Text

Initial Exam 2010-301 Draft Simulator Scenarios
	ML101230153
Person / Time
Site:	Sequoyah
Issue date:	05/03/2010
From:	; NRC/RGN-II
To:	; Tennessee Valley Authority
References
	50-327/10-301, 50-328/10-301
	Download: ML101230153 (235)
	v • d • e

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 1 Op Test No.: NRC Examiners: Operators:

Initial Conditions: 100% RTP Turnover: Maintain current conditions; currently in 0-GO-5 Section 5.2, At Power Conditions Target CTs: Isolate Faulted Steam Generator Prior to Exiting E-2 Isolate AFW to the faulted SG within 10 minutes after a steamline break.

Event No.

1 MaIf. No.

RXO2D1 Event Type*

1-RO

[ RC Loop #4 T-cold Fails High Event Description T+0 SRO-TS 2 MSO9 C-SOP Gland Seal Steam Regulator, 1-PCV-47-183 fails closed T+1 0 3 ZAIHIC6281A 1-RO CVCS Let Down Pressure Control Valve Fails Closed (1-PCV-62-83)

T+20 4 CNO9 C-BOP Loss of Condenser Vacuum- Leak w/ standby Condenser Vacuum Pump failing T+30 set yp_cnl 1 b=-1 to start automatically 5 N/A R-All MT Rapid Load Reduction due to Condenser Vacuum Leak.

T+30 6 TUO2A Turbine High Vibration (14 mills sustained- no trip required)

T+45 TUO2B 7 setyp_tcl7d=-1 SRO-TS #4 MT Stop Valve indication loss T+45 8 N/A M-All Turbine High Vibration (Turbine Trip demand condition)

T+50 9 MSI2A C-BOP Loop #1 SG Atmospheric Relief Valve sticks open T+50 10 RP13C C-RO MFW Isolation Fails to Auto Actuate (manual operator action required)

T+50 [pre-insert]

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Attachment I Scenario I Summary The crew will assume the shift with the unit in MODE 1, 100% RTP. 0-GO-5 Section 5.2, At Power Conditions is the procedure in effect.

Following completion of crew turnover and at the direction of the Lead Examiner, RC Loop #4 T-cold will fail high.

The crew will respond using alarm response procedures (ARP5) 1-AR-M6A, A-2 and C-2 directing entry into AOP 1.02, RCS Loop RTD Instrument Malfunction, Section 2.0 and Appendix D for the Loop #4 temperature instrument failure. The crew may enter AOP-C.01, Section 2.1, Uncontrolled Rod Bank Movement for the unexpected rod motion. The SRO will identify Tech Spec actions: 3.3.1 .1 Table 3.3-1, functional units 7 and 8 Action 6, and 1 4c Action 10; 3.3.2.1, functional units 6.c.i.c and 6.c.ii.c both Action 37.

When the plant is stable, at Lead Examiner direction, initiate the next event, Gland Seal Steam Regulator, 1-PCV 183 fails closed, challenging condenser vacuum. The standby condenser vacuum pump may be required but will not start automatically, requiring manual action. The crew will respond using ARP 1-AR-M2A A-5 and, as necessary, AOP-S.02, Loss of Condenser Vacuum.

When the plant is stable, at Lead Examiner direction, initiate the next event, CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81). The crew will control letdown pressure manually according to alarm response procedure, 1 -AR-M6C, B-4. The crew may decide to isolate Letdown and place Excess Letdown in service.

When Letdown is stable and controlled or Excess Letdown in service, at Lead Examiner direction, initiate Loss of Condenser Vacuum- Leak. If returned to standby, condenser vacuum pump will not start automatically, again requiring manual action. The crew will respond alarms, 1-AR-M2C C-6 and re-enter AOP-S.02, Loss of Condenser Vacuum. At step 9, the crew should implement AOP-C.03, Rapid Shutdown or Load Reduction to mitigate the vacuum loss.

During the vacuum leak/turbine load reduction, Main Turbine High Vibrations will develop, ARP for annunciator 1-AR M2A D-4 will be applied. Vibration magnitude will temporarily stabilize at less than the turbine trip value. At this time

4 MT Stop Valve indication (RPS input) will be lost. The crew will respond using the ARP 1-AR-M6B E-5 which directs entry into AOP-l.07, Turbine Auto Stop Oil Pressure Instrument or Turbine Stop Valve Limit Switch Malfunction; Sections 2.0 & 2.3 apply and will address the indication failure (while the crew continues in AOP-C.03 for the load reduction). The SRO will identify Tech Spec LCO 3.3.1.1, table 3.3-1, functional unit 18B Action 7 as applicable.

Following TS identification, at the Lead Examiner direction, the turbine vibration severity will increase resulting in a turbine trip demand condition as described in ARP. The crew will manually trip the reactor.

Following the Reactor Trip, #1 SG Atmospheric Relief Valve will stick open causing a steam leak. The crew will enter E-0, Reactor Trip or SI to stabilize the plant. The crew will proceed through to E-2, Faulted SG Isolation, to stabilize the plant by attempting to isolate the steam leak and transition to E-1, Loss of Rx or Secondary Coolant, to determine if SI termination criteria are met.

Additionally, automatic Feedwater Isolation fails requiring manual isolation actions prior to exiting E-2 and isolate AFW to the faulted SG within 10 minutes to meet time critical actions to meet successful scenario completion.

EOP flow: E-0 E-2 E-1 (ES-1 .1)

The scenario may be terminated as directed by the Lead Examiner upon completion of E-1 Step 7, SI termination determination.

PSA significant task: Isolate Faulted Steam Generator Isolate AFW to the faulted SG within 10 minutes after a steamline break.

PSA significant component failure: Feedwater Isolation automatic actuation SG #1 Atmospheric Relief Valve Appendix D NUREG 1021 Revision 9

1002 ESG-1 Page 1 of 5 APPENDIX C Time: Now Date: Today Unit 1 MCR Checklist Mode 1, 100% Power 1200 MWe NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID .02 gpm, UNID .01 gpm Until 0800 XX)O(

RCS boron: 849 ppm After 0800 )O(XX

....: ... . . . bmon Teh SpØActios. ...

LCO/TRM Equipment INOP Time INOP Owner RTS None None U-I Tech Spec Actions LCO/TRM Equipment INOP Time INOP Owner RTS None None - - - - - - - - - - -

. None

i

. None CD Verify your current qualifications (re: OPDP-1 Section 7.3 F.)

1D Review Operating Log since last held shift or 3 days, whichever is less.

Review the following for changes since last shift turnover:

j ODMI5/Standing Orders! E1 LCO actions Q PERs (applicable to unit)

Shift Orders Q j Operator workarounds, burdens, TACFs and challenges D Immediate required reading Part 3 Performed by both off-going and on-coming shift Walk down of MCR Control Boards

1002 ESG-1 Page 2 of 5 APPENDIX C Time: Now Date: Today MAIN CONTROL ROOM (7690)

Train A Week OUTSiDE(7666)[5935214] *.

None AUXILIARY BUILDING (7775)

None TURBINE BUILDING (7771).(593-8455

None

1002 ESG-1 Page 3 of 5 Time: Now Date: Today MCR Red Dot List IJNID And Noun Name Panel Problem Description WO I PER Number Date Scheduled MCR WO List ID And Noun Name Panel Problem Description WO/PER Number Date Scheduled

1002 ESG-1 Page 4 of 5 UNIT ONE REACTIVITY BRIEF I Date: Today Time: Now 1

L General Information RCS Boron: 850 ppm Today BA Controller Setpoint: 21%

RCS B-lO Depletion: 52 ppm Operable BAT: A BAT A Boron: 6850 ppm 1BATCB0r0n: 6850 ppm ERWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 42 gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw 0-SO-62J section 5.1 Estimated values for a 1° Change in Tave k I

Gallons of acid: 32 Gallons of water: 227 Rod Steps: 5 I pmprnpnv qfpn nnwrrpthinn **

-- I (Assuming Xenon equilibrium and no reactivity effects due to Xenon. 2l3totaI reactivity from rods, 1/3 from boron) I Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 107 gallons 30% 175 Steps on bank D 312 gallons 50% 156 Steps on bank D 506 gallons These values are approximations and not intended nor expected to be exact. The values may be superseded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

Previous Shift Reactivity Manipulations 1 Number of dilutions: 3 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 40 Gallons per boration: 0 Rod steps out: 0 Total amountdiluted: 120 Total amount borated: 0 Net change: 0 IN/Out CrIrrRnt 1 hiff stimatd Rctivitv Maninulal ions Number of dilutions: 3 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 40 Gallons per boration: 0 Rod steps out: 0 Total expected dilution: 120 Total expected boration: 0 Net change: 0 In/Out Remarks:

Rx Power: 100% Burnup: 10,000 Mwd/mtU Xenon: 2729 pcm, equilibrium Samarium: 926 pcm Last Dilution Completed: 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago Next Unit 1 Flux Map is scheduled three weeks from now Unit 1 M-P is 0 PPM Unit Supervisor:

Name/Date

1002 ESG-1 Page 5 of 5 Operations Chemistry Information Boron Results Sample Point Units Boron Date I Time Goal Limit Ui RCS ppm 849 Today / Now Variable Variable U2 RCS ppm 816 Today/Now Variable Variable Ui RWST ppm 2601 Today / Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today / Now 2550 2650

- 2500 2700 BATA ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BATC ppm 6850 Today/Now Variable Variable UI CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 Ui CLA #2 ppm 2575 Today! Now 2470-2630 2400-2700 Ui CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today / Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today! Now > 2050 ? 2000 Lithium Results - Goat Midpoint Ui RCS Lithium ppm 1.1 Today! Now >1 >1 U2 RCS Lithium ppm 2.43 Today! Now 2.18-2.48 2.33 PrImary to Secondary Leakrafelnfoirnatioji (Total CPMRM-99fl)

Indicator Units UI Date ITime U2 Date/Time SI 50 SIG Leakage? Yes/No No Today / Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today! Now < 0.1 Today! Now 5 gpd leak equivalent cpm 370 Today! Now 111 Today! Now 30 gpd leak equivalent cpm 1970 Today! Now 464 Today! Now 50 gpd leak equivalent cpm 3250 Today! Now 747 Today! Now 75 gpd leak equivalent cpm 4850 Today! Now 1100 Today! Now CVE Air Inleakage cfm 10 Today! Now 12.5 Today! Now Bkgd on 99/1 19 cpm 50 Today! Now 40 Today! Now Correction Factor 99/1 19 cpm!gpd 64 Today! Now 14.13 Today I Now Steady state conditions are necessary for an accurate determination of leak rate using the CVE Rad Monitor

Appendix D Scenario Outline Attachment I Op Test No.: NRC Scenario # 1 Event # 1 Page 1 of 49 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event I Indications available:

Annunciators:

. XA-55-5A Window A-6 TS-68-2M!N RC LOOPS T AVG IAUCT T AVG DEVN HIGH-LOW

. B-6 TS-68-2AIB REACTOR COOLANT LOOPSLT DEVN HIGH-LOW

. E-7 NARROW RANGE RTD FAILURE LOOP 4

. XA-55-6A Window A-2 TS-68-2D REAC COOL LOOPS OVERTEMP zT TRIP ALERT

. B-2 TS-68-2G REAC COOL LOOPS OVERPOWER zXT TRIP ALERT

. C-2 TS-68-2E OVERTEMP \T AUTO TURB RNBK BLK C-3 ROD WTD

. D-2 TS-68-2J REACTOR COOLANT LOPS LO LO TAVG I-M-5 indications:

. RCS Lp 4 Indicator 1-Tl-68-67E indicates: varies, goes down then up;

. 1-TI-68-67D indicates: varies, goes down then up;

. 1-TI-68-67A indicates: varies, goes down then up;

. I-TI-68-67B indicates: varies, goes down then up;

. I-XX-55-5, Reactor Trip Status Panel PROT. SET 4 TROUBLE Status light T = 0 CREW Respond in accordance with Alarm Response Procedures Diagnose failure and place rods in manual to stop rod motion RO Refer to Annunciator Response Procedure SRO SRO may use or refer to AOP-I.02, RCS Loop RTD Instrument Malfunction SRO Enter and direct action of AOP-C.O1 Section 2.1

1. STOP uncontrolled rod motion:

RO a. PLACE rod control in MAN.

b._CHECK_rod_motion_STOPPED.

CAUTION:

Control Rods should NOT be manually withdrawn during a plant transient.

CHECK for plant transient:

a. CHECK reactor power and T-avg STABLE.

3. CHECK for instrumentation malfunction:

a. CHECK nuclear instrumentation OPERABLE.

b. CHECK RCS RTDs OPERABLE.

Appendix D Scenario Outline Attachment I Op Test No.: NRC Scenario # 1 Event # 1 Page 2 of 49 Event

Description:

RC Loop #4 T-cold instrument fails high Time N Position Applicants Actions or Behavior (RNO Required)

RNO:

SRO

b. GO TO AOP-L02, RCS Loop RTD Instrument Malfunction.

SRO SRO may use or refer to AOP-l-02, RCS Loop RTD Instrument Malfunction, Section 2.0:

1. PLACE rod control in MANUAL.

CAUTION:

Control Rod should NOT be manually withdrawn durinq a rlant transient.

NOTE:

Tava must be witIn 1°F of Tref when restoring automatic rod control.

2. RESTORE Tavg as necessary USING one of the following:

. Manual rod control (normal method selected)

OR CREW . RCS boration OR

. Turbine load reduction RO 3. CHECK loop 1 temperature channel OPERABLE.

RO 4. CHECK loop 2 temperature channel OPERABLE.

RO 5. CHECK loop 3 temperature channel OPERABLE.

6. CHECK loop 4 temperature channel OPERABLE.

SRO/RO (RNO Required)

RNO; At SRO direction:

PERFORM the following:

a. PULL-TO-DEFEAT TAVG CHANNEL DEFEAT switch XS-68-2M to RO LOOP 4

b. PULL-TO-DEFEAT AT CHANNEL DEFEAT switch XS-68-2D to LOOP 4

c. PLACE LOOP TAVG-AT REC/SEL switch XS-68-2B in LOOP 1, 2, or 3

7. EVALUATE the following Tech Specs for applicability:

SRO

Appendix D Scenario Outline Attachment I Op Test No.: NRC Scenario # 1 Event # 1 Page 3 of 49 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position Applicants Actions or Behavior

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation Action 6 (From Table 3.3-1 Items 7 & 8) Applies Trip mop Bistables wli 6 H rs.

AND Action 10 (From Table 3.3-1 Item 14c) Applies within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Trip Time Delays (TS and TM) threshold power level for zero seconds time delay is adjusted to 0% RTP

. 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation Action 37 (From Table 3.3-3 Items 6.c.i.c & 6.c.ii.c) Applies within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected protection set, the Trip Time Delays (TS and TM) threshold power level for zero seconds time delay is adjusted to 0%

RTP.

NOTE: If performing AOP in conjunction with AOP-I.11 for an Eagle LOP failure,.. .[NIA for this event]

8. NOTIFY MIG to remove failed TAVG-tT loop from service USING appropriate Appendix:

INSTRUMENT RCS LOOP PROT APPENDIX LOOP NUMBER CH 1 T-68-2 I A SRO/ (T-4111412)

CREW 2 T-68-25 II B (T-421/422) 3 T-68-44 Ill C (T-431 /432) 4 T-68-67 IV D (T-4411442)

(Appendix D will apply)

9. IF automatic rod control is available, THEN SRO RESTORE rod control to AUTO USING 0-SO-85-1.

SRO 10. GO TO appropriate plant procedure.

Appendix D Scenario Outline Attachment I Op Test No.: NRC Scenario # 1 Event # 1 Page 4 of 49 Event

Description:

RC Loop #4 T-cold instrument fails high Time Position Applicants Actions or Behavior Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Technical Specifications are addressed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 5 of 49 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available:

. Annunciator XA-55-2A Window A-5 PIS-47-196 TURBINE SEAL STEAM PRESS. ABNORMAL

. Indicator 1-Pl-47-189 indicates 0 psig

. Indicator 1-PI-47-187 indicatesl50 psig Significant Resultant Alarms/Indications:

. Annunciator XA-55-2C Window C-6 PS-2-7B CONDENSER VACUUM LOW @2.7 psia increasing

. Recorderllndicator 1-P/TR-2-2 indicates condenser pressure trending up T + 10 BOP Respond in accordance with Alarm Response Procedures BOP refers to ARP A-5 PIS-47-196 TURBINE SEAL STEAM PRESS.

BOP ABNORMAL Corrective Actions:

[1] CHECK [1 -P1-47-187] on 1-M-2 to verify header pressure BOP (normallvexrected value: 125 rJsicl).

[2] IF header pressure low, THEN:

OPEN [1 -FCV-47-1 81] steam seal bypass to restore header BOP pressure USING 1-SO-2-9, Condenser Vacuum And Turbine Steam Seal System Operation to Bypass 1-PCV-47-183.

BOP identifies low/loss of high pressure sealing steam pressure on MCB indicators; manually controls HP Sealinci Steam usinci bvass PCV.

[3] IF header pressure is high...

BOP FThis step N/Al

[4] IF Header pressure is low...

BOP

[This step NIA1

[5] CHECK operation of PCV-47-183 HP Steam Seal.

BOP/CREW AUO dispatched for local inspection CREW [6] CHECK plant computer to determine which seal has abnormal pressure.

[7] DISPATCH operator to determine steam seal supply pressure to each CREW seal (on local indicator).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 6 of 49 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time N Position N Aoolicants Actions or Behavior

[8] ADJUST steam seal supply pressure...

BOP

[This step NIA]

BOP/CREW [9] MONITOR condenser vacuum.

Evaluator Note: SRO may decide to enter AOP-S.02, Loss of Condenser Vacuum to continue condenser vacuum restoration. Provided prompt action is implemented, this ARP provides adequate instruction to mitigate this event.

US US may use or refer to AOP-S.02, Loss of Condenser Vacuum, Section 2.0:

CAUTION: TurbIc will trip automatically when condenser pressure reaches 3.9 to 5.4 psia.

NOTE: Highest reading operable condenser pressure instrument should be used.

1. MONITOR condenser pressure for turbine trip criteria.

SOP

a. CHECK turbine load greater than or equal to 30%.

b. CHECK condenser pressure less than or equal to 2.7 psia.

BOP 2. ENSURE condenser vacuum oums RUNNING.

Evaluator Note: The standby Condenser Vacuum Pump will fail to start automatically; manual start is available and could be manually started in response to this event.

SOP 3. ENSURE condenser vacuum breaker CLOSED.

BOP 4. CHECK required CCW Pumps RUNNING [M-15].

SOP 5. CHECK turbine gland seal steam supply pressure between 120 psig and 130 psig [M-2, P1-47-187].

(RNO Required)

SOP RNO:

MAINTAIN turbine gland seal supply pressure between 120 and 130 psig USING PCV-47-181, HP Steam Seal Supply Bypass Isol.

BOP 6. CHECK HP steam seal steam supply between 16 psia and 20 psia [M-2, P1-47-189].

BOP 7. CHECK annunciator P15-47-i 96 TURBINE SEAL STEAM PRESS.

ABNORMAL,_DARK._[M-2A,_window A5].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 7 of 49 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time I Position Aoolicants Actions or Behavior BOPI

8. DISPATCH an operator to perform the following:

CREW

a. CHECK loop seal on vacuum breaker [Turbine BIdg, 706 elev}.

b. CHECK the following components:

. Main Turbine rupture discs intact

. Condenser shell intact

. Main Feedwater Pump rupture discs intact

. Main Turbine exhaust hoods

c. VERIFY Main Steam Dump Drain Tank level control operating properly.

BOP 9. CHECK condenser pressure STABLE or DROPPING.

RO 10. ENSURE control rods controlling in AUTO.

NOTE: Steam dumps will be unavailable due to loss of C-9 interlock if condenser pressure reaches approx. 2.9 3.4 psia.

BOP! 11. MONITOR annunciator C-9 CONDENSER INTERLOCK, LIT [M-4A, RO window E6].

BOP 12. DETERMINE volume of condenser inleakage USING the following plant computer points:

. F2700A

. F2263A

.__F2260A BOP 13. VERIFY inleakage value less than 45 cfm as indicated by both F2700A and F2263A.

BOP! 14. MONITOR condenser pressure USING the following computer points:

RO

P2270A

__P2271A BOP 15. CHECK condenser waterbox AP annunciator windows DARK [M-1 5A]:

. PdIS-27-95 CCW TO COND 1(2)A WEST SIDE DIFF PRESS HI [D-1j

. PdIS-27-74 CCW TO COND 1(2)B WEST SIDE DIFF PRESS HI [D-2J

. PdIS-27-54 CCW TO COND 1(2)C WEST SIDE DIFF PRESS HI [D-3)

. PdIS-27-104 CCW TO COND 1(2)A EAST SIDE DIFF PRESS HI [E-1]

. PdIS-27-83 CCW TO COND 1(2)B EAST SIDE DIFF PRESS HI [E-2]

. PdIS-27-65 CCW TO COND 1(2)C EAST SIDE_DIFF_PRESS_HI_[E-3]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 8 of 49 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time Position Alicants Actions or Behavior BOP/ 16. CHECK annunciator PdS-27-13B TRAV SCREEN lB DIFF PRESS HI, RO DARK. [M-15A, window A4].

BOP 17. CHECK annunciator TS-47-21 8, EXHAUST HOOD TEMPERATURE HIGH-VERY HIGH, DARK. [M-2A, window E5]

BOP 18. CHECK condenser water box AT less than or equal to 30°F USING the following computer points:

. T2430A, Cond A Inlet (West)

. T2431A, Cond A Inlet (East)

. T2434A, Cond B Inlet (West)

. T2435A, Cond B Inlet (East)

. T2438A, Cond C Inlet (West)

. T2439A, Cond C Inlet (East)

. T2432A, Cond A Outlet (West)

. T2433A, Cond A Outlet (East)

. T2436A, Cond B Outlet (West)

. T2437A, Cond B Outlet (East)

. T2440A, Cond C Outlet (West)

. T2441A, Cond C Outlet (East)

NOTE Condenser water box differential temperature is a turbine load dependent parameter. At low turbine loads, it may be less than 20° F.

BOP 19. CHECK condenser water box AT greater than 20°F USING computer points in previous step.

CREW 20. DISPATCH an operator to verify Seal Water level NORMAL (middle of siqht qlass) on the condenser vacuum pumps [Turbine Bldq, 662 elev.1

21. VERIFY condenser vacuum RESTORED TO NORMAL.

22. GO TO appropriate plant procedure.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 2 Page 9 of 49 Event

Description:

Gland Seal Steam Regulator, 1-PCV-47-183 fails closed Time U Position I Applicants Actions or Behavior Onertions Mment Typically Shift Manager.

iVI4iItfl -

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be deleqated to the Shift Manaqer).

Lead Examiner may cue next event when condenser vacuum has stabilized.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 10 of 49 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 Indications available:

Annunciator XA-55-6C Window B-4 FS-62-82 LOW PRESS LTDN FLOW HIGH PRESSURE HIGH

Indicator 1-FI-62-82 indicates 70-75 gpm [M-6]

Indicator 1-Pl-62-81 indicates pressure rising from 325 to 500-550 psig [M-6]

T = 20 Respond in accordance with Alarm Response Procedures CREW Diagnose failure and place 1-PCV62-81 in MANUAL RO Refer to Annunciator Response Procedure Evaluator Note: There are several notes in the alarm response that do not apply to this failure. The notes listed are the ones that do apply. There are several sections of procedure steps. ONLY the applicable steps are included below in this guide.

RO refers to ARP B-4 FS-62-82 LOW PRESS LTDN FLOW HIGH RO PRESSURE HIGH Corrective Actions:

RO [1] CHECK CRT SER point number to determine flow or pressure high.

[2] CHECK letdown flow [1-Fl-62-82] and letdown pressure [1 -P1-62-81] on RO M-6.

[3] IF RHR not in service, THEN ADJUST [1-PCV-62-81] USING [1-HIC RO 81A] and/or orifice isolation valves to control pressure and flow (Max. 120 gpm).

[7] IF Unit SRO deems it necessary, THEN

[a] REMOVE normal letdown from service in accordance withl-SO-62-1, SRO Chemical and Volume Control System.

[b] PLACE excess letdown in service in accordance with 1-SO-62-6, Excess_Letdown.

Appendix D Required Operator Actions Form ESD-2 OpTestNo.: NRC Scenario# 1 Event# 3 Page 11 of 49 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time Position Applicants Actions or Behavior

[8] RESTORE conditions to normal as soon as possible.

Evaluator Note: The CREW may decide to isolate Letdown and place Excess Letdown in service.

If normal letdown flowpath remains in service, PCV-62-81 will remain in manual control for the remainder of the scenario.

ROt 1 -SO-62-6, Excess Letdown Section 5.0 Startup/Standby Readiness CREW NOTE 1 When excess letdown is placed in service the containment radiation monitors may show some changes in particulate reading.

NOTE 2 Coordinate the following steps with AUO stationed at 0-L2 to monitor RCDT for pump operation as required during the 50 gallon flush.

RO [1] ENSURE [1-FCV-62-93] is in MANUAL and

[a] OPERATE [1-FCV-62-93] USING [1-HIC-62-93A] as required to regulate charging flow to keep pressurizer level on program.

[b} OPERATE [1-FCV-62-89] USING [1-HIC-62-89A] as required to maintain RCP seal flows in limits.

CREW [2] NOTIFY RADCON that Excess Letdown is being placed in service.

Evaluator Note: The following valves/indications in steps 3-5 are located on 0-M27B, CCS System Panel

[3] ENSURE [1 -FCV-70-1 43] CCS water to the excess letdown heat BOP exchanger is OPEN.

[4] ENSURE [1-FCV-70-85] Excess Letdown Heat Exchanger CCS flow BOP control valve is OPEN.

NOTE Step [5] will prevent subjecting the CVCS piping downstream of the Excess Letdown HX to a temperature above the design value.

BOP [51 ENSURE [1-FI-70-84] is indicating greater than 230 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event# 3 Page 12 of 49 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time I Position I Aoolicants Actions or Behavior RO [6] PLACE [1-FCV-62-59] Excess Letdown 3-way Divert Valve in DIVERT.

CAUTION FCV 62-63 has replaced RCP seal leak-off isolation valves as the primary means for isolating seal flow. The normal letdown path for excess letdown will not be available if FCV 62-63 is CLOSED.

NOTE Back flow through the RCP seals will occur should the RCP seal leakoff isolation valves fail to their OPEN position on loss of air or electrical power.

[7] IF less than 100 psig in RCS RO

[This step NIA]

RO [8] OPEN [1-FCV-62-54] Cold Leg Loop #3 Excess Letdown isolation valve.

RO [9] OPEN [1 -FCV-62-55] Excess Letdown containment isolation valve NOTE: ICS point 1 L2400A or the AUO stationed at 0-L-2 can be used to monitor RCDT for level increase during the 50 gallon flush. Reference the RCDT Level vs. Volume table in TI-28.

RO [10] OPEN [1-FCV-62-56] slowly to flush piping to RCDT.

[11] WHEN approximately 50 gallons have flushed, THEN CLOSE [1-FCV-RO 62-56], Excess Letdown Flow Control Valve.

(Designed flowrate is 20-25 gpm; flush time should be 2-3 minutes.)

RO [12] PLACE [1-FCV-62-59] Excess Letdown 3-way Divert Valve in NORMAL.

NOTE 1 Normally the temperature read on 1-TI-62-58 should be less than 200°F. If operation requires temperatures greater than 200°F, the pressure at 1-PI-62-64 (local indicator El. 690 Pnl L-46) should be less than 100 psig to protect the Grinnell valves.

NOTE 2 Operation above 200°F will require that Systems Engineering be notified to allow an evaluation of the need for valve maintenance.

[13] OPEN [1-FCV-62-56] slowly to increase excess letdown flow to desired RO amount, not to exceed 240° F heat exchanger outlet temperature, as indicated on 1-TI-62-58.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 13 of 49 Event

Description:

CVCS Letdown Pressure Control Valve Fails Closed (1-PCV-62-81)

Time Position Applicants Actions or Behavior NOTE: Placing Excess Letdown in service causes increased activity in various areas of the Auxiliary Building.

RO [14] NOTIFY RADCON that Excess Letdown has been placed in service.

Evaluator Note: Due to reduced letdown flow, 20-25 gpm, reduced manual charging flow is required; expected flow rate 40-50 gpm to retard Pzr fill rate.

Annunciator 1-XA-55-6C, D-3, FS-62-93A1B CHARGING LINE FLOW ABNORMAL is an expected continuous alarm condition (setpoint: 55 gpm;).

The RO should re-establish/maintain 6-10 gpm/RCP stable supply flow conditions.

Annunciators 1-XA-55-5B, A-3, B-3, 0-3, D-3 FS-62-XX REAC COOL PMPS SEAL LEAKOFF LOW FLOW may be actuated during transient conditions; operator response is to clear the condition.

Establishes/maintains reduced charging flow rate jaw 1-SO-62-1, Chemical RO and Volume Control System and 0-GO-i 4, MCR Rounds Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when charging flow is controlled.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4, 5 Page 14 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time I Position I Aoolicants Actions or Behaor Booth Instructor: When directed, initiate Event 4, 5 Indications available:

. 0-M-12A, C-2, 1-RA-90-119B COND VAC PMP LO RNG AIR EXH MON INSTR MALFUNC

. 1-AR-M2-C, C6, CONDENSER VACUUM LOW

. Condenser Vacuum degrading (Monitored on recorder or ICS), Air in leakage increasing CREW Refer to alarm response procedure T = 30 Evaluator Note: CREW may recognize vacuum leak early and enter abnormal procedure AOP-S.02, Loss Of Conder ser Vacuum, prior to alarm.

BOP VERIFY alarm via [1-PITR-2-2] recorder.

BOP VERIFY required number of CCW pumps are in service.

CHECK condenser vacuum exhaust on ICS using either:

BOP a. 1 F2700A if 1-FCV-2-255 is closed

b. 1F2263A if 1-FCV-2-255 is open.

BOP IF condenser vacuum exhaust flow> 45 CFM, THEN ENSURE 1-FCV-2-255 OPEN.

BOP IF alarm is valid, THEN GO TO AOP-S.02, Loss of Condenser Vacuum.

SRO Directs entry into AOP-S.02 NOTE: Use of the highest reading operable condenser pressure instrument is conservative and recommended by engineering.

MONITOR condenser pressure for turbine trip criteria.

. CHECK turbine load greater than or equal to 30%.

(MT Low Condenser Vacuum Trip @ 3.9 psia increasing)

Appendix D - Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4, 5 Page 15 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time N Position N Aoolicants Actions or Behavior CHECK condenser pressure less than or equal to 2.7 psia.

(1-AR-M2-C, C-6, CONDENSER VACUUM LOW 2.7 psa increasinq.)

ENSURE condenser vacuum pumps RUNNING.

BOP (Stby 1 B Condenser Vacuum Pump fails to start automatically @ 2.1 psia; BOP manually starts 1 B CVP.)

ENSURE condenser vacuum breaker CLOSED.

CHECK required CCW Pumps RUNNING FM-i 51.

1. MONITOR condenser pressure for turbine trip criteria.

BOP

a. CHECK turbine load greater than or equal to 30%.

b. CHECK condenser pressure less than or equal to 2.7 psia.

2. ENSURE condenser vacuum pumps RUNNING.

BOP (BOP manually starts 1 B CVP if not started previously.)

BOP 3. ENSURE condenser vacuum breaker CLOSED.

Evaluator Note: During the course of the power reduction, Lead Evaluator will initiate the MT Vibration condition. MT Vibration Event Guide is included at the end of AOP-C.03 Event Guide Evaluator Note: The standby Condenser Vacuum Pump will fail to start automatically; manual start is available and should be manually started in response to this event.

BOP 5. CHECK turbine gland seal steam supply pressure between 120 psig and 130 psig [M-2, P1-47-187].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4, 5 Page 16 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time Position 1 Aoolicants Actions or Behavior Evaluator Note: BOP is manually controlling Gland Seal Steam from previous malfunction.

BOP RNO: (from Event 1)

MAINTAIN turbine gland seal supply pressure between 120 and 130 psig USING PCV-47-181, HP Steam Seal Supply Bypass Isol.

BOP 6. CHECK HP steam seal steam supply between 16 psia and 20 psia [M-2, P1-47-189].

BOP 7. CHECK annunciator PIS-47-196 TURBINE SEAL STEAM PRESS.

ABNORMAL, DARK. [M-2A, window A5].

BOP/

8. DISPATCH an operator to perform the following:

CREW

a. CHECK loop seal on vacuum breaker [Turbine Bldg, 706 elev].

b. CHECK the following components:

. Main Turbine rupture discs intact

. Condenser shell intact a Main Feedwater Pump rupture discs intact

. Main Turbine exhaust hoods

c. VERIFY Main Steam Dump Drain Tank level control operating properly.

BOP 9. CHECK condenser pressure STABLE or DROPPING.

(RNO Required)

BOP RNO:

REDUCE turbine load as necessary to maintain condenser vacuum USING one of the following:

. AOP-C.03, Rapid Shutdown or Load Reduction (preferred)

OR

.__Valve_Position_Limiter.

Evaluator Note: AOP-C.03, Rapid Shutdown or Load Reduction event guide is included at the end of this event.

Appendix D - Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4. 5 Page 17 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time 0 Position N Aoplicants Actions or Behavior Evaluator Note: SRO should decide to implement AOP-C.03, Rapid Shutdown or Load Reduction and initiate a load reduction specifying a rate and reduced power level (include a reactivity brief using AOP-C.03 Appx E, reactivity Management Briefing).

Plant power reduction will be adequate along with the standby vacuum pump capacity to stabilize condenser vacuum adequately to stop the power reduction.

RO 10. ENSURE control rods controlling in AUTO.

NOTE: Steam dumps will be unavailable due to loss of C-9 interlock if condenser pressure reaches approx. 2.9 3.4 psia.

BOP/ 11. MONITOR annunciator 0-9 CONDENSER INTERLOCK, LIT [M-4A, RO window E-6}.

BOP 12. DETERMINE volume of condenser inleakage USING the following plant computer points:

. F2700A

. F2263A

. F2260A BOP 13. VERIFY inleakage value less than 45 cfm as indicated by both F2700A and F2263A.

BOP! 14. MONITOR condenser pressure USING the following computer points:

RO

P2270A

.__P2271A BOP 15. CHECK condenser waterbox AP annunciator windows DARK [M-1 5AJ:

. PdIS-27-95 CCW TO COND 1(2)A WEST SIDE DIFF PRESS HI [D-1]

. PdIS-27-74 CCW TO COND 1(2)B WEST SIDE DIFF PRESS HI [D-2]

. PdIS-27-54 CCW TO COND 1(2)C WEST SIDE DIFF PRESS HI [D-3]

. PdIS-27-104 CCW TO COND 1(2)A EAST SIDE DIFF PRESS HI [E-1j

. PdIS-27-83 CCW TO COND 1(2)B EAST SIDE DIFF PRESS HI [E-2]

. PdIS-27-65 CCW TO COND 1(2)C EAST_SIDE_DIFF_PRESS_HI_[E-3]

Appendix D - Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 4,5 Page 18 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time Position Applicants Actions or Behavior BOP/ 16. CHECK annunciator PdS-27-13B TRAV SCREEN lB DIFF PRESS HI, RO DARK. [M-15A, window A4].

BOP 17. CHECK annunciator TS-47-218, EXHAUST HOOD TEMPERATURE HIGH-VERY HIGH, DARK. [M-2A, window E5]

BOP 18. CHECK condenser water box AT less than or equal to 30°F USING the following computer points:

. T2430A, Cond A Inlet (West)

. T2431A, Cond A Inlet (East)

. T2434A, Cond B Inlet (West)

. T2435A, Cond B Inlet (East)

. T2438A, Cond C Inlet (West)

. T2439A, Cond C Inlet (East)

. T2432A, Cond A Outlet (West)

. T2433A, Cond A Outlet (East)

. T2436A, Cond B Outlet (West)

. T2437A, Cond B Outlet (East)

. T2440A, Cond C Outlet (West)

. T2441A, Cond C Outlet (East)

NOTE Condenser water box differential temperature is a turbine load dependent parameter. At low turbine loads it may be less than 20° F.

BOP 19. CHECK condenser water box AT greater than 20°F USING computer points in previous step.

CREW 20. DISPATCH an operator to verify Seal Water level NORMAL (middle of sight glass) on the condenser vacuum pumps [Turbine Bldg, 662 elev.]

SRO 21. VERIFY condenser vacuum RESTORED TO NORMAL.

SRO 22. GO TO appropriate plant procedure.

Evaluator Note: AOP-C.03, Rapid Shutdown or Load Reduction from AOP-S.02, Loss of Condenser Vacuum step 9 RNO:

Evaluator Note: During the course of the power reduction, Lead Evaluator will initiate the MT Vibration condition. MT Vibration Event Guide is included at the end of AOP-C.03 Event Guide

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4. 5 Page 19 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure / MT Rapid Load Reduction due to Condenser Vacuum Leak Time I Position I ADDlicants Actions or Behavior SRO 1. ENSURE CREW has been briefed on reactivity management expectations USING Appendix E.

(SRO determines plant power reduction rate. According to AOP-C.03, that rate may be 1-4%/minute; and may be varied during the power reduction/shutdown based on SRO determination/direction.)

C

2. NOTIFY following personnel of rapid shutdown or load reduction:

CREW

Load Coordinator

Chemistry

RADCON

Plant Management CREW 3. MONITOR reactor/turbine trip NOT required USING Appendix A, Reactor and Turbine Trip Criteria.

BOP 4. CHECK VALVE POSITION LIMIT light DARK on EHC panel. [M-2]

NOTE: BAT is preferred boration source. Boration volume and flowrates listed in following step are recommendations and may be adjusted as necessary.

RO 5. IF borating from BAT, THEN PERFORM the following:

a. DETERMINE recommended boration volume:

800 gal to reduce power from 100% to 20%

OR

10 gal for each 1% power reduction OR

volume recommended by Reactor Engineering

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4. 5 Page 20 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure / MT Rapid Load Reduction due to Condenser Vacuum Leak Time D Position - Applicants Actions or Behavior RO/ b. DETERMINE recommended boration flowrate from table below or from SRO Reactor Engineering:

TURBINE LOAD REDUCTION RATE BORATION

(%Imin) FLOWRATE 1% 15 gpm 2% 30 gpm 3% 45 gpm 4% 70 gpm SRO c. ENSURE concurrence obtained from US and STA for boration volume and flowrate.

RO d. PLACE boric acid transfer pump aligned to blender in FAST speed.

RO e. ADJUST FCV-62-138 to establish desired flow rate.

RO g. GOTOStep7.

SRO 7. INITIATE load reduction as follows:

BOP a. ADJUST load rate to desired value:

between 1% and 4% per minute if borating via FCV-62-138 OR

between 1% and 3% per minute if borating via normal boration (App. D)

OR

2% or 3% per minute if borating from RWST.

BOP b. ADJUST setter for desired power level:

DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE 90% 76 80% 56 70% 46 60% 40 50% 35 40% 30 30% 25 20% or less 15

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # I Event # 4, 5 Page 21 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure / MT Rapid Load Reduction due to Condenser Vacuum Leak Time 1 Position N Aoolicants Actions or Behavior BOP c. INITIATE turbine load reduction by depressing GO pushbutton.

SRO/ d. CONTROL turbine load reduction as necessary to reduce power to BOP desired level.

RO 8. MONITOR T-avglT-ref mismatch:

a. CHECK T-ref indication AVAILABLE.

b. MONITOR automatic rod control maintaining T-avglT-ref mismatch less than 3°F.

BOP 9. MONITOR automatic control of MEW pump speed AVAILABLE.

BOP 10. STOP secondary plant equipment USING Appendix B, Secondary Plant Equipment.

NOTE: If LEFM thermal power (U2118) is inoperable, rod insertion limit curve must be raised by 3 steps. Rod insertion limit alarms and ICS display are NOT automatically adjusted when LEFM is inoperable.

RO 1 1. MONITOR control rods above low-low insertion limit USING ICS or COLR.

NOTE: Initiating plant shutdown required by Tech Specs requires 4-hour NRC notification per SPP 3.5, Regulatory Reporting Requirements.

SRO 12. EVALUATE Tech Specs/TRM for applicability:

. 3.2.1, Axial Elux Difference

. 3.1.1.1, Shutdown Margin

. 3.1.3.6, Rod Insertion Limits

.__TRM_3.1.2.2,_Boration_Flowpaths

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4. 5 Page 22 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure / MT Rapid Load Reduction due to Condenser Vacuum Leak Time Position D Arnlicants Actions or Behavior SRO 13. EVALUATE EPIP-1, Emergency Plan Initiating Conditions Matrix.

RO 14. PERFORM the following to reduce boron concentration difference between Pzr and RCS loops:

RO a. CHECK at least one normal spray valve AVAI LABLE.

RO b. ENSURE at least one backup heater group ENERGIZED.

RO c. ENSURE spray valve(s) responds to control RCS pressure.

CREW 15. WHEN reactor power change exceeds 15% within one hour, THEN NOTIFY Chemistry to initiate sampling as required by 0-SI-CEM-000-050.0, 0-SI-CEM-030-407.2 and 0-SI-CEM-030-41 5.0.

CREW 16. MONITOR if turbine load reduction can be stopped:

SRO a. CHECK the following conditions met:

. reactor shutdown is NOT needed

. turbine shutdown is NOT needed I turbine load at desired power level (further load reduction NOT needed)

BOP b. STOP turbine load reduction by depressing HOLD.

RO c. WHEN control rods are above the low-low insertion limit, THEN STOP boration flow.

CREW d. NOTIFY Chem Lab to sample RCS for boron concentration.

e. T-avg within 3°F of T-ref USING one of the following:

. AUTO or MANUAL rod control

. dilution or boration USING 0-SO-62-7.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4, 5 Page 23 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure / MT Rapid Load Reduction due to Condenser Vacuum Leak Time Position Applicants Actions or Behavior RO f. CHECK reactor power greater than 50%.

RO! g. DETERMINE Tech Spec AFD limits for current power level USING SRO ICS (Primary Mimics, Doghouse Display) or COLR.

RO h. CHECK AFD within Tech Spec limits on at least three operable power range NIS channels.

RO/ I. IF AFD is outside target band, THEN INITIATE 0-SI-NUC-000-SRO 044.0,Axial Flux Difference.

SRO J. INITIATE performance of 0-Sl-OPS-092-078.0, Power Range Neutron Flux Channel Calibration By Heat Balance Comparison.

BOP k. CHECK C-7 LOSS OF LOAD INTERLOCK [M-4A window E-5] DARK.

NOTE: Time in core life, expected Xenon changes, and planned power changes should be considered when evaluating need for boration or dilution.

SRO L. CONSULT Reactor Engineering and STA regarding Al control and compensating for Xe changes.

SRO/ m. PERFORM the following as necessary to control Al and maintain T RO avg on program:

. INITIATE boration or dilution as necessary USING 0-SO-62-7, Boron Concentration Control OR

. OPERATE control rods as necessary.

RO n. CHECK at least one normal Pzr spray valve OPERABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4, 5 Page 24 of 49 Event

Description:

Loss of Condenser Vacuum wI Cond Vac Pp auto start failure I MT Rapid Load Reduction due to Condenser Vacuum Leak Time Position Applicants Actions or Behavior SRO o. DETERMINE appropriate procedure based upon power level and cause of rapid shutdown:

. Other applicable AOP OR

. 0-GO-5, Normal Power Operation (if greater than approximately 30% power)

OR

. 0-GO-4, Power Ascension from Less than 5% to 30% Power (if less than approximately 30%)

SRO p. GO TO appropriate plant instruction.

Evaluator Note: SRO/CREW may conduct a brief at this time and should return/insure actions of AOP S.02, Loss of Condenser Vacuum are completed.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Ojjerations Manacement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Evaluator Note: During the course of the power reduction, Lead Evaluator will initiate the MT Vibration condition. MT Vibration Event Guide is included at the end of AOP-C.03 Event Guide Lead Examiner may cue next event when the CREW has stabilized plant power and condenser vacu urn.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # I Event # 6, 7 Page 25 of 49 Event

Description:

Turbine High Vibration (14 mills sustained- no trip required) / #4 MT Stop Valve indication loss Time I Position I Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 6, 7 Indications available:

. 1-AR-M2A D-4, VA-47-120 TURBINE HIGH VIBRATION indicates >7 mils

. 1-M-11-XR-47-2, Main Turbine Vibration Recorder indicates elevated vibration on #s I & 2 bearings (9-IO mils).

CREW Refer to alarm response procedures and carries the following actions:

T =45 NOTE: Vendor recommends turbine trip at 14 mils.

[1] MONITOR recorder [1-XR-47-2] to determine which bearing has possible BOP vibration problems and establish trend.

CAUTION: Dispatching personnel locally could place personnel in serious danger if a catastrophic turbine failure occurs. Local verification should NOT be performed when adequate MCR indications exist.

[2] IF bearing vibration 14 mils AND any of the following conditions are met:

. High vibration is present on multiple bearings OR

. Abnormal noise or vibration locally or from MCR.

THEN PERFORM the following:

[a] IF reactor power is above 50%,

THEN TRIP the reactor and GO TO E-0.

[b] IF reactor power is less than 50%.

THEN TRIP the turbine AND GO TO AOP-S.06.

Evaluator Note: SRO/CREW determines vibration is stabilizing at 10 mils, should decide not to trip the Reactor/Main Turbine; continues in current ARP.

BOP/ [3] DISPATCH operator to sound out turbine to verify alarm and 1-XR-47-2 indications.

CREW

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6, 7 Page 26 of 49 Event

Description:

Turbine High Vibration (14 mills sustained- no trip required)! #4 MT Stop Valve indication loss Time Position Applicants Actions or Behavior BOP [4] CHECK the following conditions for potential root cause.

a. Oil temperature.

b. Critical speed.

c. Sealing steam pressure.

d. Condenser vacuum.

e. Exhaust shell temperature.

. CREW [5] CORRECT parameter values within applicable plant procedures limits.

[6] IF vibration remains high (greater than setpoint 7 mils),

THEN CONSULT with SRO/SM SRO AND EVALUATE starting unit shutdown BOP [a] DETERMINE rate of rise if possible CREW [b] CONTACT System Predictive Maintenance and System Engineer.

[7] IF vibration remains high >7 mills, THEN CONSULT with SRO/SM, SRO AND EVALUATE starting unit shutdown.

Lead Examiner: After ARP 1 -AR-M2A D-4 is performed to this point (i.e.: vibration magnitude stabilized at

-1 0 mils), initiate EVENT 7, #4 MT Stop Valve indication loss (RPS input)

Evaluator Note: Annunciator 1-XX-55-6B E-5; its ARP directs entry into AOP-I.07, Turbine Auto Stop Oil Pressure Instrument or Turbine Stop Valve Limit Switch Malfunction; Sections 2.0 & 2.2 apply to address the indication failure which is included at the end of this event guide.

[8] IF vibration continues to increase, THEN CONSULT SM, AND EVALUATE tripping the turbine prior to exceeding 14 mils verified vibration USING the guidance provided in Step 2.

[This step currently NIA]

[9] IF reactor trip, THEN GO TO E-0, Reactor Trip or Safety Injection.

[This step currently NIA]

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6, 7 Page 27 of 49 Event

Description:

Turbine High Vibration (14 mills sustained- no trip required)! #4 MT Stop Valve indication loss Time Position Applicants Actions or Behavior

[10] IF turbine trips and no reactor trip, THEN GO TO AOP-S.06, Turbine Trip.

[This step NIA; reactor power >P-9, 49% RTP]

Booth Instructor: When directed, initiate Event, 7 Indications available:

. 1-XA-55-6B E-5, TURBINE STEAMLINE STOP VALVES CLOSED

. 1-XX-55-6A Trip Status Light TURB STOP VLV 4 CLOSED CREW Refer to alarm response procedures and carries out the following actions:

NOTE* If failure of main turbine throttle valve bistable is suspected, refer to Tech Spec L.C.O.

3.3.1.1, table 3.3:-i, item 18B.

BOP [1] CHECK turbine throttle valves position on turbine EH control panel, M-2.

BOP/ [2] IF all four stop valves closed and below 50% power, THEN GO TO AOP CREW S.06, Turbine Trip.

[3] IF all four stop valves closed and above 50% power, THEN ENSURE SRO reactor trip, AND GO TO E-0, Reactor Trip or Safety Injection.

[4] IF any turbine stop valve status light is lit AND the valve is OPEN, OR RO/ status light is NOT lit with valve CLOSED, THEN GO TO AOP-l.07, Turbine Auto Stop Oil Pressure Instrument or SRO Turbine Stop Valve Limit Switch Malfunction.

Transitions to AOP-I.07, Turbine Auto Stop Oil Pressure Instrument or SRO Turbine Stop Valve Limit Switch Malfunction.

AOP-I.07, Section 2.0:

1. EVALUATE the following Tech Specs for applicability:

SRO

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation TS Action 7 (From Table 3.3-1 Item 18.b) Applies Trip inoperable channel w/i 6 Evaluation hrs. or THERMAL: POWER is reduced to less than P-9 w/i 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months SRO 2. IF Turbine auto stop oil...

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6, 7 Page 28 of 49 Event

Description:

Turbine High Vibration (1 4 mills sustained- no trip required) I #4 MT Stop Valve indication loss Time Position Applicants Actions or Behavior

[This step N/A]

3. IF Turbine stop valve limit switch has malfunctioned, SRO THEN GO TO Section 2.2.

SRO, RO determines MT SV FCV-1-70 is the affected indication, decides to SRO enter Section 2.2 Section 2.2 Turbine Stop Valve Limit Switch Malfunction:

NOTE: Computer points require a prefix 0, 1, or 2 be placed in front of the point number; for example, 2Y0391 D. Parenthetical points are for Unit 2.

1. DETERMINE affected channel USING either of the following:

RO/ Trip status lights [XX-55-6A]

SRO OR Computer Points:

PLANT CRT SER TURBINE STOP PROT COMPUTER POINT VALVE CH POINT NUMBER NUMBER FCV-1-61 Y0391D 518 (518)

FCV-1 -64 II Y0392D 552 (726)

FCV-1 -67 III Y0393D 553 (727)

FCV-1 -70 IV Y0394D 557 (728)

2. NOTIFY MIG to remove failed stop valve limit switch from service SRO/

CREW USING appropriate Appendix::

TURBINE STOP PROT VALVE CH APPENDIX FCV-1 -61 D FCV-1 -64 II E FCV-1 -67 III F FCV-1 -70 IV G SRO/CREW Determines MT SV FCV-1-70 is the affected valve indication SRO 3. GO TO appropriate plant procedure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6, 7 Page 29 of 49 Event

Description:

Turbine High Vibration (14 mills sustained- no trip required) / #4 MT Stop Valve indication loss Time Position Applicants Actions or Behavior Determines 1-AR-M2A D-4, Step 8 is correct procedure, step in effect and SRO returns to complete ARP.

LEAD EXAMINER may cue next event once TS evaluation is complete in AOP-107.

Appendix D Required Operator Actions Form ES-D-2 Op Test No: NRC Scenario # 1 Event # 8, 9, 10 Page 30 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event, 8 Indications available:

. 1-AR-M2A 0-4, VA-47-120 TURBINE HIGH VIBRATION

. 1-M-11-XR-47-2, Main Turbine Vibration Recorder Evaluator Note: the turbine vibration severity will increase (>14 mils) resulting in a turbine trip demand condition as described in ARP. Annunciator 1-AR-M2A D-4, VA-47-120 TURBINE HIGH VIBRATION has NO reflash function; the increased vibration condition will be identified by operator control board monitoring and/or AUO local observation providing feedback to the MCR crew.

The crew will manually trip the reactor.

[8] IF vibration continues to increase, T-50 THEN CONSULT SM, SRO AND EVALUATE tripping the turbine prior to exceeding 14 mils verified vibration USING the guidance provided in Step 2.

[9] IF reactor trip, SRO THEN GO TO E-O, Reactor Trip or Safety Injection.

SRO Direct Manual Rx Trip SRO Enter and Direct Immediate Operator Actions (lOAs) of E-O Evaluator Note: following IOA performance, prior to Steps 1-4 immediate action verification, RO/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

E-O, Reactor Trip or Safety Injection Note I Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page

1. VERIFY reactor TRIPPED:

RO

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 8,9,10 Page 31 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior

. Neutron flux DROPPING

. Rod bottom lights LIT

. Rod position indicators less than or eaual to 12 steps.

2. VERIFY turbine TRIPPED:

BOP . Turbine stop valves CLOSED.

3. VERIFY at least one train of shutdown boards ENERGIZED.

. Attempt to restore power to at least ONE train of shutdown boards BOP . Place DG lA-A control switch in START

. Verify Train A Shutdown Boards ENERGIZED

4. DETERMINE if SI actuated:

. ECCS pumps RUNNING.

RO

. Any SI alarm LIT [M-4D] (SI will be actuated)

(RNO Required)

RNO:

DETERMINE if SI required:

a. IF any of the following conditions exists:

. S/G pressure less than 600 psig, RO OR

. RCS pressure less than 1870 psig, OR

. Containment pressure greater than 1.5 psig, THEN ACTUATE SI.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8. 9, 10 Page 32 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior

b. IF SI is NOT required, THEN SRO PERFORM the following:

1) MONITOR status trees.

2) GO TO ES-0.1, Reactor Trip Response.

SRO determines SI not required; SRO SRO implements status tree monitoring and transitions to ES-0.1, Reactor Trio Response.

ES-O.1, Reactor Trip Response Evaluator Note: Event 9, Lp #1 SG Atmospheric Relief Valve sticks open shortly after the reactor trip resulting in SI actuation conditions; the crew should re-enter E-0 from ES-0.1. Expected indications and operator actions contained at end of this guide.

Evaluator Note: Event 10, MFW Isolation Fails to Auto Actuate will manifest itself during Event 9 cooldown and subsequent SI actuation. Identification and corrective action may occur during E-0 re-entry.

Note: This procedure has a foldout page.

1. MONITOR SI NOT actuated:

RO

. SI ACTUATED permissive DARK[M-4A. D41 BOP 2. VERIFY generator breakers OPEN.

3. MONITOR RCS temperatures:

. IF any RCP running, THEN CHECK T-avg stable at or trending to between 547°F and 552°F.

RO OR

. IF RCPs stopped, THEN CHECK T-cold_stable_at_or trending_to_between_547° F_and_552° F.

Appendix D Reciuired Ooerator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 33 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Aoolicants Actions or Behavior

4. CHECK feedwater status:

BOP a. T-avg less than 550° F.

b. MEW pumps TRIPPED.

c. MEW regulating valves CLOSED.

d. MEW regulating bypass valve controller outputs ZERO.

e. MEW isolation valves CLOSED.

BOP 5. CHECK total feed flow to S/Gs greater than 440 gpm.

6. CHECK if emergency boration is required:

a. VERIFY all control rods fully inserted:

RO . Rod bottom lights LIT

. Rod position indicators less than or equal to 12 steps.

b. MONITOR RCS temperature:

. T-avg greater than 540° F if any RCP running OR

. T-cold cireater than 540°F if all RCPs stopped.

CREW 7. ANNOUNCE reactor trip USING PA system.

8. MONITOR pressurizer level control:

RO a. CHECK pressurizer level greater than 17%.

b. CHECK non-essential control air established to containment:

. Unit 1 Only:

RO 1-FCV-32-110 OPEN. [PnI 6K]

Unit 2 Only:

2-FCV-32-1 1 1 OPEN. [Pnl 6L}

RO c. VERIFY charging IN SERVICE.

RO d. VERIFY letdown IN SERVICE.

e. CHECK pressurizer level trending to 25% (normal range 20% to RO 30%).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 34 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior RO 9. MONITOR pressurizer pressure control:

a. Pressurizer pressure greater than 1870 psig.

b. Pressurizer pressure stable at or trending to 2235 psig (normal range 2210 psiq to 2260 psici).

BOP 10. MAINTAIN SIG narrow range levels:

a. Greater than 10%.

b. Between 10% and 50%.

Bop 11. VERIFY AC busses ENERGIZED from start busses.

CAUTION Arming steam dumps in pressure mode with demand signal present could result in rapid RCS cooldown.

BOP 12. DETERMINE if steam dump to condenser available:

a. CHECK condenser AVAILABLE:

. C-9 CONDENSER INTERLOCK permissive LIT [M-4A, E6]

. At least one Intact S/G MSIV OPEN.

b. PLACE steam dumps in STEAM PRESS mode:

1) PLACE steam dumps in OFF.

2) ENSURE steam dumps in steam pressure mode.

3) ENSURE zero output (demand).

4) PLACE steam dumps in ON.

5) ENSURE steam dump controller setpoint at 1005 psig.

6) ADJUST steam dump controller as necessary to maintain SIG pressure_at_approx._1005_øsici.

Appendix D Required Operator Acfions Form ES-D-2 Op Test No.: NRC Scenario # I Event # 8, 9, 10 Page 35 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time ft Position L Applicants Actions or Behavior NOTE Loop 2 RCP and associated spray valve will provide adequate spray flow for RCS pressure control. If Loop 2 is not available, all three remaining RCPs may be required to ensure adequate spray flow.

13. CHECK RCP #2 RUNNING.

RO

14. MONITOR if source range channels should be reinstated:

RO

a. CHECK intermediate range flux less than 10- 4 % power on operable channels.

b. CHECK source range channels REINSTATED.

c. ENSURE at least one SRM and IRM displayed on NR-45 recorder.

d. ENSURE audio count rate operation.

e. RESET shutdown monitor alarm setpoints. [M-13]

f. WHEN shutdown monitor ALARM LEDs dark AND HIGH FLUX AT SHUTDOWN bistable lights dark, THEN PLACE HIGH FLUX AT SHUTDOWN alarm block switches in NORMAL._[M-13]

15. SHUT DOWN unnecessary plant equipment:

BOP

REFER TO 0-GO-12, Realignment Of Secondary Equipment Following_Reactor/Turbine_Trip.

CREW 16. MAINTAIN stable plant conditions:

a. Pressurizer pressure at 2235 psig (normal range 2210 psig to 2260 psig)

b. Pressurizer level at 25% (normal range 20% to 30%)

c. S/G narrow range levels between 10% and 50%

d. RCS temperature at 547°F (between 540°F and 550°F):

T-avg if any RCP running OR

__T-cold_if_all_RCPs_stopped.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 36 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position 1 Applicants Actions or Behavior

17. PERFORM EA-0-9, Post Trip Administrative Requirements and Recovery Actions.

RO/SRO 18. DETERMINE if natural circulation cooldown is required:

a. CHECK at least one RCP RUNNING.

b. CHECK at least one AFW pump AVAILABLE.

c. SELECT appropriate procedure:

. 0-GO-6, Power Reduction from 30% Reactor Power to Hot Standby (if maintaining hot standby)

OR

. 0-GO-7, Unit Shutdown from Hot Standby to Cold Shutdown OR

. other appropriate procedure as determined by Shift Manager or TSC_(if_manned).

SRO d. GO TO appropriate plant procedure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8,9, 10 Page 37 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior E-0, Reactor Trip or Safety Injection Indications available:

1-M-1:

. 1-M-11-XR-47-2, Main Turbine Vibration Recorder indicating >15 mils for #s I & 2 bearings 1-M-4:

. Lp #1 SG Atm Relief Valve indicates open

. 1-Xl-94-1 01/1 02, Core Exit Temp Margin to Saturation (exo sensors Tm A & B) pressure indications trending to SI actuation pressure value.

I -M-5:

. 1-Pl-68-340A, 1-Pl-68-334, 1-Pl-68-323, 1-Pl-68-322, RCS PZR PRESS narrow range indicators trending to actuation pressure value.

. 1-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS indicator trending to actuation pressure value.

. Loop I TAVG indicator 1-Tl-68-2E indicates lower temperature than adjacent Loops 2, 3, 4.

. 1-Tl-68-18, Loop I RCS CL Temp and 1-Tl-68-1, Loop I RCS HL Temp (WR indicators) shows a larger zT than adjacent Loops 2, 3, 4 indicators.

. 1-TR-68-1, HL-CL TEMP recorder indicates excessive cooldown compared to adjacent Loops 2, 3, 4 recorders.

I -M-6:

. 1-PI-68-66A, HL Pressure LOOP 3 indicator trending to actuation pressure value.

. 1-PI-68-62, RCS HL Press WR indicator trending to actuation pressure value.

. 1-Pl-68-69, RCS HL Press WR indicator trending to actuation pressure value.

Evaluator Note: Crew performs high-level actions only for steps 1-4 on re-entry at this time.

Note I Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page RO 1. VERIFY reactor TRIPPED:

BOP 2. VERIFY turbine TRIPPED:

BOP 3. VERIFY at least one train of shutdown boards ENERGIZED.

4. DETERMINE if SI actuated:

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 38 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position J Applicants Actions or Behavior Evaluator Note: Critical Task is manually actuate Feedwater Isolation, ES-0.5 Step 8, VERIFY MFW Isolation.

(If recognized, may be completed during Prudent Operator Actions (POAs) following completion of E-0 Immediate Operator Actions (IOAs).

(ES-0.5 directs completion by BOP during performance.)

Evaluator Note: Critical Task to manually isolate ALL Auxiliary Feedwater Flow within 10 minutes after a steamline break:

Isolation Time Maif. Init time: AFW isolation time:

Time:

(If recognized, may be completed during Prudent Operator Actions (POAs) following completion of E-0 Immediate Operator Actions (lOAs).

(Normally be completed by BOP during POA5.)

Evaluator Note: [(Actions for ES-0.5 are contained in attachment at back of scenario guide)]

5. PERFORM ES-0.5, Equipment Verifications WHILE continuing in this BOP procedure.

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level greater than 10% [25 ADV] in at least one SIG.

RO

c. CONTROL feed flow to maintain narrow range level between 10%

[25% ADVI and 50% in all SIG5.

(Heat Sink is available from AFW:>440 gpm available.)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 39 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

. Any SIG pressure less than 600 psig AND STEAMLINE PRESS ISOL SI BLOCK RATE ISOL ENABLE permissive DARK [M-4A, A4]

OR

Any S/G pressure dropping UNCONTROLLED.

RO OR

Phase B actuation

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

8. CHECK RCP trip criteria:

a. CHECK the following:

RCS pressure less than 1250 psig.

RO AND

At least one CCP OR SI pump RUNNING

b. STOP RCPs

Appendix D Required Operator Actions Form ES-D2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 40 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior

9. MONITOR RCS temperatures:

. IF any RCP running, THEN CHECK T-avg stable at or trending between 547 degrees F and 552 RO degrees F.

OR IF RCPs stopped, THEN CHECK T-cold stable or trendina to between 547°F and 552° F

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

RO

c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

1 1. DETERMINE SIG secondary pressure boundaries are INTACT:

. CHECK all S!G pressures CONTROLLED or RISING.

CREW

. CHECK all S/G pressures greater than 140 psig.

(RNO Required)

RNO:

SRO PERFORM the following:

a. MONITOR status trees.

b.__GO_TO_E-2,_Faulted_Steam_Generator_Isolation.

Crew transitions to E-2, FAULTED STEAM GENERATOR ISOLATION

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8,9, 10 Page 41 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position AIicants Actions or Behavior E-2, FAULTED STEAM GENERATOR ISOLATION CAUTION: Unisolating a faulted S/G or secondary break should NOT be considered UNLESS needed for RCS cooldown.

1. CHECK MSIVs and MSIV bypass valves CLOSED.

2. CHECK ANY SIG secondary pressure boundary INTACT:

. Any SIG pressure CONTROLLED or RISING.

3. IDENTIFY Faulted SIG(s):

a. CHECK S/G pressures:

Any S/G pressure DROPPING in an uncontrolled manner.

OR

Any S/G pressure less than 140 psig.

CAUTIONS:

Secondary heat sink requires at least one SIG available.

Isolating both steam supplies to the TD AFW pump when it is the only source of feed flow will result in loss of secondary heat sink.

Evaluator Note: Critical Task to manually isolate ALL Auxiliary Feedwater Flow within 10 minutes after a steamline break:

Isolation Time (If recognized, may be completed during Prudent Operator Actions (POAs) following completion of E-O Immediate Operator Actions (IOAs).

(Normally be completed by BOP during POA5.)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 42 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior 1 RO 4. ISOLATE Faulted SIG(s):

. ISOLATE MEW.

. ISOLATE AFW.

. CLOSE TD AFW pump steam supply from faulted SIG ECV-1-15 (S/G #1) or FCV-1-16 (SIG #4).

. VERIFY SIG blowdown valves CLOSED.

.__VERIFY_atmospheric_relief_CLOSED.

5. CHECK CST level greater than 5%.

6. VERIFY secondary radiation NORMAL:

a. CHECK secondary radiation NORMALUSING Appendix A, Secondary Rad Monitors.

(App. A also contained in ES-O.5)

b. NOTIFY Chem Lab to take S/G activity samples.

c. WHEN Chem Lab is ready to sample SIGs, THEN PERFORM the following:

1) ENSURE_FCV-15-43_Blowdown_Flow Control valve CLOSED.

2) ENSURE_Phase_A_signal_RESET.

3) OPEN_blowdown_isolation_valves.

d. NOTIFY RADCON to survey main steam lines and SIG blowdown.

e. WHEN SIG samples completed, THEN CLOSE blowdown isolation valves.

RO 7. CHECK SI termination criteria:

a.__RCS_subcooling_based_on_core_exit_T/Cs_greater than 40°F.

b. Secondary heat sink:

. Narrow range level in at least one Intact SIG greater than 10%

[25%ADV]

OR

. Total feed flow to Intact S/Gs greater than 440 gpm.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8, 9, 10 Page 43 of 49 Event

Description:

Turbine High Vibration (Turbine Trip demand condition) EOP TRIP SEQUENCE Time Position Applicants Actions or Behavior

c. RCS pressure stable or rising.

d. Pressurizer level greater than 10% [20% ADVI.

SRO e. GO TO ES-1.1, SI Termination.

SRO determines transition to ES-1.1 is appropriate.

Scenario may be terminated upon transition to ES-1.1, SI Termination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 44 of 49 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O.5, EQUIPMENT VERIFICATIONS Evaluator Note: BOP completes ES-O.5 including Appendices A & B and reports completion (including any discrepancies and actions taken, i.e.: manual Feedwater Isolation per ES-O.5 Step 8) to SRO.

BOP 1. VERIFY D/G ERCW supply valves OPEN.

BOP 2. VERIFY at least four ERCW pumps RUNNING BOP 3. VERIFY CCS pumps RUNNING

1. Pump 1 A-A (2A-A) Must Manually Start

2. Pump lB-B (2B-B)

3. Pump C-S.

BOP 4. VERIFY EGTS fans RUNNING.

5. VERIFY generator breakers OPEN.

BOP

6. VERIFY AFW pumps RUNNING:

MD AFW pumps BOP

TDAFW pump.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control SIG levels, to establish flow due to failure, or to isolate a faulted S/G.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 45 of 49 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

7. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b. VERIFY TD AFW LCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

Evaluator Note: Critical Task is manually actuate Feedwater Isolation, ES-O.5 Step 8, VERIFY MFW Isolation.

(If recognized, may be completed during Prudent Operator Actions (POAs) following completion of E-0 Immediate Operator Actions (IOAs).

(ES-0.5 Step 8 directs completion by BOP during performance.)

Critical Task 8. VERIFY MFW Isolation:

a. MFW pumps TRIPPED

MEW regulating valves CLOSED BOP

MEW regulating bypass valve controller outputs ZERO

MFW isolation valves CLOSED

9. MONITOR ECCS operation:

BOP

a. VERIFY ECCS pumps RUNNING:

COPs:

RHR pumps

__SI_pumps

b. VERIFY COP flow through CCPIT.

c. CHECK RCS pressure less than 1500 psig.

d. VERIFY SI pump flow.

e. CHECK RCS pressure less than 300 psig.

f. VERIFY RHR pump flow.

BOP 10. VERIFY ESF systems ALIGNED:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 46 of 49 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

a. Phase A ACTUATED:

. PHASE A TRAIN A alarm LIT [M-6C, B5].

. PHASE A TRAIN B alarm LIT [M-6C, B6].

b. Cntmt Vent Isolation ACTUATED:

. CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, 05].

. CNTMT VENT ISOLATION TRAIN B alarm LIT [M-6C, C6].

c. Status monitor panels:

. 60 DARK

. 6DDARK

. 6E LIT OUTSIDE outlined area

. 6H DARK

. 6J LIT.

d. Train A status panel 6K:

. CNTMT VENT GREEN

. PHASE A GREEN

e. Train B status panel 6L:

. CNTMTVENTGREEN

. PHASEAGREEN BOP 1 1. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

. Phase B ACTUATED OR

. Containment pressure greater than 2.8 psig.

b. VERIFY containment spray INITIATED:

1) Containment spray pumps RUNNING.

2) Containment spray header isolation valves FCV-72-39 and FCV-72-2 OPEN.

Aojendix D Required Orerator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 47 of 49 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

3) Containment spray recirculation valves to RWST FCV-72-34 and FCV-72-13 CLOSED.

4) Containment spray header flow greater than 4750 gpm per train.

5) Panel 6E LIT.

c. VERIFY Phase B ACTUATED:

. PHASE B TRAIN A alarm LIT [M-6C, AS].

. PHASE B TRAIN B alarm LIT [M-6C, A6].

d. ENSURE RCPs STOPPED.

e. VERIFY Phase B valves CLOSED:

Panel 6K PHASE B GREEN.

Panel 6L PHASE B GREEN.

f. CHECK cntmnt vacuum relief isolation valves CLOSED:

[Pnl 6K MANUAL]

FCV-30-46

FCV-30-47

FCV-30-48.

g. WHEN 10 minutes have elapsed, THEN ENSURE containment air return fans RUNNING.

12. CHECK secondary and containment rad monitors USING the following:

BOP

Appendix A, Secondary Rad Monitors (attached)

Appendix B, Containment Rad Monitors. (attached)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 48 of 49 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

13. CHECK pocket sump pumps STOPPED:

[M-15, upper left corner]

. HS-77-410, Rx Bldg Aux Floor and Equipment Drain Sump BOP pump A

. HS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

14. DISPATCH personnel to perform EA-O-1, Equipment Checks BOP Following ESF Actuation.

15. ENSURE plant announcement has been made regarding Reactor BOP Trip and SI.

Evaluator Note: BOP completes ES-O.5 including Appendices A & B and reports completion (including any discrepancies and actions taken, i.e.: manual Feedwater Isolation per ES-O.5 Step 8) to SRO.

END (ES-O.5, EQUIPMENT VERIFICATIONS)

APPENDIX A SECONDARY RAD MONITORS

1. CHECK following rad monitors including available trends prior to BOP isolation:

. Condenser exhaust recorder RR-90-1 19

. SIG blowdown recorder RR-90-1 20

. Main steam line rad monitors

. Post-Accident Main Steam Line rad recorder RR-90-268B points 3 (blue), 4 (violet), 5 (black), and 6 (brown).

[M-31_(back_of_M-30)]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # ES-O.5 Page 49 of 49 Event

Description:

Equipment Verifications Time Position i Aooicants Actions or Behavior

2. IF secondary radiation is HIGH, THEN ENSURE Unit Supervisor notified.

END OF TEXT APPENDIX B CONTAINMENT RAD MONITORS BOP 1. CHECK following rad monitors:

. Upper containment high range rad monitors RM-90-271 and RM-90-272 NORMAL [M.-30]

Lower containment high range rad monitors RM-90-273 and RM-90-274 NORMAL [M-30]

. Containment rad recorders RR-90-1 12 and RR-90-1 06 NORMAL

[M-12} (prior to isolation).

BOP 2. IF secondary radiation is HIGH, THEN ENSURE Unit Supervisor notified.

END OF TEXT

Appendix D Scenario Outline Attachment I Facility: Sequoyah Scenario No.: 2 Op Test No.: NRC Examiners: Operators:

Initial Conditions: 85% RTP wI IA-A MDAFW Pump out of service for maintenance.

Turnover: Raise plant power to 100% according to 0-GO-5 Section 5.1 Target CTs: Manually start at least 1 EDG prior to placing safeguards loads P-T-L in ECA-0.0.

Establish feedwater flow into, at least one SG before RCS feed and bleed is required.

Event No. MaIf. No. Event Type* Event Description 1 R-RO Raise plant power to 100% RTP T+0 N-SRO/OP 2 RX6A 1-RO Pressurizer Level Transmitter 68-339 Fails Low T+10 TS-SRO 3 EDO8A C-BOP Loss of 1A1-A 480 VAC SDBd and lB-B CCS Pump fail to auto start T+20 CCO9B TS-SRO 4 HDO6A N-Crew 1-LCV-6-105A Fails to Variable Position T+30 HDO3B #3 HDT Pump lB Trip results in MT runback set yp_rdl 7=-i C-RO Rod Control failure resulting in continuous CB D rod insertion FW29C C-BOP Loop #3 FRV (1-LCV-3-90) Fails to operate in Automatic 5 FW16C M-All Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand T+40 6 EDO1 M-All Loss of Offsite AC Power T+40 [pre-insert]

7 EGO8A C-BOP iA-A EDG fails to automatically start T+40 EGO8B 1 B-B EDG fails to automatically start 8 FW22B C-BOP 1 B-B AFW Pump Airbound T+40 [pre-insert]

9 FWO7C C-BOP Ui TDAFW Pump Mechanical over speed trip actuates T+40 [pre-insert)

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

Appendix D Scenario Outline Attachment I Scenario 2 Summary The crew will assume the shift with the unit in Mode 1 85% RTP with lA-A MDAFW Pump out of service; plant power reduction was completed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ago to repair 1 B Condensate Booster Pump. 1 B Pump PMT was successfully completed on the previous shift; current direction is to raise plant power to 100% according to 0-GO-5 Section 5.1 Step 58 After the RO raises power, at Lead Examiner direction, the Pressurizer Level Transmitter controlling channel fails low; Pzr heaters de-energize and letdown isolation occurs. The crew will respond using alarm response procedures, (ARPs) and AOP-I.04, Pressurizer Instrument and Control Malfunctions Section 2.4. SRO will refer to Technical Specifications 3.3.1.1 Table 3.3-1 unit 11 Action 6; TS 3.3.3.5 Table 3.3-9 Instrument 7; TS 3.3.3.7 Table 3.3-10 unit 7 Action 2 and 3.4.4 Action a.

Following letdown restoration, at the Lead Examiner direction, 1A1-A 480 VAC Shutdown Board is de-energized due to normal feeder breaker over current trip-out. lA-A Component Cooling Pump is de-energized, lB-B CCS Pump fails to start automatically. The crew will respond according to ARPs, AOP-P.05, Loss of Unit 1 Shutdown Boards, Section 2.3 and AOP-M-03, Component Cooling System Malfunction, Section 2.1. SRO will refer to Technical Specifications 3.7.3, 3.8.1.1 Action b (dependent on EDG LO temperature) & TS 3.8.2.1 Action a.

When the plant is stable, at the Lead Examiner direction, 1 B #3 HDT Pump trip and 1-LCV-6-105A fails partially open compounding the low HDT system flow resulting in a runback condition. As the transient stabilizes, Rod Control will fail resulting in a continuous CB D rod insertion at 8 steps/minute and Loop #3 FRV fails to respond in automatic.

The crew will respond, in accordance with AOP-S.04, Condensate or Heater Drains Malfunctions Section 2.6, Total or Partial Loss of #3 Heater Drain Tank Pump Flow- [preferred]; (the crew may enter Section 2.1 #3 Heater Drain Tank Pump Trip, non-preferred). Additionally AOP-C.01 Section 2.1 and AOP-S.01 Section 2.1 may be applied.

When the plant response to the runback is complete, at the Lead Examiner direction, Loop #3 Main Feedwater Regulating Valve will fail closed resulting in a Reactor trip condition. At the time of the trip, the crew will experience a loss of offsite AC power. The crew will respond to the automatic trip by performing E-0 immediate operator actions and the SRO will enter E-0; once E-0 immediate operator actions are complete, the crew should address the loss of offsite power using AOP-P.01, Loss of Offsite Power Section 2.1.

Coincident with the reactor trip, both lA-A and I B-B EDGs fail to start automatically, 1 B-B MDAFW Pump is airbound and UI TDAFW Pump mechanical over speed trip actuates and cannot be reset immediately. The crew must take action to manually start one EDG and place it on the bus to avoid entering ECA-0.0 The crew will continue in E-0, transition to ES-0.1, implement status tree monitoring and identify FR-H.1 entry criteria.

The scenario may be terminated as directed by the Lead Examiner once the crew restores secondary heat sink control either by venting the 1 B-B MDAFW Pump or by resetting the TDAFW Pump resulting in positive SG level increase/RCS temperature change.

EOP flow: E-0 ES.01 FR-H.1 ES-0.1 (Note; ECA-0.0 MAY be entered briefly prior to starting EDG)

The scenario may be terminated as directed by the Lead Examiner upon completion of ES.0-l Step 5 PSA significant task: Start EDG; Start an AFW Pump (TD or MD Pump);

PSA significant DAS: Loss Of Offsite AC Power; PSA significant component failure: CCS Pump trip 1 Al -A 480 VAC SDBd

1002 ESG-2 Page 1 of 5 APPENDIX C Time: Now Date: Today Unit .

MCR Checklist Parti Model, 85% Power 1020 MWe NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID .02 gpm, UNID .01 gpm Until 0800 XX)(X RCS boron: 1128 ppm After 0800 XX)(X LCOJTRM Equipment INOP Time INOP Owner RTS None None

,1 TeenspecActions LCOITRM Equipment INOP Time INOP Owner RTS 3.7.1.2.a lA-A MDAFW Pump 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MMG +24 hrs.

Protected Equipment

lB-B MD AFW Pump

TDAFW Pump Shift Priorities

I B Pump PMT was completed on the previous shift- pump is running

Raise plant power to 100% according to Tl-40; O-GO-5 Section 5.1 Step 57 completed; Part 2 Performed by on-coming shift LI Verify your current qualifications (re: OPDP-1 Section 7.3 F.)

LI Review Operating Log since last held shift or 3 days, whichever is less.

Review the following for changes since last shift turnover:

fl ODMI5/Standing Orders! LI LCD actions LI PERs (applicable to unit)

Shift Orders LI TACFs LI Operator workarounds, burdens, Immediate required reading and challenges Part 3 Performed by both off-going and on-coming shift Walk down of MCR Control Boards

1002 ESG-2 Page 2 of 5 APPENDIX C Time: Now Date: Today MAIN CONTROL ROOM (7690)

Train A Week OUTSIDE (7666)r593-52141

None AUXILIARY BUILDING (7775)

None TURBINE BUILDING (7771) (593-8455)

None

1002 ESG-2 Page 3 of 5 Time: Now Date: Today MCR Red Dot List UNID And Noun Name Panel Problem Description WO I PER Number Date Scheduled MCR WO List ID And Noun Name Panel Problem Description WOIPER Number Date Scheduled

1002 ESG-2 Page 4 of 5 UNIT ONE REACTIVITY BRIEF I Date: Today Time: Now General Information : 1 RCS Boron: 1128 ppm Today BA Controller Setpoint: 27.5% RCS B-b Depletion: 52 ppm Operable BAT: A BAT A Boron: 6850 ppm BAT C Boron: 6850 ppm RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 50 gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw 0-SO-62-7 section 5.1 Estimated valuesforaioChangeinTave**, :

Gallons of acid: 26 Gallons of water: 136 Rod Steps: 3 Estimated rodslboron for emergency step power reductjon r (Asuming Xenon quiIibnun and no reactivity efcts due to Xenon. 2!tota1 rao tyfromso1s IY34ron boron)

Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 196 Steps on bank D 99 gallons 30% 173 Steps on bank D 292 gallons 50% 151 Steps on bank D 481 gallons These values are approximations and not intended nor expected to be exact. The values may be superseded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

Previous Shift Reactivity Manipulations Number of dilutions: 1 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 12 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 12 Total amount borated: 0 Net change: 0 IN/Out

. Curreiit Shift Estimated Reactivity Manipulations Number of dilutions:

Number of borations: 0 Rod steps in: 0 Gallons per dilution:

Gallons per boration: 0 Rod steps out: 0 Total expected dilution:

Total expected boration: 0 Net change: 0 In/Out Remarks:

Per Reactor Engineer Spreadsheet Rx Power: 85% Burnup: 10,000 Mwd/mtU Xenon: 2729 pcm, equilibrium Samarium: 926 pcm Last Dilution Completed

Next Unit 1 Flux Map is scheduled three weeks from now Unit 1 M-P is 0 PPM Unit Supervisor:

Name/Date

1002 ESG-2 Page 5-of 5 Operations Chemistry Information Boron Results.

Sample Point Units Boron Date I Time Goal Limit - -

Ui RCS ppm 1 128 Today / Now Variable Variable U2 RCS ppm 816 Today / Now Variable Variable UI RWST ppm 2601 Today! Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today I Now 2550 2650

- 2500 2700 BAT A ppm 6850 Today I Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BAT C ppm 6850 Today I Now Variable Variable Ui CLA #1 ppm 2556 Today! Now 2470-2630 2400-2700 Ui CLA #2 ppm 2575 Today I Now 2470-2630 2400-2700 Ui CLA #3 ppm 2591 Today I Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today I Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today I Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today! Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today! Now > 2050 2000 Lithium Results - Goal Midpoint Ui RCS Lithium ppm 1.1 Today! Now >1 >1 U2 RCS Lithium ppm 2.43 Today! Now 2.18-2.48 2.33 PrJmaryto Secondary I.eakrate Information TotalGPMRM$O-9)

Indicator Units UI Date ITime U2 Date/Time SI 50 S!G Leakage? Yes/No No Today! Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today / Now < 0.1 Today / Now 5 gpd leak equivalent cpm 370 Today / Now 111 Today I Now 30 gpd leak equivalent cpm 1970 Today / Now 464 Today! Now 50 gpd leak equivalent cpm 3250 Today / Now 747 Today I Now 75 gpd leak equivalent cpm 4850 Today / Now 1100 Today I Now CVE Air Inleakage cfm 10 Today! Now 12.5 Today! Now Bkgd on 99/119 cpm 50 Today/Now 40 Today/Now Correction Factor 99/119 cpm/gpd 64 Today I Now 14.13 Today! Now Steady state conditions are necessary for an accurate determination of leak rate using the CVE Rad Monitor

Unit 1 DELTA REACTOF POWER ASSUMED INSERTEDEXPECTE[DELTA RHC BORON DELTA ECOMMEN RECOMME IODINE DATE/TIME TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATIOI CONC (hrs) (%) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0 85.0 1421.8 190.0 -186.3 -2683.0 --- 1128.0 --- --- --- 99.4 2/14/10 22:00 1 89.5 1498.5 193.0 -161.2 -2727.5 96.1 1113.0 -15.0 867 0 98.2 2/14/10 23:00 2 94.0 1582.4 196.0 -137.1 -2739.2 71.5 1101.9 -11.1 651 0 97.6 2/15/10 0:00 3 98.5 1666.3 199.0 -115.4 -2728.0 51.0 1093.9 -8.0 468 0 97.5 2/15/10 1:00 4 100.0 1696.6 202.0 -96.5 -2707.9 -8.6 1095.3 1.3 0 15 97.6 2/15/10 2:00 5 100.0 1696.0 205.0 -79.5 -2690.7 -34.8 1100.7 5.4 0 61 97.9 2/15/10 3:00 6 100.0 1693.3 208.0 -63.9 -2678.8 -30.2 1105.4 4.7 0 53 98.1 2/15/10 4:00 7 100.0 1691.1 211.0 -48.4 -2670.7 -25.9 1109.4 4.0 0 45 98.3 2/15/10 5:00 8 100.0 1689.2 214.0 -35.0 -2665.5 -20.5 1112.6 3.2 0 36 98.4 2/15/10 6:00 9 100.0 1687.7 2160 -26.9 -2662.3 -12.8 1114.6 2.0 0 22 98.6 2/15/10 7:00 10 100.0 1686.7 216.0 -26.9 -2660.8 -2.5 1115.0 0.4 0 4 98.7 2/15/10 8:00 11 100.0 1686.5 216.0 -26.9 -2660.3 -0.6 1115.1 0.1 0 1 98.9 2/15/10 9:00 12 100.0 1686.5 216.0 -26.9 -2660.6 0.3 1115.1 0.0 2 0 99.0 2/15/10 10:00 13 100.0 1686.5 216.0 -26.9 -2661.5 0.9 1114.9 -0.1 8 0 99.1 2/15/10 11:00 14 100.0 1686.6 216.0 -26.9 -2662.7 1.3 1114.7 -0.2 12 0 99.2 2/15/10 12:00 15 100.0 1686.7 216.0 -26.9 -2664.2 1.5 1114.5 -0.2 14 0 99.2 2/15/10 13:00 16 100.0 1686.8 216.0 -26.9 -2665.7 1.7 1114.2 -0.3 15 0 99.3 2/15/10 14:00 17 100.0 1686.9 216.0 -26.9 -2667.3 1.7 1114.0 -0.3 16 0 99.4 2/15/10 15:00 18 100.0 1687.0 216.0 -26.9 -2668.9 1.7 1113.7 -0.3 16 0 99.4 2/15/10 16:00 19 100.0 1687.2 216.0 -26.9 -2670.5 1.7 1113.4 -0.3 15 0 99.5 2/15/10 17:00 20 100.0 1687.3 216.0 -26.9 -2672.0 1.6 1113.2 -0.3 15 0 99.5 2/15/10 18:00 21 100.0 1687.4 216.0 -26.9 -2673.4 1.6 1112.9 -0.2 14 0 99.6 2/15/10 19:00 22 100.0 1687.5 216.0 -26.9 -2674.8 1.5 1112.7 -0.2 13 0 99.6 2/15/10 20:00 23 100.0 1687.6 216.0 -26.9 -2676.0 1.4 1112.5 -0.2 12 0 99.7 2/15/1021:00 24 100.0 1687.7 216.0 -26.9 -2677.2 1.3 1112.3 -0.2 11 0 99.7 2/15/10 22:00 25 100.0 1687.8 216.0 -26.9 -2678.3 1.2 1112.1 -0.2 11 0 99.7 2/15/10 23:00 26 100.0 1687.9 216.0 -26.9 -2679.3 1.1 1111.9 -0.2 10 0 99.8 2/16/10 0:00 27 100.0 1688.0 216.0 -26.9 -2680.2 1.0 1111.8 -0.2 9 0 99.8 2/16/10 1:00 28 100.0 1688.1 216.0 -26.9 -2681.0 0.9 1111.7 -0.1 8 0 99.8 2/16/102:00 29 100.0 1688.1 216.0 -26.9 -2681.7 0.8 1111.5 -0.1 7 0 99.8 2/16/103:00 30 100.0 1688.2 216.0 -26.9 -2682.4 0.8 1111.4 -0.1 7 0 99.8 2/16/10 4:00 31 100.0 1688.2 216.0 -26.9 -2683.1 0.7 1111.3 -0.1 6 0 99.9 2/16/10 5:00 32 100.0 1688.3 216.0 -26.9 -2683.6 0.6 1111.2 -0.1 6 0 99.9 2/16/106:00 33 100.0 1688.3 216.0 -26.9 -2684.2 0.6 1111.1 -0.1 5 0 99.9 2/16/10 7:00 34 100.0 1688.4 216,0 -26.9 -2684.6 0.5 1111.0 -0.1 5 0 99.9 2/16/10 8:00 35 100.0 1688.4 216.0 -26.9 -2685.0 0.5 1111.0 -0.1 4 0 99.9 2/16/10 9:00

Unit 1 36 100.0 1688.5 216.0 -26.9 -2685.4 0.4 1110.9 -0.1 4 0 99.9 2/16/10 10:00 37 100.0 1688.5 216.0 -26.9 -2685.8 0.4 1110.8 -0.1 3 0 99.9 2/16/10 11:00 38 100.0 1688.5 216.0 -26.9 -2686.1 0.3 1110.8 -0.1 3 0 99.9 2/16/10 12:00 39 100.0 1688.5 216.0 -26.9 -2686.4 0.3 1110.7 0.0 3 0 99.9 2/16/10 13:00 40 100.0 1688.6 216.0 -26.9 -2686.6 0.3 1110.7 0.0 3 0 99.9 2/16/10 14:OO 41 100.0 1688.6 216.0 -26.9 -2686.9 0.3 1110.7 0.0 2 0 99.9 2/16/10 15:00 42 100.0 1688.6 216.0 -26.9 -2687.1 0.2 1110.6 0.0 2 0 100.0 2/16/10 16:00 43 100.0 1688.6 216.0 -26.9 -2687.3 0.2 1110.6 0.0 2 0 100.0 2/16/10 17:00 44 100.0 1688.6 216.0 -26.9 -2687.4 0.2 1110.6 0.0 2 0 100.0 2/16/10 18:00 45 100.0 1688.6 216.0 -26.9 -2687.6 0.2 1110.5 0.0 2 0 100.0 2/16/10 19:00 46 100.0 1688.7 216.0 -26.9 -2687.7 0.2 1110.5 0.0 1 0 100.0 2/16/1020:00 47 100,0 1688.7 216.0 -26.9 -2687.8 0.1 1110.5 0.0 1 0 100.0 2/16/1021:00 48 100.0 1688.7 216.0 -26.9 -2688.0 0.1 1110.5 0.0 1 0 100.0 2/16/1022:00 49 100.0 1688.7 216.0 -26.9 -2688.1 0.1 1110.5 0.0 1 0 100.0 2/16/10 23:00 50 100.0 1688.7 216.0 -26.9 -2688.2 0.1 1110.4 0.0 1 0 100.0 2/17/10 0:00 51 100.0 1688.7 216.0 -26.9 -2688.2 0.1 1110.4 0.0 1 0 100.0 2/17/10 1:00 52 100.0 1688.7 216.0 -26.9 -2688.3 0.1 1110.4 0.0 1 0 100.0 2/17/10 2:00 53 100.0 1688.7 216.0 -26.9 -2688.4 0.1 1110.4 0.0 1 0 100.0 2/17/10 3:00 54 100.0 1688.7 216.0 -26.9 -2688.4 0.1 1110.4 0.0 1 0 100.0 2/17/10 4:00 55 100.0 1688.7 216.0 -26.9 -2688.5 0.1 1110.4 0.0 1 0 100.0 2/17/10 5:00 56 100.0 1688.7 216.0 -26.9 -2688.5 0.1 1110.4 0.0 0 0 100.0 2/17/10 6:00 57 100.0 1688.7 216.0 -26.9 -2688.6 0.0 1110.4 0.0 0 0 100.0 2/17/10 7:00 58 100.0 1688.7 216.0 -26.9 -2688.6 0.0 1110.4 0.0 0 0 100.0 2/17/10 8:00 59 100.0 1688.7 216.0 -26.9 -2688.7 0.0 1110.3 0.0 0 0 100.0 2/17/10 9:00 60 100.0 1688.7 216.0 -26.9 -2688.7 0.0 1110.3 0.0 0 0 100.0 2/17/10 10:00 61 100.0 1688.8 216.0 -26.9 -2688.7 0.0 1110.3 0.0 0 0 100.0 2/17/10 11:00 62 100.0 1688.8 216.0 -26.9 -2688.8 0.0 1110.3 0.0 0 0 100.0 2/17/10 12:00 63 100.0 1688.8 216.0 -26.9 -2688.8 0.0 1110.3 0.0 0 0 100.0 2/17/10 13:00 64 100.0 1688.8 216.0 -26.9 -2688.8 0.0 1110.3 0.0 0 0 100.0 2/17/10 14:00 6350 MWD/MTU Hold Tavg = Tref -f-f- 1 .5F Total 2258 238 6740 BAT ppm Small hourly boration/dilution volumes may be accumulated for larger single additions Reason for Maneuver #1 B Condensate Booster Pump Repair Date 2/12/10 RxEng Name Rx Engineering

Unit I Comments 48 Hour hold at 83%

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 1 of 47 Event

Description:

Raise plant power to 100% RTP Time Position Applicants Actions or Behavior Booth Instructor:

No action required for Event I T = 0 Crew will perform power change lAW O-GO-5, Section 5.1 NOTES

1) Reactor power can be increased greater than 90% as long as adequate MFP suction is maintained.

2) Steps 5.1 [58] through 5.1 [62] may be performed out of sequence.

[58] WHEN approximately 85 to 90% reactor power OR when determined by Unit SRO (if power raised above 90%), THEN, SRO ENSURE third condensate booster pump in service in accordance with 1 ,2-SO-2/3-1. [C.2]

NOTES A nominal CBP suction pressure of approximately 180 psig, as indicated on [P1-2-771, will alleviate bypassing to the condenser at full power.

[59] IF condensate pressure is high resulting in #3 or #7 heater drain tank BOP bypassing to the condenser, OR the normal level control valves are near full open, THEN

[59.1] THROTTLE [1 4-550] to attain desired condensate pressure.

[59.2] IF unable to throttle [14-550], THEN REFER to 1 ,2-SO-5-2, Section 8.0 to adjust condensate pressure.

OR EVALUATE removal of the condensate demineralizer booster pumps (N/A if NOT in service).

NOTE Two Cond DI Booster pumps must be started at the same time.

[60] EVALUATE starting available condensate demineralizer booster BOP pump(s) to raise system pressure 40 psig.

Pump Started YES D NO D

[61] WHEN reactor power is approximately 90%,

SRO/RO THEN PERFORM_the_following:

[61 .1] ADJUST Power Range instrumentation in accordance with 0-SI-OPS-092-078.0.

[61.2] INITIATE performance of 1 -PI-OPS-000-020. I or 2-PI-OPS-000-022.1, Appendix_B.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 2 of 47 Event

Description:

Raise plant power to 100% RTP Time Position I Applicants Actions or Behavior CAUTION The potential exists for condensation formation in steam extraction lines when feedwater heaters are isolated.

[61.3] ENSURE the following leveT controllers are maintaining levels within normal ranges:

BOP A. Secondary plant heaters.

B. MSR drain tanks.

CAUTION DO NOT exce d an averacie of 3455.0 MWT durinq an 8-hour reriod. rc.ii

[62] MONITOR NIS, AT and calorimetrics on plant computer (pt. U21 18)

RO while increasing reactor power.

NOTES

1) Feedwater venturi unfouling may impact U1118 indication. LEFM calorimetric power (U21 18) is not affected by venturi unfouling.

2) If U1118 is being used to monitor reactor power due to LEFM unavailable, then Calorimetric Calculation should be performed prior to exceeding 97% reactor power.

3) Steps 5.1 [63] through 5.1 [67] may be performed out of sequence.

[63] IF Unit is returning to full power after a turbine load reduction to less than 50%

BOP/RO AND U1118 is being used to monitor power, THEN PERFORM the following prior to exceedin 97% rower:

[63.1] NOTIFY Systems Engineering to perform O-PI-SXX-000-022.2, SRO Calorimetric Calculation, Section 8.1, if necessary.

[63.2] PERFORM applicable sections of 0-Pl-S)(X-000-022.2 to adjust Feedwater Flow Constant. (N/A if NOT required)

SRO BOP Enciineer determined this step NIA NOTES

1) Ramp load rate increases shall be within the limits of TI-40

2) Intermediate Power Threshold ramp rate target value of 2% / hr may apply.

RO [64] RECORD power ascension ramp rate from Tl-40: 4.5%/hr

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 3 of 47 Event

Description:

Raise plant power to 100% RTP Time N Position ft Applicants Actions or Behavior CREW V

[65] CONTINUE power ascension to 100% RTP.

NOTE Control rods may be used along with dilution during reactor power increase to maintain AFD within the target control band

[66] IF diluting the RCS to increase TAVG, THEN RO/SRO CONTINUE dilution and increase turbine load to maintain TREF with TAVG. (0-SO-62-7)

NOTE Valve position limit and governor control meter are displayed on EHC Display panel 1 ,2-)O(-

047-2000 (M-2)

[67] MONITOR the turbine load increasing AND BOP MAINTAIN valve position limit approximately 10% above the current governor control indication as turbine load is changed.

NOTE Steps 5.1[68] through 5.1[71] may be performed out of sequence.

[68] WHEN reactor power approaches 100%, THEN BOP ADJUST governor valve position limiter 2% above governor valve position.

NOTE Engineering recommends placing the 3rd Condensate Demineralizer Booster Pump in service when at full power. Operation of only 2 Condensate Demineralizer Booster Pumps is allowed but reduces the operating margin in the event of a condensate transient based on the lower suction pressure to the MFP5.

[69] IF it is desired to place the 3rd condensate demineralizer booster pump in service, THEN SRO/BOP START 3rd condensate demineralizer booster pump in accordance with 1 ,2-SO-2/3-1. V

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 4 of 47 Event

Description:

Raise plant power to 100% RTP Time Position Applicants Actions or Behavior CAUTION Governor valve position limit meter may NOT match the governor valve position meter; therefore, monitor the megawatt meter and valve position limit light continuously during the following step.

NOTES

1) Operation with the VALVE POS LIMIT light LIT is acceptable if unsatisfactory load swings are experienced.

2) Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance.

[70] IF unsatisfactory load swings are experienced as the unit approaches SROIBOP full power, THEN

[70.1] WITH turbine load set for maximum of 100% power, SLOWLY and CAUTIOUSLY PULSE the governor VALVE POSITION LIMIT in LOWER direction while monitoring megawatts for a decrease and VALVE POS LIMIT light to ILLUMINATE.

[70.2] WHEN the limiter just reaches the governor valve position, THEN STOP limiter adjustment.

CAUTION Do not raise the limiter position unless the turbine control is positively controlling the turbine (limit light NOT LIT).

NOTE Actions effecting reactivity are directed in the following step. All appropriate verifications and peer checks shall be utilized during performance.

[71] PERFORM the following if the limiter prevents reactor operation at BOP approximately_100%:

[71.1] ADJUST SETTER/REFERENCE controls to reduce turbine loading until the VALVE POS LIMIT light is NOT LIT.

[71.2] INCREASE VALVE POSITION LIMIT to allow a load increase using the SETTER/REFERENCE controls, NOT to exceed 3455.00 MWT.

NOTES

1) Full power operation is defined as 100% power operation at approximately 3455 MWT instantaneous value, U21 18 not to exceed 3455.00 MWT average thermal power in an 8-hour period. [C.1]

2) Do not intentionally operate the reactor at greater than 100% power (e.g., if reactor power is less than 100% for any time period then operation at slightly greater than 100% to make up for lost power is not permissible). [C.1]

3) Computer point U21 18 should be trended on a trend recorder in the unit horseshoe and monitored for increasing reactor power trends above 3455 MWT. Prompt action shall be taken to decrease reactor power whenever an increasing power trend is observed. [C.1]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 5 of 47 Event

Description:

Raise plant power to 100% RTP Time Position Applicants Actions or Behavior

4) Do not exceed an 8-hour average value (U21 26) of 3455.00 MWT. Do not allow U21 25 (one hour avg) to exceed 3455.00 MWT (100%) for more than one hour. [C.1]

5) Portions of step 5.1173] may be performed in parallel with step 5.11721 if required.

[72] WHEN the unit stabilizes at 100% reactor power, CREW THEN PERFORM the followinq: (may be performed in any order)

[72.1] ADJUST Governor Valve position, rod height, and/or RCS boron CREW concentration as necessary to establish core thermal power at desired value and Auctioneered Hi T-avq approximately equal to T-ref.

SRO [72.2] NOTIFY load coordinator that the power increase is complete.

CREW [72.3] NOTIFY RADCON that power has stabilized at 100%.

[72.4] IF Seal Steam spillover bypass [FCV-47-191] is IN SERVICE, THEN BOP THROTTLE Seal Steam spillover bypass to control [FCV-47-191] as required to control seal steam pressure.

[72.5] IF river temperature is less than 45°F, THEN BOP/SRO CONSULT Engineering to determine if third CCW pump should be removed from service.

[72.6] CONTACT vibration engineer in Predictive Maintenance Group to CREW monitor MFWP vibration.

CAUTION A bias adjustment in the upward direction (> 50%) should NOT be used unless evaluated by Systems Engineering since this could impact a MFPTs maximum speed and the ability to fully load in the event the other MFPT trips.

[72.7] IF feed pump vibration is above desired levels, THEN BOP/SRO CONSULT with vibration engineer and system engineer to determine which_feed_pump_to_bias_to_reduce_vibration.

[72.8] IF MFPT master controller output is NOT indicating 45% to 55%

THEN BOP/SRO CONSULT with MFPT controls system engineer to evaluate if adjustment_is_required_per_1 ,2-SO-2/3-1.

[72.9] IF start up on Unit 2, THEN...

SRO This step NIA

[73] IF startup is following refueling activities, THEN....

SRO This step NIA SRO [74] IF Steam Generator WR level recorders were re-scaled to 80% 90% in -

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 Page 6 of 47 Event

Description:

Raise plant power to 1 OO% RTP Time Position I Aprlicants Actions or Behavior 0-GO-2, THEN NOTIFY MIG to re-scale LR-3-43A and LR-3-98A, Steam Generator Wide Range Level Recorders, to 0% 100%. -

This step NIA

[75] IF unit shutdown to minimum load, THEN GO TO Section 5.3.

SRO This step NIA

[76] IF unit is to be maintained at normal power, THEN SRO GO TO Section 5.2.

When power change is sufficient to record a reactivity manipulation, lead examiner may cue the next event.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 7 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available:

. 1-AR-M5A, C-3: LS-68-335D1E PRESSURIZER LEVEL HIGH-LOW

. E-3:LS-68-335E1D PRZR LVL LOW HEATER OFF & LETDOWN SECURED

. Indicator 1-TI-62-78 indicates 70°F

. Indicator 1-PI-62-81 indicates70-100 psig

. Indicator 1-FI-62-82 indicates Ogpm T = 10 CREW Respond in accordance with Alarm Response Procedures CREW US may use or refer to AOP-I.04, Pressurizer Instrument & Control Malfunctions, Section 2.4, Pressurizer Level Instrument Malfunction NOTE: Appendix M shows layout of PZR level control for operator reference.

SRO Directs the following operator actions:

1. CHECK Ll-68-339 NORMAL.

RO (RNO Required)

RNO:

PERFORM the following:

a. ENSURE LEVEL CONTROL CHANNEL SELECTOR switch XS 339E in LT-68-335 & 320.

RO

b. ENSURE LEVEL REC CHANNEL SELECTOR switch XS-68-339B in LT-68-320 or LT-68-335.

c. GO TO Step 4.

RO/SRO Steps 2-3 are NIA

4. CHECK letdown IN SERVICE RO (RNO Required)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 8 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time Position Applicants Actions or Behavior RNO:

BOP RESTORE letdown USING EA-62-5, Establishing Normal Charging and Letdown.

Evaluator Note: EA-62-5, Establishing Normal Charging and Letdown included following this section.

CHECK Letdown restored:

RO I -M-5 lndicationslAlarms

. Letdown HX Outlet Temp Indicator 1-Tl-62-78 indicates 100-105°F

. Letdown HX Outlet Press Indicator 1-PI-62-81 indicates 325 psig

. Letdown HX Outlet Flow Indicator 1-Fl-62-82 indicates 75gpm O-M-27B Indications/Alarms

. 1-Fl-70-190, LETDOWN HX OUTLET FLOW indicates 250 gpm

. 1-Fl-70-191, LETDOWN HX OUTLET TEMP indicates 12O gpm

. Annunciator 0-XA-55-27B-B, A-5: LETDOWN HX OUTLET FLOW/TEMP ABNORMAL is clear

5. EVALUATE the following Tech Specs for applicability:

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation Action 6 (From Table 3.3-1 Item 11) Applies Trip mop Bistables w/i 6 Hrs.

. 3.3.3.5, REMOTE SHUTDOWN INSTRUMENTATION From Table 3.3-9 Instrument 5; Applies restore to OPERABLE status w/l 7 SRO days or Ht SD w/l next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

. 3.3.3.7, ACCIDENT MONITORING INSTRUMENTATION Action 2.a (From Table 3.3-10 Item 7) Applies within 30 days;

. 3.4.4, PRESSURIZER Action b: Applies within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , restore at least two groups to OPERABLE.

RO 6. ENSURE pressurizer heaters restored to service.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 9 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time 1L Position Applicants Actions or Behavior CAUTION RCS pressure changes and changes in RCS boron concentration (due to differences between Pzr and RCS boron) mayirnpact core reactiviy RD 7. MONITOR reactor power:

a. CHECK reactor in Mode 1 or 2.

b.__MONITOR_core_thermal_power_for_unexpected_changes.

NOTE: If performing AOP in conjunction with AOP-I.11 for an Eagle LOP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop is restored to operable status by resetting Eagle rack.

8. NOTIFY MIG to remove failed pressurizer level channel from service CREW USING appropriate Appendix:

PZR LEVEL INSTRUMENT CHANNEL APPENDIX L-68-339 (L-459) I I L-68-335 (L-460) II J L-68-320 (L-461) Ill K SRO Appropriate Appendix is I SRO 9. GO TO appropriate plant procedure.

Lead Examiner may cue next event when Letdown is restored and Tech Specs are addressed.

EA-62-5 ESTABLISHING NORMAL CHARGING AND LETDOWN 4.0 OPERATOR ACTIONS 4.1 Section Applicability Steps 4.1.1 & 4.1.3 are NIA

1. IF normal charging flow is to be established This step is NIA

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 10 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time Position Applicants Actions or Behavior

2. IF normal letdown flow is to be established, SRO THEN GO TO Section 4.3.

4.3 Establishing Normal Letdown Flow NOTE EA-62-3, Establishing Excess Letdown, may be utilized if Normal Letdown cannot be established.

1. IF charging flow NOT established,...

This step is NIA BOP 2. VERIFY pressurizer level greater than 17%

BOP 3. ENSURE letdown orifice isolation valves CLOSED:

LETDOWN ORIFICE ISOLATION VALVES CLOSED q

FCV-62-72 U FCV-62-73 U FCV-62-74 U

. BOP 4. OPEN letdown isolation valves:

LETDOWN ISOLATION VALVES OPEN q

FCV-62-69 11 FCV-62-70 D FCV-62-77 D NOTE Placing cooling water on the Letdown Heat Exchanger prior to restoring letdown flow should prevent TIS-62-79B/A from actuating and fully opening TCV-70-1 92.

BOP 5. PLACE [HIC-62-78] in MANUAL, AND OPEN [TCV-70-192] to 50%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 11 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time Position I Applicants Actions or Behavior BOP 6. PLACE letdown pressure controller [PCV-62-81 in MANUAL and ADJUST output between 40% and 50%, (50%-60% open).

BOP 7. ADJUST charging flow as necessary to prevent flashing in the letdown line.

RO 8. OPEN letdown orifice isolation valves as needed:

LETDOWN ORIFICE ISOLATION VALVES OPEN q

FCV-62-72 D FCV-62-73 D FCV-62-74 ED NOTE Normal letdown pressure is 325 osia at normal oeratina temperature.

BOP 9. ADJUST letdown pressure controller [PCV-62-81] output to obtain desired pressure.

BOP 10. ADJUST letdown pressure controller [PCV-62-81] setpoint to match existing pressure.

BOP 11. PLACE letdown pressure controller [PCV-62-81] in AUTO.

NOTE Normal letdown temperature is 100°F.

BOP 12. ADJUST [HIC-62-78A] to obtain desired letdown temperature, as indicated on [Tl-62-78].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 2 Page 12 of 47 Event

Description:

Pressurizer Level Transmitter 68-339 Fails Low Time Position Applicants Actions or Behavior BOP 13. PLACE [HIC-62-78A] in AUTO.

NOTE Letdown temperature may swing due to repeated actuation of TIS-62-79B/A, which causes letdown temperature control valve TCV-70-192 to fully open.

BOP 14. IF necessary to stabilize letdown temperature, THEN PERFORM the following:

a. PLACE [HIC-62-78A] in MANUAL and ADJUST controller output in OPEN direction.

b. WHEN letdown heat exchanger outlet temperature is stabilized at approximately 100°F, THEN PLACE [HIC-62-78A] in AUTO.

BOP 15. ENSURE high temperature divert valve [HS-62-79A] in DEMIN position.

BOP 16. ADJUST charging and letdown as necessary to maintain RCP seal injection flow and pressurizer level.

BOP 17. IF CCP suction is aligned to the RWST and realigning CCP suction to VCT is desired, THEN THEN ENSURE VCT aligned for normal operation:

a. ESTABLISH VCT level greater than 20%

BOP b. ENSURE VCT outlet valves ALIGNED:

COMPONENT POSITION i LCV-62-132 OPEN D HS-62-132 PULL A-P AUTO D LCV-62-133 OPEN D HS-62-133 PULL A-P AUTO D

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Ow

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 14 of 47 Event

Description:

Loss of 1A1-A 480 VAC SDBd and lB-B CCS Pump fail to auto start Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 Indications available:

1-M-1 Annunciators:

I-XA-55-IB Window D-5: 480V SD BD IAI-A FAILURE OR UNDERVOLTAGE

I-XA-55-IC Window A-4 125V DC CHGR I FAILURE OR VITAL BAT I DISCHARGE

Window A-5 125V DC VITAL BAT I ABNORMAL

Window E-7 PNL 1-M-7 TROUBLE I-M-I Indicators:

480V SD BD IAI-A VOLTS, I-EL-57-29A: goes to 0;

125V VITAL BATT BD I AMPS, l-EL-57-92: goes up to 200 to 250 AMPS I -M-5B Annunciators:

I-XA-55-5B Window E-3: REACTOR COOLANT PUMPS MOTOR THRUST BEARING TEMP HIGH 0-M-26A Annunciators:

0-XA-55-26A Window C-4: DIESEL GEN IA-A JACKET WATER TEMP HIGH-LOW ENGINE I OR 2

Window D-6: 480V SD BD IAI-A FAILURE OR UNDERVOLTAGE 0-M-27B-A Annunciators:

XA-55-27B-A Window A-I CCS REAC BLDGSUPPLY HEADERFLOW LOW T = 20 CREW Respond in accordance with Alarm Response Procedures Diagnose failure and place rods in manual to stop rod motion Refer to Annunciator Response Procedure SRO Enter and direct action of AOP-P.05 Section 2.3 CAUTIONS: 1. Operation of RCPs for greater than 2 minutes without CCS cooling to oil coolers will result in bearing temperatures greater than 200°F.

MaIf. Init time: 1 B-BCCS Pump Start time:

Time:

2. Containment Spray Pumps may experience bearing failure 10 minutes after loss of CCS coolinq.

NOTES: 3. COPs, SI pumps, and RHR Pumps must be considered INOPERABLE when the

ADoendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 15 of 47 Event

Description:

Loss of 1A1-A 480 VAC SDBd and lB-B CCS Pump fail to auto start Time Position Aonlicants Actions or Behavior associated train of CCS is out of service; however, pumps are available for operation if needed in an emergency.

4. Power loss to LCV-6-iO6B will result in reduced #3 Heater Drain Tank Pump discharge flow.

5. Indicating lights for the turbine throttle, governor, intercept & reheat-stop valves are de enerqized.

BOP 1. ENSURE lB-B CCS Pump SUPPLYING Train A CCS.

Evaluator Note: ARP O-AR-M27-B-A, A-i will direct starting the idle CCS Pump, i B-B in this scenario.

Any of the other ARPs on this same annunciator window will also direct standby pump start and may be implemented by the crew for the same purpose.

2. MONITOR REACTOR COOLANT PUMPS MOTOR THRUST BEARING RO TEMP HIGH alarm DARK [1-M-5B, E-3].

NOTE I Power is lost to 1-FCV-72-34, Train A Containment Spray Pump Recirc Valve and i-FCV 72-39, Containment_Spray_Pump_Header_Isolation.

NOTE 2 Power is lost to 1-FCV-74-12, Train A RHR Minimum Flow Valve.

RO 3. PLACE the following pumps in PULL TO LOCK:

. iA-ARHRPump

. iA-A_Containment_Spray_Pump NOTE I i-M-7 Instrument Rack A is normally powered from 480V Shutdown Bd 1A1-A. Power loss results in loss of various rad monitors, boric acid flow indication, and other MCR indications and controls.

NOTE 2 Restoration of power to Instrument Rack A may cause LCV-6-1 06B to open, resulting in condensate system flow changes.

LEAD Evaluator Note: I-M-7A Transfer to Alternate- coordinate with examiner)

Evaluator Note: Note I & 2 conditions should be restored andlor monitored following I-M-7 power supply transfer to the alternate source.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 16 of 47 Event

Description:

Loss of 1A1-A 480 VAC SDBd and lB-B CCS Pump fail to auto start Time Position N Applicants Actions or Behavior

4. RESTORE power to 1-M-7 Instrument Rack A by placing Instrument BOP Rack A Transfer Switch to ALTERNATE position.

[l-M-7, middle switch]

SRO 5. PERFORM Appendix AA, Potential Tech Spec Impacts

6. DISPATCH operators with radios to Shutdown Board Room [AB eI. 734]

CREW to determine cause of failure.

NOTES: . Service air isolation valve 0-PCV-33-4 will be closed due to loss of power on Instrument Power Rack A [1-M-7].

. P1-32-200, Control Air Hdr and P1-33-199, Service Air Hdr are NOT available while 480V SD Bd 1A1-A is de-energized.

BOP 7. EVALUATE air system status:

a. DISPATCH personnel to observe header pressure in the following locations:

. Auxiliary Control Air Header Pressure (El. 734 AB)

. Control Air Header Pressure (El. 685 TB)

b. CHECK Aux Control Air pressure greater than 90 psig.

BOP FM-is]

BOP c. CHECK control air pressure greater than 90 psig.

CAUTION: Loss of CRDM cooling fans can affect operability of rod position indicators due to temperature fluctuations.

8. EVALUATE starting additional CRDM cooling fans based on reactor RO/SRO cavity air temperature (Ti 01 4A) and RPI indications USING 0-SO-30-6.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 17 of 47 Event

Description:

Loss of 1AI-A 480 VAC SDBd and lB-B CCS Pump fail to auto start Time 1 Position ADDlicants Actions or Behavior SRO 9. ENSURE following equipment STOPPED and LOCKED OUT:

. lA-A Component Cooling Water Pump

. lA-A Thermal Barrier Booster Pump

. A-A Main Control Room AHU NOTE: Spare Charger 1-S Train A supply is from 480V Shutdown Board 1A2-A. Spare charger should be placed in service promptly to prevent excessive battery discharge.

SRO 10. ENSURE Battery Charger RESTORED for 125V Vital Battery I:

BOP a. VERIFY 480V Shutdown Board 1A1-A still DE-ENERGIZED.

b. PLACE Spare Charger 1-S in service to Vital Battery Board I USING 0-S0-250-1.

Evaluator Note: 1-M-1 Indicator 125V VITAL BATT BD I AMPS, I-EL-57-92: returns to 0 AMPS when the I-S Battery Charger is placed in service.

BOP 11. CHECK CCS to SFP Cooling ADEQUATE:

. ALIGNED to Unit 2 OR

. 1 B CCS Pump in service to Train A CCS

12. DISPATCH an operator to ensure SEP cooling in service USING 0-SO-BOP 78-1 CREW 13. REFER TO following Appendixes for additional equipment lost:

. Appendix B, 480V Shutdown Board 1AI-A Load List

. Appendix E, 480V Rx MOV Board IA1-A Load List

. Appendix G, 480V C & A Vent Board 1A1-A Load List

. Appendix I, 480V Reactor Vent Board lA-A Load List

. Appendix J, 480V Diesel Auxiliary Bd 1A1-A Load List

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 18 of 47 Event

Description:

Loss of 1A1-A 480 VAC SDBd and lB-B CCS Pump fall to auto start Time Position Applicants Actions or Behavior

14. EVALUATE need for starting additional Lower Compartment Cooling RO/SRO Units to maintain containment temperatures within Tech Spec limits.

15. EVALUATE need to transfer Fire Protection Distribution Panel power SRO supply to Alternate USING 0-SO-i 3-1, Fire Detection System.

16. CHECK 1A1-A 480V Shutdown Board ready to be ENERGIZED.

SRO (RNO Required)

RNO:

SRO DO NOT CONTINUE in this procedure UNTIL failure repaired.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event after the determination in step 16 above.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 19 of 47 Event

Description:

1 B #3 HDT Pump trip and 1-LCV-6-1 05A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 4 Indications available:

I-M-1 Annunciators:

I-XA-55-IB Window E-3: MOTOR TRIPOUT PNL I-M-I THRU I-M-6 1-M-1 Indicators:

Generator Megawatts Recorder, 1-XR-57-107: megawatts decreasing, stabilizing at 940 MWe I-M-2 Annunciators:

I-XA-55-2C Window A-I: LS-6-III NO 3 HEATER DRAIN TANK LEVEL ABNORMAL

B-7: ZS-6-105A & B NO 3 HTR DR TK BYPASS TO COND I-M-2 Indicators:

HTR DR SYSTEM FLOW, I-FR-6-107 Red Pen: slowly degrades to <5500 gpm;

EHC Display, I-XX-47-2000: Valve Pos Limit light illuminated (when runback is actuated)

Main Generator Electrical Load-MEGAWATTS decreasing to 940 MWe I-M-4 Annunciators:

I-XA-55-4B Window A-7: ZB-412A RODCONTROL BANKS LIMIT LOW

B-7: ZB-412B RODCONTROL BANKS LIMIT LOW-LOW 1-M-4 Indicators:

SG-3 MAIN REG VALVE FLOW CONTORL I-FIC-3-90: indicates full OPEN demand

SG PROGRAM LVL SP, I-LI-I-73: Program level 44% from 20-I 00% RTP

GENERATOR WATTS, I-EI-57-16A: decreasing to $40 MWe

ROD SPEED, SI-412 and adjacent RODS IN/RODS OUT red and green lights lit: indicating rod control controlling Tave.

Automatic actions may occur due to a malfunction of the heater drain system:

Turbine runback from #3 Heater Drain Tank Pump trip if greater than 81% turbine load.

T = 30 CREW Respond in accordance with Alarm Response Procedures Diagnose failure and place rods in manual to stop rod motion Refer to Annunciator Response Procedure SRO Enter AOP-S.04, Condensate or Heater Drains Malfunction Section 2.6 Evaluator Note: AOP-S.04, Section 2.1, #3 Heater Drain Tank Pump Trip crew may enter this section which will mitigate the event. Section 2.1 is included at the end of this event guide.

BOP 1. MONITOR the following:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 20 of 47 Event

Description:

lB #3 HDT Pump trip and 1-LCV-6-105A valve failure HDT system low flow runback Time Position I Applicants Actions or Behavior

. at least one #3 Heater Drain Tank Pump RUNNING AND

#3 Heater Drain Tank Pump flow greater than zero BOP recognizes 1 B #3 HDT Pump tripped and continues to monitor #3 HD system flow usinci 1-FR-6-107 flow recorder NOTE: Turbine runback will occur if the following conditions met:

3 HDT bypass valve, LCV-6-105A or 105B, is OPEN Turbine load is greater than 81% (Unit 1) or 82% (Unit 2)

3 HDT pump discharge flow, FS-6-107, less than 5500 gprn for greater than 10 seconds.

BOP 2. MONITOR for turbine runback conditions:

a. Turbine load greater than 81% (Unit 1) or 82% (Unit 2).

b. #3 Heater Drain Tank Outlet Flow less than 5500 gpm.

[M-2, FR-6-107

c. LCV-6-105A or 105B OPEN. [M-2}

3. VERIFY turbine runback to less than or equal to 77% (Unit 1) or 78%

BOP (Unit 2) turbine load (approximately 940 MWE).

Evaluator Note: As the transient stabilizes, Rod Control will fail resulting in a continuous CB D rod insertion at 8 steps/minute and Loop #3 FRV fails to respond in automatic.

RO 4. CHECK rods controlling in AUTO.

NOTE: If LEFM thermal power (U21 18) is inoperable, rod insertion limit curve must be raised by 3 steps. Rod insertion limit alarms and ICS display are NOT automatically adjusted when LEFM is inoperable.

5. MONITOR control rods above low-low insertion limit using ICS or COLR.

RD (RNO Required)

RNO:

RO INITIATE boration USING Appendix A.(attached to end o f this event guide)

SRO EVALUATE Tech Spec LCD 3.1.3.6 and 3.1.1.1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 21 of 47 Event

Description:

1 B #3 HDT Pump trip and 1-LCV-6-1 05A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior

. 3.1.3.6, CONTROL ROD INSERTION LIMITS Action A Applies Restore wli limits w/i 2 hrs., or reduce to less than or equal to that fraction of RATED THERMAL POWER which is allowed by the group position using the insertion limits specified in the COLR, or Ht Stby w/i 6 hrs.

AND

. 3.1.1.1, SHUTDOWN MARGIN Tavg Greater Than 200°F Applies immediately initiate and continue boration at 35 gpm until the SHUTDOWN MARGIN is restored (CB D Rods above the Lo-Lo RIL),

CAUTION: Feedwater temperature changes may impact core thermal power.

Evaluator Note: As the transient stabilizes, Rod Control will fail resulting in a continuous CB D rod insertion at 8 steps/minute and Loop #3 FRV fails to respond in automatic.

SRO may use or refer to AOP-C-01, ROD CONTROL SYSTEM MALFUNCTIONS, Section 2.1, Uncontrolled Rod Bank Movement: in response to this failure; it is attached to this event guide.

6. MONITOR Steam generator levels returning to program.

[M-4]

BOP (RNO Required)

RNO:

CONTROL Main Feedwater Pumps or Feed Reg Valves as required.

BOP MAINTAIN S/G generator levels on program.

IF low S/G level reactor trip is imminent, THEN TRIP reactor and GO TO E 0, Reactor Trip or Safety Injection.

BOP recognizes Loop #3 FRV failing to respond in automatic; takes manual control and restores #3 SG level to program. vi RO 7. MONITOR reactor power:

a. CHECK ICS thermal power indication AVAILABLE.

b. REDUCE turbine load as necessary to maintain 10-minute average oower less than applicable limit (3455 or 341 1 MWt).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 22 of 47 Event

Description:

lB #3 HDT Pump trip and l-LCV-6-105A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior

8. DISPATCH operators to investigate cause for loss of #3 heater drain BOP tank um flow:

. CHECK LCV-6-106A and -106B functioning properly.

. CHECK position of LCV-6-105A and 105B

. CHECK #3 heater drain tank pumps functioning properly.

NOTE 1: Recommended load rate is 1% per minute if turbine load reduction is needed.

NOTE 2: Severe MEW pump cavitation is likely if inlet pressure is less than 250 psig.

9. MONITOR Feedwater pump inlet pressure greater than 320 psig. [M-3, BOP P1-2-1291

10. MONITOR Condensate Booster pump suction pressure greater than 100 BOP psiq. [M-3, P1-2-771

11. CHECK VALVE POSITION LIMIT light DARK on I (2)-XX-47-2000, EHC BOP Dl SPLAY

12. IF C-7 Interlock LIT, BOP THEN RESET_Load_Rejection_Signal:

a. PLACE HS-1-103A and 103B, Steam Dump Control, in OFF.

b. PLACE HS-1-103D, Steam Dump Control, in RESET and VERIFY spring_return_to_TAVG.

c. VERIFY C-7, LOSS OF LOAD INTERLOCK alarm, DARK. [M-4A, 5E]

d. ENSURE Steam Dump demand is ZERO.

e. PLACE HS-1-103A and 103B, Steam Dump Control, in ON.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 23 of 47 Event

Description:

1 B #3 HDT Pump trip and 1-LCV-6-1 05A valve failure HDT system low flow runback Time 1 Position 1 AoDlicants Actions or Behavior

13. EVALUATE reactor power reduction to less than 60% USING one of the SRO following:

0-GO-5, Normal Power Operation OR

AOP-C.03, Rapid Shutdown or Load Reduction END OF SECTION SRO Go to Procedure and step in effect Evaluator_Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Manacement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when SRO directs appropriate plant procedure,

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 24 of 47 Event

Description:

lB #3 HDT Pump trip and l-LCV-6-105A valve failure HDT system low flow wnback Time Position Applicants Actions or Behavior AOP-C.O1, Section 2.1, Uncontrolled Rod Bank Movement IndicationslAlarms available to alert the crew are listed in the Indications section of this event guide.

Automatic actions that occur due to the heater drain system malfunction result in Turbine Runback from #3 Heater Drain Tank Pump trip if greater than 81% turbine load.

SRO may use or refer to AOP-C-O1, ROD CONTROL SYSTEM SRO MALFUNCTIONS, Section 2.1, Uncontrolled Rod Bank Movement:

SRO Enter and direct action of AOP-C.O1 Section 2.1

1. STOP uncontrolled rod motion:

RO a. PLACE rod control in MAN.

b. CHECK rod motion STOPPED.

CAUTION:

Control Rods should NOT be manually withdrawn during a plant transient.

2. CHECK for plant transient:

CREW

a. CHECK reactor power and T-avc STABLE.

RO 3. CHECK for instrumentation malfunction:

a. CHECK nuclear instrumentation OPERABLE.

b. CHECK RCS RTDs OPERABLE

c. CHECK turbine impulse pressure channels OPERABLE.

d. CHECK T-ref OPERABLE USING TR-68-2B.

e. CHECK Auctioneered T-avg OPERABLE USING TR-68-2B.

4. CHECK for inadvertent RCS dilution:

(RNO Required GO TO Step 6)

a. CHECK evidence of dilution INDICATED:

. VCT level indication

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 25 of 47 Event

Description:

lB #3 HDT Pump trip and 1-LCV-6-lO5A valve failure HDT system low flow runback Time ft Position Applicants Actions or Behavior OR

. T-avg rising unexplained with stable turbine load.

5. CHECK for inadvertent boration flow:

(RNO Required GO TO Step 6)

a. CHECK evidence of boration flow INDICATED:

. Batch counters flow indication OR

. VCT level indication OR

. T-avg dropping unexplained.

NOTE: When adjusting T-avg, reactivity changes should be accomplished by only one method at a time.

6. RESTORE T-avg to within 1.5°F of T-ref:

. POSITION control rods OR

. ADJUST turbine load OR

. ADJUST RCS boron concentration USING O-SO-62-7, Boron Concentration_Control.

7. EVALUATE the following Tech Specs/TRM for applicability:

.__3.1.1.1,_Shutdown_Margin_-T-avg_Greater than_200°F

. 3.1.1.4,_Minimum_Temperature for Criticality

.__3.1.3.1,_Movable_Control_Assemblies,_Group_Height

.__3.1.3.5,_Shutdown_Rod_Insertion_Limit

.__3.1.3.6,_Control_Rod_Insertion_Limits

. 3.2,_Power_Distribution_Limits_(entire_section)

8. CHECK cause of continuous rod motion IDENTIFIED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 26 of 47 Event

Description:

18 #3 HDT Pump trip and 1-LCV-6-105A valve failure HDT system low flow runback Time Position 1 Aoolicants Actions or Behavior

9. ENSURE Maintenance initiated as required.

10. ENSURE Plant Management notified of failure.

1 1. WHEN problem corrected AND automatic rod control is available, THEN PERFORM the followina:

a. ENSURE T-avg and T-ref matched within 1 °F.

b. PLACE control rods in AUTO USING 0-SO-85-1, Rod Control System.

12. GO TO appropriate plant procedure.

END OF SECTION

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 27 of 47 Event

Description:

lB #3 HDT Pump trip and l-LCV-6-105A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior AOP-S.04, Section 2.1, #3 Heater Drain Tank Pump Trip while pumping forward Annunciators/Indications are similar to those listed in this event guide for Section 2.4 SRO 2.t #3 Heater Drain Tank Pump Trip MONITOR at least one #3 HDT pump IF reactor power is greater than 80%

BOP RUNNING. AND total toss of #3 HDTP flow has occurred, THEN PERFORM the following:

a. TRIP reactor and GO TO 613.

Reactor Trip or Safety Injection.

b. DO NOT CONTINUE this procedure.

IF reactor power less than or equal to 80%,

THEN GO TO Section 2.6.

NOTE: Turbine runbacc will occur if the following conditions met 3 HDT bypass valve, LCV-6-1 05A or 1056, is OPEN

turbine load is greater ttan 81% (Unit 1) or 82% (Unit 2)

3 HDT pump dIscharge flaw, FS-6-107. less than 5500 gpni for greater than 10 seconds, BOP 2. MONITOR for turbine runback conditions:

a. Turbine load greater than 81% (Unit 1) a. IF runback has already occurred or 82% (Unit 2). OR is in progress.

THEN GO TO Step 3.

IF runback has NOT occurred, THEN GO TO Caution prior to Step 6.

1,. #3 Heater Drain Tank Outtet Flow b. GO TO Caution prior to Step 6.

less than 5500 gpm. M..2, FR-6..1071 c.__LCV-6-1 054 or 1056_OPEI&_[M-21

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 28 of 47 Event

Description:

1 B #3 HDT Pump trip and 1 -LCV-6-1 05A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior 2.1 #3 Heater Drain Tank Pump Trip

3. VERIFY turbine runback to less than INITIATE turbine ninback BOP or equal to 77% turbine load USING valve position limiter.

(approximately 940 MWE>.

RO 4 CHECK rods controlling in AUTO. PERFORM the following:

a ENSURE control rods in MANUAL

b. INSERT reds as necessary to restore T.avg within 3F ofT-ref.

NOTE If LEFM thrrnaI power (1J21 16) is inoperable, rod insertion limit curve must be raised by 3 steos. od insertion limit alarms and [CS display are NOT automatically adjusted when LEFM is inoperable.

RO 5. MONITOR control rods above low-low INITIATE boration USING Appendix A.

insertion limit using [CS or COLR.

EVALUATE Teth Spec. LCO 3.1.3.6 and 3.1.1.1.

CAUTION: Feedwater temperature changes may impact core thermal power.

BOP 6. MONITOR 5/0 levels retumg to program.. CONTROL Main Feedwaier Pumps or Feed Reg Valves as required.

MAINTAIN 5/0 levels on program.

IF low S/S level reactor trip is imminent, THEN TRiP reactor and GO TO E-0, Reactor Trip or Safety Injection.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 29 of 47 Event

Description:

lB #3 HDT Pump trip and 1-LCV-6-105A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior NOTE An auto valve closure for LCV-6-iOBB exists if any one of three #3 Heater Drain Tank Pumps trip and turbine load is greater than 81% (Unit 1) Or 82%: (Unit 2).

7. CHECK LS-6-1 11 #3 1-IEATER DRAIN TANK PERFORM the following:

BOP LEVEL ABNORMAL alarm, DARK.

IM-2C, All a. DISPATCH an operator o:

a CHECK #3 Heater Drain Tank level [Turb Eidg, 685 elevl.

VERIFY LCV-6-IOSA and 1066 operating. as required [Turb BLdg, 662.5 elev, between column T3-D and T3-E.

b. IF #3 heater drain tank level is high, ThEN ENSURE LCV-6-IOSA and 1056 OPEN as required [M-2. XX-6-fl, RO 8. MONITOR reactor power:

a. CHECK ICS thermal power indication a. REDUCE turbine load as necessari AVAILABLE, to maintain reactor power less than or equal to 100%.

GO TO Caution prior to Step 9.

SRO b. REDUCE turbine load as necessanj to maintain 10 minute average power less than applicable limIt (3455 or 3411 MWt).

CAIJTION Reducing turbine load too rapidly could result in further drop in condensate pressure due to reduction in heater drain flow. Recommended load rate is 1% per minute if turbine load reduction is needed.

, MONITOR Feedwater pump inlet pressure REDUCE turbine lead UNTIL feed pump BOP greater than 320 psig. [M-3, P1-2-1291 inlet pressure greater than 321) psig.

BOP 10. MONITOR Condensate Booster pump REDUCE turbine load UNTIL condensate suction pressure greater than 100 psig. booster pump suction pressure tM-3, P1-2-77] greater than 100 psig.

11. DISPATCH an operator to investigate cause CREW of #3 Heater Drain Tank Pump trip.

12. NOTIFY Maintenance to investigate and CREW repair pump maTh.nctfon as necessary.

13. CHECK VALVE POSITION LIMIT light RESTORE turbine controls to normal BOP DARK on i(2)-XX-47-2000, USING Appendix B, Turbine Runbac1 EF4C DISPLAY. Restoration.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 30 of 47 Event

Description:

1 B #3 HDT Pump trip and 1 -LCV-6-1 05A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior NOTE: Steam dump load rejection circuit may require several minutes decay time before C-? can be reset BOP 14. [F C-7 InteriocI LIT, THEN RESET Load Rejection Signal:

a. PLACE HS-1-103A and 103, Steam Dump Confrol, in OFF

b. PLACE HS-1-103D, Steam Dump Controi, in RESET and VERIFY spring return to TAVG.

c. VERIFY C-7, LOSS OF LOAD INTERLOCK alarm, DARK.

[M-4A, 5E]

d. ENSURE Steam Dump demand is ZERO.

e. PLACE HS-1-103A and 10E, Steam Dump Controi. in ON.

I5 CHECK reactor power less than 95 %, IF #3 KDTF CANNOT be restored RO within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , THEN EVALUATE power reduction to less fran 95% using 0-00-5, Normal Power Operation.

16. GO TO appropriate plant procedure.

SRO END OF SECTION SRO Go to Procedure and step in effect Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when SRO directs appropriate plant procedure,

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4 Page 31 of 47 Event

Description:

lB #3 HDT Pump trip and 1-LCV-6-105A valve failure HDT system low flow runback Time Position Applicants Actions or Behavior AOP-S.04, CONDENSATE OR HEATER DRAINS MALFUNCTION APPENDIX A IMMEDIATE BORATION TO RESTORE RODS ABOVE LOW-LOW ROD INSERTION LIMIT

[1) IMMEDIATELY INiTIATE boration by performing the following:

[aj PLACE BA transfer pump aligned to blender in FAST speed. D

[b] ADJUST FcV-62-1 38 as necessary to establish boration flow greater than or equal to 35 gpm from BAT (at least 6120 ppm) Li c1 IF required flow via FCV-62-138 CANNOT be established, THEN PERFORM one of the following:

. INITIATE normal boration of greater than or equal to 35 gprn from BAT (at least 6120 ppm)

USING 0-SO-62-7 Sect. 64 Li OR

. INITIATE boration flow of greater than or equal to 90 gpm from RWST USING 0-80-62-7 Sect &4 fd] WHEN control rods are verified to be above low-low insertion limit.

THEN REDUCE or STOP horation flow as required. Li END

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 32 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available:

Annunciators:

I-M-3 indications:

. SG-3 MAIN REG VALVE FLOW CONTORL I-FIC-3-90: indicates full OPEN demand I-M-4 Annunciators

. XA-55-4D Window A-3 LD-3-97B STM GEN LOOP 3 LEVEL LOW-LOW REACTOR TRIP I-M-4 indications:

. LOOP 3 SG-3 NR LEVEL indicator I-LI-3-97: varies, then goes down;

I-Ll-3-94: varies, then goes down;

I-LI-3-93: varies, then goes down;

. LOOP 3 SG-3 FW INLET FLOW CH-I indicator I-FI-3-90A: varies, then goes down;

. CH-2 indicator I-Fl-3-90B: varies, then goes down; I-M-5 indications:

. LOOP 3 SG-3 NR LEVEL indicator I-LI-3-97: varies, then goes down;

. I-LI-3-94: varies, then goes down;

I-LI-3-93: varies, then goes down;

. LOOP 3 SG-3 FW INLET FLOW CH-I indicator 1-Fl-3-90A: varies, then goes down;

. CH-2 indicator I-FI-3-90B: varies, then goes down; I-M-6 Annunciators

. XA-55-6B Window C-I LS-3-94D STM GEN LOOP 3 LOW FW FLOW LOW WATER LEVEL

. C-4 LS-3-93B STEAM GENERATOR LOOP 3 LOW LOW WATER LEVEL

. C-7 FS-3-90B STM GEN LOOP 3 STEAM/FEEDWATER FLOW MISMATCH T = 40 BOP Identifies failed closed Loop #3 FRV and makes a crew announcement.

SRO Directs reactor triD, IQAs performance Evaluator Note: following IOA performance, prior to Steps 1-4 immediate action verification, RO/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5. 6, 7. 8. 9 Page 33 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand/ Loss of Ofisite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time 1 Position I Aoolicants Actions or Behavior E-O, Reactor Trip or Safety Injection Note I Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page

1. VERIFY reactor TRIPPED:

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN RO

Neutron flux DROPPING

Rod bottom lights LIT

Rod position indicators less than or equal to 12 steps.

2. VERIFY turbine TRIPPED:

BOP e Turbine stop valves CLOSED.

Evaluator Note: Critical Task is manually start at least I EDG prior to placing safeguards loads P-T-L in ECA-O.O.

(BOP may attempt to start both EDGs at 1-M-1 using 1-HS-82-15, DG EMERG START

!A-A, 2A-A, 1 B-B, 2B-B or O-M-26A1B panel emergency start PBs O-HS-82-1 6A and 0-HS-82-46A for lA-A and 1 B-B EDGs respectively. Either location/control will achieve the expected response.)

3. VERIFY at least one train of shutdown boards ENERGIZED.

. Attempt to restore power to at least ONE train of shutdown boards BOP

Place DG lA-A control switch in START

Verify Train A Shutdown Boards ENERGIZED

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 34 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position AIicants Actions or Behavior

4. DETERMINE if SI actuated:

. ECCS pumps RUNNING.

RO

. Any SI alarm LIT [M-4Dj (SI will be actuated)

(RNO Required)

RNO:

DETERMINE if SI required:

a. IF any of the following conditions exists:

S/G pressure less than 600 psig, RO OR

RCS pressure less than 1870 psig, OR

Containment pressure greater than 1.5 psig, THEN ACTUATE SI.

CREW Determines SI Actuation NOT required by current conditions

b. IF SI is NOT required, THEN SRO PERFORM the following:

1) MONITOR status trees.

2) GO_TO_ES-0.1,_Reactor Trip_Response.

SRO SRO determines SI not required; SRO implements status tree monitoring and transitions to ES-0.1, Reactor Trip Response.

Since a loss of off site power occurred at initiation of the event, AOP-P.01, LOSS OF OFFSITE POWER will be handed off to the BOP to complete. It is attached to the end of this event guide.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5. 6. 7. 8. 9 Page 35 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position 1 Aoølicants Actions or Behavior ES-O.1. Reactor Trip Response Evaluator Note: Events8& 9, lB-B AFW Pump Airbound and Ui TDAFW Pump Mechanical over speed trip actuate with the reactor trip. Since the lA-A MDAFW Pump is out of service for maintenance, a loss of all AFW flow occurs and results in RED path conditions for Heat Sink safety function. The crew should identify this RED path condition and the SRO should transition to FR-H.1, Loss of Heat Sink. Expected indications and operator actions contained at end of this guide.

Note: This procedure has a foldout page.

1. MONITOR SI NOT actuated:

RO

. SI ACTUATED permissive DARK[M-4A, D4}

BOP 2. VERIFY generator breakers OPEN.

3. MONITOR RCS temperatures:

. IF any RCP running, THEN CHECK T-avg stable at or trending to between 547°F and 552°F.

RO OR

. IF RCPs stopped, THEN CHECK T-cold stable at or trending to between 547°F and 552°F.

4. CHECK feedwater status:

BOP a. T-avg less than 550° F.

b. MFW pumps TRIPPED.

c. MEW regulating valves CLOSED.

d. MFW regulating bypass valve controller outputs ZERO.

e. MEW isolation valves CLOSED.

5. CHECK total feed flow to S/Gs greater than 440 gpm.

BOP (RNO Required)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 36 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDG5 fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position Applicants Actions or Behavior RNO:

BOP ESTABLISH AFW flow as necessary.

IF AFW flow CANNOT be established, SRO THEN ESTABLISH main feedwater flow USING EA-2-2, Establishing Secondary Heat Sink Using Main Feedwater or Condensate System.

Since the initiating event included a loss of off-site power, EA-2-2 cannot be SRO implemented and directs the BOP to implement 1-FR-0, Status Tree Monitoring (for implementation).

BOP identifies FR-H.1 Red Path condition:

. <440 gpm AFW flow, not by operator action; and,

. <10% in all SGs BOP Informs the SRO as the highest RED/ORANGE path critical safety function challenae.

SRO Directs transition to FR-H.1 from ES-0.1 step in effect (5)

Lead Evaluator Note: The scenario may be terminated as directed by the Lead Examiner once the crew restores secondary heat sink control either by venting the 1 B-B MDAFW Pump or by resetting the TDAFW Pump resulting in positive SG level increase/RCS temperature change.

FR-H.1 , LOSS OF SECONDARY HEAT SINK CAUTION: Unisolating a faulted S/G or secondary break should NOT be considered UNLESS needed for RCS cooldown.

CAUTION Feeding an intact or Ruptur&d SIG is preferred to feeding a Faulted SIG.

Thermal stresses From: feeding a Faulted SIG could rupture tubes resulting in a Faulted-AND-Ruptured 51G.

Aoøendix D Required Operator Acfions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5,6.7,8,9 Page 37 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, lB-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position Applicants Actions or Behavior

1. DETERMINE procedure applicability:

BOP a. CHECK the followIng: a. GO TO Step Z

Total feed flow less than 44gpm due to operator action dIrected by another procedure.

AND

. Total feed flow capability of greater than 440 gpm AVAILABLE.

b RETURN TO procedure and step in effect SRO Continues in FR-Hi

2. MONITOR RWST level IF RHR pumps aligned to RWST, greater than 27%. THEN GO TO ES-I .3, Transfer to RHR RO Containment Sump.

3. CHECK if secondary heat sink required:

RO a RCS pressure greater than any a RETURN TO procedure and step non-Faulted SJG pressure. in effect.

I....

Crew determines faulted SG(s) not the initiating conditions; CREW!

SRO Continues

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 38 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand? Loss of Offsite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position Applicants Actions or Behavior b RCS iemperatsre b. ATTEMPT to place RHR System greater than 350F. in service USING EA-74-1, Placing RO RHR Shutdown Cooling in Service, WHILE continuing with this procedure, WHEN adequate RHR cooling established, THEN RETURN TO procedure and step in effect.

4. MONITOR at least one CCP available. STOP all RCPs.

RD GO TO Caution prior to Step 17.

NOTE Pressurizer pressure greater than or equal to 2335 psig with rising RCS temperature and a tow loop deita-T indicates loss of heat removal capability.

SRO

MONITOR ICS feed and bleed criteria:

BOP a. CHECK the following: a. GO TO Step &

. Any three S/C wide ranoe leveis less than 20% 141% ADv1 OR RD

Pressurizer pressure greater than or equal to 235 psig due to loss of secondary heat removal.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 39 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, I B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time Position Applicants Actions or Behavior ti. STOP RCPs.

RO C. GO TO Caution prior to Step 17.

6. MONITOR CST level greater than 5%. AUGN AEW suction to ERCW BOP USING EA-3-9, Establishing Turbine Driven AFW Flow, and EA-3-1G, Establishing Motor Driven AEW Flow.

7. ATTEMPT to establish AEW flow to BOP at least one SIG in the following order of prioriti Intact, Ruptured, Faulted:

a. CHECK SIG blawdown isolation a. CLOSE valves.

valves CLOSED.

b. CHECK control room indications for BOP cause of AFW failure:

CST level

AFW pump power supply

AFW valve alignment

7. c ESTABLISH MD AW pump iiow c. PERFORM the following:

BOP

1) ENSURE MD AFW pumps

REFER To EA310, EstabliShing RUNNIFliG Motor Drwen AFW Flow, as necessar

2) ENSURE AFW level control

DISPATCH personnel to restore vaves OPEN.

MO AEW pump flow.

3) ENSURE MD AFW recirculation valves FCV-3-400 and FCV-3-401 CLOSED.

Appendix D Recuired Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 40 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDc3s fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time I Position 1 Aoolicants Actions or Behavior

d. ESTABLISH TD AFW pump flow: d. PERFORM the following:

BOP 1) ENSURE turbine steam supply

REFER TO EA-3-, Establishing valves OPEN: Turbine Driven AFW Flow as necessaiy

Either FCV- 1-IS or FCV-1-1 6

DISPATCH personnel to restore

FCV-1-17 and ECU-I-IS TO AFW pump flow.

Trip and ihrote valve, FCV-1-51

2) ENSURE AFW level aontrol valves OPEN.

BOP

3) RAISE TD AFW pump speed as necessary.

NOTE Continuous actions in Step 8 are NOT applicable after RCS feed and bteed is initiated_in_Step_17.

8. MONITOR for AFW flow:

BOP

a. CHECK total AEW flow to SIGs a. IF NO AFW flow can be verified, greater than 440 :gpm. THEN:

1) ENSURE personnel dispatched to locally restore AFW flow.

2) GO TO Step 9.

Evaluator Note: Critical Task is Establish feedwater flow into at least one SG before RCS feed and bleed is required. Crew should have at least I AFW Pump with flow established to at least 2 SGs.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 5, 6, 7, 8, 9 Page 41 of 47 Event

Description:

Loop #3 FRV (1-LCV-3-90) Fails closed resulting in a Reactor Trip demand! Loss of Offsite AC Power, Both EDGs fail to Auto Start, 1 B-B MDAFW Pump is airbound and the TDAFW pump mechanical overspeed trip actuates.

Time N Position N Applicants Actions or Behavior

b. RETURN TO procedure and step in effect.

SRO Determines ES-O.1 step (5) in effect Lead Examiner may terminate the scenario once the crew restores secondary heat sink control either by venting the lB-B MDAFW Pump or by resetting the TDAFW Pump resulting in positive SG level increaselRCS temperature change and a transition procedure and step in effect is determined.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 42 of 47 Event

Description:

Loss of Off Site Power Time Il Position I Aoolicants Actions or Behavior AOP-P.O1, Loss of Off Site Power 20 OPERATOR ACTIONS

1. DIAGNOSE the faiure:

GO TO IF... SECTION PAGE CREW Complete loss of on-site power 21 4 Partial Loss of Offsite Power:

A or B start busses de-eneroized 29 OR b loss of normal supply to individual shutdown board (shutdown board energized from DIG)

CREW NOTE: Steps I and 2 are immediate actions.

1. CHECK Diesel Generators RUNNING EMERGENCY START avaIlable DiGs.

SOP and supplying shutdown boards.

BOP 2. CHECK ERCW supply valves to DIGs ENSURE normal or alternate ERCW supply OPEN. valve OPEN.

IF any diesel generator running AND cooling water IIOT available, THEN EMERGENCY STOP affected diesel generator(s).

I MONtTOR BOTH 900V shutdown IF NO 6900V stuitdown lard is ENERGIZED BOP boards on this unit ENERGIZED. on this unit; Ti-lEN PERFORM The following:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 43 of 47 Event

Description:

Loss of Off Site Power Time Position I Applicants Actions or Behavior

a. IF unit is in Mode 1-4, THEN SRO ENSURE ECA-O.O, Loss of All AC Power has been entered.

b. IF unit is in Modes 4-6.

THEN SRO ENSURE AOP-R.03, RHR System Malfunction, has been entered, WHH F 1.fl LIiLIUIIlt4 in This

c. IF any DIG is available (capable of starting),

THEN SRO PERFORM Appendix 5, Manually Energizing Shutdown Board from DIG.

d. WHEN off-site power is available, THEN PERFORM Section 2.3. Recovery from Loss of Offsite Power.

e. DO NOT CONTINUE Section 2.1 UNTIL at least one shutdown board j

IF one 6900V shutdown board is ENERGIZED SRO on this unit, ThEN PERFORM the following:

RO a. ENSURE available CCP r SRO b. IF NO CCP is available THEN PERFORM the following:

1) IF Phase B is NOT actuated.

THEN RO ENSURE RCP thermal barrier cooling:

one CCS pump RUNNING aligned to supply Train A CCS.

BOP

one TB8P RUNNING.

2) REFER TO AOP-M.O9, Loss of Charging.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 44 of 47 Event

Description:

Loss of Off Site Power Time 1 Position N Aoolicants Actions or Behavior C. IF any DIG avaiable (capable of starting),

SRO THEN PERFORM Appendix 5, Manually Energizing Sttutdown Board from D/G.

d. PERFORM applicable AOP for loss of SRO shutdown board as time allows:

AOP-PO5 (Unit I Shutdown Boards)

AOP-R06 lJnit 2 Shutdown Boards

e. IF off-site power is av*ailalie SRO AND rapid restoration is needed, THEN PERFORM Sect. Z3, Recovery from Less of Offsite_Power.

4. NOTIFY SM to pert&n, the following:

SRO

a. EVALUATE EP[P-1, Emergency Plan Classification Matrix

b. INITIATE staffing of TSC and OSC USING Emergency Paging System.

CREW 5. REcORD time of loss of oft-site power.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 45 of 47 Event

Description:

Loss of Off Site Power Time N Position 0 Applicants Actions or Behavior

& MONITOR diesel generator loading:

BOP a VERIFY DIG load sequencing USING Apoendi B. Loss of Offsite Power Diesel Generator Load Sequence [C.2].

h. ENSURE four ERCW pumps RUNNING (one per shuidowo board).

c. MONITOR diesel generator(s) load C. REDUCE excess diesel generator load less than or equal to 4.4 MW USING Appendix A Diesel Generator (4.5 MW for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ). Load Evaluation List tC.11.

7. CHEEK charging system operation:

RO

a. ENSURE all RCS dilution activities STOPPED.

b. ENSURE CCP suction aligned to RWST:

I) OPEN LCV-62-i 35 or LCV-62-136.

2) CLOSE LCV-62-132 or LCV-52-133.

CAUTION I Failure to promptly restart air compressors and restore non-essential air to containment will delay restoration of letdown. This may result in uncontrolled pressurizer level rise and PORV opening.

CAUTION 2 Opening Train A ERCW supply to Station Air Compressors with ERCW tarp greater than 82.3°F makes Train A MCR Chiller and EBR Chiller inoperable due to inadequate ERCW flow. This would place both units in LCO 3,0.5.

NOTE Starting control air compressors will add about 0.1 MW to DIG 1-A and iB-B E RESTORE control ai BOP a PLACE MSIV handswitches in CLOSE_position.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 46 of 47 Event

Description:

Loss of Off Site Power Time Position Applicants Actions or Behavior

b. ESTA8IJSH coo[ing water to station b. IF Train 8 ERCW supply NOT available CREW air compressors: AND ERCW temp is less than 82.3F

1) VERIFY Train B ERCW auailabis.

FCV-B725, Train A ERCW

2) ENSURE FCV-672O8 Train B to: air compressors. [13-M-27A]

ERCW to air compressors OPEN.

[-M-27AJ

a. DISPATCH an operator to start BOP Station Air Compressors A and B USING EA-32-2, Establishing Control and Service Air.

ci. ENSURE auxiliary air compressors d. WHEN control air pressure is BOP RUNNING. [M-15 or AG el 734] greater than 75 psig, (powered from Unit 2 S1utdown Bds) THEN AUGN control air to supply auxiliary air USING EA-32-2.

8. e. CHECK Phase B NOT actuated. e, IF Phase B actuated.

RO THEN GO TO Note prior to Step 9.

BOP WHEN control air pressure restored, THEN RESTORE air to containment USING EA32i:, Establishing Control Air to Containment.

NOTE: 0-50-82-1, 2, 3, 4 Appendix C contains normal DIG running parameters.

Copies of these appendices may be obtained from AOP-C.04 cabinet in DIG Bldg.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # AOP-P.O1 Page 47 of 47 Event

Description:

Loss of Off Site Power Time Position Aoolicants Actions or Behavior BOP 9 DISPATCH operator to DIG euHding to monitor diesel generators USING OSO-82-1 2, 3 4 App C Evaluator Note: During AOP-P.O1 implementation, the crew performs through step 9, which contains actions important to support current operating strategies; further activities, while important, are administrative or are delegated to plant personnel outside the MCR.

Appendix D Scenario Outline Form ES-D-1 Facility: Sequoyah Scenario No.: 3 Op Test No.: NRC Examiners: Operators:

Initial Conditions: 3-4% RTP, 1A Main Feedwater Pump is in service.

Turnover: Continue plant startup. Operations are complete though O-GO-4.Section 5.2 Step 2 Target CTs: Start at least 1 EDG prior to placing equipment PTL in ECA.O-O Start at least 1 CCP prior to completion of E-O Start at least 1 A Train ERCW Pump in an operating safeguards train Event No.

1. N/A Maif. No.

J Event Type*

R-RO Continue Power Increase to MODE 1 Event Description N-SRO/BOP T÷O

2. Nl04 l-RO Intermediate Range channel N-35 failure low (>5% RTP at initiation)

TS-SRO T+1O 3 CNO1 B C-BOP. 1 of 2 running Hotwell Pumps Trip (1 B Hotwell Pump);

T+20 4 RWO1G C-BOP Q-A ERCW Pump Over current trip TS-SRO T÷30

5. RCO7A C-RO PORV 68-334 fails open. The PORV can be closed manually TS-SRO T+40

6. THO2B M-All RCS Leak T+50 7 THO2B M-All SBLOCA/Loss of offsite power resulting in a loss of power to both 6.9 kV EDO1 Shutdown Boards T+55

8. ZDIHS8215 C-BOP 1-M-1 Common Start Switch MaIf EGO8A- lA-A EDG fails to start in Automatic T+55 EGO3B- 1 B-B EDG trips and cannot be restarted pre-insert 9 CV35 C-RO IA-A CCP fails to start in Automatic pre-insert T+55

10. RP16K61 1A C-BOP Selected A Train Safety Injection Loads fail to start automatically T+55 (N)ormal, (R)eactivity, ( I )nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Scenario 3 Summary The crew will assume the shift with the unit in startup at 3-4% RTP, controlling SG levels with main feedwater, ready to proceed to MODE 1. Following the briefing summary, the crew will raise reactor power starting in 0-GO-4 Section 5.2 Step 3.

At the direction of the Lead Examiner, an Intermediate Range NI will fail requiring action to remove it from service in accordance with AOP-I.01, Section 2.2. SRO will refer to Technical Specifications 3.3.1.1 Table 3.3-1 unit 5 Action 3, 3.3.3.7 Table 3.3.10 instrument 17 Action 1 and 3.9.2 Action a.

At the direction of the Lead Examiner, 1 B Hotwell Pump will trip. The crew refers to alarm response procedures (ARPs) 1-AR-Mi B, E-3 and will start the standby Hotwell Pump according to AOP-S.04, Section 2.4.

At the direction of the Lead Examiner, Q-A ERCW Pump will trip; the crew will refer to ARPs 1-27A A-i and C-2, 1-AR-M27B-A E-3 and E-4 and should go to AOP-M.0i, Section 2.1 which directs manually starting J A ERCW Pump and repositioning the DG Power Selector for proper safeguards actuation. SRO will refer to Technical Specifications 3.7.4.

When standby ERCW Pump is in service, at the direction of Lead Examiner direction, a Pzr PORV will fail open causing an uncontrolled RCS Pressure drop. The crew should close the block valve and refer to ARPs 1-AR-M5A D-2, E-2 and 1-AR-M5C B-6 directing entry into AOP-l.04, section 2.1. The crew should also refer to 0-SO-68-3, section 8.3 to close the associated block valve. SRO will refer to Technical Specifications 3.2.5.b and LCO 3.4.3.2 action a (See TS Bases for PORV operability).

The RCS leak occurs and progresses into a SBLOCA. The crew responds to alarms by referring to ARPs i-AR-5C B-i, B-3, 1-AR-M 6E C-6 directing them to AOP-R.05 Section 2.1 for lowering Pzr level and a challenge to VCT Make-up capability. Subsequently the crew will initiate a reactor trip and enter E-0.

Shortly after the trip, offsite power is lost, iA-A EDG fails to automatically start and must be manually started since Common Start Sw 1-HS-82-15 on 1-M-i fails to actuate a start signal. lB-B EDG trips and cannot be re-started. The crew must start lA-A EDG using Emergency Start PB 0-HS-82-16A on back panel 0-M-26A and place it on the bus to avoid entering ECA-0.0 [Note; ECA-0.0 MAY be entered briefly (through Step 8) prior to starting EDG].

Additionally, selected A Train Safety Injection Loads: lA-A CCP, iA-A MD AFW Pump, Train A SI signal to TDAFW Pump and ERCW Pumps J-A, Q-A, K-A and R-A (if selected) fail to automatically start. Starting the CCP is critical to a SBLOCA with the unavailability due to the loss of AC power. Re-starting the J-A ERCW Pump is critical for long term cooling of iA-A EDG and lA Header ECCS loads due to the Q-A Pump loss.

EOP flow: E-0 E-1 ES-i .2 The scenario may be terminated at the direction of the Lead Examiner, when ES-i .1, Post LOCA Cooldown transition is determined.

PSA significant task: Start EDG, IA-A COP and J-A ERCW Pump PSA significant DAS: SBLOCA PSA significant component failure: Pzr PORV, iA-A EDG, Q-A ERCW Pump Appendix D NUREG 1021 Revision 9

1002 ESG-3 Page 1 of 5 APPENDIX C Time: Now Date: Today Unit! MCR Checklist Part I - Comoleted by Off-aoina Shift I Reviewed by On-comma Shift Mode 2, 3-4% Power - - MWe NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID 02 gpm, UNID .01 gpm Until 0800 X)OO(

RCS boron: 1710 ppm After 0800 )O(XX Cmn.1ech Spec Actions, :

LCOITRM Equipment INOP Time INOP Owner RTS None None LCOJTRM Equipment INOP Time INOP Owner RTS None None - - - - - - - - - - -

None Shift Piiitie Raise power to 13-15%; prepare for Main Generator Synchronization.

LI Verify your current qualifications (re: OPDP-1 Section 7.3 F.)

Q Review Operating Log since last held shift or 3 days, whichever is less.

Review the following for changes since last shift turnover:

Q 0DM Is/Standing Orders! Q LCO actions Q PERs (applicable to unit)

Shift Orders E TACFs Operator workarounds, burdens, Immediate required reading and challenges

[J Walk down of MCR Control Boards

1002 ESG-3 Page 2 of 5 APPENDIX C Time: Now Date: Today MAIN CONTROL ROOM (7690)

Train A Week OUTSIDE (7666)[593-5214] -

None AUXILIARY BUILDING (7775)

None TURBINE BUILDING (7771) (593-8455)

None

1002 ESG-3 Page 3 of 5 Time: Now Date: Today MCR Red Dot List UNID And Noun Name Panel Problem Description WO I PER Number Date Scheduled MCR WO List ID And Noun Name Panel Problem Description WO/PER Number Date Scheduled

1002 ESG-3 Page 4of5 UNIT ONE REACTIVITY BRIEF I Date: Today Time: Now 1

-:GeneraI1fl RCS Boron: 1710 ppm Today BA Controller Setpoint: 46.3% RCS B-b Depletion: 52 ppm Operable BAT: A BAT A Boron: 6850 ppm BAT C Boron: 6850 ppm RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 50 gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting jaw 0-SO-62-7 section 5.1 r- . :..- - -

Estimated values

-.-- for a 10 ChanGe an Tave

-r-- -. -

Gallons of acid: 26 Gallons of water: 136 Rod Steps: 3 Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 196 Steps on bank D 99 gallons 30% 173 Steps on bank D 292 gallons 50% 151 Steps on bank D 481 gallons These values are approximations and not intended nor expected to be exact. The values may be superseded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

Previous Shift Reactivity Manipulation s - -U.r-- - --_;--

I I

Number of dilutions: 1 Number of borations: 0 Rod steps in: 0 Gallons per dilution: 12 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 12 Total amount borated: 0 Net change: 0 IN/Out I;..... :u,-<._._-:. :-

flt3lMEStIfl Manipulatb, Number of dilutions:

Number of borations: 0 Rod steps in: 0 Gallons per dilution:

Gallons per boration: 0 Rod steps out: 0 Total expected dilution: Total expected boration: 0 Net change: 0 In/Out Remarks:

Per the RE Reactivity Spreadsheet Rx Power: 3-4% Burnup: 10,000 Mwd/mtU Xenon: -54.7 pcm, equilibrium Samarium: 544 pcm Last Dilution Completed:

Next Unit 1 Flux Map is scheduled - three weeks from now Unit 1 M-P is 0 PPM Unit Supervisor:

Name/Date

1002 ESG-3 Page 5 of 5 Operations Chemistry Information Boron Results L .a..

Sample Point Units Boron Date I Time Goal Limit Ui RCS ppm 1710 Today/Now Variable Variable U2 RCS ppm 816 Today/ Now Variable Variable Ui RWST ppm 2601 Today! Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today / Now 2550 2650

- 2500 2700 BAT A ppm 6850 Today / Now Variable Variable BAT B ppm 6850 Today / Now Variable Variable BAT C ppm 6850 Today / Now Variable Variable Ui CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 Ui CLA#2 ppm 2575 Today/Now 2470-2630 2400-2700 UI CLA #3 ppm 2591 Today / Now 2470-2630 2400-2700 UI CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today! Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today / Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today / Now > 2050 2000 Uthium Resulti : Goal Midpdint Ui RCS Lithium ppm 1.1 Today! Now >1 >1 U2 RCS Lithium ppm 2.43 Today! Now 2.18-2.48 2.33 Pnrnary to SecQndary Leakrate Information (Total ORM Indicator Units UI Date/Time U2 Date/Time SI 50 S!G Leakage? Yes/No No Today! Now No Today / Now SI 137.5 CVE Leakrate gpd < 0.1 Today! Now < 0.1 Today! Now 5 gpd leak equivalent cpm 370 Today! Now 111 Today / Now 30 gpd leak equivalent cpm 1970 Today! Now 464 Today I Now 50 gpd leak equivalent cpm 3250 Today! Now 747 Today / Now 75 gpd leak equivalent cpm 4850 Today! Now 1 100 Today! Now CVE Air Inleakage cfm 10 Today! Now 12.5 Today / Now Bkgd on 99/1 19 cpm 50 Today! Now 40 Today! Now Correction Factor 99/119 cpm!gpd 64 Today! Now 14.13 Today! Now Steady state conditions are necessary for an accurate determination of leak rate using the CVE Rad Monitor

Unit 1 DELTA REACTOF POWER ASSUMEIDINSERTEDEXPECTEDELTA RHC BORON DELTA ECOMMENIRECOMMEN[ IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATION CONC (hrs) (%) (pcm) (steps) (pcm) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0 4.0 73.1 180.0 -430.8 -54.7 1710.0 --- 0.1 1 9.0 160.6 182.0 -401.0 -55.6 58.6 1700.6 -9.4 371 0 0.7 2 15.0 262.1 186.5 -346.5 -63.8 55.1 1691.7 -8.9 351 0 1.8 3 15.0 262.6 187.0 -341.5 -79.9 11.8 1689.8 -1.9 75 0 3.1 4 18.0 310.8 188.0 -326.4 -102.9 56.0 1680.9 -9.0 357 0 4.5 5 20.0 343.5 189.0 -312.6 -132.7 48.7 1673.0 -7.8 312 0 5.9 6 22.0 375.0 190.0 -298.9 -168.7 53.8 1664.4 -8.6 346 0 7.4 7 27.0 452.4 196.0 -233.7 -211.0 54.4 1655.7 -8.7 351 0 9.1 8 30.0 498.7 200.0 -191.5 -259.7 52.9 1647.2 -8.5 343 0 11.0 9 30.0 499.8 200.0 -190.8 -314.3 54.9 1638.4 -8.8 357 0 12.8 10 30.0 500.8 201.0 -180.8 -373.0 49.8 1630.4 -8.0 324 0 14.5 11 30.0 501.8 202.0 -170.8 -434.3 52.3 1622.0 -8.4 342 0 16.1 12 30.0 502.8 203,0 -160.8 -496.9 53.7 1613.4 -8.6 352 0 17.4 13 30.0 503.8 204.0 -150.9 -559.9 54.0 1604.7 -8.7 356 0 18.7 14 30.0 504.8 205.0 -141.3 -622.2 53.8 1596.1 -8.6 356 0 19.8 15 30,0 505.9 207.0 -122.9 -683.5 43.8 1589.1 -7.0 291 0 20.8 16 30.0 506.7 208.0 -113.5 -743.0 51.0 1580.9 -8.2 339 0 21.7 17 30.0 507.7 209.0 -104.2 -800.6 49.2 1573.0 -7.9 328 0 22.5 18 30.0 508.6 209.0 -103.8 -855.9 55.8 1564.1 -8.9 373 0 23.2 19 30.0 509.6 209.0 -103.3 -908.7 53.4 1555.5 -8.6 359 0 23.9 20 30.0 510.7 209.0 -102.9 -958.9 50.8 1547.4 -8.1 342 0 24.5 1000 MWD/MTU Hold Tavg = Tref +1- 1 .5F Total 6628 0 6820 BAT ppm Small hourly boration/dilution volumes may be accumulated for larger single additions Reason for Maneuver Reactor/Plant restart following forced outage- 30% hold Date Today RxEng Name J. Sidekick Comments none

I- PUn Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 1 of 48 Event

Description:

Raise plant power to 13-15% RTP Time N Position N Applicants Actions or Behavior Booth Instructor:

No action required for Event I T = 0 Crew will perform power change lAW O-GO-4, Section 5.2 Reactor Power Ascension To Between 13%

And 15% RTP NOTE The steam generator level operator is in control of unit startup until the main feedwater reg valves are in AUTO. IC.51

[1] REVIEW plant parameters and indications, AND VERIFY stability prior to SRO reactor power escalation.

NOTES

1) Act)usting blowdown flow will provide an additional method of controlling 56 water inventofy. (Close blowdowri isolation valves only if level cannot be maIntained)

2) Prior to increasinq reactor power above 5%, 56 blowdown should be in service.

3) Maximum blowdown rate is less than or equal to 270 gpm. Each steam generator flow, up to 60 gpm is indicated on panel L-357 located in the A.B. Supply Fan Rm.

Minimum blowdowii rate equals 5 gpm for each steam generator Final blowdown rate should be determined by chemical analysis.

4) Computer points require a prefix 0, 1, or 2 be placed in front of the point number for example, 1 F2261A.

[2] IF SG blowdown is in service, BOP THEN_ADJUST_FIC-15-43_as_desired._(plant_computer_pt._F2261A)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 2 of 48 Event

Description:

Raise plant power to 13-15% RTP Time I Position N Applicants Actions or Behavior NOTES

1) Actions effecting reactivity are directed in the toilowing step. O-SO-2-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). AU appropriate verifications and peer checFs shall be utilized during performance

2) Recommended dilurion rate Ls 50 to 75 gallon batches everj 12 to 15 minutes tar a steady power increase. Rod movement should be limited to 112 step increments approximately every 1 1/2 minutes Dilution and rod movement rates may be adjusted depending on SG level control stability.

3) Control Rod withdrawal and or dilution requirements may be significantly impacted by the chance in core reactivity due to changing Xenon concentration.

[3] INITIATE a methodical and deliberate reactor power increase by manual RO adjustment_of_the_control_banks_or_by_diluting_the_RCS.

Evaluator Note: Mode change call is made using Loop AT indications on the MCB and ICS, not Nis.

Refer to 0-GO-4 Section 3.1, Precaution C, specifically bullets 2 & 3:

. When reactor power is less than or equal to 15%, use average loop AT (UO485).

. When reactor power is greater than 15%, use LEFM core thermal power indication (U21 18). If LEFM is NOT available, then continue using average loop AT up to 40%.

(U1118 will be used above 40% with LEFM unavailable).

[4] WHEN reactor power is above 5%,

SRO THEN_LOG_Mode_1_entry_in_the_Unit_Narrative_Log.

[5] MAINTAIN the SG levels on program by periodically adjusting the BOP feedwater_bypass_reg_controller_level_setpoints_using_Appendix_B_and_C.

[6] IF Turbine roll in parallel with power increase is desired, CREW THEN PERFORM Section 5.3 in parallel with the remainder of this section.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 3 of 48 Event

Description:

Raise plant power to 13-15% RTP Time I Position I Applicants Actions or Behavior

[7] IF the intermediate range rod stop setpoint is reached before P-1O RO enerqizes, THEN

[7.1] STOP the power escalation.

[7.2] CONTACT Reactor Engineering to evaluate power range calibration. FC.31

[8] WHEN reactor power is greater than or equal to 10% on at least 2 out of 4 BOP PRMs, THEN FC.1i [C.31

[8.1] VERIFY annunciator XA-55-4A, window D-5:

P-lU NUCLEAR AT POWER is LIT.

PERMISSIVE BOP [8.2] VERIFY annunciator XA-55-4A, window B-5:

P-7 LOW POWER TRIP BLOCK is DARK.

[8.3] COMPARE the highest reading PRM with the highest reading loop RO z\T indication to be within 5% of each other. [C.1] [C.3]

[8.4] IF the above conditional response is NOT attained, RO THEN A. STOP the power increase. 0 B. NOTIFY the SRO.

Initials Time Date

Aloendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 4 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior

[9] BLOCK the IR HI FLUX reactor trip and PR LO Range HI FLUX reactor RO trip by performing the following:

[9.1] PLACE IRM TRIP BLOCK P-b [HS-92-5003] AND [HS-92-5004] to RO BLOCK.

BOP [9.2] VERIFY annunciator XA-55-4A, window C-2:

INTERMED RANGE TRAINS A & B TRIP BLOCKED is LIT.

[9.3] RELEASE [HS-92-5003] AND [HS-92-5004].

RO [9.4] PLACE PRM LOW POWER TRIP BLOCK P-b [HS-92-5005] AND

[HS-92-50061 to BLOCK.

BOP [9.5] VERIFY annunciator XA-55-4A, window D-1:

POWER RANGE LOW SETPOINT TRAINS A & B TRIP is LIT.

BLOCKED

[10] WHEN reactor power is between 13 and 15%,

CREW THEN

[10.1] STOP_power_increase.

[10.2] STABILIZE_the_plant.

[11] IF rolling of second MFWP...

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 5 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior This step NIA

[12] IF unit shutdown is required...

This step NIA SRO

[13] ENSURE steps 5.2[1] through 5.2[11] of this section complete.

(applicable steps)

NOTE If Settion 5.3 has already been initiated, then performance should continue at the step in effect.

I

[14] IF rolling the turbine, SRO THEN GO TO Section 5.3.

END OF TEXT Lead examiner may cue the next event when power change is sufficient to record a reactivity manipulation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 6 of 48 Event

Description:

Intermediate Range channel N-35 failure low (>5% RTP at initiation)

Time I Position I Annilcants Action or Behaviors Booth Instructor:

No action required for Event 1 1-M-4 indicators:

. 1-XI-92-5003A IRM % POWER N-35 indicator fails to 0.

. 1-XI-92-5011C, IRM-STARTUP RATE N-35 indicator trends down then stabilizes at 0.

. 1-XR-92-5001, NUCLEAR POWER NR-45 Recorder selected trace goes to 0 1-M-13 indicators:

. 1-Xl-92-5003B NEUTRON FLUX INTERMEDIATE RANGE indicator fails to 0.

T = 10 Respond to MCR indications no alarms associated with this failure; N-35 Crew failure will be identified by operator control board monitorinq.

SRO US may use AOP-I.O1,Nuclear Instrument Malfunction Section 2.2, Intermediate Range Failure:

NOTES:

For a high Intermediate Range OR) channel failure, a reduction in reactor power to less than P-ID will result rn a reactor trip. This condition wiLl be corrected when the channel is bassed in Stec 5 a If an IR channel has failed at a level greater than P-6, the following conditions wiLl exist

Source Range at,tornstic re-enable at P- from iR signals will be dieablsci (SRs will require manual reinstatement per O-GO-.)

a The following SR shutdown high flux annunóiators will be disabled and DARK:

SOURCE RANGE NIGH FUIX LEVEL AT SHUTDOWN [M-4B, B-I]

SOURCE RANGE HIGH SHUTDOWN FLUX ALARM RIOCKED

[At4B. C-i]

a Failure of an intermediate Range Channel may affect the associated Source Range Channel.

RO 1. STABILIZE reactor power at current level.

RO 2. CHECK at least one Intermediate Range OPERATING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 7 of 48 Event

Description:

Intermediate Range channel N-35 failure low (>5% RTP at initiation)

Time Position Applicants Action or Behaviors

3. EVALUATE the following Tech Specs for applicability:

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation SRO Action 3.c & d (From Table 3.3-1 Item 5) Applies Above 5% & 1 0%of RATED THERMAL POWER, POWER OPERATION may continue; TS 3.0.3. is N/A AND

. 3.3.3.7, Accident Monitoring Instrumentation Actions 1 (From Table 3.3-10 Instrument 17) Applies within 30 days, return the affected instrument or Ht Stby w/i 6 hrs. & Ht SD w/i following 6 hrs.

Evaluator Note: TSs 3.3.3.5 and 3.9.2 would be applicable with this failure since the associated Source Range is not affected.

4. IF reactor power less than 1%, THEN ENSURE OPERABLE IR channel RO selected on Nuclear Power Recorder [M-4, NR-45}.

CAUTIONS:

loss of instrument OR control power will cause a single channl reactor trip signal.

For loss of control power oniy, the reactor trip signal cannot le bypassed.

Reducing reactor power below P-lU will result in a reactor trip.

5. CHECK power available to failed Intermediate Range channel RO [M-13, N35/N36]:

RO

INSTRUMENT POWER ON a. IF reactor power is greater than P-ID, indicator LIT TI-lEN MAINTAIN reactor power above P-i 0.

AND

. CONTROL POWER ON b. RESTORE power to failed Intermediate indicator LIT Range channel (NIS cabinet power sources provide power to ALL instruments in that cabinet):

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 8 of 48 Event

Description:

Intermediate Range channel N-35 failure low (>5% RTP at initiation)

Time Position I Applicants Action or Behaviors NI IIUVAL Vt1 InSt VOW SupiW]

Channel -- INST PWR I PWR l-iN-35 I RD i(2-[ Rkr3 I RD 1f2i-L Skr4 I

II (N-36 I RD 1(2)-il Bkr3 I RD 1(2)-li, Bkr4 I

c. DO NOT continue UNTIL control power SRO is restored to faiied IR channel..

1) IF affected channel [s failed, TKEN GO TO Step 6.

6. PLACE Level Trip switch for failed channel in BYPASS [M-1 3, RO N35/N36].

BOP 7. VERIFY NIS TRIP BYPASS annunciator LIT [M-6A, A-i].

RO 8. VERIFY appropriate annunciator LIT:

. iNTERMEDIATE RANGE TRIP BYPASS CHANNEL I [M-4A, A-2}

OR

INTERMEDIATE RANGE TRIP BYPASS CHANNEL II IM-4A. B2]

RO 9. CHECK associated Source Range Channel NOT affected.

SRO 10. GO TO appropriate plant procedure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 9 of 48 Event

Description:

Intermediate Range channel N-35 failure low (>5% RTP at initiation)

Time 1 Position 1 Applicants Action or Behaviors Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when Technical Specifications are addressed.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario 3 Event # 3 Page 10 of 48 Event

Description:

1 of 2 running Hotwell Pumps Trip (1 B Hotwell Pump);

Time Position Apphcants Actions or Behavior Time Position H Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 Indications available:

1-M-1 Annunciators:

. 1-XA-55-IB Window E-3: MOTOR TRIPOUT PNL 1-M-1 THRU 1-M-6 1-M-3A Annunciators:

. 1-XA-55-3A Window E-1: PS-2-129 LOW NPSH AT MFPS 1-M-3A Indicators:

CONDENSATE FLOW, 1-FR-2-35: Recorder shows decreasing trend (to single pump flowrate)

. HOTWELL PUMP B, 1-HS-2-26A RED-WHITE-GREEN Light Indicators: WHITE & GREEN Lights illuminated.

MFP INLET PRESS, 1-PI-2-129 Indicator trends down, varies around 250-275 psig T = 20 CREW Respond in accordance with Alarm Response Procedures SRO may use AOP-S.04, Condensate Or Heater Drains Malfunction Section 2.4, SRO Hotwell Pump Trip:

Evaluator Note: Crew starts the idle Hotwell Pump (def. of ENSURE pre rules of usage) and does not implement Step 1 RNO.

BOP 1. ENSURE two Hotwell pumps RUNNING.

BOP 2. MONITOR Steam generator levels returning to program. [M-4]

RO 3. MONITOR reactor power:

a. CHECK lOS thermal power indication AVAILABLE.

b. REDUCE turbine load as necessary to maintain 10 minute average powerless RO than applicable limit (3455 or 341 1 MWt).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario 3 Event # 3 Page 11 of 48 Event

Description:

1 of 2 running Hotwell Pumps Trip (1 B Hotwell Pump);

Time I Position AnDlicants Actions or Behavior Time N Position AiIicants Actions or Behavior BOP 4. DISPATCH operator to investigate cause of Hotwell Pump trip.

CAUTION: Reducing turbine load too rapidly could result in further drop in condensate pressure due to reduction in heater drain flow. Recommended load rate is 1% per minute if turbine load reduction is needed.

NOTE: Severe MFW pump cavitation is likely if inlet pressure is [ess than 250 psig.

5. MONITOR Feedwater pump inlet pressure greater than 320 psig.

BOP

[M-3, P1-2-i 29]

RO 6. CHECK reactor power greater than 75%.

NOTE: With only two Hotwell pumps in service at 100% power, cavitation may occur and over time could lead to pump damage. Power reduction to 75% provides margin for additional failures.

SRO 7. IF Hotwell Pump cannot be restored within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , THEN EVALUATE reactor power reduction to less than 75% at 1% per minute USING 0-GO-5, Normal Power Operation.

CREW 8. NOTIFY Maintenance to investigate and repair pump malfunction as necessary.

SRO 9. GO TO appropriate plant procedure.

END OF SECTION

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario 3 Event # 3 Page 12 of 48 Event

Description:

1 of 2 running Hotwell Pumps Trip (1 B Hotwell Pump);

Time Position Applicants Actions or Behavior Time N Position Ij Applicants Actions or Behavior Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when the idle Hotwell Pump is in service and MFP suction pressure is restored.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 13 of 48 Event

Description:

Q-A ERCW Pump Over current trip Time fl Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 4 Indications available:

O-M-27A Annunciators:

O-XA-55-27A Window A-I: UNIT I HEADER A PRESSURE LOW C-2: PUMP Q-A DISCH PRESS LOW O-M-27A Indicators:

ERCW HDR IA SUPPLY FLOW I-FI-67-61 Indicator shows decreasing trend (to single pump conditions)

ERCW HDR IA SUPPLY PRESS, I-PI-67-493A indicator shows decreasing trend (to single pump conditions)

ERCW HDR 2A SUPPLY FLOW 2-FI-67-61 Indicator shows normal steady trend.

ERCW HDR IA SUPPLY PRESS, 2-Pl-67-493A indicator shows normal steady trend.

ERCW PUMP Q-A MOTOR AMPS, O-El-67-458A indicator shows 0 amps.

0-M-27B Annunciators:

O-XA-55-27B-A Window E-4: ERCWICCS PUMP MOTOR TRIP T = 30 CREW Respond in accordance with Alarm Response Procedures US may use AOP-M.O1, LOSS OF ESSENTIAL RAW COOLING WATER SRO Section 2.1, ERCW Pump(s) tripped or failed BOP 1. IDENTIFY and LOCK OUT failed ERCW pump.

2. START additional ERCW pumps as required to maintain supply header pressure_between_78_psig_and_124_psig.

3. CHECK two Train A ERCW Pumps AVAILABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 14 of 48 Event

Description:

Q-A ERCW Pump Over current trip Time Position fl Applicants Actions or Behavior

4. CHECK 1A and 2A ERCW suroly header pressures and flows NORMAL:

a Supply header pressures

[between 78 psig and 124 psigj:

. I P1-67-493A

. 2-Pl7-493A

b. Supply header flows

[expected vaiuel:

. 1-Fl-6761

. 2-F[-67-61

5. CHECK 1 B and 2B ERCW supply header pressures and flows NORMAL:

a. Supply header pressures [between 78 psig and 124 psigj:

. i-Pi-67-488A

. 2-Pl-67-488A

b. Supply header flows [expected value}:

. 1-Fl-67-62

. 2Fl-6762

6. DISPATCH personnel to inspect failed pump(s) and determine cause for failure.

7. NOTIFY STA to evaluate Tech Spec LCO 3.7.4, ERCW System, for both units.

3.7A, Essential Raw Cooling Water System

. Restore inoperable pump wli 72 hrs. or Ht Stby wli next 6 hrs and CId SD wli the following 30 hrs. (Action applicable until Transfer Switch 0-XS-67-285, ERCW PUMPS J-A & Q-A DG POWER SEL is re selected to the OPERABLE pump, in this case the J-A position.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 4 Page 15 of 48 Event

Description:

Q-A ERCW Pump Over current trip Time Position Applicants Actions or Behavior

8. CHECK ERCW pump loading amps NORMAL.

9. TRANSFER emerqency power selector switch away from failed pump.

10. EVALUATE need to close and place clearance on manual discharge valve for failed umo.

1 1. GO TO appropriate plant procedure.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Manaciement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when US directs return to appropriate plant procedures.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 16 of 48 Event

Description:

PORV 68-334 fails open (can be closed manually)

Time Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available:

1-M-5 Annunciators:

1-XA-55-5A Window 0-4: PS-68-340G/F PRESSURIZER PRESSURE LOW BACKUP HTRS ON

E-2: TS-68-331 PRESSURIZER POWER RELIEF LIINE TEMP HIGH

1-XA-55-5C Window B-6: XS-68-363 PRESSURIZER RELIEF VALVE OPEN 1-M-5 Indicators:

RCS PR PRESS (Chs 1-4), 1-PI-68-340A, 334, 323, 322: showing RCS (Pzr) pressure going down;

PRT LEVEL, 1-LI-68-300 shows an increasing trend (magnitude proportional to time PORV remained open)

PRT PRESSURE, 1-PI-68-301 shows an increasing trend (magnitude proportional to time PORV remained open)

PRT TEMPERATURE, 1-Tl-68-309 shows an increasing trend (magnitude proportional to time PORV remained open)

RCS PZR PRESS Recorder 1-PR-68-340 shows a decreasing pressure trend proportional to time PORV remained open

RCS LOOP I HL WIDE RANGE PRESS Recorder I-PR-68-69 shows a decreasing pressure trend proportional to time PORV remained open 1-M-6 Indicators:

RCS WR HL PRESSURE LOOP 3 I-PI-68-66A, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE I-PI-68-62, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE I-Pl-68-69, shows a decreasing pressure value; T = 40 CREW Respond in accordance with Alarm Response Procedures US may use AOP-I.04, Pressurizer Instrument And Control Malfunctions SRO Section 2.1, Uncontrolled RCS pressure drop due to open PORV in Modes 1-3 CAUTION Partially open PORV may display no light indications.

NOTE Step I is an IMMEDIATE. AcIION.

BOP 1. CHECK Pzr PORVs CLOSED:

valve position indication

acoustic monitors

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 17 of 48 Event

Description:

PORV 68-334 fails open (can be closed manually)

Time I Position I Applicants Actions or Behavior

2. MONITOR RCS pressure STABLE or RISING.

3. CHECK SI signal NOT actuated.

4. ENSURE available Pzr heaters ENERGIZED as necessary.:

CAUTION RC.S pressure thanges and changes :fl RCS boron concentration (due to differences between pzr and RCS boron) may impact core reactivity.

5. MONITOR reactor power:

a CHECK reactor in Mode 1 012

b. MONITOR core thermal power for unexpected changes.

6. EVALUATE EPIP-1. Emerencv Plan Classification Matrix.

7. EVALUATE the following Tech Specs for applicability:

. 325 DNB Parameters

. 3A3.2, PORVs

. 3.2.5.b DNB Parameters Applies restore the parameter (Pressurizer Pressure) w/i 2 hrs. or reduce to 5% RTP w/i the next 4 hrs.

AND

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 18 of 48 Event

Description:

PORV 68-334 fails open (can be closed manually)

Time Position Applicants Actions or Behavior

. 3.4.3.2.a, Relief Valves Operating Applies restore the PORV to OPERABLE status or close the associated block valve or HT STBY w/i next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , HT SD w/i followinq 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

8. IF PORV block valve must be closed OR power must be removed from block valve to comply with LCO 3.4.3.2, THEN REFER TO O-SO-68-3, Pressurizer Pressure Control System.

9. CHECK the following NORMAL:

10. ENSURE WO initiated on failed equipment.

1 1. GO TO appropriate plant procedure.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Manaqement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event when US completes Tech Spec evaluation or directs return to appropriate plant procedures.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 19 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time

] Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 6 Indications available:

I-M-4 Indicators:

RCS PZR LVL, 1-LI-68-339A, shows a decreasing pressure value

RCS PZR LVL, I-Ll-68-335A, shows a decreasing pressure value

RCS PZR LVL, I-LI-68-320, shows a decreasing pressure value

I-XI-94-1011102, Core Exit Temp Margin to Saturation (exo sensors Tm A & B) pressure indications trending down.

I-M-5 Annunciators:

1-XA-55-5C Window B-I: TS-30-31 LOWER COMPT TEMP HIGH

B-3: TS-30-241 LOWER COMPT MOISTURE HI

B-4: TS-30-240 LOWER COMPT MOISTURE HI I-M-5 Indicators:

RCS PR PRESS (Chs 1-4), I-PI-68-340A, 334, 323, 322: showing RCS (Pzr) pressure going down;

RCS PZR PRESS Recorder 1-PR-68-340 shows a decreasing pressure trend;

RCS LOOP I HL WIDE RANGE PRESS Recorder I-PR-68-69 shows a decreasing pressure trend.

I-M-6 Annunciators:

I-XA-55-6E Window C-6: ZS-61 -I 86 ICE CONDENSER LOWER INLET DOOR OPEN I-M-6 Indicators:

RCS WR HL PRESSURE LOOP 3 1-PI-68-66A, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE 1-PI-68-62, shows a decreasing pressure value;

RCS HL PRESS WIDE RANGE I-PI-68-69, shows a decreasing pressure value; T = 50 CREW Respond in accordance with Alarm Response Procedures Evaluator Note: The RCS leak occurs and progresses into a SBLOCA. The crew responds using this procedure, AOP-R.05 Section 2.1 for lowering Pzr level; this situation could also present a challenge to VCT Make-up capability.

At the Lead Examiner direction, leak size will increase requiring the crew to initiate a reactor trip and enter E-O. Reactor Trip criteria US may use AOP-R.05, RCS LEAK AND LEAK SOURCE IDENTIFICATION SRO Section 2.1, RCS Leak in Mode 1-3

Appendix D Reauired Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 20 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior RO 1. CONTROL charging flow using one CCP::

. ADJUST FCV-62-93 and FCV-62-89 as necessary to maintain pzr Ieve on pro9ram.

. MAINTAIN seal injection flow at least S gpm to each RCP.

2. MONITOR pressurizer level STABLE or RISING.

RO (RNO required)

RNO:

SRO IF sufficient time is available, THEN ISOLATE normal and excess letdown:

a ENSURE FGV-62-72, 73, and 74 CLOSED.

Li CLOSE FCV-62-69 and 70.

c. ENSURE FCV-62-54 and 55 CLOSED.

IF loss of pressurizer level is imminent SRO OR low pressure reactor trip (1970 psig) is imminent, THEN PERFORM the following:

a. TRIP the reactor.

b. INITIATE Safety injection.

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 21 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior RO 3. MONITOR containment pressure STABLE or DROPPING.

RNO:

IF containment pressure is approaching 1.5 psig, THEN PERFORM the following:

a. TRIP the reactor.

b. INITIATE Safety injection

c. GO TO E-O, Reactor Trip or Safety Injection.

CAUTION: If Unit is in Mode 3 with low pressurizer pressure Si NOT blocked, SI should NOT be manually blocked to prevent safety injectian RO 4. MONITOR RCS pressure STABLE or RISING.

RNO:

IF Unit is in Mode 1 or 2 AND RCS pressure is approaching I :97 psig dropping),

THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety injection.

5. MAINTAIN VCT level greater than 13% USING automatic or manual RO makeup.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 22 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior RNO:

[F VCT level CANNOT be mainined, TI-lEN PERFORM the following:

a ENSURE CCP suction aligned to RWST:

1) OPEN LCV-62-135 and -13&

2) CLOSE LGV-62.-132 and i33 b IF Ifl: MODE I or 2, THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety injection NOTE 1: Appendix I orJ may be used to estimate RCS leak rate.

NOTE 2: If letdown was isolated in Step 2, the leak rate may have exceeded caFacity of one CCP in the normal charging alignment (EAL I 22P).

SRO 6. EVALUATE EPIP-1, Ernerciencv Plan Classification Matrix.

7. EVALUATE Tech Spec/TRM LCOs USING Appendix K, Evaluating Tech SRO Specs_and_TRM.

BOP 8. CHECK secondary side radiation NORMAL:

. SIC blowdown rad monitor

. Condenser vacuum exhaust rad monitor

. Main steam line rad monitors.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 23 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior BOP 9. STOP containment purqinq and ventinq:

a. iF containment purge in progress, THEN ENSURE containment purge tans STOPPED.

b ENSURE containment purge and vent dampers CLOSED BOP 10. CHECK containment airborne activity RISING. (RM-90-1 06 or 1 12)

CREW 11. CHECK leakaqe source UNKNOWN.

RO 12. CHECK pressurizer PORVs NORMAL:

. Tailpipe: temperature

. Acoustic monitors RO 13. ISOLATE letdown:

a ENSURE the following letdown orifice valves CLOSED:

. FCV-.62-72 a FCV-62-73

. FCV-62-74

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 24 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior

b. ENSURE the following letdown isolation RO valves CLOSED:

. FCV-62-69

. FCV-62-70

. FCV-62-77

c. CFIECK leak ISOLATED based upon the following:

containment parameters RO

. estimated leak rate BOP USING Appendix I or J.

d. ENSURE the following charging header RO isolation valves CLOSED:

. FCV-62-90

. FCV-62-91

e. GO TO Step 23.

SRO RO 14. ISOLATE charging:

a. ENSURE letdown orifice valves CLOSED:

. FCV-62-72

. FCV-62-73

. FCV-62-74

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 25 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior

b. ENSURE the following charging header RD isolation valves CLOSED:

. FCV-62-90

. FCV-629i

. FCV-62-85

. FCV-62-86.

c CHECK Leak ISOLATED SRO based upon estimated leak rate USING Appendix I orJ.

d. GOTOStep23.

SRO zzJJi RD 15. CHECK Pzr safety valves NORMAL:

. Tailpipe temperature

. Acoustic monitors RD 16. CHECK PRT conditions NORMAL:

. Level

. Pressure

. Temperature

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 26 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Q Apphcants Actions or Behavior

17. NOTIFY Chemistry to ensure all primary side sample valves CLOSED.

BOP

[Hot Sample Room]

BOP 18. CHECK CCS parameters NORMAL:

. OCS radiation monitors NORMAL

. CS surge tank level STABLE RO 19. CHECK all CLA levels NORMAL.

RO 20. CHECK excess letdown heat exchanqer NORMAL (if applicable):

. Temperature

. Pressure

21. CHECK Tl-68-398, Reactor Vessel Head Vent Temperature NORMAL.

RO

[M-41

22. CHECK Tl-68-21, reactor vessel flange leakoff temperature NORMAL.

RO

[M-5]

BOP 23. MONITOR auxiliary building radiation and HELB recorders NORMAL.

Appendix D Required Operator Actions - Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 27 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time Position Applicants Actions or Behavior SRO 24. CHECK leak IDENTIFIED and ISOLATED USING available methods:

BOP

Appendix I or J (Estimating Leak Rate>

containment parameters (radiation.

pressure, humidity)

pocket sump level rate of use on ICS (instantaneous point U0964 or U0965, 15 mm avg. point U0967 or U0968)

Rx Bldg (raceway) sump rate of rise (ICS point U0966)

local observation (if applicable)

RO 25. MONITOR if charging and letdown should be restored:

a. CHECK letdown ISOLATED.

b. CHECK Pzr level:

. level greater than or equal to program level

. level RLSING c.__CHECK_charging_and_normal_letdown_AVAILABLE:

. piping I1fTACT

. valves OPERABLE

. Train A CCS in service.

d. RESTORE CVCS charging and letdown USING EA-62-5, Establishing_Normal_Charging_and_Letdown.

RO 26. MONITOR if pressurizer heaters should be restored:

a. CKECK pressuri er level greater than 20% and rising

b. ENSURE pressurizer heaters in service as required.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 28 of 48 Event

Description:

RCS Leak to SBLOCA requiring a manual reactor trip Time I Position I Applicants Actions or Behavior

27. IF containment purging or venting is needed, THEN PERFORM the SRO followinq:

a IF leak was insde containment.

THEN NOTIFY Chem Lab to evaluate off-site dose USING O-SI-CEM03O-410i or 410.2, as applicable:.

Ii EVALUATE resuming containment purging or venting USING 0-SO-30-3 or 0SO3O8, as applicable.

SRO 28. INITIATE leak repairs.

SRO 29. GO TO appropriate plant procedure.

END_OF_SECTION Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue the next event as desired.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 29 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of I EDG/Charging Pump fails to Auto Start Time fl Position H Applicants Actions or Behaviors Booth Instructor: When directed, initiate Event 7 Indications available:

I -M-4:

. 1-XI-94-1011102, Core Exit Temp Margin to Saturation (exo sensors Tm A & B) pressure indications trending to SI actuation pressure value.

I -M-5:

. I-Pl-68-340A, I-Pl-68-334, I-Pl-68-323, 1-Pl-68-322, RCS PZR PRESS narrow range indicators trending to actuation pressure value.

. 1-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS indicator trending to actuation pressure value.

I -M-6:

. I-Pl-68-66A, HL Pressure LOOP 3 indicator trending to actuation pressure value.

. 1-Pl-68-62, RCS HL Press WR indicator trending to actuation pressure value.

. 1-Pl-68-69, RCS HL Press WR indicator trending to actuation pressure value.

Direct entry to E-O, Reactor Trip or Safety Injection Evaluator Note: following IOA performance, prior to Steps 1-4 immediate action verification, RO/BOP surveys MCBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

E-O, Reactor Trip or Safety Injection Note I Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page

1. VERIFY reactor TRIPPED:

. Reactor trip breakers OPEN RO

Reactor trip bypass breakers DISCONNECTED or OPEN

Neutron flux DROPPING

__Rod_bottom_lights_LIT_(No,_if_LOOP_has_occurred)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 30 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time I Position Ii Applicants Actions or Behaviors

. Rod position indicators less than or equal to 12 steps.

2. VERIFY turbine TRIPPED:

BOP

Turbine stop valves CLOSED.

CRITICAL Start at least I EDG prior to placing equipment PTL in ECA.O-O

3. VERIFY at least one train of shutdown boards ENERGIZED.

BOP

. Attempt to restore power to at least ONE train of shutdown boards

. Place DG IA-A control switch in START

Verify Train A Shutdown Boards ENERGIZED

4. DETERMINE if SI actuated:

ECCS pumps RUNNING.

RO

Any SI alarm LIT [M-4D] (SI will be actuated)

CRITICAL Critical Task to start IA-A CCP is contained in ES-O.5 actions TASK

[(ES-O.5 actions are contained in attachment at back of scenario guide)]

CRITICAL Start at least I A Train ERCW Pump in an operating safeguards train TASK

[(ES-O.5 actions are contained in attachment at back of scenario guide)]

5. PERFORM ES-O.5, Equipment Verifications WHILE continuing in this BO D procedure.

Appendix D Required Operator Actions Form ES-D-2j OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 31 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level greater than 10% [25 ADV] in at least one SIG.

RO

c. CONTROL feed flow to maintain narrow range level between 10%

[25% ADV] and 50% in all SIGs.

(Heat Sink is available from Train A and TDAFW)

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

. Any SIG pressure less than 600 psig AND STEAMLINE PRESS ISOL SI BLOCK RATE ISOL ENABLE permissive DARK [M-4A, A4]

OR RO

Any SIG pressure dropping UNCONTROLLED.

OR

Phase B actuation

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

(Main Steam lines will isolate on Phase B)

NOTE: Loss of seal injection flow could adversely affect RCP seals.

8. CHECK RCP trip criteria:

a. CHECK the following:

RCS pressure less than 1250 psig.

RO AND

At least one CCP OR SI pump RUNNING b._STOP RCPs

Appendix D Required Operator Actions Form ES-D-J OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 32 of 48 Event

Description:

SBLOCA requinng a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors (RCPs will be off due to loss of Off-Site Power)

9. MONITOR RCS temperatures:

. IF any RCP running, THEN CHECK T-avg stable at or trending between 547 degrees F and 552 degrees F.

RO OR

. IF RCP5 stopped, THEN CHECK T-cold stable or trending to between 547 degrees F and 552 degrees F.

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

RO c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

1 1. CHECK SIG secondary pressure boundaries INTACT:

. All S!G pressures CONTROLLED or RISING RO

. All S/G pressures greater than 140 psig.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 33 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time I Position Applicants Actions or Behaviors CHECK SIG tubes INTACT:

a. CHECK all SIG narrow range levels CONTROLLED or DROPPING.

b. CHECK following rad monitors, including available trends prior to isolation:

. Main steam line NORMAL.

RO

Condenser exhaust recorder RR-90-1 19 NORMAL.

. SIG blowdown recorder RR-90-1 20 NORMAL.

Post-Accident Main Steam Line Radiation recorder RR 268B, points 3 (blue), 4 (violet), 5 (black) and 6 (brown)

NORMAL. [M-31 (back of M-30]

12. CHECK if RCS is INTACT:

Containment pressure NORMAL

Containment sump level NORMAL

TS-30-31 LOWER COMPT TEMP HIGH alarm DARK [M-5C, Bi]

Upper containment high range rad monitors RM-90-271 and RM RO 272 NORMAL [M-30]

Lower containment high range rad monitors RM-90-273 and RM 274 NORMAL [M-30]

Containment rad recorders RR-90-1 12 and RR-90-1 06 NORMAL [M 12] (prior to isolation)

13. Monitor Status Trees Crew Go_To_E-1,_Loss_of_Reactor or_Secondary_Coolant Directs entry to E-1, Loss of Reactor or Secondary Coolant

I Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 34 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of I EDG/Charging Pump fails to Auto Start Time I Position I ADDlicants Actions or Behaviors E-1, LOSS OF REACTOR OR SECONDARY COOLANT NOTE This procedure has a foldout page.

1 CHECK RCP triD creria:

a. CHECK the following:

At least one CCP OR SI pump RUNNING AND

RCS pressure less than 1250 psig.

b. STOP RCPs.

2. MONITOR if hydrogen igniters and recombiners should be turned on:

a CHECK containment conditions NOT normal:

contathment pressure high OR

. containment sump level high.

b. DISPATCH personnel to open ice condenser Al-lU breakers USING EA-201-i, 480 V Board Room Breaker Alignments.

c CHECK hydrogen concentration measurement AVAILABLE:

. Hydrogen analyzers have been in ANALYZE for at least 5 minutes.

d CHECK containment hydrogen concentration less than 6%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 35 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDO/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

e. WHEN ice condenser AHU breakers have been opened, ThEN ENERGIZE hydrogen igniters USING Appendix 0.

f. CHECK containment hydrogen concentration less than 05%. [M-10]

3. CHECK SIG secondary pressure boundaries INTACT

. S/S pressures CONTROLLED or RISING

. 510 pressures greater than 140 psig.

4. MAINTAIN Intact SIG narrow rane levels:

a. Greater than 10% [25% ADV1.

b. Between 10% [25% [ADV1 and 50%

5. VERIFY secondary radiation NORMAL:

a CHECK secondary radiation NORMAL USING Appendix A. Secondar Rad Monitors

b. NOTIFY Chem Lab to take S/S activity samples.

c WHEN them Lab is ready to sample S/Os, THEN PERFORM the following:

Appendix D Required Operator Actions Form ES-D-2 I OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 36 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

1) ENSURE FGV-15-43 Bowdown l9ow ControL valve CLOSED.

2) ENSURE Phase A RESET

3) OPEN blowdown isolation valves

d. NOTIFY RADCON to survey main steam lines and SIC blowdown, e WHEN SIC samples completed.

ThEN CLOSE blowdown isolation valves CAUTION Any time a pressurizer PORV opens, there is a possibility that it may stick open.

6. MONITOR pressurizer PORVs and block valves:

a. Power to block valves AVAILABLE.

b. Pressurizer PORVs CLOSED.

c.__At_least_one_block_valve_OPEN.

7. MONITOR SI termination criteria:

a. RCS subcooling based on core exit T/Cs greater than 40°F.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 37 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time I Position Applicants Actions or Behaviors

b. Secondary heat sink:

a Narrow range leel n at ieast one Intact S/G greater than 10% 125% ADV].

OR a Total feed flow to Intact SJGs greater than 440 gpm.

c. RCS pressure STABLE or RISING.

d. Pressurizer level greater than 10% [20% ADV].

e. GO TO ES-1.1, SI Termination.

8. MONITOR if containment spray should be stopped:

a. CHECK any contanrnent spray pump RUNNING.

b. CHECK containment pressure less than 2.0 psig.

c. CHECK containment spray suction aligned to RWST.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 38 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

d. RESET containment spray signals.

e. STOP containment spray pumps and PLACE in A-AUTO.

f. CLOSE contanirnent spray discharge valves:

a FcV-7239, Train A a FCV-72-2 Train B.

9. MONITOR if containment vacuum control should be returned to normal:

a. CHECK containment pressure less than 1,0 psig.

b. VERIFY containment vacuum relief isolation valves OPEN: tPanel 6K1

. FCV-30-4G

. FCV-30-47

. FCV-30-48.

10. MONITOR shutdown boards continuously energized.

11. DETERMINE if RHR pumps should be stopped:

a. CHECK RCS pressure: V

1) Greater than 300 psig

2) STABLEorRISING.

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 39 of 48 Event Descnption: SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

b. CHECK RHR pump suction aligned from RWST.

c. ENSURE SI signal RESET.

d. STOP RHR pumps and PLACE in A-AUTO.

e. MONITOR RS pressure greater than 300 psig.

NOTE I S/G pressures dropping slowly during a LOGA with no faulted S!G should be considered stable in the following Step.

NOTE 2 RCS pressure rising slightly during a LOCA which is NOT iiated should be considered stabler in the following step.

12. DETERMINE_if_SI_termination_criteria_should_be_checked_again:

a CHECK pressure in all S/Gs STABLE or RISING.

b. CHECK RS pressure STABLE or DROPPING.

13. MONITOR if RHR spray should be placed in service:

a. CHECK the following conditions met:

. Containment pressure greater than 9.5 psig AND

. At least 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months has elapsed since beginning of accident

I Appendix D Required Operator Actions Form ES-D-2]

Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 40 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position I Applicants Actions or Behaviors AND a RHR suclion aligned to containment sump AND

. At least one CCP AND one SI pump RUNNING.

b CHECK both RHR pumps RUNNING.

c. ESTABLISH Train B RHR spray:

1) CHECK Train B RHR pump RUNNING.

2> ENSURE RHP crosste FCV-74-35 CLOSED

3) CLOSE RHR injection FCV-63-94.

4) OPEN RHR spray FcV-72-41.

d. MONITOR containment pressure greater than 4 psig

14. DETERMINE if diesel generators should be stopped:

a. VERIFY shutdown boards ENERGIZED from start busse&

b. ENSURE SI sgnaI RESET.

Appendix D Required Operator Actions Form ES-D-2j Op Test No.: NRC Scenario # 3 Event # 7,8,9,10 Page 41 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

c. STOP any unloaded diesel generators and PLACE in standby USING EA-82-i Racing DiGs in Standby.

15. INITIATE evaluation of plant status:

a ENSURE cold leg recirculation capability:

1) Power to at least one RHR pump AVAILABLE.

2) Capability to operate the following valves AVAILABLE:

a FcV-63-72 and FCV-74-3 (for RHR pump A-A).

OR a FCV-63-73 and FCV-74-2i (for RHR Pump B-B).

b. CHECK Auxiliary Building radiation:

1) Area Radiation Mcniors RR901A and *RR-90i B NORMAL.

2) Aux Bldg Vent monitor recorder 0-RR-90-1 01 NORMAL (prior to isolation)..

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 78.9.1O Page 42 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Arnlicants Actions or Behaviors

c. MONITOR containment sump Level less than 68%.

d. NOTIFY TSC to initiate post-accident sampling as nessary.

e. J 1 jUATE plant equipment status USiNG EA-Q-4, Evaluation of Equipment Status.

16. DETERMINE if RCS cooldown and depressurization is required:

a. CHECK RCS pressure greater than 300 psig.

b. GO TO ES-I .2, Post LOCA Cooldown and Depressurization.

17. DETERMINE if transfer to cold leg recirculation is required:

a. CHECK RWST level less than 27%.

b. IF ES-I .3 has NOT been performed, THEN GO TO ES-I .3, Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D Op Test No.: NRC Scenario # 3 Event # 7.8,9,10 Page 43 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of 1 EDG/Charging Pump fails to Auto Start Time Position Aoolicants Actions or Behaviors

18. MONITOR if CLAs should be isolated:

a CHECK RGS pressure less than 100 psig.

b. CHECK power to Ct.A isolation valves AVAILABLE.

c. ENSURE SI signal RESET.

d. Cli. OSE CLA isolation valves.

19. DETERMINE if Intact SIGs should be depressurized to RCS pressure:

a. CHECK RCS pressure less than Intact 5/0 pressures.

b. NOTIFY Chem Lab to sample all S/Os for activity levels.

c. CONSULT TSC to determine dose projection for steaming S/Os.

d. CHECK dose projection for each Sf0 acceptabla

e. DUMP steam to condenser from Intact S/Os UNTIL SO pressure less than RCS pressure.

20. DETERMINE if reactor vessel head should be vented:

. CONSULT TSC for evaluation of vessel head venting.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 7,8,9,10 Page 44 of 48 Event

Description:

SBLOCA requiring a manual reactor trip/Loss of Off-Site Power/Loss of I EDG/Charging Pump fails to Auto Start Time Position Applicants Actions or Behaviors

21. WHEN 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months have elapsed since event initiation, THEN PREPARE for hot leg recirculation:

. DISPATCH personnel to restore power to FCV-63-22 USING EA-20i-1, 489V Board Room Breaker Alignments

22. WHEN 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months have elapsed since event initiation, THEN GO TO ES-i .4, Transfer to Hot Leg Recirculation.

23. EVALUATE long term plant status:

.__CONSULT_TSC.

END Scenario may be terminated upon transition to ES-1.2

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ES-O.5 Page 45 of 48 Event

Description:

ES-O.5, Equipment Verifications Time Position Applicants Actions or Behavior CRITICAL Start at least I A Train ERCW Pump in an operating safeguards train TASK

[(ES-O.5 actions are contained in attachment at back of scenario guide)]

CHECK ERCW system operation:

BOP . VERIFY at least four ERCW pumps RUNNING.

. VERIFY DIG ERCW supply valves OPEN.

VERIFY CCS pumps RUNNING:

. Pump lA-A (2A-A) Must Manually Start BOP . Pump lB-B (2B-B)

. Pump C-S.

VERIFY EGTS fans RUNNING.

BOP VERIFY generator breakers OPEN.

BOP VERIFY AFW pumps RUNNING:

BOP . MDAFW pumps

. TDAFW pump.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control SIG levels, to establish flow due to failure, or to isolate a faulted SIG.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # ES-O.5 Page 46 of 48 Event

Description:

ES-O.5, Equipment Verifications CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b. VERIFY TD AFW LCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV 401 CLOSED.

VERIFY MFW Isolation:

. MFWpumpsTRIPPED

. MEW regulating valves CLOSED BOP

MEW regulating bypass valve controller outputs ZERO

MEW isolation valves CLOSED

MEW flow ZERO.

CRITICAL Critical Task to start IA-A CCP is contained in ES-O.5 actions TASK

[(ES-0.5 actions are contained in attachment at back of scenario quide)]

CRITICAL MONITOR ECCS operation:

TASK VERIFY ECCS pumps RUNNING:

CCPs MANUALLY START IA-A CCP BOP

RHR pumps

SI pumps VERIFY CCP flow through CCPIT.

CHECK RCS pressure less than 1500 psig.

VERIFY SI pump flow.

BOP

CHECK RCS pressure less than 300 psig.

VERIFY RHR pump flow.

Appendix D Required Operator Actions Form ES-Di1 Op Test No.: NRC Scenario # 3 Event # ES-O.5 Page 47 of 48 Event

Description:

ES-O.5, Equipment Verifications VERIFY ESF systems ALIGNED:

. Phase A ACTUATED:

o CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT

[M-6C, B5].

o CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT

[M-6C, B6].

. Containment Ventilation Isolation ACTUATED:

o CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, 05].

o CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, C6].

BOP

Status monitor panels:

o 6CDARK o 6DDARK o 6E LIT OUTSIDE outlined area o 6HDARK o 6J LIT.

Train A status panel 6K:

o CNTMT VENT GREEN o PHASE A GREEN

Train B status panel 6L:

o CNTMTVENTGREEN o PHASE A GREEN MONITOR containment spray NOT required:

Phase B NOT ACTUATED AND BOP

Containment pressure less than 2.81 psig

. Ensure Containment Spray is actuated VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]

HS-77-410, Rx Bldg Aux Floor and Equipment Drain Sump pump A BOP

HS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

I Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 3 Event # ES-O.5 Page 48 of 48 Event

Description:

ES-O.5, Equipment Verifications DISPATCH personnel to perform EA-O-1, Equipment Checks Following ESF Actuation.

BOP

Appendix D Scenario Outline Form ES-D-1 Facility: Sequoyah Scenario No.: 4 Op Test No.: NRC Examiners: Operators:

Initial Conditions: 100% stable, long duration run; Turnover: 100% RTP; Preparations complete for power reduction for MT Valve testing, Target CTs: Manually actuate at least one train of SIS-actuated safeguards before transition into E-3 series.

Depressurize the RCS to meet SI termination criteria prior to affected SG overfill Event No. Maif. No. Event Type* Event Description

1. N/A [O Reduce power in preparation for MT Valve testing T+0

[ N-SRO/BOP

2. RX19 1-RO Auto Rod Motion Failure (Tref Computer failure)

T+5

3. RX25 1-BOP Feedwater Header Pressure Transmitter PT-3-1 fails high T÷1 0

4. RXO7A 1-RO Pressurizer Pressure Transmitter 1-PT-68-340 (Ch 1) fails high T÷20 TS-SRO

5. FW11B C-BOP lB MFP Trip w/ Plant Runback T+30 M-All

6. THO5B N- ALL #2 SQ Tube Leakage (150 gpd)

T+50 TS-SRO

7. THO5B M-All #2 SGTL to SGTR 200 gpm over three minutes.

T+60

8. FWO4A C-BOP #1 SG MDAFW Level Control Valve Fails Open T+60 (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Scenario 4 Summary The crew will assume the shift with the unit in Mode 1, 100% RTP; the crew will proceed to reduce power in preparation to perform Main Turbine Valve testing (<93% RTP) according to 1-Pl-OPS-047-002.0, Steam Inlet Valve Testing. Instructions for the power reduction are from 0-GO-5, Normal Power Operation, Section 5.3 Beginning at Notes prior to step 7.

Following the plant power reduction and at the Lead Examiner direction, an Auto Rod Control Program failure will occur when reactor power is reduced below 95% RTP. The malfunction results in a failure of Tref Computer failure program signal to the rod drive system. The control rods will not move from any automatic control signal. The crew will respond using alarm response procedure (ARP5) 1-AR-M5A A-6 and abnormal procedure AOP-C.01, Rod Control Malfunctions Section 2.1, Uncontrolled Rod Bank Movement to place Rod Control in Manual.

When the plant is stable, at the Lead Examiner direction, Feedwater Header Pressure Transmitter fails high causing underfeeding of all 4 steam generators. The crew will respond to alarms, ARPs 1 -AR-M5A A-7, B-7 and 1 -AR-M6B A-7 B-7 C-7 D-7 and abnormal procedure AOP-S.1, Loss of Normal Feedwater, Section 2.2, by placing MFP Control in manual to control feedwater flow/feedwater header pressure. MFWPT Control will remain in manual through the remainder of the scenario.

After the crew has stabilized the plant, at the Lead Examiner direction, Pressurizer Pressure Transmitter 1-PT-68-340 (CH 1) fails high, will cause the Pzr heaters to de-energize, and sprays to open. The crew will respond according to ARPs 1 -AR-M5A B-3, I -AR-M6A C-5 and AOP-1 .04, Pressurizer Instrument and Controls Malfunctions Section 2.3.

The RO will manually control pressurizer pressure by closing the spray valves and controlling heaters; once plant conditions are stable, the crew will defeat the failed channel, contact l&C to remove the channel from service and restore RCS Pressure control to automatic. The SRO will identify Tech Spec actions: LCO 3.1 .3.6.a, 3.3.1 Table 3.3-1 units 7,9,10-Action 6,3.3.2.1 Table 3.3-3 units 1.d-Action 17, 8-Action 22a and 3.4.12 (MODEs 46*).

When the plant is stable, at the Lead Examiner direction, 1 B MEW Pump trips on a spurious trip signal. The plant will

( run automatically back and stabilize at 72%; the BOP will manually control MFP Control (from the previous PT-3-1 failure). The crew will respond to alarms using ARPs 1-AR-M2A B-i, i-AR-M3B A-2, B-i and D-6 (possibly), i-AR M3C A-i, 1 -AR-M5A B-7 and go to AOP-S.Oi Section 2.3 to control and stabilize the plant.

When the plant is stable, at the Lead Examiner direction, a SG tube leak will develop. The crew will respond using ARPs 0-AR-M12A B-5 and C-i and go to AOP-R.01, SG Tube Leak Section 2.2 initially. The SRO will identify Tech Spec actions: 3.4.6.2.c At the Lead Examiner direction, the leak will increase to approximately 200 gpm over several minutes giving the crew time to transition to AOP-R.01 Section 2.1 where the decision should be made ( Step 1 RNO column) to trip the reactor and enter E-0. The crew will carry; out E-0 immediate actions continuing to a transition to E-3 to mitigate the tube rupture.

Additionally, the MDAFW Level Control Valve for #1 SG will fail open at the time of the trip causing the BOP stop the IA-A MDAFW Pump to prevent overfilling the #1 SG; subsequent #1 SG level control is via the TDAFW Pump and level control valve.

EOP flow: E-0 E-3 The scenario may be terminated as directed by the Lead Examiner upon completion of E-3 Step 24, CCPIT isolation.

PSA significant task: Manually actuate at least one train of S IS-actuated safeguards before transition into E-3 series.

Depressurize RCS to meet SI termination criteria prior to SG overfill; PSA significant component failure: Steam Generator Tube Failure Appendix D NUREG 1021 Revision 9

1002 ESG-4 Page 1 of 5 APPENDIX C Time: Now Date: Today Unit 1 MCR Checklist

, Part I Completed by Off-going Shift I Reviewed by Oncoming Shift :

Mode 1, 100% Power NRC phone Authentication Code PSA Risk: Green Grid Risk: Green RCS Leakage ID .14 gpm, UNID .05 gpm Until 0800 AI2B RCS Boron: 1093 After 0800 C34D Common Tech Spec Actions LCO/TRM Eciuiment INOP Time INOP Owner RTS U-I Tech Spec Aátions LCOITRM Eciuiment INOP Time INOP Owner RTS NONE NONE - - - - - - - - - - -

Protected Equipment

. NONE Shift Priorities

. 1-PI-OPS-047-002.O, STEAM INLET VALVE TESTING Part 2 Performed by on-coming shift Verify your current qualifications Review Operating Log since last held shift or 3 days, whichever is less Standing Orders I Shift Orders LCO Actions TACF I Immediate required reading Part 3 Performed by both óff-cing and on-coming shift - -. -.

IJ Walk down of MCR Control Boards

1002 ESG-4 Page 2 of 5 APPENDIX C Time: Now Date: Today MAIN CONTROL ROOM (7690)

Train A Week OUTSIDE (7666) 593-52143 AUXILIARY BUILDJNG (7775)

TURBINE BUILDING (7771) (593-8455)

1002 ESG-4 Page 3 of 5 Time: Now Date: Today MCR Red Dot List UNID And Noun Name Panel Problem Description WO I PER Number Date Scheduled MCR WO List

1002 ESG-4 Page 4 of 5 UNIT ONE REACTIVITY BRIEF Date: Today Time: Now General Information RCS Boron: 1093 ppm Today BA Controller Setpoint: 27%

RCS B-b Depletion: 7 ppm Operable BAT: A BAT A Boron: 6850ppm BAT C Boron: 6850ppm RWST Boron: 2601 ppm Nominal Gallons per rod step from 219: 7 gallons of acid, 36 gallons of water Verify boric acid flow controller is set at Adjusted BA Controller Setting iaw O-SO-62-7 section 5.1 Estimated values for a 1° Change in Tave -

Gallons of acid: 26 Gallons of water: 138 Rod Steps: 4 1 .1 , I Power reduction amount Estimated Final Rod Position Estimated boron addition 10% 198 Steps on bank D 101 gallons 30% 174 Steps on bank D 295 gallons 50% 152 Steps on bank D 485 gallons These values are approximations and not intended nor expected to be exact. The values may be superseded by Rx Engineering or SO-62-7 calculated values. These values are calculated assuming 100% steady state power operation only. Engineering data last updated one week ago. Data Valid until one week from now.

L Previous Shift Reactivity Manipulations Number of dilutions: 0*** Number of borations: 0 Rod steps in: 0 Gallons per dilution: 0 Gallons per boration: 0 Rod steps out: 0 Total amount diluted: 0 Total amount borated: 0 Net change: 0 IN/Out Current hift Estimated Reactivity Manipulal ons Number of dilutions: 0

Number of borations: 0

Rod steps in: 0

Gallons per dilution: 0

Gallons per boration: 0

Rod steps out: 0

Total expected dilution: 0

Total expected borat ion: 0

Net change: 0 In/Out Remarks:

During Plant power reduction, Per RE Reactivity Spreadsheet Rx Power 100%

MWD/MTU 1000 Xenon & Samarium at Equilibrium

- - The boron letdown curve is flat for the next 25 EFPD.

Next Unit I Flux Map is scheduled - three weeks from now Unit 1 M-P is 0 PPM Unit Supervisor:

Name/Date

1002 ESG-4 Page 5 of 5 Operations Chemistry Information BoronResults:

SampEePoit UnIts Boron Date/Time Goal Limit Ui RCS ppm 1093 Today! Now Variable Variable U2 RCS ppm 648 Today / Now Variable Variable Ui RWST ppm 2601 Today / Now 2550 2650

- 2500 2700 U2 RWST ppm 2569 Today! Now 2550 2650

- 2500 2700 BAT A ppm 6850 Today! Now Variable Variable BATB ppm 6850 Today!Now Variable Variable BAT C ppm 6850 Today I Now Variable Variable Ui CLA #1 ppm 2556 Today / Now 2470-2630 2400-2700 Ui CLA #2 ppm 2575 Today! Now 2470-2630 2400-2700 Ui CLA #3 ppm 2591 Today! Now 2470-2630 2400-2700 Ui CLA #4 ppm 2589 Today / Now 2470-2630 2400-2700 U2 CLA #1 ppm 2531 Today! Now 2470-2630 2400-2700 U2 CLA #2 ppm 2650 Today / Now 2470-2630 2400-2700 U2 CLA #3 ppm 2522 Today I Now 2470-2630 2400-2700 U2 CLA #4 ppm 2526 Today / Now 2470-2630 2400-2700 Spent Fuel Pool ppm 2547 Today! Now > 2050 2000

.L>

Uthhjm Results Goal fMidptnt

./

Ui RCS Lithium ppm 1 1 Today! Now >1 >1 U2 RCS Lithium ppm 2.43 Today! Now 2.18-2.48 2.33 Primary to Secondary Leakrate Information(TotaI CPM R19O-99I1 9)

Indicator Units UI Date I Time U2 - Date/Time SI 50 S/G Leakage? Yes/No No Today! Now No Today I Now SI 137.5 CVE Leakrate gpd < 0.1 Today! Now < 0.1 Today! Now 5 gpd leak equivalent cpm 370 Today I Now 111 Today / Now 30 gpd leak equivalent cpm 1970 Today! Now 464 Today! Now 50 gpd leak equivalent cpm 3250 Today! Now 747 Today! Now 75 gpd leak equivalent cpm 4850 Today! Now 1100 Today! Now CVE Air Inleakage cfm 10 Today!Now 12.5 Today!Now Bkgd on 991119 cpm 50 Today I Now 40 Today! Now Correction Factor 99!1 19 cpm!gpd 64 Today! Now 14.13 Today! Now Steady state conditions are necessary for an accurate determination of leak rate using the CVE Rad Monitor

For iraining ONLY Unit 1 DELTA REACTOR POWER ASSUMEDINSERTEDEXPECTE[DELTA RHC BORON DELTA .ECOMMEN RECOMME IODINE TIME POWER DEFECT ROD HT WORTH XENON BORON CONC PPM DILUTION BORATIOI\ CONC (hrs) (%) (pcm) (steps) (pcrn) (pcm) (pcm) (ppm) (ppm) (gal) (gal) (% eq) 0 100.0 1682.7 215.0 -31.0 -2683.0 1123.0 --- --- 100.0 1 92.0 1543.6 198.0 -126.5 -2700.0 -26.6 1127.2 4.2 0 47 99.6 2 92.0 1541.8 200.0 -114.0 -2724.9 10.6 1125.5 -1.7 94 0 98.9 3 100.0 1681.5 212.0 -43.2 -2724.3 68.4 1114.8 -10.7 616 0 98.6 4 100.0 1686.6 215.0 -31.0 -2708.5 -22.9 1118.4 3.6 0 40 98.7 5 100.0 1684.9 215.0 -31.0 -2697.2 -13.1 1120.5 2.0 0 23 98.8 6 100.0 1683.9 215.0 -31.0 -2689.0 -9.1 1121.9 1.4 0 16 99.0 7 100.0 1683.3 215.0 -31.0 -2683.4 -6.3 1122.9 1.0 0 11 99.1 8 100.0 1682.8 215.0 -31.0 -2679.6 -4.3 1123.5 0.7 0 8 99.2 9 100.0 1682.5 215.0 -31.0 -2677.2 -2.8 1123.9 0.4 0 5 99.2 10 100.0 1682.3 215.0 -31.0 -2675.7 -1.6 1124.2 0.3 0 3 99.3 11 100.0 1682.2 215.0 -31.0 -2675.0 -0.8 1124.3 0.1 0 1 99.4 12 100.0 1682.1 215.0 -31.0 -2674.9 -0.2 1124.4 0.0 0 0 99.4 13 100.0 1682.1 215.0 -31.0 -2675.1 0.2 1124.3 0.0 2 0 99.5 14 100.0 1682.1 215.0 -31.0 -2675.5 0.5 1124.3 -0.1 4 0 99.5 15 100.0 1682.1 215.0 -31.0 -2676.1 0.7 1124.2 -0.1 6 0 99.6 16 100.0 1682.2 215.0 -31.0 -2676.8 0.8 1124.0 -0.1 7 0 99.6 17 100.0 1682.2 215.0 -31.0 -2677.6 0.8 1123.9 -0.1 7 0 99.7 18 100.0 1682.3 215.0 -31.0 -2678.4 0.9 1123.8 -0.1 8 0 99.7 19 100.0 1682.4 215.0 -31.0 -2679.2 0.9 1123.7 -0.1 8 0 99.7 20 100,0 1682.4 215.0 -31.0 -2680.0 0.8 1123.5 -0.1 7 0 99.8 21 100.0 1682.5 215.0 -31.0 -2680.7 0.8 1123.4 -0.1 7 0 99.8 22 100.0 1682.5 215.0 -31.0 -2681.4 0.8 1123.3 -0.1 7 0 99.8 23 100.0 1682.6 215.0 -31.0 -2682.1 0.7 1123.2 -0.1 6 0 99.8 24 100.0 1682.6 215.0 -31.0 -2682.7 0.7 1123.1 -0.1 6 0 99.8 25 100.0 1682.7 215.0 -31.0 -2683.2 0.6 1123.0 -0.1 6 0 99.9 26 100.0 1682.7 215.0 -31.0 -2683.8 0.6 1122.9 -0.1 5 0 99.9 27 100.0 1682.8 215.0 -31.0 -2684.2 0.5 1122.8 -0.1 5 0 99.9 28 100.0 1682.8 215.0 -31.0 -2684.7 0.5 1122.7 -0.1 4 0 99.9 29 100.0 1682.9 215.0 -31.0 -2685.1 0.4 1122.7 -0.1 4 0 99.9 30 100.0 1682.9 215.0 -31.0 -2685.5 0.4 1122.6 -0.1 4 0 99.9 For Training ONLY Page 1 of 3 Initial License Training

For Training ONLY Unit 1 31 100.0 1682.9 215.0 -31.0 -2685.8 0.4 1122.5 -0.1 3 0 99.9 32 100.0 1682.9 215.0 -31.0 -2686.1 0.3 1122.5 -0.1 3 0 99.9 33 100.0 1683.0 215.0 -31.0 -2686.4 0.3 1122.4 0.0 3 0 99.9 34 100.0 1683.0 215.0 -31.0 -2686.6 0.3 1122.4 0.0 2 0 99.9 35 100.0 1683.0 215.0 -31.0 -2686.9 0.2 1122.4 0.0 2 0 99.9 36 100.0 1683.0 215.0 -31.0 -2687.1 0.2 1122.3 0.0 2 0 100.0 37 100.0 1683.1 215.0 -31.0 -2687.3 0.2 1122.3 0.0 2 0 100.0 38 100.0 1683.1 215.0 -31.0 -2687.4 0.2 1122.3 0.0 2 0 100.0 39 100.0 1683.1 215.0 -31.0 -2687.6 0.2 1122.2 0.0 1 0 100.0 40 100.0 1683.1 215.0 -31.0 -2687.7 0.2 1122.2 0.0 1 0 100.0 41 100.0 1683.1 215.0 -31.0 -2687.8 0.1 1122.2 0.0 1 0 100.0 42 100.0 1683.1 215.0 -31.0 -2688.0 0.1 1122.2 0.0 1 0 100.0 43 100.0 1683.1 215.0 -31.0 -2688.1 0.1 1122.1 0.0 1 0 100.0 44 100.0 1683.1 215.0 -31.0 -2688.2 0.1 1122.1 0.0 1 0 100.0 45 100.0 1683.1 215.0 -31.0 -2688.2 0.1 1122.1 0.0 1 0 100.0 46 100.0 1683.1 215.0 -31.0 -2688.3 0.1 1122.1 0.0 1 0 100.0 47 100.0 1683.2 215.0 -31.0 -2688.4 0.1 1122.1 0.0 1 0 100.0 48 100.0 1683.2 215.0 -31.0 -2688.4 0.1 1122.1 0.0 1 0 100.0 49 100.0 1683.2 215.0 -31.0 -2688.5 0.1 1122.1 0.0 1 0 100.0 50 100.0 1683.2 215.0 -31.0 -2688.5 0.1 1122.1 0.0 0 0 100.0 51 100.0 1683.2 215,0 -31.0 -2688.6 0.0 1122.1 0.0 0 0 100.0 52 100.0 1683.2 215.0 -31.0 -2688.6 0.0 1122.1 0.0 0 0 100.0 53 100.0 1683.2 215.0 -31.0 -2688.7 0.0 1122.0 0.0 0 0 100.0 54 100.0 1683.2 215.0 -31.0 -2688.7 0.0 1122.0 0.0 0 0 100.0 55 100.0 1683.2 215.0 -31.0 -2688.7 0.0 1122.0 0.0 0 0 100.0 56 100.0 1683.2 215.0 -31.0 -2688.8 0.0 1122.0 0.0 0 0 100.0 57 100.0 1683.2 215.0 -31.0 -2688.8 0.0 1122.0 0.0 0 0 100.0 58 100.0 1683.2 215.0 -31.0 -2688.8 0.0 1122.0 0.0 0 0 100.0 59 100.0 1683.2 215.0 -31.0 -2688.8 0.0 1122.0 0.0 0 0 100.0 60 100.0 1683.2 215.0 -31.0 -2688.8 0.0 1122.0 0.0 0 0 100.0 61 100.0 1683.2 215.0 -31.0 -2688.9 0.0 1122.0 0.0 0 0 100.0 62 100.0 1683.2 215.0 -31.0 -2688.9 0.0 1122.0 0.0 0 0 100.0 63 100.0 1683.2 215.0 -31.0 -2688.9 0.0 1122.0 0.0 0 0 100.0 64 100.0 1683.2 215.0 -31.0 -2688.9 0.0 1122.0 0.0 0 0 100.0 For Training ONLY Page 2 of 3 Initial License Training

For Training ONLY Unit I 6350 MWD/MTU Hold Tavg = Tref +1- 1 .5F Total 843 154 6740 BAT ppm Small hourly boration/dilution volumes may be accumulated for larger single additions Reason for Maneuver Periodic MT Valve Testing Date Today RxEng Name J Peabody Comments None For Training ONLY Page 3 of 3 Initial License Training

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 1 Page 1 of 55 Event

Description:

Reduce power in preparation for MT Valve testing Time fl Position I Applicants Actions or Behavior Booth Instructor:

No action required for Event I Indications available:

None: Crew will initiate power reduction lAW O-GO-5 Section 5.3 starting at step 7.

T = o Direct a load reduction in accordance with O-GO-5 Normal Power SRO Operations, Section 5.3, and O-SO-62-7 Boron Concentration Control, Section 6.4.

Evaluator Note: Following Steps are from O-S0-62-7 Boron Concentration Control, Section 6.4 CAUTION: Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on Boric Acid System could introduce debris, sludge, air or solidified boron into CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid piping following an outage.

NOTE: If a large amount of boration is required (plant shutdown), Pzr heaters should be energized to cause spray operation for equalizing boron concentration in RCS and pressurizer. If Normal Spray is NOT available, then this should be accomplished by use of Auxiliary Spray (1, 2-S0-62-1) in conjunction with pressurizer backup heaters.

[1] ENSURE makeup system aligned for AUTO operation in accordance RO with Section 5.1.

NOTE: Steps 2 and 3 are NIA for minor power changes OR if immediate boration is required to maintain shutdown margin, to maintain rods above the insertion limit, during an emergency shutdown (AOP C.03), during recovery of a dropped/misaligned rod (AOP-C.O1), or at Chemistry recommendation in mcde 3, 4, 5 or 6.

[2] RECORD the quantity of boric acid required to achieve desired boron RO concentration usin Appendix D. qals

[3] PERFORM Appendix I Independent Verification of Calculation for CREW Amount of Boric Acid or Primary Water. (N/A if App. D was performed by SRO to verify data from Rx Enqineerinq)

[4] DETERMINE available boric acid volume in in-service BAT.

RO gals

j Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # I Page 2 of 55 Event

Description:

Reduce power in preparation for MT Valve testing Time I Position Analicants Actions or Behavior

[5] PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the RO STOP position.

RO [6] PLACE [HS-62-140B], CVCS Makeup Selector Switch to the BORATE position.

[7] ADJUST [FC-62-139], Boric Acid Flow Controller to the desired flow RD rate.

RD [8] SET [FQ-62-139], Batch Integrator to the desired quantity.

RD [9] PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the START_position.

[10] ENSURE Boric Acid Pump aligned to blender in FAST speed by right RD red_light_LIT_on_[HS-62-230A]_OR_[HS-62-232A].

NOTE: Flow oscillations and/or erratic controller response may require manual operation of Boric Acid Flow Controller [FC-62-139] until stable conditions exist.

RD [11] VERIFY Boric Acid Flow established.

NOTE: It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrL mentation or R DS temperature indication.

[12] IF reactor is critical, THEN MONITOR nuclear instrumentation and RD reactor_coolant_temperature_to_ensure_proper_response_from_boration.

NOTE: BAT operability limits are prescribed by TRM 3.1.2.6 (Modes 1-3) or 3.1.2.5 (Modes 4-6).

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 1 Page 3 of 55 Event

Description:

Reduce power in preparation for MT Valve testing Time fl Position I Applicants Actions or Behavior RO 1131 MONITOR Boric Acid Storacie Tank level.

IF Volume Control Tank level increases to 63 percent, RO

[14] THEN ENSURE [LCV-62-118], Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tank.

NOTE: Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the boration is as expected.

[15] WHEN boration is complete, THEN RO [a] PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the STOP position.

[b] CHECK no primary water flow on either [FI-62-142A] OR [FQ 142].

[c] ENSURE [FC-62-142], Primary Water to Blender Flow

[d] Controller is in AUTO position and the potentiometer (dial indicator) is set at 35%.

[e] ADJUST [FC-62-139], Boric Acid Flow Controller to the desired blend solution in accordance with Tl-44 Boron Tables.

[fJ ENSURE [FCV-62-128] is CLOSED.

[g] PLACE [HS-62-140B], CVCS Makeup Selector Switch to the AUTO position.

[hi PLACE [HS-62-140A], Boric Acid to Blender Flow Control Switch to the START position.

[i] IF RCS boron sample required, THEN NOTIFY Chem Lab to obtain RCS boron samDle.

NOTE: Boration is done in batches until the total boron and/or power change is completed.

RO [16] REPEAT this section as required to complete total boron change.

[17] WHEN total boration is complete, RO

[a] THEN: REALIGN the blender controls for AUTO makeup to the CVCS_in_accordance_with_Section_5.1.

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # 1 Page 4 of 55 Event

Description:

Reduce power in preparation for MT Valve testing Time [ Position 1 Applicants Actions or Behavior fbI NOTIFY Chem Lab to obtain RCS boron sample.

[18] IF in modes 1,2, or3, THEN ENSURE requirements of TRM 3.1.2.6 SRO are met.

Evaluator Note: Following Steps are from O-GO-5, Normal Power Operation, Section 5.3 Beginning at Notes prior to step 7.

NOTES

1) Guidance on restoration of EHC Controls after a BOP runback is contained in Appendix B, Turbine Runback Restoration.

2) For core operating recommendations for situations such as end of core life coast down or unusual power maneuvers, contact Reactor Engineering for guidance.

3) It is recommended that AFD be controlled within the target band.

4) The following general approach should be used during power reduction:

(a) borate RCS to reduce RCS TAVG within limits of TREF, (b) reduce turbine load to match TREE with TAVG (c) periodically take rod control to MANUAL from AUTO and insert the bank to move AFD near the target value, (d) return rod control to AUTO when not using the bank to control AFD, and (e) repeat the above as necessary to accomplish the load change.

5) Actions effecting reactivity are directed in the following step. O-SO-62-7 requirements shall be adhered to for reactivity changes (i.e. reactivity balance, amounts of boric acid or water). All appropriate verifications and peer checks shall be utilized durinq performance.

BOP [71 INITIATE a load reduction BOP [8] MONITOR turbine load decreasina BOP [9] MONITOR MFP discharge pressure:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 1 Page 5 of 55 Event

Description:

Reduce power in preparation for MT Valve testing Time I Position Applicants Actions or Behavior 9.ij DETERMINE MFP 1P Program setpoirit using Appendix A.

[9.2] IF auto control of any MFWP conolIer is NOT functional, THEN ADJUST MFWP speed as necessary to maintain MFWP A and B liowispeed approximateLy matched USING one of the following:

921] MFWP speed controller in MANUAL OR 19.2.21 Governor Valve Positioner USING I ,2-SO-2/3-i, Sect 8.6.

CAUTION: Do NOT exceed a load change rate of plus or minus 5%Iminute or a step change of 10%

NOTE: TAVG is programmed from 578.2°F at 100% power to 547°F at zero power at a rate of 0.312°F per

% power.

CREW [10] MONITOR the following during the load reduction:

[10.1] TAVG_following_TREF_program.

[10.2] All RPls, group step counters for rod insertion limits and inoperable rods or rod misalignment, Loop AT, and NIS for correct_power_distribution_and_quadrant_power_tilts.

[10.3] Core AFD within 5% control band around the power level dependent target_value.

NOTE: Valve position limit and governor control meter are displayed on EHC Display panel 1, 2-XX-047-2000 (M-2).

[10.4] Valve position limit approximately 10% above the current BOP governor_control_indication_as_turbine_load_is_changed.

Lead examiner may cue the next event when power has been decreased sufficiently to record a reactivity manipulation.

Appendix D Required Operator Actions Form ES-D Op Test No.: NRC Scenario # 4 Event # 2 Page 6 of 55 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time H Position I Apnlicants Actions or Behavior Booth Instructor: When directed, initiate Event 2 Indications available:

Annunciators:

XA-55-5A Window A-6 TS-68-2MIN RC LOOPS T AVG IAUCT T AVG DEVN HIGH-LOW

. B-6 TS-68-2AIB REACTOR COOLANT LOOPSAT DEVN HIGH-LOW

. XA-55-6A Window D-2 TS-68-2J REACTOR COOLANT LOPS LO LO TAVG 1-M-5 indications:

. RCS Lp 4 Indicator 1-TI-68-67E indicates downward trend consistent with rod motion;

. 1-Tl-68-67D indicates downward trend consistent with rod motion;

. 1-TI-68-67A indicates downward trend consistent with rod motion;

. 1-TI-68-67B indicates downward trend consistent with rod motion; T=5 CREW Respond in accordance with Alarm Response Procedures Diagnose failure and place rods in manual to stop rod motion RO Refer to Annunciator Response Procedure SRO Enter and direct action of AOP-C.O1 Section 2.1 SRO may use or refer to AOP-C-O1, ROD CONTROL SYSTEM SRO MALFUNCTIONS, Section 2.1, Uncontrolled Rod Bank Movement:

1. STOP uncontrolled rod motion:

RO a. PLACE rod control in MAN.

b. CHECK rod motion STOPPED.

CAUTION: Control Rods should NOT be manually withdrawn during a plant transient.

2. CHECK for plant transient:

CREW

a. CHECK reactor oower and T-av STABLE.

RO 3. CHECK for instrumentation malfunction:

a. CHECK nuclear instrumentation OPERABLE.

b. CHECK RCS RTDs OPERABLE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 2 Page 7 of 55 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior

c. CHECK turbine impulse pressure channels OPERABLE.

d. CHECK T-ref OPERABLE USING TR-68-2B.

RO (RNO Required)

RNO:

RO d. PERFORM the following:

1) PLACE Steam Dumps in Steam Pressure Mode USING 0-50-1-2, Steam Dump System

2) DETERMINE Program T-avg for current reactor power USING Appendix A or

[CS Trend Menu, Program T-avg)

RO e. CHECK Auctioneered T-avg OPERABLE USING TR-68-2B.

RO 4. CHECK for inadvertent RCS dilution:

a. CHECK evidence of dilution INDICATED:

. VCT level indication OR

. T-avg rising unexplained with stable turbine load.

b. GO TO AOP-C.02, Uncontrolled RCS Boron Concentration Changes.

RO 5. CHECK for inadvertent boration flow:

a. CHECK evidence of boration flow INDICATED:

. Batch counters flow indication OR

. VCT level indication OR

.__T-avg_dropping_unexplained.

b. GO TO AOP-C.02, Uncontrolled RCS Boron Concentration Changes.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 2 Page 8 of 55 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time H Position H Applicants Actions or Behavior NOTE: When adjusting T-avg, reactivity changes should be accomplished by only one method at a lime.

RO 6. RESTORE T-avg to within 1.5°F of T-ref:

. POSITION control rods OR

. ADJUST turbine load OR

. ADJUST RCS boron concentration USING 0-SO-62-7, Boron Concentration Control.

SRO 7. EVALUATE the following Tech SpecsITRM for applicability:

. 3.1.1.1, Shutdown Margin -

Greater than 200°F a 3.1.1.4, Minimum Temperature for Criticality a 3.1.31. Movable Control Asselies Group Height a

3.1.3.5. Shutdown Rod Insertion Limit a 3.1.3.6, Control Rod Insertion Limits a 3.2, Power Distnbution Limits (entire section)

SRO 8. CHECK cause of continuous rod motion IDENTIFIED.

CREW 9. ENSURE Maintenance initiated as required.

SRO 10. ENSURE Plant Management notified of failure.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 2 Page 9 of 55 Event

Description:

Auto Rod Motion Failure (Tref Computer failure)

Time Position Applicants Actions or Behavior

11. WHEN problem corrected AND automatic rod control is available, THEN CREW PERFORM the following:

a ENSURE T-avg arid T-f matched within 1F b PLACE control rods n AUTO USING O-SO.-85-i, Rod Control System.

SRO 12. GO TO appropriate plant procedure.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead Examiner may cue next event when stable plant conditions are achieved.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 3 Page 10 of 55 Event

Description:

Feedwater Header Pressure Transmitter PT-3-1 fais high Time I Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 3 Indications available:

1-M-4 indications:

. Feedwater flow dropping to all steam generators;

. Level dropping in all steam generators; Annunciators:

. XA-55-5A Window B-7 LS-3-42D STEAM GEN LVL HIGH-LOW DEVIATION

. XA-55-6B Window A-7 LS-3-39D STM GEN LOOP I LOW FW FLOW LOW WATER LEVEL

B-7 LS-3-52D STM GEN LOOP 2 LOW FW FLOW LOW WATER LEVEL

C-7 LS-3-94D STM GEN LOOP 3 LOW FW FLOW LOW WATER LEVEL

. D-7 LS-3-107D STM GEN LOOP 4 LOW FW FLOW LOW WATER LEVEL T = 10 Respond MCR indications and alarms according to Alarm Response CREW Procedures Diagnose failure.

BOP Refer to Annunciator Response Procedure SRO may use AOP-S.O1, Loss Of Normal Feedwater Section 2.2, Loss of SRO Main Feedwater Pump Control NOTE: Step 1 is an IMMEDIATE ACTION.

BOP 1. RESTORE feedwater pressure:

a.__RESTORE_feedwater_pressure:

MEPT IA(2A) & IB(23)

Speed Contro OR

. MFPT IAC2A) Speed Controller OR

. MFPT 13(28) Speed Controller

b. ADJUST speed on affected MFP(s) to restore feedwater pressure to BOP normal_Q-1040_psig_at full_power).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 3 Page 11 of 55 Event

Description:

Feedwater Header Pressure Transmitter PT-3-1 fails high Time Position Applicants Actions or Behavior BOP 2. DETERMINE if MFP trip is needed:

a._CHECK_BOTH_MFWPs_in_service.

BOP b. IF MFW pump trip is needed due to loss of speed control, THEN PERFORM_the_following:

1) TRIP affected MEP.

2) GO TO applicable section:

UNIT INITIAL CONDITION SECTION i Above 76%Turbine Load Z3 Below 76% Turbine Load 2.5 Above 77% Turbine Load 2.4 2

Below 77% Turbine Load 2.6 CAUTION: Feed flow transients may impact core thermal power.

BOP 3. MAINTAIN steam generator level(s) on program.

NOTE: Appendix C may be used to determine program feedwater DIP for current power.

4. MAINTAIN MFP discharge pressure on program USING lOS or available BOP control_board_indications.

CAUTION: Reactor operation at low power levels for extended periods may challenge reactivity control due to xenon changes.

Appendix D Required Operator Actions Form ES-D-]

OpTestNo.: NRC Scenario# 4 Event# 3 Page 12 of 55 Event

Description:

Feedwater Header Pressure Transmitter PT-3-1 fails high Time Position Applicants Actions or Behavior RO 5. CHECK Reactor sower qreater than 5%.

CREW 6. INITIATE repairs on failed equipment.

SRO 7. GO TO appropriate plant procedure.

Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Manaqement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead examiner may cue the next event when MFP Control is established in MANUAL and SG levels are controlled.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenailo # 4 Event # 4 Page 13 of 55 Event

Description:

Pressurizer Pressure Transmitter 1 -PT-68-340 (Ch 1) faUs high Time I Position Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 4 Indications available:

Annunciators:

. XA-55-5A Window B-3 PS-68-340F1G PRESSURIZER PRESS ABOVE REF SET POINT

. XA-55-6A Window C-5 PS-68-340A PRESSURIZER HIGH PRESSURE 1-M-5 indications:

. RCS PZR PRESS 1-PI-68-340A pressure going up

. RCS PZR PRESS Recorder 1-PR-68-340 pressure going up;

. 1-XX-55-5, Reactor Trip Status Panel PROT. SET 4 TROUBLE Status light T = 20 Respond MCR indications and alarms according to Alarm Response CREW Procedures Diagnose failure.

BOP Refer to Annunciator Response Procedure SRO may use AOP-I.04, PRESSURIZER INSTRUMENT AND CONTROL SRO MALFUNCTIONS Section 2.3, Pressurizer Pressure Instrument OR Controller Malfunction NOTE: Step 1 is an IMMEDIATE ACTION.

1. CHECK normal spray valves CLOSED.

RO (RNO Required)

RNO:

IF RCS pressure is less than 2260 psig, THEN CLOSE affected spray valve(s) USING the following:

. PIC-68-340A, Master Pressure Confroiler OR

. PZR Spray controllers PIC-6S-340D (Loop 1) and/or PIC.68-340B (Loop 2)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 4 Page 14 of 55 Event

Description:

Pressurizer Pressure Transmitter 1 -PT-68-340 (Ch 1) fails high Time IJ Position Applicants Actions or Behavior

2. MONITOR pressurizer pressure stable or trending to desired pressure.

NOTE: Appendix L shows layout of PZR pressure control for operator reference.

RO 3. CHECK PI-68-340A NORMAL.

RO 4. CHECK P1-68-334 NORMAL.

NOTE: A failure of channel Ill (P-68-323) will affect the automatic actuation of PCV-68-334, PZR PORV, in the normal pressure control circuit. LTOPS operation of this PORV is unaffected by this failure (except when PORV handswitch is in CLOSE position).

5. CHECK P1-68-323 NORMAL.

NOTE: A failure of channel IV (P-68-322) will affect the automatic actuation of PCV 340A, PZR PORV, in the normal pressure control circuit. LTOPS operation of this PORV is unaffected by this failure (except when PORV handswitch is in CLOSE positic n).

6. CHECK P1-68-322 NORMAL.

7. CHECK for PIC-68-340A Pressure Controller malfunction:

a NOTIFY MIG to determine and correct the cause.

b NOTIFY Duty Operations Manager of the situation, CAUTION: RCS pressure changes and changes in RCS boron concentration (due to differences between Pzr and RCS boron) may cause small change in core reactivity.

Appendix D Required Operator AcUons Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 4 Page 15 of 55 Event

Description:

Pressurizer Pressure Transmitter 1-PT-68-340 (Ch 1)fails high Time I Position Applicants Actions or Behavior

8. MONITOR reactor power:

a. CHECK reactor in Mode I or 2.

b. MONITOR core thermal power for unexpected changes.

9. EVALUATE the following Tech Specs for applicability:

. 3.2.5 DNB Parameters

. 3.3.1.1 (3,3.1), Reactor Trip System Instrumentation

. 3.3.2.1 (3.3.2), ESF Actuation System Instrumentation

. 3.3.3.5 Remote Shutdown Instrumentation

. 3.4.4 Pressurizer Heaters may be applicable while heaters. are unavailable due to instrument failure)

. 3.2.5.b DNB Parameters Applies restore the parameter (Pressurizer Pressure) wli 2 hrs. or reduce to 5% RTP w/i the next 4 hrs.

AND

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation Action 6 (From Table 3.3-1 Items 7, 9, 10) Applies Trip mop Bistables w/i 6 hrs.

AND

. 3.3.2.1 (3.3.2), Engineered Safety Feature Actuation System Instrumentation Action 17 (From Table 3.3-3 Item I .d) Applies Trip mop Bistables wli 6 hrs.

Action 22.a (From Table 3.3-3 Item 8.a) Apply Declare the interlock inoperable and verify that all affected channels of the functions listed are OPERABLE w/i 6 hrs.

TS 3.3.3.5 may be identified; SRO would dispatch an AUO to the Auxiliary Control Room to validate indications/controls affected.

TS 3.4.4 would not be applicable here since the operator has manual control capability from the MCB.

[ppendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 4 Event # 4 Page 16 of 55 Event

Description:

Pressurizer Pressure Transmitter 1 -PT-68-340 (Ch 1) fails high Time Position Applicants Actions or Behavior

10. CHECK PZR PRESS and PZR SPRAY controllers in AUTO.

(RNO Required)

RNO:

WHEN malfunction has been identified AND isolated or corrected, THEN PERFORM the followinci:

a. ENSURE Master Pzr Pressure Controller PIC68---340A Output Percent Meter is less th:afl 40%.

b. ENSURE PZR PRESS Controller, PZR SPRAY controller, and PZR HTRS in AUTO, NOTE: If performing AOP in conjunction with AOP-l.11 for an Eagle LCP failure, then actions to hard trip bistables should be delayed until Eagle system reset is attempted. Actions to hard trip bistables must be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months UNLESS affected loop is restored to operable status by resetting Eagle rack.

SRO marks F IA

11. REMOVE failed pressurizer pressure channel from service:

a. CHECK any pressurizer pressure channel INOPERABLE.

b. CHECK OTAT setpoint on affected channel NORMAL.

c.__IF_any_of the_following_conditions_exists:

a this procedure was entered due to Eagle 21 malfunction iAOP-ti 1)

OR a Engineering or Maintenance has verified OTAT setpoint is NOT affected by failure, THEN PERFORM applicable appendix:

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event# 4 Page 17 of 55 Event

Description:

Pressurizer Pressure Transmitter 1-PT-68-340 (Ch 1)fails high Time 0 Position 0 Applicants Actions or Behavior PZR PRESSURE CHANNEL AFFECTED APPENDIX INSTRUMENT RACK P-58-340 (P455) 1 1 E P-&8-334 (P456) H 5 F P-58-323 (P-457) III 9 0 P-68-322 (P458) IV 13 H

d. IF any of the following conditions exists:

a transmitter signal failed (entire instrument loop affected including OTT pressure input)

OR a OTT pressure input potentially affected or status CANNOT be determined, THEN PERFORM applicable appendix:

CHANNEL APPENDIX P-68-340 (P-455) I A P-68-334 (P-456) II B P-6-323 (P457) III C P-68-322 (P458) IV D

12. GO TO appropriate plant procedure.

END_OF_SECTION

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 4 Page 18 of 55 Event

Description:

Pressurizer Pressure Transmitter 1 -PT-68-340 (Ch 1) fafls high Time Position Applicants Actions or Behavior Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the CREW brief.

Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead examiner may cue the next event when Pzr Pressure control is returned to automatic and notifications identified.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 4 Event# 5 Page 19 of 55 Event

Description:

lB MFP Trip Time H Position H Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 4 Indications available:

Annunciators:

. XA-55-2A Window B-I TURBINE RUNBACK BOP

XA-55-3B Window A-2 TRIPPED

. B-I MAIN FEEDWATER PUMP TURBINE lB ABNORMAL I-M-3 indications:

. MFPT lB SPEED I-SI-46-20B shows decreasing RPM

MFPT lB OUTLET PRESSURE I-PI-3-80A shows decreasing pressure

MFPT lB OUTLET FLOW I-FI-3-84 shows decreasing flow T = 30 Respond MCR indications and alarms according to Alarm Response CREW Procedures Diagnose failure.

BOP Refer to Annunciator Response Procedure SRO may use AOP-S.O1, Loss of Normal Feedwater Section 2.3, Unftl SRO Loss of One Main Feedwater Pump Above 76% Turbine Load BOP 1. VERIFY turbine runback to less than 72% load (-88O MWe).

RO 2. VERIFY control rods inserting automatically to match T-avg and T-ref.

BOP 3. ENSURE runninq main feedwater pump FULLY LOADED:

. Speed controller output at maximum. [M-3, SIC-46-20A or SIC 20B1 BOP 4. ENSURE AFW pumps started:

a. MDAFW Pumps RUNNING. [M-4]

b._TDAFW_Pump_RUNNING._[M-3}

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 5 Page 20 of 55 Event

Description:

lB MFP Trip Time Position Applicants Actions or Behavior C. TDAFW Pump LCVs OPEN. [M-31

d. MDAFW Pump recirculation valves CLOSED: [M-4]

. FCV-3-400 a FCb3-401

5. ENSURE affected Main Feedwater Pump Turbine Condenser isolation BOP valves CLOSED:

a. Condenser A a FCV-2-205, Condensate Inlet a FCV-2-210, Condensate Outlet OR

b. Condenser B

. FCV-2-21 1, Condensate Inlet a FCV-2-216. Condensate Outlet

6. ENSURE the following steam generator blowdown valves CLOSED BOP

[M-41:

FCV-i-7

FCV-1-14 a FCV-T-25

. FC[1-32 BOP 7. MONITOR steam generator levels returning to program level.

Evaluator Note: BOP may request implementation of a b & d parts of this steps RNO to null FRV controllers_and_stabilize_MFPC_following_the_FE/SF_mismatch_and_SG_Level_transient.

RNO:

BOP PERFORM the following:

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 4 Event# 5 Page 21 of 55 Event

Description:

lB MFP Trip Time Position Applicants Actions or Behavior

a. IF any feed reg valve is in AUTO AND controller deviation is off-scale high with level above program, THEN PLACE affected feed reg valve controller(s)_to_MANUAL_and_back_to_AUTO_to_reset_output.

b. IF manual control of MFWP speed or feed reg valve position is needed, THEN PERFORM the following as necessary:

. ADJUST running MFWP speed OR

. ADJUST main feed reg valve position.

c. IF reactor trip is imminent due to low S/G level, THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety Injection.

d. IF necessary to prevent SIG overfill, THEN CLOSE Turbine Driven AFW LCV5. [M-3}

e. WHEN SIG levels are stable and on program, THEN EVALUATE placing MFWP_speed_controls_and_main_feed_reg_valve_controllers_in_AUTO.

NOTE: If LEFM thermal power (U2118) is inoperable, rod insertion limit curve must be raised by 3 steps. Rod insertion limit alarms and ICS display are NOT automatically_adjusted_when_LEFM_is_inoperable.

RO 8. MONITOR control rods above low-low insertion limit using ICS or COLR.

Evaluator Note: Appendix A attached at the end of this event guide.

RNO:

INITIATE boration USING Appendix A.

RO SRO EVALUATE Tech Spec LCO 3.1.3.6 and 3.1.1.1.

. 3.1.3.6, CONTROL ROD INSERTION LIMITS Action A Applies Restore w/i limits w/i 2 hrs., or reduce to less than or equal to that fraction of RATED THERMAL POWER which is allowed by the group position using the insertion limits specified in the COLR, or Ht Stby w/i 6 hrs.

AND

. 3.1.1.1, SHUTDOWN MARGIN Tavg Greater Than 200°F Applies immediately initiate and continue boration at 35 gpm until the SHUTDOWN MARGIN is restored (CB D Rods above the Lo-Lo RIL),

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 5 Page 22 of 55 Event

Description:

1 B MFP Trip Time Position Applicants Actions or Behavior CREW 9. DISPATCH operator to investigate cause of main feedwater pump trip.

CREW 10. ENSURE unit STABILIZED:

a Rx Power STABLE a S!G Leveis STABLE.

. Tavg Tref approximatey matched

. Steam dump valves CLOSED NOTE: The load rejection circuit may require several minutes decay time before C-7 can be reset.

11. IF Steam Dumps are in Tavg Mode, THEN RESET Steam Dump Load BOP Rejection Signal:

a. PLACE HS-1-i03A and 1038, Steam Dump Control, in OFF.

b. PLACE HS-1-103D, Steam Dump Control, in RESET and VERIFY sphng return to TAVG.

c. VERIFY 0-7, LOSS OF LOAD INTERLOCK permisiva DARK IM-4A, E-5]

d. ENSURE Steam Dump demand is ZERO.

e. PLACE HS-1-103A and 1038, Steam Dump Control. in ON.

12. RESTORE turbine control USING Appendix B, Turbine Runback BOP Restoration.

Evaluator Note: Appendix B attached at the end of this event guide.

LAppendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # 5 Page 23 of 55 Event

Description:

1 B MFP Trip Time Position Applicants Actions or Behavior BOP 13. EVALUATE need to reduce number of runninci condensate nums:

a EVALUATE stopping one condensate booster pump USING 1-SO-213-1.

a EVALUATE stopping cond demin booster pumps USING i-SO-2/3-I.

RO 14. EVALUATE need to borate to restore AFD USING 0-SO-62-7.

NOTE To ensure unit is within capac Of :OflC MFWP the following should be considered when determining final power Ievel

. Power should be reduced below 60% (if all cond booster pumps and heater drain tank pumps in service) or 55% (if two cond booster pumps in service).

. Less than or equal to 90% controller output should be maintained on running MFWP

15. INITIATE turbine load reduction to reduce steam flow below capacity of SRO one MFWP USING 0-GO-5, Normal Power Operation.

16. WHEN turbine load has been reduced to below capacity of one MFWP, BOP THEN RESTORE the followincj systems to NORMAL.

a Auxiliary Feedwater USING 1-SO-3-2

. Steam Generator B lowdown USING 1-SO-15-i CREW 17. INITIATE repairs on failed equipment.

SRO 18. GO TO appropriate plant procedure.

I Appendix D Required Operator Actions Form ES-D-j Op Test No.: NRC Scenario # 4 Event # 5 Page 24 of 55 Event

Description:

1 B MFP Trip Applicants Actions or Behavior Evaluator Note: The following CREW Brief and Notification actions are not contained in the procedure.

CREW Brief would typically be conducted for this event as time allows prior to the next event.

Notifications should be addressed as applicable if not specificaNy addressed by the procedure or in the CREW brief.

Operations Manaciement Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

(Note: Maintenance notification may be delegated to the Shift Manager).

Lead examiner may cue the next event when Feedwater and Feed Pump control is stable and MT Control is reset.

Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 4 Event # 5 Page 25 of 55 Event

Description:

lB MFP Trip APPENDIX A IMMEDIATE BORATION TO RESTORE RODS ABOVE LOW-LOW ROD INSERTION LIMIT

[1] IMMEDIATELY INITIATE boration by performing the following:

[a} PLACE BA transfer pump aligned to blender in FAST speed. L1

[b] ADJUST FCV-62-1 38 as necessary to estabLish boration flow greater than or equal to 35 gpm from BAT (at [east 6120 ppm). C

[c] IF requhed flow via FCV-62-138 CANNOT be established, THEN PERFORM one of the foIlowng:

. INITIATE normal boration of greater than or equal to 35 gpm from BAT (at least 6120 ppm)

USING 0-80-62-7 Sect GA. C OR

. INITIATE I oration flow of greater than or equal to 90 gpm from RWST USING 0-80-62-7 Sect. BA. C

[d] WHEN control rods are above low-low insertion limit.

THEN REDUCE or STOP boration flow as required. C END

Appendix D Required Operator Actions Form ES-D Op Test No.: NRC Scenario # 4 Event # 5 Page 26 of 55 Event

Description:

1 B MFP Trip APPENDIX B TURBINE RUNBACK RESTORATION

$OTE This appendix is uaed to rove turbine from value poaffion Imiter prior to startinç load reductIon ftI[c*ing a BOP runback.

[1] ENSURE governor valve tracking meter centered close to ZERO.. 1]

121 DEPRESS FTURB MANUAL] mode seiectcr pushbutton. ED

[3J VERIFY :fTURB MANUALI lamp LIT D

[41 VERIFY rererence and setter counters stabilize.. ED

[51 ENSURE gmor valve tracking meter centered close to ZERO..

[6j DEPRESS lOPER AUTOI flade aeieetcr pushbutton ED

[Ij VERIFY lOPER AIJTOI lamp LIT.. ED

&] VERIFY jelerence and setter counters stabilize. ED I9 IF VALVE P05 UMIT light LIT, THEN REDUCE twbine load reference using SETTER UNIL VALVE P05 LIMIT IIt is DARK. ED END OF TEXT

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6 Page 27 of 55 Event

Description:

2 SG Tube Leakage Time Position N Applicants Actions or Behavior Booth Instructor: When directed, initiate Event 5 Indications available:

Annunciators:

. O-XA-55-12A Window B-5, 1-RA-120A1121A, STM GEN BLDN LIQ SAMP MON HI RAD C-I, I-RA-90-119A, CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD D-3, 1-RA-90-99A, CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD

. XA-55-30 C-B, RA-421A, MN STM LN HI RAD Indications available:

Deviations or unexpected indications on any of the foflowing may indicate a steam generator tube leak:

I charging how rises to maintain Pressurizer level.

2. Rise in makeup to VCT

3. Rising activity on:

OrdCF1S& Vacuum Exhaust Radiation Monitor

SIG Blowdown Liquid Radiation Monitor

Math Steam Line Monitor

& 510 sample results indicating greater than o.r equal to 5 gallons per day gpd) on any 51G.

T 50 Diagnose and respond MCR indications and alarms according to Alarm CREW Response Procedures.

SRO may use AOP-R.O1, Steam Generator Tube Leak 2.2, Secondary plant SRO radiation levels rising with stable charging flow and pressurizer level. [C.4]

NOTE This section provides steps to monitor primary to secondary leakage and directs unit shutdown it leakage limits are exceeded. Entry into this section is required when secondary radiation monitors indicate a rise in primary-to-secondary leakage or when Chemistry determines S!G leak rate exceeds 5 gaL per day (gpd)

RO 1. MONITOR charging flow and Pressurizer level STABLE.

RNO:

IF Charging flow rising OR Pressurizer level dropping due to S/G tube leak, SRO THEN GO TO Section 2.1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6 Page 28 of 55 Event

Description:

2 SG Tube Leakage Ti me Position ADalicants Actions or Behavior SRO 2. EVALUATE EPIP-1, Emerqency Plan Classification Matrix.

SRO 3. EVALUATE the following Tech Specs for applicability:

. 3.4.6.2. c, Operational Leakage Action A Applies Prim-to sec leakage not w/i limits, Ht Stby wli 6 hrs, CId SD w/i the following 30 hrs.

AND

. 3.7.1.4, Secondary Coolant Activity Applies When notified by chemistry, Ht Stby w/i 6 hrs. & Cld SD w/i the following 30 hrs.

NOTE Lower containment red monftor count rate rising concurrenfly with secondary rad nIOn[tOfS may Ifldcate a sudden fuel dafect which could give a false indication of SG tube leek. Threshold values for correlating RM-99i I count rate to SIG tube ieakae must be recalculated f RCS activity has changed sigmflcanlty SRO 4. INITIATE samplinq to confirm SIG leak:

a. CHECK lower containment rad monitor count rate STABLE or DROPPING.

b.__PERFORM_Appendix_E,_Chemistry_Sampling_Actions.

NOTE 1: Based on monitor sensitivity, condenser vacuum exhaust red monitor (RM-90-99 or -i i) is preferred indication for ieak rate rnonitodng Other secondary red monitors (if evaitabie) and!or SIG sampling shoutd be used for coniirniation.

Confirmation time should l)e kept to a mininium NOTE 2 Radiation Monitor values (cpm) must be converted to a gallons per day lgpd) equivalency to determine ieakrate Correlation of R!Jl-90-9911 19 responses to Primary Secondary leak rates and limits are provided by Chern Lab on the daily turnover package.

NOTE 3: Steady State conditions (<10% power change per hour) are required to accurately correlate cpm readIngs with gpd leakage

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 4 Event# 6 Page 29 of 55 Event

Description:

2 SG Tube Leakage Time I Position fl Applicants Actions or Behavior BOP 5. MONITOR primary-to-secondary leak rate...

Evaluator Note at this step SRO transitions to Section 2.1 based on RO recognizing SG leakage is affecting charging/pressurizer level control and BOP recognizing effects on FRV position ng.

Section 2.1 High Secondary Radiation AND Pressurizer level dropping OR Charging flow rising RO 1. MONITOR if Pressurizer level can be maintained:

a. CONTROL charging flow USING FCV-62-93 and FCV-62-89 as necessary to maintain pzr level on program

b. MONITOR pressurizer level STABLE or RISiNG..

NOTE I Appendix F or G can be used to estimate leak rate.

NOTE 2 if letdown was isolated in Step 1, the leak rate may have exceeded the capatq of one COP in the normal charging alignment (EAL 1 .2.2P).

SRO 2. EVALUATE EPIP-1, Emergency Plan Classification Matrix.

RO 3. MONITOR VCT level:

a MAINTAIN VCT level greater than 13%

USING auto or manual makeup

. CHECK VCT makeup capability adequate_to_maintain_level.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6 Page 30 of 55 Event

Description:

2 SG Tube Leakage Time Position Applicants Actions or Behavior BOP 4. MONITOR indications of leaking SIG:

a. NOTIFY Chem li.ab to evaluate Primary to Secondary Leakage USING 1(2)SICEMO68.1 37.5:

. Method 1, Rapid Identification of Leaking Steam Generators

. Method 3, Gondenser Vacuum Exhaust (CVE) Sam pling for Determination of Primary4o Secondary (P15) Leakage.

b. NOTIFY RADCON to monitor Turbine Building and site environment:

. Steam lines

. S1G blowdown

c. IDENTIFY leaking SiG(s)

USING any of the following:

. Unexpected rise in any S/G narrow range level OR

. SiG sample results OR

. RADCON survey of main steamlines and SIG blowdown lines OR

. High radiation on any main steamline radiation monitor.

SRO 5. EVALUATE the following Tech Specs for applicability:

. 3.4.6.2, Operational leakage

. 3.7.14, Secondary Coolant Activity

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6 Page 31 of 55 Event

Description:

2 SG Tube Leakage Time Position Applicants Actions or Behavior

. 3.4.6.2.c, Operational Leakage Action A Applies Prim-to sec leakage not w/i limits, Ht Stby wli 6 hrs, CId SD wli the following 30 hrs.

AND

. 3.7.1.4, Secondary Coolant Activity Applies When notified by chemistry, Ht Stby w/i 6 hrs. & CId SD w/i the following 30 hrs.

Lead Evaluator Note: At the Lead Examiner direction, the leak will increase to approximately 200 gpm resulting in the reactor trip demand/decision by crew NOTE Initiating shutdown required by Tech Specs requires 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months NRC notification per SPP-35, Regulatory Reporting Requirements.

SRO 6. INITIATE rapid shutdown by performing the following:

a ANNOUNCE S/G tube teak on PA system

b. PERFORM rapid shutdown USING AQP-003 WHILE continuing in this section c ENSURE power reduced to less than 50% within one hour.

d. ENSURE unit in Mode 3 within the following 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

BOP 7. MINIMIZE Spread of contamination:

a IF tube leak identified on S/G #1 AND SIG #4 is intact, THEN PERFORM the foltowing:

I

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event 6 Page 32 of 55 Event

Description:

2 SG Tube Leakage Time Position Applicants Actions or Behavior

1) EVALUATE LCO 3.7i2.

2) CLOSE FCV-1-15 TDAFWP steam Supply from SIG #i;.

3) ENSURE FcV1-16 TDAFWP steam supply om S/G #4 OPEN.

b. PERFORM EA-O-3, Minimizing SRO Secondary Plant Gontamination.

c. IF SIG blowdown is aligned to the river, SRO THEN TERMINATE SIG Blowdown to river:

1) ENSURE SIG blowdown flow control FCV-15-43 CLOSED.

2) DISPATCH operator to perform EA-1 5-1 Realigning 510 B lowdown to Cond DL

3) WH:EN EA1:51 completed, THEN ADJUST FCV-1 5-43 to establish desired blowdown flow.

CREW d. NOTIFY Cem Lab to determine release rate for condenser vacuum exhaust USING Q-Sl-CEM-030-415.O and 0-Si-C EM-030-407.2.

e. NOTIFY Chem Lab to evaluate rerouting steam generator sample drain lines to FDCT USING Q-TI-CEM-000-01 6.4.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 6 Page 33 of 55 Event

Description:

2 SG Tube Leakage Time [ Position I Applicants Actions or Behavior BOP { WHEN notified by Chemistry to bypass Condensate Dl, THEN DISPATCH AUO to bypass polishers on affected unit:

. Unit I Only:

PLACE i-HS-14-3, Condensate Polisher Bypass Valve to OPEN

[Cond Dl BidgJ

Unit 2 Only:

PLACE 2.HS-143, Condensate Polisher Bypass Valve to OPEN

[Cond Dl Btdg

9. EVALUATE Appendix C, Contingency SRO Plan for Control and Processing of Large Volumes of Contaminated Water tC5j.

RD 8. CHECK reactor trip breakers OPEN.

Evaluator Note: at or before this point, the crew would have tripped the unit and transitioned to E-O, Rx Trip or SI Actuation.

Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 34 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time H Position fl Applicants Actions or Behaviors Booth Instructor: When directed, initiate Event 7 Indications available:

1-M-3:

. LOOP #2 FEEDWATER MAIN REG VALVE indicator shows a lower feed flow that steam flow; I -M-4:

. LOOP #2 FF indicators showing lower flow than SF for a constant power level.

. RCS Pzr LEVEL Chs, 1-Ll-68-339A, 335A & 320 going down slowly initially; I -M-5:

. RCS PZR LEVEL I-LR-68-339 shows Pzr level trending down initially.

. I-PR-68-69, RCS LOOP I HL WIDE RANGE PRESS indicator trending down.

. CHARGING HDR FLOW IFl-62-93A indicating above normal flow to maintain Pzr level on program.

I -M-6:

. I-Pl-68-66A, HL Pressure LOOP 3 indicator trending down.

. I-Pl-68-62, RCS HL Press WR indicator trending down.

. I-PI-68-69, RCS HL Press WR indicator trending down.

Direct entry to E-O, Reactor Trip or Safety Injection Evaluator Note: following IOA performance, prior to Steps 1-4 immediate action verification, RO/BOP surveys MOBs for any expected automatic system response that failed to occur. Upon discovery, they may take manual action(s) to align plant systems as expected for the event in progress. (Ref. EPM-4, Prudent Operator Actions)

E-O, Reactor Trip or Safety Injection Note I Steps 1 through 4 are immediate action steps Note 2 This procedure has a foldout page

1. VERIFY reactor TRIPPED:

RO

Reactor trip breakers OPEN

Reactor trip bypass breakers DISCONNECTED or OPEN

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 35 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time I Position I Applicants Actions or Behaviors

. Neutron flux DROPPING e Rod bottom lights LIT (No, if LOOP has occurred)

. Rod pos Won indkators ss than or eaual to 12 steøs.

2. VERIFY turbine TRIPPED:

BOP

. Turbine stor valves CLOSED.

BOP

3. VERIFY at least one train of shutdown boards ENERGIZED.

. Attempt to restore power to at least ONE train of shutdown boards

. Place DG lA-A control switch in START

. Verify Train A Shutdown Boards ENERGIZED CRITICAL TASK: Manually actuate at least one train of SIS-actuated safeguards before transition into E-3 series.

4. DETERMINE if SI actuated:

RO . ECCS pumps RUNNING.

Any SI alarm LIT [M-4D1 (SI will be actuated)

PERFORM ES-O.5, Equipment Verifications WHILE continuing in this BOP procedure._[ES-O.5_is_attached_at_the_end,]

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 36 of 55 Event

Description:

2 SGTR Time Position 1 Applicants Actions or Behavior Time Position Applicants Actions or Behaviors

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

RO b. CHECK narrow range level greater than 10% [25 ADV] in at least one S/S

c. CONTROL feed flow to maintain narrow range level between 10%

[25% ADV] and 50% in all SIGs.

7. CHECK if main steam lines should be isolated:

a. CHECK if any of the following conditions have occurred:

. Any S/G pressure less than 600 psig OR

. Any SIG pressure dropping UNCONTROLLED.

RO OR

. Phase B actuation

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1250 psig.

RO AND

. At least one CCP OR SI pump RUNNING b._STOP RCPs

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7. 8 Page 37 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time Position Appilcants Actions or Behaviors

9. MONITOR RCS temperatures:

. IF any RCP running, THEN CHECK T-avg stable at or trending between 547°F and 552°F.

RO OR

. IF RCPs stopped, THEN CHECK T-cold stable or trending to between 5470 F and 552° F.

10. CHECK pressurizer PORVs, safeties, and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

RO

c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11. CHECK S/G secondary pressure boundaries INTACT:

RO . All S/G pressures CONTROLLED or RISING

. All S/G pressures greater than 140 psig.

CHECK SIG tubes INTACT:

a. CHECK all SIG narrow range levels CONTROLLED or DROPPING.

RO b. Secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors. (App. A performed in ES-0.5).

(RNO_Required)

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 38 of 55 Event

Description:

2 SGTR Time Position Aoolicants Actions or Behavior Time Position ADDilcants Actions or Behaviors RNO:

IF any SIG has level rising in an uncontrolled manner OR has high radiation, THEN PERFORM the followinci:

IF any SIG has level rising in an uncontrolled manner OR has high radiation THEN PERFORM the following:

a MONiTOR status trees.

b. GO TO E-3, Steam Generator Tube Rupture.

E-3, Steam Generator Tube Rupture.

NOTE This procedure has a foldout page.

MONTGR at Feast one RCP RUNNING.

2. MONITOR RCP tilp criteria:

a. CHCK the foflowlng:

RCS pressure less,than 1250 psig AND

At least one CCP OR SI pump RUNNING

b. STOP RCPs.

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 39 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time Position Applicants Actions or Behaviors MONITOR indications of Ruptured SIG(s):

a. IDENTIFY Ruptured: 516(s) S indicated by any of the following:

. Unexpected rise in any 516 narrow range leVel.

OR

High radiation from any SIG sample.

OR

RADGON survey of main steam Hnes and SIG blowdown Hnes, OR High radiation on any main steamline radiation monitor.

Evaluator Note: Step #3 RNO following should is included for information; the ruptured SG should have been ident fied earlier Step 3 RNO:

a. WHEN Ruptured 5/6(s) identifIed, THEN PERFORM Steps 4 through 8.

GO TO Step 9.

CAUTION Isolating both steam supplIes to the TD AFW pump when it is the only source of feed flow will result in lass of secondary heat slnk ISOLATE flow from Ruptured 516(s):

Appendix D Required Operator Actions Form ES-DJ Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 40 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time H Position Applicants Actions or Behaviors

a. ADJUST Ruptured S/G(s) atrnosph eric relief controller setpoi nt to 87% in AUTO. (1040 psig)

b. CHECK Ruptured SIG(s) atmospheric relief hand switch in P-AUTO and valve(s) CLOSED..

c. CLOSE TD AFW pump steam supply from Ruptured S/S FCV1-15 (SIG #1) or FCV-1-16 (S/S #4).

e CLOSE Ruptured SIG(s) MSIV and MSIV bypass valve.

CAUTION Feeding a SIG that is Faulted and Ruptured rncreases the potential for an uncontrolled RCS cooldown and SIG overfill. This option should NOT be cons dered UNLESS needed for RCS cooldown.

5. MONITOR Ruptured S1G(s) level:

a. CHECK narrow range vei greater than_10% t25%_AD4

b. WHE.N ruptured SIG level is greater than 10% [25% ADV),

THEN PERFORM the fOllowing:

1) STOP feed flow to ruptured 510.

2) ENSURE Turbine DrIven AFW LCV for ruptured SIG n CLOSE_PULL TO LOCK.

VERIFY Ruptured Sf0 ISOLATED

6. from Infant 515(s):

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 41 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time H Position I Applicants Actions or Behaviors

a. CHECI< either of the following conditions SATISF1EO

Ruptured SIG MSIVs and MSIV bypass valves CLOSED OR

. MSIV(s) and MSIV bypass valve(s)

CLOSED on intact S/G.(s) to be used for RCS cooldown,

b. CHECK S1G #1 or SIC3 #4 ruptured..

(RNO Required)

RNO:

b. GO TO Step 7.

7. CHECK Ruptured SIG pressure greater than 550 psig (Unlt 1) or 425 psig NOTE

Blocking low stearnne pressure SI as soon as pressurizer pressure is less than 1S60 psg will prevent an madverterit MSIV closure and keep the condenser available for steam dump,

After the low steamilne pressure SI sinai is blocked, main steamlina isolation will occur if the high steam pressure rate setpoint is exceeded.

The 1250 psig RCP trip criterion is NOT applicle after RCS cooldown is initiated in the following step.

B. NiTIATE RCS cooldown:

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 42 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time Position Applicants Actions or Behaviors

a. DETERMINE target core exit T/C temperature based on Ruptured SIG pressure:

Lowest Ruptured Target. core Exit SJG pressure (psig) TIC Temp (F) 1100 or greater 497 1050-1099 492 1000-1049 486 95fJ999 480 900-949 473 850-899 467 800-849 460 750 799 453 700-749 445 650-699 437 -

600-649 428 550-599 419 500-549 410 450-499 399 425-449 393

8. b. WHEN RCS pressure less 1960 psg, THEN PERFORM ttie following:

1) BLOCK OW stsmflne pressure SL

Appendix D Required Operator Actions Form ES-D-27 Op Test No.: NRC Scenario # 4 Event # 7. 8 Page 43 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time fi Position Applicants Actions or Behaviors

2) CHECK STEAMUNE PRESS 1501/St BLOCK RATE ISOL ENABLE pennissive LIT.

IM4A, A4j C. DUMP steam to on denser from Intact S!G(s) at maximum achievable rate:

1) CHECK condenser available:

C9 condenser ntedock permissive LIT. I M-4A, E63

Intact SIG MSIVs OPEN.

2) PLACE steam dumps in OFF.

3) ENSURE steam dumps in steam pressure mode with demand less than 25%.

4) PLACE steam dumps in ON.

5) ADJUST steam dump demand t FULLY OPEN three oooldown vaves,

6) WHEN T-avg s less than 54OF, THEN BYPASS steam dump interlock.

7) RAISE AFW flow to intact S/Ga as necessary to support cooldown.

d WHEN core exit T/Cs tess than target temperature determined in St.thstep Ba, THEN PERFORM the followin9:

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 44 of 55 Event

Description:

2 SGTR Time I Position I Applicants Actions or Behavior Time Position Applicants Actions or Behaviors

1) CLOSE steam dumps or SIG atmospheric reliefs to stop coo Idown.

2) RE. UCE AFW flow as necessary to stop cocidown.

MAINTAIN total feed flow greater than 440 gprn UNTIL level greater than 10% 25% ADVI in at least one Intact 51G.

3) MAINTAIN core exit T/Cs less than target temperature USIN6 steam dumps or atmospheric reliefs.

9. MAINTAIN Intact SIG narrow range levels:

a. Greater than 10% [25% ADV]

b. Between 20% [2.5% ADV] and 50%.

10. MONITOR pressurizer PORVs and lo.. valves:

a__Power to block valves AVAILABLE b.__Pressurizer PORVs_CLOSED

c. At least one block valve OPEN.

I . RESET 51 signaL

Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 45 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time If Position Applicants Actions or Behaviors 12, MONiTOR AC busses energized from start busses.

13. ENSURE Phase A anci Phase B RESET.

14 CHECK control air established to containment: [Panel 6K and 61.

. 1 -FCV-32-80 (2-FCV-32-1)

Train A essential air OPEN

. I -FCV-32-1 02 2-FCV-32-1 03)

Train B essential air OPEN

. I -FCV-321 10 (2-FCV-32-i ii) non-essential air OPEN.

15. DLTERMINE If RHR pumps should be stopped:

a. CHECK RHR pump suction agned from RWST..

b CHECK RCS pressure greater than 300 psig

c. STOP RHR pumps and PLACE in A-AUTO.

d. MONITOR RCS pressure greater than_300_psig.

Appendix D Required Operator Actions Form ES-D Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 46 of 55 Event

Description:

2 SGTR Time I Position 1 Apjlicants Actions or Behavior Time Position I Applicants Actions or Behaviors

16. CHECK if RCS cooLdown should be stopped:

a. CHECK core exit T/Cs less thn target temperature determined in Substep &a.

b. CLOSE steam dumps or atmospheric reliefs to :StOD cooldown,

c. RDU CE AFW flow as necessary to stop cooldown.

cL MAINTAIN core exit T/Cs less than target temperature USING steam dumps or atmospheric reliefs, 17 CHECK Ruptured SIG(s) pressure STABLE_or RISING.

18. CHECK RGS subcooling based :fl COYB exit T/Cs greater than 6OF CRITICAL TASK: Depressurize the RCS to meet SI termination criteria prior to affected SG overfill

19. DEPRESSURIZE RCS to minimize break flow and to refill pressurizer

a. CHECK normal pressurizer spray AVAILABLE.

b INITIATE maximum available pressurier spray.

Appendix D Required Operator Actions Form ES-D-j Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 47 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time Position Applicants Actions or Behaviors

c. CHECK depressurizatlori rate ADEQUATE.

i CONTINUE depressurization UNTIL any of the foflowhig conditions SATISFIED:

e Beth of the folIowng:

1) RCS pressure less than Ruptured S/Gs) pressure AND

2) Pressurizer level greater than 10% [20% ADVJ.

OR

. Pressurizer level greater than 65%.

OR

. RCS subcciing based on core exit T/Cs less than 4O°F.

a. CLOSE spray valve(s):

1) Normal spray valves.

2> Auxiliary spray vaIves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 48 of 55 Event

Description:

2 SGTR Time ] Position j Applicants Actions or Behavior Time I Position Applicants Actions or Behaviors

f. GO TO Caution prior to Step 22, CAUTION

Depressurizing the RCS using a pressurizer PORV may ca use PRT rupture wIth resu1ting abnormal containment conditions 4

Excessive cycling of a pressurizer PORV increases the potential for PORV failure.

NOTE Upper head voiding may occur during RCS depressurization if no RCPs are running This may result in rapidly rising pressurizer leveL.

20. DEPRESSURZE RCS USING one pressurizer PORV to minimize break flow and to refill pressurizer:

a CHECK at [east one pressurizer PORV AVAILABLE

b. OPEN one pressurizer PORV UNTIL any of the following conditions SATiSFiED:

Appendix D Required Operator Actions Form ES-D Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 49 of 55 Event

Description:

2 SGTR Time ] Position Applicants Actions or Behavior Time Position Applicants Actions or Behaviors

. Both of the following;

1) RCS pressure less than Ruptured S!G()

pressure AND

2) Pressurizer level greater than 10% [20% ADVI.

OR

. Pressurizer level greater than 65%.

OR

RCS subcooflng based on core exit TICs less than 4OF.

c. C1..OS pressurizer PORV.

d.__CLOSE_spray valve(s):

1) JormaI spray valves

2) AuxiUary spray valves.

b. ENSURE SI signal RESET.

c. STOP any unloaded diesel generators and PLACE in standby USING EA-82-1, Placing DIGs in Standby.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7, 8 Page 50 of 55 Event

Description:

2 SGTR Time 0 Position 1 Aoolicants Actions or Behavior Time f Position [ Aoplicants Actions or Behaviors

21. CHECKRCS pressure RISING:.

CAUTiON Any delay In terminatIng SI after termInation criteria are met may cause Ru,tured SI((s) Qjfl

22. CHECK if ECCS flow should be ternilnated;

a. RCS subcooling based on core exit TICs greater than 40SF.

I,. Secondary heat sinic

. Narrow range level in at least one Intact SIG greater than 10% [25% ADVI OR

. Total feed flow to SIGs greater than 440 gpm AVAILABLE.

c. RCS pressure STABLE or RISING

d. Pressurizer level greater than 10% [20% ADV).

23 STOP the following ECOS pumps; a STOP SI pumps and PLACE in A-AUTO b CHECK offsite power supply[ng_shutdown_boards.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 4 Event # 7 8 Page 51 of 55 Event

Description:

2 SGTR Time Position Applicants Actions or Behavior Time I Position 1 Applicants Actions or Behaviors

c. STOP all BUT one CCP and PLACE in A-AUTO.

24. ISGLATE CCP1T;

a. CLOSE iniet isolation valves FcV-S3-39 and FGV-6S.40,

b. CLOSE outlet isolation valves FCV63-2& and FCV6325.

END Lead Examiner: Scenario may be terminated when the CCPIT is isolated.

Appendix D Required Operator Actions Form ES-D-j Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 52 of 55 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior Equipment Verifications, ES-O.5

1. CHECK ERCW system operation:

BOP

VERIFY at least four ERCW pumps RUNNING.

VERIFY D/G ERCW supply valves OPEN.

BOP 2. VERIFY at least four ERCW pumps RUNNING

3. VERIFY CCS pumps RUNNING:

BOP

Pump lA-A (2A-A)

Pump lB-B (2B-B)

Pump C-S.

BOP 4. VERIFY EGTS fans RUNNING.

BOP 5. VERIFY generator breakers OPEN.

6. VERIFY AFW pumps RUNNING:

BOP

MDAFW pumps

__TD_AFW_pump.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control SIG levels, to establish flow due to failure, or to isolate a faulted SIG.

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 53 of 55 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior Evaluator Note: #1 SG MDAFW Level Control Valve Fails Open; the crew will need to decide how control

1 SG to prevent overfill.

7. CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP b. VERIFY TD AFW LCVs OPEN.

c. VERIFY MD AFW pump recirculation valves FCV-3-400 and FCV 401 CLOSED.

VERIFY MFW Isolation:

. MFW pumps TRIPPED BOP

MFW regulating valves CLOSED

MFW regulating bypass valve controller outputs ZERO

MFW isolation valves CLOSED

MEW flow ZERO.

MONITOR ECCS operation:

VERIFY ECCS pumps RUNNING:

BOP

CCPs

RHR pumps

SI_pumps VERIFY CCP flow through CCPIT.

CHECK RCS pressure less than 1500 psig.

BOP

VERIFY SI pump flow.

CHECK RCS pressure less than 300 psig.

__VERIFY_RHR_pump flow.

VERIFY ESF systems ALIGNED:

. Phase A ACTUATED:

o CONTAINMENT ISOLATION PHASE A TRAIN A alarm LIT BOP [M-6C, B5].

o CONTAINMENT ISOLATION PHASE A TRAIN B alarm LIT

[M-6C, B6].

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 54 of 55 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior

Containment Ventilation Isolation ACTUATED:

o CONTAINMENT VENTILATION ISOLATION TRAIN A alarm LIT [M-6C, 05].

o CONTAINMENT VENTILATION ISOLATION TRAIN B alarm LIT [M-6C, 06].

Status monitor panels:

o 6CDARK o 6DDARK o 6E LIT OUTSIDE outlined area o 6HDARK o 6J LIT.

Train A status panel 6K:

o CNTMT VENT GREEN o PHASEAGREEN

Train B status panel 6L:

o CNTMT VENT GREEN o PHASEAGREEN MONITOR containment spray NOT required:

. Phase B NOT ACTUATED BOP AND

. Containment pressure less than 2.81 psig

. Ensure Containment Spray is actuated VERIFY pocket sump pumps STOPPED: [M-15, upper left corner]

. HS-77-410, Rx Bldg Aux Floor and Equipment Drain Sump pump A BOP

HS-77-41 1, Rx Bldg Aux Floor and Equipment Drain Sump pump B.

DISPATCH personnel to perform EA-O-1, Equipment Checks Following BOP ESF Actuation.

Evaluator Note: BOP completes ES-O.5 including Appendices A & B and reports completion (including any discrepancies and actions taken, i.e.: manual Auxiliary Feedwater LCV control per ES-O.5 Step 7) to SRO.

Appendix D Required Operator Actions Form ES-D-Op Test No.: NRC Scenario # 4 Event # ES-O.5 Page 55 of 55 Event

Description:

Equipment Verifications, ES-O.5 Time Position Applicants Actions or Behavior END (ES-O5, EQUIPMENT VERIFICATIONS)

APPENDIX A SECONDARY RAD MONITORS

1. CHECK following rad monitors including available trends prior to BOP isolation:

. Condenser exhaust recorder RR-90-1 19

. SIG blowdown recorder RR-90-120

. Main steam line rad monitors

. Post-Accident Main Steam Line rad recorder RR-90-268B points 3 (blue), 4 (violet), 5 (black), and 6 (brown).

[M-31 (back of M-30)1

2. IF secondary radiation is HIGH, THEN ENSURE Unit Supervisor notified.

END OF TEXT APPENDIX B CONTAINMENT RAD MONITORS

1. CHECK following rad monitors:

BOP

. Upper containment high range rad monitors RM-90-271 and RM 90-272 NORMAL [M-30]

. Lower containment high range rad monitors RM-90-273 and RM 90-274 NORMAL [M-30]

. Containment rad recorders RR-90-1 12 and RR-90-1 06 NORMAL

[M-12] (prior to isolation).

2. IF secondary radiation is HIGH, BOP THEN ENSURE Unit Supervisor notified.

END OF TEXT

ML101230153

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