, Step 3)

-

NR level > 12% [I8%]

Check emergency buses both energized

Control feed flow to maintain NR level between 22% and 58%

heck SG Tube mptured. (E-1, Step 4)

-

.

Condenser air ejector radiation - normal

SG Blowdown radiation - normal

§G MS radiation - normal

Ti3 AFW Pump exhaust - normal

SG NR level not increasimg in an uncontrolled manner

Appendix D

Required Operator Actions

Op-Tst No.: 2004-301

Scenario No.: 2

Form ES-D-2

Page 14 of 16

Time

Position

ROiSRO

RO/SRQ

RQ/SRO

WO/SRO

RO/SRO

AppIicant's Actions or Behavior

If any PWR PORV opens because of high F U R pressure, the PORV

must be verified closed or isolated afkr pressure decreases to less than

2435 pig. (E-1, Caution prior to Step 5)

Cheek PRZR PORVs and Block Valves. (E- 1, Step 5)

- Power to PRZR PORV block valves available

- PKZR PORVs closed

- P U R PORV block valve at least one open

Check If SI Flow should be reduced @-I? Step 6)

- RCS Subcooling based on CETCs 30°F [85"H]

- (30 TO Step7

Check If Hi Hi CLS Initiated. (E-1, Step 4)

- Identify RS Pumps running

-

Idcnti@ Hi Hi CLS annunciators lit

Verify Service Water Available. @-I> Step 8)

-

GOT012

Check If CTMT Depressurization Equipment can be stopped. @-I9 Step

-

Close CS Discharge valves

Check Intake Canal level being maintained by CW Pumps

1 a>

CTMT pressure < 12 psia

Reset both trains of CLS

Stop OSRS Pump(s) and put in AUTQ

Stop CS Pump(s) and put in AUTO

- 1 -CS-MBV- 10 1 A

- l-@S-MOV-IOlB

- 1 -CS-MOV- 101 e

- I-CS-MOV-lO1D

- 1-cs-haoV-102A

- I -CS-MBV- I02B

Close CHEM ADD TK OUTLT valves

. Operate ISRS Pumps with SW aligned to maintain CTMT pressure

CCS Pressure should be monitored. TfRCS Pressure decreases in an

ncontrolled manner to < 250 psig [400 pig], on LHSI pump must

ianually restarted to supply water to RCS. @-I> Caution prior to Step 13)

Appendix D

Required Operator Actions

Form ES-D-2

Qp-Test NO.: 2004-301

Scenario No.: 2

Page 15 of 16

Time

___

__

Position

RBISRO

ROISRO

ROISRB

Applicants Astions or Behavior

Check IfLHSI Pumps should be stopped. (E-1, Step 13)

-

Check RCS pressure

250 psig [400 psig]

- GO TO Step 15

Check IfEBGs can be stopped. (E-1, Step 15)

-

Veri@ AC ernergency buses energized by ofissite power.

Reset both trains of SI, ifnecessary (should not be)

Stop any unloaded EDGs IAW Attachment 1, Stopping Unloaded

WO direct the Sewice BLBG operator to secure EDGs ZAW Att. 1

EDGS

-

Verify Instrument Air Available (23-1, Step 16)

-

Initiate Evaluation of Plant Status. (E- 1: Step 17)

-

Verify cold leg recirculatisn capability

- Power to LHSI Pumps available

- Power to the following SI valves avairable

Check annunciator BB-6 not lit (should not be)

Check at least one CTMT fA compressor running (should be one)

Verify both trains of CLS reset (should be reset)

Manually open 1 -1A-TV- 100

- 1-SI-MQV-1863A & 3

- 1-SI-MOV-18858 $t B

- l-SI-MOV-1885B & C

- l-SI-MBV-I860A & B

- I-SZ-MQV-I862A

& B

- I-SI-MOV-1115B & D

-

Check auxiliary building radiation - normal

- Kaman vent-vent monitors - normal

- Auxiliary Building Control area monitor -normal

- RCS

~

Consult with TSC on need ta obtain any ofthe folIowing samples

- Boron

- Activity

- CTMTSump

- Chlorides

- Boron

- Pl-H

- Activity

- m

- Activity

- CTMT Atmosphere

Required Operator Actions

Form ES-D-2

Page 16 of 16

Appendix D

Scenario Ne.: 2

Qp-Test NO.: 2004-301

- SGS

- Activity

- Sodium

- Chlorides

- Conductivity

- Boron

- PH

-

Initiate evaluation of plant equipment

- Electrical Distribution

- Safeguards

- WatedGaseous supply and storage

- Radiation Monitoring

- %cleat Instrumentation

- CVCS

- Ventillation

- Past-Accident Monitoring

- Instrument Air System

Appendix D

Scenario Outline

Form ES-D-I

f

Facility: Surry

initial Conditions:

Reactor Power is 75%

Known ieakage in 1A Steam Generator

Thunderstorms are approaching from the West

a m f P

Turnover:

Shift orders are to raise power immediately following turnover.

Description

I

(Njorrnal,

(W)eactivity, (I)nstrurnent, (C)ornponent,

Appendix D

Required Operator Actions

Qp-Tesb No.: 2004-301

Event No.: 1

S~enario No.: 3

~

Time

Form ES-D-2

Page I of21

Event De$CPiptiQn: Raise power. (Rods initially should be positioned to prompt

dilution, as opposed

Conduct brief for raising power in accordance with 1-QP-TM-005. Unit

Position

TEAM

SROIBOP

SROXO

_ _

Ramping Operations

Review I-OP-TM-OQS: Section 5.3, Preparations for Turbine Ramp Up.

- Identifies that last shift completed Section 5.3

Review 1-OP-TM-005, Section 5.4, Power Increase Between 50% and

100% Reactor Power.

- Identifies that last shift completed Section 5.4 up to step 5.4.12

-

Continue the power escalation to 90 to 91 percent power.

Commence the power increase at the ramp rat

- Recall the Shift Manager directed setting

the Load Rate

-

iced by Shift Manager

Thumbwheel.

-

w ISS-

md/Av

Using the Load Rate % per %fin thumbwheel, rotate until setting of 8

Initiate power increase by depressing the GO pushbutton

is displayed.

-

Initiate dilution and use control rods as required to maintain A B in band.

- Observe the expected response on

- FR- 1 - 1 13, BA-PRO WTR Fhw

- d86-114A, PWI WTR SUP BATCH Integrator

-

Identi@ that b 0 is high in the band, SO dilution would be preferred prior to

outward rod motion.

[nitiate dilution

Appendix D

Bg-Test No.: 2004-301

Required Operator Actions

Scenario No.: 3

Event No.: 2

Event Description: FT-CH-1114,

Primary Water Flow XMTR fails low

AppBicants Actions

Behavior

Identifies normal dilution to VCT stops and investigates why no PG flow

indicated.

Acknowledges annunciator 1D-A4,

Directs BOP to stop the ramp to stabilize plant conditions based on the

fai lure.

Stop the turbine ramp by depressing the HOLD pushbutton.

Reviews annunciator alarm response 1D-A4.

Reset the blendes controls back to AUTO.

Performs a focus brief

the failure and actions in progress

Directs I & C Maintenance to investigate the failure.

Notifies Shifi Manager and STA of failure and actions in progress.

Appendix D

Required Operator Actions

Scenario KO.: 3

F O H ~

Page 3 of21

Event No.: 3

Event Description: I-CN-P-l A, Condensate Pump Performance Degradation ramped in

to require timely operator response. Failure of standby pump auto stant. Manual start

required

J

Required Operator Actions

Scenario No.: 3

Form ES-D-2

Page 4 of21

Appendix D

Op-Test No.: 2004-301

Event No.: 4

Event Description: Selected 1.4 Steam Generator MFW Flow Transmitter fails low

- Return level to program

- Select redundant channel

hifi Manager and STA of failure and actions in progress

Appendix D

Bp-Test No.: 2604301

Required Operator Actions

Scenario No.: 3

Event No.: 5

Event Description: 1A SG PORV Controller fails high

Form E§-D-2

Page 5 of 21

Appendix D

Required Operator Actions

OB-Test No.: 2004-301

Scenario No.: 3

Event No.: 6

Event Description: IsaIable letdown line leak in containment

Form ES-D-2

Page 6 OF 21

Applicant's Actions QP Behavior

Acknowledges annunciator 1B-A3, CTMT SURP HI LEVEL

~

Identifies increasing CYhtT Sump level with CTMT Sump pump running

in auto.

Acknowtedges annunciator 1D-A4, PRI WTR TO BLEND DEVIATION

FLOW

Implements AP-16.Q0,

EXCESSIVE RCS LEAKAGE.

~~~

Identifies LTDW flow at zero

If SI Accumulators are isolated I-@- 16 0 1, SHUTDOWN LOCA should

be used or guidance RCS average temperature has a direct impact on

pressurizer level (APB6 00, Notes prior to Step 1)

Increase CWG flow using I-CH-FCV-1122 in manual to maintain P U R

level at program setpoint, as necessary (AP-16 00, Step 1)

- Identifies PWR level at setpoint

Check RGS leak rate (AI?-16 00, Step 2)

- PRZR !eve$ decreasing (should not be)

- Annunciator D-3-5 lit (should not be)

- Go TO Step 12

Check a@%

leak rate < 10 gpm (AP-16 80, Step 12)

-

- Evaluate EPP applicability

Check Unit Conditions stable (-4P-16

00, Step 13)

- P U R level (should be)

- PRZR pressure (should be)

-

Taw (should be)

Check Letdown Ieak indicated (AP-16 00. Step 14)

-

Initiate unit shutdown IAW W P

Control CHG flow and seal injection to maintain P U R level

Identifies annunciator lB-M, CTMT Sump Hi Lvl lit

Appendix D

Required Operator Actions

Form ES-D-2

Bp-Test No.: 2004-301

Scenario No.: 3

Page 7 of 21

-

1 -CM-LCV- 1 4 6 0 ~

-

I-RC-HCV-l557A, 14, & c

-

1 -M-HCV- 1 142

Perform focus briefon failure and actions in progress.

Chec.k RCS leak rate with letdown secured reduced. (AP-16.00, Step 16)

- Identifies letdown leak st0ppe.d following securing letdown isolations

Place intact Letdown System in service IAW Shift Supervisor direction.

ce Excess letdown IAW 1-OP-CH-886

eviews precautions and limitations

erify all of the following Loop Drain header isolation valves are

I-RC-HCV-1557A7 B, SZ C (should be)

H-HPCV- 120 1, Excess LDTN HX ISOL valve is

dosed Iqhould be)

- Verify 1- H-HK-1137, Excess LDTN Flow setpoint is zero

- Verify 1-Cd\\FCV-i389,

Excess LDTN Divert is in the VCT

- Verify open 1 -C@-MO\\r- 13 8 1

~ RPCP Seal Return (should be)

- Verify running at'lqast one cc ~ u m p

(should be)

- Verify FI-CC-109; b T N HX Outlet Flow is indicating =: 140

- Notes the reset switch lbcated on the RFW flats must be held in

- Verify TI-CC-108, LDTNNX Outlet temp is indicating ambient.

- Veri5 1-CH-FZ-I 138, Excess CQT" FIX Outlet pressure is

indicating Z= 50 pisg (should be) '~,\\

- Verify 1-CH-TI-I 139, Excess L D h HX Outlet temp is

indicating ambient. (should be)

"\\

- Notes the first 50 gallons of Excess LDW flow should be

directed to the PDTT so that the Excess kDTN flow is not

(should be

!

h

(should be) \\.,

gpm (should be)

'\\,\\

the open position until I-~C-HCV-IOS

opens h11y.

(should be)

'\\ '\\

returned to the RCS.

\\

- Places 1-CH-HCV-I389 Excess LDTN Divertualve to the PDTT

position to flush the Excess LBTN pwi

Appendix D

Required Operator Actions

Form BS-D-2

Scenario No.: 3

Page I

of 21

Qp-Test No.: 2004-301

AppBicmts Actions or Behavior

Place Excess letdown MW I-OP-CH-OD6 (Continued)

- Verify I-CH-Pi-1138, Excess LDTN MX Outlet pressure

indicates = 10 psig (should be)

Open 1-CH-HCV-1201, Excess LDTN HX HSQI

Veri@ 1-CH-FI-1 122A, GHG Line flow is stable and record the

\\flow (should be zero)

iews caution about potential leak points downstream of the

caution about only one loop drain valve may be open

00T, to prevent the possibility of bypassing SI flow to

ct loops in a DSA, due tQ h o p cross-connect through

Drain header isolation valve 1 -RC-HCV-I 557A

rate can be calculated by using 1 -D@-

level changes is = 1 S gallons

- Notes Attachment

- Slowly open 1-CH

- Verify TI-GC-108, L

tlet temp indicates

I50F

- Veri@ I-CH-TI-I 139, Excess

- When the PDTT level has increa

ed to lower P U R level if required

, Excess LBTN Flow using 1-CHI-

HC-1137 until zz 15

s established to the PDTT

E X Outlet temp indicates c:

195OF

10% as indicated on

\\

GO TO 31 (AP-16.00, Step 18)

Check RCS leak rate. (Ap-16.00, Step 3 1)

-

Stabilize unit conditions

Perform RCS leak sate

Unidentified leakage less than 1 gpm (should be)

Evaluate source of leakage unit operation may contain if none of the

following exists. (M-16.00, Step 32)

-

A non-isolable fault in an RCS component body, pipe well, vessel wall,

or pipe weld

END OF AI-16.00

Form ES-D-2

Appendix D

Required Operator Actions

Qp-Te~t NO.: 2004-301

Scenario No.: 3

Page 9 of 21

be brought to HSD within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Appendix D

Required Operator Actions

Form BS-D-2

Bp-Test No.: 2004-301

Event No.: 7

Everf' ~escription: Loss of Semi-vital Bus. Bus will not be recoverable

Scenario No.: 3

Page 10 of 21

~

Applicant's Actions or Behavior

Acknowledges numerous annunciators

Identifies loss of Semi-Vital Bus by observing zero voltage on indicator.

Reviews annunciators.

9

- Identifies condenser vacuum decreasing

-

Directs placing condenser hoggers in service

- Identified GS System in service

Condenser

- 1-VP-4

--

__I-.

Appendix D

Required Operator Actions

Form ES-D-2

io1

S@C!DaB.iQ NQ.: 3

Page 11 of21

Applicants Actions or Behavior

- 1-VP-19

- 1-VP-20

- 1-as-19

- 1-AS-20

- I-VP-I

- 1-w-2

- Open Nogger steam supply valves

- Open Hogger suction valves

- Make entry in Narrative Logs that Hoggers are in service

- Notify IIP Count Room that Hoggers are in service

Power tu the Steam Header Pressure MitnuallAuto station has been lost,

h the associated controller in Auto-Hold with fixed output demand. The

minutes. The PORVS will continue to control in

setpoint set on the MCR ManuaUAuto station

ontrolier to shift to Relay

rack at last setpoint which faiied low.

nually close 1-MS-86.

Or

9. WHEN fault corrected then

ause.

Appendix D

Required Qperator Actions

Form E§-D-2

Bp-Test NO.: 2004-301

Scenario Yo.: 3

Page 12 Of21

Applicants Adorns or Behavior

Perform focus brief on failure and actions in progress.

Breaker 15 for Unit I and Breaker IS on Unit 2 Semi-vital Bus should be

opened before performing the following step. (AP-I 0.05, Note prior to

Step 9)

Directs the Electrical Department to swap the Gai-tronics power supply to

unit 2 semi-vital bus (Junction Box in Unit 1 ESGR). (AP=10.05, Step 9)

~ alternate steam release will be required to keep the Main Stean

es from lifting. (AP10.05, Caution prior to Step 10)

-

I-CV-P-lA&

-

1 -BA-P-4A & B,

-

1 -DG-P- 1 A & B, Pri

ain zXFER Pumps

Locally Transfer NRC

Supply as necessary.

-

Direct Service

[AP-10.05, Step 12)

necessary (should be

no)

Secure the following as necessary

- BR-P-SA & B, Stripper Circ Pumps (S~SU~C!

b

- Check LW and BR Panels for failed indications and c

- BR-P-4A & B, PRT DRW TK PP

Appendix D

Required Operator Actions

Form E§-D-2

Scenario No.: 3

Page 13 of 21

Op-Test NO.: 2004-301

AppBicants Actions or Behavior

Monitor the following components which have failed indications. (Ae-

10.05, Step 14)

- RCPS

- Instrument and Service Air

-

rnWPumps

autoiatically shifted to unit 2. (m-1

-

SROBO Direct Service BLDG op

check power supply

alignment

Appendix D

Required Operator Actions

Form E§-D-2

Op-Test No.: 2004-301

Scenario No.: 3

Page 14 of21

Event No.: 8, 9, 10, & 11

Event Description: Main Steam Line Break in Containment in 1A Steam Generator.

Auto and Manual Reactor Trips fail. Failure of one Hi CLS Train fails to activate.

Failure of B -CC-TV- 1 OSA (CCW return from RCP 1 A) to close an Phase ID Isolation

Time

Position

RQ

TEAM

KQ

Applicants Actions or Behavior

Acknowledges annunicators.

Identifies decreasing RCS Pressure and Temperature with control rods

stepping out .

Identifies abnormal indications on K9 SG and inside CTMT

Identifies failure automatic Reactor Trip and initiates 1 -E4 Immediate

Actions.

Directs performance of 1-E-0 Immediate Actions.

Acknowledges annunciators while RO performs Immediate Actions.

Verifies Reactor Trip @-0, Step 1 -Immediate Action Step)

-

Informs the TEAM

Attempts to manually trip Reactor

Identifies failure of both Reactor Trip Pushbuttons

Directs performance of I -FK-S. 1 Immediate Actions.

Verify Reactor Trip. (FR-S.-l, Step 1)

- Manually insert control rods

- Afler Turbine tripped return the control rods to automatic

Verify Turbine Trip (PR-S.l, Step 2)

-

- Manually trip the turbine

Verify AE;W Pumps Running. (FR-S. 1, Step 3)

-

Identifies MD AFW Pumps running (should be)

-

Identifies TD AFW Pump running (should be)

Initiate Emergency Boration ofRCS. (FR-S. 1, Step 4)

-

Verify CHG flow > 75 gpm (should not be)

-

Identifies SI in service, so CHG Pump suction align to RWST

-

Verify P U R pressure

2335 psig (should be)

Verify ail turbine stop valves closed (should not be)

Appendix D

Required Operator Actions

FOITII ES-El-2

OpTest No.: 2004-301

Scenario No.: 3

Page 15 Of 21

Position

T E N

TEAM

T E N

SROiRO

SROWOP

Applicants Actions or Behavior

If an SI signal exists or occurs, Attachment I should be performed while

continuing with this procedure. (FR-S.1, Caution prior to Step 5)

Identifies SI occurred due to Hi CLS

Hdentifies AMSAC initiated a Reactor Trip by opening MG set breakers.

Directs performance of Attachment 1, Verifying Steps 1 through 13 of I-E-

0.

-

Verify Reactor Trip - dispatch an operator to perform local trip

Verify Turbine Trip - isolate reheaters by closing 1-MS-SQV-104

Verify both AC Emergency Buses energized (should be)

Identifies SI initiated - manually initiate SI

Verify FW Isolation (should be)

Verify CTMT Isolation Phase 1 (should be)

Veri@ M W Pumps mnning (should be)

Verify SI Pumps running (should be)

Check CHG Pump Auxiliaries running (should be)

Check Intake Canal > 24 FT and level being maintained by CW Pumps

Check ifMain Steamlines should be isolated (should be)

Cheek if CS Required > 23 psia

- Manually initiate Hi Hi CLS

- Trip aH1RCPs

- Initiate Attachment 2, CLS Component Verification

- Manually close 1-RM-TV-lOOC (HI CLS Train failure)

- Manually close 1-Kh.I-TV-IOOA (Hi CLS Train fdure)

- Manually close 1-CC-TV-IOSA (Component failure)

a

-

Blocks Low PRZR pressure and High Steam Flow SI signals

Verify SI flow (should be)

- Reset both trains of SI

- Stops A CHG Pump and put in AUTO

- Identifies RCS pressure

- Stops one LHSl Pump and put in AUTO

I85 psig

heck if the following trips have occurred (FR-S. 1, Step 5)

Reactor Trip (depends on ASMSAC)

- Direct Service BLDG operator to open Unit 1 Reactor Trip

Breakers

Turbine Trip (should be)

Uternate water sources for AFW Pumps will be necessary if ECST leveh

fecreases 20%. (FR-S.

1, Caution prior to Step 6)

Identifies ECST level 9 20%

Appendix D

Required Operator Actions

Form ES-I3-2

Position

SWQ/BgPP

Applicants Actions or Behavior

Check SG Levels. (FIX-S. 1, Step 6)

-

Verify all dilution paths isolated. (FR-S. 1, Step 7)

-

Check NR level in at least one SG

Verify total feed flow > 708 gpm

Control feed flow to maintain NR level between 22% and 50%

12% (should not be)

Put PG PUMP control switches to OFF

Close PG to Blender Flow Control Valve, l-CH-FCV-1114A

Veri@ PRT PG outside TV, I-RC-TV-1519A dosed (should be)

Initiate Attachment 3, PG Isolation

- Directs Auxiliary BLDG operator to complete Att. 3

Check for Reactivity Insertion from uncontrolied RCS Cooldown @It-

- RCS temperatures decreasing in an uncontrolled manner (should be)

- A SG pressure decreasing in an uncontrolled manner (should be)

- Identifies A SG faulted inside CTMT

Check MSTVs closed. (FR-S 1, Step 9)

-

s 1, Step 8)

Identifies MSTVs closed on Hi Hi CLS

-

Check pressures in all SGs

- Identifies A SG pressure decreasing in an uncontrolled manner

At least one SG must be maintained available for RCS cooldown Hf all

SGs are faulted, at least 60 gpm El00 gpm] feed flow should be maintained

to each SG. Ifthe TD AFW Pump must be maintained from at least one

SG (EX-S. I, Cautions prior to Step B I)

Isolate FauIted SG(s). (FR-S. 1, Step 11)

- Isolate W W line

- Close A SG PW isolation MOV, l-FW-MOV-154A

- Locaily close feed REG bypass valve manual isolation valve, 1-

- Isolate A SG AFW MOVs

- Locally close steam supply valve to TB AI;W Pump, 1-MS-87

- Close or verify closed SG PORV (should be)

- Close or verify closed SG b1owdown TVs (should be)

FW-26

heck CETCs 1200°F (FR=S.l, Step 12) (sho~ld be)

Appendix D

Required Operator Actions

Op-Test No.: 2004-301

Scenario No.: 4

Time

s _

Form ES-B-2

Page 13 of 21

Applicants Actions or Behavior

If adverse CTMT conditions have been exceeded, the Gamma-Metrics

Excore Neutron Monitor system (Source and Wide Ranges) should be used

t~ monitor neutron flux for the duration ofthe event. (FR-S. 1, Note prior

to Step 13)

Verify Reactor Subcritical. (FR-S.1, Step 13)

-

Check the following

Check power range channels < 5% [Gamma-Metries Wide Range

Power]

5% (should be)

- Intermediate range channels negative startup rate [Gamma-

- or

- Shutdown margin IAW 1-OF-RX-002, SHUTDOWN MARGIN

Metrics Wide Range Power decreasing]

(CALCULATED AT ZERO PQWR) > 1.73%

Boration s h ~ u k i

be continued to obtain adequate shutdown margin during

subsequent actions. (FR-S. 1, Caution prior Step141

Return to procedure and step in effect.

Transitions to I-E-0, Step 1

Perform transient brief on failures and actions in progress.

Verifies Reactor Trip (E-0, Step 1 - Immediate Action Step)

-

Check Neutron flux lowering

Identifies Reactor was tripped by AMSAC

Check all Rods On Bottom Light lit

Check Reactor Trip and Bypass Breakers open Iocally

Verify Turbine Trip (93, Step 2 - Immediate Action Step)

-

Manually tripped the turbine by pressing both Trip Pushbuttons

Identify all Turbine Stop Valves close

Close MSR Steam Supply I-MS-SOV-IO4

Verifi Generator Output Breaker open (30 second time delay)

Verify both Emergency AC Buses energized (E-0, Step 3 - Immediate

kction Step)

Appendix D

Required Operator Actions

Fom ES-D-2

Qp-Test No.: 2004-301

Scenario No.: 3

Page I8 of21

30P/SRO

WO/SRO

-

veri@ ~ H S I

pumps running

-

Veri@ SI annunciators lit

-

A-F-3

-

A-F-4

Verify FW Isolation. @-Ox Step 5)

- Feed pump discharge MQVs closed (1-FW-MOV-150A & B)

-

MFW pumps tripped

- Feed Reg valves closed

-

SG FW bypass flow demand at zero

Veri& CTMT Isolation Phase I. (E-0, Step 0)

-

Phase I TVs closed

-

1-CH-MBV-1381 closed

-

1-SV-TV-1028 C ~ S S ~

-

PAM Isolation valves l-DA-TV-lO3A closed

PAM Isolation valves 1-DA-TV-103A closed

-

CHG Pumps running

- LHSI Pumps running

-

Level being maintained by CW Pumps

Appendix D

Required Qperator Actions

Bp-Test NO.: 2004-361

Scenario No.: 3

Form ES-D-2

Page 19 of 21

Applicant's Actions or Behavior

Check $Main Steamlines should be isolated. (33, Step 11)

-

Check if any ofthe following annunciators have been lit.

-

E-F- 10, HT S T E M FLOW SI - (should be OB^)

B-@-4, HI HI CLS TRAIN A - (should be on)

B-C-5, HI HI CLS T

W

B - (should be on)

-

Check MSTVs closed

-

Check either ofthe following actuated

-

Verify KWST crosstie valves open

-

2-SI-TV-202A & B open

Hi Stem flow SI - (should be no)

Header to line SI - (should be yes)

-

I-SI-TV-102A $r B open

Check RCS pressure < 185 PSIG - (should be no)

-

Trip all RCPs

-

Veri@ CS pumps running

-

=heck if CTMT Spray Required (E-0, Step 12)

CTMT pressure has exceeded 23 psia

Manually initiate Hi Hi CLS

Check ISRS pumps running (Time Belayed)

Check QSRS pumps running (Time BeIayed)

Initiate Attachment 1, CLS Component Verification

,ow PRZR pressure SI signal should be blocked when P U R pressure

lecreases < 2800 psig

BEocks LSW PR%R pressure SI signal by using block switches

ligh steam flow SI signal should be blocked when Tave decreases <

i43'F

Blocks High steam Bow SI signal by using the block switches

HG pumps should be run in the following order of priority. C, B, A

Jerify SI Flow. (E-0, Step 13)

-

HHSI to cold legs flow indicated

-

1 -SI-PI- 196 1

-

1 -SI-PI- 1962

-

1-SI-FI-1963

-

1-SI-FI-1943 or 19438

-

Check thee CHG Pumps running

-

Reset SI

-

Stop one 6HS Pump and place in AUTO

-

Check RCS pressure

185 psig (should not be)

rerify Total AFW flow > 350 gpm [450 gpm]. @-Q Step 14)

Appendix E)

Required Operator Actions

Form ES-D-2

Op-Test No.: 2004-301

Scemario Ne.: 3

Page 20 of 21

~

Time

Position

BQP/SRC

Applicant's Actions or B e h a ~ i ~ r

Check AFW MOVs open. (E-0, Step 15)

Verify SI Valve Alignment IAW Att. 2. (E-0, Step 16)

- Verify open CHG Pumps Suction from RWST MOVs

-

1 -CH-MOV- 1 1 15B

1 -CH-MBV- 1 1 1 5D

-

Verify closed CHG Pump Suction from VCT MOVs

-

I-CH-MOV- 1 1 15C

-

1 -CH-MOV-l115E

Verify closed CHG Line Isolation h?lBVs

-

l-CH-MOV-1289A

-

1 -CH-MQV- 1289B

-

- Verify open NHSI to cold legs MOVs

-

l-§I-MOV- 1867C

-

l-SI-LWQV-I86919

Verify open LHSI suction from RWST MOVs

-

1-SI-MOV-18628

-

1-SI-MOV-1862B

-

Verify open LHSI to cold legs MQVs

-

I-SI-MQV-1864A

-

I-SI-MBV- 18643

Verify ventilation alignment and AC power alignment IAW Attachment 3

)3-0, Step 17) (54, Att. 3 is attached)

Only one switch to be manipulated on the Ventilation Panel)

?heck RCS Avg Temp stable or trending towards 547°F. (E-0, Step IS}

-

Identify 547°F

. Identi6 not dumping steam and control total feed flow. Maintain >

350 gpm [450 gpm] until WR level > 12% [IS%] in at least one SC.

. Identify MSTVs closed

heck PRZR PQRVs and Spray Valves: (E-0, Step 19)

P U R PQRVs closed

PRZR Spray controls at zero demand (Spray valves closed)

Ai least one PORV Block Valve open

heck RCP Trip and Miniflow Recirc Criteria. (E-0, Step 20)

HHSI flow to Cdd legs indicated

RCS Subcooling > 30CF [WF]

Appendix D

Required Operator Actions

PQrIII ES-D-2

Scenario No.: 3

Page 21 of21

- Pressures in all SGs > 108

Appendix D

Scenario Outline

Form ES-D-1

Examiners:

Operators:

Initial Conditions:

700% Reactor Power

Preparing to conduct partial rod movement testing.

Turnover: Off normal conditions for Unit 1: 1-KC-HCV-1557A (Excess Letdown) is isolated

due to Ieakby, 1-EH-P-MP2 (EH6 Pump) is tagged out for thermal overload replacement.

Unit 2 is at 100% power with 2-FW-P-2 (TDAFW Pump) tagged out for governor replacement.

I

9

M

1 (ALL) Main Steam bine Break at header (50,

E-2)

t

I

12

M

(ALL) RCS bleed and feed

i

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

Appendix D

Required Operator Actions

Form ES-D-2

Op-Test NO.: 2004-301

Scenario No.: Spare

Page 1 of22

Event No.: I

Event Description: Conduct Rod Movement Testing (1-OPT-RX-005)

PARTIAL MOVEMENT

SRORO

(OPT-RX-005,

Section 6 1)

Bank Overlap Verification and Documentation (OPT-KX-005, Section 5 2 )

- Record the step counter DEMAND POSTN for control banks A, R, and

c

- Direct an uperator to record and report the bank overlap thumbwheel

settings

- Direct an operator to record and report the bank overlap counter (BOC)

number and RO records the step counter BEMAhD POSTN for control

bank D

Determine the diEerence between BOG and control bank B

Identifies the difference is 384

-

Control Bank D COPT-RX-005, Section 6 3)

- Turn the ROD CQNT -MODE §EL switch to CBD

Table 1, Control Bank I3

Insert Control Bank D 12 steps

Complete the Inserted line in Attachment I, Table 1

Withdraw Control Bank B 12 steps

compare with the Reference

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Calculate in Attachment 1, Table I the Control Bank D Insertion and

I

Appendix D

Required Operator Actions

Qp-Test No.: 2004-301

Scenario No.: Spare

Porn1 ES-D-2

Page 2 of22

Position

SRO/KQ

SRO/RO

Apphmt's A c t h s or Behavior

Control Bank C (OPT-RX-005, Section 6.4)

- Turn the ROD CON" MODE SBL switch to CBC

Table 2, Control Bank C

Insert Control Bank C 12 steps

Complete the Inserted line in Attachment I, Table 2

Verify 1G-B5, COMPU PRINTOUT ROD CONTR SYS is lit

Verify 16437, ROD BANK C LO L M T is lit.

the same after the next Step, they must be made the same by stepping out

only to prevent a Rod Croup Sequence Enor This will leave rods at 230

steps and prevent rod group misalignment.

Demand Counters

Attachment 2 for guidance

compare with the Reference.

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Notes that in the event the Group 1 and Group 2 Step Counters are not

- Withdraw Control Bank C to 235 steps as indicated by the Group Step

- Pulse the Group Group Step Demand Counters down to 230 steps using

- Caiculate in Attachment 1, Table 2 the Control Bank 6 Insertion and

- Veri@ alarms 1G-B5 and 1G-B7 are not lit

Control Bank 3 (OPT-RX-005, Section 6.5)

-

Turn the ROB CONT MODE SEL switch to CBB.

Table 3, Control Bank B

Insert Control Bank B 12 steps

Complete the Inserted line in Attachment 1, Table 3

Verify 16-B5, COMPU PRINTOUT ROD CONTR SYS is lit

Verify 16436, ROD BANK B LO L M T is lit.

the same after the next Step, they must be made the same by stepping out

only to prevent a Rod Croup Sequence Error This will leave rods at 230

steps and prevent rod group misalignment.

Demand Counters

Attachment 2 for guidance.

compare with the Reference

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Notes that in the event the Group 1 and Group 2 Step Counters ape not

- Withdraw Control Bank B to 235 steps as indicated by the Group Step

- Pulse the Group Group Step Demand Counters down to 230 steps using

- Calculate in Attachment 1, Table 3 the Control Bank B Insertion and

- veri^ alarms BGB5 and 1 G-B6 are not lit.

Appendix D

Required Operator Actions

Form ES-D-2

Qp-Test NO.: 2004-301

Scenario No.: Spare

Pa@! 3 Qf 22

Time

Position

SIPOBO

1 -

Turn the ROD COXT MODE SEL switch to CBA.

Table 4, Control Bank A.

Insert Control Bank A 12 steps.

Complete the Inserted line in &4ttachment 1, Table 4

Verify lG-B5, COMPU PRHNTOUT ROD CONTR SYS is lit.

Verify 16-B5, ROD BANK A LO LLMT is lit.

the same after the next Step, they must be made the same by stepping out

only to prevent a Rod Croup Sequence Error. This will leave rods at 230

steps and prevent rod group misalignment.

Demand Counters.

Attachment 2 for guidance.

compare with the Reference.

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Notes that in the event the Group I and Group 2 Step Counters are mot

- Withdraw Control Bank A to 235 steps as indicated by the Group Step

- Pulse the Group Group Step Demand Counters down to 230 steps using

- Calc.ulate in Attachment 1, Table 4 the Control Rank A Insertion and

- Verify alarms 1'3435 and 1GB5 are not lit.

Shutdown Bank B (OPT-RX-005, Section 6.4)

-

Turn the ROD CONT MODE SEL switch to SBB.

Table 5, Shutdown Bank B.

Insert Shutdown Bank B 12 steps.

Complete the Inserted line in Attachment, 1, Table 5

Verify 16435, C O W U FNNTOUT ROD CONTR SYS is lit.

the same after the next Step, they must be made the same by stepping out

only to prevent a Rod Croup Sequence Error. This will leave rods at 230

steps and prevent rod group misalignment.

- Withdraw Shutdown Bank B to 235 steps as indicated by the Group Step

Demand Counters.

- Pulse the Group Goup Step Demand Counters down to 230 steps using

Attachment 2 for guidance.

- Calculate in Attachment 1, Table 5 the Shutdown Bank B Insertion and

compare with the Reference.

- Verify alarm 1G85 is net lit.

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Notes that in the event the Group 1 and Group 2 Step Counters are not

1

I

Appendix D

Required Operator As.tions

Form ES-D-2

Op-Test NO.: 2004-301

Scenario No.: Spare

Page 4 of22

SRORO

Applicants Actions or Behavior

Shutdown Bank A (OPT-RX-005, Section 6 8)

-

Turn the ROB CONT MODE §EL switch to SBA

Table 6, Shutdown Bank A

Insert Shutdown Bank A 12 sreps

Complete the Inserted line in Attachment 1, Table 6

Veri@ BG-B5, COMPU PRINTOUT ROD CONTR SYS is lit

the same after the next Step, they must be made the same by stepping out

only to pievent a Rod Croup Sequence Error This will leave rods at 230

steps and prevent rod group misalignment

- Withdraw Shutdown Bank A to 235 steps as indicated by the Group Step

Demand Counters

- Pulse the Group Goup Step Demand Counters down io 230 steps using

Attachment 2 for guidance

- Calculate in Attachment 1, Table 6 the Shutdown Bank A Insertion and

compare with the Reference

- Record the baseline rod position on the Withdrawn line in Attachment 1,

-

- Notes that in the event the Group 1 and Group 2 Step Counters are not

Verify alarm B G-B5 is not lit

Rods in Automatic, and Bank Overlap Verification and Documentation

(OPT-RX-005,

Section 6 9)

- M e r verifying that Tavg is within 5 l°F of Tref, then put ROD CONT

MODE SEL switch in AUTO

- Record the step counter DEMAbD POSTK for control banks A, B. and

c

- Direct an operator to record and report the bank overlap thumbwheel

settings

- Direct an operator to record and report the bank overlap counter (BOC)

number and R 8 records the step counter DEMAND PBSTN for control

bank D

Determine the diEerence between BO@ and control bank B

Identifies the difference is 384

-

Follow-On. (OPT-RX-085, Section 7.0)

- Evaluate the test results by reviewing the Acceptance Criteria.

- Identifies the rods are inserted 12 steps, the GPI and GP2 step

- Identifies when the rods are inserted 12 steps, the WPI Insertion is

- Identifies the difference between Bank Overlap Counter and

- Identifies the thumbwheel settings are corrected based on criteria.

counter Insertion is 12.

12 6.

Control Bank D is 384.

I

Appendix D

Op-Test NO.: 2004-301

Event No.: 2

Event Description: P E R pressure transmitter fails high (1-RC-PT-1445).

Time

Position

RQ

R 8

FOMI ES-D-2

Page 5 of 22

Closes P U R PORV that open due to instrumemtation failure.

Verifies PRZR pressure recovering following the opening of P U R PORV

Performs a focus brief on the failure and actions in progress.

Reviews annunciator response procedures.

Evaluates Tech Specs sections 3.1 .A.6, 3. I .G, and 3.12.F. Declare P E R

PORV, 1-RC-PCV-1456 inoperable and close PRZW PORV block valve, 1-

RC-MQV-1535 within o g - h z r If PRZR pressure decreased < 2205 psig

then identify a two-hour to restore PBPZR pressure

Directs I B C Maintenance to investigate the failure of 1-RC-PT-1445,

BRZR Pressure control channel.

Kotifias Shift Manager and STA of failure and actions in progress.

Appendix D

Required Qperator Actions

Op-Test NO.: 2'304-301

Event No.: 3

Event Description: P U R PORV Leakage (I-RC-PCV-1455C)

Scenario Noo: Spare

Time

Position

Applicant's Actions or Behavior

Acknowledges annunciator lC-F?, PRZR RELIEF TK HI PRESS.

Identifies P U R pressure decreasing and reviews annunciator response

procedures.

Acknowledges annunciator 1C-D4, P U R PWR W L E F LINE HI TEMP.

Direct implementation of AP-3 1 00, INCREASING OR DECmASIYG

RCS PWESSURE.

Check Turbine Load stable. (AP-3 1 00, Step 1)

Check RTS pressure decreasing. (AP-3 1.06, Step 2)

- Identifies RCS pressure is slowly decreasing.

Decreasing RCS pressure will cause the QTAT setpoint to decrease. (AP-

3 I .OO, Caution prior to Step 3 )

- Monitor OTAT setpoint.

PZR PQRV I-RC-PCV-1455C

shoiald be declared inoperable when the

Master Controller is placed in Manual. (AP-3 1.00, Note prior to Step 3 )

Stop Pressure Decrease. (AP-3 1.00, Step 3)

- Place l-CH-PC-1444J, P U R P E S S MASTER CKTRL in

MAW&.

- Decrease demand on PKZR PRESS MASTER CNTRL to raise RCS

pressure.

- Declare PaZR PORV inoperable

Check RCS pressure still decreasing. (AP-3 1.00, Step 4)

-

Veri@ no pressure loss through the PRZR PORVs. (AP-3 1 .00, Step 5)

-

- Close Block M8V to isolate any PQRV, which will not close or is

- Identifies when the remaining Biock MQV closes RCS pressure will

Identifies RCS pressure is still decreasing.

Close or verify dose PWR PORVs

leaking.

start increasing.

Appendix I9

Required Operator Actions

Qp-Test No.: 2004-301

Event No.: 3

Event Description:

Scenario No.: Spare

Foran BS-B-2

Page 7 of 22

Applicants Actions or B~laavior

Turn on ail PRZR heaters. ( M - 3 1 .OO, Step 6) (should be)

Verie closed or close 1-CH-HCV-13 11, AUX Spray Is~li&~. (AP-3 I .OO,

Step 7) (should be)

Check ALJX Spray line leakage suspected. (Ap-3 1 .OO, Step 8) (should not

-

GOTO §tep 10

be)

Place Spray valve controllers in Manual and adjust demand to zero. (AI?-

31.00, Step 10)

-

Verifies demand at zero

Places both spray valves controllers in Manual.

Check either of the following conditions. (AP-3 I .OO, Step 1 1)

-

Identifies both spray valves closed.

Identifies spray valves not leaking to abnormal PRT conditions.

-

Go TO Step 13

Check RCS Pressure stabilizing or increasing. (-31

.OO, Step 13)

- Identifies R.CS pressure increasing following closing last P U R BORV

block valve.

-

TO Step 17

Peturn PRZR PRESS MASTER CNTRL and P U R Spray Valve

ontrollers back to AUTO.

3vaiuates Tech Specs sections 3.2.A.6, 3.1.6, and P.12.F. Declare PR%R

JOKV, 1-RC-PCV-1456 inoperable and close PRZR PORV block valve, 1 -

IC-MOV-1535 within one-hour. If P U R pressure decreased

hen identify a two-hour to restore ]PUR pressure. Determine RCS leak

ate after stabilizing plant conditions.

2205 psig

iotifiies Shift Manager and STA of failure and actions in progress.

Appendix D

Required Operator Actions

Bp-Test No.: 2004-301

Scenario No.: Spare

Event No.: 4

Event Description: Unit Load Reduction (AP-23.00)

Position

Form ES-D-2

Page 8 of 22

AppBicrant9s Actions OF Behavior

Acknowledges annunciator 1 E@,

GEN LEADS CLG TKBL

+

W r w h p-

wck&?M. &t5

Pa%.

Direct the Turbine BLDG operator to local annunciator panel to inwstigate

cause of alarm.

Reviews annunciator response procedure while awaiting field report

Perform ARP 1G-E5, GEN LEELBS CLG TREK

lsophase Bus Duct Cooling (BDC) Fan

- Turbine BLDG operator reports Low &r Flow due to a loss of A

- Reviews cautions

- If one or more fan is inoperable, a unit ramp down to the self

cooled rating of 14,250 amps should be initiated immediately

- Power should be reduced at the rate of 1% power per minute to

78% power Power reduction sh~uld continue fiom 78% to

14,250 m p s at normal rate of 155 MWehKR

- Reviews note in accordance with OPAP-0006, Shift Operating

Practices, at the discretion sfthe Shift Supervisor, the thermal overload

devices may be reset only once.

- Attempt to restart Pran

- Dispatch operator to check circuit breaker MCC 1A2-2-1B. GEN

- Report from field is the breaker is tripped

- Initiate a ramp down to reduce generator amps to 14,250 amps in

- G8 TO Step 8 to initiate work request to repair BDC fan

LEADS CLR PH A Pan

accordance with 8-AP-23 00, W D LOAD REDUCTION

Votify Electrical Maintenance to investigate failure of the IBBC Fan

Yotifies Shift Manager and STA of failure and actions in progress.

Directs M-23.60, Rapid Load Reduction based on loss of WDC Fan.

3onservative decision-making must be maintained during rapid load

aiuctions. If uncertain or degrading conditions arise which could

idversely affect the safety ofthe plant, or if any criteria in Attachment 1 is

xceeded, the load reduction should be terminated by tripping the Reactor

)r the turbine, or both, depending on power level. (AP-23.00, Caution

xior to Step 1)

Appendix D

Required Operator Actions

Form ES-D-2

Bp-Test No.: 2004-301

Scenario No.: Spare

Page 9 of22

actions should continue at Step 25.

- RCS Tave must be maintained 5 579F and RCS pressure 2 2205 psig.

Tech Spec 3.12.P.1 should be reviewed if either parameter is exceeded

- I&C should be contacted to provide assistance with adjusting IRPIs.

Initiate Plant Load Reduction at I % M N T E or less. (Ap-23.00,

Step 1)

-

- Insert control rods in AUTO or IMWA% as necessary to maintain

Verify turbine valve position not on limiter. (should not be)

Tave and Trefmatched.

- Veri5 or place Turbine in WLP INPd.

- Adjust LOAH> RATE %/

thumbwheel to 1%MIN ramp rate.

- Initiate Turbine load reduction using OPERATOR AUTO.

- Perform emergency boration for 30 to 60 seconds IAW the following:

- Verify or rise CHG flow to 9 95 gpm

- Transfer the in-sewice BATP to FAST

- Momitor EMER BORATE: FLOW

- After required emergency boration, perform the following:

- Open 1CH-MOV-1350

- Close 1-CH-MOV-1350

- Transfer the in-senlice BATP to AUTO

- Restore CHG Bow control to normal

- Establish a continuous 10 gprn normal boration to maintain control rod

position above the LO-LO- insertion limits.

- Check all PRZR heaters energized.

- Contra! ramp rate to maintain RCS pressure

2205 psig.

- Monitor steam dumps for proper operation.

- Reduce Turbine valve position limiter as load decreases.

Appendix D

Required Operator Actions

Form ES-D-2

Op-Test NO.: 2004-301

Scenario No.: Spare

Page 10 of22

- VPFLP-2802, Notifications and Report applicability

Appendix D

Qp-TESt No.: 2004-301

Event Yo.: 5

Event Description: HA Steam Generator Level Transmitter fails low (1-FW-LT-1476)

Required Operator Actions

Scenario No.: Spare

Form ES-D-2

Page 11 of 22

_I

I

Applicants Actions or Behavior

Acknowledges annunciators associated with the SG levels and high

Identifies A SG channel 3 faiied low (1-FW-LT-1476).

Direct BOP to place A Main FRV in Manual and restore A SG level.

Takes manual control d A Main FRV and reduces feedwater flow to

restore level.

Reviews W s .

Performs focus brief on failure and actions in progress.

Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 12 B 17

requiring Operator Action #6; identifies TS Table 3.7-2 item 3a and TS

Table 3.7-3 item 3a requiring Operator Action #20, 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months clock to place

channel in trig.

Notifies I B C Maintenance to place channel in trip.

Notifies Shift Manager and STA of failure and actions in progress.

Event No.: 6

Required Operator Actions

Seenaris No.: Spare

Event Description: 1B SG POW

E -MS-R7

C

Form ES-D-2

Page 12 of22

Appendix Id

Required Operator Actions

Form ES-D-2

Op-TeSt No.: 2604-301

Scenario No.: Spare

Page 13 of 22

Event No,: 7, 8, 9> 10, & 11

Event Description: Main Steam Line Break at header. B Charging Pump Trips and

A and C fail to auto start. Motor Driven and Steam Driven AFW punips trip.

MSTVs fail to close (I-MS-TV-101A 3, & C). B & G Main Steam MXVs fail close.

Time

_s Position

RQWQP

RB

Applicants Actions or Behavior

Acknowledges annunciators.

Identifies decreasing SG and RCS Pressure, along with RCS temperatures.

Identifies automatic Reactor Trip and initiates 1-E-0 Immediate Actions.

Directs perfbrmance of 1-E-0 Immediate Actions.

Acknowledges annunciators while RQ performs 18-0 Immediate Actions.

Verifies Reactor Trip (E-0, Step 1 - Immediate Action Step)

- Manually trip Reactor

-

Cheek Neutron flux lowering

Verify Turbine Trip (E-0, Step 2 -Immediate Action Step)

- Manually trip the turbine by pressing both Trip Pushbuttons

- Identify ai1 Turbine Stop Valves close

- Close MSR Steam Supply I-MS-SOV-104

- Verifi Generator Output Breaker open (30 second time delay)

Ver@ both Emergency AC Buses energized @-Q3 Step 3 -Immediate

Action Step)

Check if SI is actuated. (E-Q? Step 4 - Immediate Action Step)

-

- Verifi LHSI pumps running

- Verifi SI annunciators lit

Check all Rods On Bottom Light lit

Check Reactor T ~ p

and Bypass Breakers open

Manually actuate both trains of SI

- A-P-3

- A-F-4

May take actions BO isolate the steam break by:

- Attempting to close MSTVs using control switches and App Ha

Emergency closure switch (Vertical Board 2)

Closes A

MS hXV and attempts to close B & G MS NwVs

-

Appendix D

Required Operator Actions

Qp-Test Me.: 2084-301

Scenario No.: Spare

Form ES-D-2

Page 14 of 22

Position

SRODOP

SROBOP

(Event 9)

SRCB

RO/SRO

(Event 8 )

Applicants Actions or Behavior

Veri@ FW Isolation. (E-0, Step 5)

.

,

-

- Feed Reg valves closed

-

Feed pump discharge MOVs &sed (l-FW-MOV-150A & B)

- mw pumps tripped

SG FW bypass flow demand at zero

Verify CTMT Isolation Phase I. @-(I,

Step 4)

- Phase I TVs closed

-

1 -SV-TV- I02A closed

PwR/B Isolation valves I-DA-TV-103A closed

-

I-CH-MOV-1381 closed

PAM Isolation valves 1-DA-TV-1038 closed

Veri@ AFW pumps Running. ( 5 0 , Step 4)

-

Identifies

mw Pumps nQt running

- Lockout annunciators lit for both

mw Pumps

-

- Identifies no exhaust steam flow indicated for

AFW Pump

Identifies TD AFW Pump not running

Direct Unit 2 Operator to crosstie M W and supply Unit I IAW Bp-

50.00.

Verify SI Pumps Running. @-O> Step 8)

- Identifies B CHG Pump tripped

-

Identifies A and C CHG Pumps not running

-

Identifies no lockout annunciators lit

-

Manually start A and Cy CHG Pumps

-

LHSI Pumps mnning

Veri@ CHG Pump Auxiliaries. @-O> Step 9)

-

GPEG Pump C@ Pump running

CHG Pump SW Pump mnning

Check Intake Canal. (E-0, Step 10)

Level>24FT

-

Level being maintained by CW Pumps

Appendix D

Required Operator Actions

Form ES-B-2

Scenario No.: Spare

Page 15 OF 22

Bp-Test NO.: 2004-301

Iinne

Applicants AC~~QIIS

or Behavior

Check if Main Stearnlines should be isolated. (E-0, Step 1 I)

-

Cheek if any ofthe following annunciators have been lit.

- E-F-10, MB STEAM FLOW SI (should be on)

- B-C-4, HI HI CLS TEMN A (should be o w

- B-(2-5, Hl HI CLS TRAIN B (should be OR)

- Attempting to close MSTVs using control switches and App R

Emergency closure switch (Vertical Board 2)

- Closes A MS NRV and attempts to close B C C MS NRVs

- If annunciator E-H-10 (Header to line SI) (should be yes)

- Verify RWST crosstie vaalves open

- 1 -SI-TV- 1028

- l-SI-TV-102B

- 2-SI-TV-202A

- 2-SI-TV-2Q2E

- Check RCS pressure

185 psig (should not be)

Check if CTMT Spray Required. (E-0, Step 12)

-

- GOTOStep 13

CTMT pressure has exceeded 23 psia (should not be)

IfCTMT pressure has exceeded 17.7 psia (should not be)

Review notes. (E-0, Notes prior to Step 13)

- Low P U R pressure SI signal should be blocked when PRZK pressure

decreases < 2000 pig

- Blocks Low PRZR pressure SI signal by using block switches

- High steam flow SI signal should be blocked when Tam decreases <

543°F

CHG pumps should be pun in the following order of priority: C, B, A

- Blocks High steam flow SI signal by using the block switches

-

Verify SH Plow. (E-0, Step 13)

-

- 1 -SI-FI- 196 1

- I-SI-PI-1962

- 1-SI-1963

- 1-SI-FI-1943 or 1943A

SI

to cold legs flow indicated

-

Reset SH

-

Check three CHG Pumps running

Stop one CHG Pump and place in AUTO

Check RCS pressure

185 psig (should be > 185 pig)

Appendix B

Required Operator Actions

Bp-Test No.: 2004-301

Event No.: 12

Event De$CriptiQEI: RCS Bleed and Feed

Scenario No.: Spare

i

I I

i--

I

Position

SROWOP

SIP0

TEAM

FOETI ES-D-2

Page 16 of 22

Appticant's Actions or Behavior

Verify Total AFW flow

-

350 gpm [450 gpm]. @-0, Step 14)

Identifies no AFW Pumps running

AFW flow < 350 gprn

GO TO FR-H. 1

Transitions to FR-3.1

Reviews Cautiomrs. (FK-H.1, Cautions prior to Step 1)

- If total feed flow

Peed Bow should not be reestablished to any faulted SG if a non-

359 gpm 8450 gpm] due to operator action, this

procedure shouId not be performed.

faulted SG is available.

-

Check if Secondary heat sink is required: (TIR-H.1, Step 1)

-

RCS pressure > any non-faulted SG pressure (should be)

RCS hot Beg temperature > 350°F (should not be)

Refer to 1-OF-W-001, RHR OPEKATIQNS. If adequate cooling with

RFR is established, then RETURN TQ procedure and step in effect.

- Try to put ILPHfp system in service while continuing this procedure.

Review caution. (FR-H. 1, Caution prior to Step 2)

- If wide range level in any 2 SGs

7% [22%] or PRZR pressure >_ 2435

psig due to loss of secondary heat sink, RCPs should be tripped and

Steps 10 through 27 should b

<

@

Z

6

Identifies that 2 SGs < 7% [22%] on wide range level indication and

actions required by the Caution or eke Comtinuous Action Page

~~

Stops all RCPs.

Reviews caution. (FR-H. 1, Caution prior to Step 10)

-

Steps 10 through 17 nust be performed quickly in order to establish

RCS heat removal by RCS bleed and feed.

Veri@ stopped or stop all RCPs pR-H.1, Step lo)

-

Identifies ai1 RCPs stopped.

Appendix B

Required Operator Actions

Bp-Test No.: 2004-381

Scenario No.: Spare

F

o

~