Text

Proposed Scenarios
	ML21361A169
Person / Time
Site:	Byron
Issue date:	10/28/2021
From:	Gregory Roach; NRC/RGN-III/DRS/OLB
To:	; Exelon Generation Co
	Roach G
Shared Package
ML21055A845	List: ML21361A107; ML21361A116; ML21361A124; ML21361A126; ML21361A135; ML21361A157; ML21361A159; ML21361A169; ML21361A173; ML21361A177; ML21361A178;
References
	BYRON 2021-0041, 1.10.0101 (10 .101), 50-454/21-301, 50-455/21-301 50-454/OL-21, 50-455/OL-21
	Download: ML21361A169 (117)
	v • d • e

Facility: _Byron Nuclear Station_ Scenario No.: _1_ Op-Test No.: _2021-301_

Examiners: __________________________ Operators: _____________________________

Initial Conditions: 75% RTP, MOL, steady state.

Turnover: 1A SG Tube Leak of 15 GPD in progress. 1BOA SEC-8 open procedure for monitoring leakrate. 1A CV pump was returned to service and the pump has just been started. Complete 1BOSR 5.5.1-1 for the 1A CV pump. 1A FW pump OOS. Restoration expected in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months .

Event Malf. No. Event Event No. Type* Description 1 None N - BOP Perform 1BOSR 5.5.1-1, Seal Injection Verification, for the N - SRO 1A CV pump 2 ED049G C - ATC CV Pump trip (NRC Exam 19-2)

C - SRO TS - SRO 3 RX28E TS - SRO RCS flow channel 1FI-425 fails low 4 TH03A 0.08 R - ATC 1A SG Tube Leak increases to 115 GPD. Requires ramp ycyc9052_1v R - BOP down to 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (NRC Exam 19-2)

RP0094 R - SRO 5 ZDI1CV110B C - ATC 1CV110B Boric Acid Blender to Charging Pumps valve C - SRO closes 6 TH03A 1000 C - SRO EH pump trip / auto start failure C - BOP 2nd EH pump trip M - ALL Manual RX trip causes 1A SGTR 7 TH11B C - ATC PZR PORV fails open (Isolable) [CT]

RP04A - Pre C - BOP Train A Phase A fails to actuate in Auto [CT]

C - SRO 8 MS01A - Pre C- All MSIVs fail to close (preload)

MS01B - Pre CREW MS01C - Pre MS01D - Pre

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Critical Tasks:

1. CT-10: Close the block MOV upstream of the stuck open PZR PORV prior to reaching RCP trip criteria of RCS pressure 1425 psig with High Head SI flow greater than 100 gpm or SI pump discharge flow greater than 200 gpm. (K/A: APE 008AA1.01; importance - 4.2/4.0)

a. Safety Significance: Failure to isolate the open PORV creates a significant degradation in the mitigative capability of the plant.

b. Cues: Indication of a PZR PORV open after manual attempts to close it from the MCR AND indication of dropping RCS pressure AND indication of PRT temperature, pressure, level rising AND valve position is open for the PZR PORV block valve.

c. Performance Indicator: Manipulations of controls to close the PZR PORV block valve.

d. Feedback: Valve position indication that the block valve MOV for the open PZR PORV is closed.

2. CT-11: Close containment isolation valves such that at least one valve is closed on each Phase A penetration prior to completion of 1BCA 3.1 Step 12 Initiate RCS Cooldown to 200°F .(K/A: EPE 038EA1.30; importance -

4.0/3.8)

a. Safety Significance: Closing at least one containment isolation valve on each critical Phase A penetration constitutes a task that is essential to safety because it prevents a degradation to the containment barrier.

b. Cues: Indication that SI is actuated AND absence that a Phase A is complete as indicated by annunciator, lack of closed valve positions, OR ESF system status lamps indicating that one or more Phase A penetrations are not closed.

c. Performance Indicator: Manipulation of controls as required to close at least one containment isolation valve on each critical Phase A penetration.

d. Feedback: ESF system status lamps show at least one containment isolation valve closed on each critical Phase A penetration.

2

The scenario will start at approximately 75% RTP, MOL, steady state conditions. 1A Steam Generator has a tube Leak of 15 GPD in progress. 1BOA SEC-8 STEAM GENERATOR TUBE LEAK UNIT 1 is an open procedure pending completion of actions and for monitoring changes in the leakrate.1A CV pump was just returned to service and the pump has just been started. Complete 1BOSR 5.5.1-1 for the 1A CV pump. 1A FW pump OOS. Restoration expected in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months .

Event 1:

The crew is directed to perform 1BOSR 5.5.1-1, Unit One RCS Seal Injection Flow Verification Monthly Surveillance, for the 1A CV pump. When the surveillance is completed satisfactory, continue to Event 2.

Event 2:

1A CV pump will trip due to breaker overcurrent. The crew will take action to minimize pressurizer level changes by isolating letdown per BHC 1-9-A3. The crew will evaluate that the loss of the CV pump was not caused by gas intrusion in the pump suction and start the 1B CV pump, establish letdown, and control pressurizer level. The US will declare entry into TS 3.5.2 Condition A and TRM 3.1.d Condition A. When charging and letdown are in service, continue to event 3.

Event 3:

RCS flow channel 1FI-425 fails low. The crew will identify the failed channel and enter 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL - Attachment L RCS LOOP FLOW CHANNEL. The crew US will identify the channel needs to be placed in bypass or tripped. The US will declare entry into TS 3.3.1 Conditions A and K (Function 10). At the lead examiners discretion, continue to Event 4.

Event 4:

The Steam Generator tube leak will increase to 115 GPD. Annunciator 1-16-A5 will alarm providing indication to the crew that the SG Tube Leak has changed. Investigation by the crew will determine that the leakrate is rising. 1BOA SEC-8 STEAM GENERATOR TUBE LEAK UNIT 1 will direct a power reduction to less than 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The crew will then make reactivity plan to reduce power within the time frame. Once the power reduction is in progress, at the lead examiners discretion, continue to Event 5.

Event 5:

During boration operations, the 1CV110B Boric Acid Blender to Charging Pumps valve will close as identified by valve position and Annunciator 1-9-A6 BA FLOW DEVIATION. The ATC should identify the loss of boration flow, reference the BAR, and manually open 1CV110B to continue boration flow. Once boration flow is established, at the lead examiners discretion, continue to Event 6.

Event 6:

The 1A EH pump will trip and the 1B EH pump will fail to auto start. The crew will identify the failure of the 1B EH to start and manually start the pump per BAR 1-18-A15 or OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION. Failure to start the standby pump within 90 seconds will result in a Turbine trip that will cause a RX trip. 3 minutes after starting, 1B EH pump will trip. With the 1A EH pump unavailable, the crew will identify the pending turbine trip and manually initiate a RX trip and enter 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1. The RX trip will initiate a SG Tube Rupture in 1A SG. The crew will identify rapidly lowering pressurizer pressure and level and actuate Safety Injection.

Event 7 & 8:

After completion of immediate actions, PZR PORV 1RY456 will fail open. The crew will identify the PZR PORV 1RY456 is open and RCS pressure is dropping (noting that the PORV should be closed) and manually close the PZR PORV isolation valve per 1BEP-0 Step 7, the BHC 1-RY-P PRESSURIZER PRESSURE MALFUNCTION, or OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION. Train A of Phase A will not auto actuate with the Safety Injection. The crew will identify the failure and manually actuate Phase A C/S or manually close all Train A valves. The crew should transition to 1BEP-3 STEAM GENERATOR TUBE RUPTURE UNIT 1 to mitigate the event. After declaring entry into 1BEP-3 (1BEP-0 Step 13), it will be determined that no MSIV will close 3

at 1BEP-3 Step 3d and the crew will transition (RNO) to 1BCA 3.1 SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED.

The scenario may be stopped at 1BCA 3.1 Step 8 after stopping RH pumps provided all critical tasks are complete.

4

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, Simulator Ready for Training Checklist.

Establish the conditions of IC 141, 75% power, MOL, equilibrium xenon (IC 156 with change to plant configuration)

Place Simulator in RUN

Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N21-1 Scenario.ssf o Click on the MODE button (near top of screen) and pick EXECUTE o Click on the PLAY button (bottom left of screen) o Verify Simulator Setup conditions automatically load o TH03A 0.04 - 1A SG Tube Leak at 15GPD o RP04A - Train A Phase A fails to auto actuate o MS01A - MSIV A fails to close o MS01B - MSIV B fails to close o MS01C - MSIV C fails to close o MS01D - MSIV D fails to close o ZDI1EH01PB TRIP - 1B EH C/S to Trip (pump fails to start)

Verify the following are included in the Smart Scenario:

5

Ensure the following equipment is aligned

1D CD/CB Pump in STBY

1A CV pump is running

1A EH pump is running

1A FW pump is OOS

Place the following control switches in PTL:

1A FW Pump

1A FW Pump AOP

Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1A FW Pump

1A FW Pump AOP

1FW002A 1A FW Pump Discharge valve

1FW012A 1A FW Pump Recirculation valve

Place Protected Equipment placards on the following control switches:

1B FW pump

1C FW pump

Steam Generator Tube Leak placards on 1A Steam Generator

Set BAT Flow Controller to 14.4 for 917 ppm boron

Ensure REMA is available at the Unit Desk

Ensure 1BOA SEC-8 STEAM GENREATOR TUBE LEAK, UNIT 1 is open at the unit desk and place kept to Step 7.b R.N.O.a

Provide copies of the following documents:

1BOSR 5.5.1-1, RCS SEAL INJECTION FLOW VERIFICATION MONTHLY SURVEILLANCE 6

Turnover Information

Unit 1 is at 75% MOL

917 MWe

RCS boron concentration is 917 ppm

Control bank D @ 171 steps

1A CV pump was returned to service and the pump started 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago. Complete 1BOSR 5.5.1-1 for the 1A CV pump.

1BOA SEC-8 in progress due to 15 gpd leak in 1A SG. Currently at Step 7.b RNO. RP setpoint change pending.

Monitoring 1A SG leakrate.

Online Risk is Green

1A FW Pump is OOS; restoration expected in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months

Protected Equipment:

Unit 1 FC Train

1B FW Pump

1C FW Pump 7

INSTRUCTOR/SIMULATOR RUN AID GUIDE EO response time will occur per Byron Station Simulator guidelines.

TB - 2 minutes AB - 3 minutes AEER - 1 minute Event 1: Perform 1BOSR 5.5.1-1 Unit One RCS Seal Injection Flow Verification Monthly Surveillance If contacted as SM, direct crew to perform Step F.2 of 1BOSR 5.5.1-1.

As SM, acknowledge commencement and completion of procedure.

Event 2: 1A CV Pump trip At Lead Evaluators cue, use Smart Scenario to trip 1A CV Pump by right clicking on the box titled, Event 2, CV Pump, and select, Release.

When dispatched as an EO to check on 1A CV pump or breaker, report that the motor of the 1A CV pump is hot and the breaker of the 1A CV pump is tripped open with an overcurrent flag showing.

As Shift Manager, acknowledge entry into TS 3.5.2 and TRM 3.1.d.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 3: 1FI-425 fails low At Lead Evaluators cue, use Smart Scenario to trip 1A CV Pump by right clicking on the box titled, Event 3, RCS Flow Channel, and select, Release.

As Shift Manager, acknowledge procedural entry and evaluate for Emergency Plan conditions.

As Shift Manager, acknowledge requirement to bypass/trip bistable. If asked, direct to bypass bistable.

As the WEC, respond to request for tripping bistables and inform US that extra NSOs will be assembled and briefed.

As Shift Manager, acknowledge entry into TS 3.3.1.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 4: 1A SG Tube Leak increases to 115 GPD At Lead Evaluators cue, use Smart Scenario to cause the 1A SG Tube leak to increase to 115 GPD by right clicking on the box titled, Event 5, SG Tube Leak, and select, Release.

As Shift Manager, if contacted, acknowledge procedural entry and evaluate for Emergency Plan conditions.

As the WEC, acknowledge need to execute BOP MS-11 and inform US that a crew will be briefed and dispatched.

As Rad Protection, acknowledge required areas for monitoring and implementation of 0BCSR 11.i.1-1 GASEOUS RADWASTE TREATMENT EFFLUENTS DOSE CALCULATION.

As Chemistry, acknowledge requirement to initiate sampling per CY-BY-120-200-300-9 CONDENSER OFFGAS/STEAM JET AIR EJECTOR (SJAE) SAMPLING.

8

As SM, acknowledge the requirement to ramp the unit down to less than 50% and inform the US that the SM will notify NDO, PJM, and TSO.

As Shift Manager, concur with the reactivity plan presented by the US.

Event 5: 1CV110B fail closed Verify 1CV110B fail closed 35 seconds after initiation of first boration. If Event 6 does not auto actuate, initiate failure by right clicking on the box titled, Event 6, 1CV110B, and select, Bypass.

As Shift Manager, if contacted, acknowledge failure and actions taken per the BAR.

Event 6: 1A EH and 1B EH Pump trip and Tube Rupture At Lead Evaluators cue, use Smart Scenario to trip 1A EH pump by right clicking on the box titled, Event 6, EH Pump, and select, Release When dispatched as EO to check 1A EH Pump, report that the 1A EH pump is not running, the pump feels hot, and the breaker is tripped free. If asked to reset the breaker, the breaker will not reset.

Ensure Event 6a, EH Pump, to trip the 1B EH Pump automatically occurs, or use Smart Scenario to cause 1B EH Pump to trip by right clicking on the box titled, Event 6a, EH Pump, and select BYPASS.

Ensure Event 7a, Tube Rupture, occurs automatically with the manual Reactor Trip or use Smart Scenario to cause the Tube Rupture by right clicking on the box titled, Event 7a, Tube Rupture, and select BYPASS..

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-0.

Event 7, & 8 PZR PORV 1RY456 fails open & Phase A fails to automatically actuate After completion of 1BEP-0 Immediate Actions, ensure EVENT 8, PZR PORV, occurs automatically on manual actuation of the Safety Injection. If the crew does not actuate SI promptly, after 30 seconds, use Smart Scenario to cause PZR PORV 1RY456 to fail open by right clicking on the box titled, Event 8, PZR PORV, and select BYPASS.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-3, and 1BEP-3.1.

As TSC, acknowledge notification for minimum PZR level to ensure safe operation of PZR HTRS and respond with 28%

PZR Level.

9

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 1__

Event

Description:

Perform 1BOSR 5.5.1-1, seal injection verification, for the 1A CV pump Time Position Applicants Actions or Behavior CUE Directed at turnover to perform 1BOSR 5.5.1-1, seal injection verification, for the 1A CV pump US o Directs NSO to perform 1BOSR 5.5.1-1 ATC

VERIFY all applicable PREREQUISITES, PRECAUTIONS, and LIMITATIONS AND ACTIONS are satisfactorily addressed

RECORD the following initial conditions:

UNIT MODE: 1

CV Pump Status:

1A: RUN/STBY

1B: RUN/STBY

1CV121 Controller 1FK121 Status: AUTO/MANUAL

Master PZR Level Controller 1LK-459 Status: AUTO/Manual

Pressurizer Pressure:

_____ psig (P0480) ______ psig (P0481)

_____ psig (P0482) ______ psig (P0483)

CALCULATE Average Pressurizer Pressure from all available Operating Channels. psig

VERIFY Average Pressurizer Pressure > 2215 to < 2255 psig

VERIFY/PLACE 1FK121, Cent Chg Pmps Flow Cont Vlv 1CV121 controller, in MANUAL

ADJUST 1CV182, Chg Hdr Back Press Cont Vlv, as necessary to maintain total Seal Injection flow to all 4 RCPs within the limits of Tech Spec Figure 3.5.5-1.

RECORD the individual RCP Seal Inj Flows:

VERIFY/RECORD the following:

1CV121 position: ____% OPEN

Charging Header Press: (P0142) ____psig

Average of Indicating Pzr. Pressure: (> 2215 to < 2255 psig) ____psig (¢)

Differential Pressure: ____psid

Using calculated Total Seal Injection Flow and Differential Pressure, PLOT Coordinates on Tech Spec Figure 3.5.5-1 (Attachment A).

VERIFY Seal Injection Flow is within acceptable region of Tech Spec Figure 3.5.5-1. (¢)

PROCEED to Section F.4 to restore system to normal conditions.

o ADJUST 1CV182, Chg Hdr Back Press Cont Vlv, to establish normal Charging and Seal Injection flows.

o ADJUST 1FK121, Cent Chg Pmps Flow Cont Vlv 1CV121 controller, to maintain normal Pressurizer level.

o PLACE 1FK121, Cent Chg Pmps Flow Cont Vlv 1CV121 controller, in AUTO if desired, and INDICATE the "As LEFT" condition:

o PLACE 1LK-459, Master Pressurizer Level Controller, in AUTO if desired, and INDICATE the "As LEFT" condition:

10

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 1__

Event

Description:

Perform 1BOSR 5.5.1-1, seal injection verification, for the 1A CV pump US

Verify Tech Specs are satisfied by completion of surveillance EVALUATOR NOTE: After completion of 1BOSR 5.5.1-1, and with lead examiners concurrence, proceed with the next event.

11

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 2__

Event

Description:

1A CV Pump Trip Time Position Applicants Actions or Behavior CUES Annunciators

1-9-A3 CHG PUMP TRIP

1-9-D3 CHG LINE FLOW HIGH/LOW

1-9-A1 REGEN HX LTDWN TEMP HIGH

1-7-B2 RCP SEAL WTR INJ FLOW LOW

1A CV pump disagreement lamp lit ATC

Take action per BHC 1-9-A3 CV PUMP TRIP PROMPT ACTION:

Verify/close 1CV8149A, B, C Letdown Orifice Outlet Valves

Close 1CV459 Letdown Isolation Valve

Close 1CV460 Letdown Isolation Valve US

Acknowledge and confirm completion of BHC 1-9-A3

Direct actions to be completed per BAR 1-9-A3 CHG PUMP TRIP ATC

Start 1B CV Pump per BAR 1-9-A3:

Verify Letdown Isolation

Ensure a borated supply source from the VCT

Determine that NO gas binding occurred

Review CV pump trends

Verify Miniflow recirc path for the 1B CV pump

Place 1CV121 in manual and adjust to 10% open

Start 1B CV Pump

Monitor pump flow

Monitor motor amps

Raise charging flow to 70 GPM

Establish Letdown per 1BOA ESP-2 Re-establishing CV Letdown 12

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 2__

Event

Description:

1A CV Pump Trip Time Position Applicants Actions or Behavior ATC /

Establish Letdown per 1BOA ESP-2 Re-establishing CV Letdown:

BOP

Verify Letdown Isolation

Check Letdown Flowpath:

1CV8401B Letdown to 1B HX Valve, 1CV8324B Charging to Regeneration HX 1B Isolation valve, 1CV8389B Letdown to Regeneration HX 1B Isolation Valve, 1CV8152 Letdown Line Containment Isolation Valve, and 1CV8160 Letdown Line Containment Isolation Valve OPEN

BTRS Mode Selector switch in OFF

Align Letdown Controllers:

Place 1CV131 Letdown Line Pressure Control Valve controller in manual and at 40%

Place 1CC130 1A/B Letdown HX Outlet Temperature Control Valve controller in manual and at 60%

Verify Charging Flow Established:

Check 1CV8105 and 1CV8106 Charging Line Containment Isolation Valves OPEN

Throttle 1CV182 Charging Header Back Pressure Control Valve to maintain RCP seal injection flow between 8 GPM and 13 GPM per pump

Throttle 1CV121 CV Pump Discharge Flow Control Valve to establish at least 100 GPM Charging Flow

Establish Letdown Flow:

Open 1CV459 and 1CV460

Open 1CV8149A and either 1CV8149B or 1CV8149C

Adjust 1CV131 to control letdown pressure at approximately 360 psig

Adjust Charging Flow as necessary

Adjust 1CC130 to control letdown temperature between 90°F - 115°F

Restore controllers 1CV131 and 1CC130 to auto

Verify 1PR06J is In Service 13

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 2__

Event

Description:

1A CV Pump Trip Time Position Applicants Actions or Behavior US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.5.2 ECCS - Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One train inoperable o A.1

RA - Restore train to OPERABLE status

CT - 7 days (RF 6b) Locate/Determine Applicable LCOs

TRM 3.1.d Charging Pumps - Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One charging pump inoperable o A.1

RA - Restore charging pump to OPERABLE status

CT - 7 days EVALUATOR NOTE: After restoration of normal charging and letdown, with lead examiners concurrence, initiate the next event.

14

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 3__

Event

Description:

RCS Flow Channel 1FI-425 fails low Time Position Applicants Actions or Behavior CUE: Annunciator

1-13-B3 RCP 1B BRKR OPEN OR LOW FLOW LOW ALERT

1FI-425 Loop 1B Flow Indicator reads zero ATC

Take action per the BAR

Determine that 1FI-425 has failed low

Verify 1B RCP has NOT tripped US

Direct entry into 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL UNIT 1 Attachment L

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests US

Identify Bistable FB425A require to be bypassed o Contact WEC Supervisor to dispatch/brief personnel to bypass bistable US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.3.1 -Reactor Trip Instrumentation (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One or more Functions with one or more required channels or trains inoperable.

o A.1

RA - Enter the Condition referenced in Table 3.3.1-1 for the channel(s) or trains inoperable (Function 10).

CT - Immediately

CONDITION K, One channel inoperable.

o K.1

RA - Place channel in trip.

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EVALUATOR NOTE: After the US determines the Tech Spec requirements, and with the lead examiners concurrence, initiate the Event 4 & 5 15

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 4 & 5__

Event

Description:

1A SG Tube Leak Increases to 115 GPD and 1CV110B fail closed Time Position Applicants Actions or Behavior CUE Annunciator:

1-16-A5 S/G TUBE LEAK RATE EXCEEDED

PPC Point U9052 trend rising

1PR027J RMS alarm BOP

Respond per BAR 1-16-A5 S/G TUBE LEAK RATE EXCEEDED

Check additional indications of Primary to Secondary Leakage

PPC Point U9052 Estimate Primary to Secondary Leakrate trend rising

1PR027J Steam Jet Air Ejector Process Radiation Monitor RMS alarm US

Direct actions per 1BOA SEC-8 STEAM GENERATOR TUBE LEAK, UNIT1

Notify SM for procedure actions, EP evaluation ATC

Maintain PZR Level Stable

Throttle charging header control valves 1CV121 CV Pump Discharge Flow Control Valve and / or 1CV182 Charging Header Back Pressure Control Valve

Check PZR level - STABLE OR RISING - PZR level stable

Verify makeup - adequate to maintain VCT Level US

Direct WEC to perform BOP MS-11, OPERATION WITH SG TUBE LEAKAGE

Notify Rad Protection to monitor radiation levels in secondary systems, condensate polishers, area radiation in Turbine and Aux Buildings, and initiate 0BCSR 11.i.1-1 GASEOUS RADWASTE TREATMENT EFFLUENTS DOSE CALCULATION BOP/US

Identify Leaking SG - 1A SG leak

Main Steamline 1A radiation monitors in alarm - RED alarm on RMS

Estimate SG tube leak rate - leakrate risen to 115 gpd

Computer point U9052

Leak Tracker program

Estimate primary to secondary leakage to LESS THAN 10 GPM US

Direct performance of 1BOSR 4.13.1-1 REACTOR COOLANT SYSTEM WATER INVENTORY BALANCE 72 HOUR SURVEILLANCE while continuing with 1BOA SEC-8 BOP/US

Check SJAE radiation monitor - 1PR027J OPERABLE

Trend SG Leakrate

Notify Chemistry to initiate sampling per CY-BY-120-200-300-9 CONDENSER OFFGAS/STEAM JET AIR EJECTOR (SJAE) SAMPLING.

Check computer point U9052 responding to plant conditions - rising trend o 1PR008J Steam Generator Blowdown Radiation Monitor o N-16 radiation monitor

Trend leakrate values every 15 minutes 16

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 4 & 5__

Event

Description:

1A SG Tube Leak Increases to 115 GPD and 1CV110B fail closed Time Position Applicants Actions or Behavior BOP/US

Determine if shutdown required

SG leakrate less than 100 gpd - leakrate risen to 115 gpd

Confirm SG leak rate by two independent indications trend in the same direction o Main Steamline radiation monitors o SJAE/Gland Steam Exhaust radiation monitors o SG Blowdown radiation monitor o N-16 radiation monitor(s)

US

Initiate unit shutdown

Check leak rate less than 100 gpd - leak rate over 100 gpd at 115 gpd

Direct power reduction to 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of receiving annunciator alarm 1-16-A5 per 1BGP 100-4T1.1 RAPID POWER REDUCTION FLOWCHART

Shutdown to Mode 3 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of being 50% power

Implement actions of 1BGP 100-4T1.1 RAPID POWER REDUCTION FLOWCHART o Perform pre-job brief per OP-BY-101-0001 ATTACHMENT 9 REACTIVITY CHANGE BRIEF SHEET for load ramp.

EVALUATOR NOTE: Event 6: 1CV110B fail closed is set to occur during the ATC actions to ramp the unit down during the first boration.

ATC

Performs reactivity calculation for Unit 1 ramp down to 20% at a minimum rate of 5.5MWe/min.

Initiate boration per: BOP CV-6, OPERATION OF THE REACTOR MAKEUP SYSTEM IN THE BORATE MODE or BOP CV-6T1, RCMS OPERATE IN BORATE CHECKLIST

Place MU MODE CONT SWITCH to STOP position.

Set MU MODE SELECT to BOR position.

Set 1FK-110 BA Boric Acid to Blender controller to desired flowrate (Batches desired)

Enter gallons into Boric Acid Totalizer on OWS graphic (6003)

Verify totalizer reset

Verify 1CV110A Boric Acid to Blender valve & 1CV110B Boric Acid Blender to Charging Pumps valve in AUTO

Ensure BA Transfer pp is NOT in Pull Out position

Place MAKE-UP CONTROL Switch to START

Ensure proper operation of valves & BA pump

1CV110B Opens, 1CV110A Modulates , BA pump is running EVALUATOR NOTE: Event 6: Begins here. This event will occur automatically 35 seconds after the initiation of the boration for the ramp.

17

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 4 & 5__

Event

Description:

1A SG Tube Leak Increases to 115 GPD and 1CV110B fail closed Time Position Applicants Actions or Behavior CUE:

Annunciators:

1-9-A6 BA FLOW DEVIATION

1CV110B indicates closed

Boration flow drops to zero ATC/US

Takes action per the BAR 1-9-A6 BA FLOW DEVIATION

Determine the reason for the deviation - 1CV110B is closed

If the crew is uncertain of the failure:

Verify 1CV110B and 1CV111B are closed

Place Makeup Control Switch to OFF

Verify proper lineup

Restart Reactor Makeup system

If the crew determines the failure with 1CV110B:

Place 1CV110B Control Switch to OPEN

Monitor RX Makeup flow on recorder 1CD-CX4102 to verify proper PW and Boric Acid flow US

Request maintenance to troubleshoot. Notify SM for IR ATC

Monitor plant for effects and take any actions directed by the US EVALUATOR NOTE: Event 6 complete. Event 5 completion follows.

ATC o Verify expected BA flow on recorder 1CD-CX4102 o Monitor for Boration effects o Verify at least two B/U Heater groups ON and spray valves 1RY455B/C modulate OPEN.

Monitor for RCS Tave lowering.

o Place Rod Control in Manual utilizing RD-100 as reference

Manually insert Control Rods BOP

Initiate turbine load ramp: Using graphic 5501(per 1BGP 100-4T1.1)

SELECT SETPOINT

ENTER desired (>5.5) MW/MIN rate in the RATE window

DEPRESS the respective ENTER pushbutton

ENTER desired final MWe output (~250) in the REF DEMAND window

SELECT ENTER

DEPRESS EXIT

DEPRESS the GO/HOLD pushbutton

Inform US/RO of pending drop in turbine load

SELECT GO (when RO reports expected Tave drop)

Verify load lowering as expected EVALUATOR NOTE: After ramp has been initiated, Event 6 has been completed, sufficient ramping activities have been observed, and with lead examiners concurrence, continue with the Event 7, 8 & 9.

18

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 6__

Event

Description:

1A EH pump trip, 1B EH pump trip, and 1A SG Tube Rupture Time Position Applicants Actions or Behavior CUE Annunciator:

1-18-A15 EH PUMP TRIP

1A EH pump disagreement lamp lit

Take action per BAR 1-18-A15 EH PUMP TRIP:

Verify standby pump, 1B EH pump, starts on low pressure BOP

1B EH pump will fail to auto start

Check EH FLUID RSRVR LO LVL LOCKOUT RESET (Low Low Level Lockout) LOCKED OUT not lit

Start 1B EH pump in manual US

Direct start of 1B EH pump

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests CUE

Annunciator

1-18-A15 EH PUMP TRIP

1AR022/23 in HIGH ALARM

1PR08J and 1PR28J indications rising Crew

Refer to BAR 1-18-A15

Determine that Turbine Trip will cause RX trip US

Direct a manual reactor trip and operators perform immediate actions of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION ATC

Manually trips the reactor EVALUATOR NOTE: When the crew initiates the RX trip, the SG tube leak rate escalates into a 1A SG Tube Rupture.

US

Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notify SM for procedure entry, EP evaluation o Request STA to come to the control room ATC

Verify Reactor Trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux DROPPING BOP

Verify Turbine Trip

Turbine throttle valves - CLOSED

Turbine governor valves - CLOSED BOP

Verify power to 4KV busses

Bus 141 - ENERGIZED

Bus 142 - ENERGIZED 19

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 6__

Event

Description:

1A EH pump trip, 1B EH pump trip, and 1A SG Tube Rupture Time Position Applicants Actions or Behavior ATC

Check SI status

SI actuated

SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

Check PZR pressure < 1829 psig

Check Steamline pressure < 640 psig

Check CNMT pressure > 3.4 psig

If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE: Train A of Phase A will not actuate automatically. This will be addressed during the performance of 1BEP-0 Attachment B.

EVALUATOR NOTE: Crew actions of 1BEP-0 continue in Events 7 & 8.

BOP actions of 1BEP-0, Attachment B continue on page 23.

20

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7 & 8__

Event

Description:

Phase A fails to actuate in Auto with Safety Injection and 1RY456 fails open Time Position Applicants Actions or Behavior EVALUATOR NOTE: PZR PORV 1RY456 will automatically fail full open 35 seconds after SI is manually actuated.

ATC

Verify AF system:

AF pumps - BOTH RUNNING

AF isolation valves 1AF13A-H Steam Generator Auxiliary Feedwater Isolation Valve- OPEN

AF flow control valves 1AF005A-H Auxiliary Feedwater Regulating Valves -

THROTTLED

AF flow - GREATER THAN 500 GPM

Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE - MS022A & D Main Steamline Radiation Monitors indicated RED high alarm

Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER - 1A SG level is rising in an uncontrolled manner

Manually close 1AF013A, 1AF013E, 1AF005A, and 1AF005E EVALUATOR NOTE: Actions to close the 1RY8000B may be performed prior to this verification step via the BHC or BAR depending on the action of the ATC operator.

CT-10 ATC

Check PZR PORVs and Spray Valves

PORVs - CLOSED - 1RY456 Pressurizer Power Relief Valve is full open

Check pressure less than 2315 psig

Manually close 1RY456 - fails to close

[CT]

Manually close 1RY8000B Pressurizer Relief Isolation Valve

PORV isol valve - at least one ENERGIZED

PORV relief path - at least one AVAILABLE

PORV in - AUTO

Isolation valve - open

Normal spray valves - CLOSED ATC

ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC

Check steam dumps - AVAILABLE

C-9 Permissive light - NOT LIT

CW Pump - AT LEAST ONE RUNNING ATC

Control RCS Temperature per table:

Adjust Feed Flow

Steam Release EVALUATOR NOTE: It is possible the procedural path and timing may meet the conditions to trip RCPs, however it is not expected to meet the conditions to trip RCPs at this time.

21

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7 & 8__

Event

Description:

Phase A fails to actuate in Auto with Safety Injection and 1RY456 fails open Time Position Applicants Actions or Behavior ATC

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

High head flow 1FI-917 > 100 GPM and RCS Pressure > 1425 PSIG.

ATC

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

ATC

CHECK IF SG TUBES ARE INTACT:

SJAE/Gland Steam Exhaust Gas radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT. - MS022A & D indicated RED high alarm Crew

Transition to 1BEP-3 STEAM GENERATOR TUBE RUPTURE, Step 1.

EVALUATOR NOTE: The crew actions for 1BEP-3 STEAM GENERATOR TUBE RUPTURE continue on the next page.

US

Implement 1BEP-3, STEAM GENERATOR TUBE RUPTURE and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation o Request STA to come to the control room EVALUATOR NOTE: RCP Trip criteria dependent on RCS pressure when evaluated, it is anticipated to be above 1425 psig at this step.

ATC CHECK IF RCPS SHOULD BE STOPPED

All RCPs - ALL RUNNING.

ECCS flow:

High head SI flow (1FI-917) - GREATER THAN 100 GPM o RCS pressure - LESS THAN1425 PSIG o Manually trip RCPs CREW IDENTIFY RUPTURED SG(s):

o Unexpected rise in any SG narrow range level o Main Steamline radiation trend - NOT NORMAL FOR PLANT CONDITIONS o 1RT-AR022 Grid 1 4AA122 o 1RT-AR023 Grid 1 4AA123 o High activity from any SG sample o Reset CNMT isol Phase A o Notify Chem to locally sample o Open SG blowdown sample valves at Chem request

Identify 1A SG is ruptured 22

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7 & 8__

Event

Description:

Phase A fails to actuate in Auto with Safety Injection and 1RY456 fails open Time Position Applicants Actions or Behavior ATC/BOP ISOLATE FLOW FROM RUPTURED SG(s):SG PORV MS018A in AUTO

Verify future SG 1A PORV controller in AUTO

Check SG 1A PORV 1MS018A CLOSED

Verify closed when SG pressure < 1115 psig

Verify SG blowdown valves closed unless open for sampling

1SD002A

1SD002B

Close ruptured SG 1A MSIV and MSIV bypass valves - 1MS001A will not close

Manually actuate Main Steamline Isolation - MS isolation will NOT actuate and MSIVs will not close

Verify closed Main FW pump turbine HP stop valves, Steam Dump valves, 1MS067A thru D, 1MS009A thru D, 1GS001, 1GS004, 1MS052A & B, 1MS055A & B

Identify that the 1A SG cannot be isolated from any intact SG Crew

Transition to 1BCA-3.1 SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED, Step 1.

EVALUATOR NOTE: The crew actions for 1BCA-3.1 SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED continue on the next page.

US

Implement 1BCA-3.1 SGTR WITH LOSS OF REACTOR COOLANT -

SUBCOOLED RECOVERY DESIRED and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation o Request STA to come to the control room ATC/BOP

RESET SI IF NECESSARY:

Depress both SI reset pushbuttons

Verify SI ACTUATED permissive light - NOT LIT

Verify AUTO SI BLOCKED permissive light - LIT ATC/BOP

RESET CONTAINMENT ISOLATION:

Phase A BOP

ESTABLISH INSTRUMENT AIR TO CONTAINMENT:

Check SACs - ANY RUNNING

Open instrument air CNMT isol valves:

1IA065

1IA066 BOP

VERIFY ALL AC BUSSES - ENERGIZED BY OFFSITE POWER.

Bus 141, 142, 143, 144

Bus 156, 157, 158, 159 23

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7 & 8__

Event

Description:

Phase A fails to actuate in Auto with Safety Injection and 1RY456 fails open Time Position Applicants Actions or Behavior ATC

DEENERGIZE PZR HEATERS

Place B/U heater contactors in - OFF

Group 1A, 1B and 1D

Place variable heater control switch in - AFTER TRIP US

Consult TSC for a recommended minimum indicated PZR water level that will ensure PZR heaters are covered ATC/BOP

CHECK IF CS SHOULD BE STOPPED

CS pumps run lights - not LIT ATC/BOP

CHECK RUPTURED SG LEVEL

Narrow range level greater than 10%

Stop feed flow to ruptured SG ATC/BOP

CHECK IF RH PUMPS SHOULD BE STOPPED:

RH pumps - any running with suction aligned to RWST

Check RCS pressure greater than 325 psig

RCS pressure - Stable or rising

Stop RH pumps and place in STBY EVALUATOR NOTE: The scenario can be terminated after securing RH pumps provided all critical steps are complete.

24

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7, 8, & 9__

Event Description 1B EH pump trip and 1A SG Tube Rupture Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

BOP Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps - 1B RUNNING

RH pumps - BOTH RUNNING

SI pumps - BOTH RUNNING BOP Attachment B action VERIFY ECCS VALVE ALIGNMENT

Group 2 Cold Leg Injection monitor lights required for ECCS valve alignment - LIT EVALUATOR NOTE: RCS pressure is dependent on when evaluated, it is anticipated to be below 1700 psig at this step.

BOP Attachment B action VERIFY ECCS FLOW

HHSI flow >100 gpm or SI Pump Discharge flow > 200 gpm - no

RCS pressure <1700 psig

RCS pressure <325 psig - no CT-11 BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights - LIT Verify CNMT isolation Phase A

Group 3 CNMT isolation monitor lights - NOT LIT

[CT]

Manually actuate Containment Isolation Phase A or manual close Train A valves Verify CNMT Ventilation isolation

Group 6 CNMT Vent Isol monitor lights - LIT Verify CC Pumps

CC pumps - BOTH RUNNING Verify SX Pumps running

SX pumps - BOTH RUNNING Check If Main Steamline Isolation Is Required o Check SG pressure < 640 psig o Check CNMT pressure > 8.2 psig

If either condition is met, then verify MSIVs and MSIV Bypass valves closed -

valves will not close

Manually actuate MS Isolation - MSIVs will not close

Manually close valves - MSIVs will not close Check if CS is required

CNMT pressure has risen to greater than 20 psig - no BOP Attachment B action VERIFY FW ISOLATED 25

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7, 8, & 9__

Event Description 1B EH pump trip and 1A SG Tube Rupture Time Position Applicants Actions or Behavior

FW pumps tripped

FW isolation monitor lights lit

FW pumps discharge valves closed 1FW002A-C

Trip all running HD pumps BOP Attachment B action VERIFY BOTH DGS RUNNING:

DGs - BOTH RUNNING

SX valves open 1SX169A and B

Dispatch operator locally to check operation BOP Attachment B action VERIFY GENERATOR TRIP

Unit 1 Main Transformer output breakers - OPEN:

GCB 3-4

OCB 4-5

Excitation red OFF light is LIT BOP Attachment B action VERIFY CONTROL ROOM VENTILATION ALIGNED FOR EMERGENCY OPERATIONS:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints

Operating VC train equipment running Train A

Supply fan 0A

Return fan 0A

M/U fan 0A

Chilled water pump 0A

MCR chiller 0A

Operating VC train dampers

M/U fan outlet damper NOT full closed 0VC24Y

VC train M/U filter light LIT

Operating VC train Charcoal Absorber aligned for train A

0VC43Y closed

0VC21Y open

0VC22Y open

Operating VC train M/U filter alignment

0VC25Y open

0VC312Y closed

Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED

Two inaccessible filter plenums aligned 26

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7, 8, & 9__

Event Description 1B EH pump trip and 1A SG Tube Rupture Time Position Applicants Actions or Behavior

Plenum A fan 0VA03CB running

Damper 0VA023Y not fully closed

Damper 0VA436Y closed

Plenum C fan 0VA03CF running

Damper 0VA072Y not fully closed

Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans

One Exhaust Fan running for every Supply Fan running BOP Attachment B action VERIFY FHB VENTILATION ALIGNED

Train B fan 0VA04CB running

0VA055Y open

0VA062Y not fully closed

0VA435Y closed BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling

Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of

Manual actions taken

Failed equipment status

Attachment B completed BOP Attachment B action Initiate periodic checking of Spent Fuel Cooling

Dispatch an operator to verify local actions

SFP level is greater than 420 elevation (20 feet from the top of the fuel)

SFP temperature STABLE BOP Attachment B action Notify Unit Supervisor of the following:

Manual actions taken - Phase A and MS Isolation actions

Failed equipment status - All MSIVs open

Ownership of Continuous Action Step

Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN 27

Op-Test No.: 2021-301 _ Scenario No.: _N21-1_ Event No.: _ 7, 8, & 9__

Event Description 1B EH pump trip and 1A SG Tube Rupture Time Position Applicants Actions or Behavior EVALUATOR NOTE: The crew actions for of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, continue on page 18.

The crew actions for of 1BEP-3, STEAM GENERATOR TUBE RUPTURE, begin on page 21.

The crew actions for of 1BEP-3.1, 1BEP-3.1 SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED begin on page 22.

28

Facility: _Byron Nuclear Station__ Scenario No.: ___2___ Op-Test No.: _2021-301_

Examiners: __________________________ Operators: _____________________________

Initial Conditions: 75% RTP, MOL, steady state conditions.

Turnover: Crew is directed to perform IV/RV Partial surveillance and then initiate ramp to 100%. 1A FW Pump OOS. Expected RTS in 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months . 1A SI Pump OOS; expected RTS in 26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months . LCO 3.5.2 Cond A has been entered. Byron Unit 1 has been notified of potential response due grid instabilities projected over the next 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months .

Event Malf. No. Event Event No. Type* Description 1 None N - BOP Perform IV/RV partial surveillance N - SRO 2 None R - ATC Rapid ramp down of 100 MWe for grid instability R - BOP R - SRO 3 SLIM12ManPB I - ATC Master PZR Level Controller 1LK-0459 demand lowers SLIM12OutDecPB I - SRO and power failure (NRC Exam 19-1)

SLIM12pwrFail_t 4 CV16 I - ATC VCT level channel 1LI-112 fails high (NRC Exam 19-2)

I - SRO 5 CC01B C - BOP 1A CC pump trip with 1B CC pump failure to auto start CC01C C - SRO TS - SRO 6 ZDI1HSDG0200 TS - SRO Loss of 1B DG CP ZLO1HSDG0201 ZLO1HSDG0202 ZLO1HSDG0203 7 ZDI1CC685 C - BOP 1CC685 spurious closure (NRC Exam 19-2)

C - SRO 8 MS07D M (ALL) 1A and 1D Main Steamline leak inside CNMT [CT]

9 ZDI1CS01PA C - BOP A Train CS pumps fail to actuate in auto [CT]

ZAO1IICS01PB C - SRO (NRC Exam 19-1)

B Train CS pump degrades and trips

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

1. CT-17: Isolate the faulted 1D SG before transition out of 1BEP-2 (K/A number - APE 040-AA1.03 importance 4.3/4.3)

a. Safety Significance: Failure to isolate a faulted SG can result in challenges to the CSFs Integrity, Subcriticality, and Containment.

b. Cues: Steam pressure and flow rate indications that make it possible to identify a single SG as faulted AND valve position and flow rate indication that AFW continues to be delivered to the faulted SG.

c. Performance Indicator: Manipulate controls to isolate the faulted the SG by MSIVs indicate closed, feedline isolation valves closed, and indication of AFW flow to the faulted SG is stopped.

d. Feedback: Any depressurization of intact SGs stops and AFW flow rate indicates zero to faulted SG.

2. CT-3: Restart Containment Spray Pump before transition to Z-1 Red Path. (K/A: 026-A2.04; importance -

3.9/4.2)

a. Safety Significance: Failure to manually actuate one containment spray pump results in a failure to prevent a significant reduction of safety margin.

b. Cues: Rising pressure in containment and no CS Spray pumps running.

c. Performance Indicator: Manipulate controls to actuate at least one CS Spray pump.

d. Feedback: Indication and/or annunciation that at least one CS Spray pump is actuated.

2

Scenario will start at 75% RTP, MOL, steady state conditions. Crew is directed to perform IV/RV Partial surveillance and then initiate ramp to 100%. 1A FW Pump OOS. Expected RTS in 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months . 1A SI Pump OOS; expected RTS in 26 hours3.009259e-4 days 0.00722 hours 4.298942e-5 weeks 9.893e-6 months . LCO 3.5.2 Cond A has been entered. Online risk is green.

Event 1 The crew will perform a partial surveillance of 1BOSR 3.g.3-1 UNIT ONE REHEAT AND INTERCEPT VALVE QUARTERLY SURVEILLANCE Step F1.b for 1MS5001B 1B Low Pressure Turbine East Reheat Stop Valve. After valve stroke is complete, at the lead examiner discretion, continue to Event 2.

Event 2 The crew will receive notification from grid operator to lower power 100 MWe due to grid instabilities within 30 minutes.

The crew will perform a rapid down power. Expectations are to initiate the ramp within 10 minutes and complete within the directed time frame. Once sufficient observation of the reactivity maneuver is complete, at the lead examiner discretion, continue to Event 3.

Event 3 Master PZR Level Controller 1LK-0459 demand lowers and power failure. The crew will identify the failure, take manual control of the Master PZR Level Controller in Ovation or take manual control of 1CV121 to restore PZR level. Once PZR level is under control, at lead examiner discretion, continue to Event 4.

Event 4 1LI-112 Volume Control Tank (VCT) Level Channel 1 will fail high. The crew will identify the failure and respond to BAR 1-9-A2. The crew should enter 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, perform attachment V, and swap channels in Ovation to 1LT185 VCT Level Channel 2, placing 1CV112A Letdown Diversion to VCT or HUT Tanks Valve to manual and selecting HUT or VCT to control level as required. Once the VCT level is under control, at lead examiner discretion, continue to Event 5.

Event 5 The 1A CC pump will trip and the 1B CC pump will not auto start. The crew will manually start the 1B CC pump per Bar 1-2-A4 CC PUMP TRIP or OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION. The crew will enter Tech Spec 3.7.7 Condition A. Once alarms are clear and system parameters are stable, at the lead examiner discretion, continue to Event 6.

Event 6 The 1B DG will lose DC Control Power. The crew will identify the failure and respond per BAR 1-22-C8 DG 1B TROUBLE/FAIL TO START. The crew will dispatch an EO to identify local alarms for the 1B DG. The report from the field will identify that the 1B DG has lost DC CP. The crew will enter Tech Spec 3.8.1 Condition B. Once the Tech Spec has been entered, at lead examiner discretion, continue to Event 7.

Event 7 1CC685 Component Cooling Water from RCPs Thermal Barrier Isolation Valve will spuriously go closed. The crew will identify the failure and reopen the valve. The crew should enter 1BOA PRI-6 COMPONENT COOLING MALFUNCTION UNIT 1. Once restoration of CC cooling flow through the Thermal barrier is restored, at the lead examiner discretion, continue to Event 8.

Event 8 1A and 1D Steamlines will rupture inside containment. The crew should identify the faulted Steam Generators and initiate a manual RX trip and Main Steam Isolation and enter 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT1. The crew will proceed to 1BEP-2 FAULTED STEAM GENERATOR ISOLATION UNIT1 to isolate the 1A and 1D SG.

Containment pressure will rise to the Phase B / Containment Spray actuation setpoint. Only the 1B CS pump will automatically start. It will run for several minutes and then trip. The crew will identify the lack of CS pumps running above 20 PSIG containment pressure. The crew will transition to 1BFR Z-1, Orange Path BST and manually start the 1A CS pump.

The scenario can be terminated when the crew has transitioned to 1BFR Z-1 and completed Step 3h.

3

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, Simulator Ready for Training Checklist.

Establish the conditions of IC 141, 75% power, MOL, equilibrium xenon (IC 156 with change to plant configuration)

Place Simulator in RUN

Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N21-2 Scenario.ssf o Click on the MODE button (near top of screen) and pick EXECUTE o Click on the PLAY button (bottom left of screen) o Verify Simulator Setup conditions automatically load o CC01B - 1A CC pump fail to auto start o CS01A - 1A CS pump fail to auto start o FW157 - 1D CD/CB NPSH low pressure switch OFF

Verify the following are included in the Smart Scenario:

4

Ensure the following equipment is aligned

1D CD/CB Pump in STBY

1A CC pump is running

1A CV pump is running

1A EH pump is running

1A FW pump OOS

1A SI pump is OOS

Place the following control switches in PTL:

1A FW Pump

1A FW Pump AOP

1A SI pump

Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1A FW Pump

1A FW Pump AOP

1FW002A

1FW012A

1SI8923A

1SI8802A

1SI8821A

1SI8814

Place Protected Equipment placards on the following:

1B FW pump

1C FW pump

1B SI pump

Set BAT Flow Controller to 14.4 for 917 ppm boron

Ensure REMA is available at the Unit Desk

Provide copies of the following documents:

1BOSR 3.g.3-1 UNIT ONE REHEAT AND INTERCEPT VALVE QUARTERLY SURVEILLANCE 5

Turnover Information

Unit 1 is at 75% MOL

917 MWe

RCS boron concentration is 917 ppm

Control bank D @ 171 steps

Online Risk is Green

1A FW Pump is OOS; restoration expected in 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months

1A SI pump is OOS: restoration expected in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months

1BOL 5.2 ECCS - OPERATING, Condition A in effect; 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in progress

Byron Unit 1 has been notified of potential response due grid instabilities projected over the next 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months .

Protected Equipment:

Unit 1 FC Train

1B FW Pump

1C FW Pump

1B SI Pump 6

INSTRUCTOR/SIMULATOR RUN AID GUIDE EO response time will occur per Byron Station Simulator guidelines.

TB - 2 minutes AB - 3 minutes AEER - 1 minute Event 1: Perform 1BOSR 3.g.3-1 Unit One Reheat and Intercept Valve Quarterly Surveillance Acknowledge as EO 1MS5001B and 1MS5003B as initially OPEN, valves full closed after stroke, valves traveling open, and valves returned to original position.

Acknowledge as SM commencement and completion of procedure.

Event 2: Rapid ramp down of 100 MWe for grid instability As TSO, call the simulator on white phone and request a Rapid ramp down of 100 MWe within 30 minutes for grid instability. If name is required, use name of the booth operator.

As Shift Manager, acknowledge and agree with the US reactivity plan.

If requested as RP, acknowledge the ramp.

If requested, as Chemistry, acknowledge the ramp.

Event 3: Master PZR Level Controller 1LK-0459 demand lowers and power failure At Lead Evaluators cue, use Smart Scenario to fail the Master PZR Level Controller by right clicking on the box titled, Event 3, Master PZR Level Controller, and select, Release.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

If requested as EO to local check 1CV121, respond that 1CV121 appears to be working properly.

Event 4: 1LI-112 fails high At Lead Evaluators cue, use Smart Scenario to fail 1LI-112 high by right clicking on the box titled, Event 4, 1LI-112, and select, Release.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

7

Event 5: 1A CC pump trip At Lead Evaluators cue, use Smart Scenario to cause the 1A CC pump to trip by right clicking on the box titled, Event 5, 1A CC Pump Trip, and select, Release.

When dispatched as an EO to check on 1A CC pump or breaker, report that there are no issues at the 1A CC pump and the breaker of the 1A CC pump is tripped open with an overcurrent flag showing.

As Shift Manager, acknowledge entry into TS 3.7.7 Condition B.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

Event 6: 1B DG Control Power At Lead Evaluators cue, use Smart Scenario to fail DC control power to the 1B DG by right clicking on the box titled, Event 6, 1B DG CP, and select, Release When dispatched as an EO to check on 1B DG, report that 1PL08J-1-E8 MCC NOT PROPER FOR AUTO OPERATION is lit, the UNIT AVAILABLE FOR EMERGENCY light is NOT lit, and all 4 DC Power indicators are NOT lit.

As Shift Manager, acknowledge entry into TS 3.8.1 Condition B.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

Event 7 1CC685 At Lead Evaluators cue, use Smart Scenario to close 1CC685 by right clicking on the box titled, Event 7, 1B 1CC685, and select, Release.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

Event 8 & 9 1A & 1D MS Lines break inside CNMT and 1A CS pump failure to auto start and 1B CS pump degrades and trips At Lead Evaluators cue, use Smart Scenario to initiate 1D MS Line break inside CNMT by right clicking on the box titled, Event 8, 1D MS Line break, and select, Release.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-1 entry.

As EO, acknowledge dispatch for monitoring DG operation and Spent Fuel level and temperature.

8

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-2 entry.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BFR Z-1 entry.

9

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 1__

Event

Description:

Perform partial surveillance of 1BOSR 3.g.3-1 Unit One Reheat And Intercept Valve Quarterly Surveillance Time Position Applicants Actions or Behavior CUE Directed at turnover to perform 1BOSR 3.g.3-1 UNIT ONE REHEAT AND INTERCEPT VALVE QUARTERLY SURVEILLANCE Step F1.b for 1MS5001B 1B Low Pressure Turbine East Reheat Stop Valve.

US o Directs NSO to perform 1BOSR 3.g.3-1 BOP

Verify EO stationed to locally observe 1MS5001B 1B Low Pressure Turbine East Reheat Stop Valve (RV E2) and 1MS5003B 1B Low Pressure Turbine East Intercept Valve (IV E2) initial position

Verify:

RSV L2 OPEN indicator lit

IV L2 OPEN indicator lit

RSV L2 CLOSED indicator NOT lit

IV L2 CLOSED indicator NOT lit

Select VALVE TEST on graphic 5501

Select pushbutton RS/IV LEFT 2 on graphic 7000

Verify EO stationed to locally observe 1MS5001B (RV E2) and 1MS5003B (IV E2) travel fully closed

Verify:

RSV L2 CLOSED indicator lit

IV L2 CLOSED indicator lit

RSV L2 OPEN indicator NOT lit

IV L2 OPEN indicator NOT lit

Verify EO stationed to locally observe 1MS5001B (RV E2) and 1MS5003B (IV E2) travel fully open

Verify:

RSV L2 OPEN indicator lit

IV L2 OPEN indicator lit

RSV L2 CLOSED indicator NOT lit

IV L2 CLOSED indicator NOT lit

Verify EO stationed to locally observe 1MS5001B (RV E2) and 1MS5003B (IV E2) return to near initial position

Select EXIT on the popup labeled RSV & IV LH 2

Complete surveillance paperwork US

Verify Tech Specs are satisfied by completion of surveillance EVALUATOR NOTE: After completion of 1BOSR 3.g.3-1, and with lead examiners concurrence, proceed with the next event.

10

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 2__

Event

Description:

Rapid ramp down of 100MWe in 30 minutes for grid instability Time Position Applicants Actions or Behavior CUES

Receive call from TSO directing power reduction of 100 MWe within 30 minutes US

Direct Power per 1BGP 100-4T2 LOAD CHANGE INSTURCTION INSTRUCTION SHEET FOR POWER REDUCTION > 15% IN ONE HOUR

Reference 1BGP 100-4 POWER DESCENSION

Perform pre-job brief per OP-BY-101-0001 ATTACHMENT 9 REACTIVITY CHANGE BRIEF SHEET for load ramp.

Notify Shift Manager to make appropriate notifications per OP-AA-106-101-1004 and OP-AA-102-101 EVALUATOR NOTE: The crew may initiate ramp with control rods in auto. This acceptable as long as the reactivity brief determines the need to borate in order to ensure control rods remain above the insertion limits. Allowing control rods drop below the insertion limit is acceptable while borating is acceptable.

ATC

Verify rod position and boron concentration.

Conducts reactivity brief

Initiate boration per: BOP CV-6, OPERATION OF THE REACTOR MAKEUP SYSTEM IN THE BORATE MODE or BOP CV-6T1, RCMS OPERATE IN BORATE CHECKLIST

Place MU MODE CONT SWITCH to STOP position.

Set MU MODE SELECT to BOR position.

Set 1FK-110 BA Boric Acid to Blender controller to desired flowrate (Batches desired)

Enter gallons into Boric Acid Totalizer on OWS graphic (6003)

Verify totalizer reset

Verify 1CV110A Boric Acid to Blender valve & 1CV110B Boric Acid Blender to Charging Pumps valve in AUTO

Ensure BA Transfer pp is NOT in Pull Out position

Place MAKE-UP CONTROL Switch to START

Ensure proper operation of valves & BA pump

1CV110B Opens, 1CV110A Modulates , BA pump is running o Verify expected BA flow on recorder 1CD-CX4102 o Monitor for Boration effects o Verify at least two B/U Heater groups ON and spray valves 1RY455B/C modulate OPEN.

Monitor for RCS Tave lowering.

o Place Rod Control in Manual utilizing RD-100 as reference

Manually insert Control Rods 11

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 2__

Event

Description:

Rapid ramp down of 100MWe in 30 minutes for grid instability Time Position Applicants Actions or Behavior BOP

Initiate turbine load ramp: Using graphic 5501(per 1BGP 100-4T1.1)

SELECT SETPOINT

ENTER desired (>5) MW/MIN rate in the RATE window

DEPRESS the respective ENTER pushbutton

ENTER desired final MWe output (100 MWe less than current) in the REF DEMAND window

SELECT ENTER

DEPRESS EXIT

DEPRESS the GO/HOLD pushbutton

Inform US/RO of pending drop in turbine load

SELECT GO (when RO reports expected Tave drop)

Verify load lowering as expected ATC

Monitor reactor power and load ascension:

Monitor NIs, Tave, I, Pzr press/level.

During dilution, monitor the following at 1PM05J and HMI:

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow counter responding correctly.

Verify dilution auto stops at preset value.

o Return Reactor Makeup System to automatic.

Withdraw control rods per ReMA.

EVALUATOR NOTE: After measurable change in power and with lead examiners concurrence, initiate the Event 3.

12

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 3__

Event

Description:

Master PZR Level Controller 1LK-0459 failure Time Position Applicants Actions or Behavior CUE: Annunciator

1-7-B2 RCP SEAL WTR INJ FLOW LOW

1-8-C5 LTDWN HX OUTLT TEMP HIGH

1-12-C1 PZR PRESS CONT DEV LOW HTRS ON

1LR-0459 Recorder decreasing level

1LK-0459 Loss of Power

Decreasing Charging Flow ATC

Take action per the BAR

Determine that 1LK-0459 has lost power and lowered demand

Take manual control of level to restore PZR level to program o Manual control and adjust 1CV121 o Manual control PZR Level controller using Ovation Soft Slim US

Verify PZR level moving back to Program Level

Monitor Charging and Letdown parameters

Flow

Temperatures EVALUATOR NOTE: After measurable crew has established control of PZR level, and with lead examiners concurrence, initiate the Event 4.

13

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 4__

Event

Description:

1LI-112 fails high Time Position Applicants Actions or Behavior CUE Annunciator:

1-9-A2 VCT LEVEL HIGH-HIGH/LOW

1-10-E4 OVATION SYSTEM TROUBLE

1LI-112 indicates 100%

Take action per BAR 1-9-A2 VCT LEVEL HIGH-HIGH/LOW:

ATC

Determine if the VCT level is high, low, or a failed channel

Check level indications

Place 1CV112A Letdown Diversion to VCT or HUT Tanks Valve to HUT as necessary US

Enter 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL UNIT 1 ATTACHMENT V ATC

Check VCT level normal

Check VCT Level Channel 112 - channel failed high

Check VCT Level Channel 185

Select and OPERABLE VCT Level Channel in Ovation

VCT Level 1 - Select CV-LT-0185

VCT Level 2 - Select CV-LT-0185

Restore VCT level control to Auto

1CV112A EVALUATOR NOTE: After 1LI-185 is selected as the controlling channel, and with lead examiners concurrence, continue with the next event.

14

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 5__

Event

Description:

1A Component Cooling Pump trip; 1B Component Cooling Pump fails to Auto start Time Position Applicants Actions or Behavior CUE Annunciator:

1-2-A4 CC PUMP TRIP

1-2-A7 SEAL WTR HX CC FLOW LOW

1-2-B5 CC PUMP DSCH PRESS LOW

1-2-D7 CNMT PEN CLG FLOW HIGH HIGH LOW

1-7-A4 - E4 RCP 1A/B/C/D THERM BARR CC WTR FLOW LOW

1-7-A5 - E5 RCP 1A/B/C/D BRNG CC WTR FLOW LOW

Drop of Component Cooling system pressure

Disagreement light on 1A Component Cooling pump BOP

Respond per BAR 1-2-A4 CC PUMP TRIP or OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION

Verify/Start 1B CC Pump

Verify CC System pressure returns to normal US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.7.7 Component Cooling Water (CC) System (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION B, One required CC pump inoperable.

o B.1

RA - Restore required CC pump to OPERABLE status.

CT - 7 days.

EVALUATOR NOTE: After system pressure is restored to normal, and with lead examiners concurrence, continue with the Event 6.

15

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 6__

Event

Description:

Loss of 1B Diesel Generator Control Power Time Position Applicants Actions or Behavior CUE:

Annunciators:

1-22-C8 DG 1B TROUBLE/FAIL TO START

Loss of 1B DG Control Switch indication Crew

Takes action per the BAR 1-22-C8 DG 1B TROUBLE/FAIL TO START

Dispatch operator to Local Control Panel 1PL08J to investigate the alarm

EO will report a total loss of DC power to the 1B DG US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.8.1 AC Sources - Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION B, One required DG inoperable.

o B.1

RA - Verify both opposite-unit DGs OPERABLE.

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter.

o B.2

RA - Perform SR 3.8.1.1 for the required qualified circuits.

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter.

o B.3

RA - Declare required features supported by the inoperable DG when it is required redundant feature is inoperable.

CT - 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery of Condition B concurrent with inoperability of redundant required feature

3.5.2 ECCS - Operating, Condition B within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months o B.4

RA - Determine OPERABLE DG is not inoperable due to common cause failure.

CT - 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months o B.5

RA - Restore DG to OPERABLE status.

CT - 14 days.

EVALUATOR NOTE: When Tech Spec actions have been completed for loss of 1B DG Control Power and with lead examiners concurrence, continue with the Event 7.

16

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 7__

Event

Description:

1CC685 Component Cooling Water from RCPs Thermal Barrier Isolation Valve spuriously closes Time Position Applicants Actions or Behavior

Annunciator

1-7-A4 RCP 1A THERM BARR CC WTR FLOW LOW

1-7-B4 RCP 1B THERM BARR CC WTR FLOW LOW

1-7-C4 RCP 1C THERM BARR CC WTR FLOW LOW CUE

1-7-D4 RCP 1D THERM BARR CC WTR FLOW LOW

1-7-E4 RCP THERM BARR CC WTR FLOW HIGH LOW

1CC685 Component Cooling Water from RCPs Thermal Barrier Isolation Valve Closed light Lit

Refer to BAR 1-7-A4, B4, C4, D4, or E4

Check RCP Seal Injection flow for the affected pumps - in service BOP

Check 1CC9413A Component Cooling to RCPs Isolation Valve, 1CC685, and 1CC9438 Component Cooling from RCP Thermal Barrier Isolation Valve are OPEN

Determine 1CC685 is closed

Direct BOP to OPEN 1CC685 US o Refer to 1BOA PRI-6 COMPONENT COOLING MALFUNCTION BOP

Open 1CC685

Check Plant Status BOP

Verify all annunciators clear EVALUATOR When all Component Cooling alarms are clear, and with lead examiners NOTE: concurrence, continue with the Event 8.

17

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Main Steam Lines Break Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior EVALUATOR NOTE: Crew actions for 1BFR Z.1 will be on page 23.

The crew will transition to 1BFR Z.1 when entry conditions of no Containment Spray pumps running with Containment Pressure greater than 20 psig are met and the crew has transitioned out of 1BEP-0.

CUE

Annunciator

1-1-A2 CNMT DRAIN LEAK DETECT FLOW HIGH

1-10-A5 OP DELTA T HIGH ROD STOP ALERT C-4

1-10-E4 OVATION SYSTEM TROUBLE

1-10-E5 OVATION ALTERNATE ACTION

1-15-A4 S/G 1A FLOW MISMATCH FW FLOW LOW

1-15-D4 S/G 1D FLOW MISMATCH FW FLOW LOW

1-15-E2 MS PRESS LOW

1A & 1D STM Flow Indications (1FI-512A/542A AND 1FI-513A/543A) HIGH

1A & 1D SG Steam Pressures dropping

RX Power rising US o Direct a manual reactor trip and operators perform immediate actions of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION ATC

Manually trips the reactor US

Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notify SM for procedure entry, EP evaluation o Request STA to come to the control room ATC

Verify Reactor Trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux DROPPING BOP

Verify Turbine Trip

Turbine throttle valves - CLOSED

Turbine governor valves - CLOSED BOP

Verify power to 4KV busses

Bus 141 - ENERGIZED

Bus 142 - ENERGIZED 18

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Main Steam Lines Break Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior ATC

Check SI status

SI actuated

SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

Check PZR pressure < 1829 psig

Check Steamline pressure < 640 psig

Check CNMT pressure > 3.4 psig

If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE: Crew actions of 1BEP-0 continue following NOTE.

BOP actions of 1BEP-0, Attachment B continue on page 25.

ATC

Verify AF system:

AF pumps - BOTH RUNNING

AF isolation valves 1AF13A-H - OPEN

AF flow control valves 1AF005A-H - THROTTLED

AF flow - GREATER THAN 500 GPM

Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE -

Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER ATC

Check PZR PORVs and Spray Valves

PORVs - CLOSED

Check pressure less than 2315

PORV isol valve - at least one ENERGIZED

PORV relief path - at least one AVAILABLE

PORV in - AUTO

Isolation valve - open

Normal spray valves - CLOSED ATC

ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC

Check steam dumps - AVAILABLE

C-9 Permissive light - NOT LIT

CW Pump - AT LEAST ONE RUNNING ATC

Control RCS Temperature per table:

Adjust Feed Flow

Steam Release 19

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Main Steam Lines Break Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior Evaluator Note: RCP trip criteria is likely to be met at this time. If not, RCPs will meet trip criteria when Phase B actuates.

ATC

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

High head flow 1FI-917 > 100 GPM and RCS Pressure < 1425 PSIG.

Trip all RCPs if RCP trip criteria is met ATC

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner - 1A & 1D SG pressures dropping uncontrolled

NO SG Completely Depressurized.

Crew

Transition to 1BEP-2 FAULTED STEAM GENERATOR ISOLATION, Step 1.

EVALUATOR NOTE: The crew actions for 1BEP-2 FAULTED STEAM GENERATOR ISOLATION continue on the next page.

20

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Main Steam Lines Break Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior EVALUATOR NOTE: The crew is expected to transition to 1BFR Z.1 when entry conditions of no Containment Spray pumps running with Containment Pressure greater than 20 psig are met. Dependent on the speed of the crew actions this may occur immediately upon entry or during the execution of 1BEP-2. This may delay the completion of 1BEP-2, but should not count as a transition out of 1BEP-2 for purposes of evaluating the critical step. The successful completion of the BFR will return the crew to 1BEP-2.

US

Implement 1BEP-2 FAULTED STEAM GENERATOR ISOLATION and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation o Request STA to come to the control room ATC CHECK MAIN STEAMLINE ISOLATION

All MSIVs closed.

All MSIV bypass valves closed.

CREW Check if any SG Secondary Pressure Boundary is intact:

Any SG pressure STABLE OR RISING ATC/BOP IDENTIFY Faulted SG:

Any SG pressure dropping in an Uncontrolled manner - 1A & 1D SG

Any SG completely depressurized CT-17 ATC/BOP Isolate Faulted SG:

Close AF isolation valves for 1A & 1D SGs

1AF013A

1AF013E

1AF013D

[CT]

1AF013H

Check all FW Isolation lights lit for the 1A & 1D SG on 1PM04J

Verify 1MS018D and 1MS108A SG PORVs are closed

Verify SG blowdown isolated

1SD002A

1SD002B

1SD002C

1SD002D

Verify SG blowdown sample isolation valve closed

1SD005A

1SD005B 21

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Main Steam Lines Break Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior

Verify Main Steamline isolation and bypass valves closed

1MS001A

1MS001D

1MS101A

1MS101D CREW

Monitor AF Suction Pressure.

Check Secondary Radiation.

Reset Phase A

Open SG Blowdown Sample Valves

1SD005A - D

Request Chemistry sample all SGs for activity

Check Secondary radiation trends / secondary activity samples CREW

Check if ECCS flow can be reduced:

RCS subcooling acceptable

Total feed flow greater than 500 gpm or Narrow Range level in at least one intact SG greater than 31% (adverse)

RCS pressure stable or rising

PZR level greater than 28% (adverse)

CREW

Transition to 1BEP ES-1.1 SI TERMINATION, Step 1.

EVALUATOR NOTE: The crew is expected to have completed all critical tasks prior to transition to 1BEP ES-1.1 SI TERMINATION.

22

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Mainsteam Lines Leak Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BFR Z.1 RESPONSE TO HIGH CONTAINMENT PRESSURE UNIT 1 actions begin on this page.

US

Implement 1BFR Z.1 RESPONSE TO HIGH CONTAINMENT PRESSURE UNIT 1 and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation o Request STA to come to the control room

Verify CNMT Phase A - Group 3 CNMT isolation lights - lit CREW

Verify CNMT Vent Isolation - Group 6 CNMT vent isolation lights - lit CREW o Check if CS required - CNMT pressure has risen greater than 20 psig

Verify proper system valve alignment

1CS001A 1A CS Pump RWST Suction Valve or 1CS009A 1A CS Pump CNMT Recirc Sump Suction Valve open

1CS001B 1B CS Pump RWST Suction Valve or 1CS009B 1B CS Pump CNMT Recirc Sump Suction Valve open CREW

1CS007A 1A CS Pump Discharge Header Isolation Valve open

1CS007B 1B CS Pump Discharge Header Isolation Valve open

1CS019A 1A CS Eductor Spray Add Valve open - no, open 1CS019A

1CS019B 1B CS Eductor Spray Add Valve open

1CS010A 1A CS Eductor Suction Valve open

1CS010B 1B CS Eductor Suction Valve open EVALUATOR NOTE: 1A CS pump will start once 1CS019A is full open. 1B CS pump will remain tripped.

CREW

Verify CS pumps - Both running CT-3

1A CS Pump running

[CT]

1B CS pump tripped CREW

Group 6 Phase B Isolation monitor lights - lit CREW o Stop all RCPs

Check CS pump discharge flow on running pump - greater than 200 gpm CREW

Check CS pump educator suction flow on running pump - greater than 15 gpm

Check CS educator additive flow - greater than 5 gpm o Align SX Cooling Towers o All riser valves open CREW o All Hot Water Basin Bypass valves - closed o All SX Cooling Tower fans - running in HI speed CREW

Group 2 RCFC Accident Mode status lights - lit 23

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1A & 1D Mainsteam Lines Leak Inside Containment and CS Pumps Malfunction Time Position Applicants Actions or Behavior CREW o Verify all MS Isolation valves closed

Check if Feed Flow should be isolated to any SG

Any SG dropping in an uncontrolled manner - yes CREW

Any SG completely depressurized

Close 1AF013D and 1AF013H

Verify all FW Isolation Monitor Lights - lit CREW o Transition to procedure and step in effect 24

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1D Mainsteam Line Leak Inside Containment and CS Pump Malfunctions Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

BOP Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps - BOTH RUNNING

RH pumps - BOTH RUNNING

SI pumps - BOTH RUNNING BOP Attachment B action VERIFY ECCS VALVE ALIGNMENT

Group 2 Cold Leg Injection monitor lights required for ECCS valve alignment - LIT EVALUATOR NOTE: RCS pressure is dependent on when evaluated, it is anticipated to be below 1700 psig at this step.

BOP Attachment B action VERIFY ECCS FLOW

HHSI flow >100 gpm

RCS pressure <1700 psig

SI flow > 200GPM

RCS pressure NOT less than 325 psig BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights - LIT Verify CNMT isolation Phase A

Group 3 CNMT isolation monitor lights - NOT LIT Verify CNMT Ventilation isolation

Group 6 CNMT Vent Isol monitor lights - LIT Verify CC Pumps

CC pumps - BOTH RUNNING Verify SX Pumps running

SX pumps - BOTH RUNNING Check If Main Steamline Isolation Is Required o Check SG pressure < 640 psig o Check CNMT pressure > 8.2 psig

If either condition is met, then verify MSIVs and MSIV Bypass valves closed EVALUATOR NOTE: Containment pressure is dependent on when evaluated, it is anticipated to be above 20 psig by this time or soon after. BOP should recognize this and come back if required.

BOP Attachment B action Check if CS is required

CNMT pressure HAS risen to greater than 20 psig

Group 6 CS monitor lights - LIT

Group 6 Phase B Isol monitor lights - LIT 25

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1D Mainsteam Line Leak Inside Containment and CS Pump Malfunctions Time Position Applicants Actions or Behavior

Stop all RCPs

Check CS eductor suction flow on running pump greater than 15 gpm

Check CS eductor additive flow on running pump - greater than 5 gpm

Verify SX Cooling Tower alignment o All 8 riser valves open o All 4 hot water basin bypass valves closed o All 8 SX cooling tower fans running in high speed BOP Attachment B action VERIFY FW ISOLATED

FW pumps tripped

FW isolation monitor lights lit

FW pumps discharge valves closed 1FW002A-C

Trip all running HD pumps BOP Attachment B action VERIFY BOTH DGS RUNNING:

DGs - BOTH RUNNING

SX valves open 1SX169A and B

Dispatch operator locally to check operation BOP Attachment B action VERIFY GENERATOR TRIP

Unit 1 Main Transformer output breakers - OPEN:

GCB 3-4

OCB 4-5

Excitation red OFF light is LIT 26

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1D Mainsteam Line Leak Inside Containment and CS Pump Malfunctions Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY CONTROL ROOM VENTILATION ALIGNED FOR EMERGENCY OPERATIONS:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints

Operating VC train equipment running Train A

Supply fan 0A

Return fan 0A

M/U fan 0A

Chilled water pump 0A

MCR chiller 0A

Operating VC train dampers

M/U fan outlet damper NOT full closed 0VC24Y

VC train M/U filter light LIT

Operating VC train Charcoal Absorber aligned for train A

0VC43Y closed

0VC21Y open

0VC22Y open

Operating VC train M/U filter alignment

0VC25Y open

0VC312Y closed

Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED

Two inaccessible filter plenums aligned

Plenum A fan 0VA03CB running

Damper 0VA023Y not fully closed

Damper 0VA436Y closed

Plenum C fan 0VA03CF running

Damper 0VA072Y not fully closed

Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans

One Exhaust Fan running for every Supply Fan running BOP Attachment B action VERIFY FHB VENTILATION ALIGNED

Train B fan 0VA04CB running

0VA055Y open

0VA062Y not fully closed

0VA435Y closed 27

Op-Test No.: 2021-301 _ Scenario No.: _N21-2_ Event No.: _ 8 & 9__

Event

Description:

1D Mainsteam Line Leak Inside Containment and CS Pump Malfunctions Time Position Applicants Actions or Behavior BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling

Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of

Manual actions taken

Failed equipment status

Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN EVALUATOR NOTE: The crew actions for of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, continue on page 18.

The crew actions for of 1BEP-2 FAULTED STEAM GENERATOR ISOLATION, begin on page 22.

The crew actions for of BFR Z-1 RESPONSE TO HIGH CONTAINMENT PRESSURE UNIT 1 begin on page 24.

28

Facility: _Byron Nuclear Station__ Scenario No.: ___3___ Op-Test No.: _2021-301_

Examiners: __________________________ Operators: _____________________________

Initial Conditions: 8% RTP, BOL, Main Generator not synced to the grid.

Turnover: Continue raising power to the 20% per 1BGP 100-3, step 72 after Syncing the Main Generator per Step 27. 1A FW Pump OOS, expected RTS in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 1A SI pump OOS, expected RTS in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . 1BOL 5.2 entered for 1A SI pump.

Event Malf. No. Event Event No. Type* Description 1 None R - ATC R - BOP R - SRO Raise power above 10%

N - BOP N - SRO Sync Main Generator to the grid 2 CV08 I - ATC 1PT131 fails low I - SRO 3 TH11B C - ATC PZR PORV leaking (Isolable) (NRC Exam 19-2)

C - SRO TS - SRO 4 ED10D ED11D C - BOP Loss of Instrument Bus 114 C - SRO TS - SRO 5 TH06B M (ALL) SB LOCA - E-1 Manually start 1B SI Pump [CT]

6 ZDI1CV112B CREW 1CV112 valves fail to swapover for SI [CT]

ZDI1CV112C ZDI1CV112D ZDI1CV112E

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Critical Tasks:

1. CT-7: Establish flow from the1B SI pump before transition out of E-0. (K/A number - 006A3.05; importance 4.2/4.3)

a. Safety Significance: Failure to manually start at least one high-head SI pump results in degraded ECCS capacity.

b. Cues: Indication of a SI actuation AND RCS pressure below the shutoff head of the high-head SI pumps AND all Charging/SI pumps indicate zero discharge pressure and zero injection flow.

c. Performance Indicator: Manipulation of controls as required to establish flow from at least one Charging/SI pump.

d. Feedback: Indication and/or annunciation that at least one high-head SI pump is injecting.

2. CT-15: Transfer suction from VCT (BAT) to RWST for at least one operating train of high-head SI before suction on the VCT (BAT) is lost due to low level. (K/A Number - 006-A3.08, Importance - 4.2/4.3)

a. Safety Significance: Failure to manually transfer high-head SI suction to the RWST results in loss of high-head SI at a time when high-head injection is required for core cooling.

b. Cues: Indications that a safety injection is actuated AND indication that the high-head SI suction is not transferred to the RWST.

c. Performance Indicator: Manipulations of controls to align the high-head SI suction for at least one train of high-head SI from the VCT (BAT) to the RWST

d. Feedback: Flow indication of RWST water through the high-head SI pumps into the RCS.

2

The scenario will start at ~8% RTP, BOL, with the crew being directed to continue raising power to the 20% per 1BGP 100-3 POWER ASCENSION, step 72 after Syncing the Main Generator per Step 27. 1A FW Pump OOS, expected RTS in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 1A SI pump OOS, expected RTS in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . 1BOL 5.2 entered for 1A SI pump.

Event 1 The crew will raise power above 10% RX power, per 1BGP 100-3 POWER ASCENSION to establish conditions to support synching the Main Generator to the grid. The crew will Sync the Main Generator per Step 27 after starting the 1C HD pump per Step 26. The crew will continue to perform steps 33 and 34 of 1BGP 100-3. Once the Generator is synced and RX power is greater than 10%, at the lead examiners discretion, proceed to Event 2.

Event 2 1PT-131 Letdown Line Pressure Transmitter will fail low causing 1CV131 Letdown HX Outlet Header Pressure Control Valve to close. The crew will identify the failed instrument and take manual control of 1CV131 per BHC 1-LD LETDOWN MALFUNCTION. Once letdown is restored to normal in manual, at the lead examiner discretion, continue to Event 3.

Event 3 1RY456 U1 Pressurizer PORV will start to leakby at 5 GPM. The crew will identify the leakage, by Dual Indication on the valve and rising tailpipe temperature. The crew will respond per BAR 1-12-C6 PZR PORV DSCH TEMP HIGH. The crew will close PZR PORV Block valve 1RY8000B to isolate the leakage. The crew will enter Tech Spec 3.4.11 Condition A.

Once the Tech Spec has been entered, at lead examiner discretion, continue to Event 4.

Event 4 Instrument Bus 114 will fail. The crew will identify the failure of the instrument bus and respond with 1BOA ELEC-2 LOSS OF INSTRUMENT BUS UNIT 1. The crew will reference Table D, enter 1BOA INST-1 NUCLEAR INSTRUMENTATION MALFUNCTION for loss of N44 to bypass/defeat N44 functions, and dispatch an EO to fail the air to the 1AF005E-H 1B AF Pump Discharge Valves to the Steam Generators. The crew will enter Tech Specs 3.8.9 Condition B. Once the initial actions are complete for both BOAs, at the lead examiners discretion, continue with Event 5.

Event 5 A LOCA will occur inside containment. The crew will identify the event and manually trip the RX and actuate a Safety Injection. The crew will respond per 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1. Due to the loss of Instrument Bus 114, B Train ECCS equipment will need to be manually aligned. The only SI pump available, 1B SI pump, will need to be manually started. The crew will transition to 1BEP-1 LOSS OF REACTOR OR SECONDARYCOOLANT UNIT 1.

Event 6 The 1CV112D and E, RWST to U1 Charging Pump Suction Isolation Valves, will fail to open on the Safety Injection initiation. 1CV112B and C, VCT Outlet Upstream and Downstream Isolation Valves, receive the close signal from the SI, but are interlocked to close only after 1CV11D and E are open, respectively. The crew will identify and align the valves per 1BEP-0, Attachment B or OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION. The crew will need to manually open the 1CV112D and E valves (at least one) to ensure proper suction to ECCS pumps.

The scenario can be terminated after completion of 1BEP-1 Step 6 and completion of critical tasks of ECCS equipment alignment and alignment of the 1CV112 valves.

3

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, Simulator Ready for Training Checklist.

Establish the conditions of IC 142, ~8% power, MOL, equilibrium xenon

Place Simulator in RUN

Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N21-3 Scenario.ssf o Click on the MODE button (near top of screen) and pick EXECUTE o Click on the PLAY button (bottom left of screen) o Verify Simulator Setup conditions automatically load o 1A FW Pump OOS o 1A SI Pump OOS

Verify the following are included in the Smart Scenario:

4

Ensure the following equipment is aligned

0A VC Train in Service

1A FW pump OOS

1A SI pump is OOS

Place the following control switches in PTL:

1A FW Pump

1A FW Pump AOP

1A SI pump

Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1A FW Pump

1A FW Pump AOP

1FW002A

1FW012A

1SI8923A

1SI8802A

1SI8821A

1SI8814

Verify FW Hardcard with Single Pump response facing out.

Verify NI cabinets back doors locked and key unavailable to candidates

Place Protected Equipment placards on the following:

1B FW pump

1B SI pump

Set BAT Flow Controller to 14.4 for 917 ppm boron

Verify clear boration / dilution valves and reset after placed in run

Ensure REMA is available at the Unit Desk

Provide copies of the following documents:

1BGP 100-3

1BGP 100-3T1 5

Turnover Information

Unit 1 is at ~8% MOL

Turbine rolling at 1775 RPM

RCS boron concentration is 1324 ppm

Control bank D @ 135 steps

Online Risk is Green

Bringing the unit online after a RX trip due to a FW transient. The unit has been shutdown for 3 days.

Just after entering Mode 1, the 1A SI pump was declared inop due to a significant oil leak. The power ascension was placed on hold at about 8% power in order to determine the impact of the 1A SI pump inoperability. With pump repairs schedule to complete in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , permission has been given to proceed with raising RX power and synching the main generator to the grid.

1BGP 100-3T1 is in progress. The Shift Manager authorized some steps to be performed early.

BOP HD-1 has all prerequisites, precautions, and limitations and actions complete. EO is on standby in the field to start the 1A HD Pump. BOP HD-1 Steps 1 & 2 complete. Local steps of Step 5 are complete.

QNE has allowed for ALT DILUTE for dilutions

1PM03J Annunciator Alarms for Heater Levels are suspended, unless HI-2 Alarm.

PDMS is inoperable.

1A FW Pump is OOS; restoration expected in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

1A SI pump is OOS: restoration expected in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

1BOL 5.2 ECCS - OPERATING, Condition A in effect; 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in progress

Protected Equipment:

Unit 2 FC Train

1B FW Pump

1B SI Pump 6

INSTRUCTOR/SIMULATOR RUN AID GUIDE EO response time will occur per Byron Station Simulator guidelines.

TB - 2 minutes AB - 3 minutes AEER - 1 minute Event 1: Raise power above 10% and sync Main Generator to the grid Acknowledge as EO all pre-start checks on the 1A HD Pump are complete. The area is clear and you are standing by for a start of the pump. After pump start, wait 1 minute, and report pump start is good all local indications normal and local flow indicates approximately 1000 gpm Acknowledge as SM commencement of each step of the procedure.

Event 2: 1PT131 fails low At Lead Evaluators cue, use Smart Scenario initiate a failure of 1PT-131 by right clicking on the box titled, Event 3, 1PT131, and select, Release.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 3: PZR PORV leaking (Isolable)

At Lead Evaluators cue, use Smart Scenario initiate a leaking PORV 1RY456 by right clicking on the box titled, Event 3, PZR PORV, and select, Release.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 4: Loss of Instrument Bus 114 At Lead Evaluators cue, use Smart Scenario to initiate a loss of Instrument Bus 114 by right clicking on the box titled, Event 4, Instrument 114, and select, Release.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BOA ELEC-2.

When dispatched as an EO to check on the instrument bus, report that there is an acrid smell in the air around the Instrument bus. Identify that no breakers are closed on the inverter or the CVT.

As Shift Manager, bistables are to be placed in Bypass.

As EO, acknowledge request to fail air to 1AF005 valves. After 3 minutes, fail air to valves by right clicking on the box titled, Event 4a, AF Valves, and select, Release.

As WEC, acknowledge personnel required to be briefed and dispatched to trip bistables.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

Event 5: SB LOCA - E1 At Lead Evaluators cue, use Smart Scenario to initiate a SB LOCA by right clicking on the box titled, Event 5, SB LOCA, and select, Release.

7

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-0 entry.

As EO, acknowledge dispatch for monitoring DG operation and Spent Fuel level and temperature.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-1 entry.

Event 6: 1CV112 valves fail to swapover for SI As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

8

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 1__

Event

Description:

Raise power above 10% and sync Main Generator to the grid Time Position Applicants Actions or Behavior CUE Directed at turnover to perform raise power above 10% and synch Main Generator to the grid US o Directs NSO to perform 1BGP-100 steps Step 9 and subsequent steps to perform Step 27.

ATC

Verify rod position and boron concentration.

Conducts reactivity brief

Initiate dilution IAW ReMA and BOP CV-5 OPERATION OF THE REACTOR MAKEUP SYSTEMIN THE DILUTE AND ALTERNATE DILUTE MODE or BOP CV-5T1 RMCS OPERATION IN DILUTE / ALT DILUTE CHECKLIST

Place MU MODE CONT SWITCH to STOP position

Set MU MODE SELECT to DIL or ALT DIL

Set 1FK-110 BA Boric Acid to Blender controller to desired flowrate (Batches desired)

Enter gallons into Boric Acid Totalizer on OWS graphic (6003)

Verify totalizer reset

Place RMCS Makeup Control Switch to START

Verify 1CV110B OPEN if in ALT DIL

Verify 1CV111A and B OPEN

Verify proper PW flow on flow recorder 1CD-CX4102

Monitors effects of dilution

Turn on PZR backup heaters.

ATC

When reactor power is greater than 10%, PERFORM the following:

ENSURE POWER RANGE PERMISSIVE P10 (3.4) Bypass Permissive Light is NOT ILLUMINATED.

BLOCK Intermediate Range Channel Reactor Trips by taking BOTH trains of IR Man Block Switches to the BLOCK position.

ENSURE the following Bypass Permissive Lights are NOT ILLUMINATED.

IR TRIP NOT BLOCKED TRN A (1.3)

IR TRIP NOT BLOCKED TRN B (2.3)

BLOCK the Power Range Low Setpoint Reactor Trips by taking BOTH trains of Pwr Rng Man Block Switches to the BLOCK position.

ENSURE the following Bypass Permissive Lights are NOT ILLUMINATED.

POWER RANGE LOW SETPOINT TRIP NOT BLOCKED TRN A (1.4)

POWER RANGE LOW SETPOINT TRIP NOT BLOCKED TRN B (2.4)

SELECT desired channels on NR-45 Recorder to be displayed for startup.

9

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 1__

Event

Description:

Raise power above 10% and sync Main Generator to the grid BOP

Turbine Speed Increase to 1800 RPM:

o DETERMINE the maximum Main Turbine acceleration rate using BCB-1, Figure 21 or 21a.

o PREPARE to RAMP the turbine by performing the following from graphic 5501:

SELECT SETPOINT.

ENTER 1800 into the REF DEMAND window.

SELECT ENTER.

VERIFY 1800 appears in the REFERENCE DEMAND window on graphic 5501.

ENTER 50 into the RATE window (or acceleration rate determined in step F19. a.).

SELECT ENTER.

VERIFY the correct value appears in the RATE window on graphic 5501.

SELECT EXIT.

RAMP Main Turbine by performing the following from graphic 5501:

SELECT GO/HOLD.

VERIFY GO/HOLD illuminates orange.

VERIFY HOLD indicator illuminates red.

SELECT GO.

VERIFY GO indicator illuminates red while turbine ramps.

PERFORM the following when main turbine speed reaches 1800 RPM:

VERIFY that Turbine acceleration STOPS.

VERIFY the GO indicator, on graphic 5501 goes OFF when turbine speed has stabilized at ~1800 RPM.

ATC

When bypass permissive P10 and/or P13 goes OFF, ENSURE that the LOW POWER TRIPS BLOCKED P7 Bypass Permissive light goes OFF.

ATC

MAINTAIN Reactor Power less than 30% (P-8) yet great enough to provide approximately 35 to 45% Steam Dump demand on 1UI-500 for synchronization.

ENSURE steam dumps are maintaining steam header pressure in Auto or Manual.

ENSURE Tave is being maintained at approximately 562 oF.

CREW

Verify Steps 21, 22, 23, 24 BOP

Heater Drain Tank preparation for synchronization:

START a Heater Drain Pump in accordance with BOP HD-1 shortly before generator synchronization.

VERIFY/OPEN 1FW012A/B/C, FW Pump Recirc Valve, on the running Feedwater Pump.

BOP

Perform Step F27 to synch main generator CREW

Verify Steps 28, 29, 30, 33, 34, 35, 36, and 37 10

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 1__

Event

Description:

Raise power above 10% and sync Main Generator to the grid ATC

Raise power per Step 72 EVALUATOR NOTE: After main generator is synched and power is rising, and with lead examiners concurrence, proceed with Event 2.

11

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 2__

Event

Description:

1PT131 fails low Time Position Applicants Actions or Behavior CUES

Annunciator:

1-9-B1 LP LTDWN RLF TEMP HIGH

Letdown flow drops to zero

Letdown pressure drops to zero

1CV131 indicates closed US

Directs actions per the BAR or BHC 1-LD ATC

Take actions per the BAR or BHC

Verify 1CV131, Ltdwn Line Press Cont Vlv is operating properly - no

Take manual control of 1CV131 and restore letdown flow into the green band ATC

Monitor letdown line temperatures restored into green band EVALUATOR NOTE: After control is established and temperature is back in green band, with lead examiners concurrence, initiate the Event 3.

12

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 3__

Event

Description:

PZR PORV leaking (Isolable)

Time Position Applicants Actions or Behavior CUE:

Annunciator

BAR 1-12-C6 PZR PORV DSCH TEMP HIGH

BAR 1-12-B2 PZR PORV OR SAF VLV OPEN

Dual indication on 1RY456

Slight drop in PZR pressure ATC

Take action per the BHC 1-RY-P

IF Pzr PORV failed open THEN:

CLOSE affected PORV using its handswitch

IF PORV still open then close affected PORVs block valve (1RY8000A/B)

OR

BAR 1-12-C6 PZR PORV DSCH TEMP HIGH

MONITOR RCS pressure and temperature.

CHECK that PZR PORV and Safety Valves indicate CLOSED.

MONITOR Pressurizer Relief Tank level, temperature and pressure.

IF PZR PORV is leaking, THEN CLOSE its associated Block Valve.

MONITOR PZR PORV and Safety Valve Discharge Line temperatures.

US

Identify 1RY456 as leaking PORV US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

(RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One or more PORVs inoperable and capable of being manually cycled.

o A.1

RA - Close and maintain power to associated block valve.

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months EVALUATOR NOTE: After the US determines the Tech Spec requirements, and with the lead examiners concurrence, initiate the Event 4.

13

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 4__

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior CUE Annunciator:

Multiple annunciators for bus power indication

Loss of N44 US

Direct entry into 1BOA ELEC-2 LOSS OF INSTRUMENT BUS UNIT 1

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests

CHECK CONTROL CHANNELS:

Control channels - OPERABLE: Take manual control of affected parameter.

PZR pressure

PZR level ATC

Tave

T

P Impulse pressure

SG level

Steam flow

Feed flow CREW

LOCALLY ENERGIZE AFFECTED INSTRUMENT BUS:

Check bus - NOT DAMAGED - damaged

Check affected Instrument Bus - energized - no

IF INSTRUMENT BUS 114 is dead THEN perform the following:

Refer to TABLE D (Page 19) for expected equipment failures Crew

Perform 1BOA INST-1 Nuclear Instrumentation Malfunction

Dispatch and operator to fail open Train B aux feed flow control valves by failing the air to the valve operators: 1AF005E thru H

Verify/Align Train A VC as the operating train US

Direct entry into 1BOA INST-1

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests EVALUATOR NOTE: Based on the Start Up in progress, Tave - Tref stable within 1°F may be N/A.

14

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 4__

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior ATC

CHECK ROD CONTROL STATUS

ROD BANK SELECT switch in - MANUAL

CHECK FOR ROD STOP

PWR RNG FLUX HIGH ROD STOP alarm (1-10-B5) - NOT LIT

CHECK TAVE - TREF DEVIATION

Tave-Tref - STABLE AND WITHIN 1°F

CHECK SG LEVELS

SG levels - NORMAL AND STABLE BOP

REMOVE THE FAILED PR CHANNEL FROM SERVICE - 1NR-44

Select OWS graphic REACTOR TEMPERATURE CONTROL (6020)

Select NI POWER in SIGNAL SELECTORS box

Select the NI POWER graphic (7100) header to enable the window

Select the PLACE OUT OF SERVICE soft control button for the failed PR channel

Verify the PLACE OUT OF SERVICE soft control button for the affected PR channel NR-N4_ illuminates (red) and USE 2nd HIGHEST soft control button is NOT illuminated (grey)

Exit window EVALUATOR NOTE: With Instrument Bus 114 is deenergized the following functions are inoperable on the Detector Current Comparator section: Upper Section Defeat and Lower Section Defeat.

BYPASS/DEFEAT PR CHANNEL FUNCTIONS AT 1PM07J:

Bypass/Defeat affected channel functions on 1PM07J:

Detector Current Comparator:

UPPER SECTION - not available BOP

LOWER SECTION - not available

Miscellaneous Control and Indication section:

POWER MISMATCH BYPASS

ROD STOP BYPASS

Comparator and Rate panel:

COMPARATOR CHANNEL DEFEAT ATC

CHECK FLUX RATE TRIP ALARM

Pwr Rng Flux Rate Rx Trip Alert (1-10-C3) - NOT LIT 15

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 4__

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior

PLACE COMPUTER POINTS IN TEST/DELETE FROM SCAN FOR AFFECTED PR CHANNEL:

On the PPC PDMS Test Mode page place the following computer points - IN TEST:

N0047, N0048, U1143, U1147 Crew

Delete the following computer points in - FROM SCAN:

N0052A

Place the NIS input to DEH - IN TEST (Graphic 5515):

1NY-NR8044B

Select - TEST

Verify red test light - ILLUMINATES

Verify point quality indicates - BAD EVALUATOR NOTE: The crew will not be required to Locally Bypass Bistables for this scenario. The cabinet will be locked and the key currently unavailable for the crew. This task may be handed to the WEC for execution, while the crew continues with the scenario. The bistables will not be bypassed during this scenario.

US

Direct WEC to dispatch personnel to trip bistables

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.8.9 Distribution Systems - Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION B, One AC instrument bus electrical power distribution subsystem inoperable.

o B.1

RA - Restore AC instrument bus electrical power distribution subsystem to OPERABLE status.

CT - 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 16

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 4__

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior EVALUATOR NOTE: Depending on how the candidates interpret the cue of all Instrument Inverters open, they may declare the inverter inoperable with the absence of more concrete testing and investigation. If they declare the inverter inoperable, the following step is required.

US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.8.7 Inverters - Operating (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION B, One instrument bus inverter inoperable.

o A.1

RA - Restore inverter to OPERABLE status.

CT - 7 days EVALUATOR NOTE: After personnel dispatched to trip bistables, and with lead examiners concurrence, continue with Event 5.

17

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior CUE

Annunciator

BAR 1-12-C1 PZR PRESS CONT DEV LOW HTRS ON

BAR 1-12-B4 PZR LEVEL CONT DEV LOW

Dropping PZR pressure

Dropping PZR level

Rising Charging Flow EVALUATOR NOTE: The crew may attempt to enter 1BOA PRI-1. This will delay the RX trip, but is not an error or required. Charging flow and PZR pressure should identify the size of the leak and be sufficient to direct a RX Trip.

Crew

Determine that leak size is too larger to maintain continued operation and will cause RX trip and Safety Injection.

US

Direct a manual reactor trip and Safety Injection. Direct operators perform immediate actions of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION ATC

Manually trips the reactor, verify RX trip, and actuates Safety Injection EVALUATOR NOTE: When the crew initiates the Safety Injection, the 1CV 112 valves fail to realign on the SI signal.

US

Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notify SM for procedure entry, EP evaluation ATC

Verify Reactor Trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux DROPPING BOP

Verify Turbine Trip

Turbine throttle valves - CLOSED

Turbine governor valves - CLOSED BOP

Verify power to 4KV busses

Bus 141 - ENERGIZED

Bus 142 - ENERGIZED 18

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior ATC

Check SI status

SI actuated

SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1)

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open)

Determine if SI required:

Check PZR pressure < 1829 psig

Check Steamline pressure < 640 psig

Check CNMT pressure > 3.4 psig

If SI is required:

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP-0 US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE: Crew actions of 1BEP-0 continue following NOTE.

BOP actions of 1BEP-0, Attachment B continue on page 23.

ATC

Verify AF system:

AF pumps - BOTH RUNNING

AF isolation valves 1AF13A-H - OPEN

AF flow control valves 1AF005A-H - THROTTLED

AF flow - GREATER THAN 500 GPM

Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE - MS022A & D indicated RED high alarm

Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER - 1A SG level is rising in an uncontrolled manner

Manually close 1AF013A, 1AF013E, 1AF005A, and 1AF005E 19

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior ATC

Check PZR PORVs and Spray Valves

PORVs - CLOSED

Check pressure less than 2315

PORV isol valve - at least one ENERGIZED

PORV relief path - at least one AVAILABLE

PORV in - AUTO

Isolation valve - open

Normal spray valves - CLOSED ATC

ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC

Check steam dumps - AVAILABLE

C-9 Permissive light - NOT LIT

CW Pump - AT LEAST ONE RUNNING ATC

Control RCS Temperature per table:

Adjust Feed Flow

Steam Release EVALUATOR NOTE: RCP Trip criteria dependent on RCS pressure when evaluated, it is anticipated to be above 1425 psig at this step.

ATC

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

High head flow 1FI-917 > 100 GPM and RCS Pressure > 1425 PSIG.

ATC

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

ATC

CHECK IF SG TUBES ARE INTACT:

SJAE/Gland Steam Exhaust Gas radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT 20

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior Crew

CHECK IF RCS IS INTACT:

CNMT area radiation monitors are less than ALERT Alarm setpoints:

Alert on 1RT-AR020/1RT-AR021

CNMT Pressure - less than 3.4 psig.

CNMT floor drain sump level less than 46 inches EVALUATOR NOTE: The crew actions of 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT begin following this note.

US

Implement 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation o Request STA to come to the control room EVALUATOR NOTE: RCP Trip criteria dependent on RCS pressure when evaluated, it is anticipated to be above 1425 psig at this step.

ATC

CHECK IF RCPS SHOULD BE STOPPED

All RCPs - ALL RUNNING.

ECCS flow:

High head SI flow (1FI-917) - GREATER THAN 100 GPM o RCS pressure - LESS THAN1425 PSIG o Manually trip RCPs CREW

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

ATC/BOP

Check intact SG level

Narrow range levels - greater than 10% (31% adverse CNMT)

Control feed flow to maintain narrow range levels between 10% (31%

adverse) and 50%

Crew

Check Secondary radiation normal

Reset CNMT Isol Phase A if necessary

Open all SG Blowdown Sample Isol valves

Direct Chemistry to sample all SGs for activity Crew

Check secondary radiation trends (PPC or Rad Monitoring System) - NORMAL FOR PLANT CONDITIONS

Secondary activity samples - NORMAL (WHEN AVAILABLE) 21

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior ATC

CHECK PZR PORVs AND ISOLATION VALVES:

PORV isol valves - ENERGIZED:

PORVs - CLOSED

PORV isol valves - AT LEAST ONE OPEN (1RY8000B will remain closed)

CREW

CHECK IF ECCS FLOW SHOULD BE REDUCED:

RCS subcooling - ACCEPTABLE

Secondary heat sink:

RCS pressure - STABLE OR RISING

PZR level - GREATER THAN 12% (28% ADVERSE CNMT)

SI Termination Criteria NOT satisfied CREW

CHECK IF CS Pumps SHOULD BE STOPPED

CS Pumps - ANY RUNNING - No CREW

CHECK IF RH Pumps SHOULD BE STOPPED

Reset SI, as necessary

Check RCS Pressure

RCS Pressure > 325 psig

Pressure Stable or rising

Any running RH Pump with suction aligned to the RWST

Stop RH pumps and place in Standby EVALUATOR NOTE: The scenario can be terminated after RH pumps are placed in Standby per 1BEP-1 Step F.8, provided all critical steps are complete.

22

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

EVALUATOR NOTE: The following two critical tasks may have been completed prior to these steps in the procedure by Operator Action per OP-AA-103-102-1001 STRATEGIES FOR SUCCESSFUL TRANSIENT MITIGATION. They will be verified at this step in the procedure.

BOP Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps - BOTH RUNNING

RH pumps - BOTH RUNNING CT-7

[CT]

SI pumps - BOTH RUNNING - No

Start 1B SI Pump BOP Attachment B action VERIFY ECCS VALVE ALIGNMENT

Group 2 Cold Leg Injection monitor lights required for ECCS valve alignment -

CT-15

[CT] LIT - no

Open 1CV112D and / or 1CV112E

When associated interlock valve is full open - close 1CV112B and / or 1CV112C EVALUATOR NOTE: RCS pressure is dependent on when evaluated, it is anticipated to be above 1700 psig at this step.

BOP Attachment B action VERIFY ECCS FLOW

HHSI flow >100 gpm

RCS pressure NOT <1700 psig 23

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights - LIT Verify CNMT isolation Phase A

Group 3 CNMT isolation monitor lights - LIT Verify CNMT Ventilation isolation

Group 6 CNMT Vent Isol monitor lights - LIT Verify CC Pumps

CC pumps - BOTH RUNNING Verify SX Pumps running

SX pumps - BOTH RUNNING Check If Main Steamline Isolation Is Required o Check SG pressure < 640 psig o Check CNMT pressure > 8.2 psig

If either condition is met, then verify MSIVs and MSIV Bypass valves closed

Check if CS is required (NOT required)

BOP Attachment B action VERIFY FW ISOLATED

FW pumps tripped

FW isolation monitor lights lit

FW pumps discharge valves closed 1FW002A-C

Trip all running HD pumps BOP Attachment B action VERIFY BOTH DGS RUNNING:

DGs - BOTH RUNNING

SX valves open 1SX169A and B

Dispatch operator locally to check operation BOP Attachment B action VERIFY GENERATOR TRIP

Unit 1 Main Transformer output breakers - OPEN:

GCB 3-4

OCB 4-5

Excitation red Off light Is LIT 24

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY CONTROL ROOM VENTILATION ALIGNED FOR EMERGENCY OPERATIONS:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints

Operating VC train equipment running Train A

Supply fan 0A

Return fan 0A

M/U fan 0A

Chilled water pump 0A

MCR chiller 0A

Operating VC train dampers

M/U fan outlet damper NOT full closed 0VC24Y

VC train M/U filter light LIT

Operating VC train Charcoal Absorber aligned for train A

0VC43Y closed

0VC21Y open

0VC22Y open

Operating VC train M/U filter alignment

0VC25Y open

0VC312Y closed

Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED

Two inaccessible filter plenums aligned

Plenum A fan 0VA03CB running

Damper 0VA023Y not fully closed

Damper 0VA436Y closed

Plenum C fan 0VA03CF running

Damper 0VA072Y not fully closed

Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans

One Exhaust Fan running for every Supply Fan running BOP Attachment B action VERIFY FHB VENTILATION ALIGNED

Train B fan 0VA04CB running

0VA055Y open

0VA062Y not fully closed

0VA435Y closed 25

Op-Test No.: 2021-301 _ Scenario No.: _N21-3_ Event No.: _ 5 & 6__

Event

Description:

SB LOCA and 1CV112 valves fail to swapover Time Position Applicants Actions or Behavior BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling

Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of

Manual actions taken

Failed equipment status

Attachment B completed CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN EVALUATOR NOTE: The crew actions for of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, continue on page 18.

The crew actions for of 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT, begin on page 21.

26

1BGP 100-3T1 Revision 31 Page 1 of 4 POWER ASCENSION FLOWCHART Continuous Use DATE Today 1BGP 100-3 Flowchart File Location: 1.02.0133 TIME T - 2hours (Byron / Braidwood Commonality Reviewed)

ENTER SM EGC Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to the step listed in the resolve prior to step column, if applicable.

CCR PREREQUISITES Initial each RO SRO D CR PRECAUTIONS LIMITATIONS E CR FWIV CR AND ACTIONS 17 ES HD CR MODE 2-1 6 26 SM SMP 1 PERM PDMS 5% 12% P10 P7 STM DUMP DEMAND SYNC TGTMS SMP 8A CR 8B CR8C 9 10 11 20 27 29 a RTC CR5 TURB NOTIFY LATCH ETS OPC 520 1700 1775 TRIP 1800 TURB GEN NOTIFY SET PED TURB OVSPD OVSPD RPM RPM RPM TEST RPM PREP PREP TSO & PJM VPL SMP 2 3CR CR4 CR 70 CR 71 CR 7 CR14 CR 15 CR 18 19 CR 21 CR 23 24 30 FLOW S/G LEVEL FW Pp CHART CR 12 CR 16 SWITCHYARD CORE STM DUMPS PREP MON SJAE CR 13 CR 22 28 c CR 31 SD CR 25 GS b CR 32

1BGP 100-3T1 Revision 31 Page 2 of 4 POWER ASCENSION FLOWCHART Continuous Use 1BGP 100-3T1 Flowchart Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to the step listed in the resolve prior to step column, if applicable.

TURB Initial each FW PP FW VLVS FW FW PP SEQ RO SRO 10% 20% RECIRC AUTO ~20% L/U AUTO VLV >20%

33 72 38 40 41 42 44 STATUS P-8 &C-20 LIGHTS >25% >30% RTC 39 47 49 51 CALORIMETRIC 50%

a & C-15 >15% 30% 50% CALOR 45 55 a

62 AFD <50%

STM DUMPS ELEC LINEUP 56 QPTR 34 43 <50%

P-13 TURB 57 DRAINS >20% MOTOR FW PP DNBR 37 FW PP DRAINS HD <50%

46 RECIRC CD/CB FW ALIGN >40% PP H2 TEMP 58 50 52 54 60 53 35 H2 TEMP GC TEMP AS b

SEAL OIL 48 59 61 36 NIS PWR b LOOP c

c 73

1BGP 100-3T1 Revision 31 Page 3 of 4 POWER ASCENSION FLOWCHART Continuous Use 1BGP 100-3T1 Flowchart Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to GS the step listed in the resolve prior to step column, if applicable.

ADJ Initial each 63 RO SRO MDFWP 90% 100% 1BGP 100-3 90% Auto Start CALOR 100% CALOR COMPLETE DATE EXIT a 64 65 66 67 68 69 TIME SM b

c

1BGP 100-3T1 Revision 31 Page 4 of 4 Continuous Use 1BGP 100-3T1 FLOWCHART EXCEPTION SHEET RESOLVE EXCEPTION EXCEPTED TIME AND SM DESCRIPTION OF REASON FOR PRIOR TO TIME AND SM NUMBER STEP DATE INIT EXCEPTION STEP # DESCRIPTION OF RESOLUTION DATE INIT Page of ____

Facility: _Byron Nuclear Station__ Scenario No.: ___4___ Op-Test No.: _2021-301_

Examiners: __________________________ Operators: _____________________________

Initial Conditions: 49% RTP, EOL, Xenon burning out Turnover: A partial performance of 1BOSR 0.5-2.AF.1-2 UNIT ONE TRAIN B AUXILIARY FEEDWATER VALVES STROKE TEST is required to ensure surveillance compliance.

Ramp to 100% to commence after surveillance test.

1A FW pump is OOS. Expected RTS in 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months .

Event Malf. No. Event Event No. Type* Description 1 None N - BOP Partial 1BOSR 0.5-2.AF.1-2 Unit One Train B Auxiliary Feedwater N - SRO Valves Stroke Test 2 None R- ATC Normal ramp R- BOP R -SRO 3 RD02M04 C - ATC Dropped rod C - SRO TS - SRO 4 CH03D C - BOP 1D CRDM Exhaust Fan trips (NRC Exam 19-1)

C - SRO 5 FW157 Pre C - BOP 1B CD/CB trip / Stby pump fails to auto start FW22B C - SRO 6 CV10SLIM13S C - ATC 1CV121 fails closed pDecPB C - SRO 7 RX22B TS - SRO PZR Press Channel 458 fails low 8 RP24A M - ALL Spurious Safety Injection [CT]

9 CC04A C - ALL LOCA Outside CNMT - CA 1.2 [CT] (NRC Exam 19-2)

RH01B

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1

Critical Tasks:

1. CT-32: Isolate the LOCA outside containment prior to transitioning out of 1BCA 1.2 LOCA OUTSIDE OF CONTAINMENT (K/A Number - EPE 04 EA1.3, Importance - 3.8/4.0)

a. Safety Significance: Failure to isolate a LOCA outside containment (that can be isolated) degrades containment integrity beyond the level of degradation irreparably introduced by the postulated conditions.

Failure to perform the critical task eventually leads to degraded ECCS capacity because the LOCA outside containment depletes the RWST inventory without causing a corresponding increase in the containment sump inventory. Thus, failure to isolate the LOCA can result in a situation in which all ECCS pumps taking suction on the RWST must be stopped because the RWST is empty and emergency coolant recirculation is unavailable.

b. Cues: Indications of a Safety Injection is required due to RCS pressure AND indication of abnormally high radiation in the auxiliary building.

c. Performance Indicator: Manipulations of control switches to the isolate the LOCA by closing valves near the leak.

d. Feedback: RCS pressure starts increasing after closing valves.

1. CT-16: Trip RCPs, when RCP trip criteria are met (RCS pressure <1425 psig and high head SI flow >100 gpm or SI pump discharge flow >200 gpm), prior to exiting out of 1BEP-1. (K/A Number - EPE009 EK3.23, Importance -

4.2/4.3)

a. Safety Significance: Failure to trip the RCPs under the postulated plant conditions leads to core uncovery and to fuel cladding temperatures in excess of 2200°F, which is the limit specified in the ECCS acceptance criteria. Thus, failure to perform the task represents misoperation or incorrect crew performance in which the crew has failed to prevent degradation of...{the fuel cladding} ...barrier to fission product release and which leads to violation of the facility license condition.

b. Cues: Indications of a SBLOCA, Safety Injection, only one SI pump running, and RCP trip criteria of RCS pressure <1425 psig and high head SI flow >100 gpm or SI pump discharge flow >200 gpm).

c. Performance Indicator: Manual trip all RCPs.

d. Feedback: Indication that all RCPs are stopped (RCP breaker position, RCP flow decreasing).

2

21-1 NRC SCENARIO 4 OVERVIEW The scenario will start at approximately 49% RTP, EOL, xenon burning out. A partial performance of 1BOSR 0.5-2.AF.1-2 UNIT ONE TRAIN B AUXILIARY FEEDWATER VALVES STROKE TEST is required to ensure surveillance compliance.

Ramp to 100% to commence after surveillance test. 1A FW pump is OOS for an oil change.

Event 1 The crew will perform a partial surveillance of 1BOSR 0.5-2.AF.1-2 Unit One Train B Auxiliary Feedwater Valves Stroke Test for 1AF013H only. When the crew has completed the surveillance, continue to Event 2.

Event 2 The crew will commence ramp up to 100%. After sufficient observation of ramp activities, and RX power is greater than 50%, the lead examiner will direct continuation to Event 3.

Event 3 During the ramp up, after passing 50% RX power, CBD rod D12 will drop. The crew will identify the failure and respond to the failure with 1BOA ROD-3 DROPPED OR MISALIGNED ROD UNIT 1. The crew will take rods to MANUAL and stop the ramp. The crew will enter Tech Spec 3.1.4 Condition B. Once the crew has dispatched personnel to check fuses and the SRO has evaluated Tech Specs, at the lead examiners discretion, continue to Event 4.

Event 4 The 1D Control Rod Drive Mechanism fan will trip. The crew will identify the failure and respond per BAR 0-33-A5 CRDM EXH FAN TRIP. The crew will start an additional CRDM fan per BOP VP-9. After the fan is started, at lead examiners discretion, continue to Event 5.

Event 5 1B CD/CB pump will trip on overcurrent and the Stby pump, 1D CD/CB pump, will not auto start. The crew will identify the tripped pump and manually start the 1D CD/CB pump per BHC 1-17-A9 CD/CB PUMP TRIP. This will restore adequate NPSH for the Feedwater pumps and stabilize the secondary system. The crew will enter 1BOA SEC-1 SECONDARY PUMP TRIP UNIT 1. Once 1BOA SEC-1 is complete, at the lead examiner discretion, continue with Event 6.

Event 6 1CV121 fails low to 52 GPM. The crew will identify the failure and respond to BAR 1-9-A1 REGEN HX LTDWN TEMP HIGH and 1BOA PRI-15 CVCS ABNORMALITIES. The crew will take manual control of 1CV121 and restore normal charging and letdown. Once the actions to restore charging flow are complete, at lead examiners discretion, continue to Event 7.

Event 7 PZR Pressure channel 458 will fail low. The crew will identify the failure and respond per 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL UNIT 1 Attachment B. The crew will verify no changes to the RCS and bypass/remove the channel in Ovation. The crew will enter Tech Specs 3.3.1 Conditions A, E, and K and 3.3.2 Conditions A and D. After the Tech Spec assessment is complete, at lead examiners discretion, continue to Events 8 and 9.

Event 8 and 9 A spurious Safety Injection will occur. The RX will auto trip. The crew will implement 1BEP-0 REACTOR TRIP OR SI.

1B RH pump will trip, discharge check valve will fail to fully close, and 1B RH HX will develop a leak on actuation of the SI causing a LOCA outside of containment. The crew will transition from 1BEP-0 to 1BCA-1.2 LOCA OUTSIDE CONTAINMENT UNIT 1.

The 1500 GPM leak develops in the 1B RH HX bypass line just upstream of 1RH619.

The scenario can terminate after isolation of the leak. The crew will note an RCS pressure rise when 1SI8809B is closed and will isolate the LOCA outside CNMT.

3

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Appendix A, Simulator Ready for Training Checklist.

Establish the conditions of IC 143, 49% power, EOL, 200 ppm boron, equilibrium xenon (IC 160 with change to plant configuration)

Place Simulator in RUN

Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N21-4 Scenario.ssf o Click on the MODE button (near top of screen) and pick EXECUTE o Click on the PLAY button (bottom left of screen) o Verify Simulator Setup conditions automatically load o ZDI1FW01PA - 1A FW Pump PTL

ENSURE the following are included in the smart scenario:

4

Ensure the following equipment is aligned

1D CD/CB Pump in STBY

1A CV pump is running

1A FW pump is OOS

1VP03CB and 1VP03CD fans are running

Place the following control switches in PTL:

1A FW Pump

1A FW Pump AOP

Place clearance order INFO/CAUTION tags on the following COMPONENTS:

1A FW Pump

1A FW Pump AOP

1FW002A 1A FW Pump Discharge valve

1FW012A 1A FW Pump Recirculation valve

Place Protected Equipment placards on the following control switches:

1B FW pump

1C FW pump

Set Boric Acid Flow Controller 1FK-0110 to 3.4 gpm (200 ppm boron).

Ensure EOL REMA is available at the Unit Desk

Provide copies of the following documents:

o 1BOSR 0.5-2.AF.1-2 UNIT ONE TRAIN B AUXILIARY FEEDWATER VALVES STROKE TEST 5

Turnover Information

Reactor Status:

o 49% RTP, o EOL o Xenon stable o CBD - 80 steps o 200 ppm Boron.

The last 10 minute calorimetric/NIS Power Range gain check/adjustment was performed at the end of the previous shift.

1BOSR 2.3.1-1 AXIAL FLUX DIFFERENCE WEEKLY SURVEILLANCE is in frequency.

NF-AP-550-3.2.0.7 WEEKLY FQ, FNH AND DNBR TECHNICAL SPECIFICATION SURVEILLANCE USING PDMS is in frequency for DNBR.

1A FW pump is OOS for an oil change. Expected RTS in 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months .

1BGP 100-3 in progress. Currently at Step 61, reference 1BGP 100-3T1.

Online Risk is GREEN.

Protected Equipment:

Unit 1 FC Train

1B FW Pump

1C FW Pump

Planned activities:

o Partial 1BOSR 0.5-2.AF.1-2 UNIT ONE TRAIN B AUXILIARY FEEDWATER VALVES STROKE TEST for 1AF013H Auxiliary Feedwater Isolation Valve.

o Commence ramp up to 100%.

6

INSTRUCTOR/SIMULATOR RUN AID GUIDE EO response time will occur per Byron Station Simulator guidelines.

TB - 2 minutes AB - 3 minutes AEER - 1 minute Event 1, Partial 1BOSR 0.5-2.AF.1-2 Unit One Train B Auxiliary Feedwater Valves Stroke Test As Shift Manager, acknowledge commencement and completion of procedure.

Event 2, Normal ramp As Shift Manager, acknowledge the initiation of ramp (if required).

As Generation Dispatch, acknowledge initiation of ramp.

As Reactor Engineer:

Tech Spec Surveillance Requirements for LCOs 3.2.1 and 3.2.2 are satisfied.

AFD calibrations are complete for all four power range channels per Tech Spec Surveillance Requirement SR 3.3.1.6.

The high flux trip setpoint has been raised to 109% on all four power range channels.

Event 3, Dropped rod At Lead Evaluators cue, use Smart Scenario to drop CBD Rod D12 by right clicking on the box titled Event 3, CBD Rod D12 Drop and select, Release.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations.

As RE, acknowledge dropped rod and reactor data.

As EO, acknowledge order to check for blown fuses and report stationary grippers fuses are blown for Rod D12.

Event 4, 1D CRDM Exhaust Fan trips.

At Lead Evaluators cue, use Smart Scenario to trip 1D Control Rod Drive Mechanism Fan by right clicking on the box titled, Event 4, CRDM Fan Trip and select, Release.

As Shift Manager, acknowledge the failure and requests for on line risk assessment, maintenance support, and IR initiation.

As EO, report thermals have tripped on CRDM Exhaust Fan 1D breaker (MCC133X6 cubicle C4).

As QNE, acknowledge CRDM Exhaust Fans are being swapped.

Event 5, 1B CD/CB Pump At Lead Evaluators cue, use Smart Scenario to trip the 1B CD/CB Pump by right clicking on the box titled, Event 5, 1B CD/CB pump, and select, Release.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BOA SEC-1.

When dispatched as an EO to check on 1B CD/CB pump or breaker, o report that there is a significant amount of water spraying onto the motor from gland water o report the breaker of the 1B CD/CB pump is open with an overcurrent flag showing If requested, yes the EO can isolate the gland water to the pump and stop the spraying water.

As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

7

Event 6, 1CV121 failure At Lead Evaluators cue, use Smart Scenario to fail 1CV121 by right clicking on the box titled, Event 6, 1CV121 failure, and select, Release.

As EO, there is nothing apparently wrong with CV flow control valve 1CV-121 locally.

As Shift Manager, acknowledge the failure and requests for on line risk assessment, maintenance support, and IR initiation.

Event 7, PZR Press Channel 458 failure At Lead Evaluators cue, use Smart Scenario to fail PZR Pressure Channel 458 by right clicking on the box titled, Event 7, PZR Press Channel 458 failure, and select, Release.

As Shift Manager, acknowledge procedural entry and evaluate for Emergency Plan conditions.

As Shift Manager, acknowledge requirement to bypass/trip bistable. If asked, direct to bypass bistable.

As the WEC, respond to request for tripping bistables and inform US that extra NSOs will be assembled and briefed.

As Shift Manager, acknowledge entry into TS 3.3.1.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Events 8 & 9, Spurious SI and LOCA Outside CNMT At Lead Evaluators cue, use Smart Scenario to fail PZR Pressure Channel 458 by right clicking on the box titled, Event 8, Spurious SI and LOCA Outside CNMT, and select, Release.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BEP-0.

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BCA 1.2.

As EO, if sent to investigate or 5 minutes after the RH leak is active, report the 1B RH discharge header has ruptured between 1RH0607 and 1RH8716B. Hot water and steam are spraying out.

As EO, if sent to investigate after the 1SI8809B is closed, report the leak has stopped.

8

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 1__

Event

Description:

Partial surveillance of 1BOSR 0.5-2.AF.1-2 Unit One Train B Auxiliary Feedwater Valves Stroke Test Time Position Applicants Actions or Behavior CUES From turnover, a partial performance of 1BOSR 0.5-2.AF.1-2 UNIT ONE TRAIN B AUXILIARY FEEDWATER VALVES STROKE TEST is required to ensure surveillance compliance.

US Direct BOP to perform 1BOSR 0.5-2.AF.1-2 Unit One Train B Auxiliary Feedwater Valves Stroke Test for 1AF013H only BOP

Refer to 1BOSR 0.5-2.AF.1-2. Determine step F.2.4 applies.

Record OPEN for 1AF013H, 1B AF Pp Dsch Hdr to 1D S/G Isol Vlv, at 1PM06J.

EXERCISE 1AF013H, 1B AF Pp Dsch Hdr to 1D S/G Isol Vlv, at 1PM06J, by performing a full cycle of the valve and circling the result.

RETURN 1AF013H, 1B AF Pp Dsch Hdr to 1D S/G Isol Vlv, to its "As Found" condition or as directed by the Shift Manager or designated SRO licensed assistant, at 1PM06J.

ATC

Monitor the unit.

EVALUATOR NOTE: After completion of 1BOSR 0.5-2.AF.1-2, and with lead examiners concurrence, proceed with the next event.

9

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 2__

Event

Description:

Ramp up to 100%

Time Position Applicants Actions or Behavior CUES From turnover, commence ramp up to 100%

US

Direct Power ascension per turnover.

Implement actions of 1BGP 100-3, POWER ASCENSION to raise power to 100%

per step F.64.

Perform pre-job brief per OP-BY-101-0001 ATTACHMENT 9 REACTIVITY CHANGE BRIEF SHEET for load ramp.

Direct power ascension per the requirements of NF-AP-440 PWR FUEL CONDITIONING.

ATC

Verify rod position and boron concentration.

Conducts reactivity brief

Initiate dilution IAW ReMA and BOP CV-5 OPERATION OF THE REACTOR MAKEUP SYSTEMIN THE DILUTE AND ALTERNATE DILUTE MODE or BOP CV-5T1 RMCS OPERATION IN DILUTE / ALT DILUTE CHECKLIST

Place MU MODE CONT SWITCH to STOP position

Set MU MODE SELECT to DIL or ALT DIL

Set 1FK-111 PW/Total Flow Control Setpoint to desired flowrate

Verify 1FK0111 PW to Boric Acid Blender controller to the value corresponding to the desired flowrate and verify in AUTO

Enter gallons into PW/Makeup Totalizer on OWS graphic (6003)

Verify totalizer reset

Verify 1CV111A, 1CV111B, and 1CV110B in AUTO

Place RMCS Makeup Control Switch to START

Verify 1CV111A and B OPEN

Verify 1CV110B OPEN if in ALT DIL

Verify proper PW flow on flow recorder 1CD-CX4102

Monitors effects of dilution o Turn on PZR backup heaters.

10

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 2__

Event

Description:

Ramp up to 100%

Time Position Applicants Actions or Behavior BOP

Raise turbine load at 1PM02J or OWS drop 210 by performing the following:

Select SETPOINT.

Enter ~1.6 MW/min into the RATE window.

Select ENTER.

Enter 1120 MW into REF DEMAND window.

Select ENTER.

Select EXIT.

Notify US and RO of pending ramp.

Select GO/HOLD.

Verify GO/HOLD button illuminates.

Verify HOLD illuminated RED.

Select GO.

Verify GO illuminates RED.

Verify main turbine load begins to rise.

Verify Gland Steam alignment and operation.

ATC

Monitor reactor power and load ascension:

Monitor NIs, Tave, I, Pzr press/level.

During dilution, monitor the following at 1PM05J and HMI:

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow counter responding correctly.

Verify dilution auto stops at preset value.

o Return Reactor Makeup System to automatic.

Withdraw control rods per ReMA.

EVALUATOR NOTE: After measurable change in power, and > 50%, with lead examiners concurrence, initiate the Event 3.

11

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 3__

Event

Description:

CBD rod D12 drop Time Position Applicants Actions or Behavior CUES Annunciator

1-10-C4 PWR RNG CHANNEL DEV

1-10-E6 ROD AT BOTTON

Tave dropping

Rods stepping out ATC

Take action per hard card BHC1-RD

Check Turbine Power Stable - yes

Check Rod Control in manual

Place Rod Control in Manual - rod motion will stop US

Enter and direct 1BOA ROD-3, DROPPED OR MISALIGNED ROD UNIT 1.

Place rod control in - MANUAL.

ATC

Stop unnecessary boration or dilution.

BOP

Stop turbine load changes. Place DEH in HOLD.

ATC

Check DRPI not failed.

Check Rx power > 5%.

Check DRPI rod bottom light lit AND Tave dropping.

Check only one DRPI rod bottom light lit - only one rod dropped

Check Tave > 550°F.

Maintain Tave and Tref within 3°F by adjusting turbine load and/or by raising boron concentration.

Check all quadrants less than 100% - NIS and Delta T

Check alarm 1-10-C3 PWR RNG FLUX RATE RX TRIP ALERT alarm clear.

US

Complete Attachment A by recording data and report to a qualified Nuclear Engineer.

o Nature of the failure o Time failure identified o Time rods last moved o Current reactor power level o Rod failed o Position of the failed rod o Position of bank containing the failed rod

Check I - WITHIN LIMITS.

ATC

Check PDMS - OPERABLE.

Check PDMS LIMIT EXCEEDED alarm (1-10-D7) - NOT LIT.

12

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 3__

Event

Description:

CBD rod D12 drop Time Position Applicants Actions or Behavior

Check if DRPI indicates affected rod - MISALIGNED GREATER THAN 12 STEPS

- yes.

Perform 1BOSR 1.1.1-1 SHUTDOWN MARGIN SURVEILLANCE within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

ATC

Check Reactor Power less than 70%.

Check duration of rod misalignment GREATER than 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months - no.

Check reactor power less than 50% reactor power - no Crew

Check affected rod(s) for blown fuse(s) - yes, stationary grippers fuses are blown US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.1.4 Rod Group Alignment Limits (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION B, One rod not within alignment limit.

o B.1.1

RA - Verify SDM is within the limits specified within the COLR.

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

OR o B.1.2

RA - Initiate boration to restore SDM within limit.

CT - 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

o B.2

RA - Reduce THERMAL POWER to < 75%RTP.

CT - 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months from discovery of Condition B concurrent with inoperability of Power Distribution Monitoring System (PDMS)

3.5.2 ECCS - Operating, Condition B within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months o B.3

RA - Very SDM is within limits specified in the COLR.

CT - Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months o B.4

RA - Determine Heat Flux Hot Channel Factor (FQ(Z)) and Nuclear Enthalpy Rise Hot Channel Factor (FNH).

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

o B.5

RA - Reevaluate safety analyses and confirm results remain valid for duration of operation under these conditions.

CT - 5 days.

EVALUATOR NOTE: Once the crew has dispatched personnel to check fuses and the SRO has evaluated Tech Specs, at the lead examiners discretion, continue to Event 4.

13

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 4__

Event

Description:

1D Control Rod Drive Mechanism fan trip Time Position Applicants Actions or Behavior CUES Annunciator

0-33-A5, CRDM EXH FAN TRIP

0-33-B5, CRDM EXH FLOW LOW

Amber light lit on CRDM Exhaust Fan 1D.

EVALUATOR NOTE: BOP VP-9 states that the fans are preferred to be run in specific pairs, but not required. The candidates will start a second fan, as two fans are required to be running for plant conditions, and may swap the other fans to achieve the preferred line up.

The preferred line up is as follows:

1VP03CA with 1VP03CC and 1VP03CB and 1VP03CD.

This not required to successfully complete the task.

BOP

Take action per the BAR

Start another CRDM Exhaust Fan per BOP VP-9.

Notify Unit QNE CRDM Exhaust fans will be swapped (Prerequisite C.1)

PLACE one of the following Control Switches to the AFTER START position:

1VP03CB, Cont Rod Drive Mech Exh Fan 1B.

1VP03CC, Cont Rod Drive Mech Exh Fan 1C.

US

Direct BOP to respond to panel 0-33 alarms.

Notify Shift Manager of status.

EVALUATOR NOTE: After the fan is started, and with lead examiners concurrence, initiate the Event 5.

14

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 5__

Event

Description:

1B CD/CB trip / Stby pump fails to auto start Time Position Applicants Actions or Behavior Annunciator

1-17-A9 CD/CB PUMP TRIP

1-17-B11 CB PUMP DSCH FLOW HIGH

1-17-D3 HD PUMP DSCH FLOW HIGH CUE

1-17-D10 CD/CB PUMP LUBE OIL PP AUTO START

1-17-E2 HD PUMP GLND WTR INLET PRESS HIGH LOW

1-17-E9 CB PUMP GLND WTR INLET PRESS HIGH LOW

1-16-E1 FEEDWATER NPSH LOW

1B CD/CB pump disagreement light

Refer to BHC 1-17-A9 CD/CB PUMP TRIP

Start aux oil pump for the Standby 1D CD/CB pump BOP

Start the standby 1D CD/CB pump

Close the 1B CD/CB Pump recirc valve 1CB113B US

Direct entry into 1BOA SEC-1 SECONDARY PUMP TRIP UNIT 1 Attachment C

Check Turbine load - greater than 700 MWe

Check CD/CB flow restored

Standby Cd/CB pump running - no

Start the aux lube oil power for the standby pump

Start the standby Cd/CB pump

At least three CD/CB pumps running

Check FW flow - greater than or equal to steam flow BOP

Check FW pumps not cavitating

Close recirc valve on tripped pump - 1CB113B

FW pump discharge flows oscillating - no

Check CD/CB flow restored

Check alarms not lit

1-17-B11 CB PUMP DSCH FLOW HIGH

1-16-E1 FEEDWATER NPSH LOW

Check Plant Status

Delta I within limits

PDMS - OPERABLE

Check 1-10-E8 -PDMS INOPERABLE - not lit ATC

Check 1-10-D7 PDMS LIMIT EXCEEDED

Control Delta I within limit

ROD BANK LOW INSERTION LIMIT - not lit

Turbine Runback not lit

Restore plant conditions 15

EVALUATOR NOTE: When Secondary systems have been stabilized after the loss of 1B CD/CB Pump, and with lead examiners concurrence, continue with the Event 6.

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 6__

Event

Description:

1CV121 fails closed Time Position Applicants Actions or Behavior CUES Annunciator

1-10-E4 Ovation Trouble annunciator.

1-9-D3 CHG LINE FLOW HI-LOW annunciator.

Charging flow ~ 25 gpm.

Pressurizer level master controller shifts to manual.

ATC/US

Take action per the BAR

Determine the first 8 actions do not apply.

Check output of Master PZR Level Controller 1LK-459. Determine controller is in MANUAL.

Place 1FK-121 in MANUAL.

Restore charging flow to normal.

US

Establish and Assign control band for pressurizer level o Evaluate Tech Spec implications (none)

Notify Shift manager of failure and actions BOP

Respond per BAR 1-10-E4 Ovation Trouble.

Refer to Ovation alarm page.

Determine RY-PZRLVMM-MAN is applicable.

Refer to BOP CX-21 and determine no action is listed for the alarm.

If letdown is isolated, restore letdown per 1BOA ESP-2.

EVALUATOR NOTE: Once the actions to restore charging flow are complete, and with lead examiners concurrence, continue with the Event 7.

16

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 7__

Event

Description:

PZR Press Channel 458 fails low Time Position Applicants Actions or Behavior CUES Annunciator

1-12-A1 PZR PRESS LOW RX TRIP STPT ALERT

1-12-B1 PZR PRESS LOW

Pzr press indicator 1PI-458 downscale.

US

Direct entry into 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL UNIT 1 Attachment B

Notify SM to perform on line risk assessment, request maintenance support, and generate IR requests ATC

Perform 1BOA INST-2 Attachment B.

Check Pzr pressure normal.

Check PORVs closed.

Check Pzr spray valves normal.

Remove the failed Pzr press channel from service.

Select PRESSURIZER PRESSURE in the SIGNAL SELECTORS box Select the PRESSURIZER PRESSURE MASTER graphic (7105) header to enable the window Select PLACE OUT OF SERVICE for 1PT-458 Exit window Select OWS graphic REACTOR TEMPERATURE CONTROL (6020)

Select OT DELTA-T in the SIGNAL SELECTORS box Select the Ovation graphic OT DELTA T SETPOINT (7100) header to enable the window Select PLACE OUT OF SERVICE for 1PT-458.

Exit window

Check Pzr pressure control in AUTO.

PZR PORVs 1RY455A and 1RY456

PZR Spray Valves 1RY455B and 1RY455C

Master PZR pressure controller

Check P11 interlock.

Select an operable Pzr pressure channel to the T recorder.

ATC

Report failed Pzr pressure instrument.

Refer to BARs 1-12-A1 and B1.

17

US

Identify Bistables required to be bypassed

PB458A

PB458C

PB458D

TB441C

TB441D

Contact WEC Supervisor to dispatch/brief personnel to bypass bistable US (RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.3.1 Reactor Trip Instrumentation (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One or more Functions with one or more required channels or trains inoperable.

o A.1

RA - Enter the Condition referenced in Table 3.3.1-1 for the channel(s) or trains inoperable (Function 8).

CT - Immediately

CONDITION E, One channel inoperable.

o E.1

RA - Place channel in trip.

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

CONDITION K, One channel inoperable.

o K.1

RA - Place channel in trip.

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs

LCO 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME

CONDITION A, One or more Functions with one or more required channels or trains inoperable.

o A.1

RA - Enter the Condition referenced in Table 3.3.2-1 for the channel(s) or trains inoperable (Function 1.d).

CT - Immediately

CONDITION E, One channel inoperable.

o D1

RA - Place channel in trip.

CT - 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EVALUATOR NOTE: After the US determines the Tech Spec requirements, and with the lead examiners concurrence, initiate the Event 8 & 9.

18

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event

Description:

Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior Annunciator:

CUES

SI Actuated Bypass/Permissive light.

A train SI equipment running.

US

Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notify SM for procedure entry, EP evaluation

Request STA to come to the control room ATC

Verify Reactor Trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux DROPPING BOP

Verify Turbine Trip

Turbine throttle valves - CLOSED

Turbine governor valves - CLOSED BOP

Verify power to 4KV busses

Bus 141 - ENERGIZED

Bus 142 - ENERGIZED ATC

Check SI status

SI actuated

SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1)

SI ACTUATED lit (1-BP-4.1) - Yes

SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open) - Yes

Actuate SI from both SI switches (1PM05J and 1PM06J) and continue in 1BEP Yes US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE: BOP actions of 1BEP-0, Attachment B continue on page 24.

ATC

Verify AF system:

AF pumps - BOTH RUNNING

AF isolation valves 1AF13A-H Steam Generator Auxiliary Feedwater Isolation Valve- OPEN

AF flow control valves 1AF005A-H Auxiliary Feedwater Regulating Valves -

THROTTLED

AF flow - GREATER THAN 500 GPM

Check SG tubes intact:

Secondary radiation level - NORMAL AND STABLE

Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER 19

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event

Description:

Spurious Safety Injection with auto RX trip, LOCA Outside Containment ATC

Check PZR PORVs and Spray Valves

PORVs - CLOSED

PORV isol valve - at least one ENERGIZED

PORV relief path - at least one AVAILABLE

PORV in - AUTO

Isolation valve - open

Normal spray valves - CLOSED ATC

ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC

Check steam dumps - AVAILABLE

C-9 Permissive light - NOT LIT

CW Pump - AT LEAST ONE RUNNING ATC

Control RCS Temperature per table:

Adjust Feed Flow

Steam Release EVALUATOR NOTE: It is possible the procedural path and timing may meet the conditions to trip RCPs, however it is not expected to meet the conditions to trip RCPs at this time.

The crew has 10 minutes to trip RCPs once trip criteria is reached.

ATC

Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

[CT]

High head flow 1FI-917 > 100 GPM and RCS Pressure < 1425 PSIG.

Trip all RCPs CT-16

Time trip criteria is reached: __________

Time RCPs are tripped: __________

ATC

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

ATC

CHECK IF SG TUBES ARE INTACT:

SJAE/Gland Steam Exhaust Gas radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

ATC

CHECK IF RCS IS INTACT:

CNMT Area radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

CNMT pressure less than 3.4 psig

CNMT Floor drain sump level less than 46 inches 20

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event

Description:

Spurious Safety Injection with auto RX trip, LOCA Outside Containment ATC

CHECK IF ECCS FLOW SHOULD BE REDUCED:

RCS Subcooling - acceptable

Secondary heat sink

Total feed flow greater than 500 gpm or Narrow range level in at least one SG is greater than 10%

RCS pressure stable or rising - no

PZR level greater than12%

US

Initiate monitoring of Critical Safety Function Status Trees ATC

CHECK SG LEVELS

Narrow range levels greater than 10%

Control feed flow to maintain narrow range levels between 10% and 50%

ATC

RESET SI

Depress both SI reset pushbuttons

Verify SI ACTUATED permissive light goes out

Verify AUTO SI BLOCKED permissive light is LIT ATC

RESET CONTAINMENT ISOLATION

Phase A

Phase B - not required ATC

ESTABLISH INSTRUMENT AIR TO CONTAINMENT

Check SACs - any running

Open instrument air supply valves to CNMT: 1IA065 and 1IA66 ATC

CHECK IF RH PUMPS SHOULD BE STOPPED

RCS pressure greater than 325 psig

RCS pressure stable or rising

Stop both RH pumps and place in Stby ATC

CHECK SECONDARY RADIATION NORMAL

Sample all SGs for activity

Check secondary radiation trends normal for plant conditions

SJAE/Gland Steam Exhaust Gas radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT.

21

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event

Description:

Spurious Safety Injection with auto RX trip, LOCA Outside Containment ATC

CHECK AUXILIARY BUILDING RADIATION

Unit 1 Aux Bldg Vent Stack effluent normal for plant conditions - no

Unit 2 Aux Bldg Vent Stack effluent normal for plant conditions Crew

Transition to 1BCA 1.2 LOCA OUTSIDE CONTIANMENT, Step 1.

EVALUATOR NOTE: The crew actions for 1BCA 1.2 LOCA OUTSIDE CONTIANMENT continue on the next page.

22

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: __8 & 9__

Event

Description:

Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior US

Enter and direct 1BCA-1. 2 LOCA OUTSIDE CONTAINMENT.

Verify Proper Valve Alignment

Place SVAG Valve 480 bus feeds C/S to closed.

Check 1RH8701A/B 1A RH Pump Suction from Hot Leg Isolation Valves and 1RH8702A/B 1B RH Pump Suction from Hot Leg Isolation Valves closed.

ATC

Check 1SI8840 U1 RH HX to Hot Leg Isolation Valve closed.

Check 1SI8802A/B SI Pump Discharge Outside Containment Isolation Valves closed.

Check containment isolation phase A valves closed.

Try to identify and isolate break.

Reset SI recirc sump isol valves if necessary

1SI8811A/B Containment Recirc Sump Outlet Isol Valves

1CV8110/1CV8111 1A/B CV Pump Miniflow Isol Valves

Reset SI Cent CHG pump miniflow isol valves

1CV8114 1A CV Pump ESF Miniflow Isol Valve CREW

1CV8116 1B CV Pump ESF Miniflow Isol Valve

Verify CENT CHG pump miniflow isol valves - Open

1CV8110 1B CV Pump Miniflow Isol Valve

1CV8111 1A CV Pump Miniflow Isol Valve

1CV8114 1A CV Pump ESF Miniflow Isol Valve

1CV8116 1B CV Pump ESF Miniflow Isol Valve

Sequentially close and open listed valves one at a time while monitoring for an RCS pressure rise.

CREW

1SI8809A 1A RH HX SI Downstream Isol Valve

1SI8809B 1B RH HX SI Downstream Isol Valve CT-32 [CT]

Report RCS pressure rises when 1SI8809B is closed.

Identify the leak isolated and maintain 1SI8809B closed.

EVALUATOR NOTE: The scenario can be terminated after declaring the leak isolated and maintaining 1SI8809B closed.

23

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event Description Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior EVALUATOR NOTE: 1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

BOP Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps - 1B RUNNING

RH pumps - BOTH RUNNING

SI pumps - BOTH RUNNING BOP Attachment B action VERIFY ECCS VALVE ALIGNMENT

Group 2 Cold Leg Injection monitor lights required for ECCS valve alignment -

LIT EVALUATOR NOTE: RCS pressure is dependent on when evaluated, it is anticipated to be below 1700 psig at this step.

BOP Attachment B action VERIFY ECCS FLOW

HHSI flow >100 gpm or SI Pump Discharge flow > 200 gpm - no

RCS pressure <1700 psig

RCS pressure <325 psig - no BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights - LIT Verify CNMT isolation Phase A

Group 3 CNMT isolation monitor lights - LIT Verify CNMT Ventilation isolation

Group 6 CNMT Vent Isol monitor lights - LIT Verify CC Pumps

CC pumps - BOTH RUNNING Verify SX Pumps running

SX pumps - BOTH RUNNING Check If Main Steamline Isolation Is Required o Check SG pressure < 640 psig o Check CNMT pressure > 8.2 psig

If either condition is met, then verify MSIVs and MSIV Bypass valves closed

- valves will not close

Manually actuate MS Isolation - MSIVs will not close

Manually close valves - MSIVs will not close Check if CS is required

CNMT pressure has risen to greater than 20 psig - no 24

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event Description Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY FW ISOLATED

FW pumps tripped

FW isolation monitor lights lit

FW pumps discharge valves closed 1FW002A-C

Trip all running HD pumps BOP Attachment B action VERIFY BOTH DGS RUNNING:

DGs - BOTH RUNNING

SX valves open 1SX169A and B

Dispatch operator locally to check operation BOP Attachment B action VERIFY GENERATOR TRIP

Unit 1 Main Transformer output breakers - OPEN:

GCB 3-4

OCB 4-5

Excitation red OFF light is LIT BOP Attachment B action VERIFY CONTROL ROOM VENTILATION ALIGNED FOR EMERGENCY OPERATIONS:

Control Room Outside Air Intake radiation monitors < High Alarm setpoints

Operating VC train equipment running Train A

Supply fan 0A

Return fan 0A

M/U fan 0A

Chilled water pump 0A

MCR chiller 0A

Operating VC train dampers

M/U fan outlet damper NOT full closed 0VC24Y

VC train M/U filter light LIT

Operating VC train Charcoal Absorber aligned for train A

0VC43Y closed

0VC21Y open

0VC22Y open

Operating VC train M/U filter alignment

0VC25Y open

0VC312Y closed

Control Room pressure greater than +0.125 inches water on 0PDI-VC038 25

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event Description Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED

Two inaccessible filter plenums aligned

Plenum A fan 0VA03CB running

Damper 0VA023Y not fully closed

Damper 0VA436Y closed

Plenum C fan 0VA03CF running

Damper 0VA072Y not fully closed

Damper 0VA438Y closed Check Aux Building Supply and Exhaust fans

One Exhaust Fan running for every Supply Fan running BOP Attachment B action VERIFY FHB VENTILATION ALIGNED

Train B fan 0VA04CB running

0VA055Y open

0VA062Y not fully closed

0VA435Y closed BOP Attachment B action Maintain UHS Basin level > 80%

Initiate periodic checking of Spent Fuel Cooling

Dispatch operator to locally check SFP level and temperature Notify Unit Supervisor of

Manual actions taken

Failed equipment status

Attachment B completed BOP Attachment B action Initiate periodic checking of Spent Fuel Cooling

Dispatch an operator to verify local actions

SFP level is greater than 420 elevation (20 feet from the top of the fuel)

SFP temperature STABLE BOP Attachment B action Notify Unit Supervisor of the following:

Manual actions taken - Phase A and MS Isolation actions

Failed equipment status - All MSIVs open

Ownership of Continuous Action Step

Attachment B completed 26

Op-Test No.: 2021-301 _ Scenario No.: _N21-4_ Event No.: _ 8 & 9__

Event Description Spurious Safety Injection with auto RX trip, LOCA Outside Containment Time Position Applicants Actions or Behavior CREW Attachment B action Shutdown unnecessary plant equipment As time allows refer to 1BGP 100-4T4, REACTOR TRIP POST RESPONSE GUIDELINE As time allows refer to 1BGP 100-5, PLANT SHUTDOWN AND COOLDOWN EVALUATOR NOTE: The crew actions for of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, continue on page 19.

The crew actions for of 1BCA-1. 2 LOCA OUTSIDE CONTAINMENT, begin on page 23.

27

1BGP 100-3T1 Revision 31 Page 1 of 4 POWER ASCENSION FLOWCHART Continuous Use DATE Today 1BGP 100-3 Flowchart File Location: 1.02.0133 TIME T - 2hours (Byron / Braidwood Commonality Reviewed)

ENTER SM EGC Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to the step listed in the resolve prior to step column, if applicable.

CCR PREREQUISITES Initial each RO SRO D CR PRECAUTIONS LIMITATIONS E CR FWIV CR AND ACTIONS 17 ES HD CR MODE 2-1 6 CR 26 SM SMP 1 PERM PDMS 5% 12% P10 P7 STM DUMP DEMAND SYNC TGTMS SMP 8A CR 8B CR8C CR 9 CR 10 CR 11 CR20 CR 27 CR 29 a RTC CR5 TURB NOTIFY LATCH ETS OPC 520 1700 1775 TRIP 1800 TURB GEN NOTIFY SET PED TURB OVSPD OVSPD RPM RPM RPM TEST RPM PREP PREP TSO & PJM VPL SMP 3CR CR CR CR 71 CR 7 CR 14 CR CR CR CR CR CR 2 4 70 15 18 19 CR 21 23 24 30 FLOW S/G LEVEL FW Pp CHART CR 12 CR 16 SWITCHYARD CORE STM DUMPS PREP MON SJAE CR 13 CR 22 CR28 c CR 31 SD CR 25 GS b CR 32

1BGP 100-3T1 Revision 31 Page 2 of 4 POWER ASCENSION FLOWCHART Continuous Use 1BGP 100-3T1 Flowchart Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to the step listed in the resolve prior to step column, if applicable.

TURB Initial each FW PP FW VLVS FW FW PP SEQ RO SRO 10% 20% RECIRC AUTO ~20% L/U AUTO VLV >20%

CR 33 CR 72 CR 38 CR 40 CR 41 CR 42 CR 44 STATUS P-8 &C-20 LIGHTS >25% >30% RTC CR 39 CALORIMETRIC CR 47 CR 49 CR51 50%

a & C-15 >15% 30% 50% CALOR a

CR 45 CR 55 CR62 AFD <50%

STM DUMPS ELEC LINEUP CR56 CR QPTR 34 CR 43 <50%

P-13 TURB DRAINS >20% DNBR CR 57 MOTOR FW PP CR 37 DRAINS HD <50%

CR FW PP 46 CR RECIRC CD/CB FW ALIGN >40% PP 58 H2 TEMP CR 35 CR 50 CR 52 CR 54 CR 60 CR 53 H2 TEMP GC TEMP AS b

SEAL OIL CR48 CR 59 CR61 CR 36 NIS PWR b LOOP c

c CR 73

1BGP 100-3T1 Revision 31 Page 3 of 4 POWER ASCENSION FLOWCHART Continuous Use 1BGP 100-3T1 Flowchart Exceptions are to be listed on 1BGP 100-3T1, Flowchart Exception Sheet. Place the circled exception number at the excepted step. Place the circled exception number just prior to GS the step listed in the resolve prior to step column, if applicable.

ADJ Initial each CR 63 RO SRO MDFWP 90% 100% 1BGP 100-3 90% Auto Start CALOR 100% CALOR COMPLETE DATE EXIT a 64 65 66 67 68 69 TIME SM b

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1BGP 100-3T1 Revision 31 Page 4 of 4 Continuous Use 1BGP 100-3T1 FLOWCHART EXCEPTION SHEET RESOLVE EXCEPTION EXCEPTED TIME AND SM DESCRIPTION OF REASON FOR PRIOR TO TIME AND SM NUMBER STEP DATE INIT EXCEPTION STEP # DESCRIPTION OF RESOLUTION DATE INIT Page of ____

ML21361A169

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