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V.C. Summer 2015-301 Exam Final Items for ADAMS 2B
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Appendix D Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No: 1 Op Test No: NRC-ILO-13-01 Examiners: Operators: CR8:

RO:

- BOP:

Initial Conditions:

The plant has completed a Mid-Cycle outage.

The Reactor is Critical at 1 0 % power.

Critical Data has been recorded.

The National Weather Service has declared a Severe Weather Warning for Richiand, Fairfield, and Kershaw counties for the next four (4) hours.

The secondary has been warmed.

Bi Train Work Week.

Alternate Seal Injection is OOS.

Turnover:

Following turnover start RBCU 2B, then secure RBCU 1 B per an Engineering Request to monitor the RBCU 2B.

Following turnover raise Reactor Power to between 1% and 3%.

Critical Tasks:

Maintain SC levels using EFW without causing a Reactor trip.

Align at least one CHG/SI flowpath prior to completing EOP-1 .0 Attachment 3.

Isolate LOCA prior to exiting EOP-2.5.

Event MaIf No. Event Type* Event Description No.

I NA N-BOP Start RBCU 2B, then secure RBCU 1 B.

2 NA R-RO, Raise power to between 1% and 3%.

N-CRS 3 EFOO2B C-BOP, CRS MD EFW B Pump Bearing Failure leading to trip of the EFOO2T TS-CRS pump.

4 EPSOO5C C-BOP, CRS Loss of Emergency Auxiliary transformer (1 DB).

EPSOO6B TS-CRS DG fails to AUTO start.

5 CRFOO4F8 Partially Dropped Rod (F8) Rod slips to approximately CRFOO7 TS-CRS 200 steps withdrawn.

NRC 2015- Scenario 1 1 NUREG -1021 R9S1

Appendix D Scenario Outline Form ES-D-1 6 CRFOO4F8 C-RO, CRS Two Dropped Rods (F8 and D4) Trip the reactor CRFOO4D4 CRFOO7 7 CVC015A 1-RO, CRS Letdown pressure control valve PCV-145 fails CLOSED (AUTO ONLY).

8 RHRO13E M-ALL LOCA Outside the Reactor Building.

RHR013B RHRO11 PCS0O5A SI Train A Actuation Failure (Auto and Manual).

Manually configure Pumps and Valves.

CS0O4P A CHG/SI pump trips (cannot be reset).

CSO06F B CHG/Sl pump fails to Auto-Start. Manually Start.

C CHG/SI pump breaker cannot be racked-up.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NRC 2015- Scenario 1 2- NUREG -1021 R9S1

Appendix D Scenario Outilne Form ES-D-1 The following notation is used in the ES-D-2 form Time column:

IOA designates Immediate Operator Action steps.

designates Continuous Action steps.

The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.

The scenario involves a plant startup so GOP3, ReactolL Startup from Hot Standby to Startup (Mode 3 to Mode 2), is being implemented. Step 3.13, recording Critical Data, has been completed and the reactor is critical in Mode 2 at 10E-3% power. The secondary plant has been warmed with the turbine on turning gear.

The simulator will be frozen prior to the crew entering the simulator.

The Lead Evaluator may leave the simulator frozen or allow surrogates to maintain stable plant conditions until the crew assumes the watch.

The crew will be briefed to have the BOP start the 2B RBCU and then stop the 1 B RBCU following turnover due to a request from Engineering. The crew will then increase to between 1% and 3% in accordance with GOP-3 beginning at step 3.14.

GTP-702 Attachment II G, Operational Mode Change Plant Startup Entering Mode 1, has been completed.

Sections of GOP-4A, Power Operation (Mode 1 - Ascending) have been completed to perform initial lineups and to warm the secondary plant.

EVENT 1: Start RBCU 2B, then secure RBCU lB.

Three Reactor Building Cooling Units (RBCU5) will be running in fast speed at turnover. After turnover is complete, the BOP will start the 2B RBCU in fast speed then secure the 1 B RBCU in accordance with SOP-114, Reactor Building Ventilation System.

EVENT 2: Raise power to between 1% and 3%.

The RO will increase Reactor Power by withdrawing control rods. The RO will recognize the negative reactivity feedback as the Point of Adding Heat is achieved and stabilize power between 1-3%. The BOP will adjust Emergency Feedwater flow to the Steam Generators as steam flow increases.

The crew will transition to GOP-4A, Power Operation (Mode 1 - Ascending).

NRC 2015- Scenario I NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 EVENT 3: MD EFW B Pump Bearing Failure leading to trip of the pump.

TRIGGER 1 o PMP-EFOO2B XPP0021B MOTOR DRIVEN EFW PMP B BRG FAILURE RAMP = 5 seconds FINAL = 10 o PMP-EF002T XPP0021 B MOTOR DRIVEN EFW PMP B TRIP ON COMMAND DELAY = 35 seconds On cue from the Examiner at approximately 2-3% power the B MDEFW bearing will fail and the B EFW Pump will trip after a short delay if not stopped by the BOP.

In accordance with XCP-623 1-5, MD EFP B MOTOR OVRLD and XCP-623 1-3, MD EFP B Trip, EFW flow must be reduced to below 400 gpm. The EFW flow requirement is approximately 180 gpm/percent so power is limited to approximately 2% using the A MDEFW unless the crew decides to use the TDEFW Pump.

The BOP will throttle EFW flow to the SGs using the A MDEFW in accordance with SOP-21 1, Emergency Feedwater System. The CR6 will evaluate the failure and determine that the B MDEFW Pump is inoperable.

The CRS will refer to Technical Specification 3.7.1.2, Emergency Feedwater System.

EVENT 4: Loss of Emergency Auxiliary Transformer (fOB), DG fails to AUTO Start

TRIGGER 2 o MAL-EPSOO6B DIESEL GENERATOR B FAILURE FAIL TO: No Auto Start o MAL-EPSOO5C LOSS OF ESF BUS 1DB (NORMAL FEED BREAKER)

DELAY = 1 second On cue from the Examiner, power will be lost to the 1DB bus due to a breaker failure and the Auto-Start failure of the B EDG. The BOP will start the B EDG. The B EDG will then load onto the 1 DB Bus.

The CRS will refer to Technical Specification 3.8.1.1, AC Sources.

NRC 2015 Scenario I

- NUREG -1021 R9 51

Appendix D Scenario Outline Form ES-D-1 EVENT 5: Partially Dropped Rod (F8) Rod slips to approximately 200 steps withdrawn.

TRIGGER 3 o MAL-CRFOO4F8 DROPPED ROD F8 FINAL STATIONARY DELETE 1 second o LOA-CRFOO7 CONTROL ROD F8 STICKING POSITION FINAL VALUE = 200 DELETE I second On cue from the Examiner, F8 will slip to the 200 steps withdrawn position. The RO will take immediate actions in accordance with AOP-403.6, Dropped Control Rod, by verifying that only one Control Rod has slipped and by placing the Rod Cntrl Bank Sel Switch in Manual.

The CRS will referto Technical Specifications: 3.1.1.1 Shutdown Margin, 3.1.3.1 Group Height, Insertion and Power Distribution Limits, 3.1.3.6 Control Rod Insertion Limits, and 3.2.4 Quadrant Power Tilt Ratio.

EVENT 6: Two Dropped Rods tF8 and 04) Trip the Reactor

TRIGGER 4 o LOA-CRFOO7 CONTROL ROD F8 STICKING POSITION (NOTE: This LOA is inserted allow F8 to fall when dropped)

FINAL VALUE = 0 o MAL-CRFOO4F8 DROPPED ROD F8 FINAL STATIONARY o MAL-CRFOO4D4 DROPPED ROD D4 FINAL =STATIONARY After Technical Specifications have been addressed for a single dropped rod the examiner will cue the booth operator to drop a second rod. The RO will trip the Reactor and implement EOP 1.0 (E-0) Reactor Trip/Safety Injection Actuation in accordance with AOP-403.6, Dropped Control Rod.

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 EVENT 7: Letdown pressure control valve PCV-145 fails CLOSED (AUTO ONLY).

TRIGGER 5 o MAL-CVCO1 5A LETDOWN PRESSURE CONTROL VALVE PCV-145 FAILURE (AUTO ONLY)

RAMP = 5 seconds FINAL = 35 On cue from the Examiner, PCV-145 pressure controller will drift LOW in auto causing letdown pressure to increase to the alarm setpoint. The RO will respond to annunciators, XCP-613 2-4, LP LTDN FLO/PRESS HI and take manual control of PCV-145.

EVENT 8: LOCA Outside RB, SI Train A Actuation Failure (AUTO and MANUAL), A CHGISI Pump TRIP and B CHG/SI Pump Fails to Auto-Start

TRIGGER 6 o MAL-PCSOO5A SAFETY INJECTION FAILURE TRAIN A FAIL TO: Total Failure o MAL-RHROJ3E RHR DISCH CHECK VALVE 8973C LEAKAGE (0.05=800 GPM)

SEVERITY 0.05 o MAL-RHRO13B RHR DISCH CHECK VALVE 8974B LEAKAGE (0.05=800 GPM)

SEVERITY = 0.05 o FLX-RHRO11 FLEX LEAK RLF VLV 8864B SEVERITY = 5000

AUTO-TRIGGER 7 LPPLSI ==1 SAFETY INJECTION ACTUATED o PMP-CSOO4T XPPOO43A CHRG/Sl PMP A TRIP ON COMMAND o PMP-CSOO6F XPPOO43B CHRG/SI PMP B FAIL TO START

TRIGGER 8 LOA-CVCO4 1 CHARGING PUMP A SUPPLY BRKR POSITION TO: RACK OUT NRC 2015- Scenario 1 NUREG -1021 R9 S1

Appendix D Scenario Outline Form ES-D-1 Scenario Attributes Events

MD EFW B Pump Bearing Failure leading to Trip

Loss of Emergency Auxiliary transformer (1 DB)

DG fails to auto-start Rod F8 slips to approximately 200 steps withdrawn Total Malfunctions 9 2 Dropped Rods fF8 and D4)

Letdown pressure control valve PCV-145 fails CLOSED SI Train A Actuation Failure (Auto and Manual)

A Charging Pump Trip B CHG/SI pump fails to Auto-Start SI Train A Actuation Failure (Auto and Manual).

Malfunctions after A Charging Pump Trip EOP entry (1-2) B CHG/SI pump fails to Auto-Start C CHG/Sl pump fails to Rack-Up MD EFW B Pump Bearing Failure leading to Trip Loss of Emergency Auxiliary transformer (1 DB) with DG failing to Abnormal Events auto-start (2-4) Rod F8 slips to approximately 200 steps withdrawn 2 Dropped Rods (F8 and D4)

Control Card Output for Letdown PCV-145 Drifts LOW Major Transient 1 LOCA Outside the Reactor Building.

EOP-2.5 (ECA-1.2), LOCA Outside Containment EOPs Entered (1-2) 3 EOP-2.0 (E-1), Loss Of Reactor Or Secondary Coolant EOP-1.2 (ES-1.1), Safety Injection Termination EOP Contingencies 1 EOP-2.5 (ECA-1.2), LOCA Outside Containment Maintain SG levels using EFW without causing a Reactor trip.

Critical Tasks . Align at least one CHG/SI flowpath prior to completing EOP-1 .0 (2-3) Attachment 3.

Isolate LOCA prior to exiting EOP-2.5 (ECA-J .2).

NRC 2015- Scenario 1 NUREG -1021 R9 SI

Appendix D Scenario Outline Form ES-D-1 On cue from the Examiner, a LOCA will be inserted in the RHR suction line outside the Reactor Building. This leak is in the discharge line from the B RHR Pump to the RCS.

The crew will implement AOP-101.1, Loss of Reactor Coolant Not Requiring SI, and determine that an SI is required.

The crew will implement EOP-1 .0 (E-0) and determine that the RCS leak is outside of containment and transition to EOP-2.5 (ECA-1 .2). The crew will isolate the leak by closing

.8888B, RHR LP A to Cold Legs, and transition to EOP-2.O (E-1).

A Train Safety Injection will fail to actuate automatically or manually. Individual components will be started/positioned to their required SI condition.

When Safety Injection actuation is attempted the running A Charging pump will trip and the B Charging pump will fail to auto-start resulting in the loss of all High Head Safety injection. It is a critical task to start one High Head Safety Injection Pump.

lithe crew attempts to rack-up the C Charging/SI pump they will be informed that the breaker will not rack-up. Both the A and C Charging pumps are failed in this step to limit the flow rate from High Head Safety Injection. Too much flow would mask the leak as RCS pressure is lowered.

CRITICAL TASKS:

It is a critical task to:

align at least one CHG/SI flowpath prior to completing EOP-1 .0 Attachment 3.

isolate the LOCA prior to exiting EOP-2.5 (ECA-1 .2).

maintain SG levels using EFW without causing a Reactor trip.

TERMINATION:

The scenario can be terminated after the crew has isolated the leak in EOP-2.5 (ECA-1 .2), and transitions to EOP -2.0 then EOP-1.2 (ES-1.1) and terminates Safety Injection or at any time at the discretion of the Examiner.

NRC 2015- Scenario 1 NUREG -1021 R9 51

Appendix D Scenario Outline Form ES-D-1 SIMULATOR SCENARIO SETUP INITIAL CONDITIONS:

lCSet29O

10% Power EOL

Burnup = 20,000 MWD/MTU

RCS Boron Concentration = 652 ppm

FCV-113 Pot Setting 2.80

Rod Position: Group D 94

Tavg = 557.9

Xe=-0.Opcm

Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires.)

PRE-EXERCISE:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.).

VCS-TQP-0807 Attachment I-A, Unit 1 Booth Instructor Checklist, has been completed.

Verify the Hard Card for Turbine Load changes is in its proper storage location.

Verify the Hard Card for borating via MVT-8104 is in its proper storage location.

Hang Red Tags for equipment out of service.

Mark up procedures in use with Circle and slash as applicable:

o GOP-3, Reactor Startup From Hot Standby To Startup (Mode 3 To Mode 2) o GOP-4A, Power Operation (Mode 1 Ascending)

Conduct two-minute drill.

PRE-LOAD:

STANDARD SIMULATOR SETUP:

PMP-LDOO3P, XPPO138 Leak Detection Sump Pmp Loss of Power

VLV-FWO28W, XVG01676-FW FW Hdr Recirc Isol VIv Loss of Power

VLV-FWO29W, XVG01679-FW FW HTR Recirc Iso VIv Loss of Power

VLV-CSO52W, XVTO8141A-CS RCP A Seal Leakoff VIv Loss of Power

VLV-CSO54W, XVTO8141 C-CS RCP C Seal LeakoffVlv Loss of Power

VLV-C5053W, X\JT08141 B-CS RCP B Seal Leakoff VIv Loss of Power SCENARIO RELATED:

ANN-TAO3O, GEN AUX PNL TRBL FAIL TO: OFF

ANN-CS044, ALT SEAL INJ PUMP TRBL FAIL TO: ON

MAL-CVCO27, ALT SEAL INJ D/G FAIL TO START

MAL-CVCO29, ALT SEAL INJ PUMP FAIL TO START NRC 2015 Scenario 1

- NUREG -1021 R9SI

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-01 Scenario# 1 Event # 1 Page: 10 of 49 Event

Description:

Start RBCU 26, then secure RBCU lB.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: No triggers for this event.

CRS Direct BOP to start RBCU 2B, then secure RBCU 1 B in accordance with SOP-i 14, Reactor Building ventilation System,,Section III .A.

NOTE2.1 SOP1141

a. Due to eddy current brakes, RBCU control switches must be held in START position until the red breaker closed light is lit and starting current is indicated on appropriate meter.

b. Normal and preferred lineup is three RBCUs running in NORM (fast speed).

c. To increase stay times for teams entering containment, four RBCUs may be placed in service in NORM (fast speed).

BOP 2.1 Place RBCUs in service by starting three or four RBCUs in SLOW SOP-i 14 or NORM as follows:

BOP b. For XFNOO65B-AH, REACTOR BLDG COOLING UNIT 2B SOP-I 14 EMERG FAN, start one of the following:

1) XFN 0065B-AH, 2B NORM.

NOTE 2.1.e SOP-i 14 Contact PSE to evaluate, if RBCU fan motor amps exceed the values given.

BOP e. Verify RBCU Fan motor amps return to normal operating range: SOP-i 14

1) For fast speed operation, 275 amps to 300 amps.

NOTE 2.1.f SOP-i 14 The RBCU TRAIN A (B) EMERG switch must be selected to an operable RBCU.

BOP f. Verify the following switches are in the desired position: SOP-i 14

2) XFN-64B/XFN 65B - RBCU TRAIN B EMERG.

BOP 2.2 Shut down RBCUs by placing appropriate switch(es) in STOP: SOP-l 14

c. XFN 0064B-AH, lB NORM.

BOP Report that the 2B RBCU is running and the 1 B RBCU has been SOP-i 14 secured.

EVALUATOR NOTE: The next event is a power change which does not require a trigger.

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 2 Page: 11 of 49 Event

Description:

Raise power to between 1% and 3%.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: No triggers for this event.

EVALUATOR NOTE:

The Unit is stable in Mode 3 at turnover with all surveillances completed for a Mode change to Mode 2. GOP-3 is complete to step 3.14. The RD will bring the Reactor to the POAH and transition to GOP-4A Power Operation (Mode 1 Ascending). GOP-4A steps have been signed off to indicate that lineups have been completed and the secondary warmed.

NOTE 3.14 GOP-3 Ensure sufficient Emergency Feedwater Flow exists prior to raising power.

RD 3.14 Increase Reactor Power to between 1% and 3%. GOP-3 RO 3.15 At the Point of Adding Heat, if NR-45, NIS RECORDER, had GOP-3 previously been selected to HI speed place the recorder in LO speed.

CAUTION 3.16 GOP-3

a. Adjustment of Tavg with the Rod Control System must not be attempted with the ROD I CNTRL BANK SEL Switch in any position other than MAN.

b. Manual rod control is required to establish equilibrium conditions, since C-S blocks automatic rod withdrawal.

RD 3.16 Maintain Tavg between 555°F and 559°F. GOP-3 BOP Adjust EFW flow to the Steam Generators (SG) as power is increased to maintain Narrow Range SG levels between 60% and 65%.

EVALUATOR NOTE: Attachment II.G was completed prior to turnover N/A 3.17 Complete Attachment II.G, Operational Mode Change Plant GOP-3 Startup Entering Mode 1, of GTP-702.

CRS 3.18 Proceed to GOP-4A, Power Operation (Mode I - Ascending). GOP-3 EVALUATOR NOTE: GOP-4A POWER OPERATION (MODE 1 ASCENDING) has several -

line-up verifications. GOP-4A lineups and secondary plant warming have been completed.

NOTE 3.1 through 3.11 GOP-4A Steps 3.1 through 3.11 raise Reactor Power from 1% to 25%.

EVALUATOR NOTE: The next event may be initiated after GOP-4A is entered.

NRC 2015- Scenario I NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 3 Page: 12 of 49 Event

Description:

MD EFW B Pump Bearing Failure leading to trip of the pump.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR When directed Initiate Event 3 (TRIGGER 1).

EVALUATOR NOTE:

Event 3 should be initiated on entry int&EOP-4A:Power Operation (Mode 1 -Ascending).

Power should be between 2 3% when this event is triggered.

Indications Available:

MD EFP BAmps>60 amps XCP-623 1-5, MD EFP B MOTOR OVRLD CRS Enters ARP-001-XCP-623, 1-5 XCP-623 1-5 CORRECTIVE ACTIONS: XCP-623 1-5 BOP 1. If possible, reduce demand to less than 400 gpm by throttling the XCP-623 1-5 flow control valves to the Steam Generators.

BOP 2. Start Motor Driven Emergency Feedwater Pump A if necessary to xcp maintain Steam Generator levels.

EVALUATOR NOTE: The guidance in SOP-21 1, Emergency Feedwater System, is not relevant for this failure because both pumps are running initially.

BOP 3. Refer to SOP-211. XCP-623 1-5 BOP 4. Determine if a single phasing event is in progress by diagnosis of XCP-623 1-5 any combination of the following symptoms:

a. Vibration Alarms are received for other equipment.

b. MCB Potential Lights are not lit.

c. MCB Amber Overload lights are lit for running equipment or Motor Overload Alarms are received.

U. MCB Undervoltage Alarms.

e. Affected bus local 7.2 KV Bus ammeters EVALUATOR NOTE: The CRS could direct the RO to Stop the B MD EFW Pump, reduce power to ensure MD EFW Pump A is sufficient and/or for the BOP to start the TD EFW Pump.

The TD EFW Pump is not normally used for SG level control during heatup/cooldown.

Indications Available:

MD EFP B Amps> 60 amps XCP-623 1-5, MD EFP B MOTOR OVRLD XCP-623 1-3, MD EFP B TRIP NRC 2015 - Scenario 1 NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 1 Event # 3 Page: 13 of 49 Event

Description:

MD EFW B Pump Bearing Failure leading to trip of the pump.

Time Position Applicants Actions or Behavior EVALUATOR NOTE: The crew will enter ARP-001 -XCP-622, 1-5 first but since the B MD EFW Pump will trip within one minute only the actions associated with XCP-623 1-3, MD EFP B TRIP are included. , .. -

XCP-623 1-5 CR5 Enters ARP-001-XCP-622, 1-5 XCP-623 1-3 CRS Enters ARP-001-XCP-623, 1-3 EVALUATOR NOTE: The CR8 could direct the RO to reduce power to ensure MD EFW Pump A is sufficient and/or for the BOP to start the TD EFW Pump. The TD EFW Pump is not normally used for SG level control during heatup/cooldown.

CORRECTIVE ACTIONS: XCP-623 1-3 BOP 1. Start Motor Driven Emergency Feedwater Pump A if necessary to XCP-623 1-3 maintain Steam Generator levels.

RO 2. Reduce feedwater demand to less than 400 gpm. XCP-623 1-3 CRS 3. RefertoSOP-211. XCP-623 1-3 XCP-623 1-3 SUPPLEMENTAL ACTIONS:

BOP 1. If Steam Generator levels cannot be maintained with one motor XCP-623 1-3 driven pump, start the Turbine Driven Emergency Feedwater Pump.

2. Place PUMP B control switch in NORMAL-AFTER-STOP to clear the alarm.

CRS 3. Determine the cause of the trip and correct as soon as possible. XCP-623 1-3

4. If the pump is inoperable, refer to Technical Specification 3.7.1.2.

EVALUATOR NOTE: Emergency Feedwater requirements ate approximately 180 gpm per percent power.

NRC 2015- Scenario 1 13- NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 3 Page: 14 of 49 Event

Description:

MD EFW B Pump Bearing Failure leading to trip of the pump.

Time Position Applicants Actions or Behavior RO/BOP Maintain SG level without tripping the unit by reducing feedwater

< demand (Reactor Power) and/or controlling Emergency Feedwater flow.

U) .

0 V BOOTH OPERATOR; If contacted to investigate the condition of the B MD EFW wait 3 minutes and report that the pump bearing are hot and the breaker is tripped with no flags.

CRS Contacts Work Control and/or Maintenance for assistance.

EVALUATOR NOTE: Technical Specification 3.0.4 is applicable so entry into Mode I is prohibited.

TECH SPEC CR3 Enters Technical Specification 3.7.1.2, Action a:

With one emergency feedwater pump inoperable, restore the required emergency feedwater pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

EVALUATOR NOTE: The next event may be initiated after SG levels are under control and the Technical Specification determination is complete.

NRC 2015 - Scenario 1 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2

I Op Test No: NRC-lLO-13-01 Scenario # 1 Event # 4 Page: 15 of 49 Event

Description:

Loss of Emergency Auxiliary transformer (1DB). DG fails to AUTO start.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR When directed - Initiate Event 4 (TRIGGER 2)

BOOTH OPERATOR Silence the HVAC Alarms INDICATIONS AVAILABLE:

Multiple Alarms .

XCP-637 5-2 7KV ESF CHAN B BKR TRIP 1DB Volts = 0 1DB Feed Amps = 0 AUTOMATIC ACTIONS: xcP-637 5-2

1. If XSW1DB 07, TRANS 1DB1 & 1DB2, tripped, XSW1DB1 4B, MAIN XCP-637 5-2 INCOMING BREAKER, and XSW1DB2 4B, MAIN INCOMING BREAKER, will trip.

2. If XSW1DB 16, BUS 1DB NORMAL INCOMING BKR, tripped, Diesel Generator B will automatically start.

3. If XSW1EB 03, TRANSF 1EB1 FEEDER BREAKER, tripped, SW1EB1 4B, MAIN INCOMING BREAKER, will trip.

EVALUATOR NOTE: The B DB failed to start and load onto the 1DB bus. After determining that there are no lockout on the B DG or the 1 DB Bus the operator should perform an emergency start of the B DG.

BOP Perform an Emergency Start of the 1 B Diesel Generator.

CORRECTIVE ACTIONS: XCP-637 5-2 BOP 1. Using MCB indication, determine which breaker tripped. XCP-637 5-2

2. Verify appropriate automatic actions.

3. Dispatch an operator to investigate the cause of the breaker trip.

4. Request Electrical Maintenance to troubleshoot and correct the cause of the breaker trip.

SUPPLEMENTAL ACTIONS: XCP-637 5-2

1. When the cause has been corrected, reclose the breaker. XCP-637 5-2 CRS 2. Refer to Technical Specifications 3.8.1 and 3.8.3 for LCO XcP-637 5-2 requirements.

NRC 2015- Scenario 1 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 4 Page: 16 of 49 Event

Description:

Loss of Emergency Auxiliary transformer (1DB). DG fails to AUTO start.

Time Position Applicants Actions or Behavior CRS T.S. 3.8.1.1 AC SOURCES Actions T.S. 3.8 1.1

c. With one offsite circuit and one EDG inoperable:

1 Demonstrate the OPERABILITY of the remainihg offsft AC source by performing Surveillance Requirement 4.8.1.1.1 within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, and

2. *11 the EDG became inoperable due to any cause other than preplan ned preventative maintenance or testing:

a) determine the OPERABLE EDG is not inoperable due to a common cause failure within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , or b) demonstrate the OPERABILITY of the remaining EDG by performing Surveillance Requirement 4.8.1.1 .2.a.3 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , and

3. Within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , verify that required systems, subsystems, trains, components and devices that depend on the remaining EDG as a source of emergency power are also OPERABLE and in MODE 1, 2, or 3, that the Turbine Driven Emergency Feed Pump is OPERABLE. If these conditions are not satisfied within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

4. Restore one of the inoperable sources to OPERABLE status within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , and

5. Restore the other AC power source (offsite circuit or diesel generator) to OPERABLE status in accordance with the provisions of Section 3.8.1.1 Action Statement a. or b. as appropriate, with the time requirement of that Action Statement based on the time of initial loss of the remaining inoperable A.C.

power source.

EVALUATOR NOTE: The operators may have re-energized the 1 DR bus using the 1 B Diesel Generator.

NRC 2015- Scenario 1 16- NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 4 Page: 17 of 49 Event

Description:

Loss of Emergency Auxiliary transformer (1DB). DG fails to AUTO start.

Time ] Position Applicants Actions or Behavior CRS T.S. 3.8.3.1 Actions T.S. 3.8 3.1

a. With one of the required trains of AC Emergency busses not fully energized, re-energize the divisio.n within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

EVALUATOR NOTE: The next event may be initiated after the 1 B Diesel Generator is powering the 1DB 7.2 KV Bus.

CR5 Implement SOP-306, Emergency Diesel Generator, B. Operation Of Diesel Generator B After An Automatic Start And Load.

BOP 2.1 Verify B TRN BLACKOUT SEQ COMPLETE Status Light is lit. SOP-306 RO 2.2 Ensure one Charging Pump is running. SOP-306 BOP 2.3 Ensure the following loads have started: SOP-306

a. RHR Pump B.

I b. One Train B Service Water Pump.

c. One Train B HVAC Chilled Water Pump.

U. One Train B CCW Pump.

e. MD EFW Pump B.

1. The Train B RBCU selected for emergency operation (slow speed).

g. Train B FHB Exhaust Fan.

h. Service Water Booster Pump B.

i. The Train B HVAC Chiller associated with the running Train B HVAC Chilled Water Pump.

BOP 2.4 Verify greater than or equal to 2000 gpm flow on Fl-4496, SWBP B SOP-306 DISCH FLOW.

NRC 2015- Scenario 1 NUREG -1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 1 Event # 4 Page: 18 of 49 Event

Description:

Loss of Emergency Auxiliary transformer (1DB). DG fails to AUTO start.

Time Position Applicants Actions or Behavior BOP 2.5 Perform the following per SOP-220: SOP-306

a. Ensure Instrument Air is supplied by one of the following:

1)

Either Station Intruh,ent Air Compressor A or B.

2) Diesel Driven Air Compressor.

BOP 2.6 Supply Reactor Building Instrument Air from Station Instrument Air SOP-306 with Reactor Building Instrument Air Compressors secured per SOP-121,Section IV.

BOP 2.7 Maintain RB temperature as follows: SOP-306

a. Monitor RB temperature and pressure for indications of insufficient cooling.

b. If required, supply Service Water to the Train A RBCUs per SOP-117.

BOP 2.8 With Shift Supervisor concurrence perform the following: sOP

a. Secure Emergency Feedwater Pumps.

b. Realign the Emergency Feedwater System for standby operation per SOP-21 1.

NOTE 2.9 SOP-306 Spent Fuel Cooling Loop B is unavailable until NON-ESF LCKOUTS is reset.

BOP 2.9 If required, startup Spent Fuel Cooling Loop A aligned to the Spent SOP-306 Fuel Pool per SOP-i 23.

CAUTION 2.10 SOP-306 De-energizing the following Atmospheric Gaseous Module rate meters when the appropriate Interlock Switch is in NORMAL/OFF will result in the generation of a High Radiation signal and component realignment:

a. RMA0001-RM, ATM GASEOUS IODINE CONT ROOM SUPP AIR.

b. RMA0002-RM, ATM GASEOUS IODINE RB SAMPLE LINE.

c. RMAOO1O-RM, WASTE GAS DISCHARGE RADIATION MONITOR.

NRC 2015- Scenario I - 18- NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 1 Event # 4 Page: 19 of 49 Event

Description:

Loss of Emergency Auxiliary transformer (1DB). DG fails to AUTO start.

Time ] Position ] Applicants Actions or Behavior BOP 2.10 Perform either of the following for Train B radiation monitors: SOP-306

a. Restore Train B radiation monitors to normal operation per SOP

. . 124.

. b. If Train radiation monitors are unable to be restored to normal operation, contact Health Physics to perform compensatory actions per HPP-904 for loss of electrical power to Train B radiation monitors.

NRC 2015 Scenario 1

- NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-01 Scenario # 1 Event # 5 Page: 20 of 49 Event

Description:

Partially Dropped Rod (F8) Rod slips to approximately 200 steps withdrawn.

Time I Position I Applicants Actions or Behavior BOOTHOPERATOR When directed Initiate Event 5 (TRIGGER 3)

Indication Available:

XCP-620 2-5 CMPTR ROD DEV CORRECTIVE ACTIONS: XCP-620 2-5 RD 1 Observe the Digital Rod Position Indication display for proper rod positions.

2 Determine if the cause is a dropped or misaligned rod.

3 If DRPI ALARM URGENT is in refer to ARP-001-XCP-621, 2-1.

SUPPLEMENTAL ACTIONS:

1 If a rod is misaligned, refer to AOP-403.5, Stuck or Misaligned Rod.

2 If a rod is dropped, refer to AOP-403.6, Dropped Control Rod.

3 Operate the Rod Control System in MAN as described in SOP-403 until proper automatic Rod Control in restored.

4 Refer to Technical Specification 3.1.3.1.

EVALUATOR NOTE:

XCP-620 2-5 CMPTR ROD DEV is an Entry Condition for AOP-403.5 and AOP-403.6. The steps of both procedures are similar and would ensure a success path for the recovery of one partially dropped rod. Only the steps of AOP-403.6 are included here.

CRS Implement AOP-403.6, Dropped Control Rod.

Verify only one Control Rod has dropped. AOP-403.6 IOA RO 1 Place ROD CNTRL BANK SEL Switch in MAN. AOP-403.6 IOA RD 2 Stabilize the plant: AOP-403.6 RD 3

a. Decrease Main Turbine load to maintain Tavg within 5°F of Tref.

b. Verify PZR pressure is stable at OR trending to 2235 psig (2220 psig to 2250 psig).

c. Verify PZR level is stable at OR trending to program level.

Check if Reactor power is LESS THAN 75%. AOP4O RO 4 NRC 2015 Scenario 1

- 20 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 5 Page: 21 of 49 Event

Description:

Partially Dropped Rod (F8) Rod slips to approximately 200 steps withdrawn.

Time Position [ Applicants Actions or Behavior CRS 5 Initiate GTP-702, Attachments IV.A, IV.B, and IV.C. AOP-403.6

.CRS 6 Notify the following plant personnel prior to moving Control Rods: AOP-4936

Marageh,ent Duty Supervisor.

. Rod Control System Engineer.

. Reactor Engineering CRS 7 Provide Reactor Engineering with the following information: AOP-403.6 Time rod dropped:

Dropped rod location:

Initial Reactor power level:

Current Reactor power level:

Current QPTR:

BOOTH OPERATOR 1

As Reactor Engineering after receiving the report of plant conditions, recommend that Reactor Power be maintained at the current level until a recovery plan is developed.

CRS 8 Determine and correct the cause of the failure. AOP-403.6 NOTE Step 9 AOP-403.6 This Step must be completed before continuing with Step 10.

CRS 9 Obtain the following information from Reactor Engineering: AOP-403.6 Power level at which recovery is to be performed:

Rate of Control Rod movement during recovery:

NRC 2015 - Scenario 1 - 21 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 5 Page: 22 of 49 Event

Description:

Partially Dropped Rod fF8) Rod slips to approximately 200 steps withdrawn.

Time Position Applicants Actions or Behavior CR6 Enter Technical Specification 3.1.3.1 .d.3 TECH SPEC

d. With gne full length rod inoperable due to causes pther than addressed by ACTION a., above, or misálignéd from its grOu tep counter demand height by moi than +/- 12 stps (indictéd osition),

POWER OPERATION may continue provided that within one hour either:

3. The rod is declared inoperable and the SHUTDOWN MARGIN requirement of Specification 3.1.1.1 is satisfied. POWER OPERATION may then continue provided that:

a) A reevaluation of each accident analysis of Table 3.1-1 is performed within 5 days...

b) The SHUTDOWN MARGIN requirement of Specification 3.1.1.1 is determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

c) A core power distribution measurement is obtained and F0(z) and Fj5 are verified to be within their limits within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and d) The THERMAL POWER level is reduced to less than or equal to 75% of RATED THERMAL POWER within the next hour and within the following 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the high neutron flux tip setpoint is reduced to less than or equal to 85% of RATED THERMAL POWER.

EVALUATOR NOTE: This scenario does NOT include Control Rod recovery. The next event may be inserted after Technical Specifications have been addressed. The Technical Specifications may be addressed in post-exam questioning if it is desired to expedite the scenario.

NRC 2015 - Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 1 Event # 6 Page: 23 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time I Position I Applicants Actions or Behavior BOOTH OPERATOR When directed - Initiate Event 6 (TRIGGER 4)

EVALUATOR NOTE: The following steps occur after the 2 rod drops.

Indications Available: V XCP-621, 3-2 RODS ON BOTTOM V RO CORRECTIVE ACTIONS: XCP-621 3-2 1 If two or more rods have dropped, manually trip the Reactor and implement EOP-1 .0, Reactor Trip/Safety Injection Actuation.

SUPPLEMENTAL ACTIONS:

1 Have l&C verify proper operation of the DRPI System and repair if necessary.

CRS Direct EOP-1 .0 (E-0) Reactor Trip/Safety Injection Actuation, entry.

1 Verify Reactor Trip: EOP-1.0 I IOA C rew

Trip the Reactor using either Reactor Trip Switch.

Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

2 Verify Turbine/Generator Trip: EOP-1 .0

a. Verify all Turbine STM STOP VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

IOA BOP

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped IOA BOP 3 Verify both ESF buses are energized. EOP-1 .0 NRC 2015- Scenario 1 - 23 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-1 3-01 Scenario # 1 Event # 6 Page: 24 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time Position Applicants Actions or Behavior 4 Check if SI is actuated: FOP-i .0

a. Check if either: (NO) -

SI ACT status light is blight on XCP-6107 1-1.

0R IOA BOP

Any red first-out SI annunciator is lit on XCP-626 top row.

ALTERNATIVE ACTION

a. GOTOStep5.

5 Check if SI is required: FOP-i .0

a. Check if any of the following conditions exist: (NO)

. PZR pressure LESS THAN 1850 psig.

RB pressure GREATER THAN 3.6 psig.

IOA CREW

Steamline pressure LESS THAN 675 psig.

OR

. Steamline differential pressure GREATER THAN 97 psid.

ALTERNATIVE ACTION

a. GO TO EOP-1.1, REACTOR TRIP RECOVERY, Step 1.

CRS Direct EOP-1.1 entry.

NRC 2015 - Scenario 1 - 24 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 6 Page: 25 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time I Position I Applicants Actions or Behavior EOP-1 .1 REFERENCE PAGE FOR EOP-1.1 1 SI ACTUATION CRITERIA .....

IF either of the following conditions óccürs, THEN actuate SI nd GO TO EOP-1 .0, REACTOR TRIP/SAFETY INJECTION ACTUATION, Step 1:

. PZR level can NOT be maintained GREATER THAN 8%.

OR

. RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN the value listed in the table below:

RCS PRESSURE (psig) RCS SUBCOOLING (°F) 1576-3075 42.5 876-1575 45 576-875 47.5 476-575 50 375-475 52.5 CAUTION EOP-1 .1 If SI actuation occurs during this procedure, EOP-1 .0, REACTOR TRIP/SAFETY INJECTION ACTUATION, should be performed to stabilize the plant.

NOTE EOP-1 .1

Main Turbine vibration should be monitored during coastdown.

The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

CREW 1 Announce plant conditions over the page system. EOP-1.1 EVALUATOR NOTE: At the discretion of the Lead Examiner after EOP-1 .1 has been entered -

Initiate Event 7 (TRIGGER 5). Remaining steps of EOP-1.1 will be run concurrently with Event 7 (next section) for PCV-I 45 failure.

NRC 2015- Scenario 1 - 25 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 6 Page: 26 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time Position Applicants Actions or Behavior BOP 2 Check FW status: EOP-1 .1

a. Check if RCS Tavg is LESS THAN 564°F.

b. Verify FW Isolation:

. Ensure the FW Flow Control Valves, FCV-478(488)(498), are closed.

. Ensure the Main FW Isolation Valves, PVG-1611A(B)(C), are closed.

. Ensure the FW Flow Control Bypass Valves, FCV-3321 (3331)(3341), are closed.

EVALUATOR NOTE: B MDEFW Pump tripped during an earlier event.

BOP c. Ensure EFW Pumps are running: EOP-1 .1

1) Ensure th MD EFW Pumps are running. (NO)

2) Verify the TD EFW Pump is running if necessary to maintain SG levels.

d. Verify total EFW flow is GREATER THAN 450 gpm.

e. Trip all Main FW Pumps.

RO 3 Check RCS temperature: EOP-1 .1

. With any RCP running, RCS Tavg is stable at OR trending to 557°F.

OR

. With no RCP running, RCS Tcold is stable at OR trending to 557°F.

BOP 4 IF EOP-1 .0 was entered from AOP-1 12.2, THEN RETURN TO AOP EOP-1 .1 112.2, STEAM GENERATOR TUBE LEAK NOT REQUIRING SI, Step 7. (NO)

ALTERNATIVE ACTION 4 GOTOStep5.

BOP 5 Verify all Control Rods are fully inserted. EOP-1 NRC 2015 Scenario 1

- - 26 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 6 Page: 27 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time Position Applicants Actions or Behavior BOP 6 Check DA level control: EOP-1 .1

a. Open LCV-3235, DEAER START UP DRAIN CNTRL, as necessry to maintain DA level LESS THAN 10.5 ft as indicated

on Ll-31 35, DEER STOR TK WR LVL FEET.

b. Locally adjust ITV-3062A(B)(C), BD COOLER A(B)(C) CDSTE OUT TEMP, to 90% (XPN-0029, NUCLEAR BLOWDOWN PROCESSING PANEL, AB-436).

RO 7 Check PZR level control: EOP-1 .1

a. Verify PZR level is GREATER THAN 17%.

b. Verify Charging and Letdown are in service.

c. Verify PZR level is trending to 25%.

RO 8 Check PZR pressure control: EOP-1.1

a. Verify PZR pressure is GREATER THAN 1850 psig.

b. Verify PZR pressure is stable at OR trending to 2230 psig (2220 psig to 2250 psig).

BOP 9 Check SG levels: EOP-1.1

a. Verify Narrow Range level in all SGs is GREATER THAN 26%.

b. Control EFW flow to maintain Narrow Range SG level between 40% and 60%.

BOP 10 Verify all AC buses are energized by offsite power: EOP-1 .1

. ESF AC buses.

. BOP AC buses.

NRC 2015- Scenario 1 - 27 - NUREG -1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 6 Page: 28 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time Position Applicants Actions or Behavior SOP 1 1 Transfer Condenser Steam Dumps to the Steam Pressure Mode: EOP-1 .1

a. Verify PERMISV C-9 status light is bright on XCP-61 14 1-3.

b. WHEN RCS Tavg is LESS THAN P-12 (552F), THEN place beth STM DUMP INTERLOCK Switches to BYP INTLK.

c. Perform the following:

. Verify the MS Isolation Valves, PVM-2801A(B)(C), are open.

OR

. Open MS Isolation Bypass Valves:

1) Depress both MAIN STEAM ISOL VALVES RESET TRAIN A(S).

2) Open MS Isolation Bypass Valves, PVM-2869A(B)(C).

d. Place the STM DUMP CNTRL Controller in MAN and closed.

e. Ensure the STM DUMP CNTRL Controller is set to 8.4.

f. Place the STM DUMP MODE SELECT Switch in STM PRESS.

g. Place the STM DUMP CNTRL Controller in AUTO.

NOTE Step 12 EOP-1 .1

Priority should be given to running RCP A to supply Normal PZR Spray.

Since a time lag is expected after increasing steam flow before natural circulation parameters can be verified, this procedure should be continued concurrently with the establishment of natural circulation.

RO 12 Verify RCP A is running. EOP-1 .1 RO 13 Verify PERMISV C-9 status light is bright on XCP-6114 1-3. EOP-1 .1 NRC 2015 - Scenario 1 28 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 1 Event # 6 Page: 29 of 49 Event

Description:

Two Dropped Rods (F8 and D4) Trip the reactor Time Position Applicants Actions or Behavior RO 14 Check the position of NR-45, NIS RECORDER: EOP-1 .1

a. Verify Intermediate Range Power is LESS THAN P-6 (7.5x10-6%).

b. Transfer NR-45, .NIS RECORDER, to both Source Range channels.

c. Initiate GTP-702, Attachment VI.KK.

BOP 15 Shut down and stabilize the Secondary Plant. REFER TO AOP EOP-1 .1 214.1, TURBINE TRIP.

RO 16 Maintain stable plant conditions: EOP-1.1

a. Maintain PZR pressure at 2230 psig (2220 psig to 2250 psig).

b. Maintain PZR level at 25%.

c. Maintain Narrow Range SG levels between 40% and 60%.

d. Maintain RCS temperature:

With any RCP running, Tavg at 557°F.

OR

With no RCP running, Tcold at 557°F.

e. REFER TO GOP-5, REACTOR SHUTDOWN FROM STARTUP TO HOT STANDBY (MODE 2 TO MODE 3).

NRC 2015- Scenario 1 - 29 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 7 Page: 30 of 49 Event

Description:

Letdown pressure control valve PCV-145 fails CLOSED (AUTO ONLY)

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR When directed - Initiate Event 7 (TRIGGER 5)

Indications Available:

XCP-613 2-4 LP LTDN Ft.O/PRESS HI CRS Dirett implemeNatioh of ARP-0O1-XCP-613 CORRECTIVE ACTIONS: XCP-613 2-4

1. Verify proper operation of PCV-145, LO PRESS LTDN. XCP-613 2-4 RO EVALUATOR NOTE: The Operator should identify the malfunction of PCV-145 automatic control and adjust letdown pressure with Manual control of PCV-145.

2. If necessary, place PCV-145, LO PRESS LTDN, in MAN and adjust XcP-613 2-4 RO as necessary to reduce flow or pressure.

3. Close Letdown orifice isolation valves as necessary to reduce flow or XCP-613 2-4 RO pressure.

XCP-61 3.4 RO 4. Isolate Charging flow if Letdown is isolated.

CRS Contacts Work Control/Maintenance for assistance.

EVALUATOR NOTE: The next event may be initiated after letdown pressure control is established in manual.

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 31 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position Applicants Actions or Behavior BOOTH OPERATOR When directed - Initiate Event 8 (TRIGGER 6)

EVALUATOR NOTE: The CRS may, at his/her discretion, implement AOP-1O1.1 LOSS OF REACTOR COOLANT NOT REQUIRING SI to attempt leak isolation in parallel with EOP-tl.

The leak rate will quickly exceed the capability of available makeup to maintain Pressurizer level. EOP-1.1, REACTOR TRIP RECOVERY reference page will also direct actuation of Safety Injection if AOP-1 01.1 is not entered.

Indications Available:

XCP-614 5-1 CHG LINE FLO HI/LO XCP-616 1-5 PZR LOS DEV HI/LO XCP-616 2-3 PZR PRESS HI/LO XCP-616 3-6 PZR PCS LO BU HTRS ON XCP-607 3-4 LD TRBL AB SMP/FLDRN LVL HI XCP-644 3-2 PLANT VENT PARTIC RM-A3 TRBL XCP-645 2-2 AB VENT DUCTS RM-A1 1 TRBL

Decreasing Pressurizer level with increased Charging flow and normal Letdown flow.

Decreasing Pressurizer pressure.

Increased Heater output and Backup Heaters on.

Increased VCT makeup frequency.

BOOTH OPERATOR: If an Operator is dispatched to investigate a local alarm in the Relay Room report:

XPN-6033 2-1, Leak Detection Drain 19 Level High AB-41 2 W. Pen South, is in alarm.

XPN-6033 2-2, Leak Detection Drain 21 Level High AB-412 W. Pen Middle, is in alarm.

CRS Diagnose an RCS Leak.

CR5 Implement AOP-101.1, Loss of Reactor Coolant Not Requiring SI. AOP-1O1.1 NOTE: AOP-1o1.1

If a Reactor Trip occurs AND SI is NOT required, this procedure should be continued after the actions of EOP-1.1, REACTOR TRIP RECOVERY, are completed.

As valves are isolated, it may be necessary to monitor RCS pressure for a period of time to determine if the leak is isolated.

EVACUATOR NOTE:

PCV-145 has previously been placed in manual due to a failure of the controller in auto.

Letdown should be controlled in manual rather the placing the failed controller back in service.

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 32 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time ] Position ] Applicants Actions or Behavior

RO 1. Verify PZR level is at or trending to program level. (NO) AOP-1O1 .1

. ALTERNATIVE ACTION . .,

1. IF PZR Tevel is decreasing, THEN perform the following: V a) Open FCV-122, CHG FLOW, as necessary to maintain PZR level.

b) IF PZR level continues to decrease, THEN reduce Letdown to one 45 gpm orifice:

1) Set PCV-145, LO PRESS LTDN, to 70%.

2) Ensure PVT-8149A, LTDN ORIFICE A ISOL, is open.

3) Close both PVT-8149B(C), LTDN ORIFICE B(C) ISOL.

4) Adjust PCV-145, LO PRESS LTDN, to maintain P1-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.

5) Place PCV-145, LO PRESS LTDN, in AUTO.

CRS, RO 2 Check if SI is required: AOP-101 .1

a. Check if any of the following criteria are met:

. PZR level is decreasing with Charging maximized and Letdown minimized. (YES)

OR

. PZR level is approaching 8%.

OR

. PZR pressure is approaching 1870 psig.

OR

VCT level is approaching 5%.

b. Perform the following:

1) Trip the Reactor.

2) GOTO EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION. WHEN EOP-1 .0 Immediate Actions are complete, THEN actuate SI.

CRS Implement EOP-1.0, Reactor Trip/Safety Injection Actuation.

NRC 2015 - Scenario 1 32 - NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 1 Event # 8 Page: 33 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position I Applicants Actions or Behavior REFERENCE PAGE FOR EOP-1.0 EOP-1.0 RCP TRIP CRITERIA . .

See step 1 note for

a. IF Phase B Containment Isolation has actuated (XCP-612 4-2), THEN trip all RCPs. RCP Trip

b. IF both of the following conditions occur, THEN trip all RCPs: Criteria

SI flow is indicated on Fl-943, CHG LOOP B CLD/HOT LG FLOW GPM.

AND

RCS Wide Range pressure is LESS THAN 1418 psig.

2 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM.

3 MONITOR SPENT FUEL COOLING Periodically check status of Spent Fuel Cooling by monitoring the following throughout event recovery:

Spent Fuel Pool level.

Spent Fuel Pool temperature.

IOA RO 1 Verify Reactor Trip: EOP-1 .0

Trip the Reactor using either Reactor Trip Switch.

Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

IOA BOP 2 Verify Turbine/Generator Trip: EOP-1 .0

a. Verify all Turbine STM STOP VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP 3 Verify both ESF buses are energized. EOP-1 .0 NRC 2015- Scenario 1 33 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 1 Event # 8 Page: 34 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, 6 CHG/SI Auto-Start Failure.

Time Position Applicants Actions or Behavior IOA RO 4 Check if SI is actuated: EOP-1 .0

a. Check if either: . .,

. SI ACT statuslightis bright on XCP-61b7 OR

. Any red first-out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch.

c. GO TO Step 6.

EVALUATOR NOTE: The CR5 may direct that SI be actuated during or after this step based on the instruction in AOP-1 01.1 to actuate SI following the EOP-1.0, Immediate Operator Actions.

IOA RO 5 Check if SI is required: EOP-1.O

a. Check if any of the following conditions exist:

PZR pressure LESS THAN 1850 psig.

OR

RB pressure GREATER THAN 3.6 psig.

OR

Steamline pressure LESS THAN 675 psig.

OR

Steamline differential pressure GREATER THAN 97 psid.

RO b. Actuate SI using either SI ACTUATION Switch. EOP-1.O EVALUATOR NOTE:

A Train Actuation is failed. The BOP will need to manually align the A Train Components to their SI condition in accordance with Attachment 3.

SI Actuation is a Trigger to trip the A Charging/SI pump.

The B Charging/SI pump will not Auto-Start on SI.

Attachment 3, SI Equipment Verification, is included as an attachment to this guide on page 47.

NRC 2015 Scenario 1

- NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 8 Page: 35 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior BOOTH OPERATOR If contacted about the A Charging Pump Trip wait Zrninutes and report that the breaker is tripped.

If contacted to align the C CHG/SI wait 1 minute:

. Use LOA-CVCO41 to tack-down A CHG/Sl.

. Report the C CHG/Sl breaker will not rack-up.

. Acknowledge requests for support.

BOP 6 Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION. EOP-1.0 Crew 7 Announce plant conditions over the page system. EOP-1 .0

RO 8 Verify RB pressure has remained LESS THAN 12 psig on PR-951, EOP-1 .0 RB PSIG (P-951), red pen.

RO 9 Check RCS temperature: EOP-1.0 I . With any RCP running, RCS Tavg is stable at OR trending to 557°F.

OR

. With no RCP running, RCS Tcold is stable at OR trending to 557°F.

RO 10 Check PZR PORVs and Spray Valves: EOP-1.0

a. PZR PORVs are closed.

b. PZR Spray Valves are closed.

c. Verify power is available to at least one PZR PORV Block Valve:

. MVG-8000A, RELIEF 445 A ISOL.

. MVG-8000B, RELIEF 444 B ISOL.

. MVG-8000C, RELIEF 445 B ISOL.

d. Verify at least one PZR PORV Block Valve is open.

NOTE-Step 11 EOP-1 .0 Seal Injection flow should be maintained to all RCPs.

NRC 2015- Scenario I 35 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 8 Page: 36 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior RO 1 1 Check if RCPs should be stopped: EOP-1 .0

a. Check if either of the following criteria is met:

V

. Annunciator )(P-61 2 42 is lit (PHASE B ISOL).

OR

. RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

EVALUATOR NOTE: In accordance with OAR-I 34.4, EOP/AOP Users Guide, RCP Trip Criteria for RCS pressure less than 1418 psig with SI flow do not apply in an event initiated from Mode 2.

RO b. Stop all RCPs. EOP-1 .0 RO 12 Verify no SG is FAULTED: EOP-1.0

. No SG pressure is decreasing in an uncontrolled manner.

. No SG is completely depressurized.

RO 13 Verify Secondary radiation levels indicate SG tubes are NOT EOP-1.0 RUPTURED:

. RM-GI9A(B)(C), STMLN HI RNG GAMMA.

. RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.

. RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.

. RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.

RO 14 Check if the RCS is INTACT: EOP-1.0

a. RB radiation levels are normal on:

. RM-G7, CNTMT HI RNG GAMMA.

. RM-G18, CNTMT HI RNG GAMMA.

b. RB Sump levels are normal.

c. RB pressure is LESS THAN 1.5 psig.

d. The following annunciators are NOT lit:

. XCP-606 2-2 (RBCU 1N2A DRN FLO HI).

. XCP-607 2-2 (RBCU 1B/2B DRN FLO HI).

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 8 Page: 37 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior RO 15 Reset both SI RESET TRAIN A(B) Switches. EOP-1 .0 RO 16 Reset Containment Isolation: EOP-1 .0

. RESET PHASE A TRAIN A(s) CNTMT ISOL.

. RESET PHASE B TRAIN A(B) CNTMT ISOL.

RO 17 Place both ESF LOADING SEQ A(B) RESETS to: EOP-1.0

a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

RO 18 Establish Instrument Air to the RB: EOP-1.0

a. Start one Instrument Air Compressor and place the other in Standby.

b. Open PVA-2659, INST AIR TO RB AIR SERV.

I c. Open PVT-2660, AIR SPLY TO RB.

RO 19 Check if SI flow should be reduced: EOP-1 .0

a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN 52.5°F.

b. Secondary Heat Sink is adequate:

. Total EFW flow to the SGs is GREATER THAN 450 gpm.

OR

. Narrow Range level is GREATER THAN 26% in at least one SG.

c. RCS pressure is stable OR increasing. (NO)

ALTERNATIVE ACTION

c. GO TO Step 20.

NOTE - Step 20 EOP-1.0 Procedures referenced in EOP-12.0, MONITORING OF CRITICAL SAFETY FUNCTIONS, may now be implemented.

I NRC 2015- Scenario I 37 - NUREG -1021 R9 SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 38 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/SI Auto-Start Failure.

Time Position Applicants Actions or Behavior CRS 20 Initiate monitoring of the Critical Safety Function Status Trees. EOP-1.0 REFER TO EOP-12.0, MONITORING OF CRITICAL SAFETY FUNCTIONS.

RO 21 Check SG levels: EOP-1.O

a. Verify Narrow Range level in all SGs is GREATER THAN 26%.

b. Control EFW flow to maintain Narrow Range SG levels between 26% and 60%.

BOOTH OPERATOR Acknowledge request to sample SGs RO 22 Check if Secondary activity is normal: EOP-1 .0

a. Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.

b. Notify Chemistry to sample all SG secondary sides for abnormal activity.

CRS 23 Check for loss of Reactor Coolant outside Containment: EOP

a. Verify AB radiation levels are normal on: (NO)

. RM-A3, MAIN PLANT VENT EXH ATMOS MONITOR:

PARTICULATE, IODINE, GAS.

. RM-A13, PLANT VENT HI RANGE.

. RM-A1 1, AB VENT GAS ATMOS MONITOR.

. Local area monitors.

b. Verify annunciator XCP-631 6-1 is NOT lit (AB SMP LVL HI).

c. Verify annunciators XCP-606 3-4 and XCP-607 3-4 are NOT lit (LD TRBL AB SMP/FLDRN LVL HI).

ALTERNATIVE ACTION 23 Evaluate the cause of abnormal AB conditions. IF the cause is a loss of RCS inventory outside Containment, THEN GO TO EOP-2.5, LOCA OUTSIDE CONTAINMENT, Step 1.

CRS Transition to EOP-2.5, LOCA OUTSIDE CONTAINMENT, Step 1.

NRC 2015- Scenario 1 38 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 39 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position I Applicants Actions or Behavior NOTE

As valves are isolated, t may be necessary to monitor RCS pressure for a.period of time to determine if the leak is isolated.

Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

Crew 1 Announce plant conditions over the page system. EOP-2.5 RO 2 Ensure the following are closed: EOP-2.5

a. RHR Pump Suction Valves from the RCS:

1) MVG-8701A and MVG-8702A, RCS LP A TO PUMP A (Status Lights XCP-6106 1-11(2-11)), for Train A.

2) MVG-8701 B and MVG-8702B, RCS LP C TO PUMP B (Status Lights XCP-6106 1-12(2-12)), forTrain B.

b. Other paths out of Containment:

1) Normal Letdown Isolation

PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

PVT-8152, LTDN LINE ISOL.

2) RCP Seal Return Isolation:

MVT-8100, SEAL WTR RTN ISOL.

MVT-8112, SEAL WTR RTN ISOL.

3) PZR Sample Isolation:

SVX-9356A, PZR STM SMPL ISOL.

SVX-9356B, PZR LIQ SMPL ISOL.

4) RCS Loop B Sample Isolation:

SVX-9364B, RCS LP B SMPL ISOL.

SVX-9365B, RCS LP B SMPL ISOL.

5) RCS Loop C Sample Isolation:

SVX-9364C, RCS LP C SMPL ISOL.

SVX-9365C, RCS LP C SMPL ISOL.

RO 3 Check if RCS pressure is continuing to decrease. EOP-2.5 I

NRC 2015- Scenario 1 39 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-01 Scenario# 1 Event # 8 Page: 40 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position ] Applicants Actions or Behavior RO 4 Try to identify and isolate the break: EOP-2.5

a. Close MVG-8888A, RHR LP A TO COLD LEGS.

b. Check if RCS pressure is continuing to decrease.

c. Open MVG-8888A, RHR LP A TO COLD LEGS.

EVALUATOR NOTE: The following step isolates the leak from the RCS.

RO d. Close MVG-8888B, RHR LP B TO COLD LEGS. EOP-2.5

e. Check if RCS pressure is continuing to decrease. (NO) s I

ALTERNATIVE ACTION 0

e. GO TO EOP-2.O, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1.

CR8 Direct the implementation of EOP-2.0, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1.

NRC 2015 - Scenario I -40 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 41 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position Applicants Actions or Behavior REFERENCE PAGE FOR EOP-2.0 EOP-2.O 1 SI REINITIATION CRITERIA IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary:

RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN 52.5°F [67.5°F].

PZR level can NOT be maintained GREATER THAN 10% [28%].

2 RCP TRIP CRITERIA See note on IF either of the following criteria is met, THEN trip all RCPs: next page

Annunciator XCP-612 4-2 is lit (PHASE B ISOL). for RCP Trip Criteria

RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on Fl-943, CHG LOOP B CLD/HOT LG FLOW GPM.

3 SECONDARY INTEGRITY TRANSITION CRITERIA IF any unisolated SG pressure is decreasing in an uncontrolled manner OR is completely depressurized, THEN GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.

4 TUBE RUPTURE TRANSITION CRITERIA IF any SG level increases in an uncontrolled manner OR if any SG has abnormal radiation, THEN start Charging Pumps and operate valves as necessary, and GO TO EOP-4.0, STEAM GENERATOR TUBE RUPTURE, Step 1.

5 COLD LEG RECIRCULATION TRANSITION CRITERION IF RWST level decreases to LESS THAN 18%, THEN GO TO EOP-2.2, TRANSFER TO COLD LEG RECIRCULATION, Step 1.

6 LOSS OF EMERGENCY COOLANT RECIRCULATION TRANSITION CRITERION IF Emergency Coolant Recirculation is established and subsequently lost, THEN GO TO EOP-2.4, LOSS OF EMERGENCY COOLANT RECIRCULATION, Step 1.

7 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505, CONTROL BUILDING VENTILATION SYSTEM.

NOTE EOP-2.O

The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

Seal injection flow should be maintained to all RCPs.

Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

EVALUATOR NOTE: If flow has been High Head Safety Injection flow has been established with RCS pressure < 1418 psig and the RCPs ate running they should be stopped in the following step.

NRC 2015 - Scenario 1 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 8 Page: 42 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: In accordance with CAP-I 34.4, EOP/AOP Users Guide, RCP Trip Criteria for RCS pressure less than 1418 psig with SI flow do not apply in an event initiated from Mode 2.

RO I Check if RCPs should be stopped: EOP-2.O

a. Check if either of the following criteria is met:

Annunciator XCP-612 4-2 is lit (PHASE B ISOL).

OR

RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

b. Stop all RCPs.

RO 2 Verify no SG is FAULTED: EOP-2.O

No SG pressure is decreasing in an uncontrolled manner.

No SG is completely depressurized.

RO 3 Check INTACT SG levels: EOP-2.O

a. Verify Narrow Range level in INTACT SGs is GREATER THAN 26%.

b. Control EFW flow to maintain Narrow Range level in each INTACT SG between 40% and 60%.

RO 4 Reset both SI RESET TRAIN A(B) Switches. EOP-2.O RO 5 Reset Containment Isolation: EOP-2.O

RESET PHASE A TRAIN A(B) CNTMT ISOL.

RESET PHASE B TRAIN A(B) CNTMT ISOL.

NRC 2015- Scenario 1 - 42 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 1 Event # 8 Page: 43 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior RO 6 Check if Secondary radiation levels are normal: EOP-2.O

a. Check radiation levels normal on:

. RM-GI9A(B)(C), STMLN HI RNG GAMMA. V V

V V

. RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.

. RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.

. RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.

b. Place SVX-9398A(B)(C), SG A(B)(C) SMPL ISOL, in AUTO.

c. Notify Chemistry to sample all SG secondary sides, and screen samples for abnormal activity using a frisker.

RO 7 Check PZR PORVs and Block Valves: EOP-2.O

a. Verify power is available to the PZR PORV Block Valves:

1) MVG-8000A, RELIEF 445 A ISOL.

2) MVG-8000B, RELIEF 444 B ISOL.

3) MVG-8000C, RELIEF 445 B ISOL.

CAUTION Step 7.b

- EOP-2.O If any PZR PORV opens because of high PZR pressure, Step 7.b should be repeated after pressure decreases to LESS THAN 2330 psig, to ensure the PORV recloses.

RO b. Verify all PZR PORVs are closed. EOP-2.O

c. Verify at least one PZR PORV Block Valve is open.

RO 8 Place both ESF LOADING SEQ A(B) RESETS to: EOP-2.O

a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

RO 9 Establish Instrument Air to the RB: EOP-2.O

a. Start one Instrument Air Compressor and place the other in Standby.

b. Open PVA-2659, INST AIR TO RB AIR SERV.

c. Open PVT-2660, AIR SPLY TO RB.

NRC 2015 - Scenario I NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # 8 Page: 44 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior

RO 10 Check if SI flow should be reduced: EOP-2.O

a. RCS subcooling on TI-499A( 8), A(B) TEMP °F is GREATER THAN 52.5°F.

b. Secondary Heat Sink is adequate:

. Total EFW flow to INTACT SGs is GREATER THAN 450 gpm.

OR

. Narrow Range level is GREATER THAN 26% in at least one INTACT SG.

c. RCS pressure is stable OR increasing.

NOTE Step 10.d EOP-2.O If PZR level is LESS THAN 10% [28%], the PZR should refill from SI flow after pressure is stabilized.

RO d. PZR level is GREATER THAN 10%. EOP-2/

RO e. GO TO EOP-1.2, SAFETY INJECTION TERMINATION, Step 1. EOP-2.O REFERENCE PAGE FOR EOP-1.2 EOP-1.2 1 SI REINITIATION CRITERIA Following SI termination, IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary, and GO TO EOP-2.0, LOSS OF REACTOR OR SECONDARY COOLANT, Step 1:

. RCS subcooling on TI-499A(B), A(B) TEMP °F, is LESS THAN 52.5°F [67.5°F].

OR

. PZR level can NOT be maintained GREATER THAN 10% [28%].

2 SECONDARY INTEGRITY TRANSITION CRITERIA IF any unisolated SG pressure is decreasing in an uncontrolled manner OR is completely depressurized, THEN GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.

3 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-SOS, CONTROL BUILDING VENTILATION SYSTEM.

NOTE EOP-1 The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

NRC 2015- Scenario 1 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-O1 Scenario # 1 Event # 8 Page: 45 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/Sl Auto-Start Failure.

Time Position Applicants Actions or Behavior RO 1 Stop all but one Charging Pump and place in Standby. EOP-1 .2 RO . 2 Verify RCS pressure is ta.bleO.R increasing. .. .

EOP-1.2 RO 3 Establish Normal Charging: EOP-1.2

a. Close FCV-122, CHG FLOW.

b. Open both MVG-8107 and MVG-8108, CHG LINE ISOL.

c. Adjust FCV-122, CHG FLOW, to obtain 70 gpm Charging flow.

d. Close both MVG-8801A(B), HI HEAD TO COLD LEG INJ.

RO 4 Control FCV-122, CHG FLOW, to maintain PZR level. EOP-1 .2 RO 5 Check if RHR Pumps should be stopped: EOP-1 .2

a. Check if any RHR Pump is running with suction aligned to the RWST.

b. Stop any RHR Pump which is running with suction aligned to the RWST and place in Standby.

RO 6 Verify SI flow is NOT required: EOP-1 .2

a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN 52.5°F.

b. PZR level is GREATER THAN 10%.

NRC 2015- Scenario I NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 1 Event # 8 Page: 46 of 49 Event

Description:

LOCA Outside the Reactor Building, SI Train A Actuation Failure, A Chg Pp Trip, B CHG/SI Auto-Start Failure.

Time Position Applicants Actions or Behavior RO 7 Check if Letdown can be established: EOP-1 .2

a. verify PZR level is GREATER THAN 22%.

b. Establish Normal Letdown:

1) Adjust FCV-122, CHG FLOW, to obtain 70 gpm Charging flow.

2) Set PCV-145, LO PRESS LTDN, to 70%.

3) Open TCV-144, CC TO LTDN HX.

4) Open PVT-8152, LTDN LINE ISOL.

5) Open both LCV-459 and LCV-460, LTDN LINE ISOL.

6) Open desired Orifice Isolation Valve(s) to obtain 60 gpm to 120 gpm:

PVT-8149A, LTDN ORIFICE A ISOL (45 gpm).

PVT-8149B, LTDN ORIFICE B ISOL (60 gpm).

PVT-8149C, LTDN ORIFICE C ISOL (60 gpm).

7) Adjust FCV-122, CHG FLOW, to maintain TI-140, REGEN HX OUT TEMP °F, between 250°F and 350°F while maintaining PZR level.

8) Adjust PCV-145, LO PRESS LTDN, to maintain P1-145, LO PRESS LTDN PRESS PSIG, between 300 psig and 400 psig.

9) Place PCV-145, LO PRESS LTDN, in AUTO.

10) Place TCV-144, CC TO LTDN HX, in AUTO.

EVALUATOR NOTE: Terminate scenario after normal charging and letdown is established.

NRC 2015- Scenario 1 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-1 3-01 Scenario # 1 Event # NA Page: 47 of 49 Event

Description:

SI Equipment Verification (ATTACHMENT 3)

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: Due to the Failure of Safety Injection Train A Actuation, Train A Pumps and Valves will need to be manually positioned to their required condition.

BOP ,. 1 Ensure EFVV Pumps re running: EOP-1.O Attachment 3

a. Ensure both MD EFW Pumps are running.

b. Verify the TD EFW Pump is running if necessary to maintain SG levels.

BOP 2 Ensure the following EFW valves are open: Attachment 3

. FCV-3531(3541)( 3551), MD EFP TO SG A(B)(C).

. FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).

. MVG-2802A(B), MS LOOP B(C) TO TD EFP.

BOP 3 Verify total EFW flow is GREATER THAN 450 gpm. Attachment 3 BOP 4 Ensure FW Isolation: Attachment 3

a. Ensure the following are closed:

FW Flow Control, FCV-478(488)(498).

FW Isolation, PVG-161 1A(B)(C).

FW Flow Control Bypass, FCV-3321(3331)(3341).

SG Blowdown, PVG-503A(B)(C).

SG Sample, SVX-9398A(B)(C).

b. Ensure all Main FW Pumps are tripped.

EVALUATOR NOTE: It is a critical task to start the B Charging Pump, if it has not been previously started, to provide High Head Safety Injection.

BOP 5 Ensure SI Pumps are running: Attachment 3

Two Charging Pumps are running.

I

°

Both RHR Pumps are running.

BOP 6 Ensure two RBCU Fans are running in slow speed (one per train). Attachment 3 NRC 2015- Scenario I NUREG -1021 R9 SI

Appendix D Operator AcUons Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 1 Event # NA Page: 48 of 49 Event

Description:

SI Equipment Verification (ATTACHMENT 3)

Time Position Applicants Actions or Behavior BOP 7 Verify Service Water to the RBCUs: Attachment 3

a. Ensure two Service Water Pumps are running.

b. \ierifybothService Water Booster Pumps A(B) are running.

c. Verify GREATER THAN 2000 gpm flow for each train on:

. FI-4466, SWBP A DISCH FLOW GPM.

. F[-4496, SWBP B DISCH FLOW GPM.

BOP 8 Verify two COW Pumps are running. Attachment 3 BOP 9 Ensure two Chilled Water Pumps and Chillers are running. Attachment 3 BOP 10 Verify both trains of Control Room Ventilation are running in Attachment 3 Emergency Mode.

BOP 1 1 Check if Main Steamlines should be isolated: Attachment 3

a. Check if any of the following conditions are met:

. RB pressure GREATER THAN 6.35 psig.

OR

Steamline pressure LESS THAN 675 psig.

OR

. Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.

b. Ensure all the following ate closed:

. MS Isolation Valves, PVM-2801A(B)(C).

. MS Isolation Bypass Valves, PVM-2869A(B)(C).

BOP 12 Ensure Excess Letdown Isolation Valves are closed: Attachment 3

. PVT-8153, XS LTDN ISOL.

. PVT-8154, XS LTDN ISOL.

BOP 13 Verify ESF monitor lights indicate Phase A AND Containment Attachment 3 Ventilation Isolation on XCP-6103, 6104, and 6106.

REFER TO ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MOB STATUS LIGHT LOCATIONS, as needed.

NRC 2015- Scenario 1 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 1 Event # NA Page: 49 of 49 Event

Description:

SI Equipment Verification (ATTACHMENT 3)

Time Position Applicants Actions or Behavior BOP 14 Verify proper SI alignment: Attachment 3

a. Verify SI valve alignment by verifying SAFETY

. INJECTION/PHASE A ISOL monitor lights are bright on XCP-6104.

BOP b. Verify all SAFETY INJECTION monitor lights are dim on Attachment 3 XCP-61 06.

c. Verify SI flow on Fl-943, CHG LOOP B CLD/HOT LG FLOW GPM.

U. Check if RCS pressure is LESS THAN 325 psig. (NO)

ALTERNATIVE ACTION

d. ATTACHMENT 3, SI EQUIPMENT VERIFICATION, is complete.

BOP Report completion of Attachment 3.

EVALUATOR NOTE: ATTACHMENT 3 is complete.

NRC 2015- Scenario I -49 - NUREG -1021 R9S1

Appendix D Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No: 2 Op Test No: NRC-ILO-13-01 Examiners: Operators: CRS:

RO:

. BOP: -. .

Initial Conditions: 60% Power MOL.

Bi Train Work Week.

The National Weather Service has declared a Severe Weather Warning for Richland, Fairfield, and Kershaw counties for the next four (4) hours.

Alternate Seal Injection is OOS.

C MEW Pump is not running.

. Investigating small steam leak on C MEW Pump Casing.

Turnover: Maintain current power until Maintenance releases the C MEW Pump for operation.

Critical Tasks: Maintain SG Level without causing a Reactor/Turbine trip.

Close A or B MSIV Prior to Orange path on Integrity or Containment.

Isolate EFW to the faulted SG prior to Orange path reached on Integrity.

Event Mall No. Event Type* Event Description No.

1 CVCDO8 C-RO, CRS Isolable Letdown Line Leak Inside Reactor Building 50 TS-CRS gpm.

2 MSOO5O 1-BOP, CRS FT-494 (C Steam Flow Transmitter) fails LOW.

TS-CRS 3 NA N-BOP, CRS Rapid downpower due to B MFW pump vibration.

R-RO 4 CRFOO7H14 C-RO, CRS Rod H14 stuck but trippable (blown fuse).

TS-CRS 5 EWO17O 1-BOP, CRS PT-508 (MEW Pump Discharge Header Pressure) Fails LOW. (Manual control of MFW Pp speed)

NRC 2015 Scenario 2 1 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 6 MSSOO3A M-ALL A Main Steamline Break inside the RB due to a AUXOO9AA seismic event.

AUXOO9AB AUXOO9AC EPSO13 Main Generator and Voltage Regulator Breakers Fail to Trip.

MSSOO6A SG A and B MSIV Fails toClosein AUTO.

MSSOO6B ..

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor NRC 2015 Scenario 2 2- NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 The following notation is used in the ES-D-2 form Time column:

IOA designates Immediate Operator Action steps.

designates Continuous Action steps.

The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.

GOP-4A, Power ascension was halted at 60% due to a mechanical problem with the C MEW Pump. The current power level has been maintained for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Xenon is stable. The crew instructions are to maintain the current power until mechanical maintenance releases the C MEW Pump for operation.

EVENT 1: Isolable Letdown Line Leak Inside Reactor Building -50 gpm.

TRIGGER I o MAL-CVCOO8 LETDOWN LINE LEAK INSIDE CONTAINMENT El NAL=30%

On cue from the Examiner, a 50 gpm leak will be inserted on the letdown line inside the Reactor Building. The crew will identify that a leak exists and implement AOP-1 01.1, Loss of Reactor Coolant Not Requiring SI. The RO will isolate the leak by isolating letdown. The RO will then place excess letdown in service.

The CRS will refer to Technical Specification 3.4.6.2, Operational Leakage.

EVENT 2: FT-494 (C Steam Flow Transmitter) fails LOW.

TRIGGER 2 o XMT-MSOO5O 1FT00494 SG C STEAM FLOW FAIL TO POSN El NAL=0 On cue from the Examiner, FT-494 will fail LOW. This is the selected C SG selected Steam Flow transmitter for SG level control. ECV-498 will stroke closed causing SG level to lower. The crew will implement AOP-401 .3 Steam Elow Feedwater Flow Protection Channel Eailure and select the operable Steam Flow Transmitter for control. This is a Technical Specification transmitter.

The CRS will refer to Technical Specification 3.3.1, Reactor Trip System Instrumentation, Action 6 and 3.3.2, Engineered Safety Feature Actuation System Instrumentation, Action 24.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 EVENT 3: Rapid downpower due to B MFW pump vibration.

The Shift Supervisor will call the CRS and report that the B Main Feedwater Pump vibration is in alert. He will instruct to crew to lower power to less than 45% at 3% per minute in accordance with GOP-4C Rapid Power Reduction and leave the pump running for engineering to evaluate.

The RO will utilize boration and/or rod control to lower power while coordinating the downpower with the BOP who will be controlling turbine demand.

EVENT 4: Rod H14 stuck but trippable (blown fuse).

AUTO-TRIGGER 3 FNISPR(2) < 56 (N-42 indicates < 56% Power) o MAL-CRFO07H14 STUCK ROD H-14 FAIL TO: TRIPPABLE

TRIGGER 4 o MAL-CRFOO7H14 STUCK ROD H-14 FAIL TO: TRIPPABLE DELETE=00:00:01 Removes failure to allow rod recovery This event will occur when power is reduced to less than 56% or earlier if directed by the Examiner. Control Rod H-14 in Control Bank D will stop moving. This event must be inserted early enough in the downpower so that the failure will be apparent as power is lowered. The RO will realign the control rods in accordance with AOP-403.5 Stuck or Misaligned Control Rod.

The CRS will refer to Technical Specification 3.1.3.1, Movable Control Assemblies.

EVENT 5: PT-508 (MFW Pump Discharge Header Pressure) Fails LOW. (Manual control of MFW Pp speed).

TRIGGER 5 o XMT-FW0170 1PT00508 FW PP DSCHG HDR PRESS P1-508 FAIL TO POSN Fl NAL=200 On cue from the Examiner, a Main Feedwater Header Pressure transmitter will fail LOW causing the MFW Pump speed to increase and raise SG level. The operators will respond to annunciators and implement AOP-210.3, Feedwater Pump Malfunction.

The BOP will take manual control of the master Speed control and adjust speed to maintain Feedwater Pump discharge pressure 150 to 250 psi greater than Main Steam Header pressure and restore SG levels.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 EVENT 6: A Main Steamline Break inside the RB due to a seismic event.

PRE-LOAD o MAL-EPSO13 GENERATOR BREAKER FAILS TO TRIP

TRIGGER 6 o MAL-AUXOO9AB SEISMIC EVENT EARTHQUAKE 2/3 O.B.E.(UP/DOWN VERTICAL)

Final Value 2.1 Delay = 0 o MAL-AUXO09AA SEISMIC EVENT EARTHQUAKE 2/3 O.B.E.(NORTH/SOUTH HORIZONTAL)

Final Value = 3.2 Delay = 1 sec o MAL-AUXOO9AC SEISMIC EVENT EARTHQUAKE 2/3 O.B.E.(EASTIWEST HORIZONTAL)

Final Value = 4.2 Delay = 1 sec o MAL-MSSOO3A STEAMLINE S/G A BREAK INSIDE CONTAINMENT Final Value = 3E+6 Ibm/hr Delay = 10 sec o MAL-EPSO13 GENERATOR BREAKER FAILS TO TRIP o MAL-MSSOO6A MAIN STEAM ISOLATION VALVE (S/G A) FAILURE Fail to: FAILURE TO CLOSE o MAL-MSSOO6B MAIN STEAM ISOLATION VALVE (S/G B) FAILURE Fail to: FAILURE TO CLOSE

AUTO-TRIGGER 7 X101041C == I (MSIV A Taken to CLOSE) o MAL-MSSOO6A MAIN STEAM ISOLATION VALVE (S/G A) FAILURE Delete = 00:00:01

AUTO-TRIGGER 8 X1OIO42C 1 (MSIV B Taken to CLOSE) o MAL-MSSOO6B MAIN STEAM ISOLATION VALVE (S/G B) FAILURE Delete = 00:00:01 On cue from the Examiner, seismic monitors will indicate a seismic event has occurred. Ten (10) seconds later a steamline break inside the Reactor Building will be inserted. The Reactor will trip and the crew will implement EOP-1 .0 (E-0) Reactor Trip/Safety Injection Actuation. The crew will identify that at least one Steam generator is faulted and transition to EOP-3.0 (E-2),

Faulted Steam Generator Isolation. When the faulted SG is isolated the crew will transition to EOP-1 .2 (ES-i .1), Safety Injection Termination.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 The malfunction will be apparent after the Reactor Trip. The crew will identify that the Main Generator Output Breaker failed to automatically trip and the BOP will manually open the breaker from the control board.

The BOP must identify that the MSIVs are open and manually close them from the control board to isolate the faulted Steam Generator and prevent over-pressurization of the Reactor Building.

TERMINATION:

The scenario can be terminated after the crew has transitioned to EOP-1.2 (ES-1.1), Safety Injection Termination, and terminated Safety Injection or at the discretion of the Examiner.

Scenario Attributes Events

Letdown Line Leak Inside Reactor Building 50 gpm.

. FT-494 (C Steam Flow Transmitter) fails LOW Rod H14 stuck but it can be tripped (blown fuse).

Iota ivia f unctions PT-508 (MFW Discharge Header Pressure) Fails LOW I

s -

A MSLB inside Reactor Building

. Main Gen and Voltage Regulator Breakers Fail to Trip SG A and B MSIV Fails to Close in AUTO.

Malfunctions after Main Generator and Voltage Regulator breakers fail to trip.

2 EOP entry (1-2) A and B MSIVs fail to close in auto.

. Letdown Line Leak Inside Reactor Building 50 gpm.

Abnormal Events FT-494 (C Steam Flow Transmitter) fails LOW (2-4) Rod H14 stuck but it can be tripped (blown fuse).

PT-508 (MFW Discharge Header Pressure) Fails LOW Major Transient 1 Faulted Steam Generator (MSLB inside RB)

EOP-3.0 (E-2) Faulted Steam Generator Isolation EOPs Entered (1-2) 2 EOP-1.2 (ES-li), Safety Injection Termination EOP Contingencies 0

(0-2)

Maintain SG Level without a Reactor/Turbine trip.

.. Close A or B MSIV Prior to Orange path on Integrity or Critical Tasks 3 Containment.

2 k 3I Isolate EFW to the faulted SG prior to Orange path reached on Integrity.

NRC 2015 Scenario 2 NUREG-1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 SIMULATOR SCENARIO SETUP INITIAL CONDITIONS:

ICSet291

60% Power

Rod Position = 173

FCV-1 13 Pot Setting = 4.81

Boron=ll22ppm

Xe=-2815pcm

Burnup = 10,000 MWD/MTU

Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCO action time expires.)

PRE-EXERCISE:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)

VCS-TQP-0807 Attachment I-A, Unit 1 Booth Instructor Checklist, has been completed.

Verify the Hard Card for Turbine Load changes is in its proper storage location.

Verify the Hard Card for borating via MVT-8104 is in its proper storage location.

Hang Tags for equipment out of service.

Mark up procedures in use with Circle and Slash as applicable.

o GOP-4A, POWER OPERATION (MODE 1 - ASCENDING) marked to step 3.16

Prepare a turnover sheet for each position.

Conduct two-minute drill.

The simulator may be left running at turnover (stable plant conditions).

Ensure SIPCS rod position is matched to DRPI indication.

PRELOAD:

STANDARD SIMULATOR SETUP:

PMP-LDOO3P, LEAK DETECTION SUMP PMP LOSS OF POWER

VLV-FWO28W, FW HDR RECIRC ISOL VLV LOSS OF POWER

VLV-FWO29W, FW HTR RECIRC ISO VLV LOSS OF POWER

VLV-CSO52W, RCP A SEAL LEAKOFF VLV LOSS OF POWER

VLV-CSO53W, RCP B SEAL LEAKOFF VLV LOSS OF POWER

VLV-CSO54W, RCP C SEAL LEAKOFF VLV LOSS OF POWER NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 SCENARIO RELATED

ALTERNATE SEAL INJECTION OUT-OF-SERVICE ANN-CS044, ALT SEAL INJ PUMP TRBL Fail to: ON

ANN-CS046, ALT SEAL DIG TRBL Fail to: ON

MAL-CVSO27, ASI D/G FAIL TO START

MAL-CVCO29, ASI PUMP FAIL TO START NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-01 Scenario # 2 Event # 1 Page: 9 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: When directed, initiate Event 1 (TRIGGER 1).

EVALUATOR NOTE: On cue from the Examiner, a 50 gpm leak will be inserted on the letdown line inside the Reactor uilding. The crew will identify that a leak exists and imptementAOP 101.1, Loss of Reactor Coolant Not Requiring SI. The RO.will isolate the leak by isolating letdown. The RO will then place excess letdown in service.

Indications Available:

Charging increasing with no change in Letdown Changing RB environmental conditions XCP-6061607-2-2, RBCU Drain Flow alarms XCP-614-5-1, CHG LINE FLO HI/LO XCP-615-3-6, RCS Leak Calculation alarm RM-A2 HI RAD Additional Alarms which may occur as time elapses:

XCP-606 3-2 LD TRBL RB/INCORE SUMP LVL HI XCP-607 3-2 LD RB SMP LVL HI EVALUATOR NOTE: If the BOP responds to the HVAC alarms the BOOTH OPERATOR will ENSURE that an INSTRUCTOR notifies the BOP that the Control Building Operator will handle all future HVAC alarms.

BOOTH OPERATOR If necessary direct an Instructor to relieve the BOP as the Control Building Operator. Inform the BOP that you will handle all future HVAC alarms.

When the HVAC panel annunciates acknowledge the alarm.

Report as the Control Building Operator (Unit 4)

High Temperature alarm in STEAM GENERATOR A COMPARTMENT and

High Temperature alarm in REACTOR COMPARTMENT COOLING SYSTEM.

EVALUATOR NOTE: If Primary containment average air temperature exceeds 120°F then Technical Specification 3.6.1.5 Action applies:

With the containment average air temperature greater than 120F, reduce the average air temperature to within the limit within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

NRC 2015 Scenario 2 9- NUREG-10.21 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 1 Page: 10 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time Position Applicants Actions or Behavior xcP-614 5-1 RO CORRECTIVE ACTIONS:

3. Monitor LT-1 12A and LT-1 15, % LEVEL, to verify proper VCT level.

4. Monitor Fl-i 22A, CHG FLOW GPM.

. SUPPLEMENTAL ACTIONS:

6. If RCS leakage is indicated, determine the leak rate and refer to Technical Specification 3.4.6.2.

CRS Determines than RCS leakage is indicated and implements AOP-101.1, LOSS OF REACTOR COOLANT NOT REQUIRING SI.

AOP-1 01.1 NOTE

If a Reactor Trip occurs AND SI is NOT required, this procedure should be continued after the actions of EOP-1.i, Reactor Trip Recovery, are completed.

As valves are isolated, it may be necessary to monitor RCS pressure for a period of time to determine if the leak is isolated.

RO 1 Verify PZR level is at or trending to program level.

0 AOP-1Of RO 2 Check if SI is required: (NO) AOP-1O1 .1

a. Check if any of the following criteria are met:

PZR level is decreasing with Charging maximized and Letdown minimized.

OR

PZR level is approaching 8%.

OR

PZR pressure is approaching 1870 psig.

OR

VCT level is approaching 5%.

ALTERNATIVE ACTION

a. GOTOStep3.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 2 Event # 1 Page: 11 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time Position I Applicants Actions or Behavior NOTE - Step 3 AOP-101 .1 Conditions for implementing Emergency Plan Procedures should be evaluated using EPP.001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

CRS 3 Determine RCS leak rate: AOP-101 .1

a. Estimate the RCS leak rate:

. REFER TO IPCS CHGNET.

. REFER TO IPCS 4RW1.

b. Estimate the RCS leak rate using IPCS VCT level. (14 gal/percent)

c. If necessary, calculate the RCS leak rate. REFER TO STP 114.002, OPERATIONAL LEAK TEST.

I CRS 4 Check if the RCS leak rate is GREATER THAN Technical AOP-101 .1 Specification 3.4.6.2 limits.

CRS 5 Comply with the applicable Technical Specification 3.4.6.2 action AOP-101 .1 statement.

CRS TS 3.4.6.2 Reactor Coolant System operational leakage shall be limited TS 3.4.6.2 to:

b. 1 GPM UNIDENTIFIED LEAKAGE, ACTION

b. With any operational Reactor Coolant System leakage greater than any one of the above limits, excluding PRESSURE BOUNDARY LEAKAGE, primary-to-secondary leakage, and leakage from Reactor Coolant System Pressure Isolation Valves, reduce the leakage rate to within limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

NRC 2015 Scenario 2 -11 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # 1 Page: 12 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

lime [ Position ] Applicants Actions or Behavior AOP-1O1 .1 RO 6 Verify RCS pressure is GREATER THAN 2210 psig.

EVALUATOR NOTE Step 7 isolates the letdown leak AOP-101.1 RO 7 Close all Letdown Isolation Valves:

a. PVT-8149A, LTDN ORIFICE A ISOL.

b. PVT-8149B, LTDN ORIFICE B ISOL.

c. PVT-8149C, LTDN ORIFICE C ISOL.

d. LCV-459, LTDN LINE ISOL.

e. LCV-460, LTDN LINE ISOL.

RO 8 Check if the leak has been isolated: AOP-101.1

a. Evaluate the following:

. IPCS CHGNET

. IPCS4RW1

. Pressurizer level

. VCT Level

. Reactor Building Conditions

b. If necessary, calculate the RCS leak rate. REFER TO SIP-i 14.002, OPERATIONAL LEAK TEST.

NRC 2015 Scenario 2 NUREG-1021 R9SJ

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 1 Page: 13 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE:

If the crew does not recognize that they have isolated the leak they will perform the Alternate actions for step 8 which isolates charging.

Alternative Actions will direct completion of steps 1 1 and 12 which duplicates steps 9 and 10.

AOP-101.1 ALTERNATIVE ACTION 8 Perform the following:

a) Isolate Charging by closing either of the following:

MVG-8107, CHG LINE ISOL.

MVG-8108, CHG LINE ISOL.

b) GOTOStepI1.

BOOTH OPERATOR If directed to investigate Relay Room Alarms report there are Reactor Building Sump A and B alarms for High Level and Leakage greater than 10 GPM.

Place Excess Letdown in service using Attachment 1, Establishing AOP-101 .1 RO 9 Excess Letdown.

NRC 2015 Scenario 2 NUREG-1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # 1 Page: 14 of 55 Event

Description:

Isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time Position Applicants Actions or Behavior RO 1 Place Excess Letdown in service: AOP-101 .1 ATTACH 1

a. Close FCV-122, CHG FLOW.

b. MaiitaihCorePower LESS THAN 2898 MWt prior to and during Excess Letdown operation.

c. Close all Letdown Isolation Valves:

1) PVT-8149A(B)(C), LTDN ORIFICE A(B)(C) ISOL.

2) LCV-459, LTDN LINE ISOL.

3) LCV-460, LTDN LINE ISOL.

d. Isolate Charging by closing either of the following:

. MVG-8107, CHG LINE ISOL.

. MVG-8108, CHG LINE ISOL.

e. Reduce Seal Injection flow to 7 gpm per RCP as indicated on the following:

. FI-130A, RCP A INJ FLO GPM.

. FI-127A, RCP B INJ FLO GPM.

. FI-124A, RCP C INJ FLO GPM.

f. Ensure HCV-137, XS LTDN HX, is closed.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 1 Page: 15 of 55 Event

Description:

lsolable Letdown Line Leak Inside Reactor Building - 50 gpm.

Time 1 Position Applicants Actions or Behavior

g. Place PVM-8143, XS LTDN TO VCT OR RCDT, in VCT position.

h. Ensure the following are open:

MVT-8100, SEAL WTR RTN ISOL.

MVT-8112, SEAL WTRRTN ISOL.

i. Ensure MVG-9583, FROM XS LTDN HX, is open.

j. Open the following:

PVT-8153, XS LTDN ISOL.

PVT-8154, XS LTDN ISOL.

k. Establish Excess Letdown flow:

1) Slowly throttle open HCV- 137, XS LTDN HX.

2) Maintain temperature on TI-139, XS LETDOWN HX OUT TEMP °F, LESS THAN 165°F.

I. Monitor the following to ensure flow between 0.2 gpm and 5.0 g pm:

FR-154A, RCP SL LKOFF HI RANGE.

FR-154B, RCP SL LKOFF LO RANGE.

10 GOTOStep42. AOP-101 .1 42 Evaluate Plant status: AOP-101 .1

a. Maintain stable plant conditions.

b. Consult with the Shift Supervisor to determine further actions.

43 RETURN TO Procedure and Step in effect. AOP-1 01.1 NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 1 Page: 16 of 55 Event

Description:

isolable Letdown Line Leak Inside Reactor Building 50 gpm.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: The next event may be inserted after excess letdown is placed in service.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 2 Page: 17 of 55 Event

Description:

FT-494 (C Steam Flow Transmitter) fails LOW.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: When directed, initiate Event 2 (TRIGGER 2).

EVALUATOR NOTE:

On cue from the Examiner, FT-494 will fail LOW. This is the selected C SG selected Steam Flow transmitter for SG.level control. FCV-498 wilt stroke closed causing SG level to lower. The crew will implement AOP-401 .3 Steam Flow Feedwater Flow Protection Channel Failure and select the operable Steam Flow Transmitter for control. This is a Technical Specification transmitter.

Technical Specifications 3.3.1, Reactor Trip System Instrumentation, Action 6 and 3.3.2, Engineered Safety Feature Actuation System Instrumentation, Action 24 requires that the inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Indications Available:

XCP-624 3-5, SG C LVL DEV XCP-624 6-4, SG C FWF>STF MISMATCH CR8 Implements AOP-401 .3, Steam Flow Feedwater Flow Protection Channel Failure I

NOTE AOP-401 .3 Throughout this procedure, AFFECTED refers to any SG experiencing level control problems.

IOA BOP 1 Verify the failed channel is the controlling channel. AOP-401.3 NOTE Step 2 AOP-401.3 FW AND STEAM CONTROL CHANNEL SEL Switches for a SG should be selected to the same direction (both to the left or both to the right).

IOA BOP 2 Select the operable flow channel: AOP-401 .3

Place FW CONTROL CHANNEL SEL Switch to the operable channel.

Place STEAM CONTROL CHANNEL SEL Switch to the operable channel.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 2 Page: 18 of 55 Event

Description:

FT-494 (C Steam Flow Transmitter) fails LOW.

Time Position I Applicants Actions or Behavior NOTE - Step 3 AOP-401 .3 CTRL+ALT+S on either EHC HMI is equivalent to 50 MWe, and is the preferred method to accomplish a rapid load reduction. . .

IOA BOP 3 Verify Turbine Load is LESS THAN 950 MWe. AOP-401 .3 IOA BOP 4 Verify only one SG is AFFECTED. AOP-401 .3 IOA BOP 5 Adjust the Feedwater Flow Control Valve as necessary to restore AOP-401 .3 feed flow to the AFFECTED SG.

IOA BOP 6 Check if Feedwater Pump speed control is operating properly: AOP-401.3

Feedwater Header pressure is GREATER THAN Main Steam Header pressure.

Feed flow is normal for steam flow and power level.

All operating Feedwater Pump speeds and flows are balanced.

BOP 7 Verify Narrow Range levels in all SGs are between 60% and 65%. AOP-401 .3 BOP 8 Restore the AFFECTED SG control systems to normal: AOP-401 .3

Place the Feedwater Flow Control Valve in AUTO.

Place the Feedwater Pump Speed Control System in AUTO.

REFER TO SOP-210, FEEDWATER SYSTEM.

NOTE Step 9 AOP-401 .3 Steam flow transmitters FT-474, FT-484, FT-494, FT-475, FT-485, and FT-495 are density compensated by steam pressure transmitters PT-475, PT-485, PT-495, PT-476, PT-486, and PT-496.

CRS 9 Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , place the failed channel protection bistables in a AOP-401 .3 tripped condition:

a. Identify the associated bistables for the failed channel. REFER TO Attachment 1.

NRC 2015 Scenario 2 18- NUREG-1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 2 Page: 19 of 55 Event

Description:

FT-494 (C Steam Flow Transmitter) fails LOW.

Time Position Applicants Actions or Behavior AOP-401 .3 FT-494 FB-494A C3-?48-BS-1 CHAN III LP C FB-494A TABLE 3.3-1 ITEM 14 302.030 Attachment 1 FB-4988 C3-7$9-BS-1 CHAN 111 SG C FB-4986 TABLE 3.3-3 tTEM 4. 395.006 CRS Identifies FB-474A and FB-478B as the affected Bistables. AOP-401 Attachment 1 CRS b. Record the following for each associated bistable on SOP-401, AOP-401 .3 REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:

Instrument.

Associated Bistable.

Bistable Location.

STPs.

CRS Refers to Technical Specifications: Tech Specs Table 3.3-1 item 14 (Action 6 within 72 hrs) The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

I Table 3.33 item 4.d (Action 24 within 72 hrs) The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

BOOTH OPERATOR Acknowledge requests for support in troubleshooting and placing channel in trip.

CRS c. Notify the I&C Department to place the identified bistables in trip. AOP-401.3 EVALUATE NOTE: The next event may be initiated after the applicable Technical Specification Actions have been identified.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 3 Page: 20 of 55 Event

Description:

Rapid downpower due to B MFW pump vibration.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR When directed by the Evaluator Call the Control Room as the Shift Supervisor

-The AO has reported to me that the B MEW Pump sounds unusual.

I am at the BMFW Pump with Engineering and Mechanical Maintenance.

Reduce power to less than 45% at 3% per minute lAW GOP-4C, Rapid Power Reduction.

Leave the B MEW Pump running for Engineering to evaluate.

GOP-4C GOP-4C REFERENCE PAGE GENERAL NOTES A. Procedure steps should nomially be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. After any Thermal Power change of greater than 15% within any one hour, Attachment IIl.H of GTP-702 must be completed.

C If Reactor Power is stabilized during this procedure for the purpose of raising power per GOP-4A, a Power Range Heat Balance shall be performed.

D. Once a Rapid Power Reduction has begun, every effort should be mode to prevent the Turbine from reaching AT SET LOAD unless it is desired to stabilize the plant.

REACTOR CONTROL A During operation with a positive Moderator Temperature Coefficient, power and temperature changes will require constant operator attention.

B Rod Control should be maintained in Automatic if any Pressurizer PORV is isolated.

co2 C. If at any time, power decreases unexpectedly below 0.1% on any Power Range Ni (computer indication available) OR below 1 0% on any Power Range NI control board indication (computer not available):

1) No positive reactivity will be added by rods or dilution.

2) A complete reactor shutdown shall be performed per GOP-5.

3) A controlled reactor startup may be commenced per GOP-3 once the event has been reviewed by Reactor Engineering.

REACTOR TRIP CRITERIA DURING RAPID LOAD REDUCTION A. If any of the following conditions occur, trip the Reactor and implement EOP-1 .0:

1) RCS T is less than 551°F for greater than 15 minutes.

2) Tvg/Tr mismatch exceeds 10°F.

3) Pressurizer pressure approaches 1870 psig.

4) Power reduction at 5% per minute is not sufficient to mitigate the event.

NRC 2015 Scenario 2 - 20 - NUREG-1021 R951

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 2 Event # 3 Page: 21 of 55 Event

Description:

Rapid downpower due to B MFW pump vibration.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: The crew will lower power from 60% in accordance with GOP-4C, Rapid Power Reduction. The RO will utilize boration and/or rod control to lower power while coordinating the downpower with the GOP who will be controlling turbine demand.

NOTE 3.0 GOP-4C If time allows, load reductions should be discussed with the Load Dispatcher.

CAUTION 3.1 through 3.12 GOP-4C

a. Thermal Power changes of greater than 15% in any one-hour period requires completion of GTP-702 Attachment lll.H.

b. VCS PID Report, POWER CHANGE SEARCH, should be periodically performed to ensure a thermal power change of greater than 15% in any one-hour period is detected.

RO 3.1 Commence rapid Plant Shutdown as follows: GOP-4C

a. Energize all Pressurizer Heaters.

NOTE 3.1.b GOP-4C Setting FCV-1 1 3A&B, BA FLOW SET PT to 8.3 will yield 33 gpm Boration flow rate.

RO b. Maintain the following with rod motion or boron concentration GOP-4C changes:

1) Tavg within 10°F and trending to Tref.

2) tl within limits.

3) Control Rods above the rod insertion limit.

RO c. Maintain Tavg within the control band by Control Rod motion or GOP-4C boron concentration changes.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 3 Page: 22 of 55 Event

Description:

Rapid downpower due to B MEW pump vibration.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE:

. SOP-106 HF, Borate Operations, is attached (Page 48).

. SOP-I 06 IV.D, Borating the RCS Using the Emergency Borate Valve, is attached (Page 50).

RO 3.1.d. Borate or dilute per SOP-I 06, Reactor Makeup Water System, to GOP-4C maintain the following parameters:

1) IXI within limits.

2) Control Rods above the Rod Insertion Limit.

NOTE 3.2 GOP-4C

a. Step 3.2 lowers Reactor Power from 90% to 48%.

b. While the plant is being maneuvered, total condensate flow through the Blowdown Heat Exchangers must be maintained greater than 450 gpm, which should maintain condensate outlet temperature at least 30°F below the DA temperature.

BOP 3.2 Reduce Reactor Power to 48% as follows:

GOP-4C EVALUATOR NOTE: Applicable portions of SOP-214 are attached (Page 51).

BOP a. Using the EHC HMI, Control/Load screen, reduce load per SOP- GOP-4C 214 at a rate of 3% per minute or less.

NOTE 3.2.b GOP-4C The System Controller should be notified prior to manually changing MVARs by more than 50 MVARs in a five minute period, unless the change is needed to prevent equipment damage.

BOP b. As load decreases, adjust Megavars using GEN FIELD VOLT GOP-4C ADJ as requested by the System Controller and within the Estimated Generator Capability curve (Enclosure A).

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-01 Scenario # 2 Event # 3 Page: 23 of 55 Event

Description:

Rapid downpower due to B MFW pump vibration.

Time ] Position ] Applicants Actions or Behavior BOP c. When Reactor Power is between 60% and 80%, reduce to the GOP-4C following pumps in service per SOP-210, Feedwater System:

. 1) Two Main Feedwater Pumps.

2) Three Feedwater Booster Pumps.

BOP d. When Reactor Power is between 60% and 75%, perform PTP GOP-4C 1 02.001, Main Turbine Tests (Power Operated Extraction System Check Valve portion only).

NA Power was never increased above 60%,

EVALUATOR NOTE: Event 4 (Stuck Rod) will be auto-triggered at 56% power so that it is apparent that a rod is not moving.

NRC 2015 Scenario 2 23- NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 2 Event # 4 Page: 24 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: NO ACTION REQUIRED.

Event 4 (TRIGGER 3) will auto-initiate when power is below 56%.

EVALUATOR NOTE: This event will auto-actuatewhen poWer is reduced below 56%. Control Rod H-14 in Control Bank D will stop moving. The RO will realign the control rods in accordance with AOP-403.5 Stuck or Misaligned Control Rod.

Indications available:

IPCS alarm, XCP-620 2-5 CMPTR ROD DEV Occurred at 51.8% during Work Week validation:

XCP-620 1-5 PR UP DET FLUX HI DEV AUTO DEFEAT CRS Refer to Alarm Response Procedure ARP-OO1-XCP-620 2-5 CORRECTIVE ACTIONS: XCP-6

1. Observe the Digital Rod Position Indication display for proper rod positions.

2. Determine if the cause is a dropped or misaligned rod.

3. If DRPI ALARM URGENT is in refer to ARP-OO1-XCP-621, 2-1.

SUPPLEMENTAL ACTIONS: XCP-620 2-5

1. If a rod is misaligned, refer to AOP-403.5, Stuck or Misaligned Rod.

3. Operate the Rod Control System in MAN as described in SOP-403 until proper automatic Rod Control in restored.

4. Refer to Technical Specification 3.1.3.1.

NRC 2015 Scenario 2 NUREG-1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 2 Event # 4 Page: 25 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: lithe crew is having difficulty due to continuing with the power reduction white implementing AOP-403.5, consider having the Booth Operator direct stopping the downpower.

BOOTH OPERATOR: If directed by the Lead Examiner: .

. Call the CRS as the SS.

. Direct the CRS to hold power while implementing the AOP to realign rods.

CRS Implement AOP-403.5, Stuck or Misaligned Rod.

CRS Apply Technical Specification 3.1.3.1 Action d TS-3.1 .3.1 Action d

d. With one full length rod inoperable due to causes other than addressed by ACTION a., above, or misaligned from its group step counter demand height by more thanl2 steps (indicated position),

POWER OPERATION may continue provided that within one hour either:

I 1. The rod is restored to OPERABLE status within the above alignment requirements, or

2. The remainder of the rods in the group with the inoperable rod are aligned to within 12 steps of the inoperable rod within one hour while maintaining the rod sequence and insertion limits specified in the CORE OPERATING LIMITS REPORT (COLR);

the THERMAL POWER level shall be restricted pursuant to Specification 3.1.3.6 during subsequent operation, or IOA RO 1 Place ROD CNTRL BANK SEL Switch in MAN. AOP-403.5 IOA RO 2 Check if Reactor Power is GREATER THAN OR EQUAL TO 5%. AOP-403.5 IOA BOP 3 Stabilize Main Turbine load/Steam Dumps demand. AOP-403.5

CREW 4 Maintain Tavg within 5°F of Tref using the following: AOP-403.5

. Main Turbine load or Steam Dumps demand adjustment.

. RCS Boration or Dilution. REFER TO SOP-i 06, REACTOR MAKEUP WATER SYSTEM.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 4 Page: 26 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time I Position I Applicants Actions or Behavior NOTE - Steps 5 through 16 AOP-403.5 Throughout the following steps, AFFECTED refers to any Rod Bank which contains a misaligned Control Rod.

RO 5 Record the misaligned Control Rod and AFFECTED Bank: AOP-403.5

. Misaligned Rod:

. AFFECTED Bank:

NOTE - Step 6 AOP-403.5 Computer rod positions can be found at Group Display DRPIRODS.

RO 6 Record the Control Rod positions and Group Step Counter AOP-403.5 demands:

. Control Bank A DRPI: Computer:

Demand Group 1: Demand Group 2:

. Control Bank B DRPI: Computer:

Demand Group 1: Demand Group 2:

. Control Bank C DRPI: Computer:

Demand Group 1: Demand Group 2:

. Control Bank D DRPI: Computer:

Demand Group 1: Demand Group 2:

. Shutdown Bank A DRPI: Computer:

Demand Group 1: Demand Group 2:

. Shutdown Bank B DRPI: Computer:

Demand Group 1: Demand Group 2:

NRC 2015 Scenario 2 NUREG-1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-O1 Scenario # 2 Event # 4 Page: 27 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time Position Applicants Actions or Behavior CRS 7 Notify the following plant personnel prior to moving Control Rods: AOP-403.5

Management Duty Supervisor.

Rod Control System Engineer.

Reactor Engineering.

V V -

CRS 8 Notify the l&C Department to investigate the cause of the Control AOP-403.5 Rod misalignment.

BOOTH OPERATOR:

Acknowledge request for I&C support

. Wait 3 minutes

. Report as l&C a blown lift coil fuse has been identified in Power Cabinet 1BD

. Request permission to replace blown fuse.

. Insert TRIGGER 4 Removes the blown fuse failure.

. Report as I&C that the blown lift coil fuse in Power Cabinet 1 BD was replaced CAUTION - Step 9 AOP-403.5 IF rod alignment could result in a mode change or a subcritical Reactor reaching criticality, then the plant shall be shut down to Mode 3.

RO 9 Verify the misaligned Control Rod is NOT located on bottom of core. AOP-403.5 CRS 10 Provide Reactor Engineering with the following information: AOP-403.5

. Time Control Rod noticed to be AFFECTED:

V . AFFECTED Control Rod location:

. Initial Reactor power level:

a Current Reactor power level:

. Current QPTR:

Acknowledge request for Reactor Engineering support a Wait 2 minutes after being provided with the information from step 10.

. Notify the CRS o Perform rod recovery at the current power level.

o There is no restriction on rod withdrawal speed.

NRC 2015 Scenario 2 - 27 - NUREG-1 021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 4 Page: 28 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time I Position I Applicants Actions or Behavior NOTE- Step 11 AOP-403.5 This Step must be completed before continuing with Step 12.

CRS 1 1 Obtain the following information from Reactor Engineering: AOP-403 .5

. Power level at which recovery is to be performed:

. Rate of Control Rod movement during recovery:

RO 12 Rotate the ROD CNTRL BANK SEL Switch clockwise to the AOP-403.5 AFFECTED Bank position.

RO 13 Check if the misaligned Control Rod can be moved: AOP-403.5

a. Monitor DRPI.

b. Using the rate of Control Rod movement determined in Step 1 1, move the AFFECTED Bank six steps in the direction of the misaligned rod.

c. Using the rate of Control Rod movement determined in Step 1 1, move the AFFECTED Bank six to eight steps in the direction of its original position.

NOTE Step 13.d AOP-403.5 Technical Specification 3.1.3.1 requires plant shutdown if a Control Rod can NOT be moved due to excessive friction or mechanical interference in Mode 1 or 2 OR is known to be untrippable.

RO d. Check if the misaligned Control Rod moved. AOP-403.5

e. Using the rate of Control Rod movement determined in Step 1 1, return the AFFECTED Bank to its original position.

RO 14 If necessary, reduce Reactor power to the power level determined in AOP-403.5 Step 1 1. REFER TO GOP-4B, Power Operation (Mode 1 -

Descending) or GOP-4C, Rapid Power Reduction.

NRC 2015 Scenario 2 NUREG-1021 R951

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 4 Page: 29 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time Position Applicants Actions or Behavior RO 15 Align the misaligned Control Rod with the AFFECTED Bank: AOP-403.5

a. At the CONTROL ROD DISCONNECT SWITCH BOX inside the MCB, place all Lift Coil Disconnect Switches for the AFFECTED Bank, except the switch for the misaligned Control Rod, to the ROD DISCONNECTED position.

b. Dispatch an operator with the Rod Control Cabinets Key to the Rod Control Cabinet room (IB-463).

NOTE Step 15.c AOP-403.5 This step is only applicable for Control Banks.

BOOTH OPERATOR

Acknowledge request for a field operator.

Report you are located at the Rod Control Cabinet.

If directed to report to the Control Room for the key REPORT l&C is with you and they have a key.

Use INSIGHT ZCRFPA(6), REAL PA VALUE to PCSROD, for the P/A converter reading for the bank D.

NA c. Locally at XCA4-CR, P/A CONVERTER CABINET (IB-463), AOP-403.5 record the P/A CONVERTER reading for the AFFECTED Bank:

NOTE Step 15.d AOP-403.5 ROD CNTRL SYS FAIL URGENT (XCP-620 5-1), annunciator will alarm when a misaligned rod is moved in this step.

RO d. Using the rate of Control Rod movement determined in Step 1 1, AOP-403.5 move the misaligned Control Rod six steps in the direction of the AFFECTED Bank.

e. Verify only the misaligned Control Rod moved.

1. Using the rate of Control Rod movement determined in Step 1 1, continue moving the misaligned Control Rod until it is realigned with the AFFECTED Bank.

NRC 2015 Scenario 2 29 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # 4 Page: 30 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time ] Position ) Applicants Actions or Behavior RO 16 Reset the Group Step Counters and P/A CONVERTER: AOP-403.5

a. Reset the Bank Group Step Counters to indicate the Group Demands recorded in Step 6.

NOTE-Stepl6.b AOP-403.5 This step is only applicable for Control Banks.

BOOTH OPERATOR When directed - reset P/A converter using Remote Functions

Insert LOA-CRFOO5, P/A MAN HEIGHT VALUE (USE BEFORE SETTING LOA CRF1), to the value recorded in step 15.

Insert LOA-CRFOO1, P/A MAN BANK SELECT (USE AFTER SETTING LOA CRF5), to CB D.

b. Locally at XCA4-CR, P/A CONVERTER CABINET (IB-463), reset AOPt the P/A CONVERTER as follows:

1) Ensure the Bank Position Display Switch is in the AFFECTED Bank position.

2) Place MANUAL/AUTOMATIC Switch in MANUAL.

3) Depress the UP or DOWN Pushbutton to reset the P/A CONVERTER to the reading recorded in Step 15.

4) Place the MANUAL/AUTOMATIC Switch in AUTOMATIC.

5) Place the Bank Position Display Switch to DISPLAY OFF.

NOTE Step 17 AOP-403.5 lithe Control Rods are near the All Rods Out position, SOP-403, ROD CONTROL AND POSITION INDICATING SYSTEM, should be used for final alignment.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 4 Page: 31 of 55 Event

Description:

Rod H14 stuck but trippable (blown fuse).

Time Position ( Applicants Actions or Behavior BOP 17 Restore the Rod Control System to normal alignment: AOP-403.5

a. Place all Lift Coil Disconnect Switches to the ROD CONNECTED

. position.. V

b. Rotate the ROD CNTRL BANK SEL Switch counter-clockwise to MAN.

c. Depress the ROD CNTRL ALARM RESET Pushbutton.

d. Verify the ROD CNTRL SYS FAIL URGENT (XCP-620 5-1),

annunciator clears.

EVALUATOR NOTE: Initiate the next event after rod alignment has been restored.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 5 Page: 32 of 55 Event

Description:

PT-508 (MEW Pump Discharge Header Pressure) Fails LOW. (Manual control of MEW Pp speed)

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: When directed, insert Event 5 (TRIGGER 5)

EVALUATOR NOTE: On cue from the Examiner, a Main Feedwater Header Pressure transmitter will fail LOW causing the MFW Pump speed to increase and raise SG level. The operators will respond to annunciators and implement AOP-21 0.3, Feedwater Pump Malfunction.

The BOP will take manual control of the master Speed control and adjust speed to maintain Feedwater Pump discharge pressure 150 to 250 psi greater than Main Steam Header pressure and restore SG levels.

Indications Available:

XCP-624 1-5; 2-5; 3-5, SG LVL DEV XCP-624 4-4, 5-4, 6-4, FWF>STF MISMATCH CREW Responds to multiple SG LVL DEV alarms and/or change in feedwater flow.

EVALUATOR NOTE: The crew may first enter an ARP but could go directly to AOP-21 0.3, FEEDWATER PUMP MALFUNCTION, based on multiple alarms or early diagnosis.

CR3 Enters ARP-001-XCP-624 1-5 or 2-5 or 3-5 BOP CORRECTIVE ACTIONS: xcP-624 1-5

1. If required, restore Steam Generator A level to between 60% and 65% by performing either or both of the following:

a. Manually control PVT-478, SG A FWF, as required.

b. Manually control Feedwater Pump speed as follows:

1) Place the Feedwater Pump MASTER SPEED CNTRL in MAN.

2) Adjust the differential pressure between Feedwater Pump discharge header pressure and Main Steam header pressure, as required, to restore Steam Generator water level.

NRC 2015 Scenario 2 NUREG-1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-O1 Scenario # 2 Event # 5 Page: 33 of 55 Event

Description:

PT-508 (MEW Pump Discharge Header Pressure) Eails LOW. (Manual control of MFW Pp speed)

Time Position Applicants Actions or Behavior BOP 2. Evaluate SG A Narrow Range level indicators Ll-474, Ll-475, and LI- XcP-624 1-5 476:

a. For increasing level:

1) At 70% Narrow Range level:

f a) During startups (below 15% power) close the Feed Regulating valves with the B Train Switches.

(b) When above 15% power take manual control of PVT-478, SG A FWF.

(c) Ensure Feed Flow is 200 kbh to 400 kbh less than Steam Flow.

2) At 75% Narrow Range level:

(a) Trip the Reactor if above 15% power.

(b) Close the Feed Isolation valves.

(c) Trip the Turbine.

(ci) Trip the Feed Pumps.

(e) Close the Feedwater Regulating valves, if not closed earlier.

(f) If the Reactor has NOT been tripped, reduce power to between 1% and 3%

(g) Reestablish Emergency Feed.

CRS 3. If FCV-478, A FCV, malfunctioned go to AOP-210.1, Feedwater Flow XCP-624 1-5 Control Valve Failure. (NO)

CRS 4. If a Main Feedwater Pump has tripped or is malfunctioning go to XCP-624 1-5 AOP-210.3, Feedwater Pump Malfunction.

CRS Implements AOP-210.3, Feedwater Pump Malfunction.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 5 Page: 34 of 55 Event

Description:

PT-508 (MFW Pump Discharge Header Pressure) Fails LOW. (Manual control of MFW Pp speed)

Time I Position I Applicants Actions or Behavior REFERENCE PAGE FOR AOP-210.3 AOP-21 0.3 1 Manual Control of Main Feedwater Regulating Valves ispermissibIe at any time as çleemed necessary during the performance of this procedure. If a-Main Feedwater Regulating Valve has been placed in Manual it sliould be returned to Automatic as soon as possible.

2 IF only one Main Feedwater Pump is operating and cannot be controlled THEN trip the Main Turbine and go to AOP-214.1, TURBINE TRIP.

3 IF Narrow Range SG level decreases to LESS THAN 40%, THEN Trip the reactor and enter EOP- 1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION.

4 IF Reactor Power is GREATER THAN 15% and NR Steam Generator level exceeds 75%,

THEN Trip the reactor and enter EOP-1 .0, REACTOR TRIP/SAFETY INJECTION ACTUATION.

IOA BOP 1 Verify at least one Feedwater Pump is running. AOP-21 0.3 IOA BOP 2 Check if a Feedwater Pump trip occurred. (NO) AOP-ALTERNATIVE ACTION 2 GOTOStep4.

IOA BOP 4 Check Main Feedwater Pump operation. AOP-21 0.3

a. Verify all Main Feedwater Pumps are affected.

b. Place the MCB MASTER SPEED CNTRL in MAN. and adjust the MCB MASTER SPEED CNTRL as necessary to match Steam Flow and Feedwater Flow.

BOP 5 If necessary, place the Main Feed Regulating valves in Manual. AOP-21 0.3 NOTE-Step 6 AOP-21 0.3 Due to the slow operation of the Main Feedwater Pump Recirculation Valves, a constant Main Feedwater Pump speed should be maintained until the recirculation valves have become relatively stable while adjusting Feedwater Flow.

NRC 2015 Scenario 2 34 - NUREG-1 021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 5 Page: 35 of 55 Event

Description:

P1-508 (MFW Pump Discharge Header Pressure) Fails LOW. (Manual control of MFW Pp speed)

Time ] Position ] Applicants Actions or Behavior

6 Maintain Narrow Range Steam Generator Water level between 60% AOP-21 0.3 and 65%

EVALUATOR NOTE: Manual speed control will be maintained for the remainder of the scenario.

EVALUATOR NOTE: The NEXT EVENT may be initiated after the Main Feedwater Pump Master speed controller is in manual.

7 WHEN conditions allow, Place Main Feed Regulating valves in AOP-21 0.3 AUTO.

NOTE Step 8 AOP-21 0.3 Main Feedwater Program iP should be established using the following as available:

P1-508, FW PP DISCH HDR PRESS P31G.

Any operating Main Feedwater Pump Discharge Pressure.

Pl-464C, MS HDR PRESS PSIG.

Any available MOB Main Steam Header Pressure.

IPCS (ZZMENU S/G SU Trend or FW Start) 8 Restore Feedwater Pump D/P to program. AOP-21 0.3

a. Using the Feedwater Pump Speed Control method established in Step 4, slowly adjust Feedwater Pump discharge header pressure to within the limits of ATTACHMENT 1, FEEDWATER PUMP DIP LIMITS.

b. Adjust PUMP A(B)(C) SPEED CNTRL (MOB M/A Stations) as necessary to balance all operating Feedwater Pumps speed to within 120 rpm of each other.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-1 3-01 Scenario # 2 Event # 6 Page: 36 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR: When directed, initiate Event 6 (TRIGGER 6).

EVALUATOR NOTE (EVEN16):

On cue from the Examiner, a steamline break inside the Reactor Building will be inserted. The Reactor will trip and the crew will implement EOP-1 .0 (E-O) Reactor Trip/Safety Injection Actuation. The crew will identify that at least one Steam generator is faulted and transition to EOP-3.O (E-2), Faulted Steam Generator Isolation. When the faulted SG is isolated the crew will transition to EOP-1 .2 (ES-i .1), Safety Injection Termination.

The crew will identify that the Main Generator Output Breaker failed to automatically trip and the BOP will manually open the breaker from the control board.

The BOP must identify that the MSIVs are open and manually close them from the control board to isolate the faulted Steam Generator and prevent over-pressurization of the Reactor Building.

Indications Available:

XCP-62i 3-2 RODS ON BOTTOM XCP-624 2-4 STMLN PRESS LO XCP-626 4-1 STM PRESS LO SI XCP-626 6-i RB PRESS HI-i SIl NRC 2015 Scenario 2 36 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 j Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 6 Page: 37 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time I Position I Applicants Actions or Behavior REFERENCE PE FOR EOP1,U EOP-l.O 1 RCP TRIP CRITERIA ..

a. IF Phase B Cuntafnment Isolation has actuated fXCP612 42)

IE1I t r I p jj RC Ps.

b. IF both of the following conditions ocur. ijjN trip RCPs:

Si flow is indicated on FI943, CHG LOOP B CLD/HOT LO FLOW GPM.

RCS Wide Range pressure is LESS ThAN 1418 psig.

2 REDUCING CONTROL ROOM EHERENCY VENTIUTION Reduce Control Room Enerqency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-SOS.

CONTROL BUILDING VENTILATION SYSTEM.

3 NONITOR SPENT FUEL COOLING Periodically check status of Spent Fuel Cooling by monitoring the following throughout event recovery:

Spent Fue Pool level

Spent Fuel Pool teoperature.

NOTE EOP-1.O

Steps 1 through 5 are Immediate Operator Actions.

The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

Conditions for implementing Emergency Plan Procedures should be evaluated using EPP 001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

IOA RO 1 Verify Reactor Trip: EOP-l.O

Trip the Reactor using either Reactor Trip Switch.

Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

NRC 2015 Scenario 2 NUREG-1021 R9SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 6 Page: 38 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time Position Applicants Actions or Behavior IOA BOP 2 Verify Turbine/Generator Trip: EOP-1 .0

a. Verify all Turbine STM STOP VLVs are closed.

EVALUATOR NOTE:

The GEN BKR and GEN FIELD BKR are failed and need to be manualty opened.

IOA BOP b. Ensure Generator Trip (after 30 second delay): EOP-1 .0

1) Ensure the GEN BKR is open. (NO)

2) Ensure the GEN FIELD BKR is open. (NO)

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP 3 Verify both ESF buses are energized. EOP-1 .0 IOA RO 4 Check if SI is actuated:

fl EOP-1.-

a. Check if either:

SI ACT status light is bright on XCP-6107 1-1.

OR

Any red first-out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch.

C. GOTOStep6.

EVALUATOR NOTE:

Attachment 3, SI Equipment Verification, is attached (Page 51).

BOP 6 Initiate ATTACHMENT 3, SI EQUIPMENT VERIFICATION. EOP-1 .0 CREW 7 Announce plant conditions over the page system. EOP-1.0 NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 6 Page: 39 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time Position Applicants Actions or Behavior

RO 8 Verify RB pressure has remained LESS THAN 12 psig on PR-951, EOP-1.O RB PSIG (P-951), red pen. (NO)

ALTERNATIVE ACTION t

8 Perform the following:

a) Verify both the following annunciators are lit:

XCP-612 3-2 (RB SPR ACT).

XCP-612 4-2 (PHASE B ISOL).

IF either annunciator is NOT lit, THEN actuate RB Spray by placing the following switches to ACTUATE:

Both CS-SGA1 and CS-SGA2.

OR

Both CS-SGB1 and CS-SGB2.

b) Verify Phase B Isolation by ensuring RB SPRAY/PHASE B ISOL monitor lights are bright on XCP-6105.

I c) Ensure the following are open:

MVG-3001A(B), RWST TO SPRAY PUMP A(B) SUCT.

MVG-3002A(B), NAOH TO SPRAY PUMP A(B) SUCT.

MVG-3003A(B), SPRAY HDR ISOL LOOP A(B).

d) Ensure both RB Spray Pumps are running.

e) Verify RB Spray flow is GREATER THAN 2500 gpm for each operating train on:

FI-7368, SPR PP A DISCH FLOW GPM.

FI-7378, SPR PP B DISCH FLOW GPM.

f) Stop all RCPs.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-01 Scenario # 2 Event # 6 Page: 40 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time Position Applicants Actions or Behavior

RO 9 Check RCS temperature: EOP-1.O

With any RCP running, RCS Tavg is stable at OR trending to 557°F.

OR

With no RCP running, RCS Tcold is stable at OR trending to 557°F.

ALTERNATIVE ACTION 9 IF RCS temperature is LESS THAN 557°F AND decreasing, THEN stabilize temperature by performing the following as required:

a) Close IPV-2231, MS/PEGGING STM TO DEAERATOR.

b) Perform one of the following:

IF Narrow Range SG level is LESS THAN 41% in all SGs, THEN reduce EFW flow as necessary to stop cooldown, while maintaining total EFW flow GREATER THAN 450 gpm.

OR

WHEN Narrow Range SG level is GREATER THAN 41% in at least one SG, THEN control EFW flow as necessary to stabilize RCS temperature at 557°F.

EVALUATOR NOTE: Attachment 6, Steam Valve Isolation, is attached (Page 55).

c) Initiate ATTACHMENT 6, STEAM VALVE ISOLATION, while continuing with this procedure.

EVALUATOR NOTE: Close A or B MSIV Prior to Orange path on Integrity or Containment.

NRC 2015 Scenario 2 -40 - NUREG-1021 R951

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-01 Scenario # 2 Event # 6 Page: 41 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time ] Position Applicants Actions or Behavior RO d) IF RCS cooldown continues, THEN close: EOP-1.O U)

MS Isolation Valves, PVM-2801A(B)(C).

.c -

MS Isolation Bypass Valves, PVM-2869A(B)(C).

U .

I.

L ci RD 10 Check PZR PORVs and Spray Valves: EOP-1 .0

a. PZR PORVs are closed.

b. PZR Spray Valves are closed.

c. Verify power is available to at least one PZR PORV Block Valve:

MVG-8000A, RELIEF 445 A ISOL.

MVG-8000B, RELIEF 444 B ISOL.

MVG-8000C, RELIEF 445 B ISOL.

I

d. Verify at least one PZR PORV Block Valve is open.

NOTE-Step 11 EOP-1 .0 Seal Injection flow should be maintained to all RCPs.

RD 1 1 Check if RCPs should be stopped: EOP-1 .0

a. Check if either of the following criteria is met:

Annunciator XCP-612 4-2 is lit (PHASE B ISOL).

OR

RCS pressure is LESS THAN 1418 psig AND SI flow is indicated on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

. b. Stop all RCPs.

NRC 2015 Scenario 2 -41 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 6 Page: 42 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIV5 fail to close.

Time Position Applicants Actions or Behavior RO 12 Verify no SG is FAULTED: EOP-1 .0 No SG pressure is decreasing in an uncontrolled manner.

NoSG is completely depressurized.

ALTERNATIVE ACTION 12 GO TO EOP-3.0, FAULTED STEAM GENERATOR ISOLATION, Step 1.

CR8 Implement EOP-3.0, Faulted Steam Generator Isolation, Step 1.

EVALUATOR NOTE: If EFW pump runout protection has occurred, the CRS may enter and exit EOP-15.0, Response To Loss Of Secondary Heat Sink.

CAUTION EOP-3.0

At least one SG must be maintained available for RCS cooldown.

Any FAULTED SG or secondary break should remain isolated during subsequent recovery actions unless needed for RCS cooldown, to prevent rein itiating the break.

NOTE EOP-3,0 Conditions for implementing Emergency Plan Procedures should be evaluated using EPP 001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

SOP 1 Ensure all the following ate closed: EOP-3.0

MS Isolation Valves, PVM-2801A(B)(C).

MS Isolation Bypass Valves, PVM-2869A(B)(C).

BOP 2 Check if any SG is NON-FAULTED: EOP-3.0

Pressure in any SG is stable OR increasing.

Any SG is NOT completely depressurized.

NRC 2015 Scenario 2 -42 - NUREG-1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # 6 Page: 43 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time Position Applicants Actions or Behavior BOP 3 Identify any FAULTED SG(s): EOP-3.O

Any SG pressure decreasing in an uncontrolled manner.

OR

Any SG completely depressurized.

BOP 4 Close the following for each FAULTED SG: EOP-3.O

FW Flow Control, FCV-478.

FW Isolation, PVG-161 1A.

SG Blowdown, PVG-503A.

FW Flow Control Bypass, FCV-3321.

BOP 5 Complete the isolation of each FAULTED SG: EOP-3.O

a. Close SG Chemical Feed Isolation, MVK-1633A.

b. Close MS Drain Isolation, PVT-2843A.

c. Close MS Drain Isolation, PVT-2877A for SG A PVT-2877B for SG C.

U. Place the Steamline PWR RELIEF A SETPT Controller(s) in MAN and closed.

e. Place the Steamline Power Relief A Mode Switch(s) in PWR RLF.

BOP f. Close FCV-3531, MD EFP TO SG A. EOP-3.O

g. Close FCV-3536, TD EFP TO SG A.

I 0

CAUTION - Step 5.h EOP-3.O If the TD EFW Pump is the only available source of feed flow, the steam supply to the TD EFW Pump must be maintained from at least one SG, to maintain a secondary heat sink.

BOP h. Close and locally deenergize the appropriate valve if SG B or SG EOP-3.O C is FAULTED: (NA)

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-I LO-1 3-01 Scenario # 2 Event # 6 Page: 44 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time I Position I Applicants Actions or Behavior NOTE - Step 6 EOP-3.O Any high radiation level received on a radiation monitor that was unisolated.at event initiation, may be considered a valid alarm.

CRS 6 Check if Secondary radiation levels are normal: EOP-3.0

a. Check radiation levels normal on all unisolated radiation monitors:

RM-GI9A(B)(C), STMLN HI RNG GAMMA.

RM-L3, STEAM GENERATOR BLOWDOWN LIQUID MONITOR.

RM-L10, SG BLOWDOWN CW DISCHARGE LIQUID MONITOR.

RM-A9, CNDSR EXHAUST GAS ATMOS MONITOR.

BOOTH OPERATOR: Acknowledge request for Chemistry to sample and frisk samples for abnormal activity.

b. Notify Chemistry to sample all SG secondary sides, and screen EOP-3.0 samples for abnormal activity using a frisker.

CRS 7 Check if SI flow should be reduced: EOP-3.O

a. RCS subcooling on TI-499A(B), A(B) TEMP °F, is GREATER THAN 52.5°F [67.5°F].

b. Secondary Heat Sink is adequate:

Total EFW flow to INTACT SGs is GREATER THAN 450 gpm.

OR

Narrow Range level is GREATER THAN 41% in at least one INTACT SG.

c. RCS pressure is stable OR increasing.

d. PZR level is GREATER THAN 28%.

NRC 2015 Scenario 2 NUREG-1021 R9 Si

Appendix D Operator Actions Form ES-D-2 1 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 6 Page: 45 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time Position Applicants Actions or Behavior RO 8 Reset both SI RESET TRAIN A(B) Switches. EOP-3.O RO 9 Reset Containment Isolation: EOP-3.O

RESET PHASE A TRAIN A(B) CNTMT ISOL.

RESET PHASE B TRAIN A(B) CNTMT ISOL.

BOP 10 Place both ESF LOADING SEQ A(B) RESETS to: EOP-3.O

a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

BOP 11 Establish Instrument Air to the RB: EOP-3.O

a. Start one Instrument Air Compressor and place the other in Standby.

b. Open PVA-2659, INST AIR TO RB AIR SERV.

c. Open PVT-2660, AIR SPLY TO RB.

CRS 12 GO TO EOP-1.2, SAFETY INJECTION TERMINATION, Step 1. EOP-3.O NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # 6 Page: 46 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time I Position I Applicants Actions or Behavior EOP-1 .2 REFERENCE PAGE FOR EOP-1.2 1 SI REINITIATION CRITERIA Following SI termination. IF either of the following conditions occurs, THEN start Charging Pumps and operate valves as necessary.

and GO TO EOP-2.O. LOSS OF REACTOR OR SECONDARY COOLANT. Step it

RCS subcooling on TI-499A(B), ACB) TEMP oF. is LESS THAN 52.5°F t67.5°F].

OR

PZR level can NOT be maintained GREATER THAN 10% [28%].

2 SECONDARY INTEGRITY TRANSITION CRITERIA IF unisolated SG pressure is decreasing in an uncontrolled manner OR is compThtely depressurized, THEN GO 10 EOP-3.O, FAULTED STEAM GENERATOR ISOLATION. Step 1.

3 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to one train in operation within 30 minutes of actuation. REFER TO SOP-505.

CONTROL BUILDING VENTILATION SYSTEM.

NOTE EOP-1.2 The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

RO 1 Stop all but one Charging Pump and place in Standby. EOP-1 .2 RO 2 Verify RCS pressure is stable OR increasing. EOP-1 .2 NRC 2015 Scenario 2 46 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # 6 Page: 47 of 55 Event

Description:

A Main Steamline Break inside the RB due to a seismic event. Generator breaker failure. A and B MSIVs fail to close.

Time ] Position ] Applicants Actions or Behavior RO 3 Establish Normal Charging: EOP-1 .2

a. Close FCV-122, CHG FLOW.

b. Open both MVG-8107 and MVG-8108, CHG LINE ISOL.

c. Adjust FCV-122, CHG FLOW, to obtain 70 gpm Charging flow.

U. Close both MVG-8801A(B), HI HEAD TO COLD LEG INJ.

EVALUATOR NOTE: The scenario may be terminated now the Safety Injection has been terminated (i.e. normal charging restored).

NRC 2015 Scenario 2 47 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # NA Page: 48 of 55 Event

Description:

SOP-106 TIlE. BORATE OPERATIONS Time I Position I Applicants Actions or Behavior SOP-i 06 III.F NOTE 2.0

1. Energizing additional Pressurizer Heaters will enhance mixing.

2. LCV-1 15A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70% level on LI-H 5, VCT LEVEL %.

SOP-106 III.F RO 2.1 Ensure at least one Reactor Coolant Pump is running.

SOP-i06 III.F RO 2.2 Place RX COOL SYS MU switch to STOP.

SOP-i06 III.F RO 2.3 Place RX COOL SYS MU MODE SELECT switch to BOR.

SOP-106 III.F RO 2.4 Set FIS-1 13, BA TO BLNDR FLOW, batch integrator to the desired volume.

SOP-i 06 III.F RO 2.5 Place RX COOL SYS MU switch to START.

NOTE 2.6 SOP-i 06 III.F Step 2.6 may be omitted when borating less than 10 gallons.

Place FCV-1 13 A&B, BA FLOW, controller in AUTO. SOP-i 01 RO 2.6 SOP-i 06 III.F NOTE 2.7 The AUTO setpoint dial for FCV-1 1 3A&B, BA FLOW, controller may be adjusted slowly to obtain the desired flow rate.

SOP-i 06 III.F RO 2.7 Verify the desired Boric Acid flow rate on FR-i 13, BA TO BLNDR GPM (F-113).

SOP-106 III.F RO 2.8 When the preset volume of boric acid has been reached, perform the following:

a. Place FCV-1 13A&B, BA flow controller in MAN.

b. Verify boration stops.

SOP-I 06 III.F RO 2.9 Place RX COOL SYS MU switch to STOP.

NOTE 2.10 SOP-i 06 III.F

a. If plant conditions requite repeated borations, Step 2.10 may be omitted.

b. The volume in the piping between the blender and the VCT outlet is approximately 3.8 gallons.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 2 Event # NA Page: 49 of 55 Event

Description:

SOP-106 III.F. BORATE OPERATIONS Time Position 3 Applicants Actions or Behavior RD 2.10 Alternate Dilute 4 to 6 gallons of Reactor Makeup Water to flush SOP-106 II.F the line down stream of the blender by performing the following:

a. Place RX COOL .SYS MU MODE SELECT switch to ALT DIL.

b. Adjust FCV-i 68, TOTAL MU FLOW SET PT, to desired flow rate.

c. Set FIS-168, TOTAL MU FLOW, batch integrator to desired volume.

d. Place RX COOL SYS MU switch to START.

e. Verify desired flow rate on FR-i 13, TOTAL MU GPM (F-i68).

f. Verify alternate dilution stops when preset volume is reached on FIS-i68, TOTAL MU FLOW, batch integrator.

g. Place RX COOL SYS MU switch to STOP.

I RO 2.11 Place RX COOL SYS MU MODE SELECT switch to AUTO. SOP-106 III.F RD 2.12 Adjust FCV-i68, TOTAL MU FLOW SET PT, to 7.5 (120 gpm). SOP-J06 IH.F RD 2.13 In MAN, adjust FCV-ii3A&B, BA FLOW OUTPUT, to the required SOP-i 06 IILF position which will ensure proper Boric Acid addition for subsequent Automatic Makeup operations.

RD 2.14 Adjust FCV-i i3A&B, BA FLOW SET PT, to the desired position to SOP-i 06 III.F ensure proper boric acid addition for subsequent Automatic Makeup operations.

RO 2.15 Place RX COOL SYS MU switch to START. SOP-106 III.F RD 2.16 Perform the following: SOP-i 06 II.F

a. Start XPP-i 3A(B), BA XFER PP A(B), for the in-service Boric Acid Tank.

b. If necessary, start XPP-13A(B), BA XFER PP A(B), for the Boric Acid Tank on recirculation.

END OF SECTION SOP-i 06 IILF NRC 2015 Scenario 2 49 - NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # NA Page: 50 of 55 Event

Description:

SOP-106 IV.D. BORATING THE RCS USING THE EMERGENCY BORATE VALVE Time I Position I Applicants Actions or Behavior SOP-i 06 IV.D CAUTION 2.0 AOP-i 06.1, Emergency Boration, should be used for any of the following:

a. Failure of the Reactor Makeup Control System such that bypass is necessary to accomplish boration.

b. Uncontrolled cooldown with Safety Injection NOT required.

c. ANY questionable Shutdown Margin.

d. Control Rod Insertion Limit is exceeded.

SOP-i 06 IV.D RO 2.1 Open MVT-8104, EMERG BORATE.

SOP-i 06 IV.D RO 2.2 Ensure XPP-1 3A(B), BA XFER PP A(B), is running.

SOP-i 06 IV.D RO 2.3 Verify greater than 30 gpm flow on Fl-i 10, EMERG BORATE FLOW GPM.

2.4 When boration is no longer required, perform the following: so p; o RO

a. Close MVT-8i04, EMERG BORATE.

b. Verify no flow on Fl-i 10, EMERG BORATE FLOW GPM.

END OF SECTION SOP-i 06 IV.D NRC 2015 Scenario 2 NUREG-i 021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 2 Event # NA Page: 51 of 55 Event

Description:

SOP-214 HID. Turbine Load Reduction/Shutdown Time I Position I Applicants Actions or Behavior BOP 2.1 Ensure the Control/Load screen is selected. SOP-214 NOTE 2.2 SOP-214 The turbine will come off the limiter and turbine load will lower once Load Set Reference is less than Load Limit Reference.

Acknowledging dialog boxes is skill of the Craft.

BOP 2.2 To lower Turbine Load using Load Set, perform the following: SOP-214

a. If directed by Operations Management, disable the Turbine Vibration Trips per Section III.

b. Select (or enter) the desired Rate %/min on Load Set.

c. Select Load on Load Set (a dialog box will open).

d. Enter the desired load and confirm.

e. Verify proper system response.

I

f. If during a load reduction, it is desired to stop the load reduction, perform the following:

1) Select Hold on Load Set.

2) Select the desired Rate %/min to resume load reduction.

3) If desired, place LOAD LIMIT in service per Section III.

BOP 2.3 For rapid load shedding of 50 MWe, on an HMI keypad select Ctrl SOP-214

+ Alt + S.

EVALUATOR NOTE: The remainder of this section deals with actions after Turbine Load is below 15%.

NRC 2015 Scenario 2 NUREG-1021 R9 SI

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 2 Event # NA Page: 52 of 55 Event

Description:

EOP-1 .0, Attachment 3 Time Position Applicants Actions or Behavior BOP 1 Ensure EFW Pumps are running: EOP-1 .0 Attachment 3

a. Ensure both MD EFW Pumps are running.

b. Verify the TD EFW Pump is running if necessary to maintain SG levels. . . . . .,

BOP 2 Ensure the following EFW valves are open: Attachment 3

. FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).

. FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).

. MVG-2802A(B), MS LOOP B(C) TO TD EFP.

BOP 3 Verify total EFW flow is GREATER THAN 450 gpm. Attachment 3 BOP 4 Ensure FW Isolation: Attachment 3

a. Ensure the following are closed:

. FW Flow Control, FCV-478(488)(498).

. FW Isolation, PVG-1 61 1A(B)(C).

. FW Flow Control Bypass, FCV-3321(3331)(3341).

. SG Blowdown, PVG-503A(B)(C).

. SG Sample, SVX-9398A(B)(C).

b. Ensure all Main FW Pumps are tripped.

BOP 5 Ensure SI Pumps are running: Attachment 3

. Two Charging Pumps are running.

Both RHR Pumps are running.

BOP 6 Ensure two RBCU Fans are running in slow speed (one per train). Attachment 3 BOP 7 Verify Service Water to the RBCUs: Attachment 3

a. Ensure two Service Water Pumps are running.

b. Verify both Service Water Booster Pumps A(B) are running.

C. Verify GREATER THAN 2000 gpm flow for each train on:

. FI-4466, SWBP A DISCH FLOW GPM.

. FI-4496, SWBP B DISCH FLOW GPM.

BOP 8 Verify two CCW Pumps are running. Attachr NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2

h. Op Test No: NRC-ILO-13-01 Scenario # 2 Event # NA Page: 53 of 55 Event

Description:

EOP-1.O, Attachment 3 Time ] Position Applicants Actions or Behavior BOP 9 Ensure two Chilled Water Pumps and Chillers are running. Attachment 3 BOP 10 Verify both trains of Control Room Ventilation are running in Attachment 3 Emergency Mode.

EVALUATOR NOTE: It is a critical task to close the A or B MSIV Prior to Orange path on Integrity or RE pressure.

BOP 11 Check if Main Steamlines should be isolated: Attachment 3

a. Check if any of the following conditions are met:

RB pressure GREATER THAN 6.35 psig.

-J OR

Steamline pressure LESS THAN 675 psig.

OR ci

Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.

b. Ensure all the following are closed:

MS Isolation Valves, PVM-2801A(B)(C).

MS Isolation Bypass Valves, PVM-2869A(B)(C).

BOP 12 Ensure Excess Letdown Isolation Valves are closed: Attachment 3

PVT-8153, XS LTDN ISOL.

PVT-8154, XS LTDN ISOL.

BOP 13 Verify ESF monitor lights indicate Phase A AND Containment Attachment 3 Ventilation Isolation on XCP-6103, 6104, and 6106.

REFER TO ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # NA Page: 54 of 55 Event

Description:

EOP-1 .0, Attachment 3 Time Position Applicants Actions or Behavior BOP 14 Verify proper SI alignment: Attachment 3

a. Verify SI valve alignment by verifying SAFETY

. INJECTION/PHASE A ISOL monitor lights ar bright on XCP-61 04.

b. Verify all SAFETY INJECTION monitor lights are dim on XCP-6 106.

c. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

d. Check if RCS pressure is LESS THAN 325 psig.

BOP Report completion of Attachment 3.

EVALUATOR NOTE: ATTACHMENT 3 is complete.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 2 Event # NA Page: 55 of 55 Event

Description:

EOP-1 .0, STEAM VALVE ISOLATION, Attachment 6 Time Position [ Applicants Actions or Behavior BOP 1 Close Feedwater Pump TURB DRN VLVs: EOP-1 .0 Attachment 6

MOV-1-5A.

MOV-1-5B.

MOV-1-5C.

BOP 2 Close the following turbine drain valves: EOP-1 .0 Attachment 6

MVG-2896A, SV-1 BSD.

MVG-2896B, SV-2 BSD.

MVG-2896C, SV-3 BSD.

MVG-2896D, SV-4 BSD.

BOP 3 Ensure the following drain valves are in AUTO: EOP-1 .0 Attachment 6

PVT-2851A,B,C,D, MS LINES TO TURB DRN.

PVT-2713A,B,C,D, STM DUMP DRN BYP.

PVT-2870, TO MSR A & B DRN.

PVT-2875, TO MSR A & B DRN.

PVT-2845A,B,C, PVT-2824, PVT-2879A,B, LINE DRN.

PVT-2838A,B, HDR DRNS.

BOP 4 Place the STM DUMP CNTRL Controller in MAN and CLOSED. EOP-1 .0 Attachment 6 BOP 5 Place the STM DUMP MODE SELECT Switch in STM PRESS. EOP-1 .0 Attachment 6 BOP 6 Place the STM DUMP CNTRL Controller in AUTO. EOP-1 .0 Attachment 6

BOP 7 WHEN the Condenser is NOT available, THEN perform the EOP-1 .0 Attachment 6 following:

a. Place the Steamline Power Relief A(B)(C) Mode Switches in PWR RLF.

b. Adjust the PWR RELIEF A(B)(C) SETPT Controllers as necessary to control RCS temperature.

BOP 8 Verify proper response of all Steamline PORVs and Condenser EOP-1.0 Attachment 6 Steam Dumps for existing plant conditions.

BOP 9 Ensure SG Blowdown Valves, PVG-503A(B)(C), are closed. EOP-1 .0 Attachment 6 BOP 10 If desired, drain valves may be aligned per Shift Supervisor EOP-1 .0 Attachment 6 discretion based on current and expected plant status.

NRC 2015 Scenario 2 NUREG-1021 R9S1

Appendix D Scenario Outline Form ES-D-1 Facility: VC SUMMER Scenario No: 3 Op Test No: NRC-ILO-13-01 Examiners: Operators: CRS:

RO:

BOP:

Initial Conditions: 100% MOL.

Bi Train Work Week.

. Alternate Seal Injection is 005.

. Thermography of transformer disconnects is in progress in the switchyard.

Turnover: Maintain 100% power.

Critical Tasks: Start Back-up EHC Pump prior to a RxlTurbine Trip on Low EHC Pressure.

. Manually control C SG Feedwater without a RxlTurbine Trip on SG Level.

. Manually trip the Reactor prior to completion of Immediate Actions of EOP-1 .0 (E-0).

Establish feed flow to at least one SG before RCS feed and bleed criteria is met.

Event MaIf No. Event Type* Event Description No.

1 TURO12A 1-RO, CRS PT-446 (Turbine First Stage Pressure) fails LOW. (Rods TS-CRS Drive In) 2 NA N-BOP, CRS Rapid Power Reduction due to overheating of main R-RO generator disconnects.

3 EHOO1 B C-BOP Running EHC Pump Trip. (Standby EHC must be EHOO2F manually started).

4 MSO200 1-BOP, CRS LT-496 (C SG Level Instrument) fails HIGH. (Manually TS-CRS control feedwater to C SG) 5 CVCOO5C C- CRS Progressive failure of #2 Seal on A RCP.

6 RCSOO3A C-RO, CRS RCP Trip, ATWS, FW Isol Valve 161 1A Fails Closed.

PCSOO8A (Manual Reactor trip)

PCSOO8B FWO25P NRC 2015 Scenario 3 1 NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 7 MSSO1 5 M-ALL Loss Of Heat Sink (EFW) After Reactor Trip.

EEOC iS EFOO2T FWMOO1A All Main Feedwater Pumps Trip. (Feed with Condensate)

FW MOO 1 B FWMOO1 C (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor NRC 2015 Scenario 3 2- NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 The following notation is used in the ES-D-2 form Time column:

IOA designates Immediate Operator Action steps.

designates Continuous Action steps.

The crew will assume the watch having been pre-briefed on the Initial Conditions, the plan for this shift and any related operating procedures.

EVENT 1: PT-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

TRIGGER 1 o MAL-TURO12A TURBINE IMPULSE PRESSURE TRANSMITTER PT-446 FAILURE FINAL=0

TRIGGER 2 o ANN-MI007 AMSAC GENERAL WARNING Fail To: ON On cue from the Examiner, the selected turbine first stage pressure transmitter (PT-446) will tail LOW. The failure causes a Tave -Tref mismatch resulting in rods inserting at the maximum speed. The crew will enter AOP-401 .7, Turbine First Stage Pressure Channel Failure.

The RO will respond to the rod insertion by placing rod control in manual and restoring Tave to within 1 degree of Tref. The crew will then select the operable 1St stage pressure channel for control. The RO may restore automatic rod control after the operable channel is selected. The BOP will place the STM DUMP MODE SELECT in STM PRESS.

The CRS will refer to Technical Specification Table 3.3-1 Items 19.B, E and Table 3.3-3 Item

4. d.

EVENT 2: Rapid Power Reduction due to overheating of main generator disconnects.

On cue from the Examiner, the Booth Operator as the Shift Supervisor will direct the CRS to lower power 10% within the next 15 minutes in accordance with GOP-4C Rapid Power Reduction, due to a report that the transformer disconnects are overheating. The RO will lower Reactor power with boration and/or rod motion. The BOP will reduce turbine load using the Turbine controls.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 EVENT 3: Running EHC Pump Trip. (Standby EHC must be manually started).

TRIGGER 3 o PMP-EHO01B XPP0003-PP1 HFM PMP A BRG FAILURE o PMP-EH002F XPP0003-PP2 HEM PMP B FAIL TO START On cue from the Examiner, the running EHC pump will trip and the backup pump will not start in auto. The BOP will respond to annunciator XCP-631 1-4, EHC PP A MOTOR OVRLD, determine the cause of the event, and take corrective action by starting the backup EHC pump to prevent turbine stop valves from closing. A Turbine trip will occur within 2 minutes if the event is not mitigated.

EVENT 4: LT-496 (C SG Level Instrument) fails HIGH. (Manually control feedwater to C SO)

TRIGGER 4 o XMT-MSO200 1LT00496 SG C NR LVL Ll.496 FAIL TO POSN FINAL VALUE = 100 RAMP = 00:00:10 On cue from the Examiner, C SG level transmitter will fail HIGH. The BOP will identify the failure and take manual control of the C SG Feedwater Regulating Valve to maintain/restore SG level to between 60% and 65% and prevent a reactor trip.

The crew will enter AOP-40i .11, Steam Generator Level Control and Protection Channel Failure, and remove the channel from service.

The CRS will refer to Technical Specifications 3.3-1, Item 13 (Action 6) and 3.3-3, Items 5, and 6c (Action 24).

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 EVENT 5: Progressive failure of #2 Seal on A RCP.

TRIGGER 5 o MAL-CV0005A, RCP 1 NUMBER 2 SEAL FAILURE

TRIGGER 6 o VLV-CS052W, XVTO8141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER DELETE: 1 second On cue from the Examiner, RCP A Seal Number 2 will begin a ramped failure. The crew will respond to annunciator XCP-61 7 2-4, RCP A STNDPIP LVL HI/LO.

NOTE: The Annunciator will alarm within 4 minutes after the event is triggered and will not cleat.

The RO will fill the standpipe for 2 minutes to determine that either the #1 or #2 seal is failing.

The crew will implement AOP-101 .2, Reactor Coolant Pump Seal Failure and determine that a reactor trip is not required. The RO will continue to monitor the RCP for further seal degradation.

EVENT 6: RCP Trip, ATWS, FW lsol Valve 1611A Fails Closed. (Manual Reactor trip)

TRIGGER 7 o MAL-PCSOO9AB REACTOR TRIP BREAKER A FAILURE (FAIL TO OPEN)

FAIL TO: AUTO o MAL-PCS009BB REACTOR TRIP BREAKER B FAILURE (FAIL TO OPEN)

FAIL TO: AUTO o PCSOO8B FAILURE OF MANUAL REACTOR TRIP SWITCH CS-CRO1A o MAL-RCSOO3A REACTOR COOLANT PUMP 1 TRIP FAIL TO: TRIP o VLV-FWO25P XVGO1611A-FW FEEDWTR ISO VLVA FAIL POSITION Final 0 Delay 00:00:02

EVENTTRIGGER8 o VLV-FWO25P XVG01611A-FW FEEDWTR ISO VLVA FAIL POSITION Delete = 00:00:01 X07D033M <26 NR A SG Level < 26%

NRC 2015 Scenario 3 NUREG -1021 R951

AppencxD Scenario Outline Form ES-D-1 On cue from the Examiner, RCP A will trip but the Reactor will not trip. The crew will enter EOP-1 .0 (E-0), Reactor Trip/Safety Injection Actuation. The RO will manually trip the Reactor.

Only the Manual Reactor trip switch the RD normally operates is functional.

The Feedwater Isolator Value to the A SG (PVG-1611A) spuriously fails closed to lower level in the A SG. Because the associated RCP has tripped, this SC level would otherwise remain above 26% required to force the crew to EOP-15 (FR-H.1), Response to Loss of Secondary Heat Sink. The PVG-1611A failure is auto-removed after NR A SG level is less than 26%.

EVENT 7: Loss Of Heat Sink (EFW) After Reactor Trip.

EVENTTRIGGER9 L52RTAO == 1 RX TRIP BRKR RTA OPEN = TRUE OR L52RTBO == 1 RX TRIP BRKR RTB OPEN = TRUE o MAL-MSSO15 STEAM FAILURE TO EFW TURBINE PRELOAD o PMP-EFOO1S XPPOO21A MOTOR DRIVEN EFW PMP A SHEARED SHAFT PRELOAD o PMP-EFOO2T XPPOO21B MOTOR DRIVEN EFW PMP B TRIP ON COMMAND o MAL-FWMOD1A MAIN FEEDWATER PUMP A TRIP o MAL-FWMOO1B MAIN FEEDWATER PUMP B TRIP o MAL-FWMOO1C MAIN FEEDWATER PUMP C TRIP

TRIGGER 10 o LOA-FWMO4O SS-FW61A XVGO161 1A,B,C KEY SWITCH Position To: BYPASS

TRIGGER 11 o LOA-FWMO41 SS-FW81A1 IFV03321 ,3331 ,3341 TRAIN A KEY SWITCH Position To: BYPASS NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Scenario Outline Form ES-D-1

TRIGGER 12 o LOA-FWMO42 SS-FW81 Bi 1FV03321 33313341 TRAIN B KEY SWITCH Position To: BYPASS This event is automatically triggered when the Reactor Trip Breakers open. The crew will continue in EOP-1 .0 (E-0) Reactor Trip/Safety Injection Actuation and identify that there is no Emergency Feedwater flow to the Steam Generators. The crew will then transition to EOP-1 5.0 (FR-H.1) Response to Loss of Secondary Heat Sink.

All Main Feedwater Pumps will trip when the Reactor Trip Breakers open.

The BOP will depressurize one Steam Generator, reset the Safety Injection actuation, and attempt to establish Main Feedwater flow to one SG. The Main Feedwater pumps cannot be reset so the success path is to continue in EOP-15 (FR-H.1) and utilize Condensate flow to restore SG level.

Trigger 10, 11, 12 places local key-switches in bypass so that Feedwater Valves can be opened to restore flow to one steam generator using Condensate and Feedwater Booster pumps.

CRITICAL TASKS:

It is a critical task to:

Start Back-up EHC Pump prior to a RxlTurbine Trip on Low EHC Pressure.

Manually control C SG Feedwater without a RxlTurbine Trip on SG Level.

Insert a manual Reactor Trip prior to completion of Immediate Actions of EOP-1 .0 (E-0).

Establish feed flow to at least one SG before RCS Feed and Bleed criteria is met (WR level in any two SGs is less than 12% or PZR pressure is greater than 2330 psig due to the loss of secondary heat sink) is met.

TERM I NATION:

The scenario can be terminated after the crew has established feedwater to one Steam Generator or at the Examiners discretion.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Scenario Outline Form ES-D-1 Scenario Attributes Events

PT-446 (Turbine First Stage Pressure) fails LOW.

. Running EHC Pump Trip.

. LT-498 (C SG Level Instrument) fails HIGH.

Total Malfunctions . Progressive failure of #2 Seal on A RCP 5-8 . RCP Trip.

RX trip breakers fail to open.

. FW Isol Valve 1611A Fails Closed.

. EFW pumps trip.

. MFWpumpstrip.

Malfunctions after . LossofMFW.

EOP entry (1-2) 3 . Loss of MD FEW.

Loss of ID EFW.

PT-446 (Turbine First Stage Pressure) fails LOW.

Abnormal Events . Running EHC Pump Trip.

(2-4) . LT-498 (C SG Level Instrument) fails HIGH.

Progressive failure of #2 Seal on UA RCP Major Transient 1 Loss of all Feedwater MEW, MD FEW and TD FEW.

FOPs Entered (1-2) 1 . FOP-i 5.0 (ER-Hi) Response to Loss of Secondary Heat Sink.

FOP Contingencies 1 . FOP-i 5.0 (FR-Hi) Response to Loss of Secondary Heat Sink.

. Start Back-up EHC Pump prior to a Rx/Turbine Trip on Low EHC Pressure.

Critical Tasks . Manually control C SG Feedwater without a Rx/Turbine Trip on SG 2-3 4 Level.

I

. Manual Trip prior to completion of Immediate Actions of FOP-i .0 (E-0).

. Establish feed flow to at least one SG before RCS feed and bleed criteria is met.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Scenario Outline Form ES-D-1 SIMULATOR SCENARIO SETUP INITIAL CONDITIONS:

lCSet292

100% Power MDL

Rod Position = 230

FCV-1 13 Pot Setting = 4.31

Boron = 1005 ppm

Xe=-2700pcm

Burnup = 10001 MWD/MTU

Prior to the scenario, crew should pre-brief on conditions and expectations for the Shift (maintain power, repairs estimated to be complete well before LCD action time expires.)

PRE-EXERCISE:

Ensure simulator has been checked for hardware problems (DORT, burnt out light bulbs, switch malfunctions, chart recorders, etc.)

VCS-TQP-0807 Attachment I-A, Unit 1 Booth Instructor Checklist, has been completed.

Verify the Hard Card for Turbine Load changes is in its proper storage location.

Verify the Hard Card for borating via MVT-81 04 is in its proper storage location.

Hang Tags for equipment out of service.

Mark up procedures in use with Circle and slash as applicable.

A turnover sheet has been prepared for each position.

Conduct two-minute drill.

PRE-LOAD:

STANDARD SIMULATOR SETUP:

PMP-LDOO3P, XPPO138 LEAK DETECTION SUMP PMP LOSS OF POWER

VLV-FWO28W, XVG01676-FW FW HDR RECIRC ISOL VLV LOSS OF POWER

VLV-FWO29W, XVG01679-FW FW HTR RECIRC ISO VLV LOSS OF POWER

VLV-CSO52W, XVTO8141A-CS RCP A SEAL LEAKOFF VLV LOSS OF POWER

VLV-CSO54W, XVTO8141C-CS RCP C SEAL LEAKOFF VLV LOSS OF POWER

VLV-CSO53W, XVTO8141B-CS RCP B SEAL LEAKOFF VLV LOSS OF POWER

ANN-TAO3O, GEN AUX PNL TREL SCENARIO RELATED:

ANN-TAO3O, GEN AUX PNL TRBL FAIL TO: OFF

ANN-CS044, ALT SEAL INJ PUMP TRBL FAIL TO: ON

MAL-CVCO27, ALT SEAL INJ DIG FAIL TO START

MAL-CVCO29, ALT SEAL INJ PUMP FAIL TO START NRC 2015 Scenario 3 NUREG -1021 R951

Appendix D Operator Actions Form ES-D-2 OplestNo: NRC-ILO-13-01 Scenario# 3 Event 1 Page: 10 of 47 Event

Description:

PT-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

Time I Position Applicants Actions or Behavior EVALUATOR NOTE: On cue from the Examiner, the selected turbine first stage pressure transmitter (PT-446) will fail LOW. The failure causes a Tave -Tref mismatch resulting in rods inserting at the maximum speed. The crew will enter AOP-401 .7, Turbine First Stage Pressure Channel Failure.

The RO will respond to the rod insertion by placing rod control in manual and restoring Tave to within 1 degree of Tref. The crew will then select the operable 1st stage pressure channel for control. The RO may restore automatic rod control after the operable channel is selected. The BOP will place the STM DUMP MODE SELECT in STM PRESS.

The Failed instrument is addressed in Technical Specification Table 3.3-1 Items 19.B, E and Table 3.3-3 Item 4.d. Within one hour verify the P7 and P13 permissives are dim, trip the affected bistables within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and place AMSAC in Bypass.

BOOTH OPERATOR: When directed, insert Event 1 (TRIGGER 1)

Indications available:

Uncontrolled Rod Motion XCP-615, 2-5, RCS TAVG-TREF HI/LO; XCP-624-4-2, 5-2, 6-2; SG A, B, C STM FLO HI EVALUATOR NOTE: The crew could enter the ARP but it is likely that they will recognize the entry condition for AOP-401 .7, Turbine First Stage Pressure Channel Failure.

CRS Enters AOP-401.7, Turbine First Stage Pressure Channel Failure A0P401.7 EVALUATOR NOTE: If XCP-621 1-1 CRB INSERT LMT LO-LO is received the RO will immediately Emergency Borate per AOP-1 06.1, Emergency Boration until Shutdown Margin is restored.

IOA RO 1 Place Rod Control Bank Select Switch to MANUAL AOP-401 .7 NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 3 Event # 1 Page: 11 of 47 Event

Description:

P1-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

Time ] Position Applicants Actions or Behavior 1ST AOP-401 .7 RO 2 Ensure TREF STG PRESS switch is positioned to the operable channel:

P446, OH III. (FAILED)

OR PT-447, OH IV RO 3 Adjust Control Rods until Tavg is within 1.00 F of Tref. AOP-401 .7 BOP 4 Check if Main Turbine load is greater than 10% AOP-401 .7 CRS 5 Within one hour, verify the following permissives are dim: AOP-401 .7

P-13, ist STG PRESS

P-7, REACTOR TRIP BLOCKED EVALUATOR NOTE:

Due to the windup (integral) characteristic of the Rod Control function, the crew may not immediately place rods back in automatic.

The crew may elect to restore rods to their previous position.

RO 6 Restore automatic rod control. AOP-401 .7

a. Check if automatic rod control is desired.

b. Verify Reactor power is GREATER THAN 15% (0-5 status light dim).

c. Verify Tavg is within 1.0°F of Tref.

d. Place ROD CNTRL BANK SEL Switch in AUTO.

BOP 7 Place Steam Dump Mode Select Switch in STM PRESS. AOP-401 .7 NRC 2015 Scenario 3 11 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-1 3-01 Scenario # 3 Event # 1 Page: 12 of 47 Event

Description:

P1-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR:

. Acknowledge requests for support.

. Wait 3 minutes

. Call for permission to proceed.

. Use TRIGGER 2 to place AMSAC in BYPASS

. Report that AMSAC is in Bypass CRS 8 Notify I&C to place AMSAC in BYPASS. AOP-401 .7 CRS 9 Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , place the failed channel protection bistables in a AOP-401 .7 tripped condition:

CRS a. Identify the associated bistables for the failed channel. REFER AOP-401 .7 TO Attachment 1.

TURBINE FIRST STAGE PRESSURE PROTECTION AOP-401 .7 CHANNELS Attachment 1 ASSOCIATED BIS [ABLE BISTABLE LOCATION TRIP STATUS LIGHT TECH SPECS FB-474A C3-741-BS-I [HAN III LPA FB-474A TABLE 3.3-1 ITEMS 19.B. E FB-484A C3-746-BS-1 [HAN III LPB FB-484A TABLE 3.3-3 ITEM 4.d FB-494A C3-748-BS-1 [HAN III LPC FB-494A CRS b. Record the following for each associated bistable on SOP-401, AOP-401 .7 REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:

Instrument

. Associated Bistable.

. Bistable Location.

. STPs.

NRC 2015 Scenario 3 - 12- NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # 1 Page: 13 of 47 Event

Description:

P1-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

Time Position Applicants Actions or Behavior CRS Table 3.3-1 Action 7 Tech Spec 3.3.1 Refers to Technical Specification Table 3.3-1 and within one hour determines by observation of the associated permissive annunciator window(s) that the interlock is in its required state for the existing plant condition.

IARtE 3.31 (ConC1nud)

REACTOR TRIP SYSTEM INSTRUMENTATION MiNIMUM TOTAL NO. CHANNELS CHANNELS APPLICABtE FUNCTIONAL UNIT 5* CHANNELS TO TRIP OPERANts MODES ACTION

19. Reactor TrIp System Int.rIoCEs N. 1.0w Power Reactor Trips Block, P-i P-ID Input 4 2 3 1 7 P-13 Input 2 1 2 1 7

t. Turbine First Stage Pressure, P13 2 1 2 1 ACTION 7 - With less than the Minimum Number of Channels OPERABLE, within one hour detemrine by obsematioi, of the associated pemissive annunciator window(s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.03.

CRS Table 3.3-3 Action 24 Tech Spec Refers to Technical Specification Table 3.3-3 and determines that the 3.3.2 inoperable channel must be placed in a tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

TABLE 333 lcon,1lLULe.clj ENGINEERED SAEEIYFEATURE AC]1.(ATION SYSTEM INSTRUMENTATION TOTAL NO. MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT CHANNELS jj OPERABLE MODES IiQN

4. STEAM LIME ISOLATION

d. Steam Flow in Two Steam 2/stesm line 1/steam line 1/steam line 1, 2, 3U 24 Lines..Higfl any 2 steam lines COINCIDENT WITH I T--Low-Low 1 T,9iIoop 1 T.w any I any 1,2, 3 24 stoops 2 loops The provisions of Specification 3 0 4 are not applicable ACTION 24 - With the number f OPERABLE channels one less than the Total Number of Channels, STARTUP andlor POWER OPERATION may proceed provided the following conditions are satisfied a The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months b The Minimum Channels OPERABLE requirement is met; however. the inoperable channel maybe bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels per Specificalion 4.32 1 BOOTH OPERATOR:

Acknowledge requests for assistance and inform the crew that support personnel will be assigned.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-O1 Scenario # 3 Event # 1 Page: 14 of 47 Event

Description:

PT-446 (Turbine First Stage Pressure) fails LOW. (Rods Drive In)

Time Position [ Applicants Actions or Behavior c Notify I&C to place the failed channel protection bistables in a tripped AOP-401 .7 condition within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

FB-474A CR5

FB-484A

FB-494A d Initiate a 30 day R&R for placing AMSAC in BYPASS.

EVALUATOR NOTE:

The next event may be initiated after I&C is called to trip the bistables and Technical Specifications have been addressed.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 2 Page: 15 of 47 Event

Description:

Rapid Power Reduction due to overheating of main generator disconnects.

Time Position I Applicants Actions or Behavior EVALUATOR NOTE: Direct the Booth Operator to call the Control Room as the Shift Supervisor. The RO will lower Reactor power with boration and/or rod motion. The BOP will reduce turbine load using the Turbine controls.

BOOTH OPERATOR:

No triggers for this event.

When directed, call the Control Room as the Shift Supervisor and notify the CRS:

Thermography in the switchyard indicates the transformer disconnects are overheating.

Lower power 10% within the next 15 minutes in accordance with GOP-4C, Rapid Power Reduction.

CRS Direct the crew to reduce power 10% in accordance with GOP-4C Rapid Power Reduction.

NOTE 2.0 through 3.0 GOP-4c

a. If this procedure must be initiated under conditions other than those in Section 2.0, INITIAL CONDITIONS, the Shift Supervisor or Control Room Supervisor will review Sections 2.0, INITIAL CONDiTIONS, and 3.0, INSTRUCTIONS. Steps that are not applicable due to plant conditions will be marked N/A and initialed by the Shift Supervisor or Control Room Supervisor. All other items will require sign-off or check-off.

b. All personnel who sign off steps in this procedure must enter their names and initials on Attachment I.

c. Each step should be initialed and dated when all its substeps are either completed and checked-off or marked as N/A and initialed.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-01 Scenario # 3 Event # 2 Page: 16 of 47 Event

Description:

Rapid Power Reduction due to overheating of main generator disconnects.

Time I Position Applicants Actions or Behavior GOP- 4C REFERENCE PAGE GOP-4C GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. After any Thermal Power change of greater than 15% within any one hour, Attachment lII.H.

of GTP-702 must be completed.

C. If Reactor Power is stabilized during this procedure for the purpose of raising power per GOP-4A, a Power Range Heat Balance shall be performed.

D. Once a Rapid Power Reduction has begun, every effort should be made to prevent the Turbine from reaching AT SET LOAD unless it is desired to stabilize the plant.

REACTOR CONTROL A. During operation with a positive Moderator Temperature Coefficient, power and temperature changes will require constant operator attention.

B. Rod Control should be maintained in Automatic if any Pressurizer PORV is isolated.

C. If at anytime, power decreases unexpectedly below 0.1% on any Power Range NI (computer indication available) OR below 1 .0% on any Power Range NI control board indication (computer not available):

1) No positive reactivity will be added by rods or dilution.

2) A complete reactor shutdown shall be performed per GOP-5.

3) A controlled reactor startup may be commenced per GOP-3 once the event has been reviewed by Reactor Engineering.

REACTOR TRIP CRITERIA DURING RAPID LOAD REDUCTION A. If any of the following conditions occur, trip the Reactor and implement EOP-1 .0:

1) RCS Tavg is less than 551°F for greater than 15 minutes.

2) Tavg/Tref mismatch exceeds 10°F.

3) Pressurizer pressure approaches 1870 psig.

4) Power reduction at 5% per minute is not sufficient to mitigate the event.

NOTE 3.0 GOP-4C If time allows, load reductions should be discussed with the Load Dispatcher.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 3 Event # 2 Page: 17 of 47 Event

Description:

Rapid Power Reduction due to overheating of main generator disconnects.

Time I Position I Applicants Actions or Behavior CAUTION 3.1 through 3.12 GOP-4C

a. Thermal Power changes of greater than 15% in any one-hour period requires completion of GTP-702 Attachment lll.H.

b. VCS PID Report, POWER CHANGE SEARCH, should be periodically performed to ensure a thermal power change of greater than 15% in any one-hour period is detected.

RD 3.1 Commence rapid Plant Shutdown as follows: GOP-4C

a. Energize all Pressurizer Heaters.

EVALUATOR NOTE:

SOP-106 lll.F, Borate Operations, is attached (Page 41).

SOP-i 06 IV.D, Borating the RCS Using the Emergency Borate Valve, is attached (Page 43).

SOP-214 Ill. D. Turbine Load Reduction/Shutdown, is attached (Page 44).

NOTE 3.1.b GOP-4C Setting FCV-i 13A&B, BA FLOW SET PT to 8.3 will yield 33 gpm Boration flow rate.

RD b. Maintain the following with rod motion or boron concentration GOP-4C changes:

1) Tavg within 10°F and trending to Tref.

2) Lii within limits.

3) Control Rods above the rod insertion limit.

BOP c. Using the Turbine HMI, Control/Load screen, reduce to the GOP-4C desired load, as low as 5% (50 MWe), as follows:

1) Under Rate %/min, select desired ramp rate up to 5% per minute.

2) Select Load (a dialog box opens).

3) Enter desired load.

4) Select OK.

5) Confirm setpoint.

6) Select OK.

7) Verify proper plant response.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # 2 Page: 18 of 47 Event

Description:

Rapid Power Reduction due to overheating of main generator disconnects.

Time I Position I Applicants Actions or Behavior CREW Stabilize the unit at 10% reduced power.

EVALUATOR NOTE: The next event may be initiated after a significant power change has been observed.

NRC 2015 Scenario 3 18- NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 3 Page: 19 of 47 Event

Description:

Running EHC Pump Trip. (Standby EHC must be manually started).

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: On cue from the Examiner, the running EHC pump will trip and the backup pump will not start in auto. The BOP will respond to annunciator XCP-631 1-4, EHC PP A MOTOR OVRLD, determine the cause of the event, and take corrective action by starting the backup EHC pump to prevent turbine stop valves from closing. A Turbine trip will occur within 2 minutes if the event is not mitigated.

BOOTH OPERATOR: When directed, insert Event 3 (TRIGGER 3)

Indications available:

Control Switch Red and Green lights XCP-631, 1-4, EHC PP A MOTOR OVRLD XCP-631, 1-2, EHC FLUID PRESS LO BOP Enters ARP-OO1-XCP-631 1-4, EHC PP A MOTOR OVRLD XCP-631 1-4 CORRECTIVE ACTIONS: xcP-631 1-4 BOP 1. If EHC PUMP A is still running, verify high amps. (NO) xcP-631 1-4 BOP 2. Start EHC PUMP B and observe motor amps. xcP-631 1-4

3. If EHC PUMP A is still running with higher amps than EHC PUMP B, XCP-631 1-4 BOP secure EHC PUMP A and continue to monitor EHC PUMP B. (NO)

BOOTH OPERATOR:

Acknowledge request to check for EHC Leaks. 3 minutes later report no leaks.

If called to investigate the pump and/or breaker, wait 3 minutes and report the breaker for the A EHC Pump is tripped. No problems are apparent with the pump.

BOP 4. Dispatch an operator to check for EHC System leaks. xcP-631 1-4 BOP 5. If EHC PUMP B is drawing high amps with EHC PUMP A tripped, xcp-631 1-4 attempt to restart EHC PUMP A and run both pumps until an external leak is located or a low level in the EHC fluid tank alarm is received.

(NO)

NRC 2015 Scenario 3 NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 3 Event # 3 Page: 20 of 47 Event

Description:

Running EHC Pump Trip. (Standby EHC must be manually started).

Time Position Applicants Actions or Behavior BOP 6. If EHC PUMP B overload annunciator is received after starting, xcP-631 1-4 commence a Turbine Runback at 5% per minute per GOP-4C. (NO)

EVALUATOR NOTE: The failure of the backup EHC pump to auto-start results in EHC pressure continuing to decrease. The Low Pressure alarm will alert operators to the failure if not previously discovered however this alarm provides no additional operator actions Respond to alarm EHC FLUID PRESS LO (XCP-631, 1-2) EHC BOP FLUID PRESS LO EVALUATOR NOTE: The next event may be initiated after the B EHC pump is started.

NRC 2015 Scenario 3 NUREG -1021 R9 51

Ajrendix D Ooerator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 4 Page: 21 of 47 Event

Description:

LT-496 (C SG Level Instrument) fails HIGH. (Manually control feedwater to C SG)

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: On cue from the Examiner, C SG level transmitter will fail HIGH. The BOP will identify the failure and take manual control of the C SG Feedwater Regulating Valve to maintain/restore SG level to between 60% and 65% and prevent a reactor trip.

The crew will enter AOP-401 .11, Steam Generator Level Control and Protection Channel Failure, and remove the channel from service.

The CRS will refer to Technical Specifications 3.3-1, Item 13 (Action 6) and 3.3-3, Items 5, and 6c (Action 24) to determine that the protection bistables for the failed channels must be placed in the TRIPPED condition with 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

BOOTH OPERATOR: When directed, insert Event 4 (TRIGGER 4)

Indication Available:

XCP-624 3-4, SG C LVL DEV

XCP-624 6-4, SG C FWF>STF MISMATCH BOP Responds to alarms.

BOP Diagnoses/reports LT-496 failed.

CRS Enters AOP-401 .11.

IOA BOP 1 Adjust the Feedwater Flow Control Valve as necessary to restore AOP-401 .17 Narrow Range level in the AFFECTED SG to between 60% and 65%.

CRS 2 Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , place the failed channel protection bistables in a AOP-4D1 .17 tripped condition:

a. Identify the associated bistables for the failed channel. REFER TO Attachment 1.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-O1 Scenario # 3 Event # 4 Page: 22 of 47 Event

Description:

Ll-496 (C SG Level Instrument) fails HIGH. (Manually control feedwater to C SG)

Time I Position I Applicants Actions or Behavior AOP-401.11 STEAM GENERATOR LEVEL PROTECTION CHANNELS Excerpt from Attachment 1 ASSOCIATED BISTABLE INSTRUMENT BISTABLE LOCATION TRIP STATUS LIGHT TECH SPECS STPS LT-496 LB-496A C3-731-BS-I CHAN III SO C LB-496A TABLE 3.3-1 ITEM 13 302.025 LB-496C C3-731-BS-2 CHAN III SO C LB-496C TABLE 3.3-3 ITEMS 5. 6.c 345.029

LB496 XPN-6O1OtAMSAC)

Bistable defeated by placing AMSAC in BYPASS BOP b. Record the following for each associated bistable on SOP-401, AOP-401 .11 REACTOR PROTECTION AND CONTROL SYSTEM, Attachment I:

Instrument.

Associated Bistable.

Bistable Location.

STPs.

EVALUATOR NOTE: The scenario does not allow time for any bistables to be put in trip or bypass.

BOOTH OPERATOR: Acknowledge request to troubleshoot failure and place bistables in trip.

CRS c. Notify the l&C Department to place the identified bistables in trip. AOP-401 .11 CRS d. For channels LT-474, LT-485, and LT-496, initiate a 30 day R&R AOP-401 .11 for placing AMSAC in BYPASS.

NRC 2015 Scenario 3 - 22 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 3 Event # 4 Page: 23 of 47 Event

Description:

LT-496 (C SG Level Instrument) fails HIGH. (Manually control feedwater to C SG)

Time I Position I Applicants Actions or Behavior 1ABIE 3.3-1 (Continued) Excerpt from Tech Spec REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM TOTAC NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL tINIT Of CHANNELS TO TRIP OPERABLE MODES ACIZON

13. Steam Generator bater 3/loop 2/loop In 2/loop In 1 z Level--low-Low each oper 6

any oper-ating loope ating loop ACTION 6 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; and

b. The Minimum Channels OPERABLE requirement is met: however, the inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels per Specification 4.3.1.1.

Excerpt from TAILE 1. }3 lCr11iiue Tech Spec UIEfDSUtTY ftTJ[ UITtc S9 N11I!1rUCJl

!ItNDM IEThL 3 CW4HtI_5 t11EL LJCtE rdFCTJINALIWT hf OM1ULLi tf 111 f NOfl T1UN fl ti2 TP I.LATI,N i lr,i niol ,..i Let4. .3, :x acop ii nv a Oop ir 1, 2 J Cfl UpIt.

b:p atrt till-p 6 UER&ENCY ;tEO,TER

. $tii. ben. Wt.r i.c*n 1 Lnw tnw

1. start tbtor tYtl U7p1 tintn. 9Ii. 2tstn. tin. Ztbe in 1 2. 3 24*

nny 11 c*ri.

11. Start Turbine Orlwen Pi1i i/nUn, ten. 2tbi. n 2/atm. .n 1, 2. 3 24*

eny 2 ntn. gn.

ACTioN 23 - Wth lne lumber of OPEft5LE cnariels one Iae than the Tola NLlrnoer o CflanleIU. TATUP ardor PC WE OPEftATION may proceco proildea the oIoIrg ColdioDle are Eatsle-3 a me notieratile chalne Ia placed In me cupped cond lion WIthin 72 hOUr5.

0. Tfle Minimur ChaflrCIe OPERAcE raquiremeru Is met; hoeer. tile qoperatile cIlalne- may be bytiasoed for up to 12 rtiurs tor surveillance uestir or other channels tier tiecitc.aton 3.3.2.1.

CRS Refers to:

T.S. 3.4.3.1 Reactor Trip System Instrumentation Table 3.3-1 -

Action 6 NRC 2015 Scenario 3 - 23 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # 4 Page: 24 of 47 Event

Description:

LT-496 (C SG Level Instrument) fails HIGH. (Manually control feedwater to C SG)

Time Position Applicants Actions or Behavior T.S. 3A 3.2 Engineered Safety Feature Actuation System Instrumentation Table 3.3-3 Action 24 EVALUATOR NOTE: The next event may be initiated after Technical Specifications have been addressed.

NRC 2015 Scenario 3 - 24 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-lLO-13-O1 Scenario# 3 Event # 5 Page: 25 of 47 Event

Description:

Progressive failure of #2 Seal on A RCP.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE: On cue from the Examiner, RCP A Seal Number 2 will begin a ramped failure. The crew will respond to annunciator XCP-61 7 2-4, RCP A STNDPIP LVL HI/LO.

NOTE: The Annunciator will alarm within 4 minutes after the event is triggered and will not cleat.

The RO will fill the standpipe for 2 minutes to determine that either the #1 or #2 seal is failing.

The crew will implement AOP-1 01.2, Reactor Coolant Pump Seal Failure and determine that a reactor trip is not requited. The RO will continue to monitor the RCP for further seal degradation.

BOOTH OPERATOR: When directed, insert Event 5 (TRIGGER 5)

Indications Available:

XCP-617 2-4, RCP A STNDPIP LVL HI/LO.

RO 1. Determine which seal failed as follows: XCP-617 2-4 RO a. Attempt to fill the standpipe as follows: XcP-61 7 2-4

1) Ensure Reactor Makeup Water System Non-Essentials are aligned.

2) Open PVD-8028, PRT RMWST MU.

3) Open PVD-8168A, RX MU WTR TO STNDPIPE A.

RO 4) When one of the following occurs, close PVD-8168A, R)( MU XCP-617 2-4 WTR TO STNDPIPE A:

a) RCP A STNDPIP LVL HI/LO alarm clears and re-annunciates on a standpipe high level.

b) RCP A STNDPIP LVL HI/LO alarm does not clear within two minutes.

5) Close PVD-8028, PRT RMWST MU.

6) Monitor radiation levels in the Reactor Building.

EVALUATOR NOTE: The alarm will NOT clear by filling the standpipe.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # 5 Page: 26 of 47 Event

Description:

Progressive failure of #2 Seal on A RCP.

Time Position Applicants Actions or Behavior RO b. If the standpipe alarm clears by filling, assume #2 or #3 Seal XCP-61 7 2-4 failure.

c. If the standpipe alarm does not cleat by filling, assume #1 or #2 Seal failure and go to AOP-101.2, Reactor Coolant Pump Seal Failure.

CRS Diagnose #1 or #2 Seal failure.

CRS Implement AOP-1 01.2, Reactor Coolant Pump Seal Failure.

CAUTION AOP-1 01.2

PVT-8141A(B)(C), A(B)(C) SEAL LKOFF, should be closed between three minutes and five minutes after the affected Reactor Coolant Pump is secured.

Reactor Coolant System Controlled Leakage should be limited to 33 gpm per Technical Specification 3.4.6.2 in Modes 1,2,3, and 4.

BOOTH OPERATOR:

. Wait 3 minutes after being directed to install the fuses

. Use Trigger 6 to install XVT-8141A-FU-CS75 for RCP A

. Report power has been restored to the Seal Leakoff Valve for RCP A RO 1 While continuing with this procedure, have an operator install the pre AOP-1 01.2 staged fuses for the AFFECTED RCPs Seal Leakoff Valve in Main Control Board Panel XCP-6109 Subpanel #5:

XVT-8141A-FU-CS75.

XVT-8141 B-FU-CS76.

XVT-81 41 C-FU-CS77.

NOTE Ster 2 AOP-1 01.2 IF Seal Injection flow has been throttled to optimize RCP Seal performance, THEN Step 2 does not need to be performed.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 3 Event # 5 Page: 27 of 47 Event

Description:

Progressive failure of #2 Seal on A RCP.

Time Position Applicants Actions or Behavior RD 2 Ensure seal injection flow is GREATER THAN 8 gpm for the affected AOP-1 01.2 Reactor Coolant Pump on Fl-i 30A(127A)(124A), RCP A(B)(C) INJ FLO GPM.

RD 3 Ensure Component Cooling Water flow to the affected Reactor AOP-1 01.2 Coolant Pump thermal barrier is between 35 gpm (50%) and 60 gpm (87.5%) on FM-7i38(7i58)(7178), RCP THERM BAR A(B)(C)

(MODUFLASH M2 CC POINTS i9,i8, and 20).

RD 4 Check the following conditions for the affected Reactor Coolant Pump AOP-1 01.2 on the IPCS:

Bearing water temperature (LOWER SEAL WTR BRG T) on T041 7A (T0437A)(T0457A) is LESS THAN 225° F and NOT significantly increasing.

AND

#1 seal leakoff temperature (SEAL WTR OUT TEMP) on T0181A (TO1S2A)(T0183A) is LESS THAN 235°F and NOT significantly increasing.

RO 5 GOTOStepii. AOP-1 01.2 RD i i Check total #i seal flow (#i seal leakoff plus #2 seal leakoff) for the AOP-1 01.2 affected Reactor Coolant Pump from the following:

a. Check if #i seal leakoff flow is LESS THAN 6 gpm on FR-i 54A, RCP SL LKOFF HI RANGE.

RD b. Determine total #1 seal flow (#i seal leakoff plus #2 seal leakoff) AOP-1 01.2 for the affected Reactor Coolant Pump from the following:

i) #i seal leakoff flow by observing FR-i 54B, RCP SL LKOFF LO RANGE, and FR-i 54A, RCP SL LKOFF HI RANGE, or by having l&C install a temporary flow transmitter with readout on the IPCS per ICP-340.050, TEMPORARY INSTRUMENT INSTALLATION FOR RCP SEAL LEAKOFF MONITORING.

2) #2 seal leakoff flow by monitoring RCDT inleakage per the applicable portion of STP-i 14.002, OPERATIONAL LEAKAGE TEST, for any increase from the previous leak rate.

NRC 20i5 Scenario 3 NUREG-102i R9Si

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-01 Scenario # 3 Event # 5 Page: 28 of 47 Event

Description:

Progressive failure of #2 Seal on A RCP.

lime Position Applicants Actions or Behavior RO 12 IF total #1 seal flow is GREATER THAN 0.8 gpm AND LESS THAN AOP-1 01.2 6 gpm, THEN perform the following:

Contact Plant Support Engineering for evaluation.

Continue to monitor for further seal degradation.

EVALUATOR NOTE: The next event may be initiated after #1 seal flow is identified as greater than 0.8 gpm.

CRS 13 Return to Procedure and Step in effect. AOP-1 01.2 EVALUATOR NOTE: If this event is run for greater than 15 minutes XCP-61 7 2-1, RCP A #1 SL LKOFF FLO HI/LO, will alarm indicating that seal flow is less than 0.8 gpm. The Alternative Action for Step 12 would then require completion of steps 14-16.

CRS 14 Within eight hours, stop the affected Reactor Coolant Pump. REFER AOP-101 .2 TO SOP-lOl, REACTOR COOLANT SYSTEM.

BOOTH OPERATOR: Acknowledge requests for support.

CRS 15 Contact Plant Support Engineering for evaluation. AOP-1O1 .2 RO 16 Continue to monitor for further seal degradation. AOP-1 01.2 NRC 2015 Scenario 3 NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-1 3-01 Scenario # 3 Event # 6, 7 Page: 29 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (LFW), Trip of Main FW pumps.

Time I Position I Applicants Actions or Behavior EVALUATOR NOTE:

EVENT 6 On cue from the Examiner, RCP A will trip but the Reactor will not trip. The crew will enter EOP-1 .0 (E-0) Reactor Trip/Safety Injection Actuation. The RO will manually trip the Reactor.

Only the Manual Reactor trip switch the RO normally operates is functional.

EVENT 7 This event is automatically triggered when the Reactor Trip Breakers open. The crew will continue in EOP-1 .0 (E-0) Reactor Trip/Safety Injection Actuation and identify that there is no Emergency Feedwater flow to the Steam Generators. The crew will then transition to EOP-15.0 (FR-H.1) Response to Loss of Secondary Heat Sink.

The BOP will depressurize one Steam Generator, reset the Safety Injection actuation, and attempt to establish Main Feedwater flow to one SG. The Main Feedwater pumps cannot be reset so the success path is to continue in EOP-15 (FR-H.1) and utilize Condensate flow to restore SG level.

BOOTH OPERATOR: When directed, insert Event 6 (TRIGGER 7)

Indications Available:

Indication of a Turbine trip w/o a reactor trip.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-tLO-13-01 Scenario # 3 Event # 6, 7 Page: 30 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time I Position I Applicants Actions or Behavior REFERENCE PAGE FOR EOP-1.0 EOP-1.O 1 RCP TRIP CRITERIA

a. IF Phase B Containment Isolation has actuated (XCP-612 4-2).

THEN trip all RCPs.

b. I.E iath of the following conditions occur. THEN trip all RCPs:

SI flow is indicated on FI-943. CHG LOOP B CLD/HOT LG FLOW GPM.

AND

RCS Wide Range pressure is LESS THAN 1418 psig.

2 REDUCING CONTROL ROOM EMERGENCY VENTILATION Reduce Control Room Emergency Ventilation to gn train in operation within 30 minutes of actuation. REFER TO SOP-505.

CONTROL BUILDING VENTILATION SYSTEM.

3 MONITOR SPENT FUEL COOLING Periodically check status of Spent Fuel Cooling by monitoring the following throughout event recovery:

Spent Fuel Pool level.

Spent Fuel Pool temperature.

NOTE EOP-1.O

Steps 1 through 5 are Immediate Operator Actions.

The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

EVALUATOR NOTE: The Reactor will not automatically trip. The RO must manually trip the reactor. Only the Manual Reactor trip switch the RO normally operates is functional.

NRC 2015 Scenario 3 - 30 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-01 Scenario # 3 Event # 6, 7 Page: 31 of 47 Event

Description:

RCP Trip, AIWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior IOA RO 1 Verify Reactor Trip: (NO) EOP-1.0

Trip the Reactor using either Reactor Trip Switch.

Verify all Reactor Trip and Bypass Breakers are open.

Verify all Rod Bottom Lights are lit.

Verify Reactor Power level is decreasing.

BOP ALTERNATIVE ACTION EOP-1.0

-J 1 Trip the Reactor using both Reactor Trip Switches.

OFc If the Reactor is NOT subcritical, THEN GO TO EOP-13.0, 0 RESPONSE TO ABNORMAL NUCLEAR POWER GENERATION, Step 1.

IOA BOP 2 Verify Turbine/Generator EOP-1 .0

a. Verify all Turbine VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

IOA BOP 3 Verify both ESF buses are energized. EOP-1 .0 IOA RO 4 Check if SI is actuated: (NO) EOP-1 .0

a. Check if either:

SI ACT status light is bright on XCP-6107 1-1.

OR

Any red first-out SI annunciator is lit on XCP-626 top row.

b. Actuate SI using either SI ACTUATION Switch.

c. GO TO Step 6.

ALTERNATIVE ACTION

a. GO TO Step 5.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 3 Event # 6, 7 Page: 32 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 161 1A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior RO 5 Check if SI is required: (NO) EOP-1 .0

a. Check if any of the following conditions exist:

PZR pressure LESS THAN 1850 psig.

OR

RB pressure GREATER THAN 3.6 psig.

OR

Steamline pressure LESS THAN 675 psig.

OR

Steamline differential pressure GREATER THAN 97 psid.

ALTERNATIVE ACTION

a. GO TO EOP-1 .1, REACTOR TRIP RECOVERY, Step 1.

EVALUATOR NOTE:

EOP-1 .0 directs a transition to EOP-1 .1 however a Red Path on Heat Sink requires implementation of EOP-15.0, Response to Loss of Secondary Heat Sink.

If Safety Injection occurs while EOP-1 5 is being implemented the crew may implement EOP-1 .0 Attachment 3 (Page 45).

CRS Implement EOP-15.0, Response to Loss of Secondary Heat Sink.

CAUTION EOP-1 5.0

If total EFW flow is LESS THAN 450 gpm due to operator action, this procedure should NOT be performed, since these actions are NOT appropriate if 450 gpm EFW flow is available.

If a NON-FAULTED SG is available, feed flow should NOT be reestablished to any FAULTED SG, to prevent thermal shock to SG tubes.

NOTE EOP-1 5.0 Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 6, 7 Page: 33 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 161 1A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior RD 1 Check if a secondary heat sink is required: FOP-i 5.0

a. Verify RCS pressure is GREATER THAN any NON-FAULTED SG pressure.

b. Verify RCS Thot is GREATER THAN 350°F.

RD 2 Verify power is available to all PZR PORV Block Valves: FOP-i 5.0

a. MVG-8000A, RELIEF 445 A ISOL.

b. MVG-S000B, RELIEF 444 B ISOL.

c. MVG-8000C, RELIEF 445 B ISOL.

RD 3 Open the Block Valve for any PZR PORV that has been isolated due EOP-i 5.0 to excessive seat leakage:

MVG-8000A, RELIEF 445 A ISOL.

MVG-8000B, RELIEF 444 B ISOL.

MVG-8000C, RELIEF 445 B ISOL.

CAUTION - Steps 4 through 16 EOP-i 5.0 If Wide Range level in any two SGs is LESS THAN 12% OR PZR pressure is GREATER THAN 2330 psig due to loss of secondary heat sink, Steps 17 through 24 should be immediately initiated for bleed and feed cooling.

RD 4 Ensure the following valves are closed: FOP-i 5.0

SG Blowdown, PVG-503A(B)(C).

SG Sample, SVX-9398A(B)(C).

NOTE Step 5 FOP-i 5.0 If EFW flow control can NOT be reestablished from the Control Room, this procedure should be continued while local operator action is in progress to restore EFW flow.

NRC 2015 Scenario 3 33 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 6, 7 Page: 34 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time ] Position Applicants Actions or Behavior BOP 5 Try to establish EFW flow to at least one SG: EOP-1 5.0

a. Check Control Room indications for the cause of EFW failure:

1) Verify no EFW annunciators are lit:

XCP-621 3-5 (EFP SUCT HDR PRESS LO XFER TO SW).

Any alarm on XCP-622.

Any alarm on XCP-623.

2) Verify CST level is GREATER THAN 5 ft.

3) Ensure power is available to both MD EFW Pumps.

CAUTION - Step 5.a.4) EOP-1 5.0

EFW valves should NOT be opened to SGs with Wide Range level LESS THAN 12%.

If Wide Range level in all SGs is LESS THAN 12%, EFW valves should be open to only one SG, until RCS temperatures are decreasing, to limit any failure to one SG.

BOP 4) Ensure all EFW valves are open: EOP-1 5.0

FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).

FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).

MVG-2802A(B), MS LOOP B(C) TO TD EFP.

PVG-2030, STM SPLY TO TD EFP TRN A(B).

BOP b. Try to restore any EFW flow. EOP-1 5.0 NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # 6,7 Page: 35 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time I Position I Applicants Actions or Behavior BOOTH OPERATOR:

NOTE: Do Not Provide Information About Any Equipment Which Was Not Specifically Requested.

Acknowledge requests to investigate the EFW problems. The following conditions exist:

The A EFW Pp has a sheared shaft.

The B EFW Pp has tripped with no obvious cause.

The TD EFW Pp Steam Supply Valve, IFV-2030, has failed closed and cannot be opened.

After 5 minutes report to the control room that attempts to correct the problems are unsuccessful.

BOP c. Check total EFW flow to SGs GREATER THAN 450 gpm. EOP-15.O ALTERNATIVE ACTION

c. IF any feed flow to at least one SG verified, THEN perform the following: ... (NO)

IF feed flow NOT verified, THEN perform the following:

1) Locally restore EFW flow.

2) GO TO Step 7.

RD 7 Stop all RCPs. EOP-15.O CAUTION - Step 8 EOP-15.O Deaerator Storage Tank level should be monitored closely and maintained between 2.5 ft and 10.5 ft on LI-31 35, DEAER STOR TK WR LVL FEET, to prevent tripping Condensate and Feedwater Booster Pumps.

NRC 2015 Scenario 3 - 35 - NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 6, 7 Page: 36 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 161 1A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior BOP 8 Align the MCB for establishing feed flow: EOP-1 5.0

a. Ensure one Condensate Pump is running.

b. Ensure two Feedwater Booster Pumps are running.

c. Ensure Main FW Control Valves are closed:

FCV-478, A FCV.

FCV-488, B FCV.

FCV-498, C FCV.

d. Place all Main FW Bypass Valve Controllers in MAN and closed:

FCV-3321 ,LOOP A MAIN FW BYP.

FCV-3331,LOOP B MAIN FW BYP.

FCV-3341,LOOP C MAIN FW BYP.

BOOTH OPERATOR:

When called to place local key-operated switches in bypass:

Acknowledge request.

Wait 3 minutes.

Insert TRIGGER 10, TRIGGER 11, and TRIGGER 12.

Wait 1 minute.

Report that all switches are in BYPASS.

BOP e. Locally place the following key switches in BYPASS (CB-448): EOP-1 5.0

XVGO161 1A,B,C (XPN 7114).

1FV03321 ,3331 3341 TRAIN A (XPN 7115).

1FV03321,3331,3341 TRAIN B (XPN 7121).

BOP f. Verify XCP-612 2-1 is NOT lit (RB PRESS HI-2 STM LINE ISOL). EOP-1 5.0 NOTE Step 8.g EOP-1 5.0

SG B or C is preferred, so that a steam supply for the TD EFP will be restored as soon as possible.

Before the Low Steamline Pressure SI signal is blocked, Main Steam Isolation will occur if the Low Steam Pressure rate setpoint is exceeded.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 3 Event # 6,7 Page: 37 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior BOP g. Align the MS Isolation Valves to depressurize only one SG: FOP-i 5.0

1) Verify the MS Isolation Valve, PVM-280iA(B)(C), is open for the SG to be depressurized.

2) Ensure the remaining two MS Isolation Valves, PVM 280 iA(B)(C), are closed.

EVALUATOR NOTE:

. The Alternative Actions are only required if the Low Steam Pressure rate setpoint is exceeded before the Low Steamline Pressure SI signal is blocked as stated in Step Note 8.g.

. P-12 actuates on Tavg < 552°F to close all steam dumps unless the function is bypassed.

P-I 2 coincident with high steamline flow causes main steamline isolation.

BOP ALTERNATIVE ACTION

g. Open the MS Isolation Bypass Valve for one SG:

1) IF RCS Tavg is LESS THAN P-i 2(552°F), THEN place STMLN SI TRAIN A(B) Switches to BLOCK.

2) Depress both MAIN STEAM ISOL VALVES RESET TRAIN A(B).

3) Open the MS Isolation Bypass Valve, PVM-2869A(B)(C), for only the SG to be depressurized.

4) Ensure the remaining two MS Isolation Bypass Valves, PVM-2$69A(B)(C), are closed.

h. Place the following switches in AUTO:

PVG-i6liA(B)(C), A(B)(C) ISOL.

FCV-3321 ,333i ,334i, FW CNTRL BYP VLVS, Train A Switch.

FCV-3321 ,333i ,334i, MAIN FW BYPASS VLVS, Train B Switch.

BOP 9 Reset both SI RESET TRAIN A(B) Switches. EOP-i 5.0 EVALUATOR NOTE: The Main Feedwater Pumps will trip immediately if they are reset due to failure inserted in scenario.

NRC 2015 Scenario 3 NUREG-i021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 3 Event # 6, 7 Page: 38 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior BOP 10 Establish Main Feedwater flow to the unisolated SG: EOP-1 5.0

a. Verify PERMISV 0-9 status light is bright on XCP-61 14 1-3.

b. Open MOV-1-5A(B)(C), TURB DRN VLV.

c. Ensure Feedwater Pump to be started is RESET (MCB or DCS (T ICON)). (NO If any pump resets it will trip immediately)

ALTERNATIVE ACTION 10 GO TO Step 1 1. Observe the NOTE prior to Step 1 1.

NOTE-Step 11 EOP-1 5.0

Step 11 should NOT be performed as long as the Main Feed Pump is supplying sufficient flow to increase SG level.

Before the Low Steamline Pressure SI signal is blocked, Main Steam Isolation will occur if the Low Steam Pressure rate setpoint is exceeded.

BOP 1 1 WHEN the Main Feed Pump will NOT supply adequate flow to the EOP-1 5.0 SG, THEN depressurize one SG to establish Condensate flow:

a. WHEN RCS Tavg is LESS THAN P-12 (552°F), THEN:

Place both STM DUMP INTERLOCK Switches to BYP INTLK.

Place STMLN SI TRAIN A(B) Switches to BLOCK.

NOTE-Step 11.b EOP-1 5.0 SG B or C is preferred, so that a steam supply for the TD EFP will be restored as soon as possible.

BOP b. Open FCV-3321(3331)(3341), LOOP A(B)(C) MAIN FW BYP, to EOP-1 5.0 the SG to be depressurized.

NRC 2015 Scenario 3 NUREG -1021 R9SJ

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # 6, 7 Page: 39 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 161 1A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior BOP c. Dump steam to the Condenser at the maximum rate: EOP-1 5.0

1) Verify PERMISV C-9 status light is bright on XCP-61 14 1-3.

2) Place the STM DUMP MODE SELECT Switch in STM PRESS.

3) Adjust the STM DUMP CNTRL Controller to fully open the Bank 1 Steam Dump Valves.

BOP d. Adjust Condensate flow to restore SG Narrow Range level to EOP-1 5.0 between 26% and 60%.

-Cl)

I 0

EVALUATOR NOTE: The scenario may be terminated after Condensate flow is established to one Steam Generator and SG Level increases.

BOP 12 Reset Containment Isolation: EOP-1 5.0

RESET PHASE A TRAIN A(B) CNTMT ISOL.

RESET PHASE B TRAIN A(B) CNTMT ISOL.

BOP 13 Place both ESF LOADING SEQ A(B) RESETS to: EOP-1 5.0

a. NON-ESF LCKOUTS.

b. AUTO-START BLOCKS.

BOP 14 Establish Instrument Air to the RB: EOP-1 5.0

a. Start one Instrument Air Compressor and place the other in Standby.

b. Open PVA-2659, INST AIR TO RB AIR SERV.

c. Open PVT-2660, AIR SPLY TO RB.

NOTE-Steps 15 and 16 EOP-1 5.0 The specified SG level range (Narrow Range OR Wide Range) must be used in the following Steps.

NRC 2015 Scenario 3 39 - NUREG -1021 R9 51

Appendix D Operator Actions Form ES-D-2 Op lest No: NRC-ILO-13-01 Scenario # 3 Event # 6, 7 Page: 40 of 47 Event

Description:

RCP Trip, ATWS, FW Isol Valve 1611A Fails Closed. (Manual Reactor trip)

Loss of Heat Sink (EFW), Trip of Main FW pumps.

Time Position Applicants Actions or Behavior EVALUATOR NOTE: If this scenario is not terminated the crew may continue Step 15 until EOP-15.O Narrow Range level is GREATER THAN 26%.

BOP 15 Check SG levels: EOP-15.0

a. Verify Narrow Range level is GREATER THAN 26% in at least one SG. (NO)

ALTERNATIVE ACTION

a. IF feed flow to at least one SG is verified by:

Core exit TC temperatures decreasing, OR

Wide Range SG level increasing, THEN maintain flow to restore Narrow Range SG level to GREATER THAN 26%. RETURN TO Step 15.a.

IF flow is NOT verified to any SG, THEN GO TO Step 16. (NA)

CRS b. RETURN TO the Procedure and Step in effect. EOP-1 5.0 EVALUATOR NOTE: If the scenario continues to this point the crew will exit EOP-1 5.0 and implement EOP-1.1, Reactor Trip Recovery.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 3 Event # NA Page: 41 of 47 Event

Description:

SOP-106 lll.F. BORATE OPERATIONS Time I Position Applicants Actions or Behavior NOTE 2.0 SOP-i 06 III.F

1. Energizing additional Pressurizer Heaters will enhance mixing.

2. LCV-1 1 5A, LTDN DIVERT TO HU-TK, will begin to modulate to the HU-TK position at 70%

level on Ll-115, VCT LEVEL %.

RO 2.1 Ensure at least one Reactor Coolant Pump is running. SOP-i 06 III.F RO 2.2 Place RX COOL SYS MU switch to STOP. SOP-i 06 III.F RO 2.3 Place RX COOL SYS MU MODE SELECT switch to BOR. SOP-i06 III.F RO 2.4 Set FIS-1 13, BA TO BLNDR FLOW, batch integrator to the desired SOP-i 06 III.F volume.

RO 2.5 Place RX COOL SYS MU switch to START. SOP-i 06 III.F NOTE 2.6 SOP-i06 III.F Step 2.6 may be omitted when borating less than 10 gallons.

RO 2.6 Place FCV-1 13 A&B, BA FLOW, controller in AUTO. SOP-i 06 III.F NOTE 2.7 SOP-i06 III.F The AUTO setpoint dial for FCV-1 13A&B, BA FLOW, controller may be adjusted slowly to obtain the desired flow rate.

RO 2.7 Verify the desired Boric Acid flow rate on FR-i 13, BA TO BLNDR SOP-i 06 III.F GPM (F-113).

RO 2.8 When the preset volume of boric acid has been reached, perform SOP-i 06 III.F the following:

a. Place FCV-1 13A&B, BA flow controller in MAN.

b. Verify boration stops.

RO 2.9 Place RX COOL SYS MU switch to STOP. SOP-i 06 III.F NOTE 2.10 SOP-i06 III.F

a. If plant conditions require repeated borations, Step 2.10 may be omitted.

b. The volume in the piping between the blender and the VCT outlet is approximately 3.8 gallons.

NRC 2015 Scenario 3 41 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario # 3 Event # NA Page: 42 of 47 Event

Description:

SOP-106 lll.F. BORATE OPERATIONS Time Position Applicants Actions or Behavior RD 2.10 Alternate Dilute 4 to 6 gallons of Reactor Makeup Water to flush SOP-106 III.F the line downstream of the blender by performing the following:

a. Place RX COOL SYS MU MODE SELECT switch to ALT DIL.

b. Adjust FCV-168, TOTAL MU FLOW SET PT, to desired flow rate.

c. Set FIS-1 68, TOTAL MU FLOW, batch integrator to desired volume.

d. Place RX COOL SYS MU switch to START.

e. Verify desired flow rate on FR-113, TOTAL MU GPM (F-168).

f. Verify alternate dilution stops when preset volume is reached on FIS-168, TOTAL MU FLOW, batch integrator.

g. Place RX COOL SYS MU switch to STOP.

RO 2.11 Place RX COOL SYS MU MODE SELECT switch to AUTO. SOP-i 06 III.F RO 2.12 Adjust FCV-168, TOTAL MU FLOW SET PT, to 7.5 (120 gpm). SOP-i 06 III.F RD 2.13 In MAN, adjust FCV-1 13 A&B, BA FLOW OUTPUT, to the required SOP-i 06 III.F position which will ensure proper Boric Acid addition for subsequent Automatic Makeup operations.

RO 2.14 Adjust FCV-1 13A&B, BA FLOW SET PT, to the desired position to SOP-i 06 III.F ensure proper boric acid addition for subsequent Automatic Makeup operations.

RO 2.15 Place RX COOL SYS MU switch to START. SOP-i 06 III.F RD 2.16 Perform the following: SOP-i 06 III.F

a. StartXPP-13A(B), BAXFER PPA(B), forthe in-service Boric Acid Tank.

b. If necessary, start XPP-13A(B), BA XFER PP A(B), for the Boric Acid Tank on recirculation.

END OF SECTION SOP-i 06 III.F NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 3 Event # NA Page: 43 of 47 Event

Description:

SOP-106 IV.D. BORATING THE RCS USING THE EMERGENCY BORATE VALVE Time I Position Applicants Actions or Behavior CAUTION 2.0 SOP-1061V.D AOP-106.1, Emergency Boration, should be used for any of the following:

a. Failure of the Reactor Makeup Control System such that bypass is necessary to accomplish boration.

b. Uncontrolled cooldown with Safety Injection NOT required.

c. ANY questionable Shutdown Margin.

U. Control Rod Insertion Limit is exceeded.

2.1 Open MVT-8104, EMERG BORATE. SOP-i 06 IV.D 2.2 Ensure XPP-i 3A(B), BA XFER PP A(B), is running. SOP-i 06 V.0 2.3 Verify greater than 30 gpm flow on Fl-i 10, EMERG BORATE SOP-i 06 IV.D FLOW GPM.

2.4 When boration is no longer required, perform the following: SOP-i 06 IV.D

a. Close MVT-8i04, EMERG BORATE.

b. Verify no flow on Fl-i 10, EMERG BORATE FLOW GPM.

END OF SECTION SOP-i 06 IV.D NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-O1 Scenario# 3 Event # NA Page: 44 of 47 Event

Description:

SOP-214 hID. Turbine Load Reduction/Shutdown Time I Position I Applicants Actions or Behavior SOP 2.1 Ensure the Control/Load screen is selected. SOP-214 NOTE 2.2 SOP-214 The turbine will come off the limiter and turbine load will lower once Load Set Reference is less than Load Limit Reference.

Acknowledging dialog boxes is skill of the Craft.

BOP 2.2 To lower Turbine Load using Load Set, perform the following: SOP-214

a. If directed by Operations Management, disable the Turbine Vibration Trips per Section III.

b. Select (or enter) the desired Rate 3/4/mm on Load Set.

c. Select Load on Load Set (a dialog box will open).

d. Enter the desired load and confirm.

e. Verify proper system response.

f. If during a load reduction, it is desired to stop the load reduction, perform the following:

1) Select Hold on Load Set.

2) Select the desired Rate 3/4/mm to resume load reduction.

3) If desired, place LOAD LIMIT in service per Section III.

BOP 2.3 For rapid load shedding of 50 MWe, on an HMI keypad select Ctrl SOP-214

+ Alt + S.

EVALUATOR NOTE: The remainder of this section deals with actions after Turbine Load is below 15%.

NRC 2015 Scenario 3 NUREG -1021 R9 Si

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario# 3 Event # NA Page: 45 of 47 Event

Description:

EOP-1 .0, Attachment 3 Time Position Applicants Actions or Behavior BOP 1 Ensure EFW Pumps are running: EOP-1 .0 Attachment 3

a. Ensure both MD EFW Pumps are running.

b. Verify the TD EFW Pump is running if necessary to maintain SG levels.

BOP 2 Ensure the following EFW valves are open: Attachment 3 FCV-3531(3541)(3551), MD EFP TO SG A(B)(C).

FCV-3536(3546)(3556), TD EFP TO SG A(B)(C).

MVG-2802A(B), MS LOOP B(C) TO TD EFP.

BOP 3 Verify total EFW flow is GREATER THAN 450 gpm. Attachment 3 BOP 4 Ensure FW Isolation: Attachment 3

a. Ensure the following are closed:

FW Flow Control, FCV-478(488)(498).

FW Isolation, PVG-1611A(B)(C).

FW Flow Control Bypass, FCV-3321 (3331 )(3341).

SG Blowdown, PVG-503A(B)(C).

SG Sample, SVX-9398A(B)(C).

b. Ensure all Main FW Pumps are tripped.

BOP 5 Ensure SI Pumps are running: Attachment 3 Two Charging Pumps are running.

Both RHR Pumps are running.

BOP 6 Ensure two RBCU Fans are running in slow speed (one per train). Attachment 3 BOP 7 Verify Service Water to the RBCUs: Attachment 3

a. Ensure two Service Water Pumps are running.

b. Verify both Service Water Booster Pumps A(B) are running.

c. Verify GREATER THAN 2000 gpm flow for each train on:

Fl-4466, SWBP A DISCH FLOW GPM.

Fl-4496, SWBP B DISCH FLOW GPM.

BOP 8 Verify two CCW Pumps are running. Attachment 3 NRC 2015 Scenario 3 45 - NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 OpTestNo: NRC-ILO-13-O1 Scenario# 3 Event # NA Page: 46 of 47 Event

Description:

EOP-1 .0, Attachment 3 Time Position Applicants Actions or Behavior BOP 9 Ensure two Chilled Water Pumps and Chillers are running. Attachment 3 BOP 10 Verify both trains of Control Room Ventilation are running in Attachment 3 Emergency Mode.

BOP 1 1 Check if Main Steam lines should be isolated: Attachment 3

a. Check if any of the following conditions are met:

RB pressure GREATER THAN 6.35 psig.

OR Steamline pressure LESS THAN 675 psig.

OR Steamline flow GREATER THAN 1.6 MPPH AND Tavg LESS THAN 552°F.

b. Ensure all the following are closed:

MS Isolation Valves, PVM-2801A(B)(C).

MS Isolation Bypass Valves, PVM-2869A(B)(C).

BOP 12 Ensure Excess Letdown Isolation Valves are closed: Attachment 3 PVT-8153, XS LTDN ISOL.

PVT-8154, XS LTDN ISOL.

BOP 13 Verify ESF monitor lights indicate Phase A AND Containment Attachment 3 Ventilation Isolation on XCP-6103, 6104, and 6106.

REFER TO ATTACHMENT 4, CONTAINMENT ISOLATION VALVE MCB STATUS LIGHT LOCATIONS, as needed.

BOP 14 Verify proper SI alignment: Attachment 3

a. Verify SI valve alignment by verifying SAFETY INJECTION/PHASE A ISOL monitor lights are bright on XCP-61 04.

b. Verify all SAFETY INJECTION monitor lights are dim on XCP-61 06.

c. Verify SI flow on FI-943, CHG LOOP B CLD/HOT LG FLOW GPM.

d. Check if RCS pressure is LESS THAN 325 psig.

NRC 2015 Scenario 3 NUREG -1021 R9S1

Appendix D Operator Actions Form ES-D-2 Op Test No: NRC-ILO-13-01 Scenario # 3 Event NA Page: 47 of 47 Event

Description:

EOP-1 .0, Attachment 3 Time Position I Applicants Actions or Behavior BOP Report completion of Attachment 3.

EVALUATOR NOTE: ATTACHMENT 3 is complete.

NRC 2015 Scenario 3 NUREG -1021 R9S1

OAP-1 00.6 ATTACHMENT VIII PAGE 1 OF 1 A SCANA COMPANY REVISION 4 TURNOVER NOTES (read at the start of the scenario)

Turnover Notes Mode 1 //100% Power II Work Week Bill EOOS: Green II Grid Risk: Green II FEP Risk: Green II Switchyard thermography is in progress.

Alternate Seal Injection is QOS for planned maintenance. It has been ODS for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and is expected back in 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months . A fire watch has been established lAW SOP-i 02.

Xenon concentration is at equilibrium.

Midnight RCS Boron Concentration is 1005 ppm.

CAP-i 00.6 ATTACHMENT VIII PAGE 1 OF 2 A SCANA COMPANY REVISION 4 CONTROL ROOM SUPERVISOR RELIEF CHECKLIST TEITlME: today RELIEF SECTION Turnover Notes Mode 1//100% Power//Work Week Bill EDOS: Green II Grid Risk: Green// FEP Risk: Green 1/Switchyard thermography is in progress.

Alternate Seal Injection is DOS for planned maintenance. It has been DOS for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and is expected back in 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months . A fire watch has been established lAW SOP-i 02.

Xenon concentration is at equilibrium.

Midnight RCS Boron Concentration is 1005 ppm.

Offgoing Control Room Supervisor Operations in progress (GOPs, SOPs, load chances. etc.:

Opeat1nScheduled for oncoming shifts:

nt safeguard systems in degraded status:

Initials In the Control Room, all books are replaced, the desk and console tops are clear, and all trash is properly disposed of.

Station Log completed.

OAP-1 00.6 ATTACHMENT VIII PAGE 2 OF 2 A SCANA COMPANY REVISION 4 Oncoming Control Room Supervisor Initials Oncoming watch has reviewed the VCS Switchgear mailbox for switchinq orders.

Plant Status (to be completed prior to turnover):

Plant ESF System Status:

Component Cooling System Service water System Reactor Building Cooling System Reactor Building Spray System Accumulator Tanks RHR System Charging/Safety Injection System Emergency Feedwater System Accumulator Tanks Diesel Generator Chilled Water System Control Room Ventilation System Position indications, power availability, and annunciator alarms are normal for present plant conditions.

Plant Parameters Limit Reactor Power 0-100%

RCS Tavg 589.2°F per loop RCS Pressure <2385 psig RCS Flow >100% per loop RCS Subcooling Normal 1 parameters within allowable limits for plant conditions. If not, what actions are being taken to correct conditions: [

I Review of Logs:

Station Log Removal and Restoration Log Tagout Log Special Orders Shift Turnover (to be completed during turnover):

Briefing on plant conditions by offgoing Control Room Supervisor.

Review of SPDS and BISI displays.

Discussion of Protected Equipment.

Identification of in-progress procedures including their present status and locations.

To the best of my knowledge, I am fully qualified to assume this watch taking into consideration fitness for C02+

duty, requalification status, and minimum watchstanding qualification.

Oncoming Control Room Supervisor Shift relief completed: Offgoing Control Room Supervisor C-R Stperv-or Shift Supervisor review

CAP-i 00.6 ATTACHMENT IX PAGE 1 OF 1 A SCANA COMPANY REVISION 4 n DATE/TIME: today REACTOR OPERATOR RELIEF CHECKLIST LOG SECTION Date Entry RELIEF SECTION Turnover Notes Mode 1//100% Power//Work Week Bill EOOS: Green II Grid Risk: Green II FEP Risk: Green II Switchyard thermography is in progress.

Alternate Seal Injection is 005 for planned maintenance. It has been OOS for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and is expected back in 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months . A fire watch has been established lAW SOP-i 02.

Xenon concentration is at equilibrium.

Midnight RCS Boron Concentration is 1005 ppm.

Offgoing Reactor Operator Initials Main Control Board (Reactor Operator portion) properly aligned for the applicable mode.

I j-lousekeeping is satisfactory in the Reactor Operator area of responsibility. RQ Discussion of Protected Equipment. RO Oncoming Reactor Operator Initials Review of HVAC Panel.

Review of Station Log.

Review of Removal & Restoration Log.

Review of Main Control Board Panels.

System Alignment A B C Train aligned to Reasons for any inoperable equipment Service Water Pumps X X A Component Cooling Pumps X A Charging Pumps X A HVAC Chillers X X A Reactor Building Spray Pumps RHR Pumps TDEFP Emergency Feedwater Pumps Inoperable Radiation Monitors To the best of my knowledge, I am fully qualified to assume this watch taking into consideration fitness C02*

for duty, regualification status, and minimum watchstanding qualification.

) Oncoming Reactor Operator Shift relief completed: Offgoing Reactor Operator Reavr Op.e-ro/Dr Shift Supervisor review

OAP-1 00.6 ATTACHMENT X PAGE 1 OF 1 A SCANA COMPANY REVISION 4 BALANCE OF PLANT RELIEF CHECKLIST DATE/TIME: today Date Entry RELIEF SECTION Turnover Notes Mode 1 //100% Power//Work Week Bill EOOS: Green II Grid Risk: Green II FEP Risk: Green II Switchyard thermography is in progress.

Alternate Seal Injection is OOS for planned maintenance. It has been OOS for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and is expected back in 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months . A fire watch has been established lAW SOP-i 02.

Xenon concentration is at equilibrium.

Midnight RCS Boron Concentration is 1005 ppm.

I Offgoing Reactor Operator Initials Main Control Board (Reactor Operator portion) properly aligned for the applicable mode. 60P 1J-Iousekeeping is satisfactory in the Reactor Operator area of responsibility. 130P i of Protected Equipment. --

Oncoming Reactor Operator Initials Review of Main Control Room Panels.

Review of Station Log.

Review of Removal & Restoration Log.

Test annunciator lights (with Offgoing operator concurrence).

To the best of my knowledge, I am fully qualified to assume this watch taking into consideration fitness C02*

for duty, regualification status, and minimum watchstanding qualification.

Oncoming Balance of Plant Shift relief completed: Offgoing Balance of Plant 6o-L-c- ofr PLtu1-Shift Supervisor review

OAP-1 00.6 ATTACHMENT IA PAGE 1 OF 2 REVISION 4 REACTIVITY CONTROL PARAMETERS NOTE This information should be recalculated every Sunday Dayshift (when the plant is in Mode 1) to be available for Reactor Engineering review Monday morning or following work day.

RCS Boron Concentration (CRCS) 1-005 ppm Burnup 1-0000 MWD/MTU (Check BAT in Service)

CBABAT 73 ppm CB B BAT 71-00 ppm Moderator Temperature Coefficient(MTC) (Fig. 11-3.7, HFP) 1-7.87% pcm/°F Differential Boron Worth (DBW) (Fig. 11-7.2, HFP) pcm/ppm Gallons of Boric Acid or Reactor Makeup Water required to change RCS average temperature by one (1) degree:

MTC/DBW = 7.872 / = (zB) 2.57 ppm Boron Change/°F gal. Acid/°F = 20.4 From Fig. 111-2: gal. Acid/°F = 49640 in (C8))

gal. RMW!°F = 1-27.1-4 From Fig. 111-3: gal. RMW/°F = 49640 in Power Defect (PD) for 10% power change (100% to 90%) (Fig. 11-2):

1-7(6 PD @ 100% RTP 1-52.8 PD @ 90% RTP =1-73.2 A Power Defect, pcm Gallons of Boric Acid jjyto reduce reactor power from 100% to 90%:

A Power DefectIDBW = 1-73.2 / = 2-a- ppm Boron (Fig. 111-2) 2-03.3 gal. Boric Acid!10% RTP Final rod height using rods jjjy to reduce reactor power from 100% to 90%:

(Assume ARO)

A Power Defect Integrated Rod Worth (IRW) = 1-73.2 pcm (Fig. 11-10) 185 final rod height Bank D

CAP-i 00.6 ATTACHMENT IA PAGE 2 OF 2 REVISION 4 REACTIVITY CONTROL PARAMETERS NOTE For a 10% reduction in load, 1/2 of the calculated boric acid should be used and 1/2 the calculated Control Rod motion.

For a 100% to 90% load reduction:

Use 1-02 gallons boric acid (Y2 the gallons calculated above), and expect the rods to be at approximately 200 steps on bank D (Fig. 11-10 series, 1/2 the IRW, NOT the steps).

1/2 To change TAVG by 1°F: 20.q gallons Boric Acidl°F 1-24.1- gallons Reactor Makeup Waterl°F For a 100% to 90% load reduction: Use 1-01-.7 gallons boric acid and expect steps on bank D NOTE:

This calculation is to provide a second check to the batch integrator setting to establish continuity between the setting and actual make-up results.

FCV 113 A&B, pot setting for current RCS boron concentration 4.81-Expected Boric Acid flowrate for VCT makeup Expected Boric Acid total gallons on an Auto Makeup based on current BAT in service:

Current RCS CB 1-1-22 x 270 gallons* 42.7 CBfor BAT in service 71-00 Normal Auto Makeup is 267 to 275 gallons Calculation and Auto Makeup pot settings by ReDr Oo/rtr I- todac-,

Signature I Data Calculation and Auto Makeup pot settings verified by Re-ac-#vr OrJ--o-tar 2 todaq Signature / Date Reactor Engineering Review RUC-#Or Evi.ALe% Date toda c-i

CAP-I 00.6 ATTACHMENT lB PAGE 1 OF 2 REVISION 4 REACTIVITY MANAGEMENT BRIEF MODES 1 -3 NOTE PART 1 REACTIVITY MANAGEMENT TURNOVER should be read at Shift Turnover Meeting.

PART 2 REACTOR STATUS should be discussed between the NROATC, SOP, and CR5.

PART 1 REACTIVITY MANAGEMENT TURNOVER:

Date of last Automatic or Manual Make-Up: today

Is Auto Makeup expected this shift (circle)? YES

Expected Boric Acid total gallons on a normal Auto Makeup based on current BAT in service: 42.7 gallons

FCV 113 A&B, pot setting for current RCS boron concentration:

Expected Boric Acid flowrate for VCT makeup:

. Total gallons Diluted 22. Borated 42.7 (Last Shift)

Last evolution (circle one): Borate / Dilute

Expected Borations, Dilutions, or Blended changes to the RCS:____________

List Reactivity Concerns in progress or planned and action(s) necessary (i.e. Steam or Feed Flow transmitter in test, Steam Generator Slowdown out of service, Calorimetric inputs in service, etc.).

A Steavv evi.erator Feed F(ow Spikes

CAP-i 00.6 ATTACHMENT lB PAGE 2 OF 2 REVISION 4 REACTIVITY MANAGEMENT BRIEF MODES 1 3 (Contd)

PART 2 REACTOR STATUS: (circle one below)

Delta Ion Target(+/-2%)? NO Not in Mode 1 If NO is circled, identify plan to re-establish target band:

Xenon Trend: Building In Burning Out

Demineralizers:

Mixed Bed in service: A PRCO1 Y Standby Demineralizer: ce Borated Empty PRCO1 Cation Bed: Date last in service I PAoLftth ago Boron Concentration when in service

ATTACHMENT IA reviewed and current: NO

Midnight Boron Concentration and Date when CHG/Sl pump was secured:

CBA Date CB B 1-01-2 Date 3 dajs ago CB C 1-0%6 Date 1- week ago

CAP-i 02.1 ATTACHMENT II PAGE 1 OF i REVISION 7 SCHEDULED WORK APPROVALIDENIAL Scheduled Work/Activity Date todaci Description of Work/Activity to be performed:

Sciedc1ed vaifttevtarce or. Atterrate Seat 1v.jectior. pwvp Thi oderate Risk levated Risk, High Risk, or Cross Train activity is approved for work provi e required plant conditions are available on the scheduled due date.

OR This specific activity has been reviewed for EOOS Risk Reassessment. Set EOOS Environmental Variance Set Risk at Times The following items were considered for making this approval:

ShIft SlApervisor Operations Supervisor (Moderate Risk or Cross Train)

In the absence of the Operations Supervisor:

Operations Scheduling, Shift Supervisor GMNPOIMDS (Elevated Risk)

PSRC (High Risk)

II. This work activity/package cannot be performed on the scheduled date due to the following reason(s):

SRO (WCC or On Shift)

Operations Scheduling Supervisor Ill. Recommended re-schedule date or plant conditions:

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPSF-141A (RI) 2015 NRC Sim a RO:

Continuous Rod Withdrawal CANDIDATE:

EXAMINER:

11OlIdtil. April 13, 2015 Page! of 16

TASK:

000-006-05-0 1 RESPOND TO CONTINUOUS ROD MOTION PER AOP-403.3/SOP-403 TASK STANDARD:

The reactor is tripped per AOP-403.3, CONTINUOUS CONTROL ROD MOTION, to terminate the transient prior to rods withdrawing to the point of adding heat (1 OeO on Intermediate Range) and immediate actions of EOP-1.0, REACTOR TRIP/SAFETY INJECTION ACTUATION, are completed.

TERMIiVA TING CUE: Immediate actions of EOP-1 .0, REACTOR TRIP/SAFETY INJECTION ACTUATION are complete.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOL SIMULATOR PERFORM

REFERENCES:

Curve Book Station Curve Book REP-i 09.001 Calculation of Estimated Critical Conditions REP-i 09. 002 Inverse Count Rate Ratio Plot GOP Appendix A Generic Operating Precautions EOP-1 .0 E-0, REACTOR TRIP/SAFETY INJECTION ACTUATION AOP-403.3 CONTINUOUS CONTROL ROD MOTION GOP-3 REACTOR STARTUP FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2)

INDEX NO. K/A NO. RO SRO 0000012413 2.4.13 Knowledge of crew roles and responsibilities during EOP usage. 4.0 4.6 00000 lAi 05 AA1 .05 Reactor trip switches 4.3 4.2 TOOLS: GOP Appendix A, Generic Operating Precautions JPM a Handout 1 GOP-3, Reactor Startup from Hot Standby to Startup (MODE 3 TO MODE 2), marked up through step 3.12.k JPM a Handout 2; REP-i 09.002, Enclosure 9.2, Recommended Rod Positions for ICRR marked through Bank C at 129 steps.

AOP-403.3, Continuous Control Rod Motion EOP-i .0, E-0, Reactor Trip/Safety Injection Actuation Copy of REP-i 90.002, Inverse Count Rate Ratio Plot EVALUATION TIME 30 TIME LRITICAL No 10CfR55: 45.a.3 TtME START: TIME FINISH PERFORMANCE TIME:

PERFORMANCE RATING: SAT: LJNSAT:

C4NDIDA TE:

/

EXAMINER: /

SIGNATURE DATE Illoiidav, /i)rit 13, 2015 Page2 of 16

INS UCTIONS TO OPERA fOR READ To OPERA Tot?:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL CONDITiON: A reactor start up is in progress after a short mini-outage.

GOP-3, REACTOR STARTUP FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2), has been completed through step 3.12k.

The Rod Insertion Limit at 0% power is 118 steps on Control Bank C.

The CRB INSERT LMT LO-LO (XCP-621 1-1) annunciator is NOT clear.

Control bank C is at 129 steps with Control Bank D at 1 step.

The estimated critical position is 100 steps on bank D.

The Minimum rod height for criticality (-500 pcm equivalent) is 38 steps on Bank D.

The Maximum rod height for criticality (+500 pcm equivalent) is 185 steps on Bank D.

The source range counts have undergone one doubling at this point in the start up.

INITIATING CUES: A surrogate operator will fill the role of CRS for the purposes of this JPM.

Complete the Reactor Start up and increase reactor power to 1 0-3%per GOP-3 starting at Step 3.12.1.

HAND JPM BRIEFING SHEET TO OPERA TOR A T THIS TIME!

Mondat. April 13, 2015 Page 3 q 16

cTFp.c CRITICAL: No SEQUENCED: Yes SAT UNSAT STEP: 1 Procedure Caution: Reactor startup should be stopped and l&C notified if the CRB INSERT LMT LO LO (XCP-621 1-1) annunciator fails to clear between 118 steps and 134 steps on Bank C.

Step 3.12.1; Verify CRB INSERT LMT LO-LO (XCP-621 1-1) annunciator clears between 118 steps and 134 steps on Bank C..

Steps_________________

STEP STANDARD:

Verifies LO-LO insertion Limit Annunciator clears (XCP-621 1-1)

CUES:

Evaluator note: Provide Examinee with copies of JPM a Handout 1 (GOP-3.0 markup) and

]PM a Handout 2 (REP-i 09.002 Enclosure 9.2 mark up) following initial conditions brief.

Surrogate cue: Once Examinee is ready (on evaluator prompt) provide the following direction Pull to 6 steps on Control Bank D or until the LO-LO Insertion Limit Alarm Cleats whichever occurs first Evaluator note: Expect alarm to clear at 3 steps withdrawn on Control Bank D.

Surrogate cue: Once Examinee stops and verifies LO-LO insertion limit annunciator is clear, provide the following direction Pull to 10 steps on Control Bank D.

[COMMENTS:

1Io,idav, April 13, 2015 PCIgL 4 0/ 16

CRITICAL: No SEOUENED: Yes SAT UNSA T STEP: I 2 Procedure Caution: 12 steps should NOT be exceeded until all Rod Bottom lights are off. If all Control Bank D Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

Step 3.12.m; At ten steps on Control Bank D, stop and verify Bank D RB lights clear.

EP STAIVDARD:

Stops at 10 steps withdrawn on Control Bank D.

CUES:

Surrogate cue: After Examinee stops rod pull give the following direction Inform me when counts are stable Surrogate cue: After Examinee announces counts are stable state ICRR is 0.4 and criticality is predicted at 120 steps withdrawn on Control Bank D. Then give the following direction Pull Control Bank D to 16 steps withdrawn or until LO Insertion Limit annunciator clears whichever comes first.

COMMENTS:

4londt,, April 13, 2015 Page 5 of Jo

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 3 Step 3.12.n; Recommence withdrawing rods while observing that the groups sequence properly.

STEP STANDARD:

Continues to pull rods and stops at 16 steps withdrawn on Control Bank D or when the LO Insertion Limit Annunciator cleats CUES:

Surrogate cue: Once Examinee stops and verifies LO insertion limit annunciator is clear, provide the following direction Pull to 53 steps on Control Bank D.

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT [] UNSA T

[STEP 4 Recommence withdrawing rods while observing that the groups sequence properly.

STEP STANDARD:

Continues rod withdrawal.

CUES:

Evaluator note: When rods are >51 steps on Bank D the continuous rod motion malfunction inserts.

When examinee stops pull at 53 steps continuous rod motion occurs. This is the point that the JPM becomes alternate path.

COilIilIENT$:

tiioudti, April 13, 2015 Page 6 of 16

CRITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 5 Enters AOP-403.3, CONTINUOUS CONTROL ROD MOTION.

STEP STANDARD:

Enters AOP-403.3, CONTINUOUS CONTROL ROD MOTION.

CUES:

Evaluator note: The examinee is not expected to pull out the procedure, but may perform the actions of this procedure from memory and trip the unit.

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 6 Step 1; Verify rod motion is NOT required:

Tavg is within 1.5 °F of Tref.

AND No load rejection has occurred (C7A OR C7B).

I STEP STANDARD:

Notes Tavg and Tref matched and Status lights for C7A and C7B are dim: rod motion is not required.

fCUES:

Evaluator note: This is an immediate operator action from AOP-403.3 and is expected to be performed from memory.

LCOMMENTS:

ilIo,,dav, April 13, 2015 Pcige 7o116

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 7 Step 2; Place ROD CNTRL BANK SEL Switch in MAN.

STEP STANDARD:

Rods are already in manual no action required.

CUES:

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT EJ LJJVS4T STEP: 8 Step 3; Verify rod motion is stopped.

STEP STANDARD:

Notes rods out light lit, step counters clicking and DRPI showing Bank D withdrawing, concludes that rod motion has NOT stopped.

CUES:

Evaluator note: This is an immediate operator action from AOP-403.3 and is expected to be performed from memory.

COMMENTS:

ioist1ar, April 13, 2015 Page# of 16

CRITICAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 9 Step 3 Alternative Action: Perform the following:

a) Trip the Reactor.

b) GO TO EOP-1.O. REACTOR TRIP/SAFETY INJECTION ACTUATION.

STEP STANDARD:

Turns one of the two reactor trip switches to trip prior to rods withdrawing to the Point of Adding Heat (1 OeO on Intermediate Range instrumentation).

CUES:

Evaluator note: This is an immediate operator action from the Alternative Action of AOP-403.3 step

3. The Point of Adding Heat was noted at approximately 170 steps withdrawn on Control Bank D during development.

COMMENTS:

1io,,da, April 13, 2015 Page 9 of 16

CRITICAL: No SEQ UENCED: Yes SAT UNSA T STEP: 10 I Procedure Note:

-Steps 1 through 5 are Immediate Operator Actions.

-The EOP REFERENCE PAGE should be monitored throughout the use of this procedure.

- Conditions for implementing Emergency Plan Procedures should be evaluated using EPP-001, ACTIVATION AND IMPLEMENTATION OF EMERGENCY PLAN.

Step 1. Verify Reactor Trip:

- Trip the Reactor using either Reactor Trip Switch.

- Verify all Reactor Trip and Bypass Breakers are open.

- Verify all Rod Bottom Lights are lit.

- Verify Reactor Power level is decreasing.

STEP STANDARD:

Verifies:

-Reactor Trip and Bypass Breakers indicate Green light ON Red light OFF.

-Rod Bottom Lights are lit.

-Reactor Power level is decreasing.

CUES:

Evaluator note: This is an immediate operator action from EOP-1 .0 and is expected to be performed from memory.

Evaluator cue: Direct Examinee to perform all Immediate actions from EOP-1 .0 (both RO and BOP actions).

COMMENTS:

41t?nday, April 13, 2015 Page IOuifI6

(RITIc4L: No SEQUENCED: Yes SAT UNSAT STEP: 11 Step 2; Verify Turbine/Generator Trip:

a. Verify all Turbine STM STOP VLVs are closed.

b. Ensure Generator Trip (after 30 second delay):

1) Ensure the GEN BKR is open.

2) Ensure the GEN FIELD BKR is open.

3) Ensure the EXC FIELD CNTRL is tripped.

STEP STANDARD:

Verifies:

a. All Turbine STM STOP VLV indicate closed, status light for each valve is bright.

b. GEN BKR, GEN FIELD BKR, and EXC FIELD CNTRL indicate Green light ON and Red light OFF.

CUES:

Evaluator note: This is an immediate operator action from EOP-1 .0 and is expected to be performed from memory.

LC0MJWENTS:

lIo,,dai, .4pri! 13, 2015 Page 11 ofl6

CRITICAL: No SEOUENCED: Yes SAT UNSA T STEP: 12 Step 3; Verify both ESF buses are energized.

STEP STANDARD:

Verifies potential lights on 1 DA and 1DB are ON for all three phases on both buses.

CUES:

Evaluator note: This is an immediate operator action from EOP-1 .0 and is expected to be performed from memory.

COMMENTS:

1o,idav, April 13, 2015 Page 12 of 16

CRITICAL: No SEQUENCED: Yes SAT UNSAT STEP: 13 Step 4; Check if SI is actuated:

a. Check if either:

SI ACT status light is brighton XCP-6107 1-1 OR Any red first-out SI annunciator is lit on XCP-626 top row.

Alternative Action go to Step 5.

STEP STANDARD:

Verifies: status light dim and no SI first out lit, goes to Step 5.

[CUES:

Evaluator note: This is an immediate operator action from EOP-1 .0 and is expected to be performed from memory.

[COMMENTS:

itoiit!cii, April 13, 2015 Page 13 of 16

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 14 Step 5; Check if SI is required:

a. Check if any of the following conditions exist:

PZR pressure LESS THAN 1850 psig.

OR RB pressure GREATER THAN 3.6 psig.

OR Steamline pressure LESS THAN 675 psig.

OR Steamline differential pressure GREATER THAN 97 psid.

Alternative action GO TO EOP-1.1, ES-0.1, REACTOR TRIP RECOVERY, Step 1.

STEP STANDARD:

Verifies:

PZR pressure is greater than 1850 psig RB pressure less than 3.6 psig All steam line pressures greater than 675 psig All steam line pressures within 97 psi.

Transitions to EOP-1.1, ES-0.1, REACTOR TRIP RECOVERY.

CUES:

Evaluator note: This is an immediate operator action from EOP-1 .0 and is expected to be performed from memory.

RMMENTS:

Examiner ends JPM at this point.

1Io,,tIai, April 13, 2075 Page 14 t.f 16

JPM SETUP SHEET JPMNO: NJPSF-141A (Ri)

DESCRIPTION: 2015 NRC Sim a RO: Continuous Rod Withdrawal ICSET: 310 INSTRUCTIONS:

If IC 310 is designated for this JPM reset to IC 310.

1. RUN

2. Set up Audio Count Rate per GOP-3, step 3.4.e

3. Turn on Digital Reactivity Function of the IPCS per REP-I 09.002 step 7.6. set up display at ROATC SIPCS station using ZZREAC or RX STRT off the ZZ Menu.

4. Place HIGH FLUX AT SHUTDOWN in block per GOP-3, step 3.11 .b.

5. Set SIPCS to MODE 2 per GOP-3, step 3.11 .f

6. Set NR-45 to HI speed.

7. RUN until the Heat up or cooldown history clears on SIPCS. This may take 10-15 minutes on the initial reset.

8. FREEZE

9. When Examinee is ready (on Evaluator cue) go to RUN.

If IC 310 is not designated for this JPM then initial conditions may be established by resetting to IC 15 and following the below directions:

1. Go to RUN and withdraw Control Rods to 129 steps on Control bank C (1 step on Control Bank D).

2. Insert: MAL-PCSOO9AB REACTOR TRIP BREAKER A FAILURE (FAIL TO OPEN)

Delay = 0, Fail To = AUTO (UV)

2. Insert MAL-PCSOO9BB REACTOR TRIP BREAKER B FAILURE (FAIL TO OPEN)

Delay = 0, Fail To = AUTO (UV)

4. Set Event #1 as Mcrfpa(1 1) >51

5. Insert: MAL-CRFOO6B UNCONTROLLED MANUAL ROD MOTION, Delay=0, set to event #1

6. Set up Audio Count Rate per GOP-3, step 3.4.e

7. Place HIGH FLUX AT SHUTDOWN in block per GOP-3, step 3.11 .b zlio,,tlt,p, April 13, 2015 Page 15 of 16

8. Set SIPCS to MODE 2 per GOP-3, step 3.11 .f

9. Turn on Digital Reactivity Function of the IPCS per REP-i 09.002 step 7.6.set up display at ROATC SIPCS station using ZZREAC or RX STRT off the ZZ Menu.

10. Set NR-45 to HI speed.

11. RUN until the Heat up or cooldown history clears on SIPCS. This may take 10-i 5 minutes on the initial reset.

12. FREEZE

13. When examinee is ready: RUN CoMMENTS:

Provide a surrogate in the role of CRS to simulate performing REP-i 09.002, Inverse Count Rate Ratio Plot and to provide cues for start up process.

During development, the Point of Adding Heat (1 OeO on Intermediate Range ) was observed at approximately 170 steps withdrawn on Control Bank D when the continuous rod withdrawal was allowed to proceed with auto trips failed malfunction in place. When the continuous rod motion malfunction was run without the auto trips blocked it took 2 minutes to reach the Source Range High Flux trip setpoint (iOe5 CPS) and Control Bank D was at 147 steps withdrawn.

11o,,dt,j, April 13, 2015 Page 16 of 16

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERA TIONS:

IIVITIA L CONDITION: A reactor start up is in progress after a short mini-outage.

GOP-3, REACTOR STARTUP FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2), has been completed through step 3.12k.

The Rod Insertion Limit at 0% power is 118 steps on Control Bank C. The CRB INSERT LMT LO-LO (XCP-621 1-1) annunciator is NOT cleat.

Control bank C is at 129 steps with Control Bank D at I step.

The estimated critical position is 100 steps on bank D.

The Minimum rod height for criticality (-500 pcm equivalent) is 38 steps on Bank D.

The Maximum rod height for criticality (+500 pcm equivalent) is 185 steps on Bank D.

The source range counts have undergone one doubling at this point in the start up.

INITIATING CUES: A surrogate operator will fill the role of CRS for the purposes of this JPM.

Complete the Reactor Start up and increase reactor power to 10-3% per GOP-3 starting at Step 3.12.1.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

JPM a Handout I SOUTH CAROLINA ELECTRIC & GAS COMPANY VIRGIL C. SUMMER NUCLEAR STATION NUCLEAR OPERATIONS NUCLEAR OPERATIONS t COPY NO._______

GENERAL OPERATING PROCEDURE GOP-3 REACTOR STARTUP FROM HOT STANDBY TO STARTUP (MODE 3 TO MODE 2)

REVISION 13 SAFETY RELATED RECORD O CHANGES CHANGE TYPE APPROVAL CANCELLATION CHANGE TYPE APPROVAL CANCELLATION LETTER CHANGE DATE DATE LETTER CHANGE DATE DATE A P 01/25/10 B P 06/19/12 C P 07/02/12 D P 04/26/14 E P 06/30/14 F P 11/14/14 CONTINUOUS USE Continuous Use of Procedure Required.

Read Each Step Prior to Performing.

This page Intentionally left blank.

For printing 2 sided sheets.

GOP-3 PAGE i REVISION 13 TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE/SCOPE 1 2.0 INITIAL CONDITIONS 2 3.0 INSTRUCTIONS 4

4.0 REFERENCES

21 ATTACHMENTS Attachment I - Sign-off Identification List

This page Intentionally left blank.

For printing 2 sided sheets.

GOP-3 REVISION 13 1.0 PURPOSEISCOPE 1.1 This procedure provides instructions for Reactor Startup, from Hot Standby to Startup.

1 .2 The following governing regulations apply to this procedure:

a. 100FR5O.59.

b. 10CFR5O, Appendix B.

c. SAP-630, Procedure/Commitment Accountability Program.

PAGE 1 OF 22

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For printing 2 sided sheets.

GOP-3 REVISION 13 (NOT,E2.0 and 3.0)

a. All personnel who sign off steps in this procedure must enter their names and initials on Attachment I.

b. Each step should be initialed and dated when all its substeps are either completed and checked-off or marked N/A and initialed.

If this procedure must be initiated under conditions other than those in Section 2.0, INITIAL CONDITIONS, the Shift Supervisor or Control Room Supervisor will review Sections 2.0, INITIAL CONDITIONS, and 3.0, INSTRUCTIONS. Steps that are not applicable due to plant conditions will be marked N/A and initialed by the Shift Supervisor or Control Room Supervisor. All other items will require sign-off or check-off.

2.0 INITIAL CONDITIONS INITIALS/DATE 2.1 RCS status is as follows: £e& /7;%

a. System temperature is being maintained between 555°F and 559°F using the Bank I Condenser Steam Dumps or Steam line PORVs.

b. System pressure is being maintained between 2230 psig and 2240 psig in AUTO control. -

c. All Reactor Coolant Pumps are in operation.

d. Pressurizer level is being maintained at 25%

in AUTO control.

2.2 All Safety Injection Systems are aligned and operable. e& / 7; 2.3 Excore NIs are aligned for critical operation per SOP-404, seo / 7%

Excore Nuclear Instrumentation System.

2.4 The Reactor is shutdown with all Control Bank Rods fully f,P& /

inserted.

PAGE 2 OF 22

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For printing 2 sided sheets.

GOP-3 REVISION 13 INITIALS/DATE 2.5 Shutdown Margin is being maintained for Mode 3 conditions LeO / 7a%

per STP-1 34.001, Shutdown Margin Verification.

2.6 Reactor Makeup Control is in AUTO and set for blended flow &e& ii;%

equal to the existing boron concentration.

2.7 Secondary Plant status is as follows: Leo / 7;4

a. The Main Turbine is on the Turning Gear per SOP-215, Main Turbine Lube Oil Supply System.

b. The Main Feedwater Pumps are on their Turning Gear per SOP-209, Feedwater Turbine Lube Oil System.

c. Narrow Range Steam Generator levels are being maintained between 60% and 65% with chemistry within specification using the following:

1) Slowdown per SOP-212, Steam Generator Slowdown.

2) Emergency Feedwater per SOP-21 1, Emergency Feedwater System.

d. Main Steam is being warmed per SOP-201, Main Steam System.

e. Feedwater is being warmed per SOP-210, Feedwater System.

f. Condensate is in operation per SOP-208, Condensate System.

g. Circulating Water is in operation per SOP-207, Circulating Water. N 2.8 The Rod Control and Position Indicating Systems are in s1iE& I ?a operation per SOP-403, Rod Control And Position Indicating System.

2.9 The Control Rod Drive Mechanism Ventilation System is in (eo /

operation per SOP-i 14, Reactor Building Ventilation System.

2.10 GOP Appendix A review has been completed. Leo I 7;ap PAGE 3 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO Licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by mote than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 3.0 INSTRUCTIONS IITIALS/DATE 3.1 Shut down and isolate BTRS as follows: (eo , 7

a. Place HCV-387, BTRS BYP FLOW, in BYP.

b. Place BTRS SELECT Switch in OFF.

3.2 Verify RCS Chemistry control for startup: ,PO I 7%

CHG

a. Contact Chemistry to ensure RCS Chemistry control is () F satisfactory for startup per CP-625, Chemistry Refueling 7 Shutdown And Startup Plan.

b. Record current Boron concentration:

765 3.3 Pertorm the following if an RB entry is in progress or will occur during the reactor startup:

a. Obtain the approval of the GeneralJy1arrr, Nuclear Plant Operations, for perannel to be in the RB during the reactp

b. NotifHeaiTFcysics that a reactor startup is about to D and dose rates in the RB could change PAGE 4 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-.3 REVISION 13 INITIALS/DATE 3.4 Align Excore NIs for Reactor Startup as follows: LcA& /

ZOQ5 a. Ensure IN100033-Nl, REMOTE SOURCE RANGE MONITOR, is de-energized with fuses removed per SOP-404, Excore Nuclear Instrumentation System, CHG D

Section IV.F.

ZOO7 b. Ensure the following Nuclear Instrumentation Channels are in operation per SOP-404, Excore Nuclear Instrumentation System, Section lll.A and tested per the applicable STPs:

1) Two Source Range Channels.

2) Two Intermediate Range Channels.

3) At least three Power Range Channels.

c. Verify both Source Range Channels are indicating a minimum of two counts per second.

d. Perform either of the following to monitor Source and Intermediate Range Channels as follows:

1) Select the highest reading Source Range Channel and either Intermediate Range Channel on recorder NR-45, NIS RECORDER.

2) Monitor the highest reading Source Range Channel and either Intermediate Range Channel using computer display NR45 in FAST SPEED.

PAGE 5 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.4 continued z3 Audio Count Rate is not required to be operable.

e. At the AUDIO COUNT RATE CHANNEL drawer, perform the following:

1) Select the highest reading Source Range Channel on the CHANNEL SELECTOR Switch.

2) Adjust the AUDIO MULTIPLIER Switch as necessary to maintain a distinguishable audio countrate.

3) Place the SR COUNTER/SCALER, POWER switch in the POWER position.

3.5 Complete Attachment lIlA, Prior to Closing Reactor Trip g1eo / 7;ai, Breakers in Modes 3, 4 & 5, of GTP-702.

coi- 3.6 Ensure the P-4 trip actuating device operational test is cSieo / 7ab No1-* performed and Reactor Trip breakers are closed per STP-345.039, Reactor Trip P-4 Trip Actuating Device Operational Test.

ZOO8 3.7 Ensure both Rod Control MG sets are supplying load to ce& / 7a CHG B

to Rod Control per SOP-403, Rod Control and Position Indicating System,Section III.A. CHG D

PAGE 6 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and, impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Iavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE 3.8 If necessary, withdraw the Shutdown Banks as follows: O I 7;da,

a. Verify Shutdown Margin Boron Concentration is satisfactory by performing SIP-i 34.001, Shutdown Margin Verification for Mode 3 with S/D Banks OUT

b. Place ROD CNTRL START UP RESET Switch in START UP.

/Z (AUTJØN 3.8.c To minimize the possibi ity of binding at the full in position, rods should not be driven below the 000 indication on the Group Demand Step Counters.

c. Ensure the Step Counters indicate zero (000) steps.

CHG zoog-+ d. Update Rod Bank positions on the IPCS, refer to OAP-i 07.1, Control of IPCS Functions, Step 6.2.b.

CHG

e. Ensure IZMOI200, DRPI Main Control Board Display CHG Monitor, and IZMO12O1, DRPI Main Control Board V F Display Monitor, indicate RB.

f. Momentarily depress the ROD CNTRL ALARM RESET Pushbutton.

g. Verify ROD CNTRL SYS FAIL URGENT (XCP-620 5-i) and ROD CNTRL SYS FAIL NON-URGENT (XCP-620 5-5) alarms cleared.

PAGE 7 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or-Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) avg is 557° F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.8 continued (CAUTION 3.8.h To prevent any inadverte,n(inward rod motion the ROD CNTRL BANK SEL Switch should not be placed in or pass through AUTO.

Reactor Coolant System tiperature is being maintained between 555°F and 559°F using the Bank 1 Condenser Steam Dumps or Steamline PORVs.

h. Place ROD CNT BA SEL Switch in SBA.

(CAUT1ON 3.8.i) 12 steps should NOT be exceedd until Rod Bottom lights are off. If all Shutdown Bank A Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

Using the ROD CONTROL ROD MOTION Lever, perform the following:

1) Withdraw Shutdown BankAto ten Steps.

2) Verify that all RB lights for Shutdown Bank A are

3) Using the ROD CONTROL ROD MOTION Lever, withdraw SBA to 230 steps.

PAGE 8 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control, Room Supervisor. -

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

5570 b) Tavg is F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.8 continued

/

(CA To prevent any inadvertent inward rod motion the ROD CNTRL BANK SEL Switch should not be placed. in or pass through AUTO.

j. Place ROD CNTRL BANK SEL Switch in SBB.

(CTO.k 12 steps should NOT be exceeded until Rod Bottom lights are off. If all Shutdown Bank B Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

k. Using the ROD CONTROL ROD MOTION Lever, perform the following:

1) Withdraw Shutdown Bank B to ten steps.

2) Verify that all RB lights for Shutdown Bank B are off.

3) Using the ROD CONTROL ROD MOTION Lever, /

withdraw SBB to 230 steps. /

PAGE 9 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room supervisor. - -

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE 3.9 Contact Reactor Engineering for recommended rod heights SAD I and Estimated Critical Condition information.

Reactor Coolant System temperature is being maintained between 555°F and 559°F using the Bank 1 Condenser Steam Dumps or Steamline PORVs.

3.10 Perform a Shutdown Margin verification per STP-134.001, SA& I Shutdown Margin Verification, using Estimated Critical Condition boron, desired RCS temperature, and expected xenon.

STTS # 35-072315 (TE For initial criticality f6iiwing refueling, REP-i 07.001, Controlling Procedure For Refueling Startup And Power Ascension Testing, is the controlling document for Reactor Startup. Appropriate steps of GOP-3 should be initialed as they are performed.

3.11 Prepare for Reactor Startup as follows: £P2 I 7;da#

a. Adjust Boron concentration as required by Estimated Critical Condition calculation as follows:

Z003 1) Borate or dilute per SOP-i 06, CHG zo1o* Reactor Makeup Water System, / D ZO17 Sections lll.D, lll.E, or lll.F.

2) When complete, direct Chemistry to sample the RCS and the Pressurizer for boron.

PAGE 10 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room S U p.rvisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Iavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.11 continued

b. Block HIGH FLUX AT SHUTDOWN as follows:

1) Disable the IPCS High Flux At Shutdown alarm function as follows:

a) Type the Tirn-On-Code HFAS.

b) Verify OPERATOR DISABLED is CHG D

indicated above the ENABLE CALCS box.

c) If OPERATOR ENABLED is indicated, select DISABLE CALCS.

2) Place HIGH FLUX AT SHUTDOWN Switch for SOURCE RANGE N-31 in BLOCK.

3) Place HIGH FLUX AT SHUTDOWN Switch for SOURCE RANGE N-32 in BLOCK.

4) Verify SR HI FLUX AT SHUTDN BLOCK (XCP-620 4-4) annunciator alarms.

c. Review Estimated Critical Condition calculation within four hours prior to criticality, verifying predicted rod height is above the Rod Insertion Limit per Tech Spec 4.1.1.1.1 .c.

Time 3 t%tus aa PAGE 11 OF22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plantconditions and impact by the Shift Supervisor or Control Room.

Supervisor. .. .. .

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by mote than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.11 continued U. Review the following for current status and limitations for Mode escalation:

1) Removaland Restoration Log. .

2) Danger Tag Log.

3) 31 Day Surveillance Book.

4) Ensure completion of Attachment ll.F, Operational Mode Change Plant Startup Entering Mode 2, of GTP-702.

5) Ensure SAP-i 16, PLANT TRIP/SAFETY INJECTION PLANT RECOVERY, is completed, if necessary.

zoli e. Pertorm CAP-i 00.4, Communication, Attachment I, CHG D

Mode Change Brief Checklist. /

f. Update the IPCS Plant Mode indicator to indicate Mode 2 as the current Plant Mode as follows:

1) Type the Turn-On-Code MODE to display the PLANT MODE CHANGE DISPLAY window

2) Select the SET MODE 2 Pushbutton.

3) Verify the selected Mode is displayed on the left end of the top toolbar.

g. Verify all Shutdown Bank Rods fully withdrawn within 15 minutes of commencing Control Bank Rod withdrawal.

Time 70 & ca, dba,t a)fC%dtaaa/

PAGE 12 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room

- Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 IN ITIALS/DATE Step 3.11 continued

//

cy3.

Reactor Coolant System temperature is being maintained between 555°F and 559° F using the Bank 1 Condenser Steam Dumps or Steamline PORVs.

h. Obtain the Shift Supervisors permission to commence a Reactor Startup.

Announce Reactor Startup over the page system.

j. If used, place NR-45 CHART in HI speed.

k. Initiate REP-109.002, Inverse Count Rate Ratio Plot.

Ti me 5 i to &irls If performing an initial cycle startup, refer to REP-i 07.001, Controlling Procedure For Refueling Startup And Power Ascension Testing, for additional actions.

PAGE 13 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact. by the Shift Supervisor, or ControiRoom Supervisor. -. . .

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557° F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE 3.12 Achieve Reactor criticality as follows: /

a. Review GOP Appendix A, Generic Operating Precautions, for Reactor Startup.

cAUTIONia,1 2.

.1.

To prevent any inadvertent inward rod motion the ROD CNTRL BANK SEL Switch should not be placed in or pass through AUTO.

b. Place the ROD CNTRL BANK SEL Switch in MAN.

N A stable Startup Rate of one decade per minute should NOT be exceeded.

c. Uing ROD CONTROL ROD MOTION lever, commenc)

Control Bank Rod withdrawal to ten steps on Bank A. \

Time 2 ioaic aya cCAUTIdN 3.12.&)

12 steps should NOT be exceeded until all Rod Bottom lights are off.

If all Control Bank A Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

d. At ten steps on Control Bank A, stop and verify:

1) Bank A RB lights clear.

2) ONE ROD ON BOTTOM (XCP-621 3-1) annunciator clears.

3) RODS ON BOTTOM (XCP-621 3-2) annunciator clears.

e. Recommence withdrawing rods while observing that the groups sequence properly.

PAGE 14 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of

plant conditions and impact by the Shift Supervisor or Control Room SipeMsor. ..*. . V B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557° F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.12 continued

çCAUTIØ 3.12.f )

12 steps should NOT be exceeded until all Rod Bottom lights are off.

If all Control Bank B Rod Bottom lights are NOT off at tenS steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

f. At ten steps on Control Bank B, stop and verify Bank B RB lights clear.

g. Recommence withdrawing rods while observing that the groups sequence properly.

h. Verify 102 step Bank Overlap between Control Bank A and Control Bank B.

12 steps should NOT be eeeded until all Rod Bottom lights are off.

If all Control Bank C Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

At ten steps on Control Bank C, stop and verify Bank C RB lights clear.

j. Recommence withdrawing rods while observing that the groups sequence properly.

k. Verify 102 step Bank Overlap between Control Bank B and Control Bank C.

PAGE 15 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Controt Room Supervisor...

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.12 continued CAUTION Step 3.12.1 Reactor startup should be stopped and 1&C notified if the CRB INSERT LMT LO-LO (XCP-621 1-1) annunciator fails to clear between 118 steps and 134 steps on Bank C.

Verify CRB INSERT LMT LO-LO (XCP-621 1-1) El annunciator clears between 118 steps and 134 stepson Bank C.

Steps CAUTION 3.12.m 12 steps should NOT be exceeded until all Rod Bottom lights are off.

If all Control Bank D Rod Bottom lights are NOT off at ten steps, AOP-403.5, Stuck Or Misaligned Control Rod, should be entered.

NOTE 3.12.m Reactor Coolant System temperature is being maintained between 555°F and 559°F using the Bank 1 Condenser Steam Dumps or Steamline PORVs.

m. At ten steps on Control Bank D, stop and verify Bank D RB lights clear

n. Recommence withdrawing rods while observing that the groups sequence properly.

o. Verify the CRB INSERT LMT LO (XCP-621 1-2) El CHG annunciator clears between 138 steps and A 144 steps on Bank C.

Steps

p. Verify 102 step Bank Overlap between Control Bank C El and Control Bank D.

PAGE 16 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditionsand impact by the Shift Supervisor or Control Room Supervisor. .

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.12 continued

q. Within 15 minutes before achieving criticality, verify Tavg greater than or equal to 551°F.

Time . Tave -.

r. Announce criticality over the page system.

Time

s. Verify critical rod position is above the Rod Insertion Limit per Tech Spec 3.1.3.6.

t. Maintain as close to 0 SUR as reasonably achievable.

u. At the AUDIO COUNT RATE CHANNEL drawer, place the following switches in OFF:

1) AUDIO MULTIPLIER. El

2) CHANNEL SELECTOR. El

3) SR COUNTER/SCALER, POWER switch. El (Toggle down)

PAGE 17 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557° F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE 3.13 Increase Reactor Power to 1O% as follows:

a. Establish a stable Startup Rate of less than one decade per minute.

b. At 7.5x106%, perform the following:

1) Verify P6 Permissive energizes to bright.

2) Verify a minimum of one decade overlap between Source Range Channels and Intermediate Range Channels.

c. Prior to 1 CPS, perform the following:

1) Momentarily place SR TRAIN A Switch in BLOCK.

2) Verify SR A TRIP BLCK Permissive energizes to bright.

3) Momentarily place SR TRAIN B Switch in BLOCK. LI

4) Verify SR B TRIP BLCK Permissive energizes to bright.

d. Perform one of the following for continued monitoring of Intermediate and Power Range instrument:

1) If available for use, select one Intermediate Range Channel and one Power Range Channel on NR-45, NIS RECORDER.

2) Ensure at least one Intermediate Range and at least one Power Range instrument are selected for continuous monitoring using computer display NR45.

e. Stabilize Reactor Power at 1O%.

PAGE 18 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Iavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 INITIALS/DATE Step 3.13 continued

f. Record the following Critical Data:

1) RCS pressure: psig

2) Tavg:

3) Bank at steps

4) Boron Concentration: ppm

5) Time:

6) Stable Power: %

g. If perlorming an initial cycle startup, refer to REP-i 07.001, Controlling Procedure For Refueling Startup And Power Ascension Testing, for physics testing instructions.

PAGE 19 OF 22

GOP 3 REFERENCE PAGE

1. GENERAL NOTES A. Procedure steps should normally be performed in sequence. However, it is acceptable to perform steps in advance after thorough evaluation of plant conditions and impact by the Shift Supervisor or Control Room Supervisor.

B. At least two licensed operators, one of whom is SRO licensed, must be present in the Control Room during Reactor Startup.

2. REACTOR CONTROL A. Shutdown Bank Control:

1) The Shutdown Banks must be fully withdrawn whenever reactivity additions are being made by dilution, Xenon, Tavg, or control rods unless one of the following conditions exists:

a) The RCS is borated to Cold Shutdown concentration and verified by sample.

b) Tavg is 557°F and the RCS is borated to the hot, Xenon-free concentration and verified by sample.

2) If the count rate on any source range channel increases by more than a factor of two during any increment of Shutdown Bank withdrawal, rod withdrawal shall be stopped and the Shutdown Bank reinserted. Until Reactor Engineering has made a satisfactory evaluation of the situation, rod withdrawal shall not resume.

B. Source Range Control:

1) Source Range Counts and Digital Rod Position indication should be monitored during any Shutdown and Control Bank withdrawal or insertion.

2) While in the Source Range, positive reactivity may be changed by only one controlled method.

C. Anticipate criticality anytime:

1) During rod motion.

2) Boron dilution is in progress.

GOP-3 REVISION 13 IITIALS/DATE CAUTION 3.14 While operating with a positive Moderator Temperature Coefficient:

a. All reactivity additions should be slow and controlled.

b. A stable Startup Rate of 0.3 decade per minute should not ba exceeded.

c. Rods should be moved in 1/2 step increments until the effect of rod motion has been evaluated.

NOTE 3.14 Ensure sufficient Emergency Feedwater Flow exists prior to raising power.

3.14 Increase Reactor Power to between 1% and 3%. I 3.15 At the Point of Adding Heat, if NR-45, NIS RECORDER, I had previously been selected to HI speed place the recorder in LO speed.

CAUTION 3.16

a. Adjustment of Tavg with the Rod Control System must not be attempted with the ROD CNTRL BANK SEL Switch in any position other than MAN.

b. Manual rod control is required to establish equilibrium conditions, since C-S blocks automatic rod withdrawal.

3.16 Maintain Tavg between 555°F and 559°F. I 3.17 Complete Attachment ll.G, Operational Mode Change I Plant Startup Entering Mode of GTP-702.

3.18 Proceed to GOP-4A, Power Operation (Mode 1 - Ascending). I PAGE 20 OF 22

This page Intentionally left blank.

For printing 2 sided sheets.

GOP-3 REVISION 13

4.0 REFERENCES

4.1 CP-625, Chemistry Refueling Shutdown And Startup Plan. CHG F

4.2 FSAR Section 5.0.

4.3 GOR Appendix A.

4.4 GOP-4A, Power Operation (Mod 1 - Ascending).

4.5 GTP-702, Operational Mode Change and Contingency Surveillance Requirements.

4.6 OAP-1 00.4, Communication.

4.7 REP-107.001, Controlling Procedure For Refueling Startup And Power Ascension Testing.

4.8 REP-i 09.002, Inverse Count Rate Ratio Plot.

4.9 SAP-630, Procedure I Commitment Accountability Program.

4.10 SOP-i03, Boron Thermal Regeneration System.

4.11 SOP-106, Reactor Makeup Water System.

4.12 SOP-i 14, Reactor Building Ventilation System.

4.13 SOP-201, Main Steam System.

4.14 SOP-205, Turbine Sealing Steam System.

4.15 SOP-206, Main and Auxiliary Condenser Air Removal System.

4.16 SOP-207, Circulating Water.

4.17 SOP-208, Condensate System.

4.18 SOP-209, Feedwater Turbine Lube Oil System.

4.19 SOP-210, Feedwater System.

4.20 SOP-21 1, Emergency Feedwater System.

4.21 SOP-212, Steam Generator Blowdown.

PAGE 21 OF 22

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For printing 2 sided sheets.

GOP-3 REVISION 13 4.22 SOP-215, Main Turbine Lube Oil Supply System.

4.23 SOP-403, Rod Control And Position Indicating System.

4.24 SOP-404, Excore Nuclear Instrumentation System.

4.25 STP-134.OO1, Shutdown Margin Verification.

4.26 STP-45.O39 Reactor Trip P-4 Trip Actuating Dev OperationI Test.

4.27 V.C. Summer Precautions, Limitations, and Setpoints.

4.28 V.C. Summer Reactor Engineering Procedures.

4.29 V.C. Summer Tech Specs.

PAGE 22 OF 22

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For printing 2 sided sheets.

REP-i 09.002 JPM a Handout 2 ENCLOSURE 9.2 PAGE 1 OF 1 REVISION 13 Recommended Rod Positions for ICRR

. BankA_ BankB_ BankC_ BankD_ Purpose. -

0 X Start 10 X Rod Bottom lights 53 ICRR 103 ( f -

ICRR 129 x 1 Overlap 138 10 X ? - ICRR, RB lights 181 53 x ICRR 230 103 X ICRR, Overlap 129 X 1 Overlap 1382 10 ICRR, RB lights 181 53 x:_ ICRR 230 103 Xf ICRR, Overlap 118-134k X LO-LO Alarm Clear 129 < 1 Overlap 118134* 0-6 LO-LO Alarm Clear 138 10 ICRR, RB lights, 138-744 10-16 LO Alarm Cleat 181 53 ICRR 206 78 ICRR (If < 0.2) 230 103 ICRR, Overlap 128 ICRR (If < 0.2) 153 ICRR 178 ICRR 203 ICRR

= placekeeping checkbox

LO.LO Alarm should clear in the 1 18-134 range and overlap should be checked at 129.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPSF-007A (RI) 2015 NRC Sim b SRO &RO: Steam Generator Tube Rupture (DepressurizeRCS to < Ruptured S/G Pressure)

CA N I)II)ArE I:xAv!INI:R:

1fo,,t!a, April 13, 2015 Page 1 of?

TASK:

000-038-05-0 1 RESPOND TO STEAM GENERATOR TUBE RUPTURE PER EOP-4.0 TASK STANDARD:

RCS pressure is reduced to less than ruptured S/G pressure with PZR level> 10% or PZR level 76% or RCS subcooling <52.5SF. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations. This JPM is related to PRA event OAP2 Depressurize RCSto stop leakage into ruptured S/G TERMJN4 TING CUE: RCS depressurization completed with task standard met and the chosen PORV Block valve closed.

PREFERRED EV4LU4 TIONLOC4 TION PREFERRED E VAL (IA HON METHOL SIMULATOR PERFORM

REFERENCES:

EOP-4.0 E-3, STEAM GENERATOR TUBE RUPTURE INDEX NC). K/A NO. RO SRO 010000A203 A2.03 PORV failures 4.1 4.2 TOOLS: Copy of EOP-4.0 marked for current plant conditions (tube rupture on S/G C) up to step 24.

EVALUATION TIME 15 TIME CRITICAL No JOCfRS5: 45(a)6 TIME START: TIMF. FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: ITNSAT CANDIDA TE:

EXAMINER:

SIGNAlURE I )AtE 11oIii!tip, April 13, 2015 Page 2 of 7

INS UCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE

.TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL COtVDITIOiV: A Steam Generator Tube Rupture is in progress.

S/G C has been isolated per EOP-4.O.

An operator initiated cooldown has been performed according to EOP-4.O, through Step 23.

IAITL4TING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

Control Room Supervisor directs you as ROATC to depressurize the RCS using PZR Spray, per EOP-4.O, Step 24.

HAND JPM BRIEFING SHEET TO OPERA TOR AT THIS TIME!

1Io,idtii, April 13, 2015 Pt:ge 3 of 7

STEPS CRITICAL: No SEQUENCED: Yes SAT UNSA T P1 Attempt to depressurize the RCS using normal spray valve PCV-444D.

STEP STANDARD:

Places PZR Spray Valve PCV-444D controller in MANUAL and increases output to 100% demand.

Determines that PCV-444D did not open based on Red light OFF and Green light ON for PCV-444D.

CUES:

Evaluator note: Give candidate 1-2 minutes to become familiar with control board indications and status of procedure implementation.

Evaluator cue: Provide the marked up copy of EOP-4.0, E-3 Steam Generator Tube Rupture at this time.

Evaluator note: With B and 0 RCP secure candidate should NOT attempt to open PCV-444C. Proceeds to Step 25 based on alternative action Step 24 a.

COMMENTS:

CRiTICAL: No SEQUENCED: Yes £4 T UNSA T []

STEP: 2 Verifies at least one PZR PORV is available.

1TEP STANDARD:

Notes all three PZR PORVs are available by observing Green lights ON for all PORV position indicators.

CUES:

3OMMENTS:

!1JOfldtiJ, April 13, 2015 Page 4af7

(7UHC4L: Yes SEOUEN(ED: Yes SAT UNSA T STEP: 3 Opens one PZR PORV until any termination criteria is met; RCS pressure < C (ruptured) SIG pressure and PZR level> 10%; or PZR level >76; or RCS subcooling <52.5°F.

STEP STANDARD:

Selected PORV indicates Red light ON, Green light OFF.

RCS pressure decreases.

Recognizes one of the following from MCB indications:

-RCS pressure < C S/G pressure with PZR level >10% or,

-PZR level >76% or,

-RCS subcooling <52.5°F.

CUES:

Evaluator note: Using the MCB indicators it is most likely that candidate will terminate on RCS pressure < Ruptured (C) S/G pressure and PZR level> 10%, but if using IPCS values it is possible that they will terminate on PZR level >76. Both termination criteria occur at about the same time and terminating on either one is satisfactory.

COMMENTS:

1tiidtii, April 13, 2015 PageS of 7

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: j 4 Closes Selected PORV.

STEP STANDARD:

Takes PORV ControF Switch for the Selected PORV to the CLOSE position.

- Notes Selected PORV position indicates Red light ON, Green light OFF and RCS pressure still decreasing.

- Candidate notes that selected PORV failed to close.

CUES:

Evaluator note: This is the point that the JPM becomes alternate path.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT tINSA T STEP: 5 Stops RCS depressurization by closing block valve for associated PORV.

STEP STANDARD:

Places associated PORV Block Valve (MVG-8000A/B/C) to close observes Red light OFF, Green light ON.

CUES:

COMMENTS:

Examiner ends JPM at this point.

Mtmdt,i, April 13, 2015 Page 6 of 7

JPM SETUP SHEET JPM NO: NJPSF-007A (Ri)

DESCRIPTION: 2015 NRC Sim b SRO & RO: Steam Generator Tube Rupture (Depressurize RCS to < Ruptured S/G Pressure)

ICSET: 311 IATRUCTIONS:

If IC-31 1 is designated for this JPM then reset to IC-31 1, leaving simulator in FREEZE.

Set IPSC to display 2PS1 at the RO station.

Mark up EOP-4.0 for current plant conditions (tube rupture on SG C) up to step 24.

When Examinee is ready, (on evaluator cue) go to RUN.

If IC-31 1 is not designated for this JPM then initial conditions may be established by reseting to IC-i 0 and following the below directions:

1. Insert: MAL-RCSOO2C Final Value = 600 Ramp = 0 (S/G Tube Rupture on C S/G)

MAL-PRSOO3B Final Value = 0 (PRESSURIZER SPRAY VALVE 4440 FAILURE)

2. Set Event #1 as X05i386o >0 Set Event #2 as X05i387o >0 Set Event #3 as X05i388o >0

3. Insert: VLV-RCOO4P Final Value = 100 (PCV-445A STUCK OPEN), set to event #1 VLV-RCOO1 P Final Value = 100 (PCV-444B STUCK OPEN), set to event #2 VLV-RCOO5P Final Value = 100 (PCV-4458 STUCK OPEN), set to event #3

4. RUN 180 seconds

5. Manual SI and perform actions of EOP-1 .0 & EOP-4.0 up through step 4.

6. Throttle EFW to C S/G when level > 40%.

7. FREEZE

8. Insert: LOA-MSSO33 Position To = RACK OUT, (RACK OUT BKR FOR MVG-2802B (STM SUPPLY TO TDEFP))

9. RUN

10. Trip RCPs B and C.

11. Perform actions of steps 5 to step 23 of EOP-4.0.

12. FREEZE

13. Set IPSC to dsplay 2PS1 at the RO station.

14. Mark up EOP-4.0 for current plant conditions (tube rupture on SG C) up to step 24.

15. When Examinee is ready: RUN CO.ILlIENTS:

JIOIIdUI, .-lpril 13, 2015 Page 7af7

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CO?SIDERA TIONS: . .

INITIAL CONDITION: A Steam Generator Tube Rupture is in progress.

S/G C has been isolated per EOP-4.O.

An operator initiated cooldown has been performed according to EOP-4.O, through Step 23.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

Control Room Supervisor directs you as ROATC to depressurize the RCS using PZR Spray, per EOP-4.O, Step 24.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPS-065 (RI) 215NRCSimcRO:

Establish Hot Leg Injection During Loss of RHR at Mid-Loop Conditions CAN DIDA1E:

[XAM1NER lIOIIt!ti). 1pril 13, 2015 Pcige I t/* 9

TASK:

000-083-05-01 RESPOND TO LOSS OF RESIDUAL HEAT REMOVAL SYSTEM WHILE AT MID-LOOP CONDITIONS PER AOP-l 15.5/SOP-il 5 TASK STANDARD:

SI flow verified on FI-940, CHG LOOP A CLD/HOT LG FLOW and hot leg level increasing.

TERMIN4TING CtJE: SI flow verified on FI-940 and hot leg level increasing.

PREFERRED EV4L U4 TION LOC4 TION PREFERRED EVALUATION METHOL SIMULATOR PERFORM

REFERENCES:

AOP-i 15.1 RHR PUMP VORTEXING AOP-l 15.5 LOSS OF RHR WITH THE RCS NOT INTACT (MODES 5 AND 6) iNDEX NO. K1A NO. RO SRO 000025K301 AK3.0l Shift to alternate flowpath 3.1 3.4 TOOLS: AOP-ll 5.5 marked to match initial conditions.

EVAL UA TION TIME 15 TIME CR!TIC4L No IOCfRSS: 41(b)l 0 lIME STAWF: lIME FINISII: PERFORivIANCEFIME:

PERFORMANCE RA TING: SAT: UNSAT CANDID A TE:

EXAMINER:

SIGNATURE DATE lloiiday. Apr11 13, 2015 Page 2 of 9

INS UCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED. -

SAFETY CONSIDERATIONS:

INITIAL CONDiTION: The plant was in Mode 5 with RCS at Mid-loop conditions with the Reactor head installed and the Pressurizer Manway removed.

The A RHR loop was the in-service loop.

Due to lowering hot leg level, the Crew entered AOP-115.1 and then AOP-115.5.

The present conditions are:

- RCS hot leg level is in the region of unacceptable operation for RHR.

- Step 17 of AOP-115.5 has been reached and core exit IC temperatures are

>200°F and increasing.

- The B Charging pump is in service.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CRS directs you as NROATC to establish Hot Leg Injection per AOP-115.5, Attachment 2.

HAND JPt1I BRIEFiNG SHEET TO OPERA TOR AT TillS TIME!

Mo,ida.r. 4priI 13, 2015 Page 3 (./ 9

STEPS CRITICAL: No SEQUENCED: Yes SAT UNSAT STEP: 1 Step 1. Check if a Charging Pump is available.

STEP STANDARD:

Verifies B charging pump is available by observing Red light ON above pump control switch and amps indicated on ammeter.

CUES:

Evaluator note: Assure that SIPCS screens are set up per the JPM Setup Instructions.

Evaluator cue: Provide the marked up copy of AOP-115.5, Loss of RHR with the RCS not Intact (Modes 5 and 6) at this time.

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT ([NSA T STEP: 2 Step 2. Stop any running Charging Pump STEP STANDARD:

Stops B Charging pump by placing control switch to STOP.

CUES:

COMMENTS:

lto,,dai. .lpril 13, 2015 Page 4 of 9

CRITICAL: No $EOUEN(ED: Yes SAT UNSA T STEP: 3 Step 3. Close MVG-8107 and MVG-8108, CHG LINE ISOL.

STEP STANDAKD V Positions MVG-8107 & 8108, CHG LINE ISOLs, to closed position, Red light OFF and Green light ON for each valve.

CUES:

Evaluator note: At least one of the valves must be closed to satisfy step.

COMMENTS:

CRITI4L No SEQUENcED: Yes SAT UNSA T STEP: 4 Step 4.a. Ensure all of the following are closed MVG-8885, CHG LP A ALT TO COLD LEGS.

MVG-8801A(B), HI HEAD TO COLD LEG IN].

STEP STANDARD:

Verifies MVG-8885, CHG LP A ALT TO COLD LEGS, indicates Red light OFF and Green light ON.

Verifies MVG-8801A & B, HI HEAD TO COLD LEG INJ, indicates Red light OFF and Green light ON.

CUES:

COMMENTS:

)1o,,dm, .4priI 13, 2015

/V Ptige 5 9

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T STEP: 5 Step 4.b. Open MVG-8884, CHG LP A TO HOT LEGS..

STEP STANDARD: -

Places TRN A PWR LCKOUT switch to ON.

I Positions MVG-8884, CHG LP A ALT TO HOT LEGS, to Open position; Red light ON and Green light OFF CL/ES:

Evaluator note: The procedure does not describe operation of the Power Lockout Switch but this action is required to get MVG-8884 to change position.

COMMENTS:

CRITIC4L: No SEQUENCED: Yes SAT EJ t/N4T STEP: 6 Step 4.c. Close MVG-8106, CHG PP, Miniflow Isolation.

STEP STANDARD:

Positions MVG-8106 CHG PP, Miniflow Isolation to Closed position; Red light OFF and Green light ON Places TRN A LCKOUT switch to OFF.

CUES:

Evaluator note; MVG-8106 operation relies on the same power lockout switch as MVG-8884.

COMMENTS:

iltondaj. April 13, 2015 Page 6 of 9

CRITIC4L: No SEQUENCED: Yes SAT (WSA T STEP: 7 Step 4.d. Close MVT-8105, SEAL WTR INJ ISOL.

STEP STANDARD:

Positions MVT-8105, SEAL WTR INJ ISOL, to Closed position; Red light OFF and Green light ON.

CUES:

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T STEP: 8 Step 5. Start one Charging Pump.

STEP STANDARD:

Starts 8 Charging pump by placing control switch to START position. Pump indicates Red light ON and Green light OFF with normal pump amps.

CUES: -

COMMENTS:

ilI()lU!(R, April 13, 2015 Page 7 if 9

CRITIC4L: No SEQUENCED: Yes SAT tJNSA T STEP: J 9 Step 6. Verify SI flow on Fl-940, CHG LOOP A CLD/HOT LG FLOW GPM.

STEP STANDARD:]

SI flow verified on F!-940, CHG LOOP A CLD/HOT LG FLOW.

CUES:

COMMENTS:

CRITICAL: No SEQUENCED: Yes £4 T UN4 T STEP: 10 Restores Hot Leg level

[STEP STANDARD:

Hot Leg level> 15.5 CUES:

Evaluator cue: End JPM when level begins to increase.

Evaluator note: The RCS Mid Loop Level Monitoring system LR-1 330/1 331 indicates in inches above the bottom of the Hot Leg and 15.5 is the desired indication. The Mansell indication is in feet elevation and 430 10 is the desired reading.

COMMENTS:

Examiner ends JPM at this point.

47oiday, April 13, 2015 Page 8 of 9

JPM SETUP SHEET JPMNO: NJPS-065 (Ri)

DESCRIPTION: 2015 NRC Sim c RO: Establish Hot Leg Injection During Loss of RHR at Mid-Loop Conditions 1CSET: 312 INSTRUCTIONS:

If IC 312 is designated for this JPM then reset to IC 312, leaving the simulator in FREEZE.

1. Set one SIPCS screen to HALFPIPE from the Map Menu selections and another to ZZSHTDWN, Shutdown off the ZZ Menu pad.

2. Set up Mansell Level monitoring cart at the CCW end of the Main Control Boards. Turn on CRS SIPCS screen by typing MLMSA or MLMSB from any SIPCS screen. If the SIPCS function is NOT enabled just set up the computer cart for Mansell Indication.

3. When Examinee is ready (on evaluator cue) go to RUN If IC-312 is not designated for this JPM then initial conditions may be established by reseting to IC-20 and following the below directions:

1. Insert: MAL-RCSOO6C Final Value = 4000 (RCS Cold leg leak)

OVR-AA028 Override To = True (Ann acknowledge)

LOA-RCSO53 Final Value POWER_ON (Mid-loop Monitor Disconnect Switch) 2.Set one SIPCS screen to HALFPIPE from the Map Menu selections and another to ZZSHTDWN, Shutdown off the ZZ Menu pad..

3. Set up Mansell Level monitoring cart at the CCW end of the Main Control Boards. Turn on CRS SIPCS screen by typing MLMSA or MLMSB from any SIPCS screen. If the SIPCS function is NOT enabled just set up the computer cart for Mansell Indication.

4. RUN

5. Perform actions of AOP-1 15.1, step 1 waiting for break flow to require Alternative Action 1 U.

6. Perform actions of AOP-1 15.5 steps 1-4 and steps 11 - 17.

7. When core exit TC temperature is >200F, with LT1 330/1331 <15.5 and Mansell <430 10 modify MAL-RCSOO6C to 2,000.

9. FREEZE

8. When Examinee is ready (on evaluator cue): RUN COi1JMENTS:

iThiuluj, .IpriI 13, 2(115 P(lgL 9 oJ9

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY COIVSIDERA TIONS:

INITIAL CONDITIOiV: The plant was in Mode 5 with RCS at Mid-loop conditions with the Reactor head installed and the Pressurizer Manway removed.

The A RHR loop was the in-service loop.

Due to lowering hot leg level, the Crew entered AOP-1 15.1 and then AOP-115.5.

The present conditions are

- RCS hot leg level is in the region of unacceptable operation for RHR.

- Step 17 of AOP-1 15.5 has been reached and core exit TC temperatures are >200°F and increasing.

- The B Charging pump is in service.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CR5 directs you as NROATC to establish Hot Leg Injection per AOP-1 15.5, Attachment 2.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. . SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPSF-019A (RI) 2015 NRC Sim U RO & SRO-U:

Manually Initiate Reactor Building Spray CANDIDATE:

EXAMINER Moi,dar, Apr11 13, 2015 Puge I of ii

TASK:

026-005-0 1 -01 MANUALLY INITIATE REACTOR BUILDING SPRAY PER SOP-116/EOP1.0.

TASK STANDARD:

At least one train of containment spray is manually actuated with >2500 gpm per EOP-1 .0 and RCPs are secured PRIOR to damaging RCP due to loss of CCW as evident from Motor Bearing temperature exceeding 195°F or Lower Seal Water Bearing temperature exceeding 225°F or Seal Water Outlet temperature exceeding 235°F.

TERPJINATING CUE: RB Spray initiated.

PREFERRED EVAL U4 TION L0C4 TIO,V PREFERRED EVA L CIA TION ME THOL SIMULATOR PERFORM

REFERENCES:

EOP-1 .0 E-0, REACTOR TRIP/SAFETY INJECTION ACTUATION INDEX NO. KA NO. RO SRO 026000A401 A4.01 CSS controls 4.5 4.3 TOOLS: EOP-1 .0, E-0, REACTOR TRIP/SAFETY INJECTION ACTUATION marked through step 7.

EVALUA TION TiME 5 TIME CRITICAL NO IOCfRS5: 45(b)(8)

TIME START. TIME FINISH: PERR)RMANCE TIME:

PERFORMANCE RATING: SAT. UNSAT:

CANDIDA TE:

EXAMINER:

SIGNATURE DATE IThnt!tn, .4prll 13, 2015 Page 2 of 11

LVSTR UCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL COtVDITION: The reactor has tripped from 100% power and an SI has occurred.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CR5 directs you as the ROATC to perform Step 8 of EOP-1 .0, E-0, REACTOR TRIP/

SAFETY INJECTION ACTUATION.

HAND .JP3I BRIEFING SHEET TO OPERA TOR .1 T THIS TIME!

1Io,,dt,i April 13, 2015 Page 3 of 11

STEPS CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 1 Step 8; Verify RB pressure has remained LESS THAN 12 psig on PR-951, RB PSIG (P-951), red pen EP STANDARD:

Verifies RB pressure >12 PSIG, moves to Alternative Action column for step 8.

CUES:

Evaluator cue: Provide the marked up copy of EOP-1 .0, E- 0, REACTOR TRIP/SAFETY INJECTION ACTUATION marked through step 7.

COMMENTS:

Iiioiidt,p, Apr11 13, 2015 Ptige 4 of]l

CRITICAL: No SEQUENCED: Yes SAT UNSAT STEP: 2 AA Step 8 a); Verity both the following annunciators are lit:

XCP-612 3-2 (RB SPRACT).

XCP-612 4-2 (PHASE B ISOL).

IF either annunciator is NOT lit, THEN actuate RB Spray by placing the following switches to ACTUATE:

Both CS-SGA1 and CS-SGA2.

OR Both CS-SGB1 and CS-SGB2.

STEP STANDARD:

Verifies both annunciators are NOT lit.

Places (CS-SGA1 and CS-SGA2) or (CS-SGB1 and CS-SGB2) to the ACTUATE position.

CUES:

Evaluator note: These switches require two hand operation to turn both switches at once.

Evaluator note: Examinee may try both trains of switches. If only A train switches are used they will fail to work and starting individual components becomes critical. If B train switches are used they will cause all spray system functions to occur EXCEPT the Train A RB Spray pump discharge valve, MVG-3003A, will not automatically open and must be manually opened. The JPM becomes alternate path once the Examinee begins manual realignment actions.

COMMENTS:

lloudc,,, April 13, 2015 Pt,gt 5 of 11

CR1TIC4L: No SEQUENcED: Yes SAT UNSA T STEP: 3 AA Step 8 b); Verify Phase B Isolation by ensuring RB SPRAY/PHASE B ISOL monitor lights are bright on XCP-6105.

STEP STANDARD:

PHASE B Isol monitor lights are bright on XCP-6105.

CUES:

Evaluator cue: If told as the SS that Phase B monitor lights are not bright on XCP-6105 then direct Examinee to ensure valves are aligned as required for Phase B.

Evaluator note: If only the A train switches were used then PHASE B lights will not turn bright.

COMMENTS:

ffoiit1cii, .4pril 13, 2015 Page 6 of Ii

(i?ITIC4L: Yes SEOUENCED: Yes SAT LINSA T E1 STEP: 4 AA Step 8c); Ensure the following are open:

MVG-3001A(B), RWST 1° SPRAY PUMP A(B) SUCT. -

MVG-3002A(B), NAOH TO SPRAY PUMP A(B) SUCT.

MVG-3003A(B), SPRAY HDR ISOL LOOP A(S).

STEP STANDARD:

MVG-3001A(B), RWST TO SPRAY PUMP A(S) SUCT. Indicates Red light ON, Green light OFF.

MVG-3002A(B), NAOH TO SPRAY PUMP A(S) SUCT. Indicates Red light ON, Green light OFF.

MVG-3003Af B), SPRAY HDR ISOL LOOP A(S). Indicates Red light ON, Green light OFF.

CUES:

Evaluator Note: If only A train switches were used in JPM step 2 the Examinee must manually open all valves from their MCB switches.

Evaluator Note: MVG-3003A must be opened manually regardless of which train switches were attempted to actuate RB spray. Examinee must manually open the valve from its MCB switches.

COMMENTS:

Mondt, April 13, 2015 Page 7 of 11

CRITIC4L: Yes SEQUENCED: Yes SAT UIVSAT STEP: 5 AA Step 8 d); Ensure both RB Spray Pumps are running.

STEP STANDARD:

Verifies A and B RB Spray Pumps are running by Red light ON indication and normal running amps, CUES:

Evaluator Note: This step is critical if the B train switches were not attempted to actuate RB spray.

If only A train switches were used in JPM step 2 the Examinee must manually start the pumps from their MCB switches.

COMMENTS:

RITIAL No SEQUENCED: Yes SAT UNSAT STEP: 6 AA Step 8 e); Verify RB Spray flow is GREATER THAN 2500 gpm for each operating train on:

Fl-7368, SPR PP A DISCH FLOW GPM.

Fl-7378, SPR PP B DISCH FLOW GPM.

STEP STANDARD:

Fl-7368, SPR PP A DISCH FLOW, and Fl-7378, SPR PP B DISCH FLOW, are> 2500 gpm.

CUES:

COMMENTS:

,lIoi,daj, April 13, 2015 Pcige S of ii

CRITIC4L: Yes SEQUENCED: Yes SAT UN$A T STEP: 7 AA Step 8 f); Stop all RCPs.

STEP STANDARD:

Places A, B, & A RCP switches in Stop; Red light OFF, Green light ON, flow decreasing and 0 running amps PRIOR to damaging RCP due to loss of CCW as evident from Motor Bearing temperature exceeding 195F or Lower Seal Water Bearing temperature exceeding 225F or Seal Water Outlet temperature exceeding 235F.

CUES:

Evaluator Note: It is possible that the Examinee may decide to trip RCPs at the beginning of this JPM based on RB Hi 3 pressure. The EOP-1.0 reference page lists the Phase B actuation annunciator (XCP-612 4-2) as criteria for tripping RCPs not the Hi 3 pressure. The phase B has not happened at the beginning of the JPM but it should have. The Examinee will ensure that it does happen. A premature trip of the RCPs would be technically incorrect but NOT grounds for failure.

Booth Operator note: Do not reset the simulator until Evaluator is satisfied that RCP temperatures were not exceeded. Provide information from SIPCS in the booth.

COMMENTS:

Examiner ends JPM at this point.

lIo,ultii, -lpril 13, 2015 Pt,gL 9 of 11

JPM SETUP SHEET JPi3I NO: NJPSF-019A (Ri)

DESCRIPTWN: 2015 NRC Sim U RO & SRO-U: Manually Initiate Reactor Building Spray ICSET: 313 INSTRUCTIONS:

If IC-31 3 is designated for this JPM then reset to IC 313 leaving the simulator in FREEZE.

1. RUN, silence annunciators and FREEZE promptly.

2. Silence DCS speaker.

3. Set up SIPCS in Booth with RCP temperatures; Motor Bearings, Lower Seal Water Bearing and Seal Watrer Outlet.

4. When Examinee is ready (on Evaluator cue) go to run.

If IC-31 3 is not designated for this JPM then initial conditions may be established by reseting to IC-i 0 and following the below directions:

1. Insert: LOA-PCS1O9 Position To = AS IS (Hl-3 Channel 1 fail as is)

LOA-PCS1 10 Position To = AS IS (Hl-3 Channel 2 fail as is)

LOA-PCS1 16 Position To = AS IS (Hl-3 Channel 4 fail as is)

MAL-RHROO8A Reactor Building Spray Pump A discharge valve (3003A) fail MAL-MSSOO3A Final Value = 1 .2E7, (Steamline break inside containment)

OVR-SGO1 1 Override To = FALSE, (Fail RB Spray actuation switch) CS-SGA1 (Train A)

OVR-SGO12 Override To = FALSE, (Fail RB Spray actuation switch) CS-SGA2 (Train A)

2. Set event #1 as xO2il 010 = = 1 (Allows manual opening of 3003A when 101 switch taken to open)

3. Insert a new MAL-RHROO8A, set to Event #1, set Delete in = 1 second.

4 .RUN until RB pressure >12 psig and ESF loading sequencer is complete (approximately 60 seconds). Leave RCPs running.

5. FREEZE

6. Ensure RCS pressure is greater than the 1418 psig RCP trip criteria then modify MAL-MSSOO3A to final value = 1 .8E6

7. RUN, silence annunciators and FREEZE promptly.

8. Silence DCS speaker.

9. Set up SIPCS in Booth with RCP temperatures; Motor Bearings, Lower Seal Water Bearing and Seal Watrer Outlet.

.41o,idt,p, April 13, 2015 Page 10 of It

10. When Examinee is ready (on evaluator cue): RUN COMMENTS:

Failing 1/2 RB Spray Actuation switches in a train will disable that function.

Booth Operator do NOT reset simulator until Evaluator has verified RCP Temperatures did NOT exceed critical standard of Motor Bearing> 195°F, Lower Seal Water Bearing > 225°F and Seal Water Outlet >2359F.

llondav, .4pri/ 13, 2015 Page 11 Y Ii

JPM BRIEFING SHEET OPERA TOR INS TB UCTIONS:

SAFETY CONSIDERA lIONS: .

INITIAL CONDITION: The reactor has tripped from 100% power and an SI has occurred.

INITI4 TING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CRS directs you as the ROATC to perform Step 8 of EOP-1 .0, E-0, REACTOR TRIP!

SAFETY INJECTION ACTUATION.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPS-025 (R2) 2015 NRC Sim e RO:

Start and Load B Emergency Diesel Generator CANI)IDAfE.

EXAMINER:

Page 1 of 14 Tuestiti, -IpriI 14, 21)15

TASK:

064-003-01 -01 LOAD THE DIESEL GENERATOR TASK STANDARD:

B Diesel Generator is started and loaded to 4150-4250 KW. The use of applicable Human Performance Tools (3-way communication self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.

TERiIIINA TJNG CUE: B D/G operating at >4150 KW load.

PREFERRED EVALUATION LOCATION PREFERRED E VAL (IA TION ME THOD SIMULATOR PERFORM

REFERENCES:

SOP-306 EMERGENCY DIESEL GENERATOR INDEX NO. KIA NO. RO SRO 064000A401 A4.01 Local and remote operation of the ED/G 4.0 4.3 ToOLS: SOP-306 with section IV.B step 2.1 and 2.2 marked as complete. (JPM e handout)

EVAL tL4 TION TIME 15 TIME RITIAL No 10CFRSS: 45(a)8 TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT. [YNSAT.

CANDIDATE:

EX4MINER:

SIGNATURE DATE Tuesday, .lpril 14, 2015 Page 2 of 14

INSTRUCTIONS TO OPERATOR READ To OPERA fOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL CONDJ TION:

The plant is operating at 100% power.

B DIG is to be started and loaded for monitoring cylinder temperatures using SOP-306 Section IV.B.

Normal and Alternate AC power is available to buses 1 DA and 1DB.

It is an B2 Maintenance Work Week.

Hourly logging of ESF XFMR FEED KV (MCB) voltage and 1DB VOLTS (MCB) is being performed by another licensed operator per SOP-306,Section IV B step 2.1.

All pre-start check steps have been completed.

tNt TIA TIiVG CUES:

CRS directs you to start and load B D/G to 4150-4250 KW per SOP-306,Section IV.B, steps 2.3 & 2.4.

HAND JPM BRIEFING SHEET TO OPERA TOR AT THIS TIME!

Tuesday, April 14, 2015 Page 3 of 14

cr.c CRITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 1 Step 2.3 a. Ensure the diesel is ready to be started as indicated by the following:

1) Verify Annunciator XCP-637 1-2, DG B AUTOSTART NOT READY, is NOT in alarm.

STEP STANDARD:

Verifies Annunciator XCP-637 1-2, DG B AUTOSTART NOT READY, is clear.

CUES:

Evaluator cue: Provide JPM e Handout to Examinee at conclusion of initial briefing.

Evaluator note: Examinee may take extra time to review Precautions as a matter of familiarizing with task prior to commencing start and load.

[Co&MENTS:

Page 4 of 14 Tuestlav, -Ipri1 14, 2015

(7?ITIC4L: No SEQUEN(ED: Yes SAT UNSA T STEP: ] 2 Step 2.3 a. Ensure the diesel is ready to be started as indicated by the following:

2) The READY FOR AUTO START light is lit at the Diesel Generator B Local Control Panel (DB-436).

STEP STANDARD:

Calls the lB operator and verifies the READY FOR AUTO START light is lit at the B D/G Local Control Panel.

CUES:

Booth Operator cue: When requested, as the lB operator, inform the Examinee that the READY FOR AUTO START light is lit at the B D/G Local Control Panel.

fCO4IMENTS:

R1TICAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 3 Step 2.3 b. Momentarily place the Diesel Generator B TEST Switch to START.

STEP STANDARD:

Momentarily rotates B Diesel Generator TEST switch to the START position.

CUES:

Evaluator note: Examinee should request a peer check.

COMMENTS:

Tuesda, 1prll 14, 2015 Page 5 of 14

CRITICAL: No SEOUENCED: Yes SAT UNSA T STEP: 4 Step 2.3 c. Verify the Diesel Generator starts and stabilizes between the following:

1)58.9Hz and 61.1 Hz.

2) 6800 volts and 7600 volts.

STEP STANDARD:

DG B VOLTS indicates 6800-7600 volts and FREQUENCY indicates 58.9 61.1 Hertz.

CUES:

COMMENTS:

CRITICAL: No SEQUENGED: Yes SAT UNSAT STEP: 5 Step 2.3 d. Reset the tripped Diesel Generator B relay flags at the local panel (XCX-5202, DB-436).

STEP STAVDARD:

Calls the lB operator and verifies the Diesel Generator B relay flags are reset at the Local Control Panel.

CUES:

Booth Operator cue: When requested, as the lB operator, inform the Examinee that the Diesel Generator B relay flags have been reset.

COIWMENT$:

Tuesttt,v, April 14, 2t115 Page 6 of 14

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 6 Procedure NOTE 2.4 If time permits, the following guidelines should be utilized to achieve the desired load:

a. Prior to closing the Diesel Generator Breaker, the Diesel should be run at no-load for at least ten minutes.

b. Once the Diesel Generator Breaker is closed, load should be adjusted to between 850 KW and 1000 KW and maintained for at least ten minutes.

c. Load should be adjusted to between 2250 KW and 2550 KW and maintained for at least ten minutes.

d. Load should be adjusted to between 3250 KW and 3550 KW and maintained for at least ten minutes.

e. Load should be adjusted to between 4150 KW and 4250 KW and maintained for at least ten minutes.

Step 2.4 If the Diesel Generator Es to be loaded, perform the following:

a. Ensure the VOLT REG Switch is in AUTO.

STEP STANDARD:

VOLT REG switch for the B D/G indicates AUTO.

CUES:

Evaluator cue: As CRS direct Exam inee as BOP to load B DG per Note 2.4. Evaluator note: Examinee should request a peer heck.

CoMMENTS:

Tuesdin, April 14, 2015 Page 7 of 14

CRITICAL: Yes SEOUENCED: Yes SAT UNSA T STEP: 7 Step 2.4 b. Place the DG B SYNC SEL switch in DSL.

STEP STANDARD.j DG B SYNC SEL switch indicates DSL.

CUES:

Evaluator note: Examinee should request a peer check.

Evaluator cue: When examinee mentions that he is waiting at least 10 minutes for diesel running at no-load or appears to be paused and waiting the 10 minutes, inform examinee that he may continue with a minimum time compression of I mm. = 10 minutes.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UN4T STEP: 8 Step 2.4 c. Using the VOLT REG RAISE-LOWER Switch adjust Diesel Generator B SYNC VOLTS to slightly higher than 1DB SYNC VOLTS.

STEP STANDARD:

VOLT REG RAISE LOWER switch used to adjust DG B SYNC VOLTS slightly higher than 1DB SYNC VOLTS.

[CUES:

Evaluator note: Examinee should request a peer check.

COMMENTS:

Tuesdti, .4priI 14, 21)15 Page 8 of 14

CR1TIC4L: Yes SEOUENCED: Yes £4 T EJ UNSA T STEP: 9 Step 2.4 d. Using the SPEED Switch adjust Diesel Generator B frequency to cause the SYNCHROSCOPE to rotate slowly in the FAST direction (clockwise).

STEP STANDARD:

I DG B SPEED switch used to adjust DIG speed so that SYNCHROSCOPE rotates slowly in the FAST direction.

CUES:

Evaluator note: Examinee should request a peer check.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes £41 UNSA T STEP: 10 Step 2.4 e. When the SYNCHROSCOPE passes 11 oclock and slowly approaches 12 oclock, close BUS 1DB DG FEED Breaker.

STEP STANDARD:

When synchroscope is between 11 oclock and 12 oclock, closes BUS 1DB DG FEED breaker.

Bus 1DB DG FEED breaker indicates red light ON, green light OFF.

CUES:

Evaluator note: Examinee should request a peer check.

COMMENTS:

Tuesday, April 11, 2015 Page 9 of 14

CRITIC4L: No SEQUENCED: Yes SAT LWSA T STEP: 11 NOTE 2.4.1 Limits per Enclosure B, Diesel Generator Power Factor, should be maintained.

Step 2.4 f. Using the SPEED Switch adjust load as necessary while monitoring the following:

1) KILOWATTS Meter.

2) AMPS Meters.

3) KILOVARS Meter.

STEP ST4NDARD:

DIG B KILOWATTS indicates 850-1000 KWforat least 10 minutes. DG B VOLTS indicates 6840-7344 volts and DG AMPS indicates 100 amps, Kvars indicates 400.

CUES:

Evaluator note: Examinee should be applying the loading schedule described in procedure note 2.4.

Evaluator note: Examinee should promptly load to 850-1000 KW.

Evaluator cue: When examinee mentions that he is waiting at least 10 minutes for pressures and temperatures to stabilize or appears to be paused and waiting the 10 minutes, inform examinee that he may continue with a minimum time compression of 1 mm. = 10 minutes.

COMMENTS:

ixwsda, April 14, 2015 Page 10 of 14

CRITICAL: Yes SEQUENCED: Yes SAT (WSAT STEP: 12 Step 2.4 g. Place the DG B SYNC SEL Switch in OFF.

STEP STANDARD:

DG B SYNC SEL switch indicates OFF.

CUES:

Evaluator note: Examinee should request a peer check.

COMMENTS:

CRiTiCAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 13 Step 2.4 f. (Repeated) Using the SPEED Switch adjust load as necessary while monitoring the following:

1) KILOWATTS Meter.

2) AMPS Meters.

3) KILOVARS Meter.

STEP STANDARD:

D/G B KILOWATTS indicates 2250-2550 KW for at least 10 minutes. DG B VOLTS indicates 6840-7344 volts and DG AMPS indicates 2200 amps and Kvars indicate 1100. DIG B indicates 2250 2550 KW for at least 10 minutes.

CUES:

Evaluator cue: When examinee mentions that he is waiting at least 10 minutes for pressures and temperatures to stabilize or appears to be paused and waiting the 10 minutes, inform examinee that he may continue with a minimum time compression of 1 mm. = 10 minutes.

COMMENTS:

Tuestlav, April 14, 2015 Page 11 of 14

CRITIC4L: Yes SEOUENGED: Yes SAT UNSA T STEP: 14 Step 2.4 f (Repeated). Using the SPEED Switch adjust load as necessary while monitoring the following:

1) KILOWATTS Meter.

2) AMPS Meters. -

3) KILOVARS Meter.

STEP STANDARD:

D/G B KILOWATTS indicates 3250-3550 KW for at least 10 minutes. DG B VOLTS indicates 6840-7344 volts and DG AMPS indicates 290 amps and Kvar indicate 1600. DIG B indicates 3250 -

3550 KW for at least 10 minutes.

CUES:

Evaluator cue: When examinee mentions that he is waiting at least 10 minutes for pressures and temperatures to stabilize or appears to be paused and waiting the 10 minutes, inform examinee that he may continue with a minimum time compression of 1 mi = 10 minutes.

COMMENTS:

Tuesdt,u, April /4, 2(115 Page 12 of 14

CRITIc4L: Yes SEQUENCED: Yes SAT UJVSA T STEP: 15 Step 2.4 1 (Repeated). Using the SPEED Switch adjust load as necessary while monitoring the following:

1) KILOWATTS Meter.

2) AMPS Meters.

3) KILOVARS Meter.

I TEP STANDARD:

DIG B KILOWATTS indicates 4150-4250 KW at 6800-7400 VOLTS and DG AMPS indicates 360 amps and Kvar indicate 2100.

CUES:

Evaluator cue: When examinee mentions that he is waiting at least 10 minutes for pressures and temperatures to stabilize or appears to be paused and waiting the 10 minutes, inform examinee that he may continue with a minimum time compression of 1 mm. = 10 minutes.

COMMENTS:

cRITIcAL: No SEQUENGED: Yes £4 T UNSA T STEP: 16 Step 2.4 h. Using the VOLT REG RAISE-LOWER Switch adjust KILOVARS.

STEP STANDARD:

Using VOLT REG RAISE-LOWER switch, adjusts Kilovars to 2100 CUES:

Evaluator cue: CRS directs adjusting Kilovars to 2100 per SOP-306, Enclosure B.

[COMMENTS:

Examiner ends JPM at this point.

TULsclay, April 14, 2015 Page 13 of 14

JPM SETUP SHEET JPMNO: NJPS-025 (R2)

DESCRIPTION: 2015 NRC Sim e RO: Start and Load B Emergency Diesel Generator ICSET: 10 INSTRUCTIONS:

1. When student is ready; RUN COMMENTS:

JPM Initial Condition of Cylinder Monitoring was intentionally used to prevent requiring STP-125.002 attachments from having to be available. Also to prevent having to have a stopwatch available. This is too much effort to test the same skills as in SOP-306.

luesda, April 14, 2015 Page 14 of 14

JPM BRIEFING SHEET OPERA TOR INSTRtJCTIONS:

SAFETY CONSIDERATIONS:

INITIAL CONDITION:

The plant is operating at 100% power with normal AC power available to all buses.

B DIG is to be started and loaded for monitoring cylinder temperatures using SOP-306 Section IV.B.

Normal and Alternate AC power is available to buses 1 DA and 1 DB.

It is an B2 Maintenance Work Week.

Hourly logging of ESF XFMR FEED KV (MCB) voltage and 1DB VOLTS (MCB) is being performed by another licensed operator per SOP-306,Section IV B step 2.1.

All pre-start check steps have been completed.

IN! TIA TING CUES:

CRS directs you to start and load B DIG to 41 50-4250 KW per SOP-306,Section IV.B, steps 2.3 & 2.4.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

Sim e Handout SO P-306 REVISION 19 B. OPERATION OF DIESEL GENERATOR B FROM THE CONTROL ROOM IN THE TEST START MODE 1.0 INITIAL CONDITIONS A Pre-Job Brief has been conducted per CAP-i 00.3.

The Precautions of Section II have been reviewed.

Diesel Generator B is prepared to start per Section III.

Enclosure F, Tech Spec/EOOS/Functionality Review has been reviewed.

2.0 INSTRUCTIONS 2.1 If XTF0004, UNIT 1 ENGINEERED SAFEGUARD TRANSFORMER, is in service and Diesel Generator B will be paralleled to the 115KV line, perform one of the following (YD-380 SSW):

Immediately prior to and during the time the XTF0006, XTF0004 7.2KV VOLTAGE REGULATOR, AUTO-OFF-MANUAL Switch is placed in MANUAL or OFF, the 115KV and the 7.2KV Bus voltages being supplied from XTF0006 should be monitored continuously. 115KV Bus voltage should be verified and recorded to be within the limits specified in CAP-i 06.1 for the present transformer configuration with the regulator out of service, If the OAP limits are exceeded, the System Controller should be notified to restore 115KV Bus voltage to within the limits.

/5 With XTF0006, XTF0004 7.2KV VOLTAGE REGULATOR in service, perform the following:

/0 1) Monitor ESF XFMR FEED KV (MOB) voltage and either 1 DA VOLTS and/or 1 DB VOLTS (MOB) Bus voltage being supplied from XTF0006.

K 2) Using the Generic Log attachment from CAP-i 06.1, Operating Rounds, record an initial ESF XFMR FEED KV (MCB) voltage and either 1 DA VOLTS and/or 1DB VOLTS (MOB) Bus voltage and then record hourly thereafter.

3/4 3) Place the XTF0006, XTF0004 7.2KV VOLTAGE REGULATOR, AUTO-OFF-MANUAL Switch, in OFF.

PAGE 26 CF 136

SOP-306 REVISION 19 Step 2.1 continued iJ%

El b. With XTF0006, XTF0004 7.2KyQLIAGEREGQtRou0 service ieXO8O8YRV TRANSFER & DISC SWITCHES [° TrariIfSwitch is in the LOAD position.

If Diesel Generator B has been run in the last twenty-four (24) hours, Step 2.2 may be omitted.

2.2 Verify the Diesel Generator B cylinders are free of fluid as follows:

a. At the Main Control Board momentarily place the EXCITER Switch, inSHUTDN. (PEERv)

b. Place the REMOTE/LOCAL/MAINT Switch in MAINT (DB-436).

(PEER v)

c. Verify the fuel injection racks move freely (DB-436).

U. Open all twelve cylinder test cocks (DB-436).

( e. Place the fuel rack in the NO FUEL position by one of the following methods (DB-436):

1) Hold the Stop Lever in the STOP position.

2) Place the Stop Lever in the STOP position and install the Fuel Rack Stop Lever Blocking Device.

PAGE 27 OF 136

SOP-306 REVISION 19 Step 2.2 continued V

(CAUTIOIcI 2.2.f Personnel should stand clear of bith sides of Diesel Generator B when barring the engine due to the exhaust of high pressure air from the test cocks.

(I24 Some discharge from the cylinder test cocks, such as a spray or mist, is to be expected. Excessive discharge which results in accumulation of fluid in the area indicates a potential coolant leak in the cylinders, If excessive fluid is found in one or more cylinders, the Diesel Generator must be declared Inoperable and the appropriate actions taken.

f. While observing the cylinder test cocks to detect the possibility of fluid leakage into the cylinders, bar the engine over by one of the following methods (DB-436):

1) Starting air by momentarily depressing the TEST START Pushbutton.

2) Starting air by using the spanner wrench on the top of one of the Main Air Start Valves on the engine.

3) Barring device motor.

4) Manually, using a wrench attached to the shaft end.

g. Remove the Stop Lever from STOP by one of the following methods (D B-436):

1) If the Stop Lever was held in the STOP position, release the Stop Lever from the STOP position.

/

Fuel Rack Stop Lever Blocking Device was installed, pe a) Remove Blocking Device.

b) Release the Stop Lever from the F h. Close all twelve cylinder test cocks (DB-436).

PAGE 28 OF 136

SO P-306 REVISION 19 Step 2.2 continued Place the REMOTE/LOCAL/MAINT Switch in REMOTE (DB-436).

(PEER V)

j. At the Main Control Board perform the following:

1) Depress the GEN RELAYS RESET Pushbutton.

2) Momentarily place the EXCITER Switch, to RESET.

3) Ensure XCP-637 1-2 (DG B AUTOSTART NOT READY) is NOT in alarm.

CAUTION 2.3 through 2.7 The REM OTE/LOCAL/MAINT Switch should not be operated anytime the Diesel Generator is running.

2.3 To start Diesel Generator B from the Main Control Board perform the following:

a. Ensure the diesel is ready to be started as indicated by the following:

El 1) XCP-637 1-2 (DG B AUTOSTART NOT READY) is NOT in alarm.

2) The READY FOR AUTO START Light is lit at the Diesel Generator B Local Control Panel (DB-436).

El b. Momentarily place the Diesel Generator B TEST Switch to START.

(PEER )

c. Verify the Diesel Generator starts and stabilizes between the following:

1) 58.9 Hz and 61.1 Hz.

2) 6800 volts and 7600 volts.

d. Reset the tripped Diesel Generator B relay flags at the local panel (XCX-5202, DB-436).

PAGE 29 OF 136

SOP-306 REVISION 19 NOTE 2.4 If time permits, the following guidelines should be utilized to achieve the desired load:

a. Prior to closing the Diesel Generator Breaker, the Diesel should be run at no-load for at least ten minutes. -

b. Once the Diesel Generator Breaker is closed, load should be adjusted to between 850 KW and 1000 KW and maintained for at least ten minutes.

c. Load should be adjusted to between 2250 KW and 2550 KW and maintained for at least ten minutes.

d. Load should be adjusted to between 3250 KW and 3550 KW and maintained for at least ten minutes.

e. Load should be adjusted to between 4150 KW and 4250 KW and maintained for at least ten minutes.

2.4 If the Diesel Generator is to be loaded, perform the following:

a. Ensure the VOLT REG Switch is in AUTO. (PEER it)

b. Place the DG B SYNC SEL Switch in DSL. (PEER it)

c. Using the VOLT REG RAISE-LOWER Switch adjust Diesel Generator B SYNC VOLTS to slightly higher than 1 DB SYNC VOLTS.

(PEER it)

d. Using the SPEED Switch adjust Diesel Generator B frequency to cause the SYNCHROSCOPE to rotate slowly in the FAST direction (clockwise). (PEER /)

e. When the SYNCHROSCOPE passes 11 oclock and slowly approaches 12 oclock, close BUS 1DB DG FEED Breaker. (PEER /)

PAGE 30 OF 136

SOP-306 REVISION 19 Step 2.4 continued NOTE 2.4.f Limits per Enclosure B, Diesel Generator Power Factor, should be maintained.

f. Using the SPEED Switch adjust load as necessary while monitoring the following:

El 1) KILOWATTS Meter.

El 2) AMPS Meters.

El 3) KILOVARS Meter.

El g. Place the DG B SYNC SEL Switch in OFF. (PEER v)

El h. Using the VOLT REG RAISE-LOWER Switch adjust KILOVARS.

CAUTION 2.5 While operation in this configuration is not prohibited by Tech Specs, the time spent separated from Offsite Power should be limited to that required for troubleshooting.

2)f it is desired to divorce XSW1DB from Offsite Power, perform the following:

El Utilizing Enclosure D estimate the present load on XSW1 DB.

El b. Usitte SPEED Switch adjust Diesel Generator B load until the estimatedXSWl DB load is being carried by Diesel Generator B.

El c. Open one of theflowing as appropriate for the Offsite Power source currently in parallel witithe Diesel Generator: (PEER v)

1) BUS 1DB NORM FEeker.

2) BUS 1 DB ALT FEED Breaker.

El d. Using the SPEED Switch, adjust Diesel Generatoanecessary to maintain frequency between 59.5 Hz and 60.5 Hz.

PAGE 31 OF 136

SOP-306 REVISION 19 te 2.5 continued

< Using the VOLT REG RAISE-LOWER Switch adjust Diesel Generator B as necessary to maintain voltage between 6800 VAC and 7.600 VAC.

f. Whtime permits, perform the following:

1) DireTh&ç to connect a Fluke 45 DMM to the back of Main Control B&açd meter DG B VOLTS (V-DGB) with the following settings (insidMCB):

a) AC volts.

b) AUTO.

c) Medium rate.

LI 2) Using the VOLT REG RAISE-LOWER Swit adjust Diesel Generator B as necessary to maintain voltagétetween 114.67 VAC and 122.90 VAC by Fluke 45 indicatibq connected at the MCB (between 6880.1 VAC and 7373.8VAC).N 2.6 If the Diesel Generator Breaker is closed and Diesel Generator B is no longer required as a source of power, perform one of the following:

a. If the Diesel Generator is the only power source supplying XSW1 DB, perform the following to parallel with Offsite Power:

1) Place the DG B SYNC SEL Switch in one of the following positions as appropriate: (PEER V) a) NORM allows paralleling with the 230 KV offsite source.

b) EMERG allows paralleling with the 115 KV offsite source.

LI 2) Using the VOLT REG RAISE-LOWER Switch, adjust Diesel Generator B 1 DB SYNC VOLTS to slightly lower than SYNC VOLTS. (PEER .V)

3) Using the SPEED Switch, adjust Diesel Generator B frequency to cause the SYNCHROSCOPE to rotate slowly in the SLOW direction (counter-clockwise). (PEER V)

PAGE 32 OF 136

SOP-306 REVISION 19 Step 2.6.a continued

4) When the SYNCHROSCOPE indicator passes 1 oclock and slowly approaches 12 oclock, close one of the following as appropriate for the synchroscope position selected: (PEER v) a) BUS 1DB NORM FEED Breaker.

b) BUS 1 DB ALT FEED Breaker.

5) Place the DG B SYNC SEL Switch in OFF. (PEER f)

NOTE 2.6.b If time permits, the following guidelines should be utilized to unload the Diesel Generator:

1) Load should be reduced to between 2150 KW and 2550 KW and maintained for three to five minutes.

2) Load should be reduced to between 850 KW and 1250 KW and maintained for three to five minutes.

3) Load should be reduced to 50 KW.

b. If the Diesel Generator is running in parallel with an Offsite Power source, perform the following:

1) Unload Diesel Generator B by holding the SPEED Switch in LOWER until load is 50 KW.

2) Using the VOLT REG RAISE-LOWER Switch, reduce KILOVARS to minimum.

3) Open BUS I DB DG FEED Breaker. (PEER V)

4) Ensure DG B VOLTS indicates between 6800 volts and 7600 volts.

5) Momentarily place the EXCITER Switch in SHUTDN.

(PEER v)

PAGE 33 OF 136

SOP-306 REVISION 19 Step 2.6.b continued NOTE 2.6.b.6)

The VOLT REG RAISE-LOWER Switch should NOT be adjusted for the remainder of this procedure.

6) Verify the steady-state, no-load, voltage for Diesel Generator B as follows:

El a) Momentarily depress the EM ERG START Pushbutton.

(PEER /)

El b) Verify DG B VOLTS indicates between 6800 volts and 7600 volts.

El c) Momentarily depress the EMERG START OVRRIDE Pushbutton. (PEER fl El U) Momentarily place the Diesel Generator B TEST Switch, in START. (PEER 1) 2.7 To return Diesel Generator B to standby status perform the following:

El a. Momentarily place the EXCITER Switch in SHUTDN. (PEER )

El b. Momentarily place the TEST Switch in STOP. (PEER /)

El c. Unless otherwise directed prepare Diesel Generator B for automatic/manual operation by performing the appropriate steps of Section III.

2.8 If Diesel Generator B has been run for greater than or equal to an hour, perform the following steps to check for and remove any accumulated water in XTKOO2OB-DG, DG FUEL OIL DAY TANK B (DB-436):

El a. If required, install a drain hose between XVT30955-DG, HI ISOL VLV FOR TEST CONNECTION, and a suitable container.

El b. Throttle open XVT30955-DG, HI ISOL VLV FOR TEST CONNECTION.

El c. Unlock and throttle open XVTOO99OB-DG, DG FUEL OIL DAY TANK B DRAIN VALVE.

PAGE 34 OF 136

SOP-306 REVISION 19 Step 2.8 continued

d. When Diesel Generator B Day Tank is free of water, perform the following:

1) Close XVTOO99OB-DG, DG FUEL OIL DAY TANK B DRAIN VALVE.

2) Lock XVT0O99OB-DG, DG FUEL OIL DAY TANK B DRAIN VALVE.

3) Close XVT30955-DG, HI ISOL VLV FOR TEST CONNECTION.

4) If necessary, remove the drain hose from XVT30955-DG, HI ISOL VLV FOR TEST CONNECTION.

NOTE 2.9

a. XTF0005, UNIT 2 ENGINEERED SAFEGUARD TRANSFORMER, must be in standby prior to placing XTF0006, XTF0004 7.2KV VOLTAGE REGULATOR, in AUTO.

b. If the Band Indicator HIGH or LOW light is lit, the Voltage Regulator will step immediately when placed in AUTO.

2.9 If AUTO operation is desired, place the XTF0006, XTF0004 7.2KV VOLTAGE REGULATOR, AUTO-OFF-MANUAL Switch in AUTO and stop recording hourly Bus Voltage readings (YD-380 SSW).

2.10 If previously installed, direct I&C to disconnect the Fluke 45 DMM from V-DGB (inside MCB).

END OF SECTION PAGE 35 OF 136

SOP-306 ENCLOSURE B PAGE 1 OF 2 REVISION 19 DIESEL GENERATOR POWER FACTOR NOTE 1: This is the preferred graph for Power Factor determination since the values are independent of voltage Do not operate in this zone NOTE 2: The machine should normally be operated with a Lagging Emergency operation or Power Factor (KVAR OUT). as directed by procedure 0.70 0.75 5000 4500 p 4000 3500 3000

< 2500 0

-J w 2000 I

ci 1500 LU fl 1000 500 0

2500 3000 3500 REAL POWER (KW)

SOP-306 ENCLOSURE B PAGE 2 OF 2 REVISION 19 DIESEL GENERATOR POWER FACTOR EMERGENCY OPERATION POWER FACTOR 6000 DO NOT OPERATE IN THIS o 075 0.70

j. r N 5000 D

i 4250

_I______

c 4000 3000 2000 L

0 A 1000 D

0 0 100 200 300 400 470 500 600 700 AVERAGE INDICATED PHASE CURRENT NOTE 1: The values on this graph are based on generator voltage of 7200 volts.

A higher voltage results in a high Power Factor and a lower voltage results in a lower Power Factor. These variations will fall within a +/- 10% range.

NOTE 2: If current increases with Voltage Regulator increase, Power Factor is lagging.

If current decreases with Voltage Regulator increase, Power Factor is leading.

NOTE 3: When in the Test Start Mode the Diesel Generator Output Breaker trips on Overcurrent (51VDG Relay) at 480 amps.

V. C. SUMMER NUCLEAR STA nON JOB PERFORMANCE MEASURE J?MNO: NJPS-I 000 (RI) 2015 NRC Sim f RO: Respond to Steam Genetor Pressure Channel Failure CAN DIDATL EXAM IN ER:

iltondci, April 13, 2015 Page 1 0/ 11

TASK:

000-1 03-05-01 Respond to Excessive Feedwater Increase per AOP-401.3 TASK STANDARD:

SG B level restored to between 60-65% such that an unnecessary plant trip is avoided and the failed channel (PT-485) has been correctly identified.

TERi11IN4TL7VG CUE: SG B level is under control and the failed channel has been correctly identified.

PREFERRED EVAL UA TIOiV L O4 TION PREFERRED F VALUATION ME THOL SIMULATOR PERFORM

REFERENCES:

SOP-401 REACTOR PROTECTION AND CONTROL SYSTEM AOP-401 .3 STEAM FLOW-FEEDWATER FLOW PROTECTION CHANNEL FAILURE INDEX NO. K/A NO. RO SRO 059000A21 1 A2.11 Failure of feedwater control system 3.0 3.3 TOOLS: AOP-401 .3, Steam Flow Feedwater Flow Protection Channel Failure EVALUATION TIME 10 TIME CRITICAL 10CfR55: 10CFR55.4 TIME START. TIME FINISH. PERFORMANCE TIME:

PERFORMANCE RATING: SAT. I JN S AT CANDIDA TE:

EXAMINER:

SIGNA[I]RE HA FE 1Io,u!a, 1pril 13, 2015 Page 2 of 11

INSTRUCTIONS TO OPERA TOR READ To OPERA TORt WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFUJrLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

£4FETY CONSIDERATIONS: None INITIAL CONDITION: The plant is operating at 100% power with all controls in automatic.

INITIATING CUES: Respond to developing plant conditions.

HAND .JPM BRIEFING SHEET TO OPERA TOR AT THIS TIME!

Io,ului, April 13, 2015 Puge 3 of ii

t STEPS CRITIC A L: No SEQUENCED: Yes SAT UNg4T STEP: 1 Step 1. Verify the failed channel is the controlling channel.

STEP STANDARD:

Fl-484 indicates 5 MPPH, P1-485 indicates 1300 psig. Examinee notes Fl-484 is the controlling channel.

CUES:

Evaluator cue: When Examinee has accepted turnover and has completed board walk down signal Booth Operator to activate Event #1.

Evaluator note: This is an immediate operator action.

COMMENTS:

,lIo,,dc,, April 13, 2015 Page 4 ./ 11

CRITIC4L: Yes $EOUENCED: Yes SAT UNSA T fcrEP: J 2 Step 2. Select the operable flow channel:

Place FW CONTROL CHANNEL SEL Switch to the operable channel.

Place STEAM CONTROL CHANNEL SEL Switch to the operable channel.

STEP STANDARD:

Places FW CONTROL CHANNEL SEL switch and STEAM CONTROL CHANNEL SEL switch to the opposite position.

CUES:

Evaluator note: This is an immediate operator action.

Evaluator note: This step is critical to remove the failed channel from control and to restore B SG level to program value (60-65%) such that an unnecessary plant trip is avoided.

[COMMENTS:

11o,,dm, April 13, 2015 Pages oil!

CRITICAL: No SEQUEiWED: Yes SAT UIVSA T STEP:] 3 NOTE Step 3 CTRL+ALT+S on either EHC HMI is equivalent to 50 MWe, and is the preferred method to accomplish a rapid load reduction.

Step 3. Verify turbine load LESS THAN 950 MWE.

Alternative Action 3. Using any method available reduce Turbine Load by 4OMWe to 50 MWe.

STEP STANDARD:

Observes> 950 MWE and reduces turbine load by 40 MWE to 50 MWE.

CUES:

Evaluator note: This is an immediate operator action.

Evaluator Note : This step could become critical on a case by case basis depending on the magnitude of the resulting Feedwater transient.

COMMENTS:

(RITIC 4 L: No SEOUEiVcED: Yes £4 T UASA T STEP: 4 Step 4. Verify only one SG AFFECTED.

STEP STANDARD:

Verifies only B SG affected.

CUES:

Evaluator note: This is an immediate operator action.

Evaluator note: The failed channel does input to Feedwater Pump Speed Control and thus may have some slight impact on A and C SG level as well as B SG. It is not expected that there will be any appreciable impact on A or C SG levels.

COMMENTS:

iliondtxp, April 13, 2015 Page 6 of]!

(RITIC4L: Yes SEQUEN(ED: Yes SAT UNSA T tSTEP: 5 Step 5. Adjust the Feedwater Flow Control Valve as necessary to restore feed flow to the AFFECTED 5G.

STEP STANDARD:

Manually controls the SG B FWC controller as necessary to restore SG B level.

CUES:

Evaluator note: This is an immediate operator action.

Evaluator note: Typically this step does not require any operator action once an operable channel is selected. Examinee may place Feedwater Flow Control Valve in manual and lower flow to obtain program SG level.

Evaluator note: This step is critical if the examinee is slow in selecting the operable SF and FF channels and SG NR level has exceeded 70% (approaching Hi Hi level Turbine trip)

COMMENTS:

1Th,itlt,j, .4pril 13, 2015 Page 7o111

cRITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 6 Step 6. Check if Feedwater Pump speed control is operating properly:

Feedwater Header pressure is GREATER THAN Main Steam Header pressure.

Feed flow is normal for steam flow and power level.

All operating Feedwater Pump speeds and flows are balanced.

STEP STANDARD:

Verifies:

-FW Header Pressure> Main Steam Header Pressure.

-FW flow is normal.

-All operating FWP speeds and flows ate balanced.

CUES:

Evaluator note: This is an immediate operator action.

Evaluator cue: As CR5 provide a copy of AOP-401 .3 and direct Examinee to complete AOP-401 .3 through step 9. Examinee should reference the AOP for remaining actions.

Evaluator note: The failed Steam Pressure Channel affects the controlling Steam Flow Channel which in turn feeds into the program value for Main Feedwater Pump Delta P. Once the examinee has selected the non-failed Steam Flow channel the program Delta P will return to normal and Main Feed Pump speed should restore to normal without any Operator Action. Examinee may place Main Feedpump Speed Control in manual and lower FW Flow and FW Header pressure to obtain program SG level.

COMMENTS:

1Io,idtij, April 13, 2015 tage 8 o/ 11

CRITICAL: No SEOUENCED: Yes SAT UNSA T STEP: 7 Step 7. Verify Narrow Range levels in all SGs are between 60% and 65%.

Alternative Action 7. Adjust the Feedwater Flow Control Valve as necessary to restore feed flow to the AFFECTED SG(s).

STEP STANDARD:

Restores and maintains B SG level to between 60% and 65% in Manual as necessary.

CUES:

Evaluator note: It is not expected that candidate will need to take manual control of the Feedwater Flow Control Valve or Feedwater Pump Speed control for this failure.

COMMENTS:

CRITIC4L: No SEQUENCED: Yes SAT UN4 T STEP: 8 Step 8. Restore the AFFECTED SG control systems to normal:

Place the Feedwater Flow Control Valve in AUTO.

Place the Feedwater Pump Speed Control System in AUTO. REFER TO SOP-210, FEEDWATER SYSTEM.

STEP STANDARD:

Ensures Feedwater Control Valve is in automatic and Feedwater Pump Speed Control is in automatic CUES:

Evaluator note: It is expected that the Feedwater Flow Control Valve and the Feedpump Speed Control will have remained in automatic for this failure.

COi11MENTS.

April 13, 2015 Pugt 9 of]!

CRITICAL: No SEOUENCED: Yes SAT UJVSA T STEP:] 9 Step 9 a. Identify the associated bistables for the failed channel. REFER TO AOP 401.3, Attachment 1.

STEP STANDARD:

Examinee identifies instrument PT-485 (Compensates FT-484).

CIJES:

Evaluator Cue: Have examinee identify the failed channel by pointing out the correct instrument number (P1-485) on AOP-401 .3 Attachment 1.

Evaluator note: Annunciator XCP-624; 4-1, SG A STMLN oP HI and 6-1, SG C STMLN oP HI are providing alternate indication that the failure was a pressure channel and not the corresponding steam flow channel.

Evaluator note: The task of completing the bistable tripping data sheet (SOP-401 Attachment 1) is performed by SROs with a Shift Engineer review.

COMMENTS:

Examiner ends JPM at this point.

ito,,dap, April 13, 2015 Page 10 qilt

JPM SETUP SHEET JPMNO: NJPS-1000 (Ri)

DESCRIPTION: 2015 NRC Sim I RO: Respond to Steam Generator Pressure Channel Failure ICSET: 315 INSTRUCTIONS:

If IC 315 is designated for this JPM then reset to IC-31 5 leaving the simulator in FREEZE.

1. When Examinee is ready (on Evaluator cue) go to RUN

2. On evaluator cue activate Event #1 If IC 315 is not designated for this JPM then initial conditions may be established by reseting to IC 10 and following the below directions:

1 Insert: MAL-MSSOO1 E Final Value = 1 300, Ramp = 3 sec (SG PT 485 Fail) set to Event #1

2. When Examinee is ready: RUN

3. On evaluator cue activate Event #1 COMMENTS:

31o,,dav, April 13, 2015 Page 11 oil!

JPM BRIEFING SHEET OPERA TOR iNSTRUCTIONS:

SAFETY CONSIDERA TIONS: None INITIAL CONDITION: The plant is operating at 100% power with all controls in automatic.

INITL4TING CUES: Respond to developing plant conditions.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPS-084 (RI) 2015 NRC Sim g RO: Restore Spent Fuel Pool Level During Refueling CANDlDiV1I:

1XAM1NER ltoudav. 4pri1 13. 2015 Page 1 of 10

TASK:

000-1 40 01 RESPOND TO DECREASING WATER LEVEL IN THE SPENT FUEL POOL OR REFUELING CAVITY PER AOP-123.5/AOP-123.1.

T4SK STANDARD:

Spent Fuel Pool Level greater than or equal to 460 ft 6 inches on LI-7431 and LI-7433.

TERiVIINATING CUE: Spent Fuel Pool Level greater than or equal to 460 ft 6 inches on Ll-7431 and LI-7433.

PREFERRED EVALUATION LOCATION PREFERRED EVALUATION METHOL SIMULATOR PERFORM

REFERENCES:

AOP-1 23.1 DECREASING LEVEL IN THE SPENT FUEL POOL OR REFUELING CAVITY DURING REFUELING INDEX NO. K/A NO. RO SRO 033000A203 A2.03 Abnormal spent fuel pool water level or 3.1 3.5 loss of water level TOOLS: AOP-123.1 marked up through step 10.

EVALUATION TIME 10 TIME CRITICAL No lt)CFRS5: 45(a)(7) liME SIAR1 IEiE FINISI 1. PER! ORMANQE lIME:

PERFORMANcE RATING: SAl UNSAF:

C4NDJDA TE:

EXA MINER:

SIGNATURE DATE lloudt:v, ApnI 13, 2015 Page 2 flU

INSTRUCTIONS TO OPERA TOR READ TO OPERATOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SA fETI CONSIDERATIONS:

INITIAL CONDITION: The Plant is in MODE 6 with Core Off Load in Progress. The A RHR Loop is in service providing Core Cooling. AOP-123.1 has been entered due to lowering level in the Spent Fuel Pool. The leakage was isolated in step 8. The A RHR Train has been verified as intact.

INITL4TIVG CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CRS has directed you as the ROATC, to respond to a lowering level in the Spent Fuel Pool in accordance with AOP-J 23.1 starting with Step JO.

H.4ND JPM BRIEFING SHEET TO OPERA TO!? AT THIS TIME!

lloiulu. April 13, 2015 Pt,ge 3 of 10

STEPS (JRITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 1 Step 10 a: Check if the operating RHR train is intact.

STEP STANDARD: .

Verifies normal pump amps and flow on A RHR pump.

CUES:

Evaluator cue: Provide the marked up copy of AOP-1 23.1, Decreasing Level in the Spent Fuel Pool or Refueling Cavity at this time.

Evaluator note: The A RHR Train was described as intact in the initiating cue.

fcoilIMENTs:

CRITICAL: Yes SEQUENCED: Yes SAT UN4T STEP: 2 Step 10 b: Open MVG-8809A(B), RWST TO RHR PP A(S).

STEP STANDARD:

Opens MVG-8809A, RWST TO RHR PP A, and verifies Red light ON and Green light OFF.

CUES:

Evaluator note: This step is critical because opening MVG-8809A assures that the A RHR pump has a suction source and that RHR can add inventory to the RCS.

(Th1itWENTS:

lIo,itk,v, .4prll 13, 2015 Page 4 tf 10

CRITIC4L: Yes SEQUENCED: Yes SAT i:ii UNSA T STEP: 3 Step 10 c: Close MVG-8701A(B), RCS LP A(C) TO PUMP A(S).

STEP STANDARD:

Closes MVG-8701A, RCS LP A TO PUMP Aand verifies Red light OFF and Green light ON CUES:

Evaluator note: This step is critical because closing MVG-8701A or MVG-8702A assures that the RHR suction source is the RWST and not the Refueling Cavity.

COMMENTS:

cRITIc4L: Yes SEQUENCED: Yes SAT i:ii UNSA T STEP: 4 Step 10 d: Close MVG-8702A(B), RCS LP A(C) TO PUMP A(S).

STEP STA NDARD:

Closes MVG-8702A, RCS LP A TO PUMP A and verifies Red light OFF and Green light ON CUES:

Evaluator note: This step is critical because closing MVG-8701A or MVG-8702A assures that the RHR suction source is the RWST and not the Refueling Cavity.

COMMENTS:

4loi,dt,p, April 13, 20l5 PageS o/1O

CRITICAL: No SEQUEN(ED: Yes SAT UNSA T STEP: 5 Step 10 e: Close HCV-603A(B), A(B) OUTLET.

STEP STANDARD:

Closes HCV-603A, A OUTLET, by turning potentiometer to zero (0).

CUES:

OMMENTS:

CRITIC I L: Yes SEQUENCED: Yes SAT UN4T STEP: 6 Step 10 1: Adjust FCV-605A(B), A(B) BYP, as necessary to establish the desired refueling water level.

STEP ST4NDARD:

lakes manual control of FCV-605A and controls flow to raise SFP level.

CUES:

Evaluator note: This step is critical because FCV-605A must remain open in order to assure a discharge flow path from the RHR pump to the refueling cavity/spent fuel pool.

C()WMENTS:

lto,,dt,i. April 13, 2015 Page 6 of 10

CRITIC4L: No SEQUENCED: Yes SAT UNSAT STEP: 7 Step 10 g: Ensure the associated Component Cooling train is operating. REFER TO SOP-118, COMPONENT COOLING WATER.

STEP STANDARD:

Verifies A CCW pump is running with normal pump amps and flow. Verifies A CCW is the active loop by verifying MVB-9524N9526A, LP A NON-ESSEN LOAD ISOL, and MVB-9687N9525A, LP A NON-ESSEN LOAD ISOL, are open, and by verifying MVB-9524B19526B, LP B NON-ESSEN LOAD ISOL, and MVB-9687B/9525B, LP B NON-ESSEN LOAD ISOL, are closed CUES:

Evaluator note: JPM may be terminated at Evaluator discretion any time after Examinee verifies rising Spent Fuel Pool level.

COMMENTS:

CRITJCiI L: No SEQUENCED: Yes £1 T UNSA T STEP: I 8 Step 10 h: Verify CCW flow through the RHR Pump A(B) Seal Cooler:

FM-7245, A RHR PP (1UR14400, M3/SW 5-3).

FM-7255, B RHR PP (1UR14401, M415W5-3).

STEP STANDARD:

Verifies flow indicated on FM-7245, flow recorder for RHR Pump A CUES:

COMMENTS:

1lIondav. Apr11 13, 2015 Page 7 of 10

CRITICAL: No SEQUENCED: Yes SAT UNSAT

[57EP: 9 Step 11: Locally align the Spent Fuel Cooling System to fill the Spent Fuel Pool via Spent Fuel Cooling Pump B. REFER TO SOP-123, SPENT FUEL COOLING SYSTEM.

STEP STANDARD:

Directs building operator to align Spent Fuel Cooling to fill the SFP from the RWST per SOP-I 23.

CUES:

Booth Operator cue: Inform Examinee as the building operator that you acknowledge the order to align Spent Pool Fuel Cooling to fill the Spent Fuel Pool.

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT UNSAT STEP: J 10 Step 12: Verify that Refueling Cavity AND Spent Fuel Pool level is recovering.

STEP ST4tVDARD:

Verifies that Spent Fuel Pool level on Ll-7431/7433 is increasing.

CUES:

Booth Operator cue: If examinee calls a building operator to verify Refueling Cavity Level, report that it is rising provided Examinee has observed Spent Fuel Pool level as rising on LI-743117433.

CoMMENTS:

lIo,,daj, .4pril 13, 2015 2 of 10

CR1 TICAL: No SEQUENCED: Yes SAT UNSA T STEP:J 11 Step 13: Check if Refueling Cavity AND Spent Fuel Pool level is adequate:

a. Refueling Cavity level is GREATER THAN OR EQUAL TO 460 ft 6 inches.

b. Spent Fuel Pool level is GREATER THAN OR EQUAL TO 460 ft 6 inches STE?STAADARD:

Verifies that Spent Fuel Pool level on Ll-743117433 is GREATER THAN OR EQUAL TO 460 ft 6 inches.

Verifies that Refueling Cavity level on Ll-7403 and or Mansell is GREATER THAN OR EQUAL TO 460 ft 6 inches (UES:

Booth Operator cue: If examinee calls a building operator to verify Refueling Cavity Level, report that it is 460 ft 6 inches once Spent Fuel Pool level is observed as 460 ft 6 inches on Ll-7431/7433.

COMMENTS:

Examiner ends JPM at this point.

lIo,uk,p. April 13, 2015 Pttge 9 of 10

JPM SETUP SHEET JPMIVO: NJPS-084 (Ri)

DE$CRIPTIOiV: 2015 NRC Sim g RO: Restore Spent Fuel Pool Level During Refueling ICSET: 316 INSTRUCTIONS:

If IC-316 is designated for this JPM then reset to IC-316 leaving the simulator in FREEZE.

1. Select shutdown from ZZMENU on MCB1 IPCS screen.

2. IF available, set up Mansell Level monitoring cart at the CCW end of the Main Control Boards. IF available Turn on CRS SIPCS screen by typing MLMSA or MLMSB from any SIPCS screen. IF the SIPCS function is NOT enabled just set up the computer cart for Mansell Indication.

3. Place red tags on RB spray pumps, PZR Back up heaters

4. When Examinee is ready (on Evaluator cue) go to RUN.

If lC-316 is not designated for this JPM then initial conditions may be established by reseting to IC-379 and following the below directions:

1. Insert: MAL-RHROO5A Final Value = 3000 (RHR bypass line leak)

OVR-AAO28 Override To = True (Override Radiation Monitoring Panel Annunciators)

LOA-AUX1 35 Position To = NORMAL (SS-SF1O Refuel Cavity Level Alarm Bypass Switch)

ANN-SFO1 0 Fail To = ON (Fuel XFER Canal LVL HI/LO)

ANN-SFO1 0 Fail To = OFF (New) tied to trigger 1 Set Trigger 1 to X03D022A>461 (Refuel Cavity level greater than 461

2. Verify: LOA-FHBOO1 Final Value = 1 (Fuel Transfer Tube Isolation Open)

LOA-FHBOO2 Final Value = 1 (Spent Fuel Gate to Transfer Tube Open)

3. RUN

4. When refueling cavity/SFP levels indicate < 460 feet, FREEZE

5. Set MAL-RHROO5A Final Value = 10

6. Select shutdown from ZZMENU on MCB1 IPCS screen

7. IF available, set up Mansell Level monitoring cart at the CCW end of the Main Control Boards. IF available Turn on CRS SIPCS screen by typing MLMSA or MLMSB from any SIPCS screen. IF the SIPCS function is NOT enabled just set up the computer cart for Mansell Indication.

8. Place red tags on RB spray pumps and PZR Back up heaters.

9. When Examinee is ready (on Evaluator cue): RUN COMMENTS:

Note as of April 1, 2015 Mansell was not correctly modeled for refuel cavity full. A Simulator DR was written as part of the ILO 13-01 NRC exam prep.

1oittla, .lpril 13. 2015 Ptige 10 of 10

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSWERA TIONS:

IiVITIAL CONDITIO[sJ: The Plant is in MODE 6 with Core Off Load in Progress.

The A RHR Loop is in service providing Core Cooling.

AOP-123.1 has been entered due to lowering level in the Spent Fuel Pool.

The leakage was isolated in step 8.

The A RHR Train has been verified as intact.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

The CRS has directed you as the ROATC, to respond to a lowering level in the Spent Fuel Pool in accordance with AOP-123.1 starting with Step 10.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPS-IOOI (RI) 2015 NRC Sim h RO: Establish Reactor Building Purge Supply and Exhaust CANDIDATE:

IiXAvIINER.

iucsdu, April 14, 2015 Page 1 of 16

TASK:

088-505-01 -04 Perform Line ups of the Reactor Building Ventilation Systems.

TASK STANDARD:

The RB Purge System is in service with at least one Purge Exhaust Fan and no more than one Purge Supply Fan started.

TERMIiVATING CUE: The RB purge system is in service.

PREFERRED EVALUATION L 0C4 TION PREFERRED EVALUATION ME THOL SIMULATOR PERFORM

REFERENCES:

CAP-i 00.5 GUIDELINES FOR CONFIGURATION CONTROL AND OPERATION OF PLANT EQUIPMENT H PP-709 Sampling and Release of Radioactive Gaseous Effluents SOP-i 14 REACTOR BUILDING VENTILATION SYSTEM INDEX NO. K/A NO. RO SRO 029000A201 A2.01 Maintenance or other activity taking place inside containment 2.9 3.6 TOOLS: JPM h Handout 1 Marked up copy of SOP-114, Reactor Building Ventilation System.

JPM h Handout 2; HPP-709 Attachment VI, Reactor Building Purge Release Permit.

JPM h Handout 3; CAP-i 06.3 Attachment II Locked Component Operating Sheet.

Copy of HPP-709, Sampling and Release of Radioactive Gaseous Effluents.

Four yellow plastic Test in Progress tags for Plant Status labeling on RM-A2 and RM-A4 sample pump CMC switches and Containment isolation valves PVA-93i2A(B) CMC switches.

Red hold tag for placement on XFN-i 3B, EXH FAN B.

EV4L VA TION TIME 30 TIME CRITICAL NO IOCFRSS: 45(a)f 8)

TIME START: TIME FINISH PFRfORvIANCE TIME PERFORMANCE K4 TING: SAT: JNSAT:

CANDIDA TE:

EXI MINER:

SIGNATURE I)ATE Thesdin, .-lpril 14, 2(115 Page 2 of 16

INSTRUCTIONS To OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS: None INITIAL CONDITION: The plant is in Mode 5 with preparations for a refueling outage in progress The equipment hatch is open.

The RB atmosphere sample analysis has been completed.

The RM-A2 and RM-A4 setpoints have been adjusted for this release and source checks are completed on both channels.

Plant status labels have been placed on the radiation monitoring equipment required for RB ventilation operability; RMA-2 and RMA-4.

Reactor Building Purge had been in service but was shutdown on the previous shift.

Reactor Building Purge Exhaust Fan, XFN-13B is tagged out for corrective maintenance.

iNITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

You are being directed to place Reactor Building Purge in service using SOP-114, Reactor Building Ventilation System Section III.C All applicable procedure Initial Conditions are completed.

1-LIND JP1I BRIEFING SHEET TO OPERA TOR .41 THIS TIME!

Thesda, .-Iprit 14, 2(115 Ptige 3 of 16

STEPS CRITICAL: No SEQ UEiVCED: Yes SAT UNSA T 1

Step 2.1; Ensure RMA0004, ATM GASEOUS IODINE-RB PURGE EXHAUST (gas channel) is in service fRaU Monitoring Panel).

STEP STANDARD:

Ensures RMA-4 is in service by checking for power and indication at Rad Monitoring Panel.

CUES:

Evaluator cue: Once the examinee acknowledges the initiating cue provide them the marked copy of SOP-114, Reactor Building Ventilation System (JPM h Handout 1) and HPP-709, Attachment VI Reactor Building Purge Release Permit (JPM h Handout 2).

Evaluator note: If Examinee becomes distracted by annunciators on Main Control Board that are NOT related to the task of placing purge in service, then cue that plant monitoring will be assigned to a surrogate operator.

COMMENTS:

Tuesth,, April 14, 2(115 Page 4 of 16

CRITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 2 Step 2.2; If core alterations are in progress, ensure RMA0002, ATM GASEOUS IODINE RB SAMPLE LINE (gas channel), is in service (Rad Monitoring Panel).

STEP STANDARD:]

Marks step N/A and proceeds to step 2.3.

CUES:

Evaluator note: Since Unit is NOT in Mode 6 and no core alterations are in progress Steps 2.2 (Check of RMA-2) is N/A. Examinee may mark step complete as RM-A2 is in service and will be required in service once core alterations begin.

COMMENTS:

Tuesthiv, April 14, 2/115 Page 5 of 16

CRITIC4L: No SEQUENCED: Yes SAT UNSAT STEP: 3 Step 2.3; If RB atmosphere sample analysis dictates, place RB Charcoal Cleanup System in service per Section III.

a. XFN-66A, FAN A (RB CHAR CLEANUP).

b. XFN-66B, FAN B (RB CHAR CLEANUP).

STEP ST4NDARD:

Marks step N/A and proceeds to step 2.4 CUES:

Evaluator cue: Inform Examinee as HP that RB atmosphere sample analysis does NOT dictate Charcoal Cleanup.

COMiIiENTS:

Tuestlt,v, .-Iprit /4, 2015 Page 6 af 16

CRITIC4L: No SEQUENCED: Yes SAT UNSAT STEP: 4 Step 2.4; Align RMA0004 sample point for RB Purge Exhaust Fan operation as follows (AB-485):

a. Open XVA00006-AH, RMA0004 SAMPLE INLET ISOLATION VALVE.

b. Close XVA00005-AH, RMA0004 SAMPLE INLET ISOLATION VALVE.

STEPSTAiVD,4RD:

Calls Building operator and directs OPEN XVA-6-AH and CLOSE XVA-5-AH.

CUES:

Booth Operator cue: As Building Operator acknowledge request for sample valve alignment or verification and report task completed per the request. Use time compression for response.

Evaluator note: Since Purge had previously been in service the building operator may only be asked to verify sample valve alignment correct.

COMMENTS:

Thesc!av, April 14, 2015 Page 7o1 16

CRITIC4L: No SEOUENQED: Yes SAT UN&4 T STEP: 5 Step 2.5; Ensure the following radiation monitors high radiation alarm setpoints are adjusted per Reactor Building Purge Release Permit:

a. RMA0002, ATM GASEOUS IODINE RB SAMPLE LINE.

b. RMA0004, RB PURGE EXH GAS ATMOS MONITOR.

STEP STANDARD:

Ensures setpoint on RMA-2 and RMA-4 at Rad monitor panel match the Purge Release Permit values.

CUES:

Evaluator cue: Provide simulated Reactor Building Purge Release Permit, HPP-709, Attachment VI, (NJPS-1 001 Handout) if not already done.

Evaluator note: This was provided as complete in the initial conditions. The simulator does not model setpoint changes. Provide following cue if needed.

Evaluator cue: If asked as CRS state that the alarm setpoints have been verified by another RO.

COMMENTS:

Tu.sda, April 14, 2015 Puge 8 of 16

cRITIC4L: No SEQUENCED: Yes SAT UNSAT STEP: 6 Step 2.6; Prior to placing RB Purge System in operation for the first time during an outage, perform STP-130.005B, AH Valve Operability Testing (Mode 5).

STEP STANDARD:

Marks step N/A and proceeds to step 2.6.

CUES:

Evaluator note: Initiating cue provided information that RB Purge had been in service previously.

COMMENTS:

iucst1a, 4pri1 14, 2015 Page 9of 16

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 7 Step 2.7; Unlock and open the foIIowng:

a. XVB00001A-AV2-AH, IA HDR ISOLATION VLV FOR XVB00001A-AH (FB-479).

b. XVB00001 B-AV2-AH, IA HDR ISOLATION VLV FOR XVB00001 B-AH (RB-463).

c. XVB00002B-AV2-AH, IA HDR ISOLATION VALVE FOR XVB00002B-AH (RB-463).

d. XVB00002A-AV2-AH, IA HDR ISOLATION VLV FOR XVB00002A-AH (FB-479).

STEP STAiVDARD:

Calls Building operators and directs opening XVB-1A(B) and XVB-2A(B) air header isolations.

OR Requests OAP-1 06.3, Locked Component Tracking Sheets for the XVB-1A(B) and XVB-2A(B) air header isolations.

CUES:

Booth Operator cue: As Building Operator acknowledge requests for valve alignment or verification and report task completed per the request. Use time compression for response.

Evaluator note: Since Purge had previously been in service the building operator may only be asked to verify air header isolation valve alignment correct.

Evaluator cue: Provide JPM h Handout 3 if Examinee requests OAP-1 06.3 Locked Component Tracking Sheets.

COMMENTS:

Tuesday, .1priI 14, 2015 Page 100/ 16

CRITICAL: No SEQUENCED: Yes SAT UNSA T

[STEP: j 8 Step 2.8; Ensure a Reactor Building Purge Release Permit has been issued per HPP-709.

STEP STANDARD:

Ensures permit is current and less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months old.

CUES:

Evaluator note: The N]PS-1001 Handout 2 (Release Permit) already indicates a SAT source check.

Evaluator note: Have a Copy of HPP-709 available for Examinee to refer to if they ask for it.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T STEP: 9 Step 2.9; Start Reactor Building Purge as follows:

a. Open PVB-2A, CNTMT EXH ISOL STEP STANDARD:

Places control switch to OPEN and holds in OPEN until Red light ON and Green light OFF.

CL/ES:

Evaluator note: This task is critical in order to ensure that the Reactor Building atmosphere is exchanged with fresh air.

COMMENTS:

Tuesdtir, April 14, 2015 Page 11 of 16

CR1TIC4L: Yes SEQUENLED: Yes SAT UNSA T STEP: 10 Procedure NOTE 2.9.b; If both trains of RB Purge are to be run, both exhaust fans should be started simultaneously.

Step 2.9 b; Hold PVB-2B, CNTMT EXH ISOL, to OPEN while simultaneously holding one or both of the following fan control switches in the START position:

1) XFN-13A, EXH FAN A.

2) XFN-13B, EXH FAN B.

STEP STANDARD:

Places control switch for PVB-2B to OPEN and Holds in OPEN. Places control switches for XFN-13A in START and holds in START until Red light ON and Green light OFF for fan and PVB-2B.

CompletesSection II, Actual Release Data on Purge Release Permit:

1. Release Start Date and Time (current date and time)

2. Start Readings on RM-A2 and RM-A4 in cps.

CUES:

Evaluator note: Only Exh Fan A (XFN-13A) should be started. Examinee should ask for a peer check.

Evaluator note: This task is critical in order to ensure that the Reactor Building atmosphere is exchanged with fresh air. Completion of the Purge Release Permit Data is NOT critical.

COMMENTS:

Tuesday, April 14, 2t115 Page 12 q 16

CR1TIC4L: No SEQUENCED: Yes SAT UNSA T STEP: 11 Step 2.9 c; Verify the following:

1) XFN-1 3A(B)-AH inlet damper opens.

2) XFN-1 3A(B)-AH outlet damper opens.

STEP ST4IVDARD:

Verifies White light ON for the INLET and OUTLET dampers for the Fan that was started (XFN-1 3A).

CUES:

Evaluator note: Fan inlet and outlet damper indications are on the mimic board above the control switches.

COMTlfENTS:

(RITIC4L: No SEQUENCED: Yes SAT UNSAT STEP:1 12 Step 2.9 d; Open XDP-28, INTAKE DMPR.

STEP STANDARD:

Places control Switch for XDP-28 to OPEN and verifies Red light ON and Green light OFF.

CUES:

COMMENTS Tuesday, .-lpril 14, 2015 Page 13 of 16

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: 13 Step 2.9 e; Open the following:

1) PVB-1A, CNTMT SPLY ISOL.

2) PVB-1 B, CNTMT SPLY ISOL.

STEP STANDARD:

Places control Switch for PVB-IA to OPEN and holds until Red light ON and Green light OFF.

Places control Switch for PVB-1A to OPEN and holds until Red light ON and Green light OFF.

CUES:

COMMENTS:

Thesdav, -IpriI 14, 2015 Page 14 qf 16

CRITIC4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 14 Step 2.9 1; Start one or both of the following, as necessary:

1) XFN-11A, SPLY FAN A.

2) XFN-1 1 B, SPLY FAN B.

STEP STAADARD:

Starts no mote than ONE Purge Supply Fan.

CUES:

Evaluator cue: If asked as CRS which supply fan to start, state Operate supply fans as required by SOP-i 14.

Evaluator note: There is a procedure note prior to the step which starts the Purge Supply Fans. The note informs the Operator that in order to maintain a negative pressure on the RB with the Equipment Hatch open, fewer Supply Fans than Exhaust Fans should be operated. In this case no supply fans or one supply fan should be started.

Evaluator note: Since the equipment hatch is open no more than ONE supply fan should be started.

This step is critical because the Examinee must maintain negative pressure on the RB.

COMMENTS:

Examiner ends JPM at this point.

Tuesc1a, April 14, 2015 Page 15 tf 16

JPM SETUP SHEET JPMNO: NJPS-1001 (Ri)

DESCRiPTION: 2015 NRC Sim h RO: Establish Reactor Building Purge Supply and Exhaust 1CSET: 317 INSTRUCTIONS:

If IC 317 is designated for this JPM then reset to IC-317 leaving the simulator in FREEZE.

1. Place yellow plastic Test in Progress tags on sample pump CMC switches for RM-A2 and RM-A4 at the rad monitor panel.

2. Place yellow plastic Test in Progress tags on CMC switches for Containment isolation valves PVA-9312A(B) on Panel 2.

3. Place red hold tag on CMC switch for XFN-13B, EXH FAN B at HVAC panel.

4. Verify SIPCS mode set to CLD Shutdown

5. Go to run, clear any alarms. Use the HVAC acknowledge button not the LOA reset if HVAC alarms.

6. FREEZE

7. When Examinee is ready (on Evaluator cue) go to RUN.

If IC 317 is not designated for this JPM then initial conditions may be established by reseting to IC 3 and following the below directions:

1. RUN

2. Perform the following at the HVAC Control Panel, XCP-6210:

Verify CMC switch for RB Purge Supply Fan A in STOP Verify CMC switch for RB Purge Supply Fan B in STOP Verify CMC switch for RB Purge Exhaust Fan A in STOP Verify CMC switch for RB Purge Exhaust Fan B in STOP Verify CMC switch for XDP-28, Intake Damper in CLOSE Verify CMC switch for RB Charcoal Cleanup fan A in STOP Verify CMC switch for RB Charcoal Cleanup fan B in STOP

3. Insert: OVR-AHO76A Override To = Off (SS-AH243 Purge Exh Fan (XFN-13B-AH) GREEN OVR-AHO76C Override To = Off (SS-AH243 Purge Exh Fan (XFN-13B-AH) WHITE

4. Place yellow plastic Test in Progress tags on sample pump CMC switches for RM-A2 and RM-A4 at the rad monitor panel.

5. Place yellow plastic Test in Progress tags on CMC switches for Containment isolation valves PVA-9312A(B) on Panel 2.

6. Place red hold tag on CMC switch for XFN-1 3B, EXH FAN B at HVAC panel.

7. Verify SIPCS mode set to CLD Shutdown

8. FREEZE

9. When Examinee is ready (on Evaluator cue) go to RUN.

COMMENTS:

Tuesclaj, April 14, 2015 Page 16 of 16

JPM BRIEFING SHEET OPERA TOR rnSTRUCT1ONS:

SAFETY COASIDERA T1ONS: None IiVITIA L CONDITION: The plant is in Mode 5 with preparations for a refueling outage in progress The equipment hatch is open.

The RB atmosphere sample analysis has been completed.

The RM-A2 and RM-A4 setpoints have been adjusted for this release and source checks are completed on both channels.

Plant status labels have been placed on the radiation monitoring equipment required for RB ventilation operability; RMA-2 and RMA-4.

Reactor Building Purge had been in service but was shutdown on the previous shift.

Reactor Building Purge Exhaust Fan, XFN-13B is tagged out for corrective maintenance.

INITIATING CUES: A surrogate operator will be provided to respond to non-related alarms per your direction.

You are being directed to place Reactor Building Purge in service using SOP-114, Reactor Building Ventilation System Section lll.C.

All applicable procedure Initial Conditions are completed.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPP-402 2015 NRC In Plant RO & SRO-U: Locally Dilute the Boric Acid Tanks CAN DIDAIE; EXAM IN ER il!o,,dav, iai:uarv 26, 2015 Page 1 of 12

TASK:

000-055-05-01 RESPOND TO LOSS OF OFF SITE AND ON SITE POWER TASK STAJVDARD:

The A BAT has been drained to 50%, then refilled to 90-95%. XVD08324A-CS is closed and both the drain rig and fillrig have been removed. -

TERMINATING CUE: The A BAT has been diluted. . -.

PREFERRED E V4L U4 TION LOCATION PREFERRED EVALUATION ME THOL PLANT SI MU LATE

REFERENCES:

EOP-6.0 LOSS OF ALL ESF AC POWER INDEX NO. K/A NC). RO SRO 000024K302 AK3.02 Actions contained in EOP for 4.2 4.4 emergency boration TOOLS: JPM i Handout (EOP-6.0, Attachment 6)

Key KAI from a set of Rover keys from the SS key box or key G1A from a ring on hook 45 of the CR key box.

E VAL U4 TION TIME 15 TIME CRITICAL NO IOCFRSS: 45(a)(6)

TIME START: TIME FINISH: PERFORMANCE TIME.

PERFORMANCE RATING: SAT: INSAT.

CA NDIDA TE:

EX4M1NER:

./

SIGNATI] RE t)ATE i!flhI(IIIP, Jai,t,ari 26. 2015 Page 2 1)112

INSTRUCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING,. I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCE$SPULLY, THIS JOB PERFORMANCE FVIEASURE WILL BE SATISFIED.

SAFETY CONSIDERiI TIONS:

INITIAL C()tVDITION: The plant has experienced an ESF Bus Blackout with the CRS implementing EOP-6.O. Annunciator BAT A TEMP HI/LO has been received and local verification indicates that temperature is 68SF in A BAT room.

INITIATING CUES: CRS directs diluting the A BAT per EOP-6.O, Attachment 6.

r

A T NO TIME A RE YOU TO OPERA TE i

ANY PLANT EQUIPMENT!

I I

d r a iFOR ELECTRICAL MANIPULATIONS, AT i NO TIME ARE YOU TO BREAK THE

PLANE Of THE ELECTRICAL PANEL!

I Ia HAND JPM BRIEFING SHEET TO OPERA TOR .4 T THIS TIME!

.4Io,,da, ]asluan 26, 2015 Page 3 of 12

.cTFP.c CRITIC4L; Yes SEQUENCED: Yes SAT UN&4 T STEP: I Step la. Connects the drain rig stored in the BAT room to XVD08324A-CS, BORIC ACID TANK A DRAIN ISOL VALVE an to the 2inchcapped pipe which penetrates the floor.

I STEP STANDARD:

Shows location of drain rig and XVD08324A and the floor penetration. Identifies necessary tools and equipment and explains how to make the connection.

CUES:

Evaluator cue: Provide a copy of JPM i Handout (EOP-6.O Attachment 6)

Evaluator cue: Provide key to Examinee once they explain where they would obtain it (either on rover key ring or from CR key box)

Evaluator note: Requires obtaining Key G1A from the control room key box hook 45 or key KA1 on a set of rover keys from the SS key box. The tool box has a lock on either side and can be difficult to open due to the nature of the lock mechanism.

Evaluator note: Examinee must identify hoses and fittings and demonstrate where each should be installed and actual layouts. Does not require removal of components from locker. Following is a description of fittings and connection points:

1. Using a pipe wrench remove the 2 stainless steel pipe cap from the nipple downstream of XVD08324A-CS

2. Thread on the Male Quick disconnect fitting labeled Hook to Tank Drain at the 8324A nipple. Tighten with wrench. Fitting has 2 threads and a 1.5 quick connect for a cam lock connector.

3. Using a pipe wrench remove the 2 stainless steel pipe cap from the vertical pipe stub rising from the floor next to valve 8323A.

4. Thread on the Male Quick disconnect fitting labeled Hook to Floor Drain at the vertical pipe stub rising from the floor next to valve 8323A. Tighten with wrench.

Fitting has 2 threads and a 1 .5 male quick connect for a cam lock connector.

5. Connect the red rubber hose labeled Drain Rig to the male fittings just installed.

Place one female quick connect cam lock on the tank drain and the other one on the floor drain connection. Connections are made by placing the male fitting inside the female fitting with the tabs on the female fitting perpendicular to the fitting then locking it on by moving the tabs 900 to parallel to the fitting.

Evaluator cue: Once demonstration by Examinee is complete state: The drain rig is connected.

[COMJ1JENTS:

j1todti, ]ui,utxr 26. 2015 Page 4 tq 12

CRITI(4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 2 Step lb. Opens XVD08324A-CS, BORIC ACID TANK A DRAIN ISOL VALVE.

STEP STANDAR1 - -

V V Simulates opening XVD08324A, by operating handwheel counte cIockise few turns until resistance is felt.

CUES:

Evaluator cue: State, Handwheel rotated CCW and stem is out.

Evaluator note: This step is critical because a sufficient volume of the tank contents must be removed to accomplish the desired outcome.

COMMENTS:

CRITJC4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 3 Step ic. Coordinate with the Control Room and drain the BAT to 50% level.

STEP STANDARD:

Contacts the CR by radio or the plant page system.

CUES:

Evaluator cue: As the NROATC, report that BAT level is 49%.

Evaluator note: This step is critical because a sufficient volume of the tank contents must be removed to accomplish the desired outcome.

COMMENTS:

lIeIl((t1j. ]anuaiv 26, 20l5 Ptige S t/ 12

CRITIC4L: No SEQUENCED: Yes SAT UNSA T rcTEP: 4 Step id. Close XVD08324A-CS, BORIC ACID TANK A DRAIN ISOL VALVE.

STEP STANDARD: .. ,

Simulates closing XVD08324A by operating thd handwheel a fewturns in the clockwise direction until it stops turning.

CUES:

Evaluator cue: State, Handwheel rotated CW and stem is in.

(OMMENTS:

O?ITIC4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 5 Step le. Remove the drain rig.

STEP STANDARD:

Describes how to disconnect the rig from XVD08324A and the penetration from the floor.

CUES:

Evaluator note: Following is a description of necessary steps to disconnect the rig:

Disconnect the red rubber hose labeled Drain Rig from the male fittings at the tank drain and the floor drain. Disconnect is accomplished by raising the tabs on the female fittings 900 to the perpendicular position and then pulling off the quick connect.

Does not remove male side of the connector which is threaded on.

Evaluator cue: Once Examinee completes the description of rig removal state: Drain rig is removed.

COMMENTS:

,1jiit1i, Janutirv 26, 2015 Pt,ge 6 q/ 12

CRITIC4L: Yes SEQUENCED: Yes SAT UNSAT tcTEP: 6 Step 2a. Open the neatest Fire Hose Reel Isolation Valve and flush the fire hose to the floor drain until the water is clear.

STEP VTANÜ4RP:

Simulates operating the reel isolation valve counter clockwise until in line with pipe. Simulates operating the nozzle counter clockwise.

CUES:

Evaluator cue: When valve is open and the nozzle is rotated CCW, state: The water is clear.

COjlIMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T STEP: 1 7 i Step 2b. Close the Fire Hose Reel Isolation Valve.

I STEP STANDARD:

Simulates operating the reel isolation valve in the clockwise direction until perpendicular with pipe CuES:

Evaluator cue: State, Handle is perpendicular to pipe.

COMMENTS:

lIoilda3, Janut,,r 26, 2015 Page 7 of 12

CRITICAL: Yes SEQUENCED: Yes SAT UNSAT rsTEP: 8 Step 2c. Connect the fill rig to XVD08324A-CS BORIC ACID TANK A DRAIN ISOL VALVE, and to the fire hose from the hose reel.

ISTEP STANDARD: i .

Explains how to make the connction.

CUES:

Evaluator cue: State, Fill rig is connected.

Evaluator note: Following is a description of necessary steps to connect the rig:

1. Take the red 1 .5 fire hose labeled fill rig and connect the 1.5 female fire hose coupling labeled Hook to Hose Reel to the male threaded coupling on the fire hose from the reel station.

2. Connect the female cam lock connection labeled To Boric Acid Tank on the opposite end of the fill rig to the previously installed male fitting at the tank drain (valve 8324A). Connection is made by placing the male fitting inside the female fitting with the tabs on the female fitting perpendicular to the fitting then locking it on by moving the tabs 900 to parallel to the fitting.

COMMENTS:

1to,,dai, January 26, 20/5 PageS t/ /2

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T tcTEP: 9 Step 2d. Opens XVD08324A-CS, BORIC ACID TANK A DRAIN ISOL VALVE.

STEP STANDARD:

- Simulates opening XVD08324A by operating handwheel counter-clockwise a few turns until resistance is felt.

fcuEs:

Evaluator cue: State, Handwheel rotated CCW and stem is out.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UNSA T fSTEP: 10 Step 2e. Open the Fire Hose Reel Isolation Valve to fill the BAT.

STEP STANDARD:

Operates the hose reel isolation valve counter-clockwise until in-line with pipe.

CUES: - -

Evaluator cue: State, Handle is in-line with pipe.

COMMENTS:

lJo,,dav. January 26, 2015 Pcige 9 q /2

(RITIC4L: Yes SF0 UENCED: Yes £4 T (INSA T STEP: 11 Step 21. WHEN BAT level is between 90% and 95%, THEN close the Fire Hose Reel Isolation Valve.

STEPSTANDARTh.1.

i Operates the reel isolation valve 900 clockwise to siut:

CUES:

Evaluator cue: As NROATC, report that A BAT level is 92%.

Evaluator cue: State handle is perpendicular with pipe.

I COMMENTS:

CRITICAL: Yes SEQUENCED: Yes SAT UNSAT

[STEP: 12 Step 2g. Close XVD08324A-CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE.

[STEP STANDARD:

Operates XVD08324A in the clockwise direction a few turns until resistance is felt.

CUES:

Evaluator cue: State handwheel rotated CW and stem is in.

COMMENTS:

tltt)fldliV. Janua,r 26. 2015 Ptige 10 of 12

(RITIc4L: No SEQUEiVCED: Yes SAT (IWSA T STEP: 13 Step 2h. Remove the fill rig.

STEP STANDARD:

Discannects the rig from the fire hose an from XV008324A. Stores the rig.

Ct/ES:

Evaluator cue: State fill rig is removed.

Evaluator note: Following is a description of fill rig removal:

1. Removes cam lock female quick connect at tank drain by moving tabs 9O to perpendicular to fitting and lifts off coupling.

2. Removes fire hose coupling connecting fill rig to hose reel hose.

2. Removes male quick disconnects from tank drain and floor drain with wrench.

3. Reinstalls pipe caps on tank drain and floor drain.

COMMENTS:

Examiner ends JPM at this point.

1It)Ildti3, ]imuarv 26. 2015 tage 11 of 12

3PM SETUP SHEET JPMNO: NJPP-402 DESCRIPTiON: 2015 NRC InPiant I RO & SRO-U: Locally Dilute the Boric Acid Tanks ICSET: NA INSTRUCTIONS:

COMMENTS:

1Io,zdaj, January 26, 2015 Page 12 of 12

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERA TIONS:

INITIAL CONDITION: The plant has experienced an ESF Bus Blackout with the CRS implementing EOP-6.O. Annunciator BAT A TEMP HI/LO has been received and local verification indicates that temperature is 68F in A BAT room.

INITIA TING CUES: CRS directs diluting the A BAT per EOP-6.O, Attachment 6.

F ______7

A T NO TIME A RE YOU TO OPERA TE i ANY PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SA1ISFACTORILY COMPLETED THE ASSIGNED TASK.

EOP6.O JPM i Handout ATTACHMENT 6 LOCALLY DILUTING THE BORIC ACID TANKS PAGE 1 OF 2 ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION Locally drain the BAT to 50% level (AB463):

a. Connect the drain rig stored in

,the BAT room to XVDOB324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE, and to the 2inch capped pipe which penetrates the floor.

b. Open XVD08324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE.

c. Coordinate with the Control Room, and drain the BAT to 50%

level.

d. Close XVDOB324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE.

e. Remove the drain rig. E PAGE 43 OF 48

EOP6.O JPM i Handout REVISION 29 ATTACHMENT 6 LOCALLY DILUTING THE BORIC ACID TANKS PAGE 2 OF 2 ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION 2 Locally fill the BAT using the Fire Service System (AB463):

a. Open the nearest Fire Hose Reel Isolation Val ye. and 11 ush the fire hose to the floor drain until the water is clear.

b. Close the Fire Hose Reel Isolation Valve.

c. Connect the fill rig to XVD08324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE, and to the fire hose from the hose reel

d. Open XVDO8324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE.

e. Open the Fire Hose Reel Isolation Valve to fill the BAT.

f. WHEN BAT level is between 90%

and 95%, THEN close the Fire Hose Reel Isolation Valve.

g. Close XVDO8324A(B)CS, BORIC ACID TANK A(B) DRAIN ISOL VALVE.

h. Remove the fill rig.

PAGE 44 OF 48

V. . $UMMER NUCLEAR S TA TION JOB PERFORMANCE MEASURE 1PM NO: NJPPF-049 (RI) 2015 In Plantj NRC RO &SRO-U:

Control Room Evacuation (Duties of BOP Operator)

CANDIDATE:

EXA MINER:

IVethiesda, April 15, 2(115 Page 1 of 15

TASK:

000-068-05-01 PERFORM CONTROL ROOM EVACUATION PER AOP-600.1.

TASK STANDARD:

AOP-600.1 Attachment 2 performed with the following complete:

1 All MFPs have been tripped V -

2. Rod Drive MG set B feeder breaker has been tripped V 3 RCP B is left running (A and C RCP are tripped already). V ,

4. Two condensate pumps have been tripped

5. Three FWBPs have been tripped.

The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phonetic alphabet, etc) and industrial safety practices meets expectations.

TERMItVA TING CUE: Step 12 of Attachment 2 is complete or when examinee returns procedure to examiner.

PREFERRED E VAL UA TION L OCt TION PREFERRED EV4LU4 TION ME THOL PLANT SIMULATE

REFERENCES:

SOP-31 3 LOCAL SWITCHGEAR BREAKER OPERATIONS ISP-027 ELECTRICAL SAFETY AOP-600.1 CONTROL ROOM EVACUATION INDEX NO. K/A NO. RO SRO 0000682130 2.1.30 Ability to locate and operate components, 4.4 4.0 including local controls.

TOOLS: JPMj Handout 1; AOP-600.1, Attachment 2 JPM j Handout 2; Picture of the inside of a 7.2 KV breaker.

JPM j Handout 3; SOP-31 3 Section lV.K, Local Operation of a Remotely Operated 480 Volt Breaker.

JPM j Handout 4; SOP-31 3 Section lV.J, Local Operation of a 7.2KV Breaker.

EVALUATION TiME 14 TIME CRITIC-IL No It)CFR55: 45(a)13 lIME START: IVI\lI. FINISh PERFOIANCE VIVIvlIV.:

PERFORMANCE RATING: SAT: [JNSAF:

CANDID 4 TE:

EXAMINER:

SIGNATURL L)i. [U VLdne.cdar, .lpriI 15, 2015 Page 2 of 15

INSTRUCTIONS TO OPERA TOR READ TO OPERATOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, .1 WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THISJOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant was operating at 100% power, with all controls in automatic.

A call was received that a bomb has been placed in the control room.

The SS has directed a control room evacuation.

AC power is available to both ESF Buses.

The reactor has been tripped by the Reactor Operator.

INITL4 TING CUES: The Control Room Supervisor directs you as the BOP Operator to perform Attachment 2 of AOP-600.1, Steps 10 through 12.

F u A T NO TIME A RE YOU TO OPERA TE ANY PLANT EQ UIPMENTI L _!

F l iFOR ELECTRICAL MANIPULATIONS, AT.

NO TIME A RE YOU TO BREA K THE PLANE OF THE ELECTRICAL PANEL!

I-bIND JPM BRIEFING SHEET TO OPERA TOR .4 T THIS TIME!

Jlediiesthn, ,-Iprit iS, 2tfl5 Page 3 of 15

cTFPc CRITIC4L: No SEQUENCED: Yes SAT UNSAT STEP: 1 Procedure CAUTION Step 10 Reactor Trip should be verified with the Reactor Operator prior to securing the Main Feedwater Pumps.

Verifie reactor has been tripped. V STEP STANDARD:

Calls the Reactor Operator and verifies reactor has been tripped.

CUES:

Evaluator note: Initial conditions have indicated that the RO has already tripped the reactor.

Evaluator cue: If the Examinee calls the Reactor Operator to verify the reactor trip, respond as the Reactor Operator that the reactor has been tripped.

COMMENTS:

CRITIC4 L: Yes SEQUENCED: Yes SAT UNSAT V

STEP: I 2 Step 10. Locally trip all Main Feedwater Pumps (436 TB).

STEP STANDARD:

Pulls MFP PULL TO TRIP handle on front standard for MFPs A B & C. Verifies trip by noting RPM decrease locally OR trips MFPs from local DCS station.

CUES:

Evaluator cue: State that the handle withdraws and that the frequency of the sound from the pump is lowering.

Evaluator note: Tripping MFPs is critical because leaving them in service would result in excessive RCS cooldown and positive reactivity addition.

COMMENTS:

JVecb,esda, 4prit 15, 2015 PagL 4 of 15

CRITICAL: No SEQUENCED: Yes SAT LINSAT STEP: 3 Step 11 a. Locally at XSW1A Switchgear Room (TB-436): Trips XSW-1 Bi 06C - ROD DRIVE M/G SET B.

TEP STANDARD:

Trips rod drive MG set B bkr 06C at XSW-1B1 by pushing on red TRIP pushbutton on left side on front of breaker. Verifies a Green OPEN flag results and Red light OFF, Green light ON.

CUES:

Evaluator cue: If asked as the Shift Supervisor if ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements can be waived respond that the requirements can be waived.

This waiver will be applied to the rest of the task. If Examinee does not wish to waive ISP-027 requirements then the following are required: Hard hat; safety glasses, hearing protection; Fire Retardant Pants and shirt or Fire Retardant coveralls.

Evaluator note: A copy of the applicable procedure is shown in JPM j Handout 3 (SOP-31 3 Section IV.K). If examinee describes the correct procedure and states they would obtain a copy then provide Handout 3.

Evaluator cue: Inform Exam inee that MG Set B breaker cubicle has a Green OPEN flag with Red light OFF and Green light ON.

Evaluator cue: If the TRIP pushbutton on the right side of the breaker is used this is incorrect.

Provide cue that there is no change in status (This pushbutton only works when the breaker is racked to test).

[LOMMENTS:

JJed,wsctav, April 15, 2015 Page 5 0/15

CRJTIc4L: No SEQUENCED: Yes SAT UNSA T STEP: 4 Step 11 b. Check status of XSWIA 06 FD WTR BOOSTER PUMP A breaker. (TB-436)

STEP STANDARD: .

Verifies that the A FWBP, bkr 06 is closed by observing red light on outside of cubie door.

CUES:

Evaluator cue: Inform Examinee that A FWBP, breaker cubicle has the Red light ON.

COMMENTS:

au TIcAL: No SEQUENCED: Yes £4 T UNSA T I STEP: 5 Step 11 c. Checks status of XSW1A 09, RX COOLANT PUMP A breaker.(TB-436)

STEP STANDARD:

Checks RCP A breaker at XSW1A 09. Verifies breaker cubicle door has Green light ON.

CUES:

Evaluator cue: Inform Examinee that RCP A breaker cubicle has the Green light ON.

Evaluator note: This will setup alternate path portion of this JPM. Examinee will have to leave B RCP running in Step 12.c.)

COMMENTS:

JVednesdar, ,Iprit 15, 2015 P(IgL 6 of li

CRITICAL: No SEOUENCED: Yes SAT UNSAT STEP: j 6 Step 11 U. Check status of XSW1A 07, COND PUMP A breaker. (TB-436)

STEP STANDARD:

Verifies that the A condensate pump bkr 07 is closed by observing Rd light ONoutside of cubicle*

door.

Evaluator cue: Inform Examinee that A condensate pump breaker cubicle has the Red light ON.

COilIMEiVTS:

Wed,wsdai, April 15, 2015 Pt,ge 7 of 15

CRITIC4L: Yes SEQUENCED: Yes SAT LWSA T STEP: 7 Step 12 Locally at XSW1B and XSW1C Switchgear Room (TB-412):

Step 12 a. If Condensate Pump A is running THEN trip both of the following:

Tr1pYSW1B 09, COND PUMP B breaker.(TB-41 2)

STEP STANDARD:

Trips breaker XSWI B 09 for Cond Pump B by pushing the MANUAL TRIP lever on front of I breaker (inside cubicle door). Verifies breaker cubicle door has the Green light ON.

CUES:

Evaluator cue: If asked as the Shift Supervisor if ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements can be waived respond that the requirements can be waived.

If Examinee does NOT wish to waive ISP-027 requirements then the following are required: 25 CalIcm2, arc flash suit and hood (use of an arc flash hood without a hard hat in an area with overhead work in progress will require manager approval. Otherwise no hard had is required when in

an arc flash hood). Short sleeve natural fiber shirt, voltage rated gloves with leather, safety glasses, earmuffs are the preferred hearing protection when an arc flash suit is being worn, however earplugs may be used. Fire Retardant coveralls or Fire Retardant Shirt (tucked in) & Pants. A 10 flash protection boundary is established.

Evaluator Note: Do not let Examinee open the breaker door. A picture has been included of the inside of a 7.2 breaker (JPM j Handout 2).

Evaluator note: A copy of the applicable procedure is shown in JPM j Handout 4 (SOP-31 3 Section lV.J). If examinee describes the correct procedure and states they would obtain a copy then provide Handout 4. This handout is applicable to all of the 7.2 KV breaker local operations.

Evaluator cue: IF correct action is described inform the Examinee Condensate Pump B breaker cubicle door has the Green light ON. IF correct actions are NOT described inform the Examinee that the Red light is ON.

Evaluator note: Tripping Condensate Pumps is critical because leaving them in service would result in excessive RCS cooldown and positive reactivity addition.

COMMENTS:

H Ved,iesth,v, April 15, 2015 Page 8 (f is

CRJTIC4L: No SEQUENCED: Yes SAT UNSA T TEP: J 8 Step 12 a. Checks status of XSW1C 06, COND PUMP C breaker. (TB-412)

STEP STANDARD:

Checks COND PUMP C Breaker, XSWO1C 06. Verifies breaker cubicle door has the Green light ON.

CUES:

Evaluator cue: Inform Examinee that COND PUMP C breaker cubicle has the Green light ON.

COi1JMENTS:

WLthscsctar, -lprit 15, 2015 Page 9 of 15

(RITIC4L: Yes SEQUEtV(ED: Yes SAT UNSAT STEP: J 9 Step 12 b. If Feedwater Booster Pump A is running, THEN trip all of the following:

Trips XSW1B 06, FD VVTR BOOSTER PUMP B breaker. (TB-412)

STEP STANDARD: .

Trips the FWBP B bkr 06 manually at XSW-1 B by pushing the MANUAL TRIP lever on front of breaker (inside cubicle door). Verifies a green light on outside of cubicle door results.

CUES:

Evaluator note: Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as for the Condensate pumps.

Evaluator Note: Do not let Examinee open the breaker door. A picture has been included of the inside of a 7.2 breaker (JPM j Handout 2).

Evaluator cue: IF correct action is described inform the Examinee that Feed Water Booster Pump B breaker cubicle door has the Green light ON. IF correct actions are NOT described inform the Examinee that the Red light is ON.

Evaluator note: Tripping FW Booster Pumps is critical because leaving them in service would result in excessive RCS cooldown and positive reactivity addition.

COMMENTS:

IVednesdav, .-Ipril 15, 2015 Page 10 qf 15

CRITIC4L: Yes SEQUENCED: Yes £4 T UNSA T STEP: 10 Step 12 b. Trips XSW1B 13, FD WTR BOOSTER PUMP D breaker. (TB-412)

STEP STANDAKD:

Trips the FWBP Dbkr 13 manually at XSW-1 B by pushing the MANUAL TRIP lever on frontof breaker (inside cubicle door). Verifies breaker cubicle door has the Green light ON.

CUES:

Evaluator note: Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as for the Condensate pumps.

Evaluator cue: IF correct action is described inform the Examinee that Feed Water Booster Pump D breaker cubicle door has the Green light ON. IF correct actions are NOT described inform the Examinee that the Red light is ON Evaluator Note: Do not let Examinee open the breaker door. A picture has been included of the inside of a 7.2 breaker (JPM j Handout 2).

Evaluator note: Tripping FW Booster Pumps is critical because leaving them in service would result in excessive RCS cooldown and positive reactivity addition.

CO11ilfEiVTS:

JVediesular, -Iprit 15, 2015 Ptige Ii of 15

CRITIC4L: Yes SEOUENCED: Yes SAT UNSAT STEP: 11 Step 12 b. Trips XSW1C 08, FD WTR BOOSTER PUMP C XPPO028C-FW breaker. (TB-412)

STEP STANDARI):

Trips the FWBP C bkr 08 manually at XSW-1 C by pushing the MANUAL TRIP lever on front of breaker (inside cubicle door). Verifies breaker cubicle door has the Green light ON.

CUES:

Evaluator note: Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as for the Condensate pumps.

Evaluator Note: Do not let Examinee open the breaker door. A picture has been included of the inside of a 7.2 breaker (JPM j Handout 2).

Evaluator cue: IF correct action is described inform the Examinee that Feed Water Booster Pump C breaker cubicle door has the Green light ON. IF correct actions are NOT described inform the Examinee that the Red light is ON Evaluator note: Tripping FW Booster Pumps is critical because leaving them in service would result in excessive RCS cooldown and positive reactivity addition.

[COiIMENTS:

IVednesdav, April 15, 2015 Page 12 (?115

CItITIC4L: Yes SEOUENCED: Yes SAT UNSAT 12 Step 12 c. If RCP A is running (NO), goes to RNO.

Ensure one of the following is open:

XSW1B 07, RX COOLANT PUMP B breaker OR XSW1C 03, RX COOLANT PUMP C breaker.

STEP STANDARD:

Does NOT trip the RCP B bkr 07 at XSW-1 B (because RCP C bkr 03 at XSW-1 C is already open).

CUES:

Evaluator note: This is the alternative path portion of this JPM. It is critical that the B RCP be left running since both the A and C pumps are already tripped in this JPM.

Evaluator cue: The following cues are crucial since the both B and C RCP breakers will actually be indicating RED light on.

I IF Examinee goes to RCP B THEN state that the XSW1 B 07, RX COOLANT PUMP B breaker

[cubicle has the RED light ON.

IF Examinee goes to RCP C THEN state that the XSW1C 03, RX COOLANT PUMP C breaker cubicle has the GREEN light ON.

Evaluator note: Same ISP-027, ELECTRICAL SAFETY INDUSTRIAL SAFETY PROCEDURE, requirements as the Condensate pumps.

COMMEjVTS:

Weduesdar, April 15, 21?I5 Ptige 13 of 15

CRITICAL: No SEQUEN(ED: Yes SAT UNSAT EP:13 Step 12 d. Ensure XSW 1C 02 Press Heater Transformer breaker is closed.

STEP STANDAKD:

Verifies that the PZR Heater Transformer Breaker 02 at XSW-C is closed by observing red light on outside of cubicle door or a red closed flag on front of breaker.

CUES:

Evaluator cue: Inform Examinee that PZR Heater Transformer breaker cubicle door has the Red light ON, Green light OFF.

Evaluator note: Same ISP-027 considerations as Condensate pumps if it was to be operated but since only verifying proper position there are no ISP-027 requirements.

COMMENTS:

Examiner ends JPM at this point.

IJecliiesdav, -tpri1 iS, 2015 Page 14 (?f

JPM SETUP SHEET JPMNO: NJPPF-049 (Ri)

DESCRIPTION: 2015 InPlantj NRC RO &SRO-U: Control Room Evacuation (Duties of SOP Operator)

IC SE T:

INSTRUCTIONS:

COMMENTS:

tVedi,esdav, -1prit 15, 2015 Page 15 of iS

JPM BRIEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSJDERA TIONS:

INITiAL CONDITION: The plant was operating at 100% power, with all controls in automatic.

A call was received that a bomb has been placed in the control room.

The SS has directed a control room evacuation.

AC power is available to both ESF Buses.

The reactor has been tripped by the Reactor Operator.

INITIATING CLIES: The Control Room Supervisor directs you as the BOP Operator to perform Attachment 2 of AOP-600.1, Steps 10 through 12.

A T NO TIME ARE YOU TO OPERA TE ANY PLANT EQUIPMENT!

HAND ThIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

AOP-600.1 JPMjHandoutl REVISION 2 ATTACHMENT 2 DUTIES OF THE BOP OPERATOR PAGE 1 OF 4 ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION 1 Verify AC power is available to 1 COMPLETE Attachment 2. WHEN both ESF Buses. Attachment 2 is complete, THEN COMPLETE Attachment 3.

2. Check if time is. available to 2 IO TO Step 10. Observe the..

perform additional Control Room CAUTION prior to Step 10.

actions.

CAUTION-Step 3 Reactor Trip should be verified prior to securing the Main Feedwater Pumps.

3 Trip all Main Feedwater Pumps.

4 Ensure only one Feedwater Booster Pump is running.

I 5 Ensure only one Condensate Pump is LI running.

6 Verify RCP A is running. 6 Locally at the 7.2KV Switchgear on the TB-412, ensure the following:

a) XSW1B 07, RX COOLANT PUMP B XPPOO3OB-RC, is open.

b) XSW1C 02, PRESSURIZER HEATER TRANSFORMER XTF41O3, is closed.

c) GO 10 Step 8.

7 Locally at the 7.2KV Switchgear on the TB-412, ensure the following:

a. XSW1B 07, RX COOLANT PUMP B XPPOO3OB-RC, is open.

b. XSW1C 03, RX COOLANT PUMP C LI XPPOO3OC-RC, is open.

XSW1C 02, PRESSURIZER HEATER I TRANSFORMER XTF41O3, is closed.

PAGE 16 OF 27

AOP-600.1 REVISION 2 ATTACHMENT 2 DUTIES OF THE BOP OPERATOR PAGE 2 OF 4 ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION 8 Locally verify aH Main Feedwater LI Pumps are on their Turning Gears (18-436).

9 00 TO Step. 15.

cAUJON -jo Reactor Trip should be verified with the Reactor Operator prior to securing the Main Feedwater Pumps.

10 Locally trip all Main Feedwater Pumps (18-436).

11 Locally at XSW1A Switchgeat Room (18-436). perform the following:

a. Trip XSW1B1 O6C, ROD DRIVE MG LI I SET B XMG0001B-CR.

b. Check the status of XSW1A 06, LI ED WTR BOOSTER PUMP A XPPOO?8A- EW.

c. Check the status of XSW1A 09, LI RX COOLANT PUMP A XPPOO3OA-RC.

d. Check the status of XSW1A 07, LI COND PUMP A XPPOO42A-CO.

PAGE 17 OF 27

AOP-600.1 REVISION 2 ATTACHMENT 2 DUTIES OF THE BOP OPERATOR PAGE 3 OF 4 I ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION 12 Locally at XSW1B and XSW1C Switchgear Room (18-412), perform the following:

a. IF Condensate Pump A is a. Ensure one of the following is running, THEN trip both of the open:

following

XSW1B 09, LI

XSW1B 09, COND PUMP B XPPOO42B-CO.

COND PUMP B XPPOO4ZB-CO.

OR

XSW1C 06, COND PUMP C XPPOO4?C-CO.

XSW1C 06, LI COND PUMP C XPPOO42C-C0.

b. IF Feedwater Booster Pump A is b. Ensure two of the following are running, THEN trip all of the open:

following

XSW1B 06, ED WIR BOOSTER

XSW1B 06, ED WIR BOOSTER PUMP B XPPOO28B-FW.

PUMP B XPPOO28B-FW.

XSW1B 13, ED WIR BOOSTER LI

XSW1B 13, ED WIR BOOSTER LI PUMP D XPPOO28D-FW.

PUMP D XPPOO28D-EW.

I

XSW1C 08, FDWTR BOOSTER

XSW1C 08, EDWIR BOOSTER PUMP C XPPOO28C-FW.

PUMP C XPPOO28C-FW.

c. IF RCP A is running, THEN trip c. Ensure one of the following is both of the following open:

XSW1B 07, RX COOLANT PUMP B

XSW1B 07, RX COOLANT PUMP B XPPOO3OB-RC. XPPOO3OB-RC.

XSW1C 03, RX COOLANT PUMP C LI OR XPPOO3OC-RC.

XSW1C 03. RX COOLANT PUMP C XPPOO3OC-RC.

d. Ensure XSW1C 02, PRESSURIZER H EATER TRANSFORMER XTF41O3, is closed.

13 Locally trip XSW1C1 05D, ROD DRIVE LI MG SET A XMG0001A-CR (TB-412).

14 Locally verify all Main Feedwater LI Pumps are on their Turning Gears (TB-436).

I PAGE 18 OF 27

AOP-600.1 REVISION 2 ATTACHMENT 2 DUTIES OF THE GOP OPERATOR PAGE 4 OF 4 I ACTION/EXPECTED RESPONSE ALTERNATIVE ACTION 15 Report to CREP Roon B.

I I

PAGE 190127

- k -

jr r -D f1I !ij I I

I I

JPM j Handout 3 SOP-313 REVISION 5 K. LOCAL OPERATION OF A REMOTELY OPERATED 480 VOLT BREAKER (6001160012000 AMPS) 1.0 INITIAL CONDITIONS D 1.1 The Contr.oI Room has bQen Jnformed of the local operations to be performed.

1 .2 One of the fllowing conditions have been met:

a. The SS/CRS has entered the cubicle number and nomenclature for the breaker to be operated in Step 2.1 .a, below. CHG

b. Personnel racking the breaker have a controlling document in the field (i.e. LOTO or SOP lineup) that identifies the correct component by listing both the breaker cubicle number and nomenclature.

NOTE 2.0 These steps shall only be performed when directed by the Shift Supervisor.

2.0 INSTRUCTIONS 2.1 Ensure you are at the correct breaker by one of the following:

El a. Per SS/CRS:_____________________________________

A El b. Per controlling document in accordance with Step 1 .2.b.

El 2.2 Verify the breaker nameplate data indicates that the Frame Size is either a 600/1 600/2000 AMP breaker.

El 2.3 Verify proper Personal Protective Equipment and Approach Boundaries per lSP-027, Enclosures 8.4 and 8.2. CHCG PAGE 47 OF 60

SOP-31 3 REVISION 5 NOTE 2.4 At Motor Control Centers having an Automatic Transfer Unit (XMC1A1X, XMC1A4X, CHG XMC1A4Y, XMC1BIX, and XMC1CIX) prior to operating the Normal or Emergency C Feeder Breakers the Mode Selector Switch must be placed in MANUAL. Refer to SOP-308 for proper operation. .

2.4 To locally close a remotely operated breaker, perform the following:

a. Lift up on the closing lever located between the left hand TRIP button and the center CLOSE button.

b. Verify the breaker is closed, as indicated by the CLOSED flag being visible.

CAUTION 2.5 When possible, the breaker should be opened locally under minimal load.

2.5 To locally open a remotely operated breaker, perform the following:

a. Depress the TRIP button on the front, left side of the breaker face.

b. Verify the breaker is open, as indicated by the OPEN flag being visible.

END OF SECTION PAGE 48 OF 60

JPM j Handout SOP-313 REVISION 5 J. LOCAL OPERATION OF A 7.2 Ky BREAKER 1.0 INITIAL CONDITIONS Di.1 The Control Room has been informed of all local operations to be performed.

1.2 One of the following conditions have been met:

a. The SS/CRS has entered the cubicle number and nomenclature for the breaker to be operated in Step 2.1 .a, below. CHG A

b. Personnel racking the breaker have a controlling document in the field (i.e. LOTO or SOP lineup) that identifies the correct component by listing both the breaker cubicle number and nomenclature.

NOTE 2.0 These steps shall only be performed when directed by the Shift Supervisor.

2.0 INSTRUCTIONS 2.1 Ensure you are at the correct breaker by one of the following:

LI a. Per SS/CRS:_____________________________________ CHG A

LI b. Per controlling document in accordance with Step 1 .2.b.

LI2.2 Verify proper Personal Protective Equipment and Approach Boundaries per ISP-027, Enclosures 8.4 and 8.2. CHG NO1-* LI 2.3 Inform the Control Room of the component affected, by the breaker to be operated.

PAGE 45 OF 53

SOP-31 3 REVISION 5 2.4 Locally close the breaker by performing one of the following:

a. For breakers that allow manual operation from inside the cubicle:

1) Depress the MANUAL CLOSE button on the lower, center portion of the breaker face.

2) Verify the breaker is closed, as indicated by the CLOSED fIa being visible. CHG

b. For breakers that are cannot be operated inside the cubicle and local use of the pistol grip switch is desired:

1) Place the pistol grip handle to the CLOSED position with a crisp hand motion.

2) Verify the breaker is closed, as indicated by the CLOSED flag being visible.

CAUTION 2.5 When possible, the breaker should be opened locally under minimal load.

2.5 Locally open the breaker by performing one of the following:

a. For breakers that allow manual operation from inside the cubicle:

1) Depress the MANUAL TRIP lever through the opening on the lower, right hand corner of the breaker face.

2) Verify the breaker is open, as indicated by the OPEN flag being visible. CHG D

b. For breakers that are cannot be operated inside the cubicle and local use of the pistol grip switch is desired:

1) Place the pistol grip handle to the TRIP position with a crisp hand motion.

2) Verify the breaker is open, as indicated by the CLOSED flag being visible.

END OF SECTION PAGE 46 OF 53

V. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPP-040 2015 NRC In-Plant k RO: Transfer a Vital 120 Volt Instrument Power Supply CANDIDATE:

EXAMiNER:

Tuesdti, Jttnuarv 27, 2015 Page 1 of /2

745K:

062-01 0-01-04 REMOVE ENGINEERING SAFETY FEATURES VITAL INVERTER FROM SERVICE TASK STANDARD:

XIT-5901 is shutdown with APN-5901 supplied by alternate power from 1 FA via manual bypass switch. The use of applicable Human Performance Tools (3-way communications, self checking, peer checking, phohetic alphabet etc) and industrial safety practices meets expectations.

TERMIN4TING CUE: Examinee returns SOP-310 to examiner.

PREFERRED EVALU1 T(OtV LOCA TIOiV PREFERRED E V4L U4 TION METHOL PLANT SI MU LATE

REFERENCES:

SOP-310 ENGINEERED SAFETY FEATURES 120 VAC INSTRUMENT AND CONTROL SYSTEM INDEX NO. K/A NO. RO SRO 062000A203 A2.03 Consequences of improper sequencing 2.9 3.4 when transferring to or from an inverter TOOLS: JPM k Handout; SOP-310 Section IV.E Placing lnverter XIT59O1 in an Alternate AC Lineup, marked through step 1.4 with steps 2.10 and 2.11 marked N/A.

EVALUATION TIME 10 TL3IECRITIC4L No JOCfRSS: 45(a)6 TIME START: TIME FINISH: PERR)RMANCE TIME.

PERFORMANCE RA TING: SAT: UNSAT:

CANDIDA TE:

E4t1f1NER:

SIGNATI.IRE DATE Tuesth, Jantwrv 27, 2015 Page 2 of 12

INSTRUCTIONS To OPERA TOR READ TO OPERA fOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

£4 FETY CONSIDERATIONS:

INITIAL CONDITION: Plant is at 100% power. Al Train maintenance work. XIT-5901 is scheduled for preventive maintenance.

INITL4 TING CUES: Shift Supervisor directs that XIT-5901 be removed from service and APN-5901 be placed on alternate power in accordance with SOP-310,Section IV.E for inverter PMs. Initial conditions are completed through step 1.4.

STP-506.005, DEENERGIZATION OF THE ESF LOAD SEQUENCER LOSS OF VOLTAGE AND DEGRADED VOLTAGE RELAYS has been completed.

!LItVD JPM BRIEFING SHEET TO OPER I TOR tl T TillS TIME!

F _

9 1A T NO TIME ARE YOU TO OPERATE ANY PLANT EQUIPMENT!

L r

1fOR ELECTRICA a L MANIPULATIONS, AT1 NO TIME ARE YOU TO BREAK THE PLANE OF THE ELECTRICAL PANEL!

L Tuesday, Jansuiry 27, 2015 Page 3 of 12

STEPS (RITIC4L: No SEQUENCED: Yes SAT UNSA T STEP: j 1 Step 1.5 On X1T5901 the following breakers are closed:

a. ALT. AC SOURCE.

b. BACKUP SOURCE.

c. NORMAL AC SOURCE.

STEP STANDARD:

Alternate source, Backup Source and Normal AC source breakers are all closed.

CtJES:

Evaluator cue: Provide a copy of JPM k Handout, SOP-31 0 Section IV.E Evaluator note: All 3 breakers should be closed during normal full power operation.

COMMENTS:

CRITIc4L: No SEQUENCED: Yes SAT UNSA T STEP: 2 Step 1.6 The MAN BYPASS Switch is in NORMAL.

STEP STANDARD:

Manual Bypass switch is in NORMAL CUES:

Evaluator note: Manual Bypass should be in NORMAL during normal full power operation.

COMMENTS:

Tuestlav, Jainuiry 27, 2015 Ptige 4 of 12

CRITICAL: No SEQUEN(ED: Yes SAT UNSA T STEP: 3 1.7 The TEST TRANSFER Switch is in the CENTER Position.

STEP STANDARD:

The TEST TRANSFERSwitch is in the CENTER Position.

CUES:

Evaluator note: Test Transfer switch should be in the CENTER position during normal full power operation.

COMMENTS:

CRITICAL: No SEQUENCED: Yes SAT UNSA T STEP: J 4 1.8 The SYNC MONITOR light is NOT lit.

1 STEP STANDARD:

Visually observes SYNC MONITOR Light OFF. (CB-436). (center of panel)

CUES:

COMMENTS:

?uestltiv, Jtuwarv 27, 2(115 Page 5 of 12

CRITICAL: No SEQUENCED: Yes SAT UNSA T TEP:J 5 Procedure CAUTION 2.0 STP-506.005, De-Energization Of The ESF Load Sequencer Loss Of Voltage And Degraded Voltage Relays A Train, XEG0001A, should be completed on Train A prior to removing lnverter X1T5901 from service. Thisshould be tracked on the Diesel Generator A R&R.

Procedure NOTE 2.0

a. All steps are performed in the Relay Room (CB-436) unless otherwise stated.

b. XCP-636 1-5 (INV 1/2 TROUBLE) and XCP-636 1-6 (INV 1/2 AC INPUT LOSS) will be locked in alarm at the completion of this procedure.

Step 2.1 Ensure Alternate Source voltage is acceptable for transfer:

a. Place the SOURCE SELECTOR Switch in LINE.

b. Verify the Alternate AC Source voltage is acceptable as indicated by an AC OUTPUT voltage indication between 115 VAC and 125 VAC.

c. Place the SOURCE SELECTOR Switch in OUTPUT.

STEP STANDARD:

Simulates placing Source Selector to line, verifies AC Source Voltage and returns Source Selector switch to Output.

ECUES:

Evaluator cue: When Examinee selects line point to AC Output voltage meter indicating 120 Volts.

COMMENTS:

iucsdav, Jaizuar 27, 2015 Page 6 q/ 12

CRITIC4L: Yes SEQUEN(ED: Yes SAT Eli UNSAT STEP: 6 Procedure NOTE 2.2 Placing the TEST TRANSFER Switch in the ALT Position forces the Static Switch to receive power from the Alternate Source and deliver it to APN59O1. This will also cause the following:

a) XCP-636 1-5 (INV 1/2 TROUBLE) annunciates (MCB).

b) ON ALTERNATE light illuminates.

c) ON INVERTER light is extinguishes.

Step 2.2; Place the TEST TRANSFER Switch to the ALT Position.

STEP STANDARD:

Simulates placing the TEST TRANSFER Switch to the ALT position. (right).

CUES:

Evaluator cue: Inform Examinee that the TEST TRANSFER Switch is in ALT position and the ON ALTERNATE light illuminates and the ON INVERTER light is extinguishes.

Evaluator cue: If Examinee contacts the control room respond that annunciator XCP-636 1-5 (INV 1/2 TROUBLE) did annunciate at the Main Control Board.

Evaluator note: Step 6 is critical is critical as the alternate source must be placed in service to accomplish the task standard.

[COMJWEJVTS:

Tuesday, January 27, 21115 Page 7 of 12

CRITIC4L: No SEOUENCED: Yes SAT UNSA T STEP: 7 Step 2.3; Verify the ON ALTERNATE light is lit.

STEP STANDARD:

Verifies the ON ALTERNATE light illuminated. V CUES:

Evaluator cue: Inform Examinee that the ON ALTERNATE Light is ON.

COMMENTS:

Tuisc1av, Jti,iuurv 27, 2015 Puge 8 of 12

CRITICAL: Yes SF0 UENCFD: Yes SAT UiVSA T STEP: 8 Procedure CAUTION Step 2.4 If the ON ALTERNATE light is not illuminated, then it cannot be verified that the Static Switch has aligned itself to receive power from the Alternate Source.

Proceeding with this procedure may result in a loss of APN59O1.

Procedure NOTE 2.4 and 2.5:

The SYNC MONITOR Light should illuminate when the INVERTER STOP Pushbutton is pressed.

Step 2.4; Momentarily depress the INVERTER STOP Pushbutton and verify the SYNC MONITOR Light is lit.

STEP STANDARD:

Simulates momentarily depressing INVERTER STOP Pushbutton and verifies the SYNC MONITOR Light illuminates.

CUES:

Evaluator cue: Inform Examinee that the SYNC MONITOR Light is ON after the INVERTER STOP Pushbutton is depressed.

Evaluator note: Examinee should proceed to step 2.6.

Evaluator note: Step 8 is critical as the inverter is to be removed from service and this step accomplishes that.

COMMENTS:

iuesday, January 27, 21115 Page 9 of 12

CRJTIC4L: Yes SEQUENCED: Yes SAT UNSAT tSTEP: 9 Procedure NOTE 2.6 The transfer performed with the MAN BYPASS switch is a Make-Before-Break operation which provides a momentary paralleling of power sources.

Step 2.6; Align Alternate AC power through the Static Switch to APN5901 by rotating the MAN BYPASS switch clockwise to the BYP TO ALT Position.

STEP STANDARD:

Simulates rotating the MAN BYPASS Switch to the BYP TO ALT position. (turn right)

CUES:

Evaluator note: Step 9 is critical to align the alternate source to 1 FA.

COMMENTS:

CR1 TJC4L: Yes SEQUENCED: Yes SAT [] UNSAT

[j STEP: 10 I Step 2.7; Open the BACKUP SOURCE Breaker on the Inverter front.

STEP STANDARD:

Simulates manually positioning the BACKUP SOURCE breaker on the inverter front to OFF, (TO THE RIGHT OF THE MAIN PANEL).

CUES:

Evaluator note: Step 10 is critical to isolate inverter power per task standard COMMENTS:

Tutstta, Jaiuuirj 27, 2015 Page 10 of 12

CRITIC4L: Yes SEQUENCED: Yes SAT UN&4 T STEP: 11 Step 2.8; Open the NORMAL AC SOURCE Breaker on the Inverter front.

STEP STANDARD:

Simulates manually positioning the NORMAL AC SOURCE Breaker on the inverter front to OFF, (Down).

CUES:

Evaluator note: Step 11 is critical to isolate inverter power per task standard

[COMMENTS:

CRiTiCAL: No SEQUENCED: No SA T UNSA T STEP: 12 Step 2.9: Verify XCP-636 1-6 (INV 1/2 AC INPUT LOSS) is in alarm (MCB).

STEP STANDARD:

Calls control room to verify XCP-636 1-6 is in alarm.

LCUES:

Evaluator cue: Respond as control room that XCP-636 1-6 did alarm.

COMMENTS:

Examiner ends JPM at this point.

Tuesday, Jaiiw,ri 27, 2(115 Page ii o/12

JPM SETUP SHEET JPM NO: NJPP-040 DESCRIPTION: 2015 NRC In-Plant k RO: Transfer a Vital 120 Volt Instrument Power Supply ICSET: NA INSTRUCTIONS:

COMMENTS:

Ttisda, January 27, 2015 Page 12 of 12

JPM BRIEFING SHEET OPERA TOR ItVSTRUCTIONS:

SAFETY CONSIDERATIONS:

IN! TL4L CONDITION: Plant is at 100% power. Al Train maintenance work. XIT-5901 is scheduled for preventive maintenance.

INITIATING CUES: Shift Supervisor directs that XIT-5901 be removed from service and APN-5901 be placed on alternate power in accordance with SOP-310,Section IV.E for inverter PMs. Initial conditions are completed through step 1.4.

STP-506.005, DEENERGIZATION OF THE ESF LOAD SEQUENCER LOSS OF VOLTAGE AND DEGRADED VOLTAGE RELAYS has been completed.

A T NO TIME A RE YOU TO OPERA TE ANY PLANT EQUIPMENT!

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

jJPM k Handoutj SOP-31 0 REVISION 11 Placing APN59O1, 12OVOLT VITAL AC DISTR PANEL 1 NSSS on ALT SOURCE, from APNIFA, 120 VOLT AC INST MAIN DISTR PANEL lEA, will prevent the Train A Engineered Safety Features Load Sequencer from operating during a Blackout condition.

7

(Ø This procedure removes the Normal AC Source and the Backup DC Source from Inverter 5901 while providing a regulated AC power to APN59OI and APN5907 via APN1FA through InverterXlT59Ol operating in Bypass.

E. PLACING INVERTER X1T5901 IN AN ALTERNATE AC LINEUP 1.0 INITIAL CONDITIONS (j%i .1 A Pre-Job Brief has been conducted per OAP-1 00.3, Human Performance Tools. CHG D

APN59O1, 120 VOLT VITAL AC DISTR PANEL I NSSS, must remain

/ energized.

53 APN1 FA, 120 VOLT AC INST MAIN DISTR PANEL I FA, is energized.

APN1FA 19, ALT SOURCE FOR APN59O1 VIA XIT5901, is closed (CB-436).

1 .5 On X1T5901 the following breakers are closed:

a. ALTAC SOURCE.

b. BACKUP SOURCE.

c. NORMAL AC SOURCE.

D 1.6 The MAN BYPASS switch is in NORMAL.

D 1.7 The TEST TRANSFER switch is in the CENTER Position.

El 1.8 The SYNC MONITOR light is NOT lit.

PAGE 8 OF 95

SOP-31 0 REVISION 11 CAUTION 2.0 STP-506.005, De-Energization Of The ESF Load Sequencer Loss Of Voltage And Degraded Voltage Relays A Train, XEG0001A, should be completed on Train A prior to removing Inverter X1T5901 from service. This should be tracked on the Diesel Generator A R&R.

NOTE 2.0

a. All steps are performed in the Relay Room (CB-436) unless otherwise stated.

b. XCP-636 1-5 (INV 1/2 TROUBLE) and XCP-636 1-6 (INV 1/2 AC INPUT LOSS) will be locked in alarm at the completion of this procedure.

2.0 INSTRUCTIONS N01 2.1 Ensure Alternate Source voltage is acceptable for transfer:

a. Place the SOURCE SELECTOR switch in LINE. CHG D

b. Verify the Alternate AC Source voltage is acceptable as indicated by an AC OUTPUT voltage indication between 115 VAC and 125 VAC.

c. Place the SOURCE SELECTOR switch in OUTPUT.

NOTE 2.2 Placing the TEST TRANSFER Switch in the ALT Position forces the Static Switch to receive power from the Alternate Source and deliver it to APN59O1. This will also cause the following:

a) XCP-636 1-5 (INV 1/2 TROUBLE) annunciates (MCB).

b) ON ALTERNATE light illuminates.

c) ON INVERTER light is extinguishes.

2.2 Place the TEST TRANSFER switch in the ALT position.

PAGE 9 OF 95

SOP-31 0 REVISION 11 D 2.3 Verify that the ON ALTERNATE light is lit.

CAUTION Step 2.4 If the ON ALTERNATE light is not illuminated, then it cannot be verified that the Static Switch has aligned itself to receive power from the Alternate Source.

Proceeding with this procedure may result in a loss of APN59O1..

NOTE 2.4 and 2.5 The SYNC MONITOR light should illuminate when the INVERTER STOP pushbutton is pressed.

CHG D

2.4 Momentarily depress the INVERTER STOP pushbutton and verify the SYNC MONITOR light is lit.

2.5 If the INVERTER STOP pushbutton fails to stop the inverter, then complete the following:

a. Simulate depressing the pushbutton by directing the Electricians to install a switchable jumper device for the INVERTER STOP Pushbutton (S103) at terminal wires 142 and 143.

b. Actuate the switchable jumper device.

c. Verify the SYNC MONITOR light is lit.

d. Remove the switchable jumper device.

PAGE 10 OF 95

SOP-31 0 REVISION 11 NOTE 2.6 The transfer performed with the MAN BYPASS switch is a Make-Before-Break operation which provides a momentary paralleling of power sources.

D 2.6 Align Alternate AC power through the Static Switch to APN59O1 by rotating the MAN BYPASS switch clockwise to the BYP TO ALT Position.

2.7 Open the BACKUP SOURCE breaker on the Inverter front.

2.8 Open the NORMAL AC SOURCE breaker on the Inverter front.

2.9 Verify XCP-636 1-6 (INV 1/2 AC INPUT LOSS) is in alarm (MCB).

CHG D

NOTE 2.10 Bypass around the Static Switch fully isolates the Static wWch and the Inverter output from the Alternate Source and will cause the fo1l6wing:

1) XCP-636 1-5 (INV 1/2 TROUBL irliinciates (MCB).

2) AC OUTPUT FAIL ligh>

3) ALTERNATE A lights.

2.10 )dred, rotate the MAN. BYPASS switch clockwise to the BYP TO ALT ISOLATE position to align Alternate AC power around the Static Switch to APN59OI.

PAGE 11 OF95

NPI1 x SO P-3 10 REVISION 11 If the electricians are to perform invejtéMs and breakers are NOT red tagged, Step 2.10 may be omitted.

CHG D

2.11 Open they ngfeeder breakers:

a. DA2Y O6ABL, INVERTER 1 NSSS FEED XIT59O1EV (AB-412).

DPN1HA22, INVERTERXIT59O1 (IB-412).

END OF SECTION PAGE 12 OF 95

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPM NO: NJPA-021 A(R1) 2015 NRC ROISRO Common Al-a:

Perfqrm Boric Acid Dilution Volume Determination CA ND I [) ATE:

EXA MINER.

JVetIiie.st/mn, Iprit 15, 2015 Page 1 of 7

TASK:

004-006-01 -01 PERFORM BORIC ACID CONCENTRATION CHANGE CALCULATION TASK ST.4ADARD:

Examinee determines that about 9359 gals (interpolated value) will be required for dilution. A range of 9250 to 9450 ( +1- 100 gal or 1%) would be acceptable. lithe examinee elects to calculate vice interpolate, the calculated value is the same range. Examinee determines that available volume in Recycle Holdup Tank is NOT sufficient to accomodate the calculated dilutior Volume required exceeds the volume at overflow 44,353 gallons required vice 42,989 gallons al overflow.

TERj1IINATING CUE: Calculations completed.

PREFERRED E V4L UA TION LOCATION PREFERRED E1AL U-I TION METHOL CLASSROOM PERFORM

REFERENCES:

SOP-l06 REACTOR MAKEUP WATER SYSTEM INDEX NO. AM tVO. RO SRO 1940012125 2.1.25 Ability to interpret reference materials 3.9 4.2 such as graphs, curves, tables, etc.

1940012137 2.1.37 Knowledge of procedures, guidelines, or 4.3 4.6 limitations associated with reactivity management.

TOOLS: Curve Book (Accessible via Desk Top Computers)

Calculator JPM Al-a, Dilution Calculation hand out.

EVALUATION TIME 20 TIME CRITIU4L NO 10CFRSS: 45(a)(12)

TIME START. TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SAT: UNSAT:

(ANDIDA TE:

EXAMINER:

S IGNATURU DATE Wi1nesdav, -Ip%l 15, 2(115 Page 2 of 7

INSTRUCTIONS TO OPERA TOR READ To OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: The plant is in MODE 3 preparing for reactor startup in accordance with GOP-3.

Latest RCS boron sample was 2038 ppm.

Estimated critical boron concentration is 1688 ppm.

A Recycle Holdup Tank is in service.

A Recycle Holdup Tank level is 83%.

ItVITIATING CUES: The SS directs you to perform the following:

1. Determine the dilution volume required to establish the estimated critical boron concentration.

2.Determine if the necessary volume is available in A Recycle Holdup Tank to accomodate the dilution. Assume that RCS temperature and Pressurizer Level remain constant. Show evidence to support your determination.

Show all work on the JPM Al-a Dilution Calculation hand out provided.

11,1 ND JP1J BRIEFING ShEET TO OPERA TOR I T TillS TIME!

Ied,,esc1o, -Iprit 15, 2015 Page 3 of 7

STEPS CRITICAL: Yes SEQUENCED: Yes SAT UNSA T STEP: 1 Examinee determines that the amount of dilution required.

STEP STANDARD:

Determines Ci - Cf = 350 ppm dilution required.

CUES:

Evaluator note: Ci and Cf values are given in the initiating cue.

COMMENTS:

(RI TICAL: Yes SEQUENCED: Yes 54 T UNSA T STEP: 2 Selects correct curve from curve book.

STEP SL4NDARD:

The examinee refers to Figure 111-3, RCS Dilution Gallons (Vw) of Dilution Water Required, in the Curve Book.

CUES:

Evaluator note: Do NOT prompt Examinee on location of the dilution tables.

COMMENTS:

Wednesdqv, .-prit 15, 2015 Page 4 of 7

CRITICAL: Yes SEOUENCED: Yes SAT UNSAT STEP: 3 Examinee interpolates or calculates the volume of water required and reports the dilution volume required to the CR5.

P STANDARD:

Examinee determines that 9359 gals (interpolated value) will be required for dilution.

CUES:

Evaluator note: The volume reported to the CR5 should be the interpolated value or greater. A range of 9250 to 9450 (-+/- 100 gal) would be acceptable. If the examinee elects to calculate vice interpolate the same range applies. See NJPA-021A(R1) Key for calculations.

CO1IMENTS:

CRITICAL: Yes SEOUENCED: Yes SAT UNSAT STEP: j 4 Examinee determines if adequate volume is available in the A Recycle Holdup Tank.

TEP STANDARD:

Volume required = 35,000 + 9,353 = 44,353 gallons (Minimum = 43,750 gallons)

Volume available = Volume at overflow = 42,989 gallons Required Volume > Volume available Recycle Holdup Volume is NOT Adequate CUES:

Evaluator note: Examinee will refer to Curve Book Figure Vl-24, Recycle Holdup Tank Volme XTK0006A/B to determine volume required and volume available. See NJPA-021A(R1) Key for calculations. The critical aspect of this step is to determine that adequate volume is NOT available.

COMMENTS:

Examiner ends JPM at this point.

1priI 15, 2015 Ptige 5 tf 7

JPM SETUP SHEET JPMNO: N]PA-021A(Rl)

DESCRIPTION: 2015 NRC RO/SRO Common Al-a: Perform Boric Acid Dilution Volume Determination ICSET: NA INSTRUCTIONS:

COMMENTS:

Weclitescia, -1prit 15, 2015 Pt,gc 7 of 7

JPM BRIEFING SHEET OPERA TOR iNSTRUCTIONS:

SAFETY CONSIDERA TIONS:

INITIAL CONDITION: The plant is in MODE 3 preparing for reactor startup in accordance with GOP-3.

Latest RCS boron sample was 2038 ppm. V Estimated critical boron concentration is 1688 ppm.

A Recycle Holdup Tank is in service.

A Recycle Holdup Tank level is 83%.

IN! TIA TING CUES: The SS directs you to perform the following:

1. Determine the dilution volume required to establish the estimated critical boron concentration.

2. Determine if the necessary volume is available in A Recycle Holdup Tank to accomodate the dilution. Assume that RCS temperature and Pressurizer Level remain constant. Show evidence to support your determination.

Show all work on the JPM Al-a Dilution Calculation hand out provided.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

JPM Al-a (RI) Dilution Calculation Handout Examinee:

Date:

Dilution Volume Required A range of 9250 to 9450 t +1- iOçiaI) icceptab1e if ierpolat;on is used A range of 9250 to 9450 (- +ihOs accabfrifalculation is used.

V*

Recycle Holdup Volume Adequate?

Volume required = 35,000 + 9,353 = 44,353 gallons (Minimum = 43,750 gallons)

Volume available = Volume at overflow = 42,989 gallons Required Volume > Volume available Recycle Holdup Volume is NOT Adequate I

Revision Date: /1 /J_LJ Prepared By:

Verified By:

Approved By::

FIGURE ffi-3. RCS DILUTION GALLONS () OF DILUTION WATER REQUIRED M

(Cm

=R 13,500 ibm)

Vw =

n C1 =

() =

Initial ppm

() C = final ppm I PPM BORON DEDUCTION ( ( C)

C1 ppm ri5 50 375 40(Vl 425 4

I 450 475 500 550 600 2,400 6,913 7,223 7.487 7.825

+ 8,067 8,434 92i 9.851 10,307 10,460 10,948 11.077 11.597 12,334 12,920 13,623 14,280 E8ppm

= 2,300 2,200 2,100 7,562 7,935 8,346 8,195 8,601 9.050 8,835 9,277 9,765 /

9,484 9,96i 10,489 10,141 10,656 11225 10.808 11,360 11.971 11,483 12,074 12.7 12,168 12.799 13,566 14,280

- 15,005 15,808 2,000 8,803 9,549 10,07 11,077 11.859 12,653 13. Calculation for Dilution 1,900 9,312 10,107 10914 11.734 12,569 13,417 14 / 203$

1,800 9,885 10,733 11,597 12,475 13,370 14280 15,2 Vw 49640 In J688 14280 15,263 16 Vw = 49640 In (1 .20735)

Interpolation for Dilution 15,326 16393 17A 9050 9549 9050 - X Vw 9353.5 16,537 17,705 2100-2000 2100-2038 I 17,959 10 MO 7flc77 I 71 Q 7477fl I 77770

-499 9050-X 19,652 A range of 9250 to 9450 (- +1- 100 ga 100 62 21,703 is acceptable if calculation is used

-309,4 = 9050-X 28,062 30,088 34.408 I222 26,115 39.139 x = 9359.4 27,470 29,677 31,986 34,408 39,638 45.485 31,724 34.408 37245 40254 46,883 54,535 800 25,877 28,561 31,398 34,408 37,611 41.036 44,715 48.688 57,739 68,815 700 30.983 34.408 38,086 42.060 46,379 5 1,110 56.340 62.187 76,467 96,595 fJ1 R727 44R I 4RRX ccc 61 16 .2 77,866 88.943 1123350 A range of 9250 to 9450 (- +1- 100 gal) 1148.708 is acceptable if interpolation is used j 300 200 100 Note: See Figure ffl-6 For Correction Factor Tech. Spec. Ref.: N/A Procedure Ref.: N/A figure Ref: DC0004O-068

C. V Level Gallons Available Figure: Vl-24 Recycle Holdup Tank Volume XTK0006NB 0% 0 Revision Date: -S 03 2112 Preparedby:

l LlI -l+/-HH-H-I-l-Hl I I

- : 6,335 Approved by:

Initial Recycle Holdup Tank Level = 83% ,?/P L.

. 55/ 23229 i++F1 -f-+-1-4 I eoi 25341 a 65/ 27453 1

70 Adequate Volume Calculation 33768 65 Volume requtred 21 rrr, II

+ -

- - - 95/0

.j,J.VUV cS.3,J.J.J t,....i... 3iOflS 40.123 60 I00/ 42,235

2 :

- Ovorllow 42989 Minimum acceptable requited volume

--- i 34 500 +9 250 = 43 750 gallons NOTE This tigure only includes volume above the pump suction!

so : : : tower instrumonttap centerline (0% level). The volume below the 0%level is 912 gallons.

Volume at overflow = 42,989 gallons -

The volume between the 100 / level and the 45 overllow level is 753 gellons a

Volume Required > Volume at ovelow -

3° Adequate Volume NOT Available E

- Uçpe T 2

- 35 500 gallons 0 --

34500gallo MnrnumToleranc 5 Minimum Tolerance LowohstrumontT 35%4 0 5 10 15 20 25 30 45 -

Useabie Volume (1,000 gal.l 35,000 Gallons Initial Volume Tech Spec Ret.: NIA Procedure Ret.: SOP-lOl Figure Ret.: 0C04360-004 Rev. 0

JPM Al-a Dilution Calculation Handout Examinee:

Date:

Dilution Volume Required Recycle Holdup Volume Adequate?

V. C SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE

.J?MNO: NJPA-I000 (RI) 2015 NRC RO/SRO Common Al-b:

Calculate Work Hour Limitations.

CAN D1DAT[:

EXAMINER llondap, April 20, 2015 Pcige I of 7

TASK:

341-038-03-02 INTERPRET AND ENSURE COMPLIANCE WITH PLANT ADMINISTRATIVE PROCEDURES DURING NORMAL AND OFF NORMAL PLANT OPERATIONS TASK STANDARD:

Determines that work hours would be exceeded by RO-1, due to not having a 34 hour3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months break in the 9 calendar days frofh 1/29 through 2/6 OR due to exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months worked in the 168 hour0.00194 days 0.0467 hours 2.777778e-4 weeks 6.3924e-5 months (7 day) period from 1900 1/30 to 1900 2/6. Work hours are exceeded by RO-2 due to not having an average of 2.5 days off in the 5 week fixed cycle.

TERMINATING CUE: Reviews work history and determines that RO-3 is eligible while RO-1 and RO-2 are NOT eligible to work the requested overtime shift without a waiver.

PREFERRED E V4L UA TION L 0C4 TION PREFERRED E V4L VA TION METHOD CLASSROOM PERFORM

REFERENCES:

SAP-i 52 FATIGUE MANAGEMENT AND WORK HOUR LIMITS INDEX NO. KA NO. RO SRO 1940012105 2.1.5 Ability to use procedures related to shift 2.9 3.9 staffing, such as minimum crew complement, overtime limitations, etc.

TOOLS: JPM Al-b Work Sheet Handout.

JPM Al-b Schedules Handout.

SAP-i 52 (Available on Desk Top Computer)

Calculator EVALUATION TIME 40 TIMECRITICAL NO JOCfRS5: 41(b)(iO)

FirviE SiA1F FIv1I tlNISII: t)ER1:(:)R4A NEt::: TiM PERFORMANCE RATING: SAT: UNSAT:

C4NDIDA TE:

/

EXAMIiVER: /

S Ri NATU RE [)AiE

.1JOfldti, Jpril 20, 2(115 Page 2 of?

INSTRUCTIONS TO OPERATOR READ TO OPERA fOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY COiVSIDERA TIOiLc: None.

INITIAL CONDITION: The Unit is at 100% power currently and has been at power continuously for the last 3 months.

The regular on-line 5 shift rotation is in effect.

The Control Room has been informed on February 5 night shift that an RD scheduled for the February 6 day shift cannot work due to illness.

You are asked to identify if any of three available individuals are eligible to work as an RD for Thursday February 6 day shift.

INITL4 TING CUES: Given the work schedules provided (JPM Al-b Schedules Handout) determine if any of three available ROs (RD-i, RO-2 or RO-3) are eligible to work the day shift beginning at 0700 on February 6 without reliance on a waiver or change to the scheduled CT.

JPM Al-b Schedules Handout includes all hours actually worked by all three ROs after December 31 AND all hours projected to be worked through February 28.

If any of the ROs is NOT eligible, identify the criteria that supports your determination.

Use the VCS fixed shift cycle method which begins on the first night of the 3 night portion of the schedule.

Assume RO-l, RO-2 and RO-3 are fully qualified. Show all work on JPM Al-b Work Sheet Handout provided.

11.1 ND JPM BRIEFING SHEET TO OPEKI TOR AT Tills TIME!

lIo,,dtgj, April 2D, 2015 Page 3 i./ 7

STEPS CRITICAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 1 Reviews RO-i work history to determine if RO-i is eligible to work the day shift on February 6.

STEP STANDARD:

Compares work history for RO-1 to SAP-i 52 criteria and notes that RO-1 is not eligible to work without reliance on a waiver based on either ONE of the following:

Identifies that RO-1 would not have had the required 34 hour3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months break within the previous 9 calendar days. He would have had only a single 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months break (0700 on 2/4 to 0700 on 2/5) in the 9 days from 1/29 through 2/6.

or Identifies that RO-i would exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months worked in the 168 hour0.00194 days 0.0467 hours 2.777778e-4 weeks 6.3924e-5 months (7 day) period from 1900 1/30 to 1900 2/6. He would have worked 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months in the 168 hour0.00194 days 0.0467 hours 2.777778e-4 weeks 6.3924e-5 months period.

CUES:

Evaluator cue: Provide a copy of JPM Al-b Work Sheet Handout and JPM Al-b Schedules Handout to the examinee. Instruct examinee to put their name and the date on JPM Al-b Work Sheet Handout and to return it to you when they are finished. Instruct Examinee to show all work on the Handout.

Evaluator note: SAP-i 52, Fatigue Management and Work Hour Limits should be referenced while I reviewing JPM Al-b Schedules Handout.

Evaluator note: The cycle for RO-l runs from Jan 7 through Feb 10 (fixed five weeks).

Evaluator note: Refer to NJPA-1 000 (Ri) Key. Critical elements are to determine eligibility and the correct reason for eligibility.

COMMENTS:

,,dc,v, -1pri1 20, 2015 Pt,ge 4 0] 7

CRITICAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 2 Reviews RO-2 work history to determine if RO-2 is eligible to work the day shift on February 6.

STEP STANDARD:.

Conapares work history for RO-2 to SP-1 52 criteria and notes that RO-2 is NOT eligible to work without reliance on a waiver.

Identifies that RO-2 would not have had an average 2.5 days off per week averaged over the shift cycle. If RO-2 works 2/6 he would have had 12 days off in the 5 week cycle, an average of 2.4 days per week CUES:

Evaluator note: The cycle for RO-2 runs from Jan 14 through Feb 17 (fixed five weeks).

Evaluator note: Refer to NJPA-1 000 (Ri) Key. Critical elements are to determine eligibility and the correct reason for eligibility.

COil1MENTS:

l!oiidtii. .4pri! 20, 2015 Page 5 of 7

CRITIc4L: Yes SEQUEN(ED: Yes SAT UNSA T STEP: J 3 Reviews RO-3 work history to determine if RO-3 is eligible to work the day shift on February 6.

STEP STANDARD:

Compares work history for RO-3 to SAP-i 52 criteria and notes that RO-3 is eligible to work without reliance on a waiver.

CUES:

Evaluator cue: Inform the examinee that the JPM has ended when they return JPM Al-b Work Sheet Handout to you.

Evaluator note: Refer to NJPA-i 000 (Ri) Key. Critical elements are to determine eligibility and the correct reason for eligibility.

[COMMENTS:

Examiner ends JPM at this point.

l(o,,dup, April 20, 2015 Page 6 of?

JPM SETUP SHEET JPMNO: NJPA-1000 (Ri)

DESCRIPTION: 2015 NRC RO/SRO Common Al-b: Calculate Work hour limitations.

ICSET: NA INSTRUCTIONS:

COMMENTS:

Ioiit1av, April 20, 2015 Page 7of?

JPM BRIEFING SHEET OPERA TOR iNSTRUCTIONS:

SAfETY CONSIDEK4 TIONS: None.

INITIAL CONDITIOTL The Unit is at 100% power currently and has been at power continuously for the last 3 months.

The regular on-line 5 shift rotation is in effect.

The Control Room has been informed on February 5 night shift that an RO scheduled for the February 6 day shift cannot work due to illness.

You are asked to identify if any of three available individuals are eligible to work as an RO for Thursday February 6 day shift.

INITIATING CUES: Given the work schedules provided (JPM Al-b Schedules Handout) determine if any of three available ROs (RO-l, RO-2 or RO-3) are eligible to work the day shift beginning at 0700 on February 6 without reliance on a waiver or change to the scheduled OT.

JPM Al-b Schedules Handout includes all hours actually worked by all three ROs after December 31 AND all hours projected to be worked through February 28.

If any of the ROs is NOT eligible, identify the criteria that supports your determination.

Use the VCS fixed shift cycle method which begins on the first night of the 3 night portion of the schedule.

Assume RO-l, RO-2 and RO-3 are fully qualified. Show all work on JPM Alb Work Sheet Handout provided.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

JPM Al-b Work Sheet Handout Examinee Name: Date:

Note:

1. JPM Al-b Schedules Handout includes all hours actually worked by RO-l RO-2 and RO-3 after December31 AND all hours projected to be worked through Feb 28.

2. Day shift is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; 0700 to 1900 and Night shift is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1900 to 0700 and Training is 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months 0730 to 1730.

1.-Place a check mark in the appropriate box for RO-J, RO-2 and RO-3.

2. Provide basis if a worker is NOT eligible E RO-1 is eligible to work 0700-1900 on 2/6.

RO-1 is NOT eligible to work 0700-1 900 on 2/6.

IF RO-1 is NOT eligible to work the overtime STATE the basis:

Per SAP-152 6.1.1 F. an individual must have at least one 34 hour3.935185e-4 days 0.00944 hours 5.621693e-5 weeks 1.2937e-5 months brealin any 9 calendar days. If RO-1 works 2/6 he would have had only a single 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months break (0700 on 2/4 to 0700 on 2/5) in the 9 days from 1/29 through 2/6. In addition SAP-152 6.1.1 C. allows no more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in any 7-day period. If RO-1 worked the proposed 01 he would have worked 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months in the 168 hour0.00194 days 0.0467 hours 2.777778e-4 weeks 6.3924e-5 months period from 1900 on 4/30 through 1900 on 216 Either reason is adequate for pass on the JPM The cycle for R0-1 I runs from Jan 7 through Feb 10 (fIxed five weeks) .

E RO-2 is eligible to work 0700-1900 on 2/6 RO-2 is NOT eligible to work 0700-1900 on 2/6.

IF RO-2 is NOT eligible to work the overtime STATE the basis I 1 Per SAP-152 6 1 2 A an individual must have on average 2 5 days off per week averaged over the shift cycle If RO 2 works 216 he would have had 12 days off in the 5 week cycle an average of 2 4 days per week The cycle for R0-2 runs from Jan 14 through Feb 17 (fixed five weeks)

RO-3 is eligible %work 0700-1900 on 2/6.

RO-3 is NOT eligible to work 0700-1 900 on 2/6.

IF RO-3 is NOT eligible to work the overtime STATE the basis:

I The cycle for R0-3 runs from Jan 7 through Feb 10 (fixed five weeks)

Page lof 2

JPM Al-b Work Sheet Handout Examinee Name: Date:

Note:

1 JPM Al-b, Schedules Handout includes all hours actually worked by RD-i, RO-2 and RO-3 after December31 AND all hours projected to be worked through Feb 28.

2. Day shift is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; 0700 to 1900 and Night shift is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1900 to 0700 and Training is 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months 0730 to 1730.

1. Place a check mark in the appropriate box for RO-1, RO-2 and RO-3.

2. Provide basis if a worker is NOT eligible RD-i is eligible to work 0700-1900 on 2/6.

RD-i is NOT eligible to work 0700-i 900 on 2/6.

IF RD-i is NOT eligible to work the overtime STATE the basis:

I RD-2 is eligible to work 0700-1900 on 2/6.

RO-2 is NOT eligible to work 0700-1900 on 2/6.

IF RO-2 is NOT eligible to work the overtime STATE the basis:

RO-3 is eligible to work 0700-1 900 on 2/6.

RD-3 is NOT eligible to work 0700-i 900 on 2/6.

IF RO-3 is NOT eligible to work the overtime STATE the basis:

Page lof 2

JPM Al-b Work Sheet Handou Additional work:

Page 2 of 2

]PMA1-b Schedules Handout Jan-14 W Th F S S M T W Th F S S M T w Th F S S M T w Th F S S M T WITh I Fl Shift 1 2 3 4 5 6 7 $ 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 RO1OTN N N N D D D D I I T T D D D OTNOTN N RO2OTNNNNNOTNOThNNNOTNDDDDOTDTT I T R03 OTN N N N OTD D D D D T T T T D D DOTD OTN N Feb-14

f I W Th 5 5 M T W F S S M T W Th F S S M T W Th 5 S M F Shift 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 ROl N N N OTD N N N OTD D 0 D 0 T *T T I R02 D D D EOTD N N N N OTN OTN N N N 0 0 D D R03 N N N OTD N N N OTN D D D D T .1 T T edoveimeshift Note:

1. QTD = Overtime Days

2. OTN = Overtime nights

1. N and OTN = 1900 to 0700; 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months worked

2. D and OTD = 0700 to 1900; 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months worked

3. T = training; 0700 to 1700; 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months worked

V. C. SUMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPA-I 006 (RI) 2O15NRCROA2:

Determine Surveillance Requirements due to loss of Main Control Board Annunciators (AN DIDAFE:

I XA MINI R:

lio,,dap. 1pril 6, 2015 Page 1 of 6

TASK:

000-1 70-05-0 1 Respond to loss of Main Control Board annunciators per AOP-1 00.5.

TASK ST4NDARD:

Identifies the following panels from Attachment 2:

XCP-610, 611, 612, 613, 614, 615, 616, 617, 618, 619, 620, 621, 624 and 626 Identifies the following surveillance requirements from Attachment 3:

XCP-615, 2-5; GTP-702 Aft IV.G XCP-615, 3-3; GTP-7O2AttVl.V-3 XCP-615, 3-6; CAP-i 06.1, RB Sump Level and STP-114.002 XCP-620, 1-5; GTP-702, Att lV.E XCP-620, 1-6; GTP-702, Att IV.E XCP-620, 2-4; GTP-702, Att IV.D XCP-620, 2-5; GTP-702, Att IV.B XCP-620, 4-2; GTP-702, Att Vl.L-2 (not critical)

XCP-620, 4-3; GTP-702, Att Vl.L-2 (not critical)

XCP-621, 1-1; GTP-702, Aft IV.C TERMINATING CL/F: Identifies required Surveillance Attachments associated with XCP-615, XCP-620 and XCP-621 from AOP 100.5 Attachment 3.

PREFERRED F VAL (TA HON LOCATION PREFERRED EVALUATION METHOD CLASSROOM PERFORM

REFERENCES:

AOP-1 00.5 Loss of Main Control Board Annunciators INDEX NO. K/A iVO. RO SRO 1940012214 2.2.14 Knowledge of the process for controlling 3.9 4.3 equipment configuration or status.

TOOLS: Copy of AOP-1 00.5, Loss of Main Control Board Annunciators available on desk top computers.

JPM A2 RO Handout 1; AOP-1 00.5 Attachment 2 JPM A2 RO Handout 2; AOP-1 00.5 Attachment 3 EVALUATION TIME 5 TIME cRITiCAL NO ]0CfR55: 45(a)(3)

TIME START: TIME FINISH: PERFORMANCE TIME:

PERFORMANCE RATING: SVt: UNSAl C4NDIDA TE:

EXAMINER:

SIGNAl URU t)ATF iIOfldtI), Iprll 6, 2tIS Page 2of6

INSTRUCTIONS TO OPERA TOR READ To OPERATOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIOIJS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIEL . ..

SAFETY CONSIDERATIONS: NA INITIAL CoNDITION: The plant is at 100% power. A loss of multiple Main Control Board annunciators has been experienced due to a loss of power.

INITIATING CUES: I&C has verified that breaker DPN 1 HX1 01 has tripped. The CRS has directed you to use the applicable Abnormal Operating Procedure (AOP) and:

1) Identify all affected Main Control Board Annunciator panels.

2) Identify all surveillance requirements associated with affected panels.

Record your answer on the JPM briefing sheet.

!IJND JPM BRiEFING ShEET TO OPERATOR AT TillS fl111E!

iIo,iila, .4pril 6, 2015 Page 3 of 6

STEPS (RITIC4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 1 Refers to AOP-1 00.5 Attachment 2 to determine which Annunciator panels are associated I with DPN 1HX1 01 -. . -

STEP STANDARTh Identifies that the following Annunciator panels are affected:

XCP-610, 611, 612, 613, 614, 615, 616, 617, 618, 619, 620, 621, 624 and 626 CUES:

Evaluator cue: Tell examinee to put their name on the JPM Briefing Sheet.

Evaluator note: Examinee will identify applicable panels using AOP-1 00.5 Attachment 2 and the initiating cue of panel DPN 1 HX1 circuit 01 has tripped.

Evaluator note: If Examinee asks for a hard copy of AOP-100.5 Attachment 2 provide them with a copy of JPM A2 RO Handout 1.

COMMENTS:

IIlt)I?dtiV, April 6, 2015 Page 4 of 6

CRITICAL: Yes SEOUENCED: Yes SAT UNSAT

[STEP: 2 REFER TO ATTACHMENT 3, SURVEILLANCE ANNUNCIATORS, for annunciators that have surveillance requirements.

STEP STANDARD: . V Identifies the following surveillance requirements from Attachment 3:

XCP-615, 2-5; GTP-702 Att lV.G XCP-615, 3-3; GTP-702 Att Vl.V-3 XCP-615, 3-6; OAP-i 06.1, RB Sump Level and STP-114.002 XCP-620, 1-5; GTP-702, Att lV.E XCP-620, 1-6; GTP-702, Att IV.E XCP-620, 2-4; GTP-702, Att lV.D XCP-620, 2-5; GTP-702, Att IV.B XCP-620, 4-2; GTP-702, Aft Vl.L-2 (not critical)

XCP-620, 4-3; GTP-702, Aft Vl.L-2 (not critical)

XCP-621, 1-1; GTP-702, Aft IV.C CUES:

Evaluator note: refer to NJPA-1 006 (Ri) Key for expected response.

Evaluator note: If Examinee asks for a hard copy of AOP-i 00.5 Attachment 3 provide them with a copy of JPM A2 RO Handout 2.

Evaluator note: Examinee may include reference to STP-1 34.001, Shutdown Margin Verification based on supplemental action of XCP-620, 4-2 or 4-3. This surveillance is not critical and not required as both Hi Flux at Shutdown annunciators are inoperable and GTP-702, Aft Vl.L-2 addresses the condition.

Evaluator note: GTP-702 Att Vl.L-2 is NOT critical as the requirements are NOT applicable in Mode 1.

COMMENTS:

Examiner ends JPM at this point.

lit)11da3, April 6, 2015 Page Sof6

JPM SETUP SHEET JPJ3f NO: NJPA-1006 (Ri)

DESCRIPTU)N: 2015 NRC RO A2: Determine Surveillance Requirements due to loss of Main Control Board Annunciators ICSET: NA INSTRUCTIONS:

COMMENTS:

iiio,idap, April 6, 2015 PugL 6 of 6

JPM BRiEFING SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERATIONS: NA INITIAL CONDITION: The plant is at 100% power. A loss of multiple Main Control Board annunciators has been experienced due to a loss of power.

INITIATING CUES: l&C has verified that breaker DPN HX1 01 has tripped. The CRS has directed you to use the applicable Abnormal Operating Procedure (AOP) and:

1) Identify all affected Main Control Board Annunciator panels.

2) Identify all surveillance requirements associated with affected panels.

Record your answer on the JPM briefing sheet.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

AOP-100.5 tNJ PA-I 006 (Ri), Answer Key 1 REVISION 0 ATTACHMENT 3 PAGE 1 of 1 SURVEILLANCE ANNUNCIATORS I

Identifies these Surveillance Attachments as required.

GTP-702 Att Vl.L-2 is NOT critical since requirement This matrix is to aid in identifying f does not apply in Mode 1.

The applicable ARP shoud be utilized when performing the surveiIIa,

\

,RNEL WINDOW SUR LLANCE A ACHMENT XCP-615 \ 2-5\ / GTP-702 \ IV.G XCP-615 \ 3-3 \ / GTP-702 \ VI.V-3 t

XCP-615 3-6 \ / OAP-1 06.1 RB SUM LEVEL I I I STP-114.002 N/A XCP-620 1-5 1 GTP-702 IV.E XCP-620 I 1-6 I GTP-702 J IV.E XCP-620 J 2-4 j GTP-702 IV.D XCP-620 2-5 1 GTP-702 / IV.B XCP-620 4-2 I \ GTP-702 / VI.L-2 /

XCP-620 4-3 / \ GTP-702 / VI.L-2 /

CP-62 1-1/ GTP-70y iV.CJ Xc2 NBiV.D, lyE, VI.KK, VI.NN Hentifies Panels XCP-610, 611, 612, 613, 614, 615 616 STEMPS B SUMP LEVEL 617, 61$, 619, 620, 621, and 624 as affected by applying :IW/J/MVAR5 AOP-1 00.5 Attachment 2 for breaker DPN 1 HX1 01. jENERIC LOG OAP-1 00.6 4jERATION AT 3NSED LIMIT OA-1 071 RESORATION OF 1PCEUNCTIONS XCP-638 1-4 OAP-106.1 IMWRVMVARS XCP-638 2-4 OAP-106.1 4 MWIKV/MVARS PAGE 7 OF 7

AOP- 100 .5 REVISION 0 JPM A2 RO Handout ATTACHMENT 2 RESTORATION OF FAILED MAIN CONTROL BOARD PAGE 1 of 1 ANNUNCIATORS A. Make a list of the annunciator panels lost.

B. Contact l&C to verify the source of power to the annunciator panel per the following table.

DPNIHA2O4 XPN6O9I I XCP-601, 604, 606, 60$. 622. 629. 636 I 13.7% MCB ANNUNCIATORS 13.7% MCB ANNUNCIATORS TOTAL DPN IW(1 02 XPN6092 I XCP-603, 62$. 630. 631. 632. 633 I 20.3% MCB ANNUNCIATORS XPN6093 I XCP-625. 627. 634. 635. 638 I 18.3% MCB ANNUNCIATORS 38.6% MCB ANNUNCIATORS TOTAL DPN 1KB 02 XPN6094 I xCp-602. 605. 607. 609. 623. 637 12.4% MCB ANNUNCIATORS 12.4% MCB ANNUNCIATORS TOTAL DPN JI-D(l 01 XPN6095 XCP-610, 611, 612, 613, 614, 615, 616 I$.3% MCB ANNUNCIATORS XPN6096 XCP-617, 61$, 619, 620, 621, 624, 626 17.0% MCB ANNUNCIATORS 35.3% MCB ANNUNCIATORS TOTAL I C. Determine if the actions taken in response to a failed annunciator are subject to OAP-1 13.1, Operator Workaround and Dark Board Program.

PAGE 6 OF 7

AOP-100 .5 REVISION 0 JPM A2 RO Handout 2 ATTACHMENT 3 PAGE 1 oIl SURVEILLANCE ANNUNCIATORS NOTE This matrix is to aid in identifying failed annunciators which have surveillance requirements.

The applicable ARP shoud be utilized when performing the surveillance.

PANEL WINDOW SURVEILLANCE AHACHMENT XCP-615 2-5 GTP-702 IV.G XCP-615 3-3 GTP-702 VLV-3 XCP-615 3-6 OAP-1 06.1 RB SUMP LEVEL STP-1 14.002 N/A XCP-620 1-5 GTP-702 IV.E XCP-620 1-6 GTP-702 IV.E XCP-620 2-4 GTP-702 IV.D XCP-620 2-5 GTP-702 IV.B XCP-620 4-2 GTP-702 VI.L-2 XCP-620 4-3 GTP-702 VI.L-2 XCP-621 7-1 GTP-702 IV.C XCP-632 6-5 GTP-702 IV.B, IV.D, IV.E, VI.KK, VI.NN I OAP-1 06.1 RB TEMPS RB SUMP LEVEL MW/KV/MVARS GENERIC LOG SR NI OAP-1 00.6 OPERATION AT LICENSED LIMIT OAP-107.1 RESTORATION OF IPCS FUNCTIONS XCP-638 14 OAP-106.1 MW/KV/MVARS XCP-638 24 OAP-106.1 MW/KV/MVARS I

PAGE 7 OF 7

V. C. SUMMER NUCLEAR STATION JOB PERFORMANCE MEASURE J?MNO: NJPA-210A (RI) 2015 NRC SRO A2: Determine Administrative ActiQns to Place 1DB on Alternate Feed.

CANDIDATE:

EXAMINER:

SRO ONLY tThndt,i, April 6, 2015 Page 1 of 6

TASK:

341-038-03-02 INTERPRET AND ENSURE COMPLIANCE WITH PLANT ADMINISTRATIVE PROCEDURES DURING NORMAL AND OFF NORMAL PLANT OPERATIONS TASK ST4NDARD:

Section 1 and 2 of the Removal and Restoration Checklist is completed satisfactorily (see Key for NJPA-210A). It is critical to identify as an action R&R, that the Train is B, the Equipment ID is S XSW1 DB 16, Equipment name is Bus 1DB Normal Incoming Breaker, to indicate that the IS is 3.8.1.1.a (the a is optional), that 3.0.4 does apply, that the restraining mode is 4 and that the mode discovered is , Compensatory Requirements are GTP-702, Att. VI.Y-1.

TERAIJNA TING CUE: After the Removal and Restoration Checksheet is provided to the Evaluator this JPM is complete.

PREFERRED F V4L UA TION LOCATION PREFERRED EVALUATION ME THOD CLASSROOM PERFORM REFEKENCES:

OAP-1 06.1 Operating Rounds STP-125. 001 Electric Power Systems Weekly Test SAP-205 STATUS CONTROL AND REMOVAL AND RESTORATION SOP-304 11 5KV/7.2KV OPERATIONS T. S. Technical Specifications I INDEX NO. KA NO. RO SRO 1940012214 2.2.14 Knowledge of the process for controlling equipment configuration or status. 3.9 4.3 TOOLS:

JPM A2 SRO Handout (hardcopy of SAP-205, Attachment I, REMOVAL AND RESTORATION CHECKSHEET.)

Electronic access to the following:

SOP-304, 11 5KV/7.2KV OPERATIONS Technical Specification 3.8.1.

GTP-702, SURVEILLANCE ACTIVITY TRACKING AND TRIGGERING SAP-205, STATUS CONTROL AND REMOVAL AND RESTORATION OAP-1 06.1, OPERATING ROUNDS EV4LU4TION TIME 30 TIME CRITICAL NO 10CFRSS: 45(a)(1 3)

TIME START TIME FINISH: PERR)RNIANCE TIME.

PERFORMANCE 1t4 TING: SAT. IJNSAY.

CANDIDA TE:

EX4MINER:

SIGNATURE DATE t)!ondai, April 6. 2015 Page 2 of 6

INSTRUCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHLCH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS: None.

INITIAL CONDITION: 100% power.

51 Maintenance Week is in progress.

ESF Bus 1DB must be transferred to XTF-4/6 to allow XSW1 DB 16, BUS 1DB NORMAL INCOMING BKR to be replaced.

The Integrated Fire Computer is being fed from Train A.

XAC-1 2-IA, SUPP INST AIR COMPRESSOR is NOT running.

The work is expected to take approximately two hours. ESF Bus 1 DA will remain on the normal source during the work and alarm setpoints will NOT be adjusted since the alignment will only be in effect for approximately two hours.

The SOP operator is preparing a pre-job brief for the evolution.

INITI4 TING CUES: As the CRS, complete Section 1 and Section 2 of a Removal and Restoration Checksheet against XSW1DB 16, BUS 1DB NORMAL INCOMING BKR to track all the requirements associated with transferring Bus 1DB to XTF-416 including any necessary compensatory actions.

The R&R number 150333 has been assigned.

Record your answers in section 1 and section 2 of the provided SAP-205, Attachment I, REMOVAL AND RESTORATION CHECKSHEET (JPM A2 SRO Handout).

Note: The required by date and time for compensatory requirements if necessary will be filled in when the breaker is declared inoperable. You are to leave that field blank for this JPM.

HIND JPM BRIEFiNG SKEET TO OPER.i TOR AT THIS TIME.

17o,,da, April 6, 2(115 Ptige 3 of 6

STEPS CRITICAL: Yes SEQUENCED: Yes SAT UNSAT STEP: 1 Complete section 1 of SAP-205, STATUS CONTROL AND REMOVAL AND RESTORATION, Attachment I, REMOVAL AND RESTORATION CHECKSHEET.

STEP STANDARD:

The section 1 data are:

Type: Action (critical)

Service Impact: Removed From Service (NOT critical)

Train: B Train (critical)

R&R Number: 130333 (NOT critical)

System: ES (NOT critical)

Equipment ID: XSW1DB 16 (critical)

Equipment Name: Bus 1DB Normal Incoming Bkr (critical)

Reason Inoperable: Something to the effect of breaker replacement (NOT critical).

CUES:

Evaluator Note: Refer to NJPA-21 OA Key.

OMMENTS:

Ioiidar, April 6, 2015 Page 4 of 6

(RITIC4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 2 Complete section 2 of SAP-205, STATUS CONTROL AND REMOVAL AND RESTORATION, Attachment I, REMOVAL AND RESTORATION CHECKSHEET.

STEP STANDARD: .

The section 2 data are:

Compensatory Requirements: GTP-702, Att. Vl.Y-1 (critical)

I Other and some statement in Removal Comments about recording bus voltage hourly. (not critical.)

Technical Specifications: TS 3.8.1.1 .a (critical). (a may be left off)

Tech Spec 3.0.4 applies: Yes (critical)

Restraining Mode: 4 (critical)

Mode Discovered: 1 (critical)

Redundant Equipment Operable: Yes or No (not critical)

CUES:

Evaluator note: Refer to NJPA-21 0A key.

Evaluator Note: Redundant Equipment Operable is typically used for things like charging pumps that have a swing component, but in this case there is an alternate feed.

COAIi11ENTS:

Examiner ends JPM at this point.

Moi,dai, April 6, 2015 PageS 0/6

J?M SETUP SHEET JPMNO: NJPA-210A DESCRIPTION: 2015 NRC SRO A2: Determine Administrative Actions to Place 1 DB on Alternate Feed.

)CSET: NA INSTRUCTIONS:

COiVIMENTS:

NJPA-21 GA folder in the Exam Data folder contains answer key

,IOII1(il, April 6, 21)15 Page 6 q/ 6

1PM BRIEFING SHEET OPERA TOR INSTRUCTIOtVS:

SAFETY CONSIDERA TIOVS: None.

INITIAL CONDITION: 100% power.

Si Maintenance Week is in progress.

ESF Bus 1DB must be transferred to XTF-4/6 to allow XSW1DB 16, BUS 1DB NORMAL INCOMING BKR to be replaced.

The Integrated Fire Computer is being fed from Train A.

XAC-12-IA, SUPP INST AIR COMPRESSOR is NOT running.

The work is expected to take approximately two hours. ESF Bus 1 DA will remain on the normal source during the work and alarm setpoints will NOT be adjusted since the alignment will only be in effect for approximately two hours.

The BOP operator is preparing a pre-job brief for the evolution.

INITIATING CUES: As the CRS, complete Section 1 and Section 2 of a Removal and Restoration Checksheet against XSW1 DB 16, BUS 1DB NORMAL INCOMING BKR to track all the requirements associated with transferring Bus 1DB to XTF-4/6 including any necessary compensatory actions.

The R&R number 150333 has been assigned.

Record your answers in section 1 and section 2 of the provided SAP-205, Attachment I, REMOVAL AND RESTORATION CHECKSHEET (JPM A2 SRO Handout).

Note: The required by date and time for compensatory requirements if necessary will be filled in when the breaker is declared inoperable. You are to leave that field blank for this JPM.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

Examinee_ Mr SAP-205 ATTACHMENT I Date_______ II Indicates Critical Items PAGE 1 OF 1 I REMOVAL AND RESTORATION CHECKSHEET REVISION 10 YPE: SERVICE IMPACT: RAIN: R&R NUMBER:

Actiorit Removed From Service E1A Train 1JX Train

. QTracking [jRestricted Service 1B TraidN/A 750333 SYSTEM: :QUIPMENT ID: EQUIPMENT NAME:

ES XSW1DB 16 Bus 1DB Normal Incoming Brake c REASON INOPERABLE: I Breaker Replacement DOMPENSATORY REQUIREMENTS: Required By ECHNICAL oi IiJkLIuN:

ElNone Ci2L Date/Time lTrp/Bypass Bistables? .ia

JBackup Fire Suppression? / / 3.0.4 APPLIES: REDUNDANT EQUIPMENT OPERABLE:

Roving Fire Watch? / siniI,gMode:_4 1No 0*

0 Continuous Fire Watch? / I Mode Discovered: 1 0

0 JAlternate Radiation Monitoring? / / SUPPORTING DOCUMENTATION:

0 (1

Smoke Detectors Operable? / 4 / SOP-304, Technical Specification, 0

GTP-702Att. VI.Y-1 / OARIO6.1 Other SOP3O4 Precaution 111 requirehoujiy logs of bus voltages until the alarm setpoint is changed RELATED DOCUMENTS:

Operable STP Document 0 sflS/ Document # Comments E

]__completed OAP-106.1 (step 6.12.b 2) requires hourly logging regardless of setpoint change, either reference is acceptable, need to mention voltage logging as well as GTP-702 OYes uyes I ONo ONo OContinued on Attachment VII.

ON/A ON/A *ECR, MWR, NCN, PMTS, RIO, SITS, WPO, etc.

RESTORATION COMMENTS:

REMOVAURESTORATION STATUS: Updated SS Authorization OAIC Concurrence Date/Time MCB BISI EOOS 0

Declared Inoperable DYes DYes DYes

/ i 0

0 rime Limit to Declare Operable .

0 0 Restoration Required By I 0

0 0

Downgraded Olracking -

/

0 to: DRestricted Service /

0 E IJYes DYes 0

Declared Operable DYes

/ DN Inoperable . . .

Total Time: .. .

Non-Functional .

COMMENTS:

JPM A2 SRO Handout SAP-205 ATTACHMENT I xaminee PAGE 1 OF 1 REVISION JO ate REMOVAL AND RESTORATION CHECKSHEET YPE: SERVICE IMPACT: RAIN: R&R NUMBER:

E:IACuO El Removed From Service ElA Train DX Train

, Tracking DRestricted Service ElB Train DN/A SYSTEM: EQUIPMENT ID: EQUIPMENT NAME:

E D

(9 - V V

REASON INOPERABLE:

0 1

Ci)

COMPENSATORY REQUIREMENTS: Required By Completed FECHNICAL SPECIFICATIONS:

QNone Date/Time Date/Time QTrip/Bypass Bistables? / /

ElBackup Fire Suppression? / / APPLIES: DUNDANT EQUIPMENT OPERABLE:

QRovng Fire Watch? / / Restraining Mode: ElNo

& QContinuous Fire Watch? / / Mode Discovered:_ DN/A QAlternate Radiation Monitoring? / / SUPPORTING DOCUMENTATION:

QSmoke Detectors Operable? / /

QGTP-702 Aft. / /

DOther: / /

° REMOVAL COMMENTS:

RESTORATION REQUIREMENTS: RELATED DOCUMENTS:

Operable STP Completed Document Completed STTS Document Comments Date/Time Type Initials/Date I /

/ /

I /

0*

0

/ /

C 0 ll compensatory requirements ECR Operability /

0 0

restored or terminated? Form?

0 DYes DYes /

C, ElNo ElNo ElContinued on Attachment VII.

C DN/A DN/A *ECR MWR, NCN, PMTS, RTO, SUS, WPO, etc.

0 U RESTORATION COMMENTS:

0 Ci)

REMOVAURESTORATION STATUS:

SS Updated Authorization OATC Concurrence Date/Time MCB BISI EOO 0

Declared Inoperable c:IYes DYes DYes 0

/ ciNo ONo cyNo Ci)

C rime Limit to Declare Operable 0

0 Restoration Required By /

0 0

C, Downgraded ElTracking /

C, to: DRestricted Service 0

/

C, Declared Operable fts I Res C

0 Inoperable Totallime V

Non Functional COMMENTS:

V. C. SUMMER NUCLEAR STA TION JO.B PERFORMANCE MEASURE JPM NO: NJPA-083A(R1) 2011 and 2015 NRC Admin A3 RO & SRO:

Apply Facility ALARA Principles to a Specific Task and Determine Overall Dose CANDIDATE EXAMINER 41o,ida April 6, 2015 Page 1 cf 7

TASK:

000-06 1 02 RESPOND TO AREA RADIATION MONITORING SYSTEM ALARMS TASK STANDARD:

Calculate dose for each case. Determines exposure as 590 to 670 mR with a respirator and 537

- to 538 mR without a respirator. Determines that working WITHOUT respirator is the best option.

TERMIJ\ATING CUE: Options have been prioritized and provided to the Evaluator. -

PREFERRED EVAL U4 TION LOCA TIOIV PREFERRED F VAL U4 TION METHOL CLASSROOM PERFORM

REFERENCES:

HPP-0155 Control of Airborne Radiation Exposure (DAC-HRS)

VCS-HPP-01 53 Administrative Exposure Limits INDEX NO. K/A NO. RO SRO 1940012312 2.3.12 Knowledge of radiological safety 3.2 3.7 principles pertaining to licensed operator duties, such as containment entry requirements, fuel handling responsibilities, access to locked high-radiation areas, aligning filters, etc.

TOOLS: HPP-0153 and HPP-0155 (Available via desk top computer)

Calculator JPM A3 Handout 1 (Worksheet)

JPM A3 Handout 2 (Hardcopy of HPP-155 Attachment IX)

EV4LUAT1ON TIME 20 TIME CRITIC4L NO JOCfR5S: 45(a)(10)

TIME SIARI: TIIvIE FINIS[t: PERFORMANCETIME PERFORMANCE RATING: SKI: UNSA I CA NDIDA TE:

EXA tlftNER: -I

/

SIGNATURE DATE 4Ionda, April 6, 2(115 Page 2 of 7

INSTRUCTIONS TO OPERA TOR READ TO OPERA TOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPLAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLEtE TH TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS:

INITIAL CONDITION: A hydrogen explosion in the waste gas system has resulted in a radioactive leak.

The crew is performing actions of ARP-01 9 XCP- 644; 2-1 GAS DECAY TK AREA RM-G10 HI RAD.

The leak will continue until several manual valves are manipulated to isolate the leak.

The general area radiation level where the work will be performed is 1000 mR/hour.

Airborne activity in the work area is estimated at a Weighted Derived Air Concentration of 30 DAC.

There are two options for performing the work:

- One person without a respirator = 30 minutes or

- One person with an SCBA = 36 minutes.

INITIATING Ct/ES: You have been assigned to calculate the expected dose for the two options and to identify the best option between them according to the VC Summer ALARA philosophy. For the purposes of the JPM, assume that no dose is received in transit and there is no additional external exposure due to respiratory equipment setup. Place your name on the 1PM A3 Handout 1 and write your answer in the space provided. Round all calculation results to two (2) decimal points.

Show all work.

IilND JPII BRIEFING ShEET TO OPERA TOR IT TIhIS TIME!

lloiidtii. April 6, 2015 Page 3 of 7

CRITICAL: No SEQUENCED: Yes SAT Li] UNSA T STEP: 1 Access necessary reference material.

STEP STANDARD:

Reviews conditions and refers to procedures for respirator factors and DAC conversion.

Evaluator cue: Provide a copy of JPM A3 Handout 1 (worksheet) and if Examinee asks for a hard copy of HPP-1 55 Attachment IX provide JPM A3 Handout 2 (copy of HPP-1 55 Att IX)

Evaluator note: Procedures that are applicable are VCS-HPP-0153, Administrative Exposure Limits and HPP-O1 55, Control of Airborne Radiation Exposures (DAC-HRS). These are available via the desktop computers.

COMMENTS:

April 6, 2015 Page 4 tf 7

CRITK4L: Yes SEQUENCED: Yes SAT UiVSA T STEP: j 2 Calculate dose for each option - One person without respirator.

STEP STANDARD: .

External exposure = (1000 mr/hr) (1 hr/6G minUtes) (30 minutes) = 500mR Internal exposure = (30 DAC) (30 minutes) (1 hr/60 minutes) (2.5 mr/DAC-hr) = 37.5 mR.

Total Exposure without respirator 537.5 mR.

CUES:

Evaluator note: Acceptable range is 537 to 538 mR. Step is critical since an accurate calculation is required in order to make correct ALARA decision.

COMMENTS:

1 1I),l(It,l, April 6, 21)15 Page S of 7

CRITICAL: Yes SEQUENCED: Yes SAT EJ UN$A T STEP: 3 Calculate dose for each option - One person with a respirator.

STEP STANDARD:

External dose = (1000 mr/hr) (1 hrI6O minutes) (36 minutes) (1.1) = 660 mR Internal Dose = (30 DAC) (36 mm) (1 hr/60 mm) (2.5 mr/DAC-hr) (1.1)/(1000 protection factor) =

0.0495 mR.

Total Exposure with respirator = 660.05 mR.

CUES:

Evaluator note: Acceptable range is 590 670 mR. The acceptable range allows for failure to apply the respirator inefficiency factor of 1.1. This factor is not common knowledge. Step is critical since an accurate calculation is required in order to make correct ALARA decision.

COMMENTS:

CRITICAL: Yes SEQUENCED: Yes £4 T UNSA T STEP: 4 Determines best option lAW the lowest total dose.

STEP STANDARD:

Best option is: One person WITHOUT respirator.

CUES:

Evaluator note: Step is critical since the correct comparison must be made in order to make correct ALARA decision.

COMMENTS:

Examiner ends JPM at this point.

tltoi,dap, .4priI 6, 2015 Page 6 al 7

JPM SETUP SHEET JP3I NO: NJPA-083A(R1 DESCRIPTION: 2011 and 2015 NRC Admin A3 RO & SRO: Apply Facility ALARA Principles to a Specific Task and Determine Overall Dose ICSET: N/A INSTRUCTIONS:

COMMENTS:

iloiititi;, April 6, 2015 PtIgL 7 of?

JPM BRIEFiNG SHEET OPERA TOR INSTRUCTIONS:

SAFETY CONSIDERATIONS:

JNITL4 L CONDITION: A hydrogen explosion in the waste gas system has resulted in a radioactive leak.

The crew is performing actions of ARP-01 9 XCP- 644; 2-1, GAS DECAY TK AREA RM-G1O H[RAD.

The leak will continue until several manual valves are manipulated to isolate the leak.

The general area radiation level where the work will be performed is 1000 mR/hour.

Airborne activity in the work area is estimated at a Weighted Derived Air Concentration of 30 DAC.

There are two options for performing the work:

- One person without a respirator = 30 minutes or

- One person with an SCBA = 36 minutes.

INITIATING CUES: You have been assigned to calculate the expected dose for the two options and to identify the best option between them according to the VC Summer ALARA philosophy. For the purposes of the JPM, assume that no dose is received in transit and there is no additional external exposure due to respiratory equipment setup. Place your name on the JPM A3 Handout 1 and write your answer in the space provided. Round all calculation results to two (2) decimal points. Show all work.

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

JPM A3 Handout -1 1 Examinee Name Dose Calculation One Person without a respirator:

Dose from General Area field = (1000 mR/hr) (1 hr/60 minutes) (30 minutes) = 500 mR 1

I Dose from Airborne = 30 DAC (30 minutes) (1 hr!60 minutes) (2 5 mRr/DAC-hr) = 37 5 mR Dose Calculation One Person wfthirator Dose from General Area field= (1000 i) (1 hrI6O minutes) (36 minutes) (1.1) 660 mR Note, if Examinee does not apply non-efficiency factr; following is the external dose:

Dose from Generairea field =( 1000 mr/hr) (1 hr/60 minutes) (36 minutes)= 600 mR DAC) (36 mm) (1 hrI6O mm) (2 5 thr/DAC hr) (11)

Dose from = 0.0495mR 1000 protec factor N

a1 exposure wI Respirator = (660 + 0.05) mR = 660.05 mR (Accept 590-670 mR)

Best Option for ALARA: One Person WITHOUT respirator

JPMA3 Handout-i Examinee Name Calculation Work Space:

for A LARA

HPP-01 55 JPM A3 Handout 2 ATTACHMENT IX PAGE 1 OF 2 REVISION 13 TEDE ALARA Respirator Evaluation RWP #:

Task Evaluated:

1. Radiological Considerations for Respirator Use Average Expected Dose Rate in Work Area mremlhr (A)

Job Duration Expected hours (B)

Weighted DAC (WDAC) in Work Area DAC (C)

WDAC-hr = (Activity x Elapsed Time DAC Respirator Protection Factor (Enclosure B)* (D)

Respirator-induced Inefficiency Factor (Enclosure A) 1.10 (E)

Conversion Factor (Enclosure A) 2.5 mrem/DAC-hr (F)

TEDE = Total Exposure = External Exposure + Internal Exposure

a. Without Respiratory Equipment:

External = AxB = x = mrem (G) lnternal=CxBxF= x x2.5= (H)

TEDE=G+H= + =

b. With Respiratory Equipment:

External = AxBxE + Respe*

x x -I-

mrem (I)

Internal = (Cl D) x B x 1.10x2.5

=(_________

/ )x xl.10x2.5= mrem (J)

TEDE =I + J = + =

Respe = External exposure due to respiratory equipment set-up, if applicable. Contact Respiratory Services if assistance is needed to estimate equipment set-up time or to choose appropriate equipment for task.

These values are to be used to determine whether the use of respiratory protection will be detrimental to maintaining the work process ALARA.

2. Will wearing respiratory equipment increase the workers industrial safety risk? D or decrease the workers industrial safety risk?

HP P-U 1 55 ATTACHMENT IX PAGE 2 OF 2 REVISION 13 Comments:

3. Would not wearing respiyatory protection lead to post job negative implications?

a. Personnel decontamination El

b. Skin dose assessment El

c. Portal monitor alarms El U. Extensive bioassay evaluation El Comments:

4. Other considerations:

5. Overall Evaluation Respirator use j indicated El Respirator use is not indicated Evaluator Date

V. C. S UMMER NUCLEAR STA TION JOB PERFORMANCE MEASURE JPMNO: NJPA-I 003 (RI) 2075 NRC SRO A4: Classify Emergency (Simulator SAE

- - Inadequate Core Cooling) (ENF)

CAND1DAIi:

EXAMINER SRO ONLY TIME CRITICAL JPM Tuesdtn, -Ipri! 14, 2015 PtIgL I of 6

TASK:

344-01 9-03-02 CLASSIFY EMERGENCY EVENTS REQUIRING EMERGENCY PLAN IMPLEMENTATION T4SK STANDARD:

Emergency classification evaluated as a SITE AREA EMERGENCY per Fission Product Barriers EAL number FS1 .1. Classification based on Potential Loss of Fuel Clad Barrier (Item B-2 Core Exit TCs > 700F) and Loss of Reactor Coolant System Barrier (Item D.2 RCS leak rate> available make up capacity as indicated by a loss of RCS subcooling) or Potential Loss of Reactor Coolant System Barrier (D.2 Unisolable leak exceeding the capacity of one charging pump in the normal charging mode). This is a time critical ]PM and the declaration must be made within 15 minutes after the emergency condition exists, and uccessful completion of EPP-002, Communication and Notification, Attachment I, Nuclear Power Plnt Ntifjcation Form, must be made within 15 minutes after the emergency declaration (see key for this JPM).

TERMINA TING CUE: Successful completion of EPP-002, Communication and Notification, Attachment I, Nuclear Power Plant Notification Form.

PREFERRED EVALUATION LOCATION PREFERRED EVAL tJA TION METHOD SIMULATOR PERFORM

REFERENCES:

EPP-106 EMERGENCY PREPAREDNESS PERFORMANCE INDICATOR PROCEDURE EOP-12.0 MONITORING OF CRITICAL SAFETY FUNC11ONS EPP-001 ACTIVATION AND IMPLEMENTATION OF THE EMERGENCY PLAN EPP-002 COMMUNICATION AND NOTIFICATION INDEX NO. K/A NO. RO SRO 1940012441 2.4.41 Knowledge of the emergency action level thresholds and classifications. 2.9 4.6 1940012440 2.4.40 Knowledge of the SROs responsibilities in emergency plan implementation. 2.7 4.5 TOOLS:

Emergency Planning Tool Box from the SM office (simulator engineering).

EPP-001, Attachment 1 EAL Classification Matrix (available via desk top computer or as big board).

Copy of EOP-1 .0 Marked up per event conditions (Including completed Attachment 3).

Copy of EOP-2.0 Marked up through step 12.

Extra copies of EPP-00J .3 Att 1, Site Area Emergency Initial Actions Summary.

Extra copies of EPP-002 Aft 1, Nuclear Power Plant Emergency Notification Form page 1 of 11.

EV4L (IA TION TIME 20 TIME cRITIC4L YES 1 OCFRSS: 45(a)(1 1)

TIME START: TIME FINISI-I: PERFORMANCE TIME.

PERFORMANCE RA TING: SAT: UN$AT:

CA NDIDA TE:

EX4MINER:

SIGNATuRE DATE Tucsday. Apr11 14, 2015 PUgL 2 of 6

INSTRUCTIONS TO OPERA TOR READ TO OPERA fOR:

WHEN I TELL YOU TO BEGIN, YOU ARE TO PERFORM THE ACTIONS AS DIRECTED IN THE INITIATING CUES. I WILL DESCRIBE THE GENERAL CONDITIONS UNDER WHICH THIS TASK IS TO BE PERFORMED AND PROVIDE THE NECESSARY TOOLS WITH WHICH TO PERFORM THIS TASK. BEFORE STARTING, I WILL EXPlAIN THE INITIAL CONDITIONS, WHICH STEPS TO SIMULATE OR DISCUSS, AND PROVIDE INITIATING CUES. WHEN YOU COMPLETE THE TASK SUCCESSFULLY, THIS JOB PERFORMANCE MEASURE WILL BE SATISFIED.

SAFETY CONSIDERATIONS: None INITIAL CONDiTION: THIS IS A DRILL

1. The plant was in MODE 1. You are the Shift Manager.

2. Weekend night shift, only routine evolutions in progress.

3. The C Charging pump was tagged out for maintenance on the previous shift. No other equipment is out of service.

4. An event occurred 20 minutes ago resulting in an automatic Reactor Trip and Safety Injection

5. The crew entered EOP-1.0, E-0, REACTOR TRIP OR SAFETY INJECTION

6. The CRS has received the following reports from the crew.

a. Reactor Trip.

b. Turbine Trip.

c. Safety Injection

d. ESFLS complete on Train A and Train B

e. The B Charging pump failed to start

f. RCS pressure is less than 1418 psig with flow on Fl-943, Stopping RCPs

7. The crew transitioned from EOP-1 .0 to EOP-2.0, LOSS OF REACTOR OR SECONDARY COOLANT

8. The CRS was subsequently notified that the A Charging pump has tripped.

9. The crew is taking action using EOP-2.0, at step 13.

10. EPP-002, Attachment I NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM, Message # 1 was completed 10 minutes ago.

11. The simulator was frozen at this point.

12. The pre-completed Emergency Notification Forms are NOT available.

13. The Emergency Planning Tool Box is available to use in the Simulator INITIATING CUES: 1. Using references available in the Simulator, your task is to perform the following:

a. Classify the event based on current conditions.

b. Complete the required notification form.

2. Do not use SS Judgment as the basis for your classification.

3. The simulator will remain in freeze during the JPM.

4. The start time for classification will be the time when the Evaluator tells you to begin.

5. Inform the Evaluator when you have determined the classificaton.

6. Inform the Evaluator when you have completed the Emergency Notification Form.

THIS IS A TIME CRITICAL JPM!

HAND ,IPM BRIEFING SHEET TO OPERA TOR .4 T THIS TIME!

Tuesday, April H, 21)15 Page 3 tf 6

STEPS CRITIC4L: Yes SEQLrENCED: Yes SAT UNSA T STEP: 1 Determine that conditions require classification as SITE AREA EMERGENCY 1 STEP STANDARD:

Classifies event as a SITE AREA EMERGENCY based on:

EAL FSi.1 Loss or Potential Loss of any two barriers (Table F-i)

CUES:

Evaluator cue: Announce the Classification start time (1-0) based on the Simulator Clock.

Record time T-0 for future reference.

Evaluator note: Examinee has 15 minutes from 1-0 to arrive at event classification.

Evaluator cue: Tell the Examinee to inform you when the notification form is completed.

COMMENTS:

iuesdav, .4prll 14, 2015 Page 4 of 6

CR1T1C4L: Yes SEQUENCED: Yes SAT UNSA T STEP: 2 Complete EPP-002, Attachment 1, Nuclear Power Plant Emergency Notification Form and provide basis for classification.

STEP STANDARD:

Correctly completes EPP-002 Attachment 1 within 15 minutes of declaring event classification. See key for correct manner of completing the attachment.

Classification Basis:

1. Core exit TCs>700°F - Potential Loss of Fuel Clad Barrier, Item B.2.

AND

2. RCS leak rate> available make up capacity as indicated by a loss of RCS subcooling - Loss of Reactor Coolant System Barrier, Item D.2.

OR

2. Unisolable leak exceeding the capacity of one charging pump in the normal charging mode -

Potential Loss of Reactor Coolant System Barrier, Item D.2.

CUES:

Evaluator cue: If Exam inee appears to be using SIPCS for Rx trip time repeat cue that trip was 20 minutes prior to T-0 for the JPM.

Evaluator cue: If asked provide 803-334-1234 as the confirmation phone number.

Evaluator cue: Examinee must explain basis for classification. Ask Examinee for basis if it is not offered. If the basis is not correct, this constitutes failure even if the classification was correct and within 15 minutes. Step is critical since proper classification must be made within 15 minutes.

Evaluator note: The EPP-002 Attachment approved by time (line 17 on the EPP-002 Attachment 1) must be within 15 minutes of the time when their classification had been completed. Refer to NJPA-1 003 (Ri) Key.

LC0MJIIENTS:

Examiner ends JPM at this point.

Tuestlaj, .-lpril 14, 2015 Page 5 of 6

JPM SETUP SHEET JPMNO: NJPA-1003 (Ri)

DESCRIPTION: 2015 NRC SRO A4: Classify Emergency (Simulator SAE - - Inadequate Core Cooling) (ENF)

ICSET: 318 INSTRUCTIONS:

Tf IC-31 8 is designated for this JPM then reset to IC-31 8 leaving the simulator in FREEZE.

1. Place Danger Tag on C Charging pump for Maintenance. -

2. Move Emergency Planning Tool Box from SM Office into simulator control room.

3. Mark up EOP-1.0, EOP-i.0 Attachment 3 and EOP-2.0 through step 12.

If IC-31 8 is not designated for this JPM then initial conditions may be established by reseting to IC-i 0 and following the below directions:

1. Place Danger Tag on C Charging pump for Maintenance.

2. Insert: MAL-RCSOO6A Final Value = 10000 Delay = 10 (RCS loop A LOCA)

MAL-CVCO 1 7A Delay = 120 (A Charging Pump Trip)

PMP-CSOO6F (Charging Pump B fail to start)

XMT-M 101 6F 10 Meter Wind Direction Fail As Is XMT-M 1008 F 10 Meter Wind speed Fail As Is XMT-MIOi 5F 61 Meter Wind Direction Fail As Is XMT-MIOO7F 61 Meter Wind speed Fail As Is

3. RUN

4. Manually trip RCPs when RCS pressure <1400 psi9.

5.Perform the following actions >1 minute after SI is initiated:

Reset SI Reset Phase A Reset Phase B Reset the ESFLS Establish IA to the RB

6. Place A and B Charging pumps in pull to lock once they have stopped.

7. Ensure steps of EOP-1 .0 and in particular EOP-1 .0 attachment 3 have been fully and correctly implemented

8. Align EFW for normal operation and throttle to approximatly 200 gpm per Steam Generator.

9. When RVLIS NR Level is <45%, reduce RCS leak to 500 GPM.

10. When Core Exit Thermocouples >715°F and <725°F with RVLIS >40%: FREEZE ii. If necessary adjust RVLIS NR to approximately 45% using:

XMT-MIOO2O Final Value = 44 (RV NR Level LI-i 311 Fail to Position)

XMT-M10050 Final Value = 45 (RV NR Level Ll-i321 Fail to Position)

12. Record met data from SIPCS, need Wind Direction, Wind Speed and Stability Class for the answer key

13. Move Emergency Planning Tool Box from SM Office into simulator control room.

14. Mark up EOP-1.0, EOP-i.0 Attachment 3 and EOP-2.0 through step 12.

COiWMENTS:

Tuesdaj, lprll 14, 2015 Pr,e 6 of 6

JPM BRIEFING SHEET OPERA TOR INS TRtJCTIONS:

SAFETY COVSIDERATIONS: None INITIAL CONDITION: THIS IS A DRILL

1. The plant was in MODE 1. You are the Shift Manager.

2. Weekend night shift, only routine evolutions in progress.

3. The C Charging pump was tagged out for maintenance on the previous shift. No other equipment is out of service.

4. An event occurred 20 minutes ago resulting in an automatic Reactor Trip and Safety Injection

5. The crew entered EOP-1 .0, E-0, REACTOR TRIP OR SAFETY INJECTION

6. The CRS has received the following reports from the crew.

a. Reactor Trip.

b. Turbine Trip.

c. Safety Injection U. ESFLS complete on Train A and Train B

e. The B Charging pump failed to start

f. RCS pressure is less than 1418 psig with flow on FI-943, Stopping RCPs

7. The crew transitioned from EOP-1 .0 to EOP-2.0, LOSS OF REACTOR OR SECONDARY COOLANT

8. The CRS was subsequently notified that the A Charging pump has tripped.

9. The crew is taking action using EOP-2.0, at step 13.

10. EPP-002, Attachment I NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM, Message # 1 was completed 10 minutes ago.

11. The simulator was frozen at this point.

12. The pre-completed Emergency Notification Forms are NOT available.

13. The Emergency Planning Tool Box is available to use in the Simulator INITIATING CUES: 1. Using references available in the simulator, your task isto perform the following:

a. Classify the event based on current conditions.

b. Complete the required notification form.

2. Do not use SS Judgment as the basis for your classification.

3. The simulator will remain in freeze during the JPM.

4. The start time for classification will be the time when the Evaluator tells you to begin.

5. Inform the Evaluator when you have determined the classificaton

6. Inform the Evaluator when you have completed the Emergency Notification Form.

THIS IS A TIME CRITICAL JPM!

HAND THIS PAPER BACK TO YOUR EVALUATOR WHEN YOU FEEL THAT YOU HAVE SATISFACTORILY COMPLETED THE ASSIGNED TASK.

EPP-002 ATTACHMENT I PAGE 1 of 11 REVISION 36 NUCLEAR POWER PLANT EMERGENCY NOTIFICATION FORM DRILL JACTUAL EVENT MESSAGE# 2

2. INITIAL FOLLOW-UP NOTIFICATION: TIME DATE I / AUTHENTICATION#______

3. SITE: V. C. Summer Confirmation Phone # C.Q.L334-1 234

4. MERGENGY UNUSUAL EVENT C c?rE AREA EMERGENCY M ALERT J GENERAL EMERGENCY BASED ON EAL# FSI.l EAL DESCRIPTION: Loss or Potential Loss of any two Barriers J .k .

5. PROTEC71VE AC11ON RECOMMENDATIONS:

EVACUATE El CONSIDER THE USE OF KI (POTASSIUM ioDiDe) IN ACCORDANCE WITH STATE PLANS AND OTHER 40.9°and_5.f__-__

6. EMERGENCY RELEASE:

L Nne El Is Occurring Has Occurred

7. RELEASE SIGNIFICANCE: jWithin norma ting Above normal operati Not applicable limits limits El Under evaluation

8. EVENT PROGNOSIS: Imp roving Il St Degrading

9. METEOROLOGICAL DATA: Wind Direction* from 41 Wind Speed* 5.0 mph

(*May not be available for Initial Precipitation* None Stability Class*

Notifications) Re Qrd El El El El

10. DECLARATION lJ TERMINATION Tim me ate / I

.11. AFFECTED UNIT(S): Classified IJ 20 mm prior

2. UNIT STATUS: TpUay1 Ui ft % Power Shut t to T-0 te (Unaffected Unit(s) Status Not Required for Initial Notifications)

El U2 % Power Shutdown at e Date I I El U3 % Pa Shutdown at Time Date / I

13. REMARKS: TIirhin flrtn . n; cv Edwtrnii IrIinninn CWithin 15 minutes of T-0)

LLUP INFORMATION (Lines 14 through 16 Not Required for Initial Notifications)

MERGENCY RELEASE DATA NOT REQUIRED IF LINE 6 A IS SELECTED.

14. RELEASC RI TION: TYPE: El Elevated El Mixed [1 G MAGNITUDE: Noble Gases: lodines:_________ Partic Items circled as Data from 4/16/15 10-318 Build: /

are critical must be as CETC = 718.3°F RVLIS NR = 44.5%

rs shown for pass rating.

10 Meter Preferred 15 mm Wind Speed = 5,4 mph TEDE tmrem) t Thyroid CDE fmrem 10 Meter Preferred 15 mm Wind direction = 40.9° Stability Class = E minutes Subcooling = -161.1°F 10 Miles I 17. APPROVED BY: Title cz NOTIFIED RECEIVED BY: BY: Time Date / I

ML17181A362

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