ML13297A323

301 Draft Simulator Scenarios

ML13297A323
Person / Time
Site:	Sequoyah
Issue date:	10/18/2013
From:	NRC/RGN-II
To:	Tennessee Valley Authority
References
Download: ML13297A323 (170)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: Sequoyah Scenario No.: 1 Op Test No.: 2013-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1 76%, BOL Turnover: Unit 1 is in MODE 1 76%, MOL raise power to 100%.

Target CTs: Manually trip the main turbine prior to the completion of E-0.

Isolate feedwater flow into the ruptured SG before a transition to ECA-3.1 occurs.

Event No. MaIf. No. Event Type* Event Description

1. RXO5A I-ATC/SRO The controlling pressurizer level channel LT 68-339 will fail high TS-SRO resulting in charging flow decreasing and energizing Pressurizer backup heaters. The ATC will remove the channel from service and restore Pressurizer heaters using AOP-l.04. The SRO will address Tech Specs and determines the instrument is INOPERABLE.

2. CCO1 C BOP/SRO A small leak develops on the Component Cooling Water system (CCS) with a failure of the CCS Surge Tank Makeup valve to AUTO open. The BOP manually opens the CCS Surge Tank Makeup valve.

3. THO5A C- ATC/SRO A small Steam Generator Tube Leak develops, the crew will TS-SRO respond using AOP-R.01. The ATC will raise Charging flow to maintain Pressurizer Level on program. The SRO will enter LCO 3.4.6.2.c, Action a.

4. R ATC The crew will reduce power using AOP-C.03, Rapid Power N SRO/BOP Reduction in response to the SGTL.

5. TC1ORLY1 C-SRO/BOP At approximately 70% power, Main feed Pump 1A trips. The BOP FW11A will raise B MFWP speed using AOP-S.01 MAIN FEEDWATER MALFUNCTIONS.

6. THO5A M-AII The tube leak will degrade to a SGTR, the crew will trip the reactor enter E-0.

7. TC1 1ALL C-BOP The Main Turbine will fail to trip when the Reactor Trips, the BOP TC12ALL will manually trip the Main Turbine.

8. MS12A M-All When the reactor trips, the ruptured SG Atmospheric Dump will open, the crew will transition through E-2, E-3, and eventually to ECA-3.1.

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

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 1 Page 1 of 58 Event

Description:

Controlling Pzr Lvl Transmitter Fails High (LT 68-339)

Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 1 Controlling Pzr Lvi Transmitter Fails High (LT 68-339)

Indications/Alarms Annunciator:

1-M-5

• 5A C-3, PRESSURIZER LEVEL HIGH-LOW

• 5A E-4, LS-68-339E1F PRESSURIZER LEVEL HIGH BACKUP HTRS ON Indications:

1-M-4

• 1-Ll-68-339 RCS PZR LEVEL indicates increasing level

• Pressurizer Backup Heaters ON LS-68.-335D1E PRESSURIZER LEVEL HIGH-LOW

[1] CHECK pressunzeclev& (1-U-68-339A, 335k 320

[2} IF leve is ligh, ThEN ENSURE bckuo heters ON.

[31 ENSURE IeeI cantrof system is aeniptng to return le to viTh ttdon and ctarging.

[4J IF level channel failed ThEN GO TOAOP-l.04, Preswizer Instrument Muncion.

BOP Responds to ARP 1-AR-M5A C-3.

Places HIC-62-93A, Charging Flow Control in MANUAL and lowers output to ATC control charging flow May adjust H1C-62-89A, Charging Seal Water Flow Controller to maintain seal ATC injection flow alarms clear.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Aioendix D Reciuired Oijerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# Page 2 of 58 Event

Description:

Controlling Pzr Lvl Transmitter Fails High (LT 68-339)

[ Time Position Applicants Actions or Behavior Transitions to AOP L04, PRESSURIZER INSTRUMENT AND CONTROL SRO MALFUNCTIONS DIAGNOSE the failure:

GOTO IF... SECTION PAGE Pressuhzer Level Instrument Malfunction 24 20 2.4 Pressurizer Level Instrument Malfunction CAUTION Chemistry sampling of PZR Liquid Space may result in additional bistables actuating due to impact on 1 -LT-68-320 or 2-LT-68-335.

NOTE Appendix M shows layout of PZR level control for operator reference.

1. CHECK Ll-68-339 NORMAL. PERFORM the tollowing:

a. ENSURE LEVEL CONTROL CHANNEL SELECTOR switch XS-68-339E in LT-65-335 & 320.

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

c. GO TO Step 4.

Places LEVEL CONTROL CHANNEL SELECTOR switch XS-68-339E in LT ATC 335&320 ATC 4. CHECK letdown IN SERVICE.

5. EVALUATE the following Tech Specs for app licabilitv:

SRO

• 33. 1.1 (3.3.1), Reactor Trip System lnsbijmentation

• 3.3.3.7 Accident Monitoring Instrumentation

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 1 Page 3 of 58 Event

Description:

Controlling Pzr Lvi Transmitter Fails High (LT 68-339)

Position Applicants Actions or Behavior

[__Time UMITING CONDfl1ON F2P OPERT1cN 33.1.1 As mnmurn, th reaotorthp system sn-umentatw chnres and nehocks of Thb4e 3.3-I

.e OPERABLE.

,PPLlCAEILITy As so n laole 3.34.

ACT ON As shown Table 3,3-1.

ii. PessurzeraterLeel 3 2 Hh ACTiON 8 - Wih ti-,e number of OPERABLE :harmels one less than the T:f Number of Channels, 3TARTJP ndor POWER OPERATION may proceed crorced the

• i condidons are sabsfied

a. The noperatte :hannel s placed n the lrtooed ocnc con ethn 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

3.3.3.7 The accider,t ronnitoning nat umentaon chanrses shcen in Tabe 3.3-10 shall be OPERABLE APPUCABILITY: MODES 1.2and3.

ACTON: As stown i Taae 3.3-tO

7. Pressirzer LeeI {W-3e Rsnge Insume.LoopaS-320.-33&-30Q)

ACTiON 2- NOTE: Aiso reero me ap:.oaoie accon requirements from Tables 3.3-1 once it may more restriclhe acuons.

a. Wth the number of onannels one ess than the mnirnum channels requred, rescore the inoperable cb.annel o OPERABLE stalsis within 30 days or be in at esst HOT STANDBY thin e neat 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> and i HOT SHUTDOWN within the next 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # Page 4 of 58 Event

Description:

Controlling Pzr Lvi Transmitter Fails High (LT 68-339)

Time Position Applicants Actions or Behavior SRO Enters LCO 3 3 1 1 Action 6 and LCO 3 3 3 7 Action 2

3. ENSURE pressurizer heaters restored ATC to ser cc.

CAUTION RCS pressure changes and changes in RCS boron concentration (due to differences between pzr and RCS boron> may impact core reactivity.

7. MONITOR reactor power:

a. CHECK reactor in Mode I or 2.

b. MONITOR core Thermal power for unexpected changes.

NOTE:

If performing AOP in conjunction with AOP-l.1 1 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> UNLESS affected loop is restored to operable status by resetting Eagle rack.

8. NOTIFY 1&C to remove failed pressurtzer level channel from service USING approphate Appendix:

L-68-339 Appendix I Crew Performs a Crew Brief as time allows.

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

Crew 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 Tech Specs have been addressed.

Aijøendix D Reauired Oøerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 2 Page 5 of 58 Event

Description:

CCS Leak Direct the Simulator Operator to initiate Event 2 Indications/Alarms Annunciator:

1 -M-276-B

. 27B-B D-2, UNIT 1 CCS SURGE TK LVL LO AUTO MAKEUP INITIATED Indications:

1-1 -M-27B-B

. 1-Ll-70-XXX CCS Surge Tank level decreasing UNIT I CCS SURGE TK LVL LO AUTO MAKEUP INITIATED (t CHECK curge tank evel byobser.lna I1-U-70-3A1 (23 ENSURE 1-LCV-70-63 OPEN.

(3] DISPATCH operator for local inspection to determine pmt1em.

[4] VERWY proper vowe agnrnent in accordance with 1-SO-TO-I C onent Cocing Woter Syen Train A, and a-SO-TO-I Cccnpcnen Cooling Water System Train a.

[5] MONITOR ee4 in lxth surge tanks to determine seal leakage reurn

[6] MONITOR leel rise in pocket cump fcr poasthie CCS leak inde containnent.

17] IF sufficient level cannot be maintained, THEN GO TO CP-MO3, Loss of Cent CocJing VVater for emergency makeup nstoicons [C,t]

BOP Responds to ARP 1-AR-M27BB D-2.

$Lb3r ATC Places 1-HS-70-63A CCS Surge Tank A Inlet Isolation to OPEN Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Lead Examiner may cue the next event when level in the CCS Surge Tank makeup valve has been opened.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 3 Page 6 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 3, #2 SG Tube Leakage of -15 gpm Indications available:

Annunciators:

1-M-1

• O-XA-55-12A Window B-5, 1-RA-120A1121A, STM GEN BLDN LIQ SAMP MON HI RAD

. O-XA-55-12A Window D-3, 1-RA-90-99A, CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD

. XA-55-30 C-8, RA-421A, MN STM LN HI RAD Indications available:

Dev[aIors or unexpected ndicaons cn any of the following may indicate a steam generator tube leak:

1 Charging flow rises :o maintain Pressunzer level.

2. Rise n makeup to VCT.

3. Rising 3CtNitj on:

• Condenser Vacuum Exhaust Radati:on Monitor

• S/C owdown liquid Radiation Monitor

• Main Steam Line Monitor

4. S/C saniole results indicating greater than or equal to 5 gabons ocr day (gpd) on any SiC.

I -RA-90-99A CNDS VAC PMP LO RNG AIR EXH MON HIGH RAD

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 3 Page 7 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

[1] CHECK 1-RR-90-99 rate meter and l-RR i* on panel O-M-12 for nd cations of increased radiatiorL NOTE Alarm validity may he deterrnned based on absence of instrument malfunction alarm, indicated response of the rad monitor, and, if possible, other indications such as biowdown monitor (recoqnizing the difference in response time due to blowdown transport time).

[2] IF alarm is valid. THEN NOTiFY ROL to perform i-CEM-068-1 375 Primary to Secondary Leakage via Steam Generators.

[3] IF olarm is vnlid THEN GO TO AOP-R 01. Sleam Generator Tube Leak [C2]

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

SRO Transitions to AOP R 01 Examiner note if the crew imolements section 2.2 go to page 1 1.

1. DIAGNOSE the failure:

IF... GOTO SECTION PAGE SRO High Secondary Radiation AND 2.1 4 Pressurizer level dropping OR Charging flow rising

1. MONITOR if Pressurizer level can be maintained:

a. CONTROL charging flow USING FCV-62-93 and FCV-62-89 ATC as necessary to maintain pzr level on program.

b. MONITOR pressurizer level STABLE or RISING.

Places FCV-62-93 in manual and controls charging flow, may adjust ATC HIC-62-89A to maintain RCP Seal Flow

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-30 1 Scenario # I Event # 3 Page 8 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior lx MONITOR pressurzer level STASLE b. PERFORM the following:

or RISING.

1) ENSURE letdown solated:

ATC

• FCV-52-72 CLOSED

• FCV-62-73 CLOSED

• FCV-62-74 CLOSED If pressurizer level IS still dropping, places HS-FCV-62-72, FCV-62-73 ATC

r CLOSED, and FCV6274 to CLOSE.

NOTE I Appendix F or S can be used to estimate leak rate.

NOTE 2 If letdown was isolated in Step 1, the leak rate may have exceeded the capacity of one CCP in the normal charging alignment (EAL 12.2P).

Examiner note; Appendix F starts on page 15

2. EVALUATE EPIP-1, Emergency Plan SRO Classification Matrix.

SRO Directs SM to evaluate EPIP-1

3. MONITOR VCT revel:

. MAINTAIN VCT level greater than 13%

ATC USING auto or manual makeup

. CHECK VCT makeup capabiHty adequate to maintain level.

4. MONITOR indications of leaking S/G:

a. NOTIFY Chem Lab to evaluate Primary to Secondary Leakage USING 1(2)-Sl-CEM-068-137.5:

CREW

• Method 1, Rapid Identification of Leaking Steam Generators

• Method 3, Condenser Vacuum Exhaust (CVE) Sampling for Determination of Primary-to-Secondary (P/S) Leakage.

b. NOTIFY Radiation Protection to monitor Turbine Building and site environment:

CREW

• Steam lines

• SG blowdown

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario# 1 Event# 3 Page 9 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

c. IDENTIFY leaking S/G(s)

USING any of the following:

. Unexpected rise in any S/G narrow range level OR

• SIG sample results CREW OR

• Radiation Protection survey of main steamlines and S/G blowdown lines OR

. High radiation on any main steamline radiation monitor.

CREW Identifies SGTL on S/G # 1 Examiner Note: SRO may refer to Operations Chemistry Information Sheet in turnover package.

5. EVALUATE the following Tech Specs for applicability:

SRO

. 3.432, OperatIonal Leakage

. 3.7.1.4, Secondary Coolant Activi 3.4.5.2 ReactarCootantSystem leakage shall be fimited to:

a. No PRESSURE BOUNDARY LEAKAGE,

b. 1 GPM UNIDENTIFIED LEAKAGE,

c. 150 gallons per day of pmary-to-secondarj leakage through any one steam generator, and

d. 10 GPM DENT[FlED LEAKAGE from the Reactor Coolant System.

APPLICABILITY: MODES 1, 2, 3 and 4 ACTION:

b. With any Reactor Coolant System leakage greater han any one of he above limits.

excluding PRESSURE BOUNDARY LEAKAGE or pma-to-seconda leakage, reduce the Leakage rate to within ihmits within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or he in at least HOT STANDBY wrthin the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN ithin the foLlowing 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

SRO Enters 3462 c, Operational Leakage action a NOTE Initiating shutdown required by Tech Specs requires 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> NRC notification per SPP-3.5, Regulatory Reporting Requirements.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC2O13-301 Scenario# 1 Event# 3 Page 10 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

6. INITIATE rapid shutdown by performing the foHowing:

a. ANNOUNCE SIG tube leak on PA system.

b. PERFORM rapid shutdown CREW USING AOP-C.03 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

SRO Transitions to AOP-C.03 Examiner note AOP-C.03 actions start on page 18.

CRC Continues with performance of AOP-R.O1 7 MINIMIZE Spread of contaminat on F tube lea dentrried on S/G #1 AND SIG #4 is inact THEN PERFORM the to rowing BOP

1) EVALUATE LCO3.7 12.

2) CLOSE FCV- -15 TDAFWP steam uppIy from SG # L

3) ENSURE FCV- I -1 TDAFWP steam supply from S1G #4 OPEN Manually closes FCV-1-15 TDAFWP steam supply from SIG #1 and BOP opens FCV-1 -16 TDAFWP steam supply from SIG #4

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # 3 Page 11 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

b. PERFORM EA-Q-3, MInmizing Secondary Plant Contamination.

C. IF S/G blowdown is aUgned to the river, THEN TERMINATE S/G Blowdown to river:

1) ENSURE S!G blowdown flow control BOP FCV-15-43 CLOSED.

2) DISPATCH operator to periarrn EA- 5-i. Realigning S1G Blowdawn to Cond DI.

3) WHEN EA-15-1 completed, THEN ADJUST FCV- 1 5-43 to establish desired blowdown flow.

7. d. NOTIFY Chem Lab to determine release rate for condenser vacuum exhaust USING D-SI-CEM-03Q-41 5.0 arid 0-SI-CEM-030-407.2.

e. NOTIFY Chem Lab to evaluate rerouting steam generator sample drain tines to FDCT USING Q-Tl-CEM-000-016.4.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O13-301 Scenario# 1 Event# 3 Page 12 of 58 Event

Description:

Steam Generator Tube Leak Time Position Applicants Actions or Behavior

f. WHEN notfled by Chemstiv to bypass Condensate Dl, THEN DISPATCH AUO to bypass polishers on affected unit:

• Unit 1 Only:

PLACE 1-HS-14-3, condensate Polisher Bypass Valve to OPEN.

[Cond Dl Bldg]

BOP s tJnit 2 Only:

PLACE 2-HS- 14-3, condensate Polisher Bypass Valve to OPEN,

[Cond DI Bldg]

g. EVALUATE Appendix C, Contingency Plan tsr Control and Processing of Large Volumes of Contaminated Water [C.5].

Examiner note Section 2.2 starts here.

NOTE This section provides steps to monitor primary to secondary leakage and directs unit shutdown if leakage limits are exceeded. Eny into this section is required when secondary radiation monitors ndicate a rise in primary-to-secondary leakage or when Chemistry determines S/G leak rate exceeds 5 gal. per day (gpd).

1. MONITOR charging flow and F Charging flow rising Pressurizer level STABLE. OR Pressunzer level dropping due to S/G tube leak.

THEN ATC GO TO Section 2.1

2. EVALUATE EPIP-1, Emergency Plan SRO Classification Matrix.

3 SM to evaluate EPIP-1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario# 1 Event# 3 Page 13 of 58 Event

Description:

Steam Generator Tube Leak Time Position (I Applicants Actions or Behavior

3. EVALUATE the following Tech Specs for applicability:

ATC

• 3452, Operational Leakage

• 31. L4. Secondar Coolant Activity SRO Enters 3462 c, Operational Leakage action a I!j NOTE Lower containment rad monitor count rate using concurrently with secondary rad monitors may indicate a sudden fuel defect, which could give a false indication of SIG tube leak. Threshold values for correlating RM-90-99/l 19 count rate to SIG tube leakage must be recalculated if RCS activity has changed signiftcantly

4. INITIATE sampling to confirm SJG leak:

a CHECK lower containment rad monitor CREW count rate STABLE or DROPPING.

b. PERFORM Appendix E, Chemistry Sampling Actions CAUTION: The clock starts ror power reduction or shutdown in Step S when any valid indication is available that the applicable leak rate threshold is exceeded.

Required time limits for power reduction or shutdown should NOT be exceeded due to delays in confirming leak rate.

NOTE 1: Based on monitor sensitivity, condenser vacuum exhaust rad monitor RM-90-99 01-119) is preferred indication For leak rate monitoring, Other secondary rad monitors (if available) and/or SJG sampling should be used for confirmation.

Confirmation time should be kept to a minimum.

NOTE 2: Rad Monitor values (cpm) must be converted to a gallons per day (gpd) equivalency to determine leakrate Correlation of RM-90-99f :1 19 responses to Primary -

Secondary leak rates and limits are provided by Chemistry in turnover package.

NOTE 3: Steady State conditons tless than 10% power change per hour) are required to accurately correlate cpm readings with gpd leaEkage

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # 3 Page 14 of 58 Event

Description:

Steam Generator Tube Leak Time Position 0 Applicants Actions or Behavior

5. MONITOR pimai-to-secondary leak rate:

a. PERFORM Appendix A, Radiation Monitor Trending Data every 15 mm.

USING available rad monitors.

b. VERIFY rise in count rate validated by at least one of the following:

SRO

• sample results confirming rise in SIC activ[ty OR

. two independent secondary rad monitors showing rise in count rate.

C. REFER TO Appendix B, Summary of Action Levels for SJG Tube Leak.

NOTE 1 When monitoring leakage using radiation monitors, pfimaly to secondary leakage should be monitored over several minutes to ensure that rtse in leakage is not a temporary spike.

NOTE 2 Leakage action levels appiy to leak rate from a single S/C. If unable to determine leakage from individual S/Cs. total leakage should be assumed to be coming from one S/C.

6. MONITOR shutdown requirements:

BOP a. CHECK condenser vacuum exhaust rad monitor RM-90-99 or RM-90-1 19 OPERABLE, NOTE If leak rate exceeds 75 gal per day (Action Level 3) based upon condenser vacuum exhaust rad monitor and NO S1G biowdown rad monitor is available to validate leak, required actions 10 shut down shall be initiated based upon the one available rad monitor.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC2O13-301 Scenario# 1 Event# 3 Page 15 of 58 Event

Description:

Steam Generator Tube Leak Time Position jI Applicants Actions or Behavior

6. b. CHECK Primary to Secondary leak b. IF leak rate in affected SJG(s) rate in affected SIG(s) greater than or equal to 75 gal per less than 75 gal per y. THEN PERFORM the following:

I) ENSURE power less than 50%

BOP within 1 hr and unit n Mode 3 within next 2 hrs (total of 3 hrs).

2) GO TO Sechon 2. 1 to shut down.

Examiner Note: crew should realize leak is sufficient and transitions to section 2.1, page 7 Step 6 RNO

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # 3 Page 16 of 58 Event

Description:

Steam Generator Tube Leak AOP.R.O1 SQN STEAM GENERATOR TUBE LEAK Rev. 26 Page 1 of I APPENDiX F ESTIMATING RCS LEAK RATE USING CVCS FLOW BALANCE NOTE 1 This method is recommended when leak requires rise in charging flow greater than 10 gpm Appendix G is more accurate for smaller leak rates.

NOTE 2 This appendix assumes RCS temperature and charging flow are approximately constant.

INITIAL FINAL Cl-lANGE PZR Levet

[1]

(iegaive fcr eve decrease)

Time Charging Flow [3]

Letdown Flow [4]

Total RCP Seal Return Flow [5]

Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Level Rate of Change change factor posdive for ee rising)

% X G2gal/% mm = gprn step [11 above step [2] above [6]

Leak Rate Calculation Charging Flow Letdown Flow Seal Return Pzr Level instrument error RCS Leak Flow Rate of Change correction factor Rate

+ 3gpm = gprn step 13] above step 4j above step [5] above step [fiJ above Page 64 of 68

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 1 Event# 3 Page 17 of 58 Event

Description:

Steam Generator Tube Leak SON STEAM GENERATOR TUBE LEAK A0P-01 Rev. 26 Page 1 oF 1 APPENDIX G ESTIMATING RCS LEAK RATE USING VCT AND PZR LEVEL CAUTiON This appendix CANNOT be used during VCT makeup, boration. or dilution.

NOTE This appendix assumes RCS temperature is approximately constant VCT LEVEL (% PZR LEVEL (%) TIME (mirØ INITIAL FINAL CHANGE [1] [21 [3]

(osibve for tevel decrease) (positive for level decrease)

VCT Level Conversion VCT evel change conversion Time Change VCT Level factor Rate of Change pcibve for level lowering)

% x 2OgalI% . mi:n = gpm step [1] above step [3] above [4]

Pressurizer Level Conversion Pressurizer level conversion Time Change Pzr Level change factor Rate of Change

)positive for (evel lowering)

% X 62gaI/% ÷ mm = gpm step [2] above step [3] above [5]

Leak Rate Calculation YCT Level Pzr Level RCS Leak Rate Rate of Change Rate of Change

+ apm step [4] above step [5] above Page 65 of 68

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event# 4 Page 18 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior No action required for Event 4, Rapid Power reduction Directs performance of AOP-C.03 RAPID SHUTDOWN OR L OAU - -

SRO REDUCTION.

1 ENSURE crew has been briefed on reactivty SRO management expectations USING Appendix A.

APPENDIX A REACTIVITY MANAGEMENT BRIEFING NOTE This appendix should be used in addttion to event-based briet

[1] ENSURE crew has been briefed on the following:

• Reason for Rapid Shutdown or Load Reduction

• Load Reduction Rate:________

• Desired tlnai power level:______

• Reactivity Management expectations:

• Unit Supeiisor shall concur with all reactivity manipulations

• Ensure reactor responding as expected using diverse indications

• Tavg-Tret Mismatch requirements:

• 3Fcontrolhand

• 5F reactor trip criteria

• Crew focus will be on reducing power in a controlled and conseivotive manner.

• OATC will monitor rod insertion limits and AFD limit

• Boration source:

• Crew will monitor reactor trip and turbine trip criteria using App B

• CR0 will stop secondaiv plant equipment using App. C.

a Termination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 4 Page 19 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior 2.

rate of i%fH,:l power 1ev MONITOR reactorturbine trip NOT required aM USING Appendix B, Reactor and Tuti inc CREW Trip Cnte,ia. ctwo extra copies provided for UOs)

3. CHECK VALVE POSITION LIMIT light CREW DARK on EHC panel. [M-2]

Examiner note: Appendix B reactor and turbine trip criteria see page 26 NOTE: Step $ should be handed off to opposite unit or extra operator (if available).

If NO operator is available, notifications should be performed concurrently with subsequent steps (when time perrnits

4. ENSURE following personnel notified of rapid shutdown or load reduction: [C1j

. Balancing Authority (Load Coordinator)

(751-7547).

CREW

. Chemistry a Radiation Protection

. Plant Management CREW Makes notifications as required.

NOTE: Boration volumes and tlowrates listed in this procedure are recommendations and may be adlusted as necessarj.

5. lNATE boration:

a. CHECK rod control AVAILABLE:

ATC

• Control Bank D rods capable of being moved

• NO dropped or misaligned rods in Controf Bank D.

Appendix 0 Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event# 4 Page 20 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

5. b CHECK Control Bank 0 group position greater than 200 steps ATC

c. CHECK boration capabHity from BAT AVAI LABLE.

d. DETERMINE recommended boration volume from BAT:

• 800 gal to reduce power from iOO% to 20%

OR SRO

• 10 gal for each 1% power reduction from current power level)

OR

• volume recommended by Reactor Engineering.

SRO Determines 5500 gal as required to reduce power from 76% to <20%

5. e. DETERMINE recommended baration flowrate from table below or fro:m Reactor Engineering:

LOAD REDUCTION BORATION SRO RATE(%imin) FLOWRATE 1% 15 gpm 2% --30 gpm

3% 45 pm SRO Chooses a 1 % load reduction rate (1% to 3% acceptable)

1. ENSURE concurrence obtained from

• ATC STA for boration volume and tlowrate.

g. CHECK status of charging and letdown:

. normal letdown flaw ATC ESTABLISHED

. charging flow control HIC-G2-93 A in AuTO.

Appendix 0 Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # Event# 4 Page 21 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

h. DETERMINE if normal boration will be used:

ATC

• desired load reduction rate is less than 4% per minute

• time is available for normal boration L INITiATE normal boration ATC USING Appendix R Examiner note: Appendix H Actions are listed in the following steps.

APPENDIX H NORMAL BORATION

[1] RECORD desired boration volume and flowrate: E ATC Volume (gal)

Flowrate lgpm)

ATC Records 25O gal as required at 15 to 45 gpm ATC [2] PLACE [HS-62-140A1 Makeup Control to STOP position.

ATC Places HS-62140A to STOP.

[3] PLACE [HS-62-1406] Makeup mode selector switch ATC in BORATE position.

ATC Places HS-62-1 408 to BORATE NOTE Boric Acid controller setting is twice the desired flow rate.

Maximum Boric Acid flow is 45 gpim

[4] ADJ UST [FC-62-I 39] BA flow controller setpont ATC for desired flow rate ATC Places FIC-62-1 39 to 15 to 45 gpni.

t5] ADJUST 1fQ62-1391 BA integrator ibatch Co nter)

ATC to desired bonc acid volume E ATC Places FQ62-1 39 to 550 gal

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # Event # 4 Page 22 of 58 Event

Description:

Rapid Power Reduction Time fl Position I Applicants Actions or Behavior 6] PLACE 1HS-62-14OA Makeup Control Switch mode ATC selector switch to START U ATC Places HS-62-1 40A to START

[7] ENSURE boric acid transfer pump aligned to blender ATC in FAST speed.

[8] IF desired boric acid flow rate NOT obtained.

THEN ADJUST one or both of the following as necessary:

ATC

• FFC-62-1 391 BA flow controller LI

. recirculation valve for BAT aligned to blender, LI ATC Adjusts FIC-62-139 as required.

ATC [9] ENSURE desired boric acid flow indicated on Fl-62-139. U

[10] RECORD time when boration flow established: U ATC Time:

ATC Records time boration initiated.

[11] WHEN required boric acid volume has been added AND control rods are above low-low insertion limit.

THEN ATC PERFORM the following:

[a] PLACE rHS-62-140A1, Makeup Control to STOP position. U ATC Places HS-62-i 40A to STOP.

[bJ ENSURE [FC-62-1421. Primary Water to Blender Flow ATC Controller in AUTO with dial indicator set at 35%. U

[C] ADJUST IFC-62-1 391. Boric Acid Flow Controller to A TC desired blend solution USING Tl-44 Boron Tables. LI ATC Places FIC-62-1 39 to 27.

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario# 1 Event# 4 Page 23 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

[d] PLACE IHS-62-140B1, Makeup Mode Selector ATC Switch in AUTO position. El ATC Places HS62-1 40B to AUTO ATC [e] PLACE rHs-62-140A1, Makeup Control to START. El ATC Places HS-62-1 40A to START.

ATC [t] ENSURE boric acid transfer pumps running in SLOW speed. LI Places HS-62-230A BA Transfer Pump 1 A to STOP ATC Places HS-62-230A BA Transfer Pump 1 A to START.

Places HS-62-232A to BA Transfer Pump 1 B to STOP ATC Places HS62-232A to BA Transfer Pump 1 B to START.

J. CONTROL boration flow as required to inject desired bonc acd volume CAUTION: If borating from the RWST. Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

13. INITTATE load reduction as follows:

a. ADJUST load rate to desired value:

• between 1% and 4% per minute 1 boratirig via FCV-62-138 BOP OR a between 1% and 3% per minute if borating via nomal boration (App. H)

OR a 2% per minute if boroting from RWST.

BOP Adjusts load rate approx 1% to 3% per minute

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 4 Page 24 of 58 Event

Description:

Rapid Power Reduction Time Position Applicants Actions or Behavior

b. ADJUST setter for desired power level:

BOP If RX POWER DESIRED LEVEL RECOMMENDED SETTER VALUE 20% or less 15 SOP Adjusts setter to approx. 15

6. C. VERIFY boratton flow establIshed.

BOP d INITIATE turbine load reducton by depressing GO pushbutton.

GOP Depresses GO pushbutton

e. CONTROL turbine load reduction BOP as necessary to reduce power to_desired_level.

7. MONITOR T-avqiT-ref mismatch:

a. CHECK T-ref indication a. PERFORM the ronowing:

AVAILABLE.

1) MONITOR Program T-avg for current reactor power USING Tl-28 Figure 3 or ICS (NSSS I BOP, Program Reactor Average Temperature).

2) USE program T-avg in place of T-ref.

3) MAINTAIN T-avg wthin 3F ot program T-avg USING manual rod ATC control.

4) ADJUST turbine load rate as necessary.

5) IF mismatch between T-avg and program value CANNOT be maintained less than 5SF.

THEN TRIP the reactor and GO TO E-O, Reactor Top or Safety injection.

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event# 4 Page 25 of 58 Event

Description:

Rapid Power Reduction Time Applicants Actions or Behavior

[__Position

7. h. MONITOR automatic rod control b. IF auto rod control is functional maintaining T-avgfT-ref mismatch AND situation allows slowing down less than 3F load reduction, THEN PERFORM the toiiowing I) REDUCE turbine load rate to atow auto rod control to restore T-avg/T-ref mismatch.

2 WHEN T REF T AUCT HIGH LOW alarm tM-5A. C-6) is clear, THEN RESTORE turbine load rate to desired value.

IF any ot the following conditions met

. auto rod control NOT functional OR

• turbine load rate adjustment is NOT effective in reducing mismatch OR

• situation does NOT allow slowing down load reduction.

THEN RESTORE 7-avg to within TF of T-ref USING manual rod control as necessory IF T-avqiT-ref rnsmatch CANNOT be maintained less than 5F, THEN TRIP the reactor and GO TO E-O, Reactor Trip or Safety Thjectio,r I 3°F Coordinates with the BOP to maintain T-avg/Pro-ef mismatch less than using the Tl-28 figure 3 or ICS

8. MONiTOR automatic control of BOP MFW pump speed AVAILABLE

9. STOP secondary plant equipment BOP USING Appendix C, Secondary Plant Equ4oment.

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 27.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Examiner Note: When the crew has sufficiently reduced power the Lead Examiner may go to the next event starting at page 36.

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 26 of 58 Event

Description:

Rapid Power Reduction APPENDIX B REACTOR AND TURBINE TRIP CRITERIA REACTOR TRIP CRITERIA TURBINE TRIP CRITERIA Turbine trip required or imminent Turbine vibration exceeding 14 mils with reactor power greater than P-9 (50%) with one of the following:

Uncontrolled rod movement which CANNOT be

• high vibration on multiple bearings stopped by placing rods in MANUAL AOP-C.O1) OR Loss of SIG level control:

• abnormal nolseivibration apparent level dropping or rising toward trip setpoint and level CANNOT be restored 1AOP-SOU More than one dropped rod OP-c.Q1)

T-avgiT-ref mismatch CANNOT be maintained less than SCF (refer to Step 7 or App El 30% turbine load: < 30% turbine load:

Condenser Pressure > 2.7 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 n.iinutes iAcP-o.D2 Any automatic reactor trip setpolnt reached Any automatic turbine trip setpoint reached OR automatic trip imminent: OR automatic trip imminent

• Turbuie trip above P-9 (50%)

• High Stator Cooling Water temp 90CC

. Safety injection OR Stator D/P 12 psig betow normal a Power Range high flux 109%

• Both MFPTs tripped

• Power Range flux rate 5% in 2 seconds

• Low Auto Stop Oil pressure 45 psig

• Pressurizer high level 92%

• High SIG level 81% narrow range a Pressurizer pressure low 1970 psig

• Main Turb Bearing Oil low pressure 7 psig a Pressurizer pressure high 2385 psig

• Thrust Bearing Oil high pressure 60 psig a RCS low flow 90%

• Turbine Overspeed 1980 rpm a RCP undervoltage 5.022 kilovolts

• Loss of EHC pressure

• RCP undertrequency 56.0 Hz

• Uiiit 1 Only

• OTT 115% (variable) Generator PCBs trippecL a OPT 105.7% (variable)

• Un!t 2 Only:

a sir I w Ic I 0 7..0r5o. EAMJ Generator Circuit Breaker (GCB trinped a SSPS general warmng in both trains

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 27 of 58 Event

Description:

Rapid Power Reduction APPENDIX C SECONDARY PLANT EQUIPMENT

[1] ENSURE plant announcement(s) made on the following:

• starting rapid shutdown (or load reduction) due to (reason)

• stopping secondar plant equipment NOTE I if reactor power will be reduced below 50%, AUO should be on station at #3 heater drain tank (if possible) when 60% power is reached.

NOTE 2 Dispatching of AUO in Steps [2] and [3] may be performed out of sequence.

[2] IF reactor power will be reduced below 50%,

THEN DISPATCH AUO with Appendix J (Unit 1) or K (Unit 2) to #3 Heater Drain Tank.

[3] IF one MFP will be shutdown using this appendix THEN DISPATCH AUO to OPEN MFWP recirc manual Isolation valve for MFWP to be removed from service: (N/A valves NOT opened)

UNiT MFWP VALVE LOCATION OPEN 1A 1 -VLV-3-576 TB el. 706, Northeast corner of 1 A condenser lB l-VLV-3-577 TB eL 706. Northeast corner of IA condenser fl 2 2A 2-VLV-3--576 TB eL 706, Southeast corner of 2A condenser 25 2-VLV-3-577 TB eL 706. Southeast corner of 24 condenser

Appendix 0 Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 28 of 58 Event Descnption: Rapid Power Reduction APPENDIX C

[4J IF BOTH of the following conditions are met:

power is being reduced as directed by AOP-S.01 (Main Feedwater Ma[functions) or AOP-S04 (Condensate or Heater Drain Malfunctions) leaving secondary pumps in service is desired THEN GO TO Step [8]

[51 WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cond Demin Booster Pump STOPPED

[b] ENSURE associated suction valve CLOSED:

SUCTION VALVE CLOSEDI BOOSTERPUMP A FCV-2-290 OR FCV-2-285 Lz J

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 29 of 58 Event

Description:

Rapid Power Reduction

[61 WHEN turbine impulse pressure is approximately 7O-75%

THEN PERFORM the following:

[a] ENSURE one Condensate Booster Pump STOPPED.

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER PUMP SUCTION VALVE CLOSED q A FCV-2-94 OR FCV2-87 OR L FCV-2-81 E

[c] PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

• 1-80-213-i Section L2 E OR

• 2-80-213-1 Section 71

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 30 of 58 Event

Description:

Rapid Power Reduction

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[Q] STOP remaining two Cond Demin Booster Pumps simultaneously.

[b] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER PUMP SUCTION VALVE CLOSED 1 A FGV-2-290 B FCV-2-2B5 C FCV-2-280

[c] STOP one No 3 Heater Drain pump El

[dj STOP one No. 7 Heater Drain pump El

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 4 Page 31 of 58 Event

Description:

Rapid Power Reduction

[8] IF reactor power will be maintained greater than 50%.

THEN GO TO Notes prior to Step [1 1]

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-105A and B using Appendix J or K.

[9] WHEN reactor power is less than 60%

AND AUO with App J (UnI) or K (Unit 2) is on station at #3 Heater Drain Tank, THEN PERFORM the fol[owing:

[a] STOP #3 Heater Drain Tank Pumps.

[b] NOTIFY AUO to perorrn App. J (Unit 1) or App. K (Unit 2),

Fully Opening #3 Heater Drain Tank Bypass Valves E

[ci CLOSE isolation valves from #3 Htr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FCV 108 Htr Drain Tk Pump 3 to Htr String A E FCV-6-109 Htr Drain Tk Pump 3 to Htr String B FCV-6-1 10 Htr Drain Tk Pump 3 to Htr String C

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 32 of 58 Event

Description:

Rapid Power Reduction NOTE I The following step ensures that MFW Bypass valves are available to control feedwater flow at low power.

NOTE 2 If any MFW Reg valve is in MANUAL, the associated MFW Bypass valve controller should remain in MANUAL to prevent undesired opening of bypass valve.

[10] WHEN Reactor power is less than 50%,

THEN PERFORM the following:

[a] IF all MEW Reg Valves are in AUTO, THEN PLACE MEW Bypass Reg Valve controllers in AUTO.

[b] IF any MEW Reg Valve is in MAN UAL THEN PERFORM the following:

1) MAINTAIN MFW Bypass Reg Valve in MANUAL for SIG with MEW Reg valve in MANUAL.

2) PLACE MEW Bypass Reg Valves l:fl AUTO for remaining SiGs

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 33 of 58 Event

Description:

Rapid Power Reduction NOTE I If performing this AOP to reduce power to allow shutting down one MEW pump, the affected MFWP may be removed from service at power level less than 56% (Unit 1) or 65% (Unit 2)

NOTE 2 AFW start function on loss of both MEW pumps is inoperable when a MEW pump is RESET but NOT pumping foivard LCO 332 1 (Unit 1) or 332 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when shutting down a MFWP.

[II] WHEN it is desired to remove one MEW pump from service AND power level is less than applicable limit:

• turbine impulse pressure less than approximately 45%

OR

• reactor power less than value specified in Note 1 THEN PERFORM the following:

[a] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (NIA valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN J tA i-VLV-3-576 TB ci. 706, Northeast corner of IA condenser tB i-VLV-3-577 TB ci 706, Northeast corner of IA condenser

, 2A 2-VLV-3--576 TB ci 706. Southeast corner of 2A condenser 2B 2-VLV-3-577 TB ci 706, Southeast corner of 2A condenser []

[b] THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MFWP to he removed from service

[cJ PLACE speed controller in MANUAL for MFWP to be removed from service

[d] REDUCE speed gradually on MFWP to be removed from service.

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 4 Page 34 of 58 Event

Description:

Rapid Power Reduction

[11] (Continued)

[e] ENSURE proper Loading on remaining MFWF E

[f IF MFWP CANNOT be fully unloaded with speed controller, THEN PERFORM one of the following:

• NOTIFY l&C to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded. El OR

• THROTTLE OPEN recirc valve for affected MFWP to assist in unloading MFWP OR

• SLOWLY CLOSE governor valve by bumping closed governor valve positianer (if operable)

OR

• OBTAIN SRO concurrence that MEWP flow is sufficiently low to allow tripping MFWR El

[g] WHEN MFWP is unloaded sufficientLy, THEN TRIP affected MFWP.

[h] CLOSE recirc valve for MFWP removed from service. El

[I] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from service. El U] OPEN drain valves for MFWP removed from seriice: [M-:3]

• [HS-46-1 4], MFWP A drain valves El OR

• [HS-4-41]. MFWP B drain valves.

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 35 of 58 Event

Description:

Rapid Power Reduction

[12) WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

[a] STOP remaining No, 7 Heater Drain pump.

[b] CLOSE isolation va[ies from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FCV-6-143 Htr Drain Tk Pump 7 to Htr String A FCV-6-163 Htr Drain Tk Pump 7 to Htr String B FCV-6-i 84 Htr Drain Tk Pump 7 to Htr String C

[13] WHEN turbine impulse pressure is approximately 30% or less.

THEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUT. n

-J

[b] IF #3 heater drain tank pumps are still running, THEN PERFORM Step t93 LI

[c] STOP one of two remaining Condensate Booster Pumps.

(steD continued on next aae)

Appendix D Scenario Outline Attachment 1 Op Test No.: 201 3-301 Scenario # 1 Event # 4 Page 36 of 58 D Event

Description:

Rapid Power Reduction

[13] (Continued)

[d] ENSURE associated CBP suction valve CLOSED:

OR FCV-2-87 OR 1 FCV-2-81

[e] STOP one of three Hotwell Pumps.

[f PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessar)

• i-S0-213-1 Section 7.2 OR

• 2-S0-213-i Section 7,3

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 5 Page 37 of 58 Event

Description:

1A MEW Pump Trip Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 5, 1A MFW Pump Trip Indications/Alarms Annunciator:

i-M-5

• 3C A-i, FS-3-70B MFP iA DISCH FLOW LOW

. 3B A-i, MAIN FEEDWATER PUMP TURBINE 1A ABNORMAL

. 3B A-2, TRIPPED Indications:

i-M-5

• Green Light on MFPT A Reset/Trip Switch HS-46-9A (M-3)

TRIPPED

[1] IF both MFPa tripped ith reactor poer greater than FW Tcw capaity (3%). ThEN ENSURE reactor tnpped. AND GO TO E-Q, 9eacter Thp cr ScfeSy ctcn.

[2] IF both MFPs tripped itti reactor newer Ies than AFW low capaIity (-3%) ThEN ENSURE FW pjmps ninning, 13] IF one MFWP has tripped, ThEN GO TO AOP-S.0t, Loss of Normal Fedwater Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

IF GOTO PAGE SECTION Main Feedwater Pump Trip 2.4 20 Below 76% (Unit I or 77% (Unit 2) Turbine Load BOP Responds to ARP 1-AR-M3B A-2.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5 Page 38 of 58 Event

Description:

1A MEW Pump Trip Time Position Applicants Actions or Behavior SRO Directs actions of AOP-S 01, Section 2 4

1. MONITOR at least one MFW pump BOP RUNNING.

2. ENSURE running MFW pump loads BOP as required.

3. CHECK teedwater ifow BOP greater than steam flow.

4. MONITOR steam generator levels PERFORM the following:

returning to program level.

a. IF manual control of MFWP speed or MFW Reg valve position is needed, THEN BOP PERFORM the following as necessary:

. ADJUST running MFWP speed OR

. ADJUST MEW Reg valve position.

BOP Places speed controller SIC 46-20B to MANUAL and raises output Crew Performs a Crew Brief as time allows.

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

Crew 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 plant is stable with MFP speed control in manual.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 6,7,8 Page 39 of 58 Event

Description:

1. 1 S/G SGTR/#1 S/G ADV Fail Open Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 6 Indications available:

• RCS pressure lowering rapidly

. Numerous radiation monitor alarms

. RCS pressure lowering.

. #1 SG Level increasing

. Satety Injection SRO Transitions to E-O. Reactor Trip or Safety Injection Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/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)

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via ICS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

CREW Performs the first four steps of E-O unprompted.

ATC Manually trips the Reactor ATC Manually initiates Safety Injection.

SRO Directs performance of E-O, Reactor Trip Or Safety Injection.

NOTE 1 Steps I through 4 are mmediate action steps.

NOTE 2 This procedure has a foldout page 1 VERIFY reactor TRIPPED:

• Reactor tIip breakers OPEN

• Reactor trip bypass breakers DISCONNECTED or OPEN ATC Rod bottom lights LIT

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

• Neutron flux DROPPING

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 6.7.8 Page 40 of 58 Event

Description:

1. 1 SIG SGTR/#1 S/G ADV Fail Open Time Position Q Applicants Actions or Behavior

2. VERIFY turbine TRIPPED:

BOP Turbine stop valves CLOSED.

cRmCAL BOP Places HS-47-24 to Trip

3. VERIFY at least one 69KV shutdown BOP board ENERGIZED on this unit

4. DETERMINE if SI actuated:

ATC ECCS pumps RUNNING

• Any SI alarm UT EM-4D1, 5 PERFORM ES-0.5, Equipment BOP Verifications WHILE continuing n this procedUre.

Continue with the performance of E-O REACTOR TRIP OR SAFETY SROIATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 51 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 6,7,8 Page 41 of 58 Event

Description:

1. 1 SIG SGTR/#1 SIG ADV Fail Open FOLDOUT PAGE RCP TRIP CRITERIA IF any of ihe following conditions occurs:

• FOS pressure less than 1250 psig AND at least one COP or SI pump running OR

• Phase B isolation, THEN STOP all ROPs EVENT DIAGNOSTiCS

• IF any S1G pressure is dropping uncontrolled, THEN PERFORM the followmg:

a CLOSE MSIVs and MSIV bypass valves.

b. IF any 810 pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated

2) IF at least one SI0 is intact (SIG pressure controlled or rising),

THEN ISOLATE AF.V to fautted Si(5(s)

• CLOSE AFW level control valves for faulted SIG(S)

• IF any AFW valve for faulted SIC CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted SIC.

3) ENSURE at least one of the following conditions met:

• total AFW flow greater than 440 gpm OR o Narrow Range level greater than 10% [25% ADVJ in at least one thtact 8/G.

• IF both trains of shutdown boards dc-energized, THEN GO TO EOA-0.0. Loss of All AC Power TANK SWITCHOVER SETPOINTS

• IF CST level less than 5%, ThEN ALIGN AFW suction to ERCW.

• IF RWST level less than 27%. THEN GO TO ES-13, Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-30 1 Scenario # 1 Event # 6,7,8 Page 42 of 58 Event

Description:

1. 1 5/0 SGTR/#1 SIG ADV Fail Open Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AF\N flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow ATC greater than 10% [25% ADVI greater than 440 gpm in at least one SJG. UNTIL narrow range level greater than 10% [25% ADVI in at least one S/G.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADVJ and 50%

in intact or ruptured S1Gs.

Manually controls AFW flow to maintain total AFW flow greater than 440 gpm ATC/BOP until SIG are greater than 10% NR. .:

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 OR

. Any S/G pressure dropping ATC UNCONTROLLED OR

. Phase B actuation.

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

C. ENSURE applicable Foldout Page actions COMPLETED.

Examiner Note: The crew may take action using the Foldout Page (FOP) to isolate the #1 Steam Generator now.

CrWcal ATC/BOP Places HS-1 -4A, 1-11 A, 1 -22A and 1 -29A to CLOSE.

Critical ATC/BOP Places HS-3 1 64A to RAMP CLOSE until valve indicates closed Critical ATC/BOP Places HS-3 1 74A to CLOSE and PTL

Aojjendix D Reguired Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 6,7,8 Page 43 of 58 Event

Description:

1. 1 SIG SGTR/#1 SIG ADV Fail Open

[ Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1250 psig ATC AND

. At least one COP OR SI pump RUNNING.

b. STOP RCPs.

9. MONITOR RCS temperatures: IF temperature less than 547F and dropping, IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547F and 552F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues.

IF RCPs stopped, THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending ATBOP 1) ENSURE total AFW flow

- to between 547cF and 552T.

less than or equal to 600 gpm.

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% ADJ]

in at least one SJG.

c. IF cooldown continues after AFW flow is controlled.

THEN CLOSE MSIVs and MSIV bypass valves.

Ajendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 6. 7. 8 Page 44 of 58 Event

Description:

1. 1 S/G SGTR/#1 S/G ADV Fail Open Time Position Applicants Actions or Behavior Manually controls AFW flow to maintain total AFW flow greater than 440 gpm ATC/BOP and less than 600 gpm until S/G are greater than 10% NR

10. CHECK pressurizer PORVs, safeties.

and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve A\JAILABLE.

e. At least one block valve OPEN.

11. DETERMINE if S/G secondary pressure boundaries are INTACT:

CHECK all S!G pressures ATC CONTROLLED or RISING.

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

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

SRO Transitions to E-2 FAULTED STEAM GENERATOR ISOLATION CAUTION Unisolating a faulted SIG or secondary break shouid NOT be considered UNLESS needed: for RCS cooldown.

SRO Directs actions from E-2 FAULTED STEAM GENERATOR ISOLATION

1. CHECK MSiVs and MSIV bypass iaives CLOSED.

Critical ATC/BOP Places HS-1 -4A, 1-11 A, 1 -22A and 1-29A to CLOSE (If not already performed)

2. CHECK ANY SJG secondary pressure boundary INTACT:

• Any 510 pressure CONTROLLED or RISING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 6,7,8 Page 45 of 58 Event

Description:

1. 1 SIG SGTR/#1 SIG ADV Fail Open Time Position Applicants Actions or Behavior

3. iDENTIFY Faulted S!G(s):

a CHECK S/G pressures:

. Any SIC pressure DROPPING in an uncontrolled manner CR

• Any S/C pressure less than 140 psig.

CREW Identifies #1 S/G is faulted.

CAUTiONS

• Secondary heat sink requires at least one SIG available.

a If the TD AFW pump is the only source of feed flow, isolating both steam supplies will result in Loss of secondary heat sink.

4. ISOLATE Faulted SJGts):

a ENSURE MEW isolated to faulted S/C(s) by any of the following:

. feedwater isolation valve CLOSED [M-4j OR

• feedwater regulating valve and bypass valve CLOSED [M-3]

b. ENSURE AEW soIated to faulted S/C(s):

• CLOSE MD AEW LCV

• CLOSE TU AFW LCV and PLACE in PULL TO LOCK.

Critical Places HS-3 1 64A to RAMP CLOSE until valve indicates closed. (If not already ATC/BOP Task performed.)

Critical ATC/BOP Places HS-3 1 74A to CLOSE and PTL. (If not already performed.)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 6.7,8 Page 46 of 58 Event

Description:

1. 1 SIG SGTR/#1 SIG ADV Fail Open

[ Time Position Applicants Actions or Behavior

d. CLOSE TD AFW pump steam supply tram fau[ted SJG FCV-l-15(S/G #1) or FC\/-l-l6 (810 #4)

Places HS-1-15A TDAFWP steam supply from SIG #1 to CLOSE and HS-1-16A ATC/BOP TDAFWP steam supply from SIG #4 to OPEN (If not already performed)

e. VERIFY SIG blowdown valves C LOSED t VERIFY atmospheric relief CLOSED. f CLOSE atmospheric relief.

IF Faulted S/G(s) atmospheric reliel CANNOT be closed, THEN DISPATCH personnel to close atmospheric relief USING EA- 1-2, L Control of 81(3 PORVs.

5 CHECK CST level greater than 5%,

6. VERIFY secondary rad ation NORMAL: IF secondary radiation is high, THEN CHECK secondary radiation NORMAL GO TO E-3. Steam Generator Tube a

Rupture.

USING Appendix A, Secondatv Rad

£ onitors (App A also contained in ES-O 5)

SRO determines SIG #1 is ruptured and transitions to E-3, Steam Generator Tube 4iJJ SRO Rupture.

SRO Direct performance of E-3, Steam Generator Tube Rupture NOTE This procedure has a foldout page SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 FOLDOUT PAGE SI REINIT1ATION CRITERIA IF SI has been terminated AND etIier 01 the following conditions occurs:

• RCS subcoollng based on core exit TICS less than 40SF CR

• Pressurizer level CANNOT be maintained greater than 10% [20% ADV}.

THEN a ESTABLISH ECCS flow by performing one or boiM of the following:

• ESTABLISH CCPIT flow as necessary USING Appendix C

• START CCPs or SI pumps manually as necessary.

b. GO TO ECA-:31, SGTR and LOCA Subcooled Recovery.

EVENT DIAGNOSTICS

• IF both trains of shutdown boards deenergized, THEN GO TO ECA-DO, Loss of All AC Power

• IF any S/G pressure dropping in an uncontiolled manner or less than 140 psig AND S1G NOT isolated AND SIG NOT needed far RCS coc[down.

THEN GO TO E-2, Faulted Steam Generator Isolation.

• IF any Intact SIG has level rising in an uncontrolled manner OR has abnormal radiation.

THEN STOP any deliberate RCS cooldown or depressurization and GO TO E-3 Step 1 TANK SWITCHOVER SETPOINTS

• IF CST level less than 5%,

THEN ALIGN AEW suction to ERCW

• IF RWST level less than 27%,

THEN GO TO ES- 3, Transfer to RHR Containment Sump.

Aooendix D Reciuired Oijerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 6,7,8 Page 48 of 58 Event

Description:

1. 1 S/G SGTR/#1 SIG ADV Fail Open Time Position Applicants Actions or Behavior ATC 1 MONITOR at least one RCP RUNNING.

2. MONITOR RCP trip criteria:

a. CHECK the following: a. GO TO Step 3

• RCS pressure less than 1250 psig ATC AND

• At least one CCP OR SI pump RUNN ING.

b. STOP RCPs.

3. MONITOR indications of Ruptured SIG(s):

a IDENTIFY Ruptured S/G(s) as indicated by any of the following:

a Unexpected rise in any S1G narrow range level.

OR

• High radiation from any SJG Crew sample.

OR

• RADCON survey of man steam lnes and S/G blowdown lines OR

• High radiation on any main stearniine radiation monitor CREI iDetermines SG 1 IS RUPTURED CAUTION If the TD AFW pump is the only source of feed flow, isolating both steam supplies will result in loss of secondary heat sink.

Aooendix D Reauired ODerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 6,7,8 Page 49 of 58 Event

Description:

1. 1 SIG SGTR/#1 SIG ADV Fail Open Time Position Applicants Actions or Behavior

4. ISOLATE flow from Ruptured SIG(s):

ATC/BOP a ADJUST Ruptured SJG(s) atmospheric relief controller setpoint to 7% in AUTO. (1040 psig)

ATC/BOP Places PlC-i -6A setpoint to 87%

b. CHECK Ruptured SIG(s) b. WHEN Ruptured S/Gts) pressure atmospheric relief hand switch in less than 1040 psig.

P-AUTO and valve(s CLOSED. THEN PERFORM the following:

1) VERIFY atmospheric relief CLOSED.

2) IF atmospheric relief NOT closed, ATC/BOP THEN CLOSE atmospheric relief.

IF Ruptured S/C(s) atmospheric relief CANNOT be closed.

THEN DISPATCH personnel to close atmospheric relief USING EA-1-2, Local Control of S/C PORVs.

c CHECK SJG #1 or #4 ruptured.

SRO Determines SG 1 IS RUPTURED

d. CLOSE TD AFW pump steam supply from Ruptured SIG FCV-1-15 (S/G #1) or FCV-l-1t3 (SG #4)

Places HS-i-15A TDAFWP steam supply from S/G #1 to CLOSE and HS-1-16A ATC/BOP TDAFWP steam supply from S/G #4 to OPEN.

ATC/BOP e. VERIFY Ruptured S/G(s) blowdown

)solation valves CLOSED.

f. CLOSE Ruptured S/G(s) MSIV ATC/BOP and MSIV bypass valve.

Critical ATC/BOP Places HS-1 -4A to CLOSE if the MSIV (If not already performed.)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 6. 7.8 Page 50 of 58 Event

Description:

1. 1 S/G SGTR/#1 SIG ADV Fail Open Time Position Applicants Actions or Behavior

5. MONiTOR Ruptured S/G(s) ievel:

a CHECK ruptured 510 narrow range level greater than 10% [25% ADVJ.

b. ENSURE AEW isolated ATC/BOP to ruptured 5/0:

1) CLOSE AFW LCVs for ruptured SIG.

2) PLACE Turbine Driven APV LCV for ruptured 510 in CLOSE PULL TO LOCK Critical Places HS-3 1 64A to RAMP CLOSE until valve indicates closed. (if not already ATC/BOP Task performed.)

Critical ATC/BQP Places HS-3 1 74A to CLOSE and PTL (If not already performed.)

6. VERIFY Ruptured SO ISOLATED from rifict S/13s) a CHECK either of the foIlowng ccndhons SATISFIED

. Ruptured SG rlslvs and siv bpass valves CLOSED OR ATC/BOP 4 MSIV(S) and MSIV bypass vaIves)

CLOSED sri Intact S:G(s) to be used for RCS cooldown

b. CHECK Sf0 4 or 44 ruptured c CHECK TDAFW pump steam supply frcm ruptured SiG ISOLATED:

. FCV-1-15(SIG#l)or FCV-1-16SiG 44 CLOSED

7. CHECK Ruptured SG pressure GO TO ECA-3.i, SGTR and LOCA -

g1te1 Lhfl 550 psig Uflit 1) Subcooled Recover SRO or 425 psig (Unit 2)

Scenario may be terminated when the SRO transitions to ECA-3.lor earlier, at discretion of Lead Examiner

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 51 of 58 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior ES-O.5 Actions BOP 1 VERIFY DIGs RUNNING.

BOP 2 VERIFY DIG ERCW supply valves OPEN BOP 3 VERIFY at least tour ERCW pumps RUNNING.

4. VERIFY CCS pumps RUNNING:

• Pump IA-A (2A-A)

BOP

• Pump lB-B 2B-B)

• Pump C-S BOP 5. VERIFY EGTS fans RUNNING.

6 CHECK main generator output breaker(s):

BOP a. Unit 1 Only:

VERIFY main generator PCBs OPEN. EM-I)

NOTIFY at least two AUOs to report BOP to MCR to be available for local actions

8. VERIFY AEW pumps RUNNING:

a. MD AFW pumps BOP b TD AFW pump.

NOTE AFW level control valves should NOT be repositioned if manual action has been taken to control S/G levels, to establish flow due to faiRife, or to isolate a faulted 31G.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario# 1 Event# ES-0.5 Page 52 of 58 Event

Description:

Equipment Verifications

[ Time Position Applicants Actions or Behavior

9. CHECK AEW valve alignment

a. VERIFY MD AEW LCVs in AUTO, BOP b. VERIFY TD AFW LCVs OPEN

c. VERIFY MD AFW pump recirculation vaWes FCV-3-400 and FCV-3-$Oi CLOSED.

10. VERIFY MFW Isolation:

a. CHECK MEW pumps TRIPPED.

b. ENSURE the following:

BOP MFW regulating valves CLOSED

• MEW regulating bypass valve controllers in MANUAL with output ZERO MEW isolation valves CLOSED.

1 I. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

• CCPs

• RHR pumps BOP

• SI pumps

b. VERIFY CCP flow through CCPIT.

c. CHECK RCS pressure less than 1500 psig..

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 53 of 58 Event

Description:

Equipment Verifications Applicants Actions or Behavior d, VERIFY SI pump flow.

e. CHECK RCS pressure e. GO TO Step 12 less than 300 psig.

f. VERIFY RI-fR pump now.

12. VERIFY ESE systems ALIGNED:

a. Phase A ACTtJATED:

• PHASE A TRAIN A alarm LIT

[M-6C, B51.

• PHASE A TRAN 6 alarm LIT

[M-6C. 66].

b. Cntmt Vent Isolation ACTUATED:

• CNTMT VENT ISOLATION TRAIN A alarm LIT {M-6C, C5].

• CNTMT VENT ISOLATION TRAIN B alarm LIT [M-GC, C6j.

c, Status monitor panels:

BOP

• SC DARK

• GD DARK

• SE LIT OUTSIDE outlined area

• SHDARK

• GJLIT.

d. Train A status panel 6K:

• CNTMT VENT GREEN PHASE A GREEN

e. Train B status panel GL:

• CNTMT VENT GREEN

• PHASEAGREEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # Event # ES-O.5 Page 54 of 58 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

• Phase BACTUATED 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.

3) Containment spray recirculation valves to RWST FCV-72-34 BOP and FCV72-13 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, A5].

• 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. WHEN 10 minutes have elapsed.

THEN ENSURE containment air return fans RUNNING.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario It 1 Event # ES-0.5 Page 55 of 58 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior NOTE The continuous action in Step 1$ remains applicable if containment pressure rises above 1.5 psig after ES-D.5 is completed.

4 MONITOR f containment vacuum relief isolation valves should be closed:

BOP a. CHECK containment pressure a. GO TO Step 15.

greater than 1.5 psig 15 CHECK secondarv and containment rad monitors USING the foilowing:

BOP

• Appendix A, Secondary Rad Monitors

• Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS f IF SI occurred on Unit i, THEN CHECK following rad monitors including available trends prior to isolation:

• Condenser exhaust recorder 1-RR-90-1 19

• S/G blowdown recorder 1-RR-90-120

• Unit 1 Main steam Hne rad monitors [i-M-301

• Post-Acddent rad recorder 1-RR-90-2688 points 3 (blue), 4 (violet:. 5 (biack), and 6 (turquoise).

[iM-31 (back of 1-M-30)j

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH.

Aøoendix D Reauired Oøerator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 56 of 58 Event

Description:

Equipment Verifications Time I Position U Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS

1. IF SI occurred on Un!t 1, THEN CHECK following rod monitors:

BOP

. Upper containment post-accident rad monaors 1-RM-90-271A and 1-RM-90-272A NORMAL [i-M-30]

• Lower containment post-accident rad monitors 1 -RM-90-273A and 1 -RM-90-274A NORMAL [1 -M-30}

• Containment rad recorders 1 -RR 1 12 and I -RR 106 NORMAL [0-M-12] (prior to isolation).

16. WHEN directed by E-0, THEN BOP PERFORM Appendix D, Hydrogen Mitigation Action&

17, CHECK pocket sump pumps STOPPED:

[M-15, upper left corner]

• H S-77-4 10, Rx Bldg Aux Floor and BOP Equipment Drain Sump pump A

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

18. DISPATCH personnel to perform BOP EA 1, Equipment Checks Following ESF Actuation.

I9 ENSURE plant announcement has been BOP made regarding Reactor Trip and Si.

20. PERFORM Appendix E, Spent Fuel BOP cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event# Page 57 of 58 Event

Description:

Critical Tasks Critical Tasks: Critical Task Statement 1

2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # Page 58 of 58 Event

Description:

Critical Tasks Critical Tasks: Critical Task Statement 1 Energize at least one 6.9 kv Shutdown Board by resetting the 1 A EDG LO relay prior to completing step 8 of ECA-O.O.

2 Manually establish ERCW flow to the required EDG prior to completing step 8.e of ECA 0.0.

Appendix D Scenario Outline Form ES-D-1 Facility: Sequoyah Scenario No.: 2 Op Test No.: 201 3-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 1 100%, MOL Turnover: Unit 1 is in MODE 1, 100% power, MOL.

Target CTs: Manually trip the reactor from the control room prior to completing step 1 of E-0.

Manually trip all Reactor Coolant Pumps prior to the completion of step 1 of E-1 during a Small Break LOCA.

Event No.

1.

[ Malf. No.

RWO1 E Event Type*

C-BOP/SRO Event Description Essential Raw Cooling Water (ERCW) pump Q-A will trip. The BOP will start the J-A ERCW pump and select the J-A ERCW pump for auto start TS-SRO using AOP-M.01. The SRO will address Tech Specs and momentarily enters LCO 3.7.4.

2. CVO1 B C-ATC/SRO The 1 B-B Charging Pump (CCP) trips resulting in a loss of letdown, the ATC will address the ARP and will start the lA-A CCP using AOP-M.09 TS-SRO LOSS OF CHARGING. The SRO will address Tech Specs and determines the lB-B CCP pump is INOPERABLE.

3. TUO2E R-ATC A high vibration condition develops on the Main Turbine. The crew will respond using the ARP and transition to AOP-C.03 RAPID TUO2F N-SRO/BOP SHUTDOWN OR LOAD REDUCTION to reduce load on the Main Turbine.

4. FW19D C-BOP/SRO Main Feed Reg Valve FCV-3-103 fails to respond to automatic control, the BOP places FIC-3-103 in MANUAL to control S/G level using AOP S.01 MAIN FEEDWATER MALFUNCTIONS.

5. RCO1 B C-ATC The #2 RCP breaker trips with both Reactor Trip breakers failing to open automatically. The crew will transition to E-0, REACTOR TRIP OR RP18C SAFETY INJECTION. The ATC will manually open the reactor trip

[pre-insert] breakers using Immediate Operator Actions.

6. THO2C M-AIl When the Reactor trip breakers are opened, a SBLOCA develops. The crew will transition to E-1 LOSS OF REACTOR OR SECONDARY COOLANT and trip the Reactor Coolant Pumps.

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

Appendix D Scenario Outline Form ES-D-1 2013-301 NRC SCN 2 Summary EVENT 1 When directed by the lead examiner, Essential Raw Cooling Water pump Q-A will trip. The BOP will start the J-A ERCW pump and select the J-A ERCW pump to auto start using AOP-M.01, LOSS OF ESSENTIAL RAW COOLING WATER. The SRO will momentarily enter the LCO 3.7.4 action.

EVENT 2 When directed by the lead examiner, the 1 B-B CCP trips resulting in a loss of letdown, the ATC will address the ARP and start the lA-A CCP using AOP-M.09 LOSS OF CHARGING. The SRO will address Tech Specs and determines entry into LCO 3.5.2 action and TRM item 3.1 .2.4 is required.

EVENT 3 When directed by the lead examiner, a high vibration condition develops on the Main Turbine. The crew will respond using the ARP and transition to AOP-C.03 RAPID SHUTDOWN OR LOAD REDUCTION to reduce load on the Main Turbine.

EVENT 4 When directed by the lead examiner, Main Feed Reg Valve FCV-3-1 03 fails to respond to automatic control, the BOP places FIC-3-103 in MANUAL to control S/G level using AOP-S.01 MAIN FEEDWATER MALFUNCTIONS.

EVENT 5 When directed by the lead examiner, the #2 RCP breaker trips with both Reactor Trip breakers failing to open automatically. The crew will transition to E-0, REACTOR TRIP OR SAFETY INJECTION. The ATC will manually open the reactor trip breakers using Immediate Operator Actions.

EVENT 6 When the Reactor trip breakers are opened, a SBLOCA develops. The crew will transition to E-1 LOSS OF REACTOR OR SECONDARY COOLANT and trip the Reactor Coolant Pumps.

EOP flow: E-0, FR-Z.1, E-1 Scenario Termination: as directed by the Lead Examiner; following completion of E-1, Step 6, SI termination determination.

Appendix D Scenario Outline Form ESD-1 Target Quantitative Attributes Required Actual

1. Total malfunctions (58) 6

2. Malfunctions after EOP entry (12) 2

3. Abnormal events (24) 4

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions 12) 1

6. EOP contingencies requiring substantive actions 02) 0

7. Critical tasks (23) 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # Page 1 of 57 Event

Description:

Q-A ERCW Pump Over current trip Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 1, 0-A ERCW Pump Over current trip.

Indications available:

Annunciator

• O-XA-55-27A B-2: PUMP R-A DISCH PRESS LOW

• O-XA-55-27B-A E-4: ERCWICCS PUMP MOTOR TRIP Indications

• ERCW HDR 1A SUPPLY FLOW 1-FI-67-61: shows decreasing trend (to single pump conditions)

• ERCW HDR 1A SUPPLY PRESS, 1-PI-67-493A: shows decreasing trend (to single pump conditions)

• ERCW PUMP 0-A MOTOR AMPS, O-EI-67-459A: shows 0 amps.

• ERCW PUMP 0-A 0-HS-67-460A Handswitch White and Green Indicating Lights are illuminated.

PUMP Q-A ERCWICCS PUMP DISH PRESS MOTOR LOW TRIP Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

BOP Responds to alarm using ARP O-AR-M27-A, B-2 and/or O-AR-M27-BA, E-4

[1] IF ERCW pump motor TRIPS, THEN GO TO AOP-M.OI, Loss of Essential Raiv Cooling Water

[2] iF CCS motor trip. THEN GO TO AOP-M.03, LOSS of Component Cooling Water.

[3] DETERMINE which motor tripped.

[4] TURN control switch to OFF position to reset alarm.

[5] DISPATCH operator to investigate cause of alarm.

[6] EVALUATE [CO 3T3 (CCS) or 3T4 (ERCW)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 1 Page 2 of 57 Event

Description:

Q-A ERCW Pump Over current trip Time Position Applicants Actions or Behavior SRO[ Transitions AOP-M.01, LOSS OF ESSENTIAL RAW COOLING WATER.

CAUTION: ERCW header rupture in Aux Bldg could fill passive sump in 15 minutes.

Prompt action may be needed to isolate rupture using this AOP.

Directs actions from AOP M 01, LOSS OF ESSENTIAL RAW COOLING SRO WATER

1. CHECK for indications of ERC\V rupture GO TO Step 4.

inside Aux Buildino:

. flooding from ERCW insde Aux Bldg which requires rapid isolation to protect equipment or personnel SRO OR

. abnormal high flow indicated on any ERCW supply header in conjunction with flooding alarms or other indications of rupture -

4 IF this procedure entered for any reason other than ERCW rupture in Aux Bldg.

THEN GO TO applicable section:

IF... GO TO SECTION PAGE ERCW Pump(s) tripped or failed 2.1 ERCW oump failure 9 Directs actions from AOP-M.01, LOSS OF ESSENTIAL RAW COOLING SRO WATER.

1 - IDENTIFY and LOCK OUT railed ERCW pump.

BOP Places 0-HS-67-460A ERW Pump Q-A in PTL

2. START additional ERCW pumps BOP as required to maintain supply header pressure between 76 psig and 124 :psjq BOP Places 0-HS-67-432A ERCW Pump J-A to START BOP CHECK two Train A ERCW Pumps AVALABLE.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 1 Page 3 of 57 Event

Description:

Q-A ERCW Pump Over current trip Time Position Applicants Actions or Behavior

4. CHECK lAarlcl 2A EROW supply header pressures and flows NORMAL:

a. Supply header pressures

[between 78 psig and 124 psig]:

• 1-Pl-67-493A BOP 2-Pi-67-493A

b. Supply header flows

[expected value]:

. i-FI-67-61

• 2-FL-67-131

. CHECK 1 B and 2B ERCW supply header pressures and flows NORMAL:

a. Supply header pressures [between 78 psig and 124 psig]:

• 1 -Pl-f37-488A BOP

• 2-Pl-67-488A

b. Supply header flows [expected value]:

• i-H-67-iB2

. 2-Fl-37-62

6. DISPATCH personnel to inspect CREW failed pump(s) and determine cause for failure.

T NOTIFY STA to evaluate Tecil Spec SRO LCO 37.4. ERCW System, for both units.

LMfVNG 003$DmcN OR OPERATiON 3,7.4 A as wo ndpendnt esnr raw c water :ERCW) ocps haII b.? OPERPSLE.

A?PLCAS[LfY: MODES 1 2. 3. &

SRO CTC>N Wth EROW cp OERABLE, rtore 3t Iattw Iccps CPE2L2 7 cc t4 fl ! .a5t HOT 3TANDBY w;thn th t 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> n OOLD SHUTDOWN 30 ts.

Aendix D Required Orerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# Page 4 of 57 Event

Description:

Q-A ERCW Pump Over current trip Time Position Applicants Actions or Behavior Enters LCO 3J.4, Essential Raw Cooling Water System SRO (Action applicable until Transfer Switch O-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.

3. CHECK ERCW pump loading amps BOP NORMAL.

9. TRANSFER emergency power selector BOP switch away from failed pump.

Places O-HS-67-285, Transfer Switch O-XS-67-285, ERCW PUMPS J-A & Q-A BOP DG POWER SEL to position J-A.

ID. DETERMINE if manual discharge value on failed pump should be closed:

a. NOTIFY local operator to check for any of the following conditions:

SRO

• tripped ERCW pump shaft is still spinning (indicating backflow due to check valve failure)

OR

• significant leakage from tripped pump which requires isolation.

1 1. GO TO appropriate plant procedure.

SRO END OF SECTION Crew Performs a Crew Brief as time allows.

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

Crew 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 Tech Specs have been addressed.

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # Event # 3 Page 5 of 57 Event

Description:

1 B Charging Pump Trip.

Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 2, 1 B-B CCP Trip Indications! Annunciators available:

Annunciators:

1-M-1

. 1-AR-Mi-B, E-3, MOTOR TRIPOUT PNL 1-M-1 THRU 1-M-6 1-M-6

. 1-AR-M6-C, D-3, FS-62-93A/B CHARGING LINE FLOW ABNORMAL Indications:

1-M-5

. i-AR-M5-B, C-3, FS-62-1, REAC COOL PMPS SEAL WATER FLOW LO FS-62-1 REAC COOL PMPS SEAL WATER FLOW LO

[1] CHECK seal water flow to each pump on flow indicators on i-M-5or ocafly in 690 penetration room.

[21 IF all seal water supply flows are low, THEN CONSIDER the following

[a] ADJUST [jCV-62-89] as necessary.

[b] IF [1 -PC V-62-89] has failed, THEN ADJUST seal flows as necessary using the manual isolations and/or bypass valves in accordance with I -SO-62-i

[C] IF seal water injection filter is the problem. THEN CHANGE filters in accordance with i-SO-62-7, Seal Injection FiIters

[d] IF loss of running CCP has occurred. THEN GO TO AOP-M09. Loss of Charoinci.

ATC Places HS-62-104A, Charging Pump B to STOPp lip Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

SRO Transitions to AOP M.09, LOSS OF CHARGING

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 6 of 57 Event

Description:

1 B Charging Pump Trip.

Time Position Applicants Actions or behavior L CHECK any CCP RUNNING. GO TO Step 4.

ATC

4. ENSURE normal letdown ISOLATED:

a FCV-62-72 CLOSED ATC FCV-62-73 CLOSED a FCV-132-74 CLOSED

5. ENSURE excess letdown ISOLATED:

ATC

• FCV-62-54 CLOSED

• FCV-62-55 CLOSED.

CAUTION If both RCP thermal barrier cooling flow and seal Injection flow have been lost, RCP seals will overheat rapidly, NOTE If all ROP seal cooling has been lost, this AOP takes precedence over AOP-R.04, RCP Malfunctions, and AOP-M.03. Loss of Corn3onent Cooling water.

6. MONITOR RCP lower bearing and seal water temperatures:

a IF any RCP lower bearing temp or seal water temp is greater than 230 F, ATC THEN GO TO Notes prior to Step 18.

7. CHECK chargingiseal injection header ATC INTACT NQ ndication of rupture) 8 ENSURE CCP suction path established:

a. CHECK SF signal NOT actuated.

b. ENSURE suction from VCT established:

ATC

. VCT level greater than 13%

• LCV62- 132 and LcV62- 133 VOT Outlet to COP OPEN.

CAUTION If gas intrusion is suspected. NO CCP should be started UNTiL CCP has been vented (addressed in later steps).

Appendix D Scenario Outline Attachment 1 Op Test No.:

Event

Description:

Time 2013-301

]__Position Scenario#

1 B Charging Pump Trip.

Event # 3 Applicants Actions or behavior Page 7 of 57

]

9. CHECK if any COP available for immediate start:

• COP available AND

• gas intrnsbn is NOT suspected 10 DISPATCH AUO to locally verwy OCR CREW is ready to be stalled.

NOTE If RCP Thermal bamer cooling is established and sufficient time exsts for local inspection of the standby pump, then COP start n Step 1 1 should be delayed until affer inspection is completed.

I 1 START available OCR ATC ATC Places HS-62-108A, 1A Charging Pump to START ATC 12. CHECK SI signal NOT actuated.

ATC 13. MONITOR OCR suction aligned to VCT.

14. ENSURE normal charging and letdown IF RCP seal injection 8ow established USING EA-62-5, Estabtishing CANNOT be established or maintained, ATC Normal Charging and Letdown. THEN GO TO Notes pror to Step 18.

Transitions to EA-62-5, ESTABLISHING NORMAL CHARGING AND ATC LETDOWN Examiner note: The following are from EA-62-5. SRO continues the performance of AOP-M.09 actions on page 10.

2, IF normal letdown flow is 10 be established, THEN GO TO Section 4.3.

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

Appendix 0 Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 8 of 57 Event

Description:

1 B Charging Pump Trip.

Time Position Applicants Actions or behavior 1 IF charging: flow NOT established, ATC THEN PERFORM Section 4.2..

ATC 2. VERIFY pressunzer level greater than 7%

3. ENSURE letdown oriflce soIaton valves CLOSED:

CLOSED LETDOWN ORIflCE ISOLATION VALVES ATC FCV-62-72 Li FCV-2-73 Li FCV-62-74 Li

4. OPEN letdown isolation valves:

LETDOWN ISOLATION VALVES OPEN ATC FCV-62-69 Li FCV-r32-YO Li FCV-62-77 Li NOTE Placing cooling water on the Letdown Heat Exchanger prior to restoring letdown flow should prevent TiS-62-79B1A from actuating and. fully opening TCV-70-i 92.

5. PLACE [H1C42-78] in MANUAL AND ATC OPEN fTCV-70-192] to 50%. -

Places HIC-62-78 LD HX Outlet Temp to MANUAL, and adjusts output to ATC open TCV-70-1 92 to 50%. -,

6. PLACE letdown pressure controller fPCV-62-81J in MANUAL and ATC ADJUST output between 40% and 50% (50%-60% open).

Places letdown pressure controller PCV-62-81 to MANUAL and ADJUST A1C output between 40 and 50%, (50%-60% open).

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

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenario # Event # 3 Page 9 of 57 Event

Description:

B 1 Charging Pump Trip.

Time Position Applicants Actions or behavior

8. OPEN letdown orifice isolation valves as needed:

LETDOWN ORIFICE ISOLATION VALVES OPEN q

ATC FCV-62-72 FCV-62-73 FCV-c32-74 ATC Places HS-62-73 (or 74) Letdown Orifice B (or C) Isol 75 gpm to OPEN.

NOTE Normal letdown pressure s :325 psig at normal operating

emperature ATC 9. ADJUST letdown pressure controller [PC V.62411 cutput to obta n desired pressure.

Adjusts letdown pressure controller PCV-62-81 output to obtain desired ATC pressure.

ID ADJUST letdown pressure controller [PG V.62-811 setpo nt ATC to match existinq pressure.

Adjusts letdown pressure controller PCV-62-81 setpoint to match existing ATC pressure.

ATC 1 PLACE letdown pressure controller [PCV-62-81] in AIJTO ATC Places letdown pressure controller PCV-62-81 in AUTO.

NOTE Normal letdown temperature is 1 DQF ATC 2. ADJUST [HIC-62-78A] to obtain desired letdown temperature, as nd cated on Tl-62-78].

Adjusts HIC-62-78A Letdown Controller to obtain desired letdown ATC temperature, as indicated on Tl-62-78.

ATC 3. PLACE [HIC-62-78AJ fl AUTO.

ATC Places Letdown Controller HIC 62-78A in AUTO Examiner Note: Several steps, notes, and cautions in the procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Examiner Note: Letdown temperature may swing due to repeated actuation of TlS-62-79B/A, which causes letdown temperature control valve TCV-70-1 92 to fully open.

Examiner Note: SRO continues the performance of AOP-M.09 actions here

Appendix D Scenario Outline Attachment 1 Op Test No.: 2013-301 Scenano# 1 Event# 3 Page 10 of 57 Event

Description:

1 B Charging Pump Trip.

Time Position Applicants Actions or behavior 15 NOTIFY STA or oilier availabe SRO licensed operator to refer to App A.

Tech Spec Impacts.

SRO Enters LCO 3.5.2 Action a LIMITING CONDITION FOR OPERAThDN 052 T ECCS trns shall be CPERABLE

---

NOTES------------

1 In HCDE 3 :h nalery njeotcn SI purn flow oaifis may be solated r.y oeng oe solalon aes or up to 2 hcrs to perrom, or-essure scIator valve estn pc CR 4A 53 2 in MODE 3. BOGS ouros rr be made neapabe c -cong spport ranshon nb or ,rom the A°UCABILiTt of LCD 34 12 Lw Temperature Cue pressure °otocton lLTOP ys:em, cr up to 4 pours or untd the tempe-atu-e o ax RCS cold sgs exceeos LTDP arrr emperature 351VF secfie rt te PlOP us 2SF, .hohever tomes ..

APPLICABILITY: MODES 1 2 and 3.

ACT:ON:

a Vih one tr more as nopeabIe d wtt at Cast 100% of e EGGS Sow eousent to a trite OPERABLE ECCS lrsr ava abe e ietfle n:cerable is to OPERABLE aratos th ri 72 twurs or be n at east HOT STANDBY thn He nextfi hours aria Ti HOT 7l-lUTDCN .s-thn the foowg S flours SRQ Enters the TR 3.1.2.4 Action L1MflING CONDITION FOR OPERATTO:N TR 3. 2.4 At les tw char puunps 5ha be OPERABLE.

AFFUCABIUTY: MODES 1.3. artd3.

ACTQN:

Wth only o charu ptTi OPERABLE restore at iesi two ,arrg mos OPERABLE status vcthin 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ben at least HOT STANDBY anc horated to a SHUTDOWN MARGIN equivalent to at least 1% d&ts kik at 2OCF within the next S ours: restore at least to charging pumps to OPERABLE status withrt the rext 7 days o be in HOT SHUTDcWN wthn the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

Crew Performs a Crew Brief as time allows.

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

Crew Orerations 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 the SRO has addresses Tech Specs and the TRM.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 11 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position U Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 3 Main Turbine High Vibration.

Indications/Alarms

• 2A D-4, VA-47-120 TURBINE HIGH VIBRATION indicates >7 mils

• ICS, Main Turbine Vibration Recorder indicates elevated vibration on #s5 & 6 bearings (9-1O mils).

VA.-47-1 20 TURBINE HIGH VIBRATION BOP Responds to ARP 1-AR-M2-A MAIN TURBINE Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

Corrective iI MONITOR recorderjXR472J:o Oeterminewhrcl, bearing Actions has possible vibration probima and establish treod CAUTION Dispatching personnel locally could place pe nnel in aerious danger if -a tastrophic turbine failure occurs.

Local verificatron should HOT be performed when adequate MCR indications exist

[2J 1F bearing ibraiion 14 nuiis AND a-ny othe foliowing dhions are met:

• Higr vbrabon a present on nultipiC bearings OR

• Aboorimsi noiae or vEbratrort ocal[y or from MCR.

TI-lEN PERFORM the fotowing a] IF reactor pcaeria above O%, THEN TRIP the reactor and GO TO E-O.

ibJ IF reactor power a less than 5D% THEN TRiP the tjrbie AND GO TO AOP-&06 31 DISPATCH operator to sound cut :urbne .0 erii .aiarm arid l-.t47-2 nthoabcrrs.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 12 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior

[41 CHECK the fctIowng ccnd;tios or oential root cause.

a. O1 tempers:ure

b. Criicat speed.

c. Seahrtg steam pressure.

d. Condenser vacwm

e. E:hsust shed ternperre

[5J CORRECT paiameterualues 1thin apptcable plant procedures linde.

[j iF vibration remns high (greater than s -point 7 milsi. THEN CONSULT with SROISM AND EVALUATE starting urtit shutdown is] DETERMiNE rate of rise i ocecibie b] CONTACT System Preoic:ive Mnenarce and System Engireer

[71 IF ration rerrans Hgn 7 mis, THEN CONSULT wim. SRO3M. AND EVALUATE starung unit sown.

[SJ IF vibration COfltiflUeS tO THEN CONSULT M, AND EVA LUATE tripping the turbine prior to exceeding 14 mile verifed 1bratiQn USiNG the guidance provided in Stu 2.

[Sf tFreactorttip, THEN GO TO E-D. Reactor Thp or Safety fnecrfon.

[10] IF urbine ip and no reactor rip, THEN GOTO AOP-S.6, Turbine Trip.

Examiner note: The crew will get direction to reduce power 20% from station management.

Transitions to AOP-C.03 RAPID SHUTDOWN OR LOAD REDUCTION, go to SRO next page for details.

Directs performance of AOP-C.03 RAPID SHUTDOWN OR LOAD S RO REDUCTION, 1 ENSURE crew has been briefed on reactivIty SRO management expectations USING Appendix A

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 13 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction APPENDIX A REACTIVITY MANAGEMENT BRIEFING NOTE This appendix should be used in addition to event-based biief

[1] ENSURE crew has been briefed on the following:

• Reason for Rapid Shutdown or Load Reduction

• Load Reduction Rate:________

• Desired final power level:______

• Reactivity Management expectations:

• lJnit Supervisor stall concur with all reactivity manipulations

• Ensure reactor responding as expected using diverse indications

• Tavg-Tref Mismatch requirements:

• 3F control band

• 5F reactor trip criteria

• Crew focus will be on reducing power in a controlled and conservave manner.

• OATC will monitor rod inserbon limits and AFD limit

• Boration source:

• Crew will monitor reactor trip and turbine trip criteria using App B

• CRC will stop secondaW plant equipment using App C

• Tennination Criteria (conditions requiring Reactor Trip, Turbine Trip, or condition no longer requiring rapid load reduction):

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 14 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[ Time Position fl Applicants Actions or Behavior Chooses a power reduction rate of 1% final power level of <55% and BAT as SRO the boration source (1% to 3% acceptable )$ahjl

2. MONITOR reactor/turbine trip NOT required USING Appendix B, Reactor and Turbine CREW Trip Criteda. (two extra copies provided for UOs)

3. CHECK VALVE POSITION LIMIT light CREW DARK on EHC panel. [M-2]

Examiner note: Appendix B reactor and turbine trip criteria see page 21 NOTE: Step 4 should be handed off to opposite unit or extra operator (if available).

It NO operator is available, notifications should be performed concurrently with subsequent steps (when time permits).

4. ENSURE following personnel notified of rapid shutdown or load reduction: Ci]

. Balancing Authority (Load Coordinator)

(751-7547).

CREW

. Chemistry

. Radiation Protection a Plant Manaqement CREW Makes notifications as required.

NOTE: Boration volumes and flowrates listed in this procedure are recommendations and may be adjusted as necessary.

. INITIATE boration:

a CHECK rod control AVA1tjBLE:

ATC

• Control Bank D rods capable of being moved

• NO dropped or misaligned rods in Control Bank D.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 3 Page 15 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior

5. b. CHECK Control Bank D group position greater than 200 steps.

ATC c CHECK boration :capabHity from BAT AVAILABLE.

d. DETERMINE recommended boration volume from BAT:

• --800 gal to reduce power from 100% to 20%

OR SRO

• 10 gal for each 1% power reduction from current power level)

OR

• volume recommended by Reactor Engineering.

SRO Determines 200 gal as required to reduce power from 76% to 56%

5. e. DETERMINE recommended boration flowrate from table below or from Reactor Engineering:

LOAD REDUCTiON BORATION SRO RATE(%Imin) FLOWRATE 1% -- 5 gpm 2% -3Ogpm 3% --45 gpm SRO Chooses a 1% load reduction rate (1% to 3% acceptable)

ENSURE concurrence obtained from A TC STA for boraticn volume and flowrate.

g CHECK status of charging and ietdown:

. normal letdown flow ATC ESTABLISHED

. charging flow control HIC-62-93A in AUTO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 16 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior h DETERMINE if normal boration wifl be used:

ATC

• desired load reduction rate is less than 4% per minute

. time s availahie for normal boration I. INITIATE normal boration ATC USING Appendix H.

Examiner note: Appendix H Actions are listed in the following steps.

APPENDIX H NORMAL BORAIION

[I] RECORD desired boration volume and flowrate:

ATC Volume (gal)

Flowrate igprn)

ATC Records 2OO gal as required at 15 to 45 gpm i!irr I ATC [2] PLACE [HS-62-140A1 Makeup Control to STOP posaion ATC Places HS-62-1 40A to STOP.

I

[3] PLACE [HS-62-14B] Makeup mode selector switch ATC in BORATE position.

ATC Places HS-62-l4OBto BORATE NOTE Boric Acid controller setting is twice the desired flow rate Maximum Boric Acid flow s 45 gpm

[4 ADJ UST [FC-62-1 39] BA flow co troller setpo nt ATC for desired f ow rate ATC Places FIC-62-139 to 15 to 45 gpm.

[53 ADJUST IFO-62-1391 BA integrator (batch counter)

ATC to desired bonc acid volume ATC Places FQ-62-1 39 to 2OO gal.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 3 Page 17 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior

[6] PLACE IHS-62-140A1 Makeup Control Switch mode ATC selector switch to START E ATC Places HS-62-1 40A to START

[7] ENSURE bonc acid transfer pump aligned to blender ATC in FAST speed. E1

[81 IF desired boric acid flow rate NOT obtained.

THEN ADJUST one or both of the following as necessary:

ATC

. FFC-62-1 391 BA flow controller LI

. recirculation valve for BAT aligned to blender. LI ATC Adjusts FI-62-139 as required.

ATC [9] ENSURE desired boric acid flow indicated on Fl-62-1 39. LI

[10] RECORD time when boration flow established: LI ATC Time:

ATC Records time boration initiated.

[11] WHEN required boric acid volume has been added AND control rods are above low-low insertion limit, THEN ATC PERFORM the following:

[a] PLACE [HS-62-140A1, Makeup Control to STOP position. LI ATC Places HS-62-140A to STOP.

[b] ENSURE FFC-62-1421, Primary, Water to Blender Flow ATC Controller in AUTO with dial indicator set at 35%.

[C] ADJUST IFC-62-1 391, Boric Acid Flo v Controller to 1

A TC desired blend solution USING TI-44 Boron Tables. LI ATC Places FIC-62-1 39 to 17.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 3 Page 18 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior

[d] PLACE IHS-62-140B1, Makeup Mode Selector ATC Switch in AUTO position. El ATC Places HS-62-140B to AUTO.

ATC [e] PLACE rHS-62-140A1, Makeup Control to START. El ATC Places HS-62-140A to START.

ATC [f] ENSURE bonc acid transfer pumps running in SLOW speed. El Places HS-62-230A BA Transfer Pump 1A to STOP ATC Places HS-6223OA BA Transfer Pump 1 A to START.

Places HS-62-232A to BA Transfer Pump I B to STOP ATC Places HS-62-232A to BA Transfer Pump 1 B to START.

J. CONTROL bortion flow as required to inject desired boric acid volume.

CAUTION: If borating from the RWST, Turbine Load Reduction Rate greater than 2% per minute could result in violating Rod Insertion Limit.

6. INmATE load reductton as Follows:

a. ADJUST load rate to desired vafue:

• between 1% and 4% per rntnute ii borating via FCV-62-138 BOP OR

• between 1% and :3% per minute it borattng va normal boration (App. H)

OR

. 2% per minute if borating from RWST.

BOP Adjusts load rate approx 1% to 3% per minute

Appendix D Reciuired Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 3 Page 19 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time Position Applicants Actions or Behavior b ADJUST setter for desired power level:

DESIRED RECOMMENDED RX POWER LEVEL SETTER VALUE BOP 50% 40 50% 35 BOP Adjusts setter to approx 37 6 C. VERIFY boration flow established.

BOP d INITIATE turbine load reduction by depressing GO pushbutton.

SOP Depresses GO pushbutton

e. CONTROL turbine load reducUan BOP as necessary to reduce power to desired level.

7. MONITOR T-avglT-rer mismatch:

a CHECK T-ref indication a PERFORM the following:

AVMLASLE.

1) MONITOR Program T-avg for current reactor power USING Tl-28 Figure 3 or ICS (NSSS 1 SOP, Program Reactor Average Temperature).

2) USE program ravg in place of T-ref..

3) MAINTAIN T-avg within 3F of program T-avg USING manual rod ATC control.

4) ADJUST turbine load rate as necessary.

5) IF mismatch between T-avg and program value CANNOT be maintained less than 5F.

THEN TRIP the reactor and GO TO 5-0, Reactor Trir or Safety injection.

ApDendix D Reauired Ooerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 3 Page 20 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction Time

[ Position

[ T h.

Applicants Actions or Behavior MONITOR automatic rod control b. IF auto rod control is ftinctional maintaininct T-avg/T-ref mismatch AND situation allows slowing down less than 3F. load reduction, THEN PERFORM the following:

1) REDUCE turbine load ate to allow auto rod control to restore T-avqT-ref mismatch.

2) WHEN T REF T AUCT HIGH LOW alarm 1-5A, C-i)) is clear.

THEN RESTORE turbine load rate to desired value IF any of the following conditions met:

. auto rod control NOT functional OR

. tuibine load rate adjustment is NOT effective in reducing mismatch OR

. situation does NOT allow slowing down load reduction, THEN RESTORE I-avg to within 3F of T-ref USING manual rod control as necessary.

IF T-aigiT-ref mismatch CANNOT he maintained iCSS than 5F.

THEN TRIP the reactor and GO TO E-O, Reactor Tap or Safety injection.

Coordinates with the BOP to maintain T-avglProgram T ref mismatch less than ATC 3F using the Tl-28 figure 3 or ICS BOP MONITOR autornatc control of MFW pump speed AVAILABLE

9. STOP sec.orTdarv pint equipment BOP USING Appendix C, Secondary Plant Equipment.

Examiner Note: Appendix C, Secondary Plant Equipment starts at page 22.

Examiner Note: Additional AOP-C.03 steps not included as required power reduction should be complete at or around this step.

Examiner Note: When the crew has sufficiently reduced power the Lead Examiner may go to the next event starting at page 32.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 3 Page 21 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction APPENDIX B REACTOR AND TURBINE TRIP CRITERIA REACTOR TRIP CRITERIA TURBINE TRIP CRITERIA Turbine trip required or imminent Turbine vibration exceeding 14 mils with reactor power greater than P-9 (50%) with cie of the following:

Uncontrolled rod movement which CANNOT be

• high vibration on multiple bearings stopped by p[acing rods in MANUAL AOP-c.cl) OR Loss of S/G level control:

• abnormal noiseMbration apparent level dropping or rising toward trip setpoint and eval CANNOT be restored os.ci More than one dropped rod p-c.o i T-avgdT-ref mismatch CANNOT be maintained less than &f (refer to Step 7 or App. E) 30% turbine load: 30% turbine load:

Condenser Pressure> 21 psia AND CANNOT Condenser Pressure> 1.72 psia be restored within 5 minutes oP-s oz oP-s.ci2 Any automatic reactor trip setpoint reached Any automatic turbine trip setpoint reached OR automatic trip imminent: OR automatic trip imminent

. Turbine trip above P-9 (50%)

• High Stator Cooling Water temp 90CC a Safety injection OR Stator D/P 12 psig betow normal a Power Range high flux 109%

• Both MFPTs tnpped a Power Range flux rate 5% in 2 seconds a Law Auto Stop Oil pressure 45 psig a Pressurizer high i:evei 92%

• High 510 level 81% narrow range a Pressurizer pressure [ow 1970 psig

• Main Turb Bearing Oil low pressure 7 psig a Pressurrzer pressure high 2385 psig

• Thrust Bearing Oil high pressure 60 psig a RCS low flow 90%

• Turbine Overspeed 1 980 :rpnl a RCP underioitage 5.022 kilovolts

• Lcss of El-iC pressure a RCP underfrequency 56.0 Hz

• Unit 1 Only:

a OTfl 115% (variable) Generator PCBs tripped.

a OPT 108.7% (variable)

• Unit 2 Only:

Generator Circuit Breaker (GCB) tripped a S/C.Z low leel 0 7 rise Ed OR 161KV PCBs 924 and 928 tripped a SSPS general warning in both trains

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 22 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction APPENDIX C SECONDARY PLANT EQUIPMENT

[1] ENSURE plant announcement(s) made on the following:

a starting rapid shutdown (or load reduction) due to (reason)

• stopping secondary plant equipment NOTE I If reactor power will be reduced below 50%. AUO should be on station at #3 heater drain tank (if possible) when 60% power is reached.

NOTE 2 Dispatching of AUO in Steps [2] and 3] may be performed out of sequence.

[2] IF reactor power will he reduced below 50%,

THEN DISPATCH AUO with Appendix 3 (Unit 1) or K (Unit 2) to #3 Heater Drain Tank.

[3] IF one MFP will be shutdown using this appendix, THEN DISPATCH AUO to OPEN MFWP rec:irc manual Isolation valve for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN 1 1A 1-VLV-3-576 TB eL 706, Northeast corner of IA condenser E 1B 1-VLV-3--577 TB eL 706, Northeast corner of IA condenser 2 2A 2-VLV-3--576 TB eL 706, Southeast corner of 2 condenser 2B 2-VLV-3-577 TB eL 706, Southeast corner of 2A condenser fl

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 3 Page 23 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction APPENDIX C

[4] IF BOTH of the following conditions are met:

power s being reduced as directed by AOP-S.Q 1 (Main Feedwater Malfunctions) or AO P-S. 04 (Condensate or Heater Drain Malfunctions)

. leaving secondary pumps n service is desired, THEN GO TO Step [8].

[5] WHEN turbine impulse pressure is approximately 80% or less, THEN PERFORM the following:

[a] ENSURE one Cond Demin Booster Pump STOPPED.

[bJ ENSURE associated suction valve CLOSED:

OR B FCV-2-285

[ c [Fcv2.28o

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 24 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[6] WHEN turbine impulse pressure is approximately 70-75%,

THEN PERFORM the fclowing:

[a] ENSURE one Condensate Booster Pump STOPPED

[b] ENSURE associated CBP suction valve CLOSED:

CONDENSATE BOOSTER urw SUCTION VALVE CLOSED 4 A FCV-2-94 OR OR FCV-2-87 E.

]

FCV-2-81

[c] PERFORM applicable procedure to adjust seal injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary)

• i-S0-213-1 Section T2 OR

• 2-50-213-1 Section T3

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 3 Page 25 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[7] WHEN turbine impulse pressure is approximately 65% or less, THEN PERFORM the following:

[a] STOP remaining two Cond Dernin Booster Pumps simultaneously.

[b] ENSURE suction valves CLOSED:

COND DEMIN BOOSTER uip SUCTION VALVE CLOSED A FCV-2-290 E B FCV-2-285 C FCV-2-280

[c] STOP one No. 3 Heater Drain pump.

[d] STOP one No. 7 Heater Drain pump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 26 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[8] IF reactor power will be maintained greater than 50%

THEN GOTO Notes prior to Step [11].

CAUTION Isolation of all three intermediate heater strings could occur if turbine is tripped prior to fully opening LCV-6-105A and B using Appendix J or K.

[9J WHEN reactor power is less than 60%

AND AUO with App. J (Unit I) or K (Unit 2) is on station at #3 Heater Drain Tank, THEN PERFORM the following:

[a] STOP 3 Heater Drain Tank Pumps.

[b] NOTIFY AUO to perform App. J (Unit I) or App. K (Unit 2),

Fully Opening #3 Heater Drain Tank Bypass Valves.

[c] CLOSE isolation valves from #3 Htr Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED I FCV-6-108 Htr Drain Tk Pump 3 to Htr String A FCV-$- 109 HIr Drain Tk Pump 3 to Htr String B E FCV-6-110 Htr Drain Tk Pump 3 to Htr String C

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 27 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction NOTE I The following step ensures that MFW Bypass valves are available to control feedwater flow at low power.

NOTE 2 If any MEW Reg valve is in MANUAL, the associated MEW Bypass valve controller should remain in MANUAL to prevent undesired opening of bypass valve.

[10) WHEN Reactor power is less than 50%,

THEN PERFORM the fol[owing:

[] IF all MEW Reg Valves are in AUTO, THEN PLACE MEW Bypass Reg Valve controllers in AUTO.

[b] IF any MEW Reg Valve is in MANUAL, THEN PERFORM the following:

I) MANTAlN MEW Bypass Reg Valve in MANUAL for SIG with MEW Reg valve in MANUAL. E

2) PLACE MEW Bypass Reg Valves in AUTO for remaining SIGs.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event

• 3 Page 28 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction NOTE I If performing this AQP to reduce power to aHow shutting down one MEW pump the affected MFWP may be removed from service at power level less than 55% (Unit 1) or 65% (Unit 2).

NOTE 2 AEW start function on loss of both MEW pumps is inoperable when a MFW pump is RESET but NOT pumping forward. LCO 3.3.2:1 (Unit 1) or 33.2 (Unit 2) allows AFW start channel to be inoperable for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when shutting down a MFWP.

[II] WHEN it is desired to remove one MEW pump from service AND power level is less than applicable limit:

• turbine impulse pressure less than approximateLy 45%

OR

• reactor power less than value specified in Note 1 THEN PERFORM the following:

[] ENSURE MFWP Recirc Manual Isolation valve OPEN for MFWP to be removed from service: (N/A valves NOT opened)

UNIT MFWP VALVE LOCATION OPEN 1A i-VLV-3--576 TB eL 706, Northeast coiner of 1A condenser 18 i-VLV-3-77 TB el.. 706. Northeast corner of iA condenser 2VLV-3-576 TB eL 736 Southeast corner of 2A condenser 2

28 2-VLV-3-577 TB el. 706. Southeast corner of 2A condenser

[bJ THROTTLE OPEN recirc valve in MANUAL (30-50% OPEN) for MEWP to be removed from service.

[cJ PLACE speed controller in MANUAL for MFWP to be removed from service.

[dJ REDUCE speed gradually on MFWP to be removed from service.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario# 1 Event# 3 Page 29 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[11] (Continued)

[e] ENSURE proper loading on remaining MFWP..

[ IF MFWP CANNOT be fully unloaded with speed controller, THEN PERFORM one of the following:

• NOTIFY l&C to slowly adjust hand speed changer for affected MFWP UNTIL MFWP is fully unloaded.

OR

• THROTTLE OPEN recirc valve for affected MFWP to assist in unloading MFWP OR

• SLOWLY CLOSE governor valve by bumping closed governor valve positioner (if operable OR

• OBTAIN SRO concurrence that MFWP flow is sufficiently low to allow tripping MFWP. El

[g] WHEN MFWP is unloaded sufficiently, THEN TRIP affected MFWR El

[Ii] CLOSE recirc valve for MFWP removed from servce.

[I] CLOSE recirc valve Manual Isolation inlet valve for MFWP removed from Service.

U] OPEN drain valves for MFWP removed from service: [M-3]

• [HS4B-141, MFWP A drain valves El OR

• [HS461] MFWP B drain valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 3 Page 30 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[12] WHEN turbine impulse pressure is approximately 45% or less, THEN PERFORM the following:

[a] STOP remaining No. 7 Heater Drain pump.

[b] CLOSE isolation valves from #7 Heater Drain Pumps to heater strings:

VALVE DESCRIPTION CLOSED FCV-6i43 Htr Drain Tk Pump 7 to Htr String A FCV-6-163 Htr Drain Tk Pump 7 to Htr String B FCV 84 Htr Drain Tk Pump I to Htr String C E

[13] WHEN turbine impulse pressure is approximately 30% or less, THEN PERFORM the following:

[a] ENSURE main turbine EHC controls in IMP OUT.

[b] IF #3 heater drain tank pumps are still running, THEN PERFORM Step t9]- E

[c] STOP one of two remaining Condensate Booster Pumps.

(step continued on next pace)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 3 Page 31 of 57 Event

Description:

Main Turbine High Vibration/Power Reduction

[13] (Continued)

[d] ENSURE associated CBP suchon valve CLOSED:

OR OR FCV-2-87 C FCV-2-81

[e] STOP one of three Hotwell Pumps.

[f PERFORM applicable procedure to adjust seat injection water pressure on stopped CBP to prevent water intrusion in oil:

(may be assigned to another operator or delayed if necessary) 1-50-2)3-I Section T2 OR

. 2-S0-2/3-1 Section T3

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 4 Page 32 of 57 Event

Description:

FcV-3-1 03 Fails To Respond While In AUTO Time fl Position Applicants Actions or behavior Direct the Simulator Operator to initiate Event 4, FCV-3-103 Fails To Respond While In AUTO Indications/Alarms Indications:

1-M-4

. SIG #4 Level above the other three SIG

. SIG #4 Feed Flow above the other three SIG Evaluator Note: For this event, crew may respond per the Annunciator Response Procedure directly enter AOP-S.01 Section 2.2. Section 2.2 Step us an IMMEDIATE ACTION step; the BOP may perform the action(s) associated with Step 1 from memory without direction.

SRO Transitions to AOP-S 01, MAIN FEEDWATER MALFUNCTIONS section 2 1 I - DIAGNOSE the failure:

IF GOTO PAGE SECTION Failure of Automatic SJG Level Control Z1 4 Directs actions from AOP-S 01 MAIN FEEDWATER MALFUNCTIONS SRO section 2 1 NOTE: Step 1 is an IMMEDIATE ACTION..

1. RESTORE steam generator level(s):

a. PLACE affected teedwater req valve controller(s) andior bypass req valve controller(s) in MANUAL.

BOP b CONTROL feedwater flow on affected S/G(s) to restore level to program.

BOP Places FIC-3-103D in MANUAL and LOWER Z CHECK the following:

BOP

• SIG pressure instruments NORMAL

• S/G level instruments NORMAL.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 4 Page 33 of 57 Event

Description:

FCV-3-103 Fails To Respond While In AUTO Time Position Applicants Actions or behavior

3. CHECK Steam Flow and Feed How nstnjments NORMAL USING tIle following:

BOP

• control board indicators [M-4]

• DCS Operator Display Monitor.

CAUTION: Feed flow transients may impact core thermal power.

NOTE lC.S point IJ11 18 (Megawatt Thermai indication) may be impacted by feed flow

nstrument failure. U21 (LEFM calorimetric power> should remain reliable.

& MAINTAIN Steam Generator level(s)

BOP on program.

OP CONTROLS #4 S/GLeve[with FIC-3-1 030 in. MANUAL

5. INITIATE repairs on failed equipment.

CREW

6. WHEN automatic control of affected MFW reg valve(s) is available and reliable.

BOP THEN PLACE controller(s) in AUTO USING 1 2-SO9&1, Distributed Control System.

NOTE: instructions for restoring bypassed instrument channels are contained in 1.2-50-98-1.

7. GO TO appropriate plant procedure.

CREW Crew Performs a Crew Brief as time allows.

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

Crew 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 plant is stable with #4 SIG control in manual.

ADijendix D Reauired Orerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 34 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time I Position 1 Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 5 #2 RCP Trip Indications available:

Indications/Alarms Annunciator:

. 1-M-4-D, D-3 One Loop Low Flow Reactor Trip Indications:

1-M-4

• #2RCPTripped Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ONE LOOP LOW FLOW REACTOR TRIP tI] lFreactcrtrps, THEN GO TO E-O. Reactor TriJ or Safety IfljCCt ton.

SRO Transitions to E-O. Reactor Trip or Safety Injection Examiner Note: following IOA performance, prior to Steps 1-4 immediate action verification, ATC/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)

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via SPDS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1 -FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE 1 Steps 1 through 1 are mmediate action steps.

NOTE 2 This procedure has a foldout page.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 5,6 Page 35 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior VERIFY reactor TRIPPED:

• Reactor trip breakers OPEN Reactor trip bypass breakers DISCONNECTED or OPEN ATC

• Rod bottom Hghts LIT

• Rod position indicators less than or equal to 2 steps.

• Neutron flux DROPPING CRITICAL ATC Places 1-RT-1 OR 1-RT-2 Reactor Trip to TRIP.

TASK ATC Manually initiates SI.

2. VERIFY turbine TRIPPED:

BOP Turbine stop valves CLOSED.

3. VERIFY at least one .9KV shutdown BOP board ENERGIZED on this unit

4. DETERMINE if SI actuated:

ATC

• ECCS pumps RUNNING.

• Any SI alarm LIT M-4Dj.

5. PERFORM ESO.5, Equipment BOP Verifications WHILE continuing in this procedure.

A1 Continue with the performance of E-O REACTOR TRIP OR SAFETY SRO/-

C 1

INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 51 for details SRO Addresses foldout page, see next page for details.

CRmCAL ATC Manually places HS 68-8A, 31A, 50A, and 73A RCPs to STOP.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-30 1 Scenario # 1 Event # 5,6 Page 36 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

• ROS pressure less than 1250 psig AND at [east one COP or SI pump running OR

• Phase B isolation, THEN STOP all ROPs.

EVENT DIAGNOSTICS

• IF any Sf0 pressure is dropping uncontrolled, THEN PERFORM the following:

a. CLOSE MSIVs and MSIV bypass valves.

b. IF any SIG pressure continues to drop uncontrolled. THEN PERFORM the following:

1) ENSURE SI actuated.

2) IF at least one S/S is intact (S/S pressure controlled or rising),

THEN ISOLATE AFW to fautted 5/0(s):

• CLOSE AFW level control valves for faulted 5/5(s)

• IF any AEW valve for faulted S/S CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted SJG.

3) ENSURE at least one of the following conditions met:

• total AFW ow greater than 440 gpm OR

• Narrow Range level greater than [0% 25% ADVJ in at least one intact 510.

• IF both trains of shutdown boards dc-energized. THEN GO TO EOA-0,0, Loss of All AC Power.

TANK SWITCHOVER SETPOINTS

• IF CST level less than 5%, THEN ALIGN AFW suction to ERCW.

• IF RWST level less than 27%. THEN GO TO ES-i.3, Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 37 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA

[ Time Position Applicants Actions or Behavior

6. DETERMINE if secondary heat sink available:

a. CHECK total AFW flow greater than 440 gpm.

b. CHECK narrow range level b. MAINTAIN total feed flow ATC greater than 10% [25% ADV] greater than 440 gpm in at least one S/G. UNTIL narrow range level greater than 10% [25% ADVI in at least one S)G.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADV] and 50%

in intact or ruptured S/Gs.

Manually controls AFW flow to maintain total AFW flow greater than 440 gpm ATC/BOP until S/G are greater than 10% NR.

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 ATC UNCONTROLLED OR

. Phase B actuation.

b ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 5.6 Page 38 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1 250 psig ATC AND

. At east one COP OR SI pump RUNNING.

b. STOP RCPs.

ATC Manually places HS 68-8A, 31A,5OA, and 73A RCPs to STOP

9. MONITOR RCS temperatures: IF temperature less than 547F and dropping, IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547F and 552cF. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues.

IF RCPs stopped. THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending ATC/BOP 1> ENSURE total AFW flow to between 547F and 552SF.

less than or equal to 600 gpm.

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10°/b [25% ADVI in at least one S/G.

c IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves,

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenano # 1 Event # 5,6 Page 39 ot 57 Event

Description:

RCP Tr1pIATWS/SBLOCA

[ Time Position Applicants Actions or Behavior ManuaNy controls AFW flow to maintain total AFW flow greater than 440 gpm ATC/BOP and less than 600 gpm until S1G are greater than 10% NR.

10. CHECK pressurizer PORVs, safeties.

and spray valves:

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

11. DETERMINE if S/G secondary pressure boundaries are INTACT:

CHECK all SIG pressures ATC CONTROLLED or RISING.

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

12. DETERMINE if S/G tubes are INTACT:

. All S/G narrow range levels CONTROLLED or DROPPING ATC

. Secondary radiation NORMAL USING Appendix A, Secondary Rad Monitors. (App. A performed in E.S-0.5).

13. DETERMINE if RCS is INTACT:

. Containment pressure NORMAL

. Containment sump level NORMAL ATC

• LOWER COMPT TEMP HIGH alarm DARK. [M-5C. Bi]

. Containment radiation NORMAL USING Appendix B, Containment Rad Monitors. (App. B performed in ES-0.5)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5.6 Page 40 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via lOS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

When a RED Path for Containment is evident on lOS, the SRO will transition to FR-Z.1, go to page 48 for details.

SRO Transitions to El Loss of Reactor or Secondary Coolant.

E-1, LOSS OF REACTOR OR SECONDARY COOLANT NOTE This procedure has a foldout page.

See next page for details

1. CHECK RCP trip criteria:

a. CHECK the following: a. GO TO Step 2.

. At least one CCP OR SI pump RUNNING ATC AND

• RCS pressure less than 1250 psig.

b. STOP RCPs.

2. CHECK SIG secondary pressure boundaries INTACT:

ATC/BOP

• S!G pressures CONTROLLED or RISING

. S/G pressures greater than 140 psig.

3. MAiNTAIN Intact SJG narrow range levels:

a. Greater than 10% [25% AD!].

ATC/BO P

b. Beeen 10% [25% ADV} and 50%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 201 3-301 Scenario # 1 Event # 5,6 Page 41 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

• RCS pressure less than 1250 psig AND at least one CCP or SI pump running OR

• Phase B isolation, THEN STOP all RCPs.

SI REINITIATION CRITERIA IF any of the following conditions occurs:

• RCS suhcooling based on core exit T/Cs less than 40F OR

• Pressurizer level CANNOT be maintained greater than 10% [20% ADV],

THEN RAISE ECCS flow by performing one or both of the following as necessary:

• ESTABLISH CCPIT flow USING Appendix C

• START CCPs or SI pumps manually.

EVENT DIAGNOSTICS

• IF both trains of shutdown boards de-energized.

THEN GO TO ECA-GO. Loss of All AC Power.

• IF any 5/0 pressure dropping in an uncontrolled manner or less than 140 psig AND S/G NOT isolated, THEN GO TO E-2. Faulted Steam Generator Isolation.

• IF any S/G has level rising in uncontrolled manner or has abnormal radiation, THEN:

a. RAISE ECCS flow by performing one or both of the following as necessary:

• ESTABLISH CCPIT flov USING Appendix C

• START CCPs or SI pumps manually.

b. GO TO E-3. Steam Generator Tube Rupture.

TANK SWITCHOVER SETPOINTS

• IF OST level less than 5%,

THEN ALIGN AFW suction to ERCW.

• IF RWST level less than 27%.

THEN GO TO ES-i .3. Transfer to RHR Containment Sump.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 5,6 Page 42 of 57 Event

Description:

RCP Trip/ATWSISBLOCA Time j Position Applicants Actions or Behavior

4. VERIFY secondary radiation NORMAL:

a. CHECK secondary radiation NORMAL USING Appendix A. Secondary Rad Monitors.

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

c. WHEN Chem Lab is ready to sample S/Gs, THEN PERFORM the following:

ATC

1) ENSURE FCV-1 5-43 Slowdown Flow Control valve CLOSED.

2) ENSURE Phase A RESET.

3) OPEN blowdown isolation valves.

d. NOTIFY RACCON to survey main steam lines and S/G blowdown.

e. WHEN S/G samples completed, THEN CLOSE blowdown isolation valves.

CAUTION Any time a pressurizer PORV opens, there is a possibility that it may stick open.

5. MONITOR pressurizer PORVs and block valves:

a. Power to block valves AVAILABLE, a. DISPATCH personnel to restore power to block valves USING EA-20 1-1, 480V Board Room Breaker Alignments.

ATC b. Pressurizer PORVs CLOSED. b. IF pressurizer pressure less than 2335 psig.

THEN CLOSE pressurizer PORVs.

1F pressurizer PORV CANNOT be closed, THEN CLOSE its block valve.

Appendix D Reauired Ooerator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 43 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior

6. MONITOR SI termination criteria:

ATC a. RCS subcooling based on core exit TiCs a. GO TO Step 7.

greater than 40F.

7. MONITOR if containment spray should be stopped:

a. CHECK any containment spray pump a. GO TO Step 8.

RUNNING.

ATC

b. CHECK containment pressure b. GO TO Step 8.

less than 2.0 psig. IIIIIIIIIIIIII

8. MONITOR shutdown boards ATC continuously energized.

9. DETERMINE if RHR pumps should be stopped:

a. CHECK RCS pressure:

1) Greater than 300 psig

2) STABLE or RISING.

b. CHECK RHR pump suction ATC aligned from RVVST.

c. ENSURE SI signal RESET.

9. d. STOP RHR pumps and PLACE mA-AUTO.

e. MONITOR RCS pressure greater than 300 psig Manually places 1-HS-63-134A and 134B SI Reset to RESET, places 1-HS-74-1OA ATC and 20A RI-IR Pumps A & B to STOP.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5.6

. Page 44 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior NOTE I S/G pressures dropping slowly during a LOCA 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 isolated should be considered stable in the following step.

10. DETERMINE if SI termination criteria should be checked again:

a. CHECK pressure in all S1Gs ATC STABLE or RISING.

b. CHECK RCS pressure STABLE or DROPPING.

11. DETERMINE if diesel generators should be stopped:

a. VERIFY shutdown boards ENERGIZED from start busses.

ATC

b. ENSURE SI signal RESET.

c. STOP any unloaded diesel generators and PLACE in standby USING EA-82-1, Placing D!Gs in Standby.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario # 1 Event # 5.6 Page 45 of 57 Event

Description:

RCP Trip!ATWS/SBLOCA Time

[ Position Applicants Actions or Behavior

12. MONITOR if hydrogen igniters and recombiners should be turned on:

a. ENSURE ice condenser AHU breakers opened USING EA-201-1, 480 V Board Room Breaker Alignments.

b. CHECK hydrogen concentration measurement AVAILABLE:

. Hydrogen analyzers have been in ANALYZE for at least 5 minutes.

ATC 12. c. CHECK containment hydrogen concentration less than 6%.

d. WHEN ice condenser AHU breakers have been opened.

THEN ENSURE hydrogen igniters ENERGIZED USING Appendix D.

e. CHECK containment hydrogen concentration less than 0.5% [M-10j

13. MONITOR if containment vacuum control should be returned to normal:

a. CHECK containment pressure less than 1.0 psig.

ATC

b. VERIFY containment vacuum relief isolation valves OPEN: [Panel 6K]

. FCV-30-46

. FCV-30-47

. FCV-30-48.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2013-301 Scenario # 1 Event# 5,6 Page 46 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time Position Applicants Actions or Behavior

14. 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:

• FCV-63-72 and FCV-74-3 (for RHR Pump A-A).

OR

• FCV-63-73 and FCV-74-21 (for RHR Pump B-B).

ATC b. CHECK Auxiliary Building radiation:

1) Area Radiation Monitors RR901A and RR901B NORMAL.

2) Aux Bldg Vent monitor recorder 0-RR-90-1Q1 NORMAL (prior to isolation).

14. c. MONITOR containment sump level less than 68%.

d. NOTIFY TSC to initiate post-accident sampling as necessary.

e. EVALUATE plant equipment status USING EA-0-4. Evaluation of Equipment Status.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 47 of 57 Event

Description:

RCP Trip!ATWS/SBLOCA Time Position Applicants Actions or Behavior

15. DETERMINE if RCS coodown and depressurization is required:

a. CHECK RCS pressure greater than 300 psig.

SRO

b. GO TO ES-i .2. Post LOCA Cooldown and Depressurization.

Scenario may be terminated when the SRO transitions to ES-1.2 or earlier, at discretion of Lead Examiner.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 48 of 57 Event

Description:

AC P Trip/ATWS/SBLOCA Time 1 Position Applicants Actions or Behavior FR-Z.1 Actions NOTE it mis procedure has been entered Tar an oranqe path and pertormance of ECA-i I (Loss of RHR Sump Recirculation) is required. FR-Z. 1 may be pertonned concurrently with ECA- 1 1.

1. MONITOR RWST level BOP greater Than 27%.

2. VERIFY Phase B valves CLOSED:

BOP Panel 6K PHASE B GREEN

• Panel GL PHASE B GREEN.

3. ENSURE RCPs STOPPED.

BOP

4. DETERMINE if this procedure should be exted:

a. CHECK for faulted S!G: a. GO TO Step 5.

Any SIG pressure DROPPING BOP -

in an uncontrolled manner OR

• Any SIG pressure less than 140 psig.

5. VERIFY containment spray operation:

a. IFECA-i.i. LossotRHRSump Recirculabon, is IN EFFECT.

THEN PERFORM the oI[owing:

1) OPERATE containment spray as directed by ECA- .1

2) GO TO Step 6 BOP

b. VERIFY containment spray pumps RUNNING.

C. CHECK RWST level greater than 27%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5.6 Page 49 of 57 Event

Description:

RCP Trip/ATNS/SBLOCA Time Position Applicants Actions or Behavior 5 d. VERIFY containment spray suction ALIGNED to RWST:

• ECV-72-22 OPEN

• FCV-72-21 OPEN

e. VERIFY containment spray viischarge valves OPEN:

• FCV-72-39 BOP

• FCV-72-2.

f. VERIFY containment spray recirc valves CLOSED:

• FCV-72-34

• FCV-72-13.

g. VERIFY containment spray flow greater than 4750 gpm on each rain.

6. MONITOR containment air return fans:

• WHEN at least 10 minutes BOP have elapsed Irom Phase B, THEN ENSURE containment air return fans RUNNING.

7. VERIFY containment ventilation campers CLOSED:

BOP Panel 5K CNTMT VENT GREEN

• Panel 6L CNTMT VENT GREEN.

8. VERiFY Phase A valves CLOSED:

BOP

• Panel 61< PHASE A GREEN

• Panel i5L PHASE A GREEN.

9. VERIFY critmnt vacuum relief isolation valves CLOSED: [Pnl 6K MANUAL]

BOP FCV-30-46

• FCV-30-47

• ECV-30-48.

10. VERIFY MS:IVs and MSIV bypass valves BOP CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# 5,6 Page 50 of 57 Event

Description:

RCP Trip/ATWS/SBLOCA Time fl Position Applicants Actions or Behavior

. DETERMINE if any SIG Intact:

a. CHECK at least one SJG pressure:

BOP CONTROLLED or RISING AND

• Greater than 140 psig.

CAUTiON lsolatthg 311 SIGs will result in a loss of secondary heat sink.

12. DETERMINE it an SIG Faulted:

a. CHECK ThG pressures: a. GO TO Step 3.

Ajw 510 pressure DROPPING BOP in an uncontrolled manner OR

• Any SJG pressure less than 40 p51g.

13. MONITOR if RHR spray should be placed in service:

BOP a CHECK the Toltcwing a. GO TO Step 14

• Containment pressure greater than 9.5 psig

13. MONITOR if conta:riment Spray should be stopped

a. CHECK any containment spray pump a. GO TO Step 15.

RIJNNING.

BOP

b. CHECK containment pressure b. GO TO Step IS.

less Than 0 psig

15. RETURN TO procedure and step in effect.

BOP END

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 51 of 57 Event

Description:

Equipment Verifications Time H Position Applicants Actions or Behavior ES-O.5 Actions BOP 1 VERIFY D/Gs RUNNING.

BOP 2. VERIFY DIG ERCW supply valves OPEN.

BOP VERIFY at least four ERCW pumps RUNNING.

4. VERIFY CCS pumps RUNNING:

• Pump lA-A (2A-A)

BOP

• Pump I B-B (2B-B)

• Pump C-S.

BOP 5. VERIFY EGTS Tans RUNNING.

6 CHECK main generator output breaker(s):

BOP a. Unit 1 Only:

VERIFY main generator PCBs OPEN. [M-1J

7. NOTIFY at least two AUOs to report BOP to MCR to be available for local actions.

8. VERIFY AFW pumps RUNNING:

a. MD AFW pumps BOP

b. TD AEW pump.

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

or to isolate a faulted 81G.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 52 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior 9 CHECK AFW valve agnment:

a. VERiFY MD APdV LCVs i AUTO.

BOP Ii. VERIFY TD AEW LCVs OPEN c VERIFY MD AFW pump redrcuiation valves f CV-34OO and FCV-3-$O1 CLOSED.

1O VERIFY MFW Isolation:

a. CHECK MEW pumps TRIPPED Ii ENSURE the following:

BOP

• MFW regulating valVes CLOSED

• MEW regulating bypass valve controllers in MANUAL with output ZERO

• MFW solation valves CLOSED.

11. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

• CCPs

• RHR pumps BOP SI pumps b VERIFY CCP ow through CCPIT.

c CHECK RCS pressure less than 1500 psg.

d VERIFY SI pump flow

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # ES-0.5 Page 53 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

e. CHECK RCS pressure e. GO TO Step 12.

less than 300 psg.

t. VERiFY RHR pump flaw.

12. VERIFY ESE systems ALIGNED:

a. Phase A ACTUATED:

• PHASE A TRAIN A alarm LIT

[M-GC, 65].

• PHASE A TRAIN B alarm LIT

[M-6C, 66].

b. Cntmt Vent Isolation ACTUATED:

• CNTMT VENT ISOLATION TRAIN A alarm LIT [M-6C, C5]

• CNTMT VENT ISOLAIION TRAIN B alarm LIT [M-6C, C6]

c Status monitor panels:

BOP

• C DARK

• 60 DARK

• SE LIT OUTSIDE outlined area

• 6HDARK

• 6J LIT.

d. Train A status panel 6K:

• CNTMT VENT GREEN

• PHASE A GREEN

e. Train B status panel 6L:

• CNTMT VENT GREEN

• PHASEAGREEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # ES-0.5 Page 54 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

13. MONITOR for containment spray and Phase B actuation:

a. CHECK for any of the following:

• Phase BACTUATED 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.

3) Containment spray recirculation valves to RWST FCV-72-34 BOP 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. A5j.

• 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. WHEN 10 minutes have elapsed.

THEN ENSURE containment air return fans RUNNING.

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # Event # ES-0.5 Page 55 of 57 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior NOTE The continuous action in Step 14 remains apphcable if containment pressure rises above 1.5 psig after ES-D.5 is completed.

4. MONITOR f contanment vacuum reef isolation valves shcud be dosed:

BOP a. CHECK containment pressure a. GO TO Step 15.

greaterthan l.Spsig.

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

BOP

• Appendix A. Secondary Rad Monitors a Appendix B, Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. IF SI occurred on Unit 1, THEN CHECK following rad monitors including available trends prior to isolation:

• Condenser exhaust recorder l-RR-90-I 19

• S/G blowdown recorder 1 -RR-90-120

• Unit 1 Main steam line rad monitors [i-M-301

• Post-Accident lad recorder 1-RR-90-268B points 3 (blue). 4 (violet)., 5 black), and 6 (turquoise).

i-M-31 (back of i-M-30)J

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH,

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # ES-0.5 Page 56 of 57 Event

Description:

Equipment Verifications Time U Position Q Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS t IF Si occurred on Unit 1, THEN CHECK following rod monitors:

BOP

. Upper containment post-accident rod monitors 1 -RM-90-27 1 A and 1 -RM-90-272A NORMAL [1 -M-30]

• Lower containment post-accident rad monitors i-RM-90-273A and i-RM-90-274A NORMAL [i-M-301

• Contanrnent rad recorders 1-RR-90-i 12 and 1-RR-Si0-106 NORMAL [D-M-12] (prior to solation

16. WHEN directed by E-0, THEN BOP PERFORM Appendix D, Hydrogen Mitigation Actions.

17. CHECK pocket sump pumps STOPPED:

[M-15, upper le cornell

• HS-77-41 C. Rx Bldg Aux Floor and BOP Equipment Drain Sump pump A

• HS-77-4l 1, Rx Bldg Aux Floor and Equipment Drain Sump pump 8.

18. DISPATCH personnel to perrorm BOP BA-U-I, Equipment Checks Following ESE Actuation.

19. ENSURE plant announcement has been BOP made regarding Reactor Thp and SI.

20. PERFORM Appendix E, Spent Fuel BOP Cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2013-301 Scenario# 1 Event# Page 57 of 57 Event

Description:

Critical Task Critical Tasks: Critical Task Statement 1 Manually trip the reactor from the control room prior to completing step 1 of E-O.

2 Manually trip all Reactor Coolant Pumps prior to the completion of step 1 of E-1 during a Small Break LOCA.

Appendix D Scenario Outline Form ES-D-1 Facility: Sequoyah Scenario No.: 3 Op Test No.: 2013-301 Examiners: Operators:

Initial Conditions: Unit 1 is in MODE 2, -.2% Reactor Power, A Main Feedwater Pump I/S Turnover: Continue Plant Startup. Currently at 0-GO-4, Section 5.1 Step 4. Place Feed Regulating valves in AUTO, then increase power to 13-15%.

Target CTs: Manually initiate a Phase B isolation prior to completing ES-0.5 step 13.

Isolate AFW Flow to #1 Steam Generator Prior to completing E-2 step 4.

Event No. MaIf. No. Event Type* Event Description

1. N/A R-ATC Continue Power Increase from -.2%.

1 .a N/A N-BOP/SRO Place feed Reg Valves in AUTO using O-GO-4.Section 5.1 Step 4.

2. IMF NIO4B I-ATC/SRO IR Channel N-36 fails higher than normal, the crew will place N36 Level Trip switch in BYPASS using AOP-l.O1. The SRO will address Tech Specs and enter TS-SRO LCO 3.3.1 .1 Action 3b and 3.3.3.7, Action 1 a.

3. I MF CC1 1 A C-BOP/SRO The 1 A Thermal Barrier Booster Pump breaker trips and the 1 B Thermal Barrier Pre-insert Booster Pump fails to AUTO Start. The BOP manually starts the 1 B Thermal Barrier Booster Pump using the ARP and AOP M.03, LOSS OF COMPONENT IMF CC 21 B COOLING WATER.

4. RX31 AUTO C-ATC/5RO PIC-68-340A Pressurizer Master Controller fails with maximum output. The ATC

,.. will take manual control of PIC-68-340 to close the Pressurizer Spray valves and TS-SR energize Pressurizer heaters. The SRO will address Tech Specs and enter LCO 3.2.5 action.

5. FW23A M-AIl A Feed line break will develop on the #1 Steam Generator inside containment, the crew will initiate a Reactor Trip and Safety Injection and transitions to E-O.

6. Pre-insert C-ATC During the performance of E-O, the Hi-Hi Containment pressure logic to initiate Phase B containment isolation fails. The ATC will manually initiate a Phase B A P07 using prudent operator actions.

7. Pre-insert C-BOP The EGTS fans fail to AUTO-START, the BOP will manually start the EGTS fans using Prudent Operator Actions or guidance from ES-0.5.

ZDIHS6523A (N)ormal, (R)eactivity, (f)nstrument, (C)omponent, (M)ajor

Appendix D Scenario Outline 201 3-301 Scenario 3 Summary EVENT 1 The crew will assume the shift, place the feed reg valves in AUTO using O-GO-4.Section 5.1 Step 4 and continue the power increase.

EVENT 2 When directed by the lead examiner, IR Channel N-36 fails higher than normal, the crew will place N36 Level Trip switch in BYPASS using AOP-l.O1 NUCLEAR INSTRUMENT MALFUNCTION. The SRO will enter LCO 3.3.1 .1 Action 3b and LCO 3.3.3.7, Action 1 a.

EVENT 3 When directed by the lead examiner, the 1A Thermal Barrier Booster Pump breaker trips and the 1 B Thermal Barrier Booster Pump fails to AUTO Start. The BOP manually starts the 1 B Thermal Barrier Booster Pump using the ARP and AOP M.03, LOSS OF COMPONENT COOLING WATER.

EVENT 4 When directed by the lead examiner, PIC-68-340A Pressurizer Master Controller fails with maximum output. The ATC will take manual control of PIC-68-340 to close the Pressurizer Spray valves and energize Pressurizer heaters. The SRO will address Tech Specs and enter LCO 3.2.5 action.

EVENT 5 A Feed line break will develop on the #1 Steam Generator inside containment, the crew will initiate a Reactor Trip and Safety Injection and transitions to E-O REACTOR TRIP OR SAFETY INJECTION. The crew will transition to E-2, FAULTED STEAM GENERATOR ISOLATION and ultimately ES-i .1, SI TERMINATION. When status tree monitoring commences, the crew will identify an orange path condition and implement FR-Z.1 for High Containment Pressure.

EVENT 6 During the performance of E-O, the Hi-Hi Containment pressure logic to initiate Phase B containment isolation fails. The ATC will manually initiate a Phase B using prudent operator actions.

EVENT 7 During performance of the EOPs, the EGTS fans fail to AUTO-START, the BOP will manually start the EGTS fans using Prudent Operator Actions or guidance in ES-O.5, EQUIPMENT VERIFICATIONS.

The scenario terminates as directed by the Lead Examiner upon transition to ES-i .1, SI TERMINATION.

EOP flow: E-O, FR-Z.i, E-2, ES-i .1

Appendix D Scenario Outline Target Quantitative Attributes Required Actual

1. Total malfunctions (58) 6

2. Malfunctions after EOP entry (12) 2

3. Abnormal events (24) 3

4. Major transients (12) 1

5. EOPs entered/requiring substantive (12) 2 actions

6. EOP contingencies requiring O2 0 substantive actions

7. Critical tasks (23) 2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # Page 1 of 48 Event

Description:

Raise plant power to 13-15% RTP Time fl Position Applicants Actions or Behavior Booth Operator: No action required for event 1 Examiner Note: The crew will shift Feed Reg Valves to AUTO using O-GO-4, Section 5.1 Actions To Be Performed Prior To Raising Reactor Power.

5.1 Actions To Be Performed Prior To Raising Reactor Power (continued)

NOTES

1) MEW Bypass valves will be using single element control, which means the desired SG level setpoint will be compared to the actual SG Level until adequate steam and feedwater tow are available. Single Element to Three Element control transition occurs at 13% RIP (.494E6 LBM/HR steam flow per loop).

2) MEW Req valves may have a positive deviation if reactor power is in the upper range of the control band (1-4%) in the following step.

4] PERFORM the foUowing:

[41] ENSURE four MFW Bypass Req valves in AUTO.

[42] ENSURE MEW Reg. valves have minimal controller deviation.

BOP [4.3] ENSURE MEW Req. valves are CLOSED

[4.4] PLACE MEW Req. valves in AUTO.

[4.5] ENSURE MEW valve control mode in 3 Element Enabied (click target located in the center of each screen under the appropriate Loop # Control button)

BOP Depresses AUTO pushbutton for FIC-3-35, 48, 90 and 103 Direct a load increase in accordance with O-GO-4, Reactor Power Ascension To SRO Between 13% And 15% RTP, Section 5.2, and O-SO-62-7 Boron Concentration Control, Section 6.1 or Section 6.2.

Aooendix D Reauired Ooerator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # Page 2 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior NOTES

1) Actions effecting reactivity are directed in the following step 0-SO-62-7 requirements shall be adhered to for reactivity changes (ie reactivity balance, amounts of boric acid or water) All appropriate verifications and peer checks shall be utilized during performance

2) Recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a steady power rise. Rod movement should be limited to 1/2 step increments approximately every 1 1/2 m;nutes. Dilution and rod movement rates may be adjusted depending on SG level control stability

3) Control Rod withdrawal and I or dilution requirements may be significantly impacted by the change in core reactivity due o changing Xenon concentratioti

[3] INITIATE a methodical and deliberate reactor power ascent by CREW manual adjustment of the control banks or by diluting the RCS.

Examiner Note: The following Steps are from 0-SO-62-7 Boron Concentration Control, Section 6.2, Dilute CAUTION I When making an RCS dilution of 3000 gallons, it should be done in batches with an RCS boron concentration verification at the halfway point (e.g., 1500 gallons). Mow at least 15 minutes between batches, [C.5] [C.7)

CAUTION 2 Returning the Boric Acid Blender to service after unplugging, cleaning, or maintenance on the Boric Acid System could introduce debris, sludge. air or chunks of solidified boron into the CCP suction resulting in pump damage. Extreme care must be exercised to properly flush the Boric Acid Blender system following an outage. [C2]

NOTE I If an excessive amount of dilution is required (plant startup), the pressurizer heaters should be energized to cause pressurizer spray operation for equalizing boron concentration in RCS and pressurizer.

NOTE 2 Dilute mode will be used anytime a long-term positive reactivity addition is desired The operator should use the normal dilute mode whenever conditions prrnit Examiner Note: Dilutions will be performed based on the Reactor Engineering provided Reactivity Spreadsheet; based on 0-GO-4 Notes, recommended dilution rate is 50 to 75 gallon batches every 12 to 15 minutes for a steady power increase. During subsequent power escalation, large volume dilutions will be divided evenly over each hour as determined by the crew [i.e.: one-third, one-quarter of the volume over each hours period (e.g.: 60 gallons, 4 times per hour for 240 gallons for the first hour)].

Examiner Note: use time compression as required to facilitate power increase.

ATC [1] ENSURE unit is NQI in a Tech Spec or TRM action that prohibits positive reactivity additions. [C.1]

NOTE: HUT level increase of 1% is equal to 1380 gallons (Tl-28 fig. 34).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # Page 3 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior ATC [2] ENSURE sufficient capacity available in the HUT selected to receive expected amounts of CVCS letdown: (N/A if not used)

HUT LEVEL INITIALS A  %

B  %

ATC [3] ENSURE makeup system is aligned for AUTO operation in accordance with Section 5.1.

ATC [4] RECORD the quantity of dilution water required to achieve desired boron concentration using Appendix D. (N/A for minor power changes)

NOTE Due to eyeball interpolation the verified calculation may slightly differ from the initial calculation. The following signoff indicates that any differences in the two results have been discussed and are close enough to be considered validated.

ATC [5] PERFORM Appendix I Independent Verification of Calculation for Amount of Boric Acid or Primary Water. (N/A if App. D was performed by SRO to verify data from Rx Engineering)

(Step not required provided in shift turnover package)

ATC [6] PLACE IHS-62-140A1, Boric Acid Supply to Blender Flow Control Switch to the STOP position.

ATC [7] PLACE IHS-62-1 4081, CVCS Makeup Selector Switch to the DILUTE position.

ATC [8] ENSURE [HS-62-140D1, Boric Acid Valve to the Blender is CLOSED (Green light is LIT).

ATC [9] SET rFQ-62-1 421, Batch Integrator for the desired quantity NOTE Primary Water Flow Controller [FC-62-1 42] receives its reference signal (70 gpm) from setpoint potentiometer (dial indicator) located on panel M-6. A setpoint of 35% corresponds to a 70 gpm primary water flow rate ATC [10] ADJUST rFC-62-1 421, Primary Makeup Water Flow Controller for the desired flow rate ATC [11] PLACE IHS-62-140A1, Boric Acid Supply to Blender Flow Control Switch to the START position.

ATC [12] VERIFY the following;

[a] Inlet to top of VCT [FCV-62-1281 is OPEN.

[b] Primary Water flow by FFI-62-142A1 OR [FQ-62-1 421.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 1 Page 4 of 48 Event

Description:

Raise plant power to 13-15% RTP Time jI Position fl Applicants Actions or Behavior NOTE Alternate dilution in small amounts is acceptable on a regular basis, provided no significant changes in seal water temperature or seal leakoff are indicated.

Batches of 5 to 10 gallons may be added through FCV-62-144 on a frequency not to exceed once per 30 minutes. ICS points for No. 1 seal leakoffs and seal water temperatures on the RCPs should be monitored during and after dilution.

ATC [13] IF primary water addition to the bottom of the VCT [FCV-62-1441 is desired, THEN ATC [a] CLOSE FFCV-62-1281 with [HS-62-1281.

ATC [b] OPEN [FCV-62-1 441 with IHS-62-1 441.

ATC [C] VERIFY Primary Water flow by rFI-62-142A1 OR [FQ-62-1 421.

NOTE It may take approximately 15 minutes before any changes to reactivity are indicated on nuclear instrumentation or RCS temperature indication.

ATC [14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution.

ATC [15] IF [LI-62-1 291, Volume Control Tank Level, increases to 63 percent, THEN ENSURE [LCV-62-1181, Volume Control Tank Divert Valve OPENS to divert excess water to the Holdup Tanks.

ATC [16] WHEN dilution is complete, THEN

• ATC [a] PLACE FHS-62-140A1, Boric Acid to Blender Flow ControlSwitch to the*

STOP position ATC [b] IF rFCV-62-1 441 was previously OPENED, THEN CLOSE IFC V-62-1 44]

with rHS-62-1 441.

ATC [c] VERIFY no primary water flow on either IFI-62-142A1 OR lFQ-62-1 421.

ATC [d] ENSURE IFCV-62-1 281 is CLOSED ATC [17] IF power increase in progress and additional dilutions will be required, THEN use this table to re-perform steps [4] through [18] (next page)

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 3 Event# 1 Page 5 of 48 Event

Description:

Raise plant power to 13-15% RTP linit 6.2 Dilute (Continued)

[17] [F pcwer ascension in progress and additional dilutions will be required, THEN use this table to repertcmi steps [41 throuqh [1SL

.[t STEP 2

[41 RECORD the quantity of dilution water required to achieve desired boron concentration using Appendix 0.

[5] PERFORM Appendix I, IV of Calculation for amount of BA or PW

[61 PLACE [HS-62-140A1 Boric Acid Supply to Blender Flow Control Switch to the z CV

.J_

1 CV 1 CV STOP position.

[7] PLACE FHS-62-140B], CVCS Makeup Selector Switch to the DILUTE position. U U U

[8] ENSURE [HS-62-140D1 Boric Add ValVe to Blender is CLOSED Green right L1Ti U U U

[9] SET fF042-i 421, Batch Integrator for the desired quantitv J /

tW] ADJUST [FC-62-1421. Primai Makeup Water Flow Contrcller for The desired flow rate. i,-

[11] PLACE [HS-62-140A1, BA Supply to Blender How Control Switch to START I I

C:

[12] VERIFY the followfng:

[a] Inlet to top of VCT [FCV-62-1281 is OPEN. U U U

[b] Prima Water flow by [FI-62-142Aj or [FQ-62-142] U U U

[13] IF PW addition to top of VCT [FCV-62-128j is not warranted, but PW addition to the bottom of the VCT [FCV-62-1441 is desired, THEN

[a] CLOSE [FCV-62-123]wrtfl [KS-62-12S1 U U U

[b] OPEN fFCV-62-1i with [HS42-1]. U U U

[ci VERIFY Primary Water flow by [Fl-62l42A] or [FQ-62-141. U U U

[14] MONITOR nuclear instrumentation and reactor coolant temperature to ensure the proper response from dilution U U U

[15] IF ILI-62-129], VCT level, rises to 63 percent, THEN ENSURE

[LCV$2-1 18],_VCT_Divert Valve,_OPENS to_divert_excess_water to_the_HUTs U U U

[16J WHEN dilution is complete, THEN /

[a] PLACE LHS-62-140A1, Boric. Acid to Blender Flow Control Switch to STOP

[b] IF fFCV42-144] was previously OPENED. THEN CLOSE [FCV-62-1]

with [HS$2-l]. U U U

[c] VERIFY no prima water flow on either iFI-62-l42A1 or [FQ-62-1421 U U U

[d] ENSURE [FCV-62-128] is CLOSED. U U U

[18)IF Step [17J will be repeated THEN PERFORM the following:

[a] PLACE [HS6214G8]; CVCS Makeup Selector Switch to the AUTO position

[b] PLACE [HS-62-14OAj BA to Blender Flow Control Switch to START position.

[c] ENSURE dilution is loqqed in Unit Narrative Loq

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # Page 6 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior ATC [19] REALIGN the blender controls for AUTO makeup to the CVCS in accordance with Section 5.1.

ATC [20] ENSURE dilution(s) is logged in Unit Narrative Log.

NOTE Sample may be obtained at normal RCS sample intervals provided the unit is at power and the unit response following the dilution is as expected.

ATC [21] IF RCS boron sample is required, THEN NOTIFY Chem Lab to obtain RCS boron sample.

Aøoendix D Reciuired Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 1 Page 7 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or behavior O-SO-85-1, Control Rod Drive System, Section 6.4, Transferring from Manual to Auto Rod Control; &

Section 6.5, Transferring from Auto to Manual Rod Control Examiner Note: As stated in each sections procedural Step 1 Note 1, the operators will use a laminated copy of Sections 6.4 & 6.5 available on the book desk under the glass at 1-M-4. It has been verified as current, in-effect revision routinely to assure currency.

NOTES 1:) A laminated copy of this section can be maintained in the Unit Control Room for repetitive use for routne rod manipulations

2) Defeating or restoring Tavg/De[ta T or NIS channel may cause step change in input to rod control. A delay of at least 3 minutes prior to returning rod control to automatic will allow lead/lag signal to decay off.

3) This Section may be N/A if Rod Control is being returned to AUTO in response to a transient (runback) condition.

ATC [1] ENSURE turbine power is greater than 15 percent.

ATC [2] ENSURE Window 31 (E-3), LOW TURB IMPULSE PRESS ROD WITHDRAWAL BLOCKED C-5, Permissive light on panel [XA-55-4A] is NOT LIT.

ATC [3] ENSURE less than 1 degree Tavg/Tref mismatch.

ATC [4] PLACE [HS-85-51 10], Rod Control Mode Selector in the AUTO position.

ATC [5] VERIFY Rod Speed Indicator [SI-412J, indicates 8 Steps/minute.

End of Section 6.4

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O13-301 Scenario# 3 Event# 1 Page 8 of 48 Event

Description:

Raise plant power to 13-15% RTP

[ Time Position Applicants Actions or behavior Section 6.5, Transferring from Auto to Manual Rod Control NOTES

1) A laminated COPY of this section can be maintained in the Unit Control Room fOr repetitive use for routine rod manipulations.

2) r1anuai rod withdrawal is inhibfted by any of the following signals:

A. C-i, High Flux Intermediate Range Monitor

8. 0-2, High Flux Power Range Monitor C. 0-3, Overtemperature Oelta-T D 0-4. Overpower Delta-T ATC [1] PLACE [HS-85-5110], Rod Control Mode Selector in the MANUAL position.

ATC [2] VERIFY Rod Speed Indicator [Sl-412], indicates 48 Steps/minute.

ATC [3] IF control rod movement is required, THEN ADJUST position using [HS 85-5111], Rod Control Switch.

ATC [4] IF it is desired to leave [HS-85-5110], Rod Control Mode Selector in Manual for an extended period of time, THEN PLACE this Section in the Active Procedures Book.

ATC [5] WHEN it is desired to place [HS-85-5110], Rod Control Mode Selector to Automatic, THEN GO TO Section 6.4.

End of Section 6.5

Appendix D Reauired Ooerator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario # 3 Event# 1 Page 9 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior O-GO-4, Section 5.2 Reactor Power Ascension To Between 13% And 15% RTP Examiner Note: Crew will coordinate control rod withdrawal and dilutions based on the Reactor Engineering provided Reactivity Spreadsheet and would coordinate rod withdrawal and dilutions observing the guidance the Step 3 NOTES above.

Examiner Note: Mode change call is made using Loop AT indications on the MCB and ICS, not Nis; Nls may be referred to during the MODE change determination Refer to 0-GO-4 Section 3.1, Precaution C, specifically bullets 2 & 3 (below):

C During startup. NIS power range indication may be reading significantty higher than true power until calibration adjustments are made. The foilowing should be used to determine the most accurate indication for comparison with NIS:

• When reactor power is less than or equal to 15%, use average loop AT (UQ45).

• 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 upto 40%. (ii 1118 will be used above 40% with LEFM unavailable)

[4] WHEN reactor power is above 5%,

ATC THEN LOG Mode 1 entry in the Unit Narrative Log.

ATC would be monitoring the mode change; any crew member may make the initial identification however the SRO should announce transition to MODE 1 based on Loop SRO AT indication. Normally, both MCB and lOS indications are reviewed for MODE transition verification.

Crew member replaces the MODE 2 sign with MODE 1 sign on 1-M-4 under the clock.

[5] MAINTAIN the SG levels on program by periodically adjusting the MFW Bypass controller level setpoints using Appendix B and 1. 2-SO-98-1, Distributed Control System (DCS).

Examiner Note: According to turnover information, the crew will not prepare for nor perform MT roll; Step 6 is N/A for this exam.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # Page 10 of 48 Event

Description:

Raise plant power to 13-15% RTP Time Position Applicants Actions or Behavior

[6] IF Turbine Roll in parallel with power increase is desired, N/A THEN PERFORM Section 5.3 in parallel with the remainder of this section.

[7] IF the intermediate range rod stop setpoint is reached before P-b energizes, AlC THEN

[7.1] STOP the power escalation.

[7.2] CONTACT Reactor Engineering to evaluate power_range calibration. [C.3]

When the crew has sufficiently raised power the Lead examiner may proceed to Event 2.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 3 Event# 1 Page 11 of 48 Event

Description:

Raise plant power to 13-15% RTP Examiner note: The following 5 pages are the guidance for maintaining S/G levels using the DCS (Digital Feed Control).

6.1 Changing MFW Bypass Reg Valve Controller Setpoint With Hand Controller Using the JOG Method NOTES I) With the MFW Bypass Reg Valve controller in auto, SG level setpoints are digitally limited to between 30 and 50%. This action prevents an inadvertent setpoint insertion by the operator from causing too much of a level swing

2) MEW Bypass Reg Valve controller setpoint can NOT be changed when the Turbine Impulse program is in controL Turbine Impulse program wll take control above 27%

during a power rise and reset at less than 23% for a power reduction.

3) SG setpoints can be changed from either the DOS Operator Display monitor or the hand controller station.

4) Two handed operation will he required to change the SG controller setpoint, when using the hand controller.

5) Setpoint push button will change from gray to red on the Hand Controller and the DCS Operator Display monitor.

[1j PRESS and HOLD SETPQINT push button for applicabte Bypass Reg Valve (N/A valves not operated)

SIG UNID INITIALS 1 I-LIC-.3-35 2 l-LIC-3-48 3 t-LIC-3-90 4 1 -LI 0-3-103

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 1 Page 12 of 48 Event

Description:

Raise plant power to 13-15% RTP NOTE The following method (JOG method) will cause the setpoint to change in 05% increments each time the button is pressed The push buttons are momentary contact closure type SO continuously holding the push button down will NOT change the setpoint, The push button will have to be released and then pressed again to change the setpoint.

[2] PRESS either the raise () or the lower (<<:) push buttons to obtain the desired setpoint (N/A valves not operated):

SIG UNID lNALS 1 i-LtC-3-35 2 i-LlC-3-48 3 i-LIC-3-90 4 1-LiC-3-103

[3] RELEASE the SETPOINT push button (NA valves not operated).

SIG UNID INITIALS I 1-110-3-35 2 1 -LlC-3-48

3 i-LlC-3-gO 4 1-110 103

[4] REPEAT Steps 6 I [iJ-fi 1 [31 as necessary to maintain S!G level in desired range.

End of Section

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 1 Page 13 of 48 Event

Description:

Raise plant power to 13-15% RTP 6.2 Changing MFW Bypass Reg Valve Controller Setpoint With DCS Operator Display Monitor NOTES

1) With the MFW Bypass Reg Valve controller in auto, SG level setpoints are digitally limited to between 30 and 50%. This action prevents an inadvertent setpoint insertion by the operator from causing too much of a level swing.

2) MFW Bypass Reg Valve controller setpoint can NOT be changed when the Turbine Impulse program is in control. Turbine Impulse program will take control above -27%

during a power rise and reset at less than -23% for a power reduction.

3) SG setpoints can be changed from either the DOS Operator Display monitor or the hand controller station.

4) Setpoint push button vvill change from gray to red on the Hand Controller and the DOS Operator Display monitor.

[1) SELECT the appropriate feedwater controller display screen from either DOS Operator Display monitors (N!A valves not operated).

LOOP UNID INITIALS 1 1 -LIC-3-35 2 1-LIC-3-48 3 1 -LIC-3-90 4 1-LIC-3-103

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 3 Event# 1 Page 14 of 48 Event

Description:

Raise plant power to 13-15% RTP 6.2 Changing MFW Bypass Reg Valve Controller Setpoint With DCS Operator Display Monitor (continued)

[2] SELECT the SETPOINT push button for applicable Bypass Reg Valve (N/A others).

LOOP UNID INITIALS 1 1-LIC-3-35 2 1-LIC-3-48 3 1-LIC-3-90 4 1-LIC-3-103 NOTE Using the JOG method will cause the setpoint to change in 0.5% increments each time the button is pressed. The push buttons are momentary contact closure type. so continuously holding the push button down will NOT change the setpoint. The push button will have to be released and then pressed again to change the setpoint.

[3] IF using the JOG method (preferred).THEN SELECT either the raise (>)or the lower (<1) push buttons to obtain the desired setpoint. 0 NOTES

1) The RAMP method of changing Bypass Reg Valve setpoints is NOT preferred. This is due to the large rate of change in valve position.

2) Using the RAMP push button along with the raise (>) or the lower (<1<]) push buttons will cause the setpoint to change at a rate of 1.67% per second. A change of 0%-100% would take approximately 1 minute.

[4] IF using the RAMP method, THEN SELECT the raise (>>)or the lower (<1<) push button to obtain the desired setpoint. 0

[5] WHEN the desired setpoint is obtained. THEN CONFIRM SETPOINT is correctly displayed on the screen. 0

[6j SELECT the SETPOINT push button. 0

[1 CONFIRM SETPOINT push button changes from red to gray. 0 End of Section

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario# 3 Event# 2 Page 15 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 2 IR Channel N-36 Fails Indications available:

. 4B B2 IPRS NIS Intermediate Range HI FLUX LVL ROD WITHDRAWAL STOP

• Control Rod motion stops, if in progress.

. Intermediate Range Instrument N-36 is greater than N-35 RS INTERMED RANGE HI FLUX LVL ROD WITHDRAWAL STO P

[ROTE Conro rods will not withdraw ir mr or ziornatfc.

Corrective [II CHECK reactor pcwer [eveL Actions

[21 REDUCE reactor powero < 2Q%.

[31 BLOCX ntered[at range high fIu ip and pcwr range high flus wp iow setpoint).

[4] LF ir rrnedia., Range channel fiId. THEt4 GO TO AOP-LD1. N&oear (n.t,vrnent Maffunctron Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to alarm using ARP 1 -AR-M4B, B2 ATC May take action using ARP to block the Low Power PR and IR Ni Trip.

SRO Transitions to AOP-LO1, Nuclear Instrument Malfunction.

. DIAGNOSE The failure:

SRO Directs actions using AOP-l.O1, Nuclear Instrument Malfunction.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 2 Page 16 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time Position Applicants Actions or Behavior CAUTION 1 if reactor power is below P-6 (i0 %), Tech Specs require restoring inoperable channel prtor to raising power above P-S.

CAUTION 2 If reactor power is above P-S but below 5% power, Tech Specs require restoring inoperable channel prior to raising power above 5%.

NOTE 1 If Intermediate Range channel is failed high, reducing reactor power to less than P-b (i0% will result in a reactor trip. If control power is available. this condition will be corrected when the channel is bypassed in Step 6.

NOTE 2 If any IR channel has failed high, then automatic re-enabling of Source Range indication may be disabied. (SRMS may require manual reinstating in ES-C. 1.)

NOTE 3 FaIure of Intermediate Range Channel may affect associated Source Range Channel.

1. iF unit is in Mode 2, SRO THEN STABILIZE reactor power at current level.

1 EVALUATE the foliowing Tech Specs for applicability:

. 3.3.1.1 (3.3.1), Reactor Trip System Instrumentation

. 33.3.5, Remote Shutdown SRO Instrumentation

• 3.3.3.7, Accident Monitoring Instrumentation

. 3.9.2, ReNding Operations Instrumentation Enters LCO 33 1 1 Action 3 and 333 7, Action 1, enters LCO 33 1 1 Action SRO 8a if still in MODE2

3. CHECK at least one Intermediate Range ATC channel OPERABLE.

CAUTIONS:

• Loss of instrument OR control power will cause a single channel reactor trip signal.

• or loss of control power only, the reactor trip signal cannot be bypassed.

Reducing reactor power below P-IC will result in a reactor trip.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # 2 Page 17 of 48 Event

Description:

IA Channel B Instrument N-36 Fails Time I Position fl Applicants Actions or Behavior NOTE: The foIlowng table lists Intermediate Range NIS power supplies:

INSTRUMENT CONTROL N S C HANNE L POWER POWER

/IPS 1-I (2-i) VIPB 1-I (2-)

N 8kr3 Bkr4 VIPB iIl C-Il) VIPS Ili (2-Il)

N 3 81cr 3 8kr4 4 CHECK power available to railed Intermediate Range channel: [M- 13]

. INSTRUMENT POWER ON ndicator LIT ATC AND

• CONTROL POWER ON ndicator LIT

5. IF required to mornt*or IR channel on NR-45 recorder.

ATC THEN ENSURE OPERABLE IR channel selected on NR-45 Recorder. [M-41 S. PLACE Level Trip switch for failed channel ATC in BYPASS [M-13. N351N36].

ATC Places N-36 Trip Level Bypass switch to BYPASS )

7. IF control power is available, THEN PERFORM the following:

a. VERIFY MS TRIP BYPASS annunciator LIT [M-6A, A-I]

Ii VERIFY appropr!ate annunciator LIT:

. INTERMEDIATE RANGE TRIP BYPASS CHANNEL I [M-4A. A-2)

OR

. INTERMEDIATE RANGE TRIP BYPASS CHANNEL II [M-4A. B-2]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O13-301 Scenario# 3 Event# 2 Page 18 of 48 Event

Description:

IR Channel B Instrument N-36 Fails Time Position Applicants Actions or Behavior

8. CHECK assocbted Source Range Channel NOT affected.

9 GO TO appropflate plant procedure.

Crew Performs a Crew Brief as time allows.

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

Crew 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 N-36 Trip Level switch has been placed in bypass.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 3 Event# 3 Page 19 of 48 Event

Description:

1 A Thermal Barrier Booster Pump Breaker Trips Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 3, 1A Thermal Barrier Booster Pump Trip Indications available:

O-M-27-B-A Annunciators:

. O-XA-27-B-A Window B-i: RC PUMPS THRM BARRIER RETURN HEADER FLOW LOW

. O-XA-27-B-A Window B-2: RC PUMP i BARRIER Outlet FLOW LOW

. O-XA-27-B-A Window B-3: RC PUMP 2 BARRIER Outlet FLOW LOW

. O-XA-27-B-A Window B-4: RC PUMP 3 BARRIER Outlet FLOW LOW

. O-XA-27-B-A Window B-5: RC PUMP 4 BARRIER Outlet FLOW LOW RC PUMPS THRM BARRIER RETURN HEADER FLOW LOW

[1] CHECK CCS thermal banter return header flow by cbserAmg 11-FL-7381 Al.

[2] IF pressure on CCS dictates. THEN

[al START standby COS pump.

[b] VERIFY CCS thermal barrier booster pumps operabng

[3] IF O-XA-55-i2A indo B-i 1-R-9O-i23A CCS UC EFF MON HtGH FAD Is alarming, THEN REFER to O-ARM12-A. [C.l1

[4] VERiFY CCS riermal baffler isolaen aes l-FCV-7C-!J, I-FC\-7D-133, 1-FCV-70-67, and t-FCY-70-;34 are OPEN.

[aJ IF CCS to FOP thermal harrier cooling coils has isolated, ThEN ENSURE Unit I CCS thermal barrier booster pump handswitsbes are in the stop PULL TO LOCK position AND GO TO AOP-1.O3. Loos of Component Cooing Water fora loss of Component Cooling Thermal Barrier Booster Purnpis

[C.1]

BOP Responds to ARP O-AR-M27B-A B-i.

May place HS-70-1 30A Thermal Barrier Booster Pump 1 B-B to START and BOP HS-70-131A Thermal Barrier Booster Pump lA-A to STOP based on prudent operator actions.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

SRO Transitions to AOP-M.03 Loss Of Component Cooling Water section 2.2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # 3 Page 20 of 48 Event

Description:

1 A Thermal Barrier Booster Pump Breaker Trips Time fl Position Applicants Actions or Behavior DIAGNOSE the failure:

r HIF... SECTION PAGE CCS Thermal Barrier Booster Pump trip or failure 2.2 13 NOTE If RCP seat injection ow is lost concurrently with loss of thermal barrier cooling, then AOP-M. 09 (Loss of Charging) takes preceence over AOP-M.03.

IDENTIFY and LOCK OUT affected Thermal BOP Barrier Booster Pump.

.. BOP Places HS-70-l3lATherma[Barrier Bóóster Pump lA-A to STOP PTL.

2. CHECK Thermal Barrier isolation valves OPEN:

• FCV-70-87 BOP

• FCV-70-90

• FCV-70-l 33 a FCV 34

3. ENSURE standby Thermal Barrier Booster BOP Pump starts.

IIiirIII BOP IL Places HS-70-1 30A Thermal Barrier Booster Pump I B-B to START if not already done

4. ENSURE proper RCP seal injection:

• Flow between 8 gpm and 13 gpm BOP

• VCT outlet temperature less than or equal to I 3OF 3 MONITOR RCP Seal and Lower Bearing BOP temperatures less than or equal to 225F.

6. MONiTOR CCS radiation levels STABLE or DROPPING:

BOP

• RA90I2:3A, OCS Liquid Effluent Monitor a Chernisti Sample

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 3 Page 21 of 48 Event

Description:

1 A Thermal Barrier Booster Pump Breaker Trips Time Position Applicants Actions or Behavior

7. NOTIFY SM to evaluate O:PDP9 Emergent Issue Response.

SRO S. INITiATE Maintenance as required.

CAUTION Automatic isolation of the thermal barrier can be caused by a heat exchanger tube leak. Realignment of the thermal barrier may cause additional leakage.

9. CHECK thermal bamer cooling in service BOP to atfecte unit.

10. GO TO appropriate plant procedure SRO END OF SECTION Crew Performs a Crew Brief as time allows.

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

Crew Operations Management Typically Shift Manager.

Maintenance Personnel Typically Maintenance Shift Supervisor (MSS).

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

Evaluator Note: Proceed to the next event when ready

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # 4 Page 22 of 48 Event

Description:

Pressurizer Master Controller Fails With Maximum Output Time Position Applicants Actions or Behavior Direct the Simulator Operator to initiate Event 4 Pressurizer Master Controller Fails With Maximum Output Alarms 1-M-5

. 5A B-3 PS 68 340F!G PRESSURIZER PRESS ABOVE REF SET POINT Indications 1-M-4

. RCS Pressurizer Main Spray Valves OPEN

. 1-PI-68-334, 323, 322 RCS PZR PRESS indicators decreasing Time Position Applicants Actions or Behavior P S-68-340 FIG PRESSURIZER PRESS ABOVE REF SET POINT

[1] CHECK pressurizer pressure.

2j IF channel failed, THEN GO TO OP-L34, Pressurizer instrument Malfuncon.

[31 IF pressurizer pressure high THEN PERFORM the fc4tcwing:

[al ENSURE pressurizer hearers OFF.

0] ENSURE pressurizer spray vaIes OPEN.

i ADJUST plant paraneters as imesessar,.

41 EVALuATE TS 13.1. 3.3.2. 3.13.5.

Examiner Note: Several steps, notes, and cautions in the Annunciator response procedure do not apply to this failure. Only those that are applicable are listed in this event guide.

ATC Responds to alarm using ARP 1 -AR-M5A, B3 Places PIC-68-340A, Master Pressure Controller in MANUAL and lowers output.

OR ATC Places PZR Spray controllers PIC-68-340D (Loop 1) and PIC-68-340B (Loop 2) and lowers output.

Using immediate operator actions (lOAs)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 3 Event # 4 Page 23 of 48 Event

Description:

Pressurizer Master Controller Fails With Maximum Output Time Position Applicants Actions or Behavior L SRO Transitions to AOP-l 04 Pressurizer Instrument And Control Malfunctions NOTE: It spray valve is open cfue to pressure instrument failure, then Section 2.3 is the appropriate entry point.

DIAGNOSE the faiIure GOTO IF.,. SECTION PAGE Pressurizer Pressure Instrument OR Controller Malfunction 2.3 11 NOTE Step I is an IMMEDIATE ACTION.

1 CHECK normal spray valves CLOSED, IF RCS pressure s less than 2250 psig.

THEN CLOSE affected spray valve(s)

USING the following:

. PlC-38-340A, Master Pressure Controller.

SRO OR

. PZ spray controllers PIC-68-340D (Loop 1) and/or PIC-t38-340B (Loop 2).

Places Master Pressure Controller in MANUAL OR Spray controllers PlC ATC 68-340D (Loop 1) and PIC-68-340B (Loop 2) in MANUAL if not already performed during IOAs

, 2. MONITOR pressurizer pressure stable or RESTORE pressunzer pressure trending to desired pressure. USING manual control of the following:

. PIC-68-340A, Master Pressure Controller.

OR ATC . PZR Spray controllers PIC-68-340D (Loop 1) and/or PIC-63-3408 (Loop 2)

OR

. Pressurizer Heaters.

ATC May energize additional Pressurizer heaters NOTE: Appendix L shows layout of PZR pressure ccntro[ for operator reference.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # 4 Page 24 of 48 Event

Description:

Pressurizer Master Controller Fails With Maximum Output Applicants Actions or Behavior

3. CHECK Pl-68-340A NORMAL.

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.

ATC 4. CHECK P1-68-334 NORMAL.

NOTE: A failure of channel III (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).

ATC 5. CHECK P1-68-323 NORMAL.

NOTE: A failure of channel I! (P-68-322) will affect the automatic actuation of PCV-68-340A, PZR PORV, in the normal pressure control circuit. LTOPS operation of this POR\/ is unaffected by this failure (except when PORV handswitch is in CLOSE position).

ATC 6. CHECK P1-68-322 NORMAL.

7. CHECK for PIC-68-340A Pressure Controller malfunction:

a. NOTIFY l&C to determine and correct ATC the cause.

b. NOTIFY Duty Operations Manager of the situation.

CAUTION RCS pressure changes and changes in RCS boron concentration (clue to differences between pzr and RCS boron> may cause small change in core reactivity.

. MONITOR reactor power:

a. CHECK reactor in Mode 1 or 2.

ATC

b. MONITOR core thermal power for unexpected changes.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 3 Event # 4 Page 25 of 48 Event

Description:

Pressurizer Master Controller Fails With Maximum Output Time Position Applicants Actions or Behavior

9. EVALUATE the following Tech Specs for applicability:

. :3.2.5 DNB Parameters

. 3.3.1. 1 (3.3.1). Reactor Trip Sstem SRO nstft1mentation

. :13.2.1 (3.3.2). SF Actuation System nstrumenlation

. 3.3.3.5 Remote Shutdown nstru mentation 3.2.5 The foiowg DNB e1ated per shai: be n. niro wthn the bm owt on Te 32:

a. Reaoto Coolant ysteo, 1RCS)T

0. PressunoerPeaaure

o. CS Thtal Flow Rate ARPLICABIUTY: 1ODE 1 ACT.ON:

Nih any of the above oarametecs exceeng 1s limit, reaoe the orarnte to within 1s tmit withn 2 houra o redtow THERhAL POWER to eas than 5% of RATED ThERMAL POWER thin te nCt SRO 4ours.

LI Mt3 4 Lcops itt AR4METER Opetolion ReaotorCooUnt 3ysten T -

Fessurzer Presstre 2230 os Reactor Ooo.ari Systent F..re 32.1 Total Flow If in MODE 1 enters LCO 325 ActIon if Pressurizer Pressure decreases to SRO less than 2220 psia

10. CHECK PZR PRESS and PZR SPRAY WHEN malfunction has been idenfied controllers in AUTO. AND isolated or corrected, THEN PERFORM the foflowing:

Lead Examiner may cue next event when Pressurizer Pressure control is established in MANUAL and Tech Specs are identified.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # 5,6,7 Page 26 of 48 Event

Description:

1. 1 SG FWLB Inside ContlFailure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior Simulator Operator: When directed, initiate Event 5 #1 Steam Generator Feed Line Break Inside Containment.

Indications available:

Annunicators:

1-M-3

• 3A, E-1, PS-2-129 LOW NPSH AT MFPS 1-M-5

• 5A, A-7, FS-3-35A STEAM GEN FEEDWATER FLOW HIGH

• 5A, B-7, LS-3-42D STEAM GEN LVL HIGH-LOW DEVIATION

• 5C, B-3, MS-30-241 LOWER COMPT MOISTURE HI 1-M-6 1-M-6

• 6B, C-6, CONTAINMENT HI-HI PRESSURE SPRAY ACTUATION Indicators:

1-M-4

• SG-1 FW INLET FLOW increasing

. SG-1 NR LEVEL: decreasing level SRO Transitions to E-O and Direct Immediate Operator Actions (IOAs)

Examiner Note: following lOA pertormance, prior to Steps 1-4 immediate action verification, ATC/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)

CREW Performs the first four steps of E-O unprompted.

SRO Directs performance of E-O NOTE 1 Steps 1 through 4 are mmedIate action steps NOTE 2 This procedure has a loldout page.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5.6,7 Page 27 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time fl Position Applicants Actions or Behavior

1. VERIFY reactor TRIPPED:

• Reactor trip breakers OPEN

• Reactor trip bypass breakers D1SCONNECTED or OPEN ATC

• Rod bottom lights LIT

• Rod position indicators less than or equal to 12 steps

• Neutron flux DROPPING

2. VERIFY turbine TRIPPED:

BOP Turbine stop valves CLOSED.

3. VERIFY at east one 6.9KV shutdown BOP board ENERGIZED on this unit.

4. DETERMINE if SI actuated:

ATC ECCS pumps RUNNING

• Any SI alarm LIT [M-4DJ.

CRITICAL Places HS-30-64A and 648 Phase B and CNTMT Vent Isol to ACTUATE BOP TASK 5 PERFORM ES-OS, Equipment BOP Verifications WHILE continuing in this procedure.

Continue with the performance of E-O REACTOR TRIP OR SAFETY SRO/ATC INJECTION BOP Performs ES-O.5, Equipment Verifications go to page 42 for details SRO Addresses foldout page, see next page for details.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.; NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 28 of 48 Event Description; #1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure FOLDOUT PAGE RCP TRIP CRITERIA IF any of the following conditions occurs:

• RCS pressure less than 1250 psig AND at least one COP or SI pump running OR

• Phase B isolation.

THEN STOP all RCPs EVENT DIAGNOSTICS a IF any SIG pressure is dropping uncontrolled, THEN PERFORM the following:

a CLOSE MSIVs and MSIV bypass valVes.

b. IF any SJG pressure continues to drop uncontrolled, THEN PERFORM the following:

1) ENSURE SI actuated

2) F at least one S/G is intact (SiG pressure controlled or i1sng),

THEN ISOLATE AFW to faulted S1G(s):

• CLOSE AFW level control valves for faulted SIG(s)

• IF any AFW valve for faulted SJG CANNOT be CLOSED, THEN PERFORM Appendix E, Isolating AFW to Faulted S/G

3) ENSURE at least one of the following conditions met:

• total AFW flow greater than 440 gpm OR a Narrow Range level greater than 0% [25% ADVI in at least one intact S/G

• IF both trains of shutdown boards de-energ[zed, THEN GO TO ECA-O0, Loss of All AC Power.

TANK SWITCHOVER SETPOINTS

• IF OST level less than 5%, THEN ALIGN AFW suction to EROW.

• IF RWST level less than 27%, THEN GO TO ES-i 3. Transfer to RHR Containment Sump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 29 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior CRITICAL Places HS-3-164A, AFP lA-A LCV to SG-l to ACC RESET then CLOSE TASK ATC/BOP Places HS-3-174A, SG-l Turbine AFP LCV to CLOSE.

6 DETERMINE if secondary heat sink available a CHECK total AFW flow a. IF SIG narrow range level is greater than 440 gprn. less Than 10% [25% ADV] in all S/Gs, THEN START AFW pumps and ALIGN valves as necessary to raise AFW flow greater Than 440 gpm.

ATC

b. CHECK narrow range level b MAINTAIN total feed ficw greater than 10% [25% ADVJ greater than 440 gprn in at least one S!G. UNTIL narrow range level greater than 10% [25% ADV]

in at least one SIG.

c. CONTROL feed flow to maintain narrow range level between 10% [25% ADVJ and 50%

in intact or ruptured SJGs.

Manually controls AFW flow to maintain total AFW flow greater than 440 gpm ATC/BOP until S/G are greater than 10% (25% ADV) NR.

7 CHECK if main steam hnes 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 ATC UNCONTROLLED OR

. Phase B actuation.

b. ENSURE MSIVs and MSIV bypass valves CLOSED.

c. ENSURE applicable Foldout Page actions COMPLETED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 1 Event # 5, 6, 7 Page 30 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase BIEGTS Auto Start Failure Time Position Applicants Actions or Behavior

8. CHECK RCP trip criteria:

a. CHECK the following:

. RCS pressure less than 1250 psig ATC AND

. At least one COP OR SI pump RUNNING.

b. STOP RCPs.

9. MONITOR RCS temperatures: IF temperature less than 547F and dropping, IF any RCP running, THEN THEN PERFORM the following:

CHECK T-avg stable at or trending to between 547F and 552F. a. ENSURE steam dumps and atmospheric reliefs CLOSED.

OR

b. IF cooldown continues, IF RCPs stopped. THEN THEN CONTROL total feed flow:

CHECK T-cold stable at or trending 1) ENSURE total AFW flow ATC/BOP to between D47F and D52F.

less than or equal to 600 gpm

2) MAINTAIN total AFW flow greater than 440 gpm UNTIL narrow range level is greater than 10% [25% AD\!]

in at least one SIG.

c. IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs and MSIV bypass valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 31 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior Manually controls AFW flow to maintain total AFW flow greater than 440 ATC/BOP gpm and less than 600 gpm until SIG are greater than 10% NR.

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

a. Pressurizer PORVs CLOSED.

b. Pressurizer safety valves CLOSED.

ATC c. Normal spray valves CLOSED.

d. Power to at least one block valve AVAILABLE.

e. At least one block valve OPEN.

It. DETERMINE t S/G secondary pressure PERFORM the following:

boundanes are 1NTACT:

a. MONITOR status trees.

• CHECK all SIC pressures ATC CONTROLLED or RISING. b. GO TO E-2. Faulted Steam Generator isolation.

• CHECK all SIC pressures greater than 140 psig.

Examiner Note: MONITOR status trees, the crew will implement status tree monitoring via ICS. When a RED or ORANGE path status tree is observed, the SRO will designate one of the Board operators (typically the BOP) to verify status tree conditions using 1-FR-O, UNIT 1 STATUS TREES. Once verified, the SRO should direct the crew to transition to the appropriate RED and/or ORANGE path procedure(s).

When a RED Path for Containment is evident on lOS, the SRO will transition to FR-Z.1, go to page 39 for details.

SRO Transitions to 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 ATC CLOSED.

2 CHECK ANY 510 secondai pressure boundary INTACT:

BOP

. Any S/G pressure CONTROLLED or RISING.

Apjendix D Required Orjerator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event# 5,6,7 Page 32 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior

& IDENTIFY Faulted S/G(s):

a. CHECK SIG pressures:

• Any SIG pressure DROPPING SRO n an uncontrolled manner.

OR

• Any SIG pressure less than 140 psig SRO Identifies #1 SIG as faulted CAUTIONS

• secondary heat sink requires at [east one SIG available.

• If the TO AFW pump is the only source of feed flow, isolating both steam supplies will result in loss of secondary heat sink.

& ISOLATE Faulted SJG(s):

a ENSURE MFW isolated to taulted S/G(s by any of the following:

• teedwater solation valve BOP CLOSED [M-4J CR

• feedwater regulating valve and bypass valve CLOSED [M-3[

b. ENSURE AFW isolated to faulted S/

BOP

• CLOSE MD AFW LCV a CLOSE TD AEW LCV and PLACE in PULL TO LOCK.

CRiTICAL Places HS-3-164A, AFP lA-A LCV to SG-l to ACC RESET then CLOSE TASK ATC/BOP Places HS-3-l 74A, SG-l Turbine AFP LCV to CLOSE.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event# 5,6,7 Page 33 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time i Position Applicants Actions or Behavior c.. CHECK S/G #1 or #4 faulted.

BOP

d. CLOSE TD AFW pump steam supply from faulted S/G CV-l-i5(SIG#l) or FCV- 1-16 iS/G #4)

BOP Places HS-1i5Ato CLOSE 4 e VERIFY S/G blowdown aIves CLOSED.

BOP f VERIFY atmospheric relief CLOSED.

5 CHECK CST level greatel than 5%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # Event# 5,6,7 Page 34 of 48 Event

Description:

1. 1 SG FWLB Inside ContlFailure of Phase BIEGTS Auto Start Failure Time Position Applicants Actions or Behavior

6. VERIFY secondarj radtion NORMAL:

a CHECK secondary radiation NORMAL USING Appendix A. Secondary Rad Monitors.

App. A also contained in ES-0.5)

h. NOTIFY Criern Lab to take SIG aciMfy samples.

c. WHEN Chem Lab is ready to sample S/Gs, THEN PERFORM the lollowing:

BOP

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.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event# 5,6,7 Page 35 of 48 Event

Description:

1. 1 SG FWLB Inside ContJFailure of Phase BIEGTS Auto Start Failure Time Position Applicants Actions or Behavior

7. CHECK Si termination criteria:

a. RCS subcooiing based on core exit T/CS greater than 40cF.

b. Secondaiy heat sink:

Narrow range level

n at least one intact SIC greater than 10% [25% AOVJ OR ATC

• Total feed how to intact S/Os greater than 440 gpm

c. RCS pressure stable or rising.

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

e. GO TO ES-i .1. SI Termination.

SAC Transitions to ES-i .1, SI TERMINATION.

SAC Directs actions from ES-i.i, SI TERMINATION NOTE ThIs prccedure has a foldout page.

SRO Addresses FOP, see next page

Appendix D Regufred Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 36 of 48 Event

Description:

1. 1 SG FWLB Inside ContlFailure of Phase B/EGTS Auto Start Failure FOLDOUT PAGE SI REINATION CRITERIA IF SI has been terminated (CCPIT isolated, SI pumps stopped, and RHR pumps NOT running n ECCS mode)

AND eaher of the following conditions occurs:

• RCS subcooling based on core exit T/Cs less Than 40F CR

• Pressurizer level CANNOT be maintained greater than 10% f20% ADV],

THEN

a. ESTABLISH ECCS flow by pellorn9ing one or both of the following:

• ESTABUSH CCPJT flow as necessary USING Appendix C

• START CCPs or SI pumps manually as necessary.

b GO TO E- I, Loss of Reactor or Secondary Coolant.

EVENT DIAGNOSTICS

• IF both trains of shutdown boards dc-energized, THEN GO TO ECA-00, Loss of All AC Power.

• IF any SIG pressure dropping in an uncontrolled manner or less than 140 psig AND 5/0 NOT isolated.

THEN GO TO E-2. Faulted Steam Generator ls.olation TANK SW1TCHOVER SETPOINTS

• IF CST level less than 5%.

THEN ALIGN AFW sucton to ERCW.

• IF RWST level less than 27%,

THEN GO TO ES-t3, Transferto RHR Containment Sump

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 37 of 48 Event

Description:

1. 1 SG FWLB Inside Cont/Failure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior

1. MONITOR if containment spray should be stopped:

a. CHECK any containment spray pump RUNNING.

ATC

b. CHECK containment pressure less than 2.0 psig.

2 DETERMINE if one cntmt spray pump should be stopped:

a. CHECK BOTH cntmt spray pumps RUNNING.

b. CHECK any SIG faulted:

• any S/G pressure dropping UNCONTROLLED OR

• any S[G pressure less than 140 psig

c. CHECK containment spray suction aligned to RWST.

ATC

d. RESET containment spray signal for cntmt spray pump to be stopped.

e. STOP one cntmt spray pump and PLACE in A-AUTO.

f. CLOSE containment spray discharge valve for stopped pump:

• FCV-72-39 (Train A)

OR

• FCV-72-2 (Train B).

g. MONITOR one cntmt spray pump RUNNING and delivering flow.

Places 1-HS-72-43 and 1-HS-72-42 Containment Spray Reset to ATC RESET

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 1 Event # 5, 6, 7 Page 38 of 48 Event

Description:

1. 1 SG FWLB inside ContlFailure of Phase B/EGTS Auto Start Failure Time Position Applicants Actions or Behavior ATC Places 1-HS-72-27A and 10 A to Containment Spray pumps to STOP ATC 3. RESET SI signal.

ATC Places 1 -HS-63-1 34A and 1 -HS-63-1 34B SI Reset to RESET

4. MONITOR shutdown boards ATC COflt!flUOUSIV energized.

5. ENSURE oni one COP RUNNING:

a CHECK otfsite power supplyng shutdown boards.

ATC

b. STOP all BUT one COP and PLACE in A-AUTO,

6. CHECK RCS pressure ATC STABLE or RISING.

ATC Places one Charging Pump 1-HS-63-108A or 104A to STOP

7. ISOLATE CCPIT:

a CLOSE CCPIT inlet valves FCV-6:3-39 and FCV-63-40.

b CLOSE CCPIT outlet valves FCV-6:3-25 and FCV-63-26.

ATC

c. VERiFY CCPIT flow isolated:

a FOV63-39 and 40 CLOSED OR

. FCV-63-25 and 26 CLOSED.

ATC Places 1 -HS-63-39A and 1 -HS-6340A CCPIT inlet valves to CLOSE.

Lead Examiner may terminate the scenario at ES-i .iStep 7, CCPIT isolation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 5 Event # 5 Page 39 of 48 Event

Description:

1. 1 Steam Generator FWLB IS ContlFailure of Phase B/Failure of EGTS Auto Start.

Time fl Position Applicants Actions or Behavior FR-Zi Actions NOTE If this procedure has been entered far an orange path and perFormance of ECA-l 1 Loss of RHR Sump Recirculation) is required, FR-Z. I may be performed: concurrently with ECA-I.1.

1. MONITOR RWST level ATC/BOP greater than 2T%

2. VERIFY P:hase B valves CLOSED:

ATC/BOP Panel 6K PHASE B GREEN

• Panel 6L PHASE B GREEN.

3. ENSURE RCPs STOPPED.

ATC/BOP

4. DETERMINE it This procedure should be exited:

a. CHECK tar faulted SIG: a GO TO Step 5.

Any 5/0 pressure DROPPING ATC/BOP in an uncontrolled manner OR

• Any 5/0 pressure less t.han 140 psig.

5. VERIFY containment spray operation:

a. IF ECA-! .1, Loss of RHR Sump Recirculation, is [N EFFECT, THEN PERFORM the tol[owing:

1) OPERATE contanmenI spray as directed by ECA- I. 1, 2 GO TO Step 6 ATC/BOP

b. VERIFY contamment spray pumps RUNN1NG.

c. CHECK RWST level greater than 27%.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Senario # 5 Event # 5 Page 40 of 48 Event

Description:

1. 1 Steam Generator FWLB IS Cont/Failure of Phase B/Failure of EGTS Auto Start.

Time Q Position Applicants Actions or Behavior

5. d. VERIFY containment spray suction ALIGNED to RWST:

• FCV-72-22 OPEN

• FCV-72-2 I OPEN.

e. VERIFY containment spray discharge valves OPEN:

• FCV-72-39 ATC/BOP a FCV-72-2.

if. VERIFY containment spray recirc valves CLOSED:

a FCV-72-34

• FCV-72-13.

g. VERIFY containment spray 710W greater than -1750 gpm on each train.

6. MONITOR containment air return fans:

a WNEN at least 10 minutes ATC/BOP have elapsed from Phase B, THEN ENSURE containment air return tans RUNNING.

7. VERIFY containment ventilation dampers CLOSED:

ATC/BOP - Panel 6K CNTMT VENT GREEN

- Panel EL CNTMT VENT GREEN.

8. VERIFY Phase A valves CLOSED:

ATC/BOP Panel 6K PHASE A GREEN

• Panel EL PHASE A GREEN.

9. VERIFY cntmnt vacuum relief isolation valves CLOSED: [Pnl 6K MANUAL]

FCV-30-46 ATC/BOP

- FCV-30-47

• FCV-3Q-48.

10. VERIFY MSIVs and MS[V bpass valves ATC/BOP CLOSED.

Aooendix D Reciuired Ooerator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 5 Event # 5 Page 41 of 48 Event

Description:

1. 1 Steam Generator F\NLB IS ContlFailure of Phase B/Failure of EGTS Auto Start.

Time fl Position fl Applicants Actions or Behavior 1 1. DETERMINE If any S1G Intact:

a. CHECK at least one S/G pressure:

ATC/BOP CONTROLLED or RISING AND

• Greater than 140 pslg.

CAUTION Isolating all SIGs will result in a loss of secondary heat sink.

12. DETERMINE if any SiG Faulted:

a. CHECK SIG pressures: a. GO TO Step 13, Any SIG pressure DROPPING ATC/BOP in an uncontroltel manner OR

• Any S/G pressure less than 140 psiq.

13. MONITOR if RHR spray should be placed in service:

ATC/BOP a. CHECKIhetollowing: a. GO TO Step 14.

• Containment pressure greater than 9.5 psig

14. MONITOR it containment spray should be stopped:

a. CHECK any containment spray pump a. GO TO Step 15.

RUNNiNG.

ATC/BOP b CHECK containment pressure b. GO TO Step 15.

less than 2.0 psig.

15. RETURN TO procedure and step in ettect.

ATC/BOP END SRO Trci+,rire fr 0 (rir fr page 31) -

I

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 5 Event # ES-0.5 Page 42 of 48 Event

Description:

Equipment Verifications

[ Time ES-O.5 Actions Position fl Applicants Actions or Behavior BOP 1, VERIFY D/Gs RUNNING.

BOP 2 VERIFY D/G ERCW supply valves OPEN.

3. VERIFY at least four ERCW pumps BOP RUNNING -

4. VERIFY CCS pumps RUNNING:

• Pump IA-A (2A-A)

BOP

• Pump 15-B 2B-B)

• Pump C-S.

BOP 5. VERIFY EGTS fans RuNNiNG.

BOP 6. VERIFY generator breakers OPEN

7. NOTIFY at least two AUOs to report BOP to MCR to be available for local action&

a VERIFY AEW pumps RUNNING:

a MDAFWpurnps BOP Ix TDAFWpump.

NOTE AEW leel control valves should NOT be repositioned it manual action has been taken to control S/G levels, to estabhsh flow due to failure, or to solate a faulted SIG 9 CHECK AFW valve alignment:

a. VERIFY MD AFW LCVs in AUTO.

BOP Ix VERIFYTDAFWLCVsOPEN.

c. VERIFY MD AFW pump recirculaticn valves FCV-3-400 and FCV-3-40 I CLOSED.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC2O13-301 Scenario# 5 Event# ES-05 Page 43 of 48 Event

Description:

Equipment Verifications

[ Time fi Position

?0 VERIFY MEW Isolation:

Applicants Actions or Behavior

a. CHECK MEW pumps TRIPPED.

b. ENSURE the following:

BOP

• MFW regulating valves CLOSED MFW regulating bypass valve controllers in MANUAL with output ZERO

• MFW isolation valves CLOSED.

BOP Manually closes Feed Reg Valves 1 1. MONITOR ECCS operation:

a. VERIFY ECCS pumps RUNNING:

• COPS

• RHR pumps

• SI pumps b VERIFY CCP ow through COP IT.

BOP

c. CHECK RCS pressure less than 1500 psig.

d VERIFY SI pump tlow

e. CHECK RCS pressure e. GO TO Step 12 less than 300 psig.

f. VERIFY RHR pump now.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 5 Event # ES-O.5 Page 44 of 48 Event

Description:

Equipment Verifications Time Position Applicants Actions or Behavior

12. VERIFY ESE systems ALIGNED:

a. Phase A ACTUATED:

• PHASE A TRAIN A alarm LIT

[M-$C, B5j.

• PHASE A TRAIN B alarm LIT

[M-3C, B6].

b Cntmt Vent Isolation ACTUATED:

• CNTMT VENT ISOLATION TRAIN A alarm LIT [M-GC, C5]

• CNTMT VENT ISOLATION TRAIN B aiarm LIT [M-GC, 06]

c Status monitor panels:

BOP

• 6CDARK

• 60 DARK

• 6E LIT OUTSIDE outlined area

• 6H DARK

• 6JLIT.

d. Train A status panel 6K:

• CNTMT VENT GREEN

• PHASE A GREEN e Train B status panel FL.:

• CNTMT VENT GREEN

• PHASEA GREEN

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 5 Event # ES-0.5 Page 45 of 48 Event

Description:

Equipment Verifications

[ Time I Position Applicants Actions or Behavior

13. 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:

BOP

1) Containment spray pumps RUNNING.

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

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, A5j.

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

CRmCAL BOP Places HS-30-64A and 64B Phase B and CNTMT Vent Isol to ACTUATE

Apjjendix D Required Orerator Actions Form ES-D-2 Op Test No.: NRC 201 3-301 Scenario # 5 Event# ES-0.5 Page 46 of 48 Event

Description:

Equipment Verifications

[ Time Position Applicants Actions or Behavior NOTE The continuous action in Step 14 remains applicable if containment pressure rises above 1.5 psig after ES-115 is compIeted

14. MONITOR if contanment vacuum relief isolation valves should be dosed:

BOP a. CHECK containment pressure a. GO TO Step 15.

greater than 1.5psig.

15 CHECK secondary and containment rad monitors USING the foiloing:

BOP

• Appendix A, Secondary RacI Monitors

• Appendix B. Containment Rad Monitors.

APPENDIX A SECONDARY RAD MONITORS

1. IF SI occurred on Unit 1, THEN CHECK following Fad monitors including available trends phor to isolation

• Condenser exhaust recorder 1-RR-90-i 19

• SIG blowdown recorder 1-RR 120

• Unit 1 Main steam line rad monitors [1-M-301

• Post-Accident rad points 3 (blue), 4 (violet) 5 (black), and 6 (turquoise)

[j43 (back ot 1-M-30)j

3. NOTIFY Unit Supervisor whether secondary radiation is NORMAL or HIGH

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC2O13-301 Scenario# 5 Event# ES-O.5 Page 47 of 48 Event

Description:

Equipment Verifications

[ Time Position Applicants Actions or Behavior APPENDIX B CONTAINMENT RAD MONITORS 1* IF SI occurred on Unjtl THEN CHECK tollowing md monitors:

BOP .

Upper containment post-accident rad monitors 1 -RM-90-271A and 1 -RM-90-272A NORMAL [1 -M-301

. Lower containment post-accident rad monitors I -RM-90-273A and I -RM-90-274A NORMAL [1 -M-30j

. Containment mad recorders 1-RR-90-i 12 and 1-RR-90-106 NORMAL [O-M-l 2] prior to isolation).

113. WHEN directed by B-U.

THEN BOP PERFORM Appendix 0, Hydrogen Mitigation Actions.

7. CHECK pocket sump pumps STOPPED:

[M- 15, upper le corner]

• HS-77-410, Rx Bldg Aux Hoar and BOP Equipment Drain Sump pump A

• HS-77-4 1 1. Rx Bldg Aux Hoar and Equipment Drain Sump pump B.

18. DISPATCH personnel to perform BOP BA-U-I, Equipment Checks Following ESF Actuation,

19. ENSURE plant announcement has been BOP jade regarding Reactor Trip and SI.

20. PERFORM Appendix E, Spent Fuel BOP cooling Actions, as time permits.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC 2013-301 Scenario # 5 Event # Page 48 of 48 Event

Description:

Critical Task Critical Tasks: Critical Task Statement

1. Manually initiate a Phase B isolation prior to completing ES-O.5 step 13.

2. Isolate AFW Flow to #1 Steam Generator Prior to completing E-2 step 4.