ML23146A072

Proposed Scenarios

ML23146A072
Person / Time
Site:	Byron
Issue date:	02/27/2023
From:	Constellation Energy Generation
To:	NRC/RGN-III
Bruce Bartlett
Shared Package
ML19121A201	List: BYRON 2022-0064, Letter 2022-0064 Submittal of Byron Integrated Initial License Training Examination Materials(Signed) ML23146A046 ML23146A048 ML23146A070 ML23146A071 ML23146A072 ML23146A077 ML23146A078 ML23146A080
References
Download: ML23146A072 (1)

Text

Scenario N22-1 Page 1 of 26 Form 3.3-1 Scenario Outline Facility:

Byron Station Scenario #: N22-1 Scenario Source:

Op. Test #: 2022-301 Examiners:

Applicants/

Operators:

Initial Conditions:

IC 71 100% RTP, MOL, steady state conditions Turnover:

Maintain power operations. Perform 1BOSR 0.5-2.AF.1-1 for post maintenance testing following repairs. 1A FW Pump OOS. Expected return to service is 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />.

Critical Tasks:

CT Isolate Main Turbine from SG during ATWS CT Insert negative reactivity into the core during ATWS Event No.

Malf. No.

Event Type*

Event Description 1

None N

(BOP)

Perform 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test (21 NRC) 2 IMF CV17 I

(ATC, US)

VCT level channel 1LT-185 fails high 3

PA0005 TS (US) 1A MSIV low pressure annunciator alarms 4

IOR ZDI0PBCW03PA ON C

(BOP, US) 0A CW M/U Pump will spuriously trip 5

TH11A C, TS (ATC, US)

PZR PORV leaking (Isolable) (NRC Exam 21-1) 6 IMF FW35A C

(BOP, US) 1A HD pump trips 7

IMF FW35B R

(ATC, BOP, US) 1B HD pump trips; runback required 8

[CT]

IMF TH16A IMF RP02A (preload)

IMF RP02B (preload)

IMF RD09 8 M

(ATC, BOP, US) 1C HD trip ATWS occurs as RX trip breakers will fail to open on manual actuation Rod speed failure occurs during ATWS limiting auto rod speed to 8 steps per minute 9

[CT]

IMF TC03 (preload)

IMF RP09A C, MC (BOP, US)

Turbine fails to trip in auto (21 NRC)

Spurious FWI isolation occurs with attempt to manually trip the RX (21 CERT)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

Scenario N22-1 Page 2 of 26 Critical Tasks:

1. CT-50 Isolate Main Turbine from SGS During ATWS Initiating Cue:

All governor and Throttle valves open, indicating Green on Ovation Panel 5501, with RX trip signal present greater than 30% reactor power.

Performance Feedback:

Valve position indication that all Governor and Throttle valves are closed.

Success Path:

Manipulations of controls to trip the main turbine with either the control board pushbutton or use of the soft keys on the Ovation panel 5502 to initiate a Turbine trip.

Measurable Performance Standard:

Manually trip the turbine from the control room prior to reaching SG levels for entry into 1BFR H.1 RESPONSE TO LOSS OF SECONDARY HEAT SINK of 10% on all SG narrow range levels. (K/A: EPE 029EA1.19; importance - 3.6).

2. CT-52 Insert negative reactivity into the core Initiating Cue:

ATWS in progress with control rods inserting at less than 48 steps per minute in automatic.

Performance Feedback:

Manually inserting rods in manual until RX trip and bypass breakers open, RX power less than 5%, constant negative IR startup rate, and/or all DRPI indications show rod at bottom indicating the RX tripped.

Success Path:

Manipulation of control rods to insert at maximum speed in manual.

Measurable Performance Standard:

Manually insert control rods prior to PZR Safeties lifting and continue until the RX is verified tripped in 1BFR S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS UNIT 1. (K/A: EPE 029EA1.20; importance - 4.0).

Scenario N22-1 Page 3 of 26 Scenario 22-1 Summary The scenario will start with at Full Power, MOL, steady state conditions. The crew will be turned over the activity to perform a stroke test of 1AF013B following maintenance. 1A FW Pump is OOS and is expected to be returned to service in 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />.

Event 1 Perform 1BOSR 0.5-2.AF.1-1 The crew will perform a partial surveillance of 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test to stroke 1AF013B. This will require a logbook entry into TS 3.7.5 Auxiliary Feedwater System for closing 1AF013B. Once complete with the stroke of 1AF013B, at lead examiner discretion, continue to Event 2.

Event 2 1LI-185 fails high 1LI-185 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 3.

Event 3 1A MSIV low pressure alarm Annunciator 1-1-B5 MSIV 1A HYD/PNEU PRESS HIGH LOW will alarm. SER point 0005 will indicate that the Active Train accumulator has a low pressure. The crew will dispatch an Equipment Operator (EO) to locally determine the accumulator pressure. After 2 minutes, the EO will report accumulator pressure of 4750 psig. The Unit Supervisor (US) will enter TS 3.7.2 MAIN STEAM ISOLATION VALVES due to the low pressure of the accumulator. Once the US has identified the TS entry and notified the Shift Manager (SM), at lead examiner discretion, continue to Event 4.

Event 4 0A CW M/U Pump trip 0A CW Makeup Pump will spuriously trip. The BOP will refer to BAR 0-38-A11 and start the standby 0B CW Makeup Pump per BOP CW-9, Circulating Makeup Pump Start-up. The crew may also enter 0BOA SEC-11, Inadequate Circulating Water Makeup. Once the 0B CW Makeup Pump has started, at lead examiner discretion, continue to Event 5.

Event 5 PZR PORV leaking (Isolable) 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 ATC will close PZR PORV Block valve 1RY8000A to isolate the leakage. The crew will enter Tech Spec 3.4.11 Condition B. Once the Tech Spec has been entered, at lead examiner discretion, continue to Event 6.

Event 6 1A HD Pump Trip 1A HD Pump will trip. 1C HD Pump will start when crew attempts to manually start the pump per the BAR 1-17-D2 HD PUMP TRIP. The crew will execute 1BOA SEC-1 SECONDARY PUMP TRIP.

After the crew stabilizes the unit and dispatches operators to perform BOP HD-1 HEATER DRAIN SYSTEM STARTUP and/or BOP HD-2 HEATER DRAIN SYSTEM SHUTDOWN, at lead examiner discretion, continue to Event 7.

Scenario N22-1 Page 4 of 26 Event 7 1B HD Pump Trip 1B HD Pump will trip. The crew will perform a HD Pump Runback of the unit at 20MW/min down to 780 MWe per 1BOA SEC-1 SECONDARY PUMP TRIP. After the crew stabilizes the unit at the new power level, the lead examiner will direct continuation to Event 8 & 9.

Event 8 & 9 1C HD Pump Trip and Reactor Trip Complications (ATWS) 1C HD Pump will trip. Loss of all HD pumps requires a manual RX trip per 1BOA SEC-1 Attachment D. The Reactor will NOT Trip on a manual actuation (RX Trip breakers will fail to open on a Manual or Automatic Trip) and the crew will implement 1BFR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS. Control rod speed will fail to 8 steps per minute in automatic requiring the operator to manually insert control rods. A spurious Feedwater Isolation will occur shortly after the attempt to manually trip the reactor. The Turbine will NOT Trip in automatic and will require a manual actuation to trip. The local operator, when dispatched, will locally Trip the Reactor Trip Breakers in 2 minutes. The crew will then return to 1BEP-0, REACTOR TRIP OR SAFETY INJECTION. The scenario is complete when the crew has transitioned from 1BEP-0 to 1BEP ES-0.1, REACTOR TRIP RESPONSE.

Scenario N22-1 Page 5 of 26 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, NRC EXAM Security Checklist.

Establish the conditions of IC 71, 100% power, MOL, equilibrium xenon (IC 22)

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 RP02A - REACTOR TRIP BREAKER FAILS TO OPEN RTA o RP02B - REACTOR TRIP BREAKER FAILS TO OPEN RTB o TC03 -TURBINE AUTO TRIP FAILURE o ED045C - 1A FW BRKR OPEN o ZDI1FW01PA - 1A FW Pump C/S Pull to Lock o ZDI1FW01PAB-1A FW Pump Lube Oil Pump Pull to Lock o ZDI1FW002A - 1FW002A 1A FW Pump Discharge valve closed o ED091C 1FW002A breaker open o ZDI1FW012A - 1A FW Pump Recirc Valve closed o ZDI1FW012a1 - 1A FW Pump Recirc Valve closed light off Verify the following are included in the Smart Scenario:

Scenario N22-1 Page 6 of 26 Ensure the following equipment is aligned 1C HD Pump in STBY Set BAT Flow Controller to 13.2 for 843 ppm boron Ensure REMA is available at the Unit Desk Place OOS cards on the following equipment:

1A FW Pump C/S 1A FW Pump Lube Oil Pump C/S 1FW001A C/S 1FW012A C/S Provide copies of the following documents:

1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test

Scenario N22-1 Page 7 of 26 Turnover Information Unit 1 is at 100% MOL 1244 MWe RCS boron concentration is 843 ppm Control bank D @ 221 steps 1AF013B emergent repair work is complete. AF tunnel is closed. Perform 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test to complete PMT.

Online Risk is Green 1A FW Pump is OOS

Scenario N22-1 Page 8 of 26 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test Acknowledge as SM commencement and completion of procedure.

Event 2: 1LI-185 failure At Lead Evaluators cue, use Smart Scenario to fail 1LI-185 high by right clicking on the box titled, Event 2 VCT, and select, Release.

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

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

Event 3: 1A MSIV Low Accumulator Pressure At Lead Evaluators cue, use Smart Scenario to bring in MSIV Accumulator pressure low annunciator by right clicking on the box titled, Event 3 MSIV, and select, Release.

As EO, report to the crew, 2 minutes after being dispatched, that the 1A MSIV Active Train Accumulator is indicating 4750 psig. There is no indication of hydraulic fluid leaks. Provide minimum required pressure of 4850 from surveillance if requested.

As EO or Field Supervisor, if dispatched to restore pressure to accumulator, acknowledge getting a prejob brief and will adjust accumulator pressure per BOP MS-5 Step 15. Subsequent questioning on status will be answered with In progress. We will report to the Unit when complete.

As Shift Manager, acknowledge entry into TS 3.7.2 for the 1A MSIV active train accumulator being low.

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

Event 4: 0A CW Makeup Pump Trip At Lead Evaluators cue, use Smart Scenario to trip 0A CW Makeup Pump by right clicking on the box titled, Event 4 CW M/U Pump, and select, Release When dispatched as EO to check 0A CW Makeup pump, acknowledge enroute to River Screen House and will arrive in 2 minutes. After 2 minutes, report that the 0A CW Makeup Pump Breaker, Bus 045-1 Cub 1, is tripped open and an overcurrent target is showing.

As EO, if directed to support starting the 0B CW Makeup Pump, acknowledge and report BOP CW-9 steps F1 - F4 are complete. When directed, report steps F5 - F7 are N/A, Step F8 is complete, and the area is clear for a start of the pump.

As EO, acknowledge pump start. Report everything looks good for 0B CS M/U Pump start. Report that you will complete steps of BOP CW-9.

Scenario N22-1 Page 9 of 26 As Shift Manager acknowledge the failure, on line risk assessment, request for maintenance support, and IR request.

Event 5: PZR PORV leaking (Isolable)

At Lead Evaluators cue, use Smart Scenario initiate a leaking PORV 1RY456 by right clicking on the box titled, Event 5, 1RY456, and select, Release.

As Shift Manager, acknowledge request for writing IR, performing risk assessment and making appropriate notifications Event 6: 1A HD Pump trip At Lead Evaluators cue, use Smart Scenario to trip 1A HD Pump by right clicking on the box titled, Event 6 1A HD Pump, and select, Release.

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

As EO, acknowledge dispatch to 1A HD Pump and/or pump breaker. Report, after 2 minutes, that 1A HD pump is stopped and no issues with the pump are evident.

As EO, if dispatched to the 1C HD Pump, report, after 2 minutes or immediately after reporting on the 1A HD pump, that the pump is running with no issues.

As EO, if dispatched to the breaker, report, after 2 minutes, the breaker is tripped open with an overcurrent flag showing.

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

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

As Shift Manager, acknowledge procedure entry and request for Emergency Plan evaluations for 1BOA SEC-1. Acknowledge notification of HD Pump Runback ramp.

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

Scenario N22-1 Page 10 of 26 Event 8 & 9: 1C HP Pump trip and ATWS At Lead Evaluators cue, use Smart Scenario to trip 1C HD Pump and initiate the ATWS by right clicking on the box titled, Event 8 9 RX Trip, and select, Release.

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

After transition to 1BFR-S.1, Acknowledge request for STA and begin monitoring BSTs.

As EO, acknowledge request for local trip of Reactor Trip Breakers. After 2 minutes, report to crew the standing by to trip RX Trip Breakers and provide the following 1st check: Standing front of 1RD05E-1B and 1RD05E-1C Reactor Trip Breaker RTA and Reactor Trip Breaker RTB.

After the crew has directed the performance of step 6.RNO in 1BFR-S.1 to locally Trip the Reactor; use Smart Scenario to locally Trip the Reactor by right clicking on the box titled, Open RX Trip Breakers, and select, Release. Report breaker opening to MCR.

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

Scenario N22-1 Page 11 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: N22-1 Event No.: __1___

Event

Description:

Perform 1BOSR 0.5-2.AF.1-1 Unit One Train Auxiliary Feedwater Valves Stroke Test partial surveillance Symptoms/Cues: As directed by Turnover Time Position Applicants Actions or Behavior US Direct performance of 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test BOP VERIFY all applicable PREREQUISITES, PRECAUTIONS, and LIMITATIONS AND ACTIONS are satisfactorily addressed US Enter 1BOL 7.5 Condition A prior to closing 1AF013B BOP Record As Found condition of 1AF013B - OPEN BOP Exercise 1AF013B by cycling the valve CLOSED and OPEN BOP Return 1AF013B to As Found condition - OPEN US Verify Tech Specs are satisfied by completion of surveillance Exit 1BOL 7.5 Condition A after stroke complete for 1AF013B US Inform Shift Manager of completion of 1BOSR 0.5-2.AF.1-1 Unit One Train A Auxiliary Feedwater Valves Stroke Test and LCO exit EVALUATOR NOTE:

After completion of 1BOSR 0.5-2.AF.1-1, and with lead examiners concurrence, proceed with Event 2.

Scenario N22-1 Page 12 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __2___

Event

Description:

1LI-185 fails high Symptoms/Cues: Annunciator 1-9-A2 VCT LEVEL HIGH-HIGH/LOW Annunciator 1-9-D2 LTDWN FLOW DIVERTED TO HUT Annunciator 1-10-E4 OVATION SYSTEM TROUBLE Annunciator 1LT-185 indicating 100%

Time Position Applicants Actions or Behavior ATC Take action per BAR 1-9-A2 VCT LEVEL HIGH-HIGH/LOW:

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 VCT US Enter 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL UNIT 1 ATTACHMENT V EVALUATOR NOTE:

ATC must select operable channel in Ovation and alignment of 1CV112A. If US assigns BOP to these actions, Evaluator should intercede.

ATC Check VCT level normal

• Check VCT Level Channel 112

• Check VCT Level Channel 185 - channel failed high Select and OPERABLE VCT Level Channel in Ovation

• VCT Level 1 - Select CV-LT-112

• VCT Level 2 - Select CV-LT-112 Restore VCT level control to Auto

• 1CV112A EVALUATOR NOTE:

After 1LI-112 has been selected as the controlling channel for both VCT Level controllers in Ovation, and with lead examiners concurrence, continue with the Event 3.

Scenario N22-1 Page 13 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __3___

Event

Description:

1A MSIV Low Pressure Alarm Symptoms/Cues: Annunciator 1-1-B5 MSIV 1A HYD/PNEU PRESS HIGH LOW Time Position Applicants Actions or Behavior BOP Take action per BAR 1-1-B5 MSIV 1A HYD/PNEU PRESS HIGH LOW Dispatch EO to determine the status of 1A MSIV EO reports Hydraulic pressure value of 4750 psig Inform US of 1A MSIV status US Review TS 3.7.2 for applicability Enter TS 3.7.2 Condition A for 1A MSIV due to being below T.S. minimum of 4850 psig.

Notify SM of plant status, request IR and maintenance notification and risk evaluation BOP o

Direct EO to raise pressure on 1A MSIV Active accumulator per BOP MS-5 MSIV ACCUMLATOR OPERABILITY CHECK EVALUATOR NOTE:

After the crew has entered TS 3.7.2, with lead examiners concurrence, initiate the Event 4.

Scenario N22-1 Page 14 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __4___

Event

Description:

0A CW Makeup Pump Trip Symptoms/Cues: Annunciator 0-38-A11 CW MAKEUP PUMP TRIP Time Position Applicants Actions or Behavior BOP Take action per BAR 0-38-A11 CW MAKEUP PUMP TRIP Place 0A CW M/U Pump C/S to AFTER TRIP Dispatch EO to determine the status of 0A CW M/U Pump US Acknowledge 0A CW M/U pump trip Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure BOP

• Start 0C CW M/U Pump per BOP CW-9 CIRCULATING WATER MAKE-UP PUMP START-UP

• Direct EO to perform steps F1 - F4 and Step F8

• Start 0C CW M/U Pump (0CW03PC) from 0PM01J by taking C/S to After Close

• Direct EO to complete steps of BOP CW-9 EVALUATOR NOTE:

After the crew has started 0C CW M/U Pump, with lead examiners concurrence, initiate the Event 5.

Scenario N22-1 Page 15 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __5___

Event

Description:

PZR PORV leaking (Isolable)

Symptoms/Cues: Annunciator 1-12-C6 PZR PORV DSCH TEMP HIGH Annunciator 1-12-B2 PZR PORV OR SAF VLV OPEN Dual indication on 1RY455A Slight drop in PZR pressure Time Position Applicants Actions or Behavior 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)

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. (1RY8000A)

MONITOR PZR PORV and Safety Valve Discharge Line temperatures.

Scenario N22-1 Page 16 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __5___

Event

Description:

PZR PORV leaking (Isolable)

Symptoms/Cues: Annunciator 1-12-C6 PZR PORV DSCH TEMP HIGH Annunciator 1-12-B2 PZR PORV OR SAF VLV OPEN Dual indication on 1RY455A Slight drop in PZR pressure Time Position Applicants Actions or Behavior 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 B, One PORV inoperable and not capable of being manually cycled.

B.1 RA - Close associated block valve.

CT - 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B.2 RA - Remove power from associated block valve.

CT - 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B.3 RA - Restore PORV to OPERABLE status.

CT - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> EVALUATOR NOTE:

After the US determines the Tech Spec requirements, with lead examiners concurrence, initiate the Event 6.

Form 3.3-2 Required Operator Actions

Scenario N22-1 Page 17 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __6___

Event

Description:

1A HD Pump Trip Symptoms/Cues: Annunciator 1-16-E1 FW PUMP NPSH LOW Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Annunciator 1-17-B9 CD/CB PUMP AUTO START Time Position Applicants Actions or Behavior BOP Recognizes 1A HD pump tripped.

Refer to BAR 1-17-D2.

Reports failure to US.

Recognizes one Heater Drain Pump running.

Perform actions of BAR 1-17-D2 Start Standby HD pump Inform US to enter 1BOA SEC-1 Direct EO to investigate cause of HD pump trip o Complete shutdown of tripped pump per BOP HD-2 US Acknowledge 1A HD pump trip.

Acknowledge start of standby HD pump per BAR Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure Implement 1BOA SEC-1, SECONDARY PUMP TRIP, Attachment D HD PUMP TRIP and direct operator actions of 1BOA SEC-1 Notify Chemistry to monitor secondary chemistry.

BOP VERIFY/START standby 1C HD pump Verify HD pumps running - TWO running Check HD tank level stable or dropping and <72%

Restore plant conditions HD tank overflow closed in AUTO Running HD pumps parameters acceptable ATC Check Delta I within limits Check PDMS OPERABLE Check PDMS LIMIT EXCEEDED alarm NOT LIT Control Delta I near target US Notify SM of plant status, request IR and maintenance notification and risk evaluation

Scenario N22-1 Page 18 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __6___

Event

Description:

1A HD Pump Trip Symptoms/Cues: Annunciator 1-16-E1 FW PUMP NPSH LOW Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Annunciator 1-17-B9 CD/CB PUMP AUTO START Time Position Applicants Actions or Behavior ATC Monitor plant response to Secondary transient and take actions directed by the US EVALUATOR NOTE:

After standby HD pump has been started, with lead examiners concurrence, continue with Event 7.

Scenario N22-1 Page 19 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __7___

Event

Description:

1B HD Pump Trip Symptoms/Cues: Annunciator 1-16-E16 FW PUMP NPSH LOW Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Annunciator 1-17-B9 CD/CB PUMP AUTO START Time Position Applicants Actions or Behavior BOP Recognizes 1B HD pump tripped.

Refer to BAR 1-17-D2.

Reports failure to US.

Recognizes one Heater Drain Pump running.

• Recognizes standby HD pump is unavailable.

ATC, BOP, US

• Identify entry conditions for 1BOA SEC-1, SECONDARY PUMP TRIP.

US Acknowledge 1B HD pump trip.

Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

Implement 1BOA SEC-1, SECONDARY PUMP TRIP Attachment D "HD PUMP TRIP" and direct operator actions of 1BOA SEC-1.

BOP Recognizes standby HD pump NOT AVAILABLE.

Check HD pump status at 1PM03J.

ONLY 1C HD pump running.

Initiate HD runback on OWS graphic 5512 at 1PM02J or OWS drop 210.

Verify turbine load lowering.

Check HD Tank level at 1PM03J:

Level > 72% and rising.

Maintain HD tank level.

Verify 1HD046A &B in AUTO.

o Open 1CB113A-D as needed.

o Manually open 1HD117, HD tank overflow valve.

o Lower turbine load as necessary to maintain HD tank level <72%.

Evaluate note. If level cannot be maintained < 80%, then should Trip the RX and enter 1BEP-0.

Scenario N22-1 Page 20 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __7___

Event

Description:

1B HD Pump Trip Symptoms/Cues: Annunciator 1-16-E16 FW PUMP NPSH LOW Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Annunciator 1-17-B9 CD/CB PUMP AUTO START Time Position Applicants Actions or Behavior EVALUATOR NOTE:

IF HD tank level can NOT be maintained less than 80%, THEN the crew should manually trip the reactor and GO TO 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, Step1.

BOP Check 1HD117, HD tank overflow valve in auto and closed at 1PM03J.

o Lower turbine load as necessary to close 1HD117.

Check 1C HD pump parameters at 1PM03J.

1C HD pump amps < 168 amps.

1C HD pump flow < 2965 KLB/HR.

o Lower turbine load as necessary to restore 1C HD pump parameters.

When complete, deactivate turbine runback:

Depress STOP HD RUNBACK softkey at OWS graphic 5512 at 1PM02J or OWS drop 210.

US/ ATC Check PDMS operable.

Annunciator PDMS INOPERABLE not lit (1-10-E8).

1BOL 3.h not implemented.

Annunciator PDMS LIMIT EXCEEDED not lit (1-10-D7).

ATC

• Control I near target.

Operate control rods in manual as necessary to restore I to desired value at 1PM05J.

Monitor RCS parameters.

o If RCS pressure lowers < 2209 psig, notify US to enter TS 3.4.1, RCS DNB Limits.

o If control rods < low - 2 rod insertion limit, notify US to enter TS 3.1.6, Control Bank Insertion Limits.

Scenario N22-1 Page 21 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __7___

Event

Description:

1B HD Pump Trip Symptoms/Cues: Annunciator 1-16-E16 FW PUMP NPSH LOW Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Annunciator 1-17-B9 CD/CB PUMP AUTO START Time Position Applicants Actions or Behavior ATC Initiate RCS boration at 1PM05J:

Determine required boric acid volume (525 gallons of boric acid per placard) o Determine from ReMA or placard (Three batches of 175 gallons of boric acid to be added during the runback)

Determine desired boric acid flow rate.

Set 1FK-110 BA Flow Control to desired boration rate.

Set 1FY-0110 BA Blender Predet Counter to desired volume.

Place MAKE-UP MODE CONT SWITCH to STOP position.

Place MODE SELECT SWITCH to BORATE position.

Place MAKE-UP MODE CONT SWITCH to START.

Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).

Turn on PZR backup heaters.

BOP Verify running CB pump recirc valves in auto.

1CB113A-D on running pumps.

o Dispatch operators to perform BOP HD-2 for 1B HD pump.

o Shutdown CD/CB pump (if started during procedure performance).

US Notify chemistry to monitor secondary plant chemistry.

Notify SM to perform risk assessment.

Check reactor power change > 15% in one hour.

o Notify chemistry to perform TS 3.4.16 sampling.

o Notify rad protection to perform TS sampling.

Contact Generation Dispatch to inform of load reduction and estimated duration of power derate.

EVALUATOR NOTE:

After the actions for the ramp are complete and the unit is stabilized, with lead examiners concurrence, continue with the next Events 8 & 9.

Scenario N22-1 Page 22 of 26 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __8 & 9___

Event

Description:

Reactor Trip Complications - 1C HD Trip and ATWS; A Feedwater Isolation will occur when the ATC attempts to trip the RX Symptoms/Cues: Disagreement light on 1C HD Pump Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Time Position Applicants Actions or Behavior BOP

• Recognizes 1C HD pump tripped

• Reports failure to US US Acknowledge 1C HD pump trip o May enter 1BOA SEC-1 Attachment D, Step 2 RNO directs RX trip if no HD pumps are running at this power level Directs RX trip Implements 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 and directs operator actions Notifies SM of 1BEP-0 entry Requests EAL evaluation ATC Verify Reactor Trip Rod bottom lights - NONE LIT Reactor trip & Bypass breakers - CLOSED Neutron flux STABLE Determines the Reactor did NOT TRIP Attempts RX trip from both RX trip switches 1PM05J 1PM06J ATC, BOP, US Transition to 1BFR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS EVALUATOR NOTE:

Actions for 1BFR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS are identified in the following steps.

US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BFR-S.1 and direct operator actions of 1BFR-S.1

Scenario N22-1 Page 23 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __8 & 9___

Event

Description:

Reactor Trip Complications - 1C HD Trip and ATWS; A Feedwater Isolation will occur when the ATC attempts to trip the RX Symptoms/Cues: Disagreement light on 1C HD Pump Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Control rods will fail to 8 steps per minute in AUTO. This will require the ATC to perform the RNO action when rod speed is less than 48 steps per minute and manually insert control rods.

EVALUATOR NOTE:

The ATC is not required to dispatch an EO at this point in time as it will be directed by 1BFR-S.1 Step 6. It is anticipated that the ATC will dispatch an EO as soon as possible, but not required at this time.

[CT]

ATC

[CT-52]

Perform immediate operator actions of 1BFR-S.1:

VERIFY REACTOR TRIP Rod bottom lights - LIT Determines Rod Bottom lights are Not LIT Reactor trip & Bypass breakers - OPEN Determines Reactor Trip Breakers are Not OPEN Determines Neutron flux - NOT DECREASING Manually trip the reactor 1PM05J 1PM06J Identifies control rods control are NOT inserting automatically at greater than or equal to 48 steps per minute Manually insert control rods at greater than or equal to 48 steps per minute o Dispatch an EO to manually open the RX Trip Breakers

[CT]

BOP

[CT-50]

Perform immediate operator actions of 1BFR-S.1 VERIFY TURBINE TRIP Determines Throttle and Governor Valves are Not CLOSED o

Use Ovation soft key Trip button on Screen 5512 Use Turbine Trip pushbutton All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED

Scenario N22-1 Page 24 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __8 & 9___

Event

Description:

Reactor Trip Complications - 1C HD Trip and ATWS; A Feedwater Isolation will occur when the ATC attempts to trip the RX Symptoms/Cues: Disagreement light on 1C HD Pump Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Time Position Applicants Actions or Behavior BOP CHECK AF PUMPS RUNNING AF pump run lights status - LIT ATC/BOP INITIATE EMERGENCY BORATION OF THE RCS Check CV pumps - 1A CV Pump running Open emergency boration valve 1CV8104 Start Boric Acid Transfer pump Verify charging and emergency boration flow greater than 30 gpm each ATC Check PZR pressure less than 2335 psig - yes BOP VERIFY CNMT VENTILATION ISOLATION Group 6 CNMT vent isolation monitor lights - LIT EVALUATOR NOTE:

The Reactor will be Tripped locally during the performance of the next step when directed.

ATC/BOP CHECK IF THE FOLLOWING TRIPS HAVE OCCURRED Reactor Trip Determines Reactor Trip has NOT occurred.

Dispatch operator to locally trip reactor Turbine Trip All Turbine governor valves - CLOSED All Turbine throttle valves - CLOSED ATC CHECK IF REACTOR IS SUBCRITICAL PR channels - LESS THAN 5%

IR channels - NEGATIVE STARTUP RATE ATC, BOP, US Transition to 1BEP-0, REACTOR TRIP OR SAFETY INJECTION EVALUATOR NOTE:

Actions for 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 are identified in the following steps.

Scenario N22-1 Page 25 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __8 & 9___

Event

Description:

Reactor Trip Complications - 1C HD Trip and ATWS; A Feedwater Isolation will occur when the ATC attempts to trip the RX Symptoms/Cues: Disagreement light on 1C HD Pump Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Time Position Applicants Actions or Behavior US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan 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 ATC Check SI status SI actuated SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1) - no SI ACTUATED lit (1-BP-4.1) - yes SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open) - yes Determine if SI required:

o Check PZR pressure < 1829 psig o Check Steamline pressure < 640 psig o Check CNMT pressure > 3.4 psig If SI is required: - yes US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

Scenario N22-1 Page 26 of 26 Op. Test No.: 2022-301_ Scenario No.: __1___ Event No.: __8 & 9___

Event

Description:

Reactor Trip Complications - 1C HD Trip and ATWS; A Feedwater Isolation will occur when the ATC attempts to trip the RX Symptoms/Cues: Disagreement light on 1C HD Pump Annunciator 1-17-D2 HD PUMP TRIP Annunciator 1-17-D3 HD/PUMP DSCH FLOW HIGH Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The scenario will be terminated after the crew has completed the Immediate Actions for 1BEP-0 and determined the need to continue in 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1, as identified by the US directing the BOP to perform Attachment B.

Form 3.3-1 Scenario Outline Scenario N22-2 Page 1 of 27 Facility:

Byron Station Scenario #:

N22-2 Scenario Source:

Op. Test #:

2022-301 Examiners:

Applicants/

Operators:

Initial Conditions:

IC 72, Unit 1 is operating at 84.0% power due to Advanced Nuclear Dispatch, MOL, 875 ppm boron, equilibrium xenon Turnover:

The shift manager requests the BOP to perform RV/IV quarterly surveillance per 1BOSR 3.g.3-1. 1A SI pump is running on recirculate pending completion of vibration testing. Generation Dispatch has alerted Byron Station of potential grid stability issues.

Critical Tasks:

CT Manually actuate main steamline isolation CT Isolate the faulted SG Event No.

Malf. No.

Event Type*

Event Description 1

None N

(BOP)

Perform 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance 2

MF CV03 TS (BOP, US)

SI Pump seal leak 3

None R

(ATC, BOP, US)

Generation Dispatch request Unit 1 lower power 50 MWe within 30 minutes (C22 - modified) 4 ZDI1CV110B C, MC (ATC, US) 1CV110B Boric Acid Blender to Charging Pumps valve fails to open (Cert 21) 5 MF CH03D C

(BOP, US) 1D CRDM Exhaust Fan trips (21 NRC) 6 MF MS04B 100 MF PB2411 ON ZLO1MS018B2 ON C, MC, TS (BOP, US) 1B SG PORV will spuriously open in auto with PORV low fluid level alarm (Cert 21) 7

[CT]

MF MS08D M

(ATC, BOP, US)

Steam break outside of CNMT on 1C SG (Cert 21) 8

[CT]

MF MS01A MF MS01B MF MS01C MF MS01D C, MC (ATC, US)

All MSIVs fail to close in Auto 1C MSIV fails to close in auto or manual

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 2 of 27 Critical Tasks:

1)

CT-12 Manually actuate Main Steamline Isolation Initiating Cue:

Indication that a main steamline isolation is required and indication that an automatic main steamline isolation did not occur.

Performance Feedback:

Valve position indication that all main steamline isolation valves are closed.

Success Path:

Manipulations of controls required to actuate main steamline isolation.

Measurable Performance Standard:

Manually actuate main steamline isolation before meeting conditions to enter 1BFR S.1 Response to Nuclear Power Generation (Intermediate Range SUR positive) or 1BFR P.1 Response to Imminent Pressurized Thermal Shock Condition (temperature drop of greater than 100°F in ALL RCS Cold Legs and ALL RCS Cold Legs less than 240°F). (K/A number: EPE 040AA1.01; importance - 4.3).

2)

CT-17 Isolate Faulted SG Initiating Cue:

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.

Performance Feedback:

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

Success Path:

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.

Measurable Performance Standard:

Isolate the faulted 1D SG before transition out of 1BEP-2. (K/A number - APE 040-AA1.03 importance - 3.9).

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 3 of 27 Scenario N22-2 Summary The scenario will start with Unit at 84% power, MOL, steady state conditions. The crew will have a turnover item to perform a partial RV/IV quarterly surveillance per 1BOSR 3.g.3-1. 1A SI pump is running on recirculate pending completion of vibration testing. Generation Dispatch has alerted Byron Station of potential grid stability issues.

Event 1 Perform 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance The crew will perform a partial surveillance of 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance to stroke 1MS5001A and 1MS5003A (Step F.1.b). Once complete with the stroke of 1MS5001A and 1MS5003A, at lead examiner discretion, continue to Event 2.

Event 2 1A SI Pump Seal Leak The crew will be notified by personnel in the field that the 1A Safety Injection Pump, running on recirc, has developed a seal leak and is spraying water in the room. The crew will determine that the pump needs to be secured and enter T.S 3.5.2 for the pump inoperability. Once the pump is secure and the T.S. determined, continue to Event 3.

Event 3 Generation Dispatch request Unit 1 to lower power Generation Dispatch will call the unit and direct a reduction of power of 50 MWe 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.

Event 4 1CV110B Boric Acid Blender to Charging Pumps valve fails to open During boration operations, the 1CV110B Boric Acid Blender to Charging Pumps valve will fail to open as identified by valve position and Annunciator 1-9-A6 BA FLOW DEVIATION. The ATC will identify the lack of boration flow, reference the BAR, and manually open 1CV110B to initiate boration flow.

Once boration flow is established sufficient observation of the reactivity maneuver is complete, at the lead examiners discretion, continue to Event 5.

Event 5 1D CRDM Exhaust Fan trips 1D CRDM Exhaust Fan trips. The BOP will refer to BAR 0-33-A5 and start an additional CDRM Fan per BOP VP-9. Once the BOP has started another CRDM Exhaust Fan, at lead examiner discretion, continue to Event 6.

Event 6 1B SG PORV will spuriously open in AUTO with PORV low fluid level alarm 1B SG PORV will start ramping open over a period of one minute. The BOP will manually close valve.

The valve will not indicate completely closed and Unit Supervisor will determine TS 3.7.4 and TS 3.6.3 applies. The crew will direct isolating the SG PORV using manual isolation valve 1MS019B.

Event 7 & 8 Steam Break outside of CNMT and MSIVs fail to close in Auto A steamline break will occur on 1C Mainsteam line outside of CNMT between the Containment wall and the 1C MSIV. The crew will identify the steamline break and initiate a manual RX Trip and actuate MS Isolation. The crew will enter 1BEP-0, REACTOR TRIP OR SAFETY INJECTION. The crew will initiate a manual Safety Injection, if an automatic one has not occurred. The Crew will transition to 1BEP-2 FAULTED STEAM GENERATOR ISOLATION. The crew will identify that the MS Isolation valves failed to close in automatic and initiate a MS Isolation via a MCB control switch. 1C MSIV will remain open. The scenario is complete when the crew has transitioned from 1BEP-2 to 1BEP ES-1.1 SI TERMINATION UNIT 1 and the 1C SG is isolated.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 4 of 27 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, NRC EXAM Security Checklist.

Establish the conditions of IC 72, 84% power, MOL, equilibrium xenon (IC 24)

Place Simulator in RUN Initiate Smart Scenario:

1. Open SMART SCENARIO (Extreme Ace icon)

2. Open file Scenario N22-2 Scenario.ssf

3. Click on the MODE button (near top of screen) and pick EXECUTE

4. Click on the PLAY button (bottom left of screen)

5. Verify Simulator Setup conditions automatically load

6. MS01A - FAILURE OF MAIN STEAM ISOLATION VALVE 1MS001A

7. MS01B - FAILURE OF MAIN STEAM ISOLATION VALVE 1MS001B

8. MS01C - FAILURE OF MAIN STEAM ISOLATION VALVE 1MS001C

9. MS01D - FAILURE OF MAIN STEAM ISOLATION VALVE 1MS001D Verify the following are included in the Smart Scenario:

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 5 of 27 Ensure the following equipment is aligned Both EH Pumps are running 1A SI Pump running on recirc Set BAT Flow Controller to 13.7 for 875 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 Quarterly Surveillance Marked up copy of 1BOSR 5.5.8.SI.5-1a UNIT ONE GROUP A INSERVICE TESTING (IST)

REQUIREMENTS FOR SAFETY INJECTION PUMP 1SI01PA Marked up copy of BOP SI-1 SAFETY INJECTION SYSTEM STARTUP Marked up copy of 1BOL 5.2 ECCS - OPERATING BOP SI-2 SAFETY INJECTION SYSTEM SHUTDOWN

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 6 of 27 Turnover Information Unit 1 is at 84% MOL 1098 MWe RCS boron concentration is 875 ppm Control bank D @ 194 steps Perform a partial surveillance of 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance to stroke 1MS5001A and 1MS5003A (Step F.1.b) and secure 1B EH Pump immediately after taking the shift.

2 EH Pumps running to support 1BOSR 3.g.3-1.

1A SI Pump is running on recirc pending completion of 1BOSR 5.5.8.SI.5-1a Unit One Group A Inservice Testing (IST) Requirements for Safety Injection Pump 1SI01PA vibration testing.

Delayed due to testing equipment issues. Operators are in the field working to correct the testing issues.

Generation Dispatch has alerted the station of potential grid stability issues.

1BOL 5.2 LCOAR ECCS - OPERATING due to 1SI8821A closed for 1BOSR 5.5.8.SI.5-1a.

Online Risk is Green

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 7 of 27 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Perform 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance As EO in the field, when contacted, report on location to observe stroke of 1MS5001A and 1MS5003A and initial position is full open.

AS EO, respond to candidates inquiries of valve position according to current valve position (traveling closed, full closed, travelling open, full open).

As EO respond on final position of valves as the same as when test started.

As EO respond to EH pressure for BOP EH-6a as 2100 psig.

Acknowledge as SM commencement and completion of procedure.

Event 2: 1A Safety Injection Pump Seal Leak At Lead Evaluators cue, initiate a call on the radio to the Unit as the Testing EO and report the following:

This is the testing EO at the 1A SI Pump. There is a lot of water is spraying from the seals of the 1A SI Pump. I am leaving the room.

As EO, if asked, report water continues to spray from seals after pump is secured.

As EO, report the leak has stopped once 1SI8964 is opened and system pressure drops.

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

Event 3: Generation Dispatch request Unit 1 to lower power At Lead Evaluators cue, call as Generation Dispatch (Brown Phone, 3812) and report the following:

This is Generation Dispatch: We need Byron Unit 1 to ramp down 50 MWe within 30 minutes due to a transmission emergency. Inform Gen Dispatch when the ramp begins and when it is completed.

If asked, identify Generation Dispatch caller as Alan Arkin.

If contacted as Gen Dispatch about terminating the power reduction, report:

It is imperative for grid stability that Byron complete the requested power reduction.

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

If requested as RP, acknowledge the ramp.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 8 of 27 If requested, as Chemistry, acknowledge the ramp.

Event 4: 1CV110B fails to open Verify 1CV110B remains closed after initiation of first boration.

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

Event 5: 1D CRDM Exhaust Fan trips At Lead Evaluators cue, use Smart Scenario to trip the 1D CRDM Exhaust Fan by right clicking on the box titled, Event 5 CRDM, and select, Release.

As EO, if dispatched to the breaker (MCC 133X6 C4), after 3 minutes, report the breaker is tripped free and will not reset.

As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 6: 1B SG PORV will spuriously open in AUTO and PORV low fluid level alarm is received At Lead Evaluators cue, use Smart Scenario to fail the 1B SG PORV by right clicking on the box titled, Event 6 SG PORV, and select, Release.

The 1B SG PORV will spuriously open and low fluid level will alarm.

As an EO, if directed to investigate, report the valve is closed and a puddle of hydraulic fluid is on the floor and there is still a slight amount of steam coming through the SG PORV.

If directed to close 1MS019B, wait 3 minutes and report 1MS019B is closed and steam has stopped.

As SM acknowledge the failure, Tech Spec entry, on line risk assessment, request for maintenance support, and IR requests.

Event 7 & 8: Steam Line Break Outside of CNMT and MSIVs fail to close in Auto At Lead Evaluators cue, use Smart Scenario to initiate a 4 MLBM Steam Line Break, full line break, outside of CNMT by right clicking on the box titled, Event 7 MS Line, and select, Release.

The MSIVs failing to close in auto are preloaded with the start of the scenario. The crew will be able to manually actuate the Mainsteam Isolation.

Two Safeties on the 1C SG have been failed open to simulate the leak between the Containment wall and the 1C MSIV. The initial failure will provide all required indications in the MS Tunnel.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 9 of 27 As Shift Manager, acknowledge transition to BEP procedure entries and request for Emergency Plan evaluations.

AS the EO, acknowledge direction to check on DGs, Spent Fuel Pool level and temperatures.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 10 of 27 Op. Test No.: 2022-301_ Scenario No.: N22-2 Event No.: __1___

Event

Description:

Perform a partial surveillance of 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance Symptoms/Cues: As directed by Turnover Time Position Applicants Actions or Behavior US

• Direct performance of a partial surveillance of 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance BOP

• Verify 2nd EH Pump running BOP

• Verify EO positioned to observe valve movement BOP

• At MCB, verify RSV L1, IV L1 OPEN BOP

• On Ovation graphic 5501:

Select VALVE TEST Select pushbutton RSV/IV LEFT 1 on graphic 7000 Select EXECUTE on the popup labeled RSV & IV LH 1 BOP

• Verify EO in field observes valve movement in the closed direction BOP

• At MCB, verify RSV L1, IV L1 CLOSED BOP

• Verify EO in field observes valve movement in the open direction BOP

• At MCB, verify RSV L1, IV L1 OPEN BOP

• Verify EO in field confirms valves return to the OPEN position BOP

• Depress EXIT on the popup labeled RSV & IV LH 1 BOP o Secure 2nd EH pump per BOP EH-6a US

• Inform Shift Manager of completion of 1BOSR 3.g.3-1 Unit One Reheat and Intercept Quarterly Surveillance EVALUATOR NOTE:

After completion of 1BOSR 3.g.3-1, and with lead examiners concurrence, proceed with Event 2.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 11 of 27 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __2___

Event

Description:

1A Safety Injection Pump Seal Leak Symptoms/Cues: Radio call from operator in the field Time Position Applicants Actions or Behavior US Direct ATC / BOP to secure 1A SI Pump US Notify SM 1A SI Pump being secured due to seal leak.

EVALUATOR NOTE:

The crew may not use BOP SI-2 to secure and realign the pump due to responding to the emergent event. The following are the steps per BOP SI-2. The crew should restore 1SI8821A to open and cycle 1SI8964 to reduce line pressure.

BOP Secure 1A SI Pump and take to Pull To Lock o Align 1A SI Pump for shutdown per BOP SI-2 SAFETY INJECTION SYSTEM SHUTDOWN o Direct Testing EO to complete BOP SI-1T1 o Verify CLOSE 1SI8871 Fill/Test Line Isolation Valve o Verify OPEN 1SI8888 SI Pps to Accum Fill Valve o Open 1SI8964 SI Test Lines to Radwaste Isol Valve to vent the SI Train to HUT (Valve should be closed after pressure drop) o OPEN 1SI8821A SI Pump 1A to Cold Legs Isol Valve o CLOSE SI8888, SI Pps to Accum Fill Vlv US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

(RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs T.S 3.5.2 ECCS -OPERATING (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A, One train inoperable A.1 RA - Restore train to OPERABLE status CT - 7 days EVALUATOR NOTE:

After the actions for securing 1A SI Pump and declaration of T.S. are complete, and with lead examiners concurrence, continue with the Event 3.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 12 of 27 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __3 & 4___

Event

Description:

Generation Dispatch request Unit 1 to lower power Symptoms/Cues: Telephone call from Generation Dispatch directing 50 MWe power reduction within 30 minutes Time Position Applicants Actions or Behavior US

• Direct Power per 1BGP 100-4T3 LOAD CHANGE 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 is acceptable if the need to borate in order to ensure control rods remain above the insertion limits is identified. Allowing control rods to drop below the insertion limit is acceptable while borating.

EVALUATOR NOTE:

Event 4: 1CV110B fails to open is set to occur during the ATC actions to ramp the unit down during the boration.

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) (Approximately 50 gallons boric acid)

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 to Lock position Place MAKE-UP CONTROL Switch to START Ensure proper operation of valves & BA pump 1CV110B Opens (fails), 1CV110A Modulates, BA pump is running

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 13 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __3 & 4___

Event

Description:

Generation Dispatch request Unit 1 to lower power Symptoms/Cues: Telephone call from Generation Dispatch directing 50 MWe power reduction within 30 minutes Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Event 4: Begins here. This annunciator will sound approximately 30 seconds after the initiation of the boration for the ramp, if the valve is not opened manually.

CUE:

o Annunciators:

o 1-9-A6 BA FLOW DEVIATION (if ATC has not opened valve within ~30 seconds) 1CV110B indicates closed

• Boration flow remains at zero ATC/US

• If the ATC determines the failure with 1CV110B while performing the procedure:

• Place 1CV110B Control Switch to OPEN Monitor RX Makeup flow on recorder 1CD-CX4102 to verify proper PW and Boric Acid flow If Flow Deviation Annunciator sounds:

Take action per the BAR 1-9-A6 BA FLOW DEVIATION Determine the reason for the deviation - 1CV110B is closed Place 1CV110B Control Switch to OPEN Monitor RX Makeup flow on recorder 1CD-CX4102 to verify proper PW and Boric Acid flow 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 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 4 complete. Event 3 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.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 14 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __3 & 4___

Event

Description:

Generation Dispatch request Unit 1 to lower power Symptoms/Cues: Telephone call from Generation Dispatch directing 50 MWe power reduction within 30 minutes Time Position Applicants Actions or Behavior BOP Initiate turbine load ramp: Using graphic 5501(per 1BGP 100-4T3)

SELECT SETPOINT ENTER desired (>5) MW/MIN rate in the RATE window DEPRESS the respective ENTER pushbutton ENTER desired final MWe output (50 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 descension:

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

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

VCT & PZR levels.

RCS Tave lowering/RCS boron concentration rising.

Boric Acid Totalizer responding correctly.

• Verify boration auto stops at preset value.

EVALUATOR NOTE:

After measurable change in power, and with lead examiners concurrence, continue with the Event 5.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 15 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __5___

Event

Description:

1D CRDM Exhaust Fan trips Symptoms/Cues: Annunciator CRDM EXHAUST FAN TRIP (0-33-A5) is LIT 1D CRDM amber trip light LIT Time Position Applicants Actions or Behavior BOP Identify failure of 1D CRDM exhaust fan and report to US US Direct starting standby CRDM exhaust fan Notify SM of failure, request risk evaluation and IR initiation.

o Direct placing ramp on HOLD (if still in progress)

BOP Refer to BAR 0-33-A5 Start standby CRDM Exhaust fan using BOP VP-9 Start 1VP03A or C by taking C/S to After Start EVALUATOR NOTE:

The BOP should be allowed to return to inside the horseshoe prior to continuing with next event.

EVALUATOR NOTE:

After the actions for starting a CRDM fan is complete, and with lead examiners concurrence, initiate the Event 6.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 16 of 27 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __6___

Event

Description:

1B SG PORV spuriously opens in AUTO with PORV low fluid level alarm Symptoms/Cues: 1MS018B Position Indication OPEN Increased steam flow Annunciator S/G 1B PORV TROUBLE (1-15-B10)

Time Position Applicants Actions or Behavior ATC, BOP, US o Identify 1B SG PORV spuriously open BOP Refer to BAR 1-15-B10 Notify US of opening SG PORV Identify SER point 2411 is in alarm Close 1B SG PORV with control switch US Direct closing 1B SG PORV Evaluate Tech Specs and determine LCO 3.6.3 condition C and 3.7.4 condition A apply.

Direct placing ramp on hold (if still in progress)

US Notify chemistry to monitor secondary plant chemistry.

Notify SM to perform risk assessment.

o Check reactor power change > 15% in one hour.

o Notify chemistry to perform TS 3.4.16 sampling.

o Notify rad protection to perform TS sampling.

US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

(RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs TRM 3.7.4 Steam Generator (SG) Power Operated Relief Valves (PORV)

(RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A, One SG PORV line inoperable A.1 RA - Restore SG PORV line to OPERABLE status CT - 30 days

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 17 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __6___

Event

Description:

1B SG PORV spuriously opens in AUTO with PORV low fluid level alarm Symptoms/Cues: 1MS018B Position Indication OPEN Increased steam flow Annunciator S/G 1B PORV TROUBLE (1-15-B10)

Time Position Applicants Actions or Behavior US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

(RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs TS 3.6.3 Containment Isolation Valves (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION C, One or more penetration flow paths with on containment isolation valve inoperable C.1 RA - Isolate the affected penetration flow path by use of at least one closed and deactivated automatic or remote manual valve, closed manual valve, or blind flange CT - 72 Hours AND CONDITION C, One or more penetration flow paths with on containment isolation valve inoperable?

C.2 RA Verify the affected penetration flow path is isolated CT - Once per 31 days following isolation EVALUATOR NOTE:

After 1B SG PORV failure has been addressed, with lead examiners concurrence, continue with the next Events 7 & 8.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 18 of 27 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior ATC, BOP, US Recognize the indications of a Main Steamline break US o Directs RX trip and MS Isolation o Implements 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 and directs operator actions o Notifies SM of 1BEP-0 entry o Requests Emergency Plan evaluation o Requests STA report to Control Room EVALUATOR NOTE:

Actions for 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 are identified in the following steps.

ATC Manually trips the RX Verify Reactor Trip Rod bottom lights Reactor trip & Bypass breakers Neutron flux STABLE Actuate MS Isolation BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED EVALUATOR NOTE:

Depending on how long it takes the crew to reach and execute Step 4, a Safety Injection could have occurred automatically.

If a SI has not automatically occurred, it is expected that the crew will actuate SI during the following step.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 19 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow 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) - no SI ACTUATED lit (1-BP-4.1) - no SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open) - no Determine if SI required:

Check PZR pressure < 1829 psig Check Steamline pressure < 640 psig Check CNMT pressure > 3.4 psig If SI is required: - yes

• Manually actuate SI US Directs BOP to perform Attachment B, SI VERIFICATION of 1BEP 0.

EVALUATOR NOTE:

Crew actions of 1BEP-0 continue below.

BOP actions of 1BEP-0, Attachment B continue on page 26.

ATC/BOP 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

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 20 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior ATC/BOP 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 Isol valve - open Normal spray valves - CLOSED ATC/BOP ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC/BOP Check steam dumps - AVAILABLE C-9 Permissive light - NOT LIT CW Pump - AT LEAST ONE RUNNING Note: Main Steam Isolation should already be actuated ATC Check RCS temperature:

RCPs - ANY RUNNING - yes Tave between 552°F and 561°F o RCPs -NONE RUNNING - n/a o Tcold between 552°F and 561°F Control RCS temperature by performing the following:

o Temperature greater than 561°F - n/a o Verify/open Steam Dumps and / or SG PORVs as necessary o Raise AF flow as necessary Temperature less than 552°F Verify/Close Steam Dumps and SG PORVs Reduce AF flow as necessary while maintaining 500 gpm total flow IF less than 10% (31% ADVERSE CNMT) (Per NOTE, throttle 1C AF flow to zero) o Actuate Main Steam Isolation as necessary (already done)

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 21 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior BOP Check if RCPs should be stopped:

All RCPs - ALL RUNNING.

High head flow 1FI-917 > 100 GPM and RCS Pressure > 1425 PSIG. - NO BOP Check pressure in all SGs:

NO SG dropping in an uncontrolled manner. NO, 1C dropping NO SG Completely Depressurized -> RNO: 1BEP-2 US Transition from 1BEP-0 to 1BEP-2, FAULTED STEAM GENERATOR ISOLATION.

Notifies SM of BEP entry Requests Emergency Plan evaluation EVALUATOR NOTE:

The actions of 1BEP-2, FAULTED SEAM GENERATOR ISOLATION, begin on this page.

[CT]

BOP

[CT-12]

CHECK MAIN STEAMLINE ISOLATION:

All MSIVs and MSIV bypass valves - CLOSED Manually actuate Main Steamline Isolation if not previously completed BOP CHECK IF ANY SG SECONDARY PRESSURE BOUNDARY IS INTACT:

Check pressure in all SGs - ANY SG PRESSURE STABLE OR RISING

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 22 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior

[CT]

ATC/BOP

[CT-17]

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

Determines 1C Steam Generator Pressure Dropping CLOSE 1AF013C and 1AF013G Check FW to faulted SG(s) - ISOLATED:

Associated row on FW ISOLATION MONITOR LIGHTS panel -

LIT FOR FAULTED SG(S)

Verify SG PORV 1MS018C - CLOSED Verify SG blowdown isol valves on faulted SG - CLOSED 1SD002G CLOSED 1SD002H CLOSED Verify SG blowdown sample isol valves on faulted SG - CLOSED 1SD005D CLOSED Verify faulted SG(s) main steamline isolation and bypass valves

- CLOSED ATC/BOP MONITOR AF PUMP SUCTION PRESSURE.

AF PUMP SX SUCT VLVS ARMED alarm (1-3-E7) - NOT LIT ATC/BOP Check secondary radiation normal Reset CNMT Isol Phase A (if necessary)

Sample all SGs for activity Open SG Blowdown Sample Isol valves Request Chem Dept to sample all SGs for activity Check secondary radiation trends NORMAL FOR PLANT CONDITIONS Secondary activity samples NORMAL (WHEN AVAILABLE)

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 23 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior ATC/BOP CHECK IF ECCS FLOW CAN BE TERMINATED:

RCS subcooling - ACCEPTABLE ICONIC DISPLAY -OR-ATTACHMENT A Secondary heat sink Total feed flow to SGs - GREATER THAN 500 GPM -OR-Narrow range level in at least one intact SG - GREATER THAN 10% (31% ADVERSE CNMT)

RCS pressure - STABLE OR RISING PZR level - GREATER THAN 12% (28% ADVERSE CNMT)

US Transition from 1BEP-2 to 1BEP ES-1.1, SI TERMINATION.

Notifies SM of BEP entry Requests Emergency Plan evaluation EVALUATOR NOTE:

Scenario may be terminated after transition into 1BEP ES-1.1 or at the direction of the lead evaluator.

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 24 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior EVALUATOR NOTE:

1BEP-0, Attachment B, SI VERIFICATION actions begin on this page 1BEP-0 main body actions continue after Attachment B section of guide on page 21.

BOP Attachment B action Verify ECCS pumps running CENT CHG pumps RH Both SI pumps NOT RUNNING 1A SI should remain Pull to Lock BOP Attachment B action Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights lit BOP Attachment B action Verify ECCS flow HHSI flow >100 gpm RCS pressure NOT <1700 psig If RCS pressure <1700 psig check SI pp flow > 200 gpm

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 25 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow 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 (already done)

Check if CS is required CNMT pressure (1PR-937 or 1PI-CS934 thru 1PI-CS937) -

HAS NOT RISEN TO GREATER THAN 20 PSIG Determines Group 6 CS monitor lights - are Not LIT 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 SX valves open 1SX169A and B Dispatch operator locally to check operation

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 26 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow Time Position Applicants Actions or Behavior BOP Attachment B action Verify Generator Trip GCB 3-4 and OCB 4-5 open 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 Return fan M/U fan Chilled water pump 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 Control Room pressure greater than +0.125 inches water on 0PDI-VC038

Form 3.3-2 Required Operator Actions Scenario N22-2 Page 27 of 27 Op. Test No.: 2022-301_ Scenario No.: __2___ Event No.: __7 & 8___

Event

Description:

Steam Break outside of CNMT MSIVs fail to close in Auto Symptoms/Cues: Annunciator 1-15-C4 1C S/G FLOW MISMATCH FW FLOW LOW Annunciator 1-15-E2 MS PRESS LOW Increased Steam Flow 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 readings Manual actions taken Failed equipment status Attachment B completed ATC, BOP, US Attachment B action Shutdown unnecessary plant equipment o 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

Form 3.3-1 Scenario Outline Scenario N22-3 Page 1 of 31 Facility:

Byron Station Scenario #:

N22-3 Scenario Source:

Op. Test #:

2022-301 Examiners:

Applicants/

Operators:

Initial Conditions:

IC 73 Unit 1 is at 55%, steady state, Equilibrium Xenon, BOL. On-line risk is green.

Turnover:

Unit 1 is at 55%, steady state, Equilibrium Xenon, BOL. On-line risk is green. Following turnover, the Unit 1 SX pumps will be swapped per BOP SX-9 to allow for Unit 2 surveillance testing. EOs are briefed and standing by for the SX pump swap. 1B CW Pump OOS, expected restoration is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Critical Tasks:

CT Isolate ruptured Steam Generator CT Stop RCS Cooldown Event No.

Malf. No.

Event Type*

Event Description 1

None N

(BOP, US)

Swap Unit 1 SX pumps 2

Smart Scenario Actions C, MC (ATC, US) 1CV121 fails open 3

IMF PB2198 ON IMF FW44 TS (US) 1B AF pump local alarm (Air Box Trip) (21 Cert) 4 Smart Scenario Actions C, MC (ATC, US) 1RY455C drifts partially open (19-2 NRC -

modified) 5 IMF SW01B IMF SW01A IRF SW07 100 C, TS (BOP, US) 1B SX pump trip with 1A SX pump failure to manually start Opens 2SX005 6

None R

(ATC, BOP, US)

Tech Spec 3.0.3 Ramp (19-2 NRC) 7 IMF TH03B

[CT]

[CT]

M (ATC, BOP, US) 1B Steam Generator Tube Rupture (21 NRC) 8 ZDI1CV8100 C, MC (BOP) 1CV8100 fails to close with Phase A coincident with the SI

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 2 of 31 Critical Tasks:

1) CT-18 Isolate ruptured SG Initiating Cue:

Indication and /or annunciation of SGTR in one SG by increasing water level or radiation, and indication and/or annunciation of a reactor trip, and indication and/or annunciation of SI.

Performance Feedback:

Indication of stable or increasing pressure or indication of decreasing or zero feedwater flow rate in the ruptured SG.

Success Path:

Manipulation of controls as required to isolate the ruptured SG.

Measurable Performance Standard:

Close 1B MSIV prior to initiating RCS Cooldown.

2) CT-54 Stop RCS cooldown Initiating Cue:

An operator-initiated cooldown is in progress following a SGTR AND indication of SGTR in a previously intact SG.

Performance Feedback:

Indication of stable RCS temperature, indication of stable of increasing pressure in the intact SG(s),

or indication of stable or increasing pressure in the newly ruptured SG Success Path:

Manipulation of controls as required to stop the operator initiated RCS cooldown.

Measurable Performance Standard:

Stop RCS depressurization prior to a transition to BCA-3.1 SGTR WITH LOSS OF REACTOR COOLANT SUBCOOLED RECOVERY DESIRED occurs. (K/A: EPE 038EA1.30; importance -

4.0/3.8).

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 3 of 31 Scenario N22-3 Summary The scenario will start with Unit 1 is at 55%, steady state, Equilibrium Xenon, BOL. On-line risk is green. Following turnover, the Unit 1 SX pumps will be swapped per BOP SX-9 to allow for Unit 2 surveillance testing. EOs are briefed and standing by for the SX pump swap. 1B CW Pump OOS, expected restoration is 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

Event 1 Swap SX pumps per BOP SX-9 After completing shift turnover and relief, the crew will perform BOP SX-9 SWITCHING A STANDBY ESSENTIAL SERVICE WATER PUMP WITH AN OPERATING ESSENTIAL SERVICE WATER PUMP to swap Unit 1 SX pumps. The BOP will swap SX pumps by starting the 1B SX pump, then stopping the 1A SX pump using peer checks as appropriate.

Event 2 1CV121 fails open During the power ascension, 1CV121 will fail to operate in auto. The valve will fail open, and annunciator 1-9-D3 CHG LINE FLOW HIGH LOW will be lit. The ATC will announce the failure and take manual control of 1CV121 to maintain pressurizer level. Once manual control of pressurizer level is established and with chief examiner discretion, continue to event 3.

Event 3 1B AF pump local alarm (Air Box Trip)

A trouble alarm will come in for the 1B AF Pump. The crew will dispatch an EO to the 1B AF pump. The EO will report that the 1B AF Pump Air Box Tripped annunciator is in alarm on the local control panel. The airbox trip lever will not reset. The SRO will enter Tech Spec 3.7.5 Condition A for the 1B AF pump. Once the US has determined the Tech Spec requirements, at lead examiner discretion, continue to Event 4.

Event 4 1RY455C drifts partially open 1RY455C will fail slowly open. This will cause PZR Pressure to slowly drop. The ATC will respond using BHC-1-RY-P PRESSURIZER PRESSURE MALFUNCTION. The ATC will take manual control of the spray valve and close it. The ATC is anticipated to control Pressurizer Pressure in automatic with the 1RY455B. Once the ATC has closed 1RY455C and has control of RCS pressure, at lead examiner discretion, continue to Event 5.

Event 5 1B SX pump trip with 1A SX pump failure to manually start Once BOP SX-9 is complete, the 1B SX pump will trip and the 1A SX pump will fail to start. The SRO will direct the BOP to respond to the SX pump trip per BHC 1-2-A1. The BOP will attempt to start the 1A SX pump, but the 1A SX pump will not start. The BOP will continue the prompt response actions and request Unit 2 to crosstie SX between the units. The crew will dispatch an EO to investigate the 1A and 1B SX pump trips. The SRO will enter Tech Spec 3.7.8 Condition A for both SX pumps and LCO 3.0.3. The crew will brief and begin to shutdown the unit.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 4 of 31 Event 6 Tech Spec 3.0.3 Ramp The crew will perform a Reactivity Brief for a Unit Shutdown. This will be accomplished per BGP 100-4 or 1BGP 100-4T2. The US may request guidance from the Shift Manager on whether to ramp immediately, as the TS 3.0.3 actions allow for an hour to take action and up to an additional 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> to be in Mode 3.

Events 7 & 8 Steam Generator Tube Rupture and 1CV8100 fails to close on Phase A A 600 gpm tube rupture will occur on 1B Steam Generator. The crew will identify the ruptured SG and initiate a manual RX Trip, enter 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1, and manually actuate a Safety Injection, if auto Safety Injection has not yet occurred depending on timing of crew actions. The crew will transition to 1BEP-3 STEAM GENERATOR TUBE RUPTURE at Step 13 of 1BEP-3. 1CV8100 will fail to close on the Phase A signal generated coincident with the Safety Injection. 1CV8100 will need to be closed in manual per 1BEP-0 Attachment B.

The scenario can be terminated when the crew Stops the depressurization per 1BEP-3 Step 13 or transitions to 1BCA-3.1.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 5 of 31 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, NRC EXAM Security Checklist.

Establish the conditions of IC 73, 55% power, BOL, equilibrium xenon (IC 16)

Place Simulator in RUN Initiate Smart Scenario:

Open SMART SCENARIO (Extreme Ace icon)

Open file Scenario N22-3 Scenario.ssf Click on the MODE button (near top of screen) and pick EXECUTE Click on the PLAY button (bottom left of screen)

Verify Simulator Setup conditions automatically load Verify the following are included in the Smart Scenario:

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 6 of 31 Ensure the following equipment is aligned 1A SX Pump running Set BAT Flow Controller to 14.7 for 937 ppm boron Ensure REMA is available at the Unit Desk 1B CW Pump OOS Place INFO card on 1CW01PB C/S Place INFO card on 1CW001B Provide copies of the following documents:

BOP SX-9 SWITCHING A STANDBY ESSENTIAL SERVICE WATER PUMP WITH AN OPERATING ESSENTIAL SERVICE WATER PUMP

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 7 of 31 Turnover Information Unit 1 is at 55% BOL 626 MWe RCS boron concentration is 937 ppm Control bank D @ 150 steps 1B CW Pump is OOS, expected restoration in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Start 1B SX Pump and secure 1A SX Pump per BOP SX-9. EOs are briefed and standing by for the SX pump swap.

Online Risk is Green

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 8 of 31 INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT 1: SWAP UNIT 1 SX PUMPS If asked as an EO, 1SX143B, 1SX2179B, and 1SX2180B are open.

When requested as an EO to start both SX pumps aux lube oil pumps, use Smart Scenario actions, Event 1a 1A SX Pump AOP and Event 1b 1B SX Pump AOP and select, Release.

As an EO, report a good start of the 1B SX pump and a good shutdown of the 1A SX pump.

After reporting the status of the pumps, or as directed by the crew, secure the SX pumps aux lube oil pumps, use Smart Scenario actions, Event 1a 1A SX Pump AOP off and Event 1b 1B SX Pump AOP off, and select, Release.

When requested as an EO, report 1B SX pump lube oil temperature at 100°F and 1SX01FB, 1B SX strainer, control switch in AUTO.

If requested as EO, report SX flow through the U0 CC HX at 10800 GPM.

As SM, acknowledge the SX pump swap completion.

Event 2: 1CV121 fails open At Lead Evaluators cue, use Smart Scenario actions, Event 2 1CV121, and select, Release.

As SM, acknowledge the failure and request for maintenance support. Acknowledge US will evaluate on-line risk and write IR.

Event 3: 1B AF pump local alarm (Air Box Trip)

At Lead Evaluators cue, use Smart Scenario to actuate 1B AF pump local alarm (Air Box Trip) annunciator by right clicking on the box titled, Event 3 1B AF pump local alarm, and select, Release.

Ensure MF PB2198 ON and MF FW44 are inserted to cause the 1B AF pump local alarm/trip.

If dispatched as an EO to investigate the 1B AF pump local alarm, wait two minutes, then right click on the box titled, Event 3B AF Panel Local Reset, and select, Release. Report that the 1B AF Pump Air Box Tripped alarm is in and the air box is failed closed.

If requested to push the reset button at 1AF01J, report no change in 1B AF pump status.

Request permission to reset the air box. When given permission to reset the air box, wait two minutes and then report that the airbox cannot be reset.

Acknowledge as System Engineering and Maintenance to assist in reopening the air box.

As SM, acknowledge Tech Spec entry 3.7.5, the failure, and request for maintenance support.

Acknowledge US will evaluate on-line risk and write IR.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 9 of 31 Event 4: 1RY455C drifts partially open Then use Smart Scenario to initiate 1RY455C drifting open by right clicking on the box titled, Event 4, 1RY455C, and select, Release.

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

Event 5: 1B SX pump trip with 1A SX pump failure to manually start At Lead Evaluators cue, use Smart Scenario to trip 1B SX pump by right clicking on the box titled, Event 5 SX Pump, and select, Release.

As the U2 NSO, when requested, respond via radio or page, to perform BHC 1-2-A1 actions.

Report that BOTH U-2 SX pumps are running.

2SX005 is open.

As the EO, if dispatched to investigate 1A SX pump breaker, wait 2 minutes and report Phase A overcurrent flag on 1A SX pump breaker cubicle (Bus 141, cubicle 2). If dispatched to check 1B SX pump, report 1B SX pump breaker has a ground overcurrent flag.

If dispatched as an EO to investigate 1A and 1B SX pumps, wait 3 minutes and report no damage or abnormal conditions at either pump. Report neither pump is rotating, if asked.

If contacted as Rad Waste Operator, report no abnormal Aux Building sump indications.

If asked as U-2 NSO, 2SX033 and 2SX034 are open.

If contacted as U-2 NSO, report 2A/2B SX pump amps are 160 amps each, each pumps SX discharge pressure is 95 psig and U-2 CC HX outlet temperature, 2TI-674, is 84°F.

As SM, acknowledge the trip of 1A and 1B SX pumps, Tech Spec 3.7.8 Condition A and Tech Spec 3.0.3 entry, requests for on-line risk assessment, maintenance support and IR initiation.

Event 6: LCO 3.0.3 Ramp As SM, once the crew determines a 3.0.3 ramp is required, direct the US to begin the ramp As SM, acknowledge the reactivity plan and concur with the ramp.

Acknowledge as Generation Dispatch, the initiation of ramp.

Event 7 & 8: Steam Generator Tube Rupture and 1CV8100 fails to close on Phase A

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 10 of 31 At Lead Evaluators cue, use Smart Scenario to initiate 1B Steam Generator Tube Rupture by right clicking on the box titled, Event 7 SG Tube Rupture, 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 1BEP-3.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 11 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3 Event No.: __1___

Event

Description:

Swap Unit SX Pumps Symptoms/Cues: From turnover, swap SX pumps per BOP SX-9, SWAPPING ESSENTIAL SERVICE WATER PUMPS Time Position Applicants Actions or Behavior BOP Refer to BOP SX-9 and perform the following actions:

Verify/Open 1SX001B, 1B SX Pump Suction Valve.

Verify/Open 1SX0016B, RCFC 1B/1D SX Inlet Valve and 1SX027B, RCFC 1B/1D SX Outlet Valve.

Contact EO to start the 1A & 1B SX pump aux lube oil pumps.

Start 1B SX pump at 1PM06J.

Check amps on 1A & 1B SX pumps approx. equal.

Stop 1A SX pump at 1PM06J.

Check 1B SX pump discharge pressure < 112 psig.

Request EO check 1B SX pump lube oil temperature, 1B SX strainer, control switch in AUTO.

Contact EO to stop the 1A & 1B SX pump aux lube oil pumps.

Verify 4 RCFCs are running.

Maintain 1SX027A open.

Monitor CC HX temperatures and throttle 0/1SX007 as needed.

Inform US that BOP SX-9 is complete.

US Acknowledge SX pump swap report.

Notify SM that BOP SX-9 is complete.

EVALUATOR NOTE:

After the actions for swapping SX pumps are complete, and with lead examiners concurrence, proceed with Event 2.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 12 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: _ N22-3__ Event No.: __2___

Event

Description:

1CV121 fails open Symptoms/Cues: Annunciator 1-7-A2 RCP SEAL WTR INJ FLTR DELTA P HIGH Annunciator 1-9-D3, CHG LINE FLOW HIGH/LOW PZR level rising Time Position Applicants Actions or Behavior ATC Identify 1CV121 is failed open.

Report failure to SRO.

ATC Take manual control of 1CV121 and reduce demand to restore level.

US Notify Shift Manager of plant status ATC Monitor RMCS during automatic VCT makeup:

Proper flow on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110) on recorder 1FR-0110.

EVALUATOR NOTE:

After the 1CV121 is in manual and the ATC has control of charging flow and PZR level, and with lead examiners concurrence, continue with the Event 3.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 13 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __3___

Event

Description:

1B AF pump local alarm (Air Box Trip)

Symptoms/Cues: Annunciator 1-3-C6, AF PUMP DIESEL TROUBLE Time Position Applicants Actions or Behavior BOP

• Reference BAR 1-3-C6 and perform the following:

Dispatch EO to investigate local alarm.

Notify SRO/team of alarm.

Request EO to push reset button on 1AF01J.

Request EO to verify air box intake damper not tripped closed.

• Place the 1B AF pump control switch to PULL TO LOCK.

US Notify Engineering/Maintenance to assist in resetting the tripped air box on 1B AF pump.

Declare the 1B AF pump inoperable and enter Tech Spec 3.7.5 Condition A.

Notify Shift Manager of plant status, Tech Spec entry, request for risk assessment and IR request.

US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure.

(RF 6a) Recognize malfunction of TS Related Component (RF 6b) Locate/Determine Applicable LCOs TS 3.7.5 Auxiliary Feedwater System (RF 6c) CONDITION, REQUIRED ACTION, and COMPLETION TIME CONDITION A, One AF Train inoperable o A.1 RA -Restore AF Train to OPERABLE status CT - 72 Hours EVALUATOR NOTE:

After the US determines the applicable TS, and with lead examiners concurrence, continue with the Event 4.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 14 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __4___

Event

Description:

1RY455C fails open Symptoms/Cues: Annunciator 1-12-C1 PZR PRESS CONT DEV LOW HTRS ON Annunciator 1-10-E4 OVATION SYSTEM TROUBLE PZR Pressure dropping 1RY455C opening Time Position Applicants Actions or Behavior ATC Respond per BHC-1-RY-P PRESSURIZER PRESSURE MALFUNCTION Place affected controller (1PK-455C) to manual Close 1RY455C Adjust PZR Pressure to pre-failed value Monitor PZR Pressure and verify 1RY455B functioning properly in auto o Attempt to place 1PK-455C to Auto when pressure stable or trending to stable EVALUATOR NOTE:

The ATC may opt to leave the controller for 1RY455C in Manual and Closed. This is acceptable and has no impact on the event or the remainder of the scenario.

US Contact SM of procedure entry, EAL evaluation, perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure EVALUATOR NOTE:

After the actions for the failed spray valve are complete and with lead examiners concurrence, initiate the Event 5.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 15 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __5___

Event

Description:

1B SX pump trip with 1A SX pump failure to manually start Symptoms/Cues: Annunciator 1-2-A1, SX PUMP TRIP Annunciator 1-2-A2, SX PUMP DSCH HDR PRESS LOW 1B SX pump trip light lit.

Time Position Applicants Actions or Behavior BOP Determine that 1B SX pump has tripped and inform the SRO.

Refer to 1BHC 1-2-A1.

Attempt start of 1A SX pump.

Request U-2 NSO perform actions of 2BHC 1-2-A1 for Unit1 SX Pump trip Open 1SX005 U-2 will start standby SX pump and open 2SX005.

U-2 will request U-1 to open 1SX005 (already open).

Request SRO refer to 1BOA PRI-7, ESSENTIAL SERVICE WATER MALFUNCTION.

o Review BAR 1-2-A1 for SX pump trip:

o Verify voltage on all 3 phases of bus 141 > 3990 volts.

o Place 1A and 1B SX pumps C/S to Pull to Lock.

ATC, BOP, US o Crew may elect to enter 1BOA PRI-7 ESSENTIAL SERVICE WATER MALFUNCTION.

Dispatch EOs to investigate status of 1A and 1B SX pump and breaker.

EVALUATOR NOTE:

The BAR states 1BOA PRI-7 ESSENTIAL SERVICE WATER MALFUNCTION if required. It is not required to address the event.

SRO Notify SM of plant status and procedure entry.

Request SM evaluation of Emergency Plan conditions.

Enter/implement 1BOA PRI-7 and direct operator actions to establish the following conditions:

ATC Monitor RCP seal cooling:

At least one of the following available:

o Seal injection flow to all RCPs.

o RCP thermal barrier CC water flow low alarms not lit.

Monitor RCP temperatures:

Lower radial bearing < 225°F.

Seal outlet < 235°F.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 16 of 31 Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __5___

Event

Description:

1B SX pump trip with 1A SX pump failure to manually start Symptoms/Cues: Annunciator 1-2-A1, SX PUMP TRIP Annunciator 1-2-A2, SX PUMP DSCH HDR PRESS LOW 1B SX pump trip light lit.

Time Position Applicants Actions or Behavior SRO Check for excessive leakage in Aux Building:

Contact Radwaste to monitor Aux Building sumps.

Annunciator SX PUMP SUCT VLV PIT LEVEL HIGH (1 D2) - NOT LIT.

BOP Check status of SX pumps at 1PM06J:

NONE running - GO TO Attachment A.

Start an additional U-2 SX pump (already performed).

Crosstie SX system (already performed).

Monitor U-2 SX system:

U-2 SX pump motor amps < 180 amps.

U-2 SX pump discharge pressure > 90 psig.

CC HX outlet temperature < 105°F.

Check chiller operation:

At least ONE MCR chiller running BOP Check SX discharge temperature between 50°F and 80°F Check SX Tower basin levels stable Check CC outlet temperatures < 105°F at 1PM06J (1TI-674, 0TI-675).

Check SX System intact Charging pump oil temperature trends Check Table A running equipment temperatures less than limit Check for SX leakage into containment at 1PM06J:

Annunciator CNMT DRAIN LEAK DETECT FLOW HIGH (1-1-A2) - NOT LIT.

Check Aux Building indications normal SRO Notify the SM of the status of the 1A and 1B SX pumps.

Enter Tech Spec 3.7.8 Condition A and Tech Spec 3.0.3 (plant shutdown required).

Notify the SM to perform risk assessment, initiate IR and contact maintenance to investigate/correct failure.

EVALUATOR NOTE:

After the actions for the 1A SX pump trip are complete, and with lead examiners concurrence, initiate the Event 6.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 17 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __6___

Event

Description:

LCO 3.0.3 Ramp Offline Symptoms/Cues: Determine inoperable SX pumps requires LCO 3.0.3 with a unit shutdown Time Position Applicants Actions or Behavior SRO Perform pre-job brief per OP-BY-101-0001 ATTACHMENT 9 REACTIVITY CHANGE BRIEF SHEET.

Implement actions of 1BGP 100-4T2, LOAD CHANGE INSTRUCTION SHEET FOR POWER REDUCTION > 15% IN ONE HOUR Inform SM of the LCO 3.0.3 ramp.

ATC Verify rod position and boron concentration.

Conducts reactivity brief Initiate boration using BOP CV-6 or BOP CV-6T1 Place Make-up Control Switch to STOP Place Mode Select Switch to BORATE Set BA controller setpoint to desired BA flowrate.

Set BA totalizer to desired value.

Place Make-up Control Switch to START.

Verify 1CV110B opens Verify 1CV110A throttles open Verify Boric Acid Transfer Pump running If desired, adjust 1LK-112, VCT level controller, setpoint to control VCT level.

When desired boration achieved, Verify Make-up Controller is OFF Verify 1CV110B closed, 1CV110A closed and Boric Acid Transfer Pump stopped.

Monitors effects of boration o

Turn on PZR backup heaters.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 18 of 31 Op. Test No.: 2022-301_ Scenario No.: __N22-3__ Event No.: __6___

Event

Description:

LCO 3.0.3 Ramp Offline Symptoms/Cues: Determine inoperable SX pumps requires LCO 3.0.3 with a unit shutdown Time Position Applicants Actions or Behavior BOP Lower turbine load at 1PM02J or OWS drop 210 by performing the following:

• Select SETPOINT.

• Enter desired MWs into REF DEMAND window.

• Select LEFT ENTER.

• Verify correct value in REFERENCE DEMAND window.

• Enter desired MW/min into the RATE window.

• Select RIGHT ENTER.

• Select EXIT.

• Inform crew of pending ramp with an UPDATE.

• Select GO/HOLD.

• Verify GO/HOLD button illuminates orange.

• Verify HOLD illuminated RED.

• Select GO.

• Verify GO illuminates RED.

• Verify main turbine load begins to lower.

• Monitor MWe and DEHC system response at 1PM02J or OWS drop 210.

ATC/BOP Monitor reactor power and turbine load lowering.

Monitor NIs, Tave, I, PZR pressure/level at 1PM05J.

Monitor MW and DEHC system response at 1PM02J or OWS 210 During boration, monitor/perform the following at 1PM05J, Ovation and/or PPC:

o Monitor VCT level.

o Verify boration auto stops at preset value.

o Return Reactor Makeup Control System to automatic at current boron concentration.

EVALUATOR NOTE:

After sufficient reactivity control has been observed, with lead examiners concurrence, continue with Event 7.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 19 of 31 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The crew may enter 1BOA SEC-8 STEAM GENERATOR TUBE LEAK UNIT 1 in an attempt to diagnose the size of the leak. If entered, the crew should exit the procedure at Step 1 or 2 and direct a RX trip and Safety Injection and enter 1BEP-0.

ATC, BOP, US

• Recognizes drop in PZR level and pressure

• Recognizes level rise in 1B Steam Generator

• Recognizes rising radiation levels on MS line rad monitors

• Reports failure to US US Acknowledge Steam Generator Tube Rupture failure Directs RX trip and Safety Injection Implements 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 and directs operator actions Notifies SM of 1BEP-0 entry Requests EAL evaluation o Requests STA to control room ATC Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux DROPPING Actuate Safety Injection BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 20 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping 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) - no SI ACTUATED lit (1-BP-4.1) - YES SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open) - YES Determine if SI required:

o Check PZR pressure < 1829 psig o Check Steamline pressure < 640 psig o Check CNMT pressure > 3.4 psig If SI is required: - YES Manually Actuate SI EVALUATOR NOTE:

Crew actions of 1BEP-0 continue below.

BOP actions of 1BEP-0, Attachment B continue on page 26.

ATC/BOP Verify AF system:

1A AF pumps -RUNNING 1B AF - Pump inop, switch in Pull to Lock 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 - NO

- RED ALARM for 1B Main Steam Line, MSIV Rm 1RT-AR022/1RT-AR023 Narrow range levels - NOT RISING IN AN UNCONTROLLED MANNER - NO - 1B Steam Generator level rising

• Manually close 1AF013B, 1AF013F, 1AF005B, 1AF005F

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 21 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC/BOP 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 Isol 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 Check RCS temperature:

RCPs - ANY RUNNING Tave between 552°F and 561°F RCPs -NONE RUNNING Tcold between 552°F and 561°F Control RCS temperature by performing the following:

Temperature greater than 561°F Verify/open Steam Dumps and / or SG PORVs as necessary Raise AF flow as necessary Temperature less than 552°F Verify/Close Steam Dumps and SG PORVs Reduce AF flow as necessary while maintaining 500 gpm total flow IF less than 10% (31% ADVERSE CNMT)

Actuate Main Steam Isolation as necessary

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 22 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping 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. - NO SG Blowdown Liquid radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT. - NO Main Steamline radiation - HAS REMAINED LESS THAN ALERT ALARM SETPOINT - NO EVALUATOR NOTE:

The crew actions of 1BEP-3, STEAM GENERATOR TUBE RUPTURE UNIT 1 begin following this note.

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

Notifies SM of BEP entry Requests Emergency Plan evaluation Request STA to come to the control room 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 Manually trip RCPs if conditions are met

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 23 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC/BOP Identify Ruptured SG - Identify 1B SG as ruptured Unexpected rise in any SG narrow range level Main Steamline radiation trend (PPC or Rad Monitoring System) - NOT NORMAL FOR PLANT CONDITIONS High activity from an SG sample

[CT]

ATC/BOP

[CT-18]

Isolate Flow from Ruptured SG Verify ruptured SG PORV controller in AUTO

• 1MS018B Controller in Auto Check ruptured SG PORV CLOSED 1MS018B CLOSED Verify ruptured SG blowdown isolation valves CLSOED 1SD002E 1SD002F Close ruptured SG MSIV and MSIV bypass valve 1MS001B 1MS101B Check PORV on intact SGs - AVAILABLE FOR RCS COOLING 1MS018A, 1MS018C, and 1MS018D Check Ruptured SG level Narrow range level - GREATER THAN 10% (31% ADVERSE CNMT)

Close ruptured SG AF isolation valves and throttle valves 1AF013B 1AF013F 1AF005B 1AF005F ATC/BOP Check ruptured SG pressure Ruptured SG pressure GREATER THAN 330 PSIG - YES

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 24 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC, BOP, US Initiate RCS Cooldown Determine required core exit temperature Determine 516°F Check PZR pressure - LESS THAN 1930 PSIG PZR Low Press SI Block Permissive P LIT Block Steamline Isolation SI Place Steam line SI RESET/BLOCK switches (A and B train) to - BLOCK Dump steam to condenser from intact SG - AT MAXIMUM RATE Check steam dumps - AVAILABLE C-9 permissive light - NOT LIT MSIV(s) or MSIV bypass valves - OPEN Place MS header pressure controller in manual Adjust MS header pressure controller demand signal to zero Place steam dump mode selector switch in STM PRESS mode Adjust MS header pressure controller in manual or auto to initiate cooldown at maximum rate Dispatch an operator with keys to standby 1SI101A and 1SI101B Check average of ten highest core exit TCs - LESS thean required temperature from Step 6a (516°F)

Stop RCS cooldown Maintain average of ten highest core exit TCs - LESS than required temeprature EVALUATOR NOTE:

The crew is allowed to perform 1BEP-3 Steps 7-12 during the cooldown as time allows.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 25 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC, BOP, US Check Intact SG levels Narrow range levels - GREATER than 10%

Control feed flow to maintain narrow range levels - between 30%

and 50%

ATC, BOP, US Check PZR Porvs And Isolation Valves PORV isol valves 1RY8000A and B - ENERGIZED PORVs 1RY455A and 1RY456-CLOSED PORV isol valves 1RY8000A and B - At least one open ATC, BOP, US Reset SI Dpress both SI reset pushbuttons Verify SI Actuated permissive light - NOT LIT Verify Auto SI Blocked permissive light - LIT ATC, BOP, US Reset Containment Isolation Phase A ATC, BOP, US Establish Instrument Air to Containment Check SACs running - yes Open instrument air CNMT isolation valves - 1IA065 and 1IA066 ATC, BOP, US Check if RH pumps should be stopped RH pumps - any running with suction aligned to the RWST RCS pressure - GREATER than 325 psig Stop RH pumps and place in Standby ATC, BOP, US Check ruptured SG pressure Ruptured SG pressure - stable or rising - yes Check RCS subcooling Acceptable - yes

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 26 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC, BOP, US Depressurize RCS to Minimize break flow and refill PZR Normal spray available - 1D RCP and 1RY455B - yes Return to Step 1 - Check if RCPs should be stopped EVALUATOR NOTE:

The crew may perform Step 17 of 1BEP-3 and open the PZR PORVs for additional capacity to reduce pressure. This a strategy encouraged by Byron Operations, but is not required. The PZR PORVs will need to be closed with the spray valves in order to stop the depressurizatioin.

ATC, BOP, US Spray Pzr With Maximum Available Spray Until Any Of The Following Conditions - Satisfied:

Both Of The Following:

RCS Pressure - Within 400 Psig Of Ruptured SG(s)

Pressure Przr Level - Greater Than 37% (50% Adverse Cnmt)

Both Of The Following:

RCS Pressure - Less Than Ruptured Sg(S) Pressure Pzr Level - Greater Than 12% (28% Adverse Cnmt)

Pzr Level - Greater Than 69%

Rcs Subcooling - Not Acceptable Per Iconic Display Or Attachment A (Page 52) And Figure 1bep 3-1 (Page 49)(Normal)

ATC, BOP, US Close spray valves Close 1RY455B and 1RY455C

[CT]

ATC, BOP, US

[CT-54]

Check RCS pressure rising EVALUATOR NOTE:

The scenario will be terminated after the crew has terminated the depressurization and RCS pressure is stable or rising.

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 27 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior EVALUATOR NOTE:

1BEP-0, Attachment B, SI VERIFICATION actions begin on this page. 1CV8100 will not close with the Phase A. The valve will need to be manually closed. This not a critical task.

BOP Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps RH pumps SI pumps 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 above 1700 psig at this step.

BOP Attachment B action VERIFY ECCS FLOW HHSI flow >100 gpm RCS pressure NOT <1700 psig

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 28 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights Verify CNMT isolation Phase A Group 3 CNMT isolation monitor lights - not all lit Manually actuate Phase A CNMT isolation - valve did not close Manually close 1CV8100 Verify CNMT Ventilation isolation Group 6 CNMT Vent Isol monitor lights Verify CC Pumps Verify SX Pumps 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 - Start 1B DG SX valves open 1SX169A and B Dispatch operator locally to check operation

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 29 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior 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

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 30 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED Two inaccessible filter plenums aligned with charcoal absorbers online Plenum A fan 0VA03CB running Align plenums and start fans as necessary to get 2 plenums online with one fan running per plenum Damper 0VA022Y not fully closed 0VA020Y 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

Form 3.3-2 Required Operator Actions Scenario N22-3 Page 31 of 31 Op. Test No.: 2022-301_ Scenario No.: N22-3_ Event No.: __7 & 8___

Event

Description:

1B Steam Generator Tube Rupture, 1CV8100 fails to close in auto Symptoms/Cues: Rising level on 1B SG Yellow / red radiation alarms on the RMS for the 1AR22J PZR pressure / level dropping Time Position Applicants Actions or Behavior ATC, BOP, US 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 21.

The crew actions for of 1BEP-0, Attachment B, SI VERIFICATION begin on page 28.

The crew actions for of 1BEP-3 STEAM GENERATOR TUBE RUPTURE begin on page 23.

Form 3.3-1 Scenario Outline Scenario N22-4 Page 1 of 34 Facility:

Byron Station Scenario #:

N22-4 Scenario Source:

Op. Test #:

2022-301 Examiners:

Applicants/

Operators:

Initial Conditions:

IC-74; 75.0% power 917 MW, MOL, steady state, 917 ppm boron, equilibrium xenon, CBD at 171 steps.

Turnover:

1B CW pump is OOS for an intake bay inspection; it is expected back in service in two days. 1A RH pump is OOS for breaker replacement, expected return in 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />. Following turnover, the shift manager requests the BOP to perform 1BOSR EH-M2. A power ascension to 1120 MWe at 1.6 MWe/min will be initiated when the surveillance is completed. Online risk is green.

Critical Tasks:

CT Manually actuate SI CT Manually start at least one low head ECCS pump Event No.

Malf. No.

Event Type*

Event Description Preload IOR ZDI1CW01PB PTL IOR ZDI1CW001B CLS MRF ED093B OPEN ZDI1RH01PA PTL ED049C OPEN IMF RP30A IMF RP30B RP28C CW Pp 1B Out of Service CW Pp 1B discharge valve closed RH pump 1A OOS SI Fails to actuate in auto 1B RH Pump fails to start in auto 1

None N

(BOP, US) 1BOSR EH-M2 (19 Cert) 2 None R

(ATC, BOP, US)

Ramp up to 1120 MWe at 1.6 MWe/min (19 NRC) 3 PN2028 PN2029 C

(ATC, US) 1B RCP #3 Seal Standpipe level low (19 Cert) 4 IMF SW06C IOR ZDI0WS01PB C, MC (BOP, US) 0C WS Pump trip 0B WS Pump fails to start in auto 5

IMF RH05D TS (US)

Loss of 1LT-933 6

IMF ED09B TS (US)

Loss of Bus 131Z 7

[CT]

[CT]

RMF ED123 OPEN RMF ED122 OPEN IMF TH06B M

(ATC, BOP, US)

MC (ATC)

MC (BOP)

Loss of Bus 143 (21 Cert)

Cold Leg B RCS LOCA after Reactor trip SI fails to actuate in Auto (19 Cert) 1B RH pp fails to auto start (21 Cert) 8 ED071N C

(ATC, BOP, US) 1SI8811B loses power (21 CERT)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Tech Spec, (MC)Manual Control

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 2 of 34 Critical Tasks:

1)

CT-2 Manually actuate Safety Injection (SI)

Initiating Cue:

Reactor trip with valid SI required but not automatically actuated.

Performance Feedback:

Indication that at least one train of SI is actuated by verifying ECCS equipment in operation.

Success Path:

Manipulation of controls as required to manually initiate a Safety Injection.

Measurable Performance Standard:

Manually actuate Safety Injection prior to transition out of BEP-0 (K/A: EPE 011EA1.04; importance - 4.3).

2)

CT-5 Manually start at least one low-head ECCS pump before transition out of E-0 Initiating Cue:

Indication and/or annunciation that low-head ECCS pumped injection is required AND Indication and/or annunciation that no low-head ECCS pump is injecting into the core Performance Feedback:

Indication that at least one RH Pump, low-head ECCS pump, is in operation Success Path:

Manipulation of controls as required to start at least one low-head ECCS pump Measurable Performance Standard:

Indication that at least one low-head ECCS pump is injecting, prior to exiting BEP-0 (K/A: EPE 011EA1.052; importance - 4.2/4.3).

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 3 of 34 Scenario N22-4 Summary The scenario will start with Unit 1 is at 75%, steady state, Equilibrium Xenon, MOL. 1B CW pump is OOS for an intake bay inspection; it is expected back in service in two days. 1A RH pump is OOS for breaker replacement, expected return in 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />. Following turnover, the shift manager requests the BOP to perform 1BOSR EH-M2. A power ascension to 1120 MWe at 1.6 MWe/min will be initiated when the surveillance is completed. Online risk is green.

Event 1 Perform 1BOSR EH-M2 After completing shift turnover and relief, the crew will perform 1BOSR EH-M2 UNIT ONE EH PUMP OPERABILITY MONTHLY SURVEILLANCE. The BOP will test the EH pumps auto start capabilities using peer checks as appropriate.

Event 2 Ramp up to 1120 MWe As directed by the turnover, the crew will initiate a ramp up to 1120 MWe at 1.6 MWe/min. The crew will hold a reactivity brief to review material prepared prior to the beginning of the scenario.

The crew will ramp per 1BGP 100-3. After the ramp is initiated and sufficient reactivity maneuvering is observed, and at lead examiner discretion, continue with Event 3.

Event 3 1B RCP #3 Seal Standpipe level low Annunciator 1-7-B7 RCP 1B STANDPIPE LEVEL LOW will alarm. The crew must identify that the fill valve has not opened. They must open the fill valve and the alarm will clear. Once the alarm is clear, at lead examiner discretion, continue to Event 4.

Event 4 0C WS pump will trip and 0B WS pump will fail to start in auto 0C WS Pump will spuriously trip. 0B WS pump will fail to auto start. The crew must respond per BAR 0-38-A10 and start the 0B WS Pump to restore system pressure. Once the 0B WS Pump is started and system pressure is stable, at lead examiner discretion, continue to Event 5.

Event 5 Loss of 1LT-933 1LT-933 RWST Level indicator will fail to 0%. The crew will identify the failure. The crew must enter 1BOA INST-2, as referenced in BAR 1-6-B7, to address the failure. The US must determine Tech Spec 3.3.2 Conditions A and K apply per Function 7.b. Once the US has made the Tech Spec determination, at lead examiner discretion, continue to Event 6.

Events 6 Loss of Bus 131Z MMC 131Z and 131Z-A feed breaker will trip open and de-energize MCC 131Z and 131Z-A.

This will impact SX Tower fan power supplies and vibration monitors. The crew must identify the impact of the electrical failure and complete actions per the BAR. The US must determine Tech Spec 3.8.9 DISTRIBUTION SYSTEMS - OPERATING Condition A. Once the US has made the Tech Spec determination, at lead examiner discretion, continue to Event 7.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 4 of 34 Event 7 & 8 Loss of Bus 143, Large Break LOCA, and Loss of Containment Sump Recirc The feed breaker to Bus 143 will trip open. This will cause a loss of Bus 143. The loss of Bus 143 will cause the 1A and 1C CW Pumps to lose power. The 1B CW Pump was OOS per the Turnover from the beginning of the scenario. The loss of all three CW pumps will create a Condenser loss of vacuum. The US must direct a RX trip and Turbine trip to address the loss of vacuum and enter 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1. Note Steam Dumps will be unavailable after this point. A Large Break LOCA will occur one minute and 30 seconds after the reactor is Manually tripped. Safety Injection will fail to actuate in auto and the crew must manually actuate Safety Injection. The crew must continue in, or return to, 1BEP-0 to complete actions to identify the LOCA and transition to 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT UNIT 1. 1B RH Pump will fail to start in auto and must be started in manual. One minute and 30 seconds after the start of the 1B RH Pump, 1SI8811B CNMT SUMP ISOLATION VALVE breaker will trip open and de-energize the valve. The crew will determine that the plant is not capable of cold leg recirculation when checking plant status. The US will direct entry into 1BCA-1.1 LOSS OF EMERGENCY COOLANT RECIRCULATION.

The scenario can terminate at the 1BCA-1.1 entry or at 1BCA-1.1 Step 2 after dispatching personnel to restore power to 1SI8811B.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 5 of 34 SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, Attachment 3, NRC EXAM Security Checklist.

Establish the conditions of IC 74, 75% power, MOL, equilibrium xenon (IC 18)

Place Simulator in RUN Initiate Smart Scenario:

o Open SMART SCENARIO (Extreme Ace icon) o Open file Scenario N22-4 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 ZDI1CW01PB PTL 1B CW Pump Control Switch Pull to Lock o ED052D OPEN 1B CW Pump Breaker Open o ZDI1CW001B CLS 1CW001B 1B CW Pump Discharge Valve Closed o ED093B OPEN 1CW001B Breaker Open o ZDI1RH01PA PTL 1A RH Pump Control Switch Pull to Lock o ED049C OPEN 1A RH Pump Breaker Open o RP28C 1A RH Pump SI Auto Start Relay fail to actuate o RP30A A Train SI fail to actuate o RP30B B Train SI fail to actuate Verify the following are included in the Smart Scenario:

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 6 of 34 Ensure the following equipment is aligned 0A and 0C WS Pumps running 0B WS Pump is Standby 1A EH Pump running Place OOS cards on the following equipment:

1A RH Pump C/S 1B CW Pump C/S 1CW001B C/S 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 EH-M2 UNIT ONE EH PUMP OPERABILITY MONTHLY SURVEILLANCE

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 7 of 34 BOL 5.2 LCOAR ECCS - OPERATING

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 8 of 34 Turnover Information Unit 1 is at 75% MOL 901 MWe RCS boron concentration is 917 ppm Control bank D @ 171 steps 1B CW Pump OOS for intake bay inspection. RTS expected is 2 days.

1A RH Pump OOS for breaker replacement. RTS expected in 14 hours1.62037e-4 days <br />0.00389 hours <br />2.314815e-5 weeks <br />5.327e-6 months <br />.

1BOL 5.2 ECCS - OPERATING in effect for 1A RH pump 1BOSR EH-M2 UNIT ONE EH PUMP OPERABILITY MONTHLY SURVEILLANCE required to be performed this shift.

Ramp Unit 1 up to 1120 MWe after completion of 1BOSR EH-M2.

Protected equipment 1A and1C CW Pumps 1B RH Pump Online Risk is Green

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 9 of 34 INSTRUCTOR/SIMULATOR RUN AID GUIDE EVENT 1: PERFORM 1BOSR EH-M2 When asked as an EO, report Standing by U1 EH pumps. Ready to start testing.

When asked as an EO, report System pressure 2100 psig. System temperature 103 degrees F.

When asked as an EO, report 1B EH Pump started with a local pressure of 2050 psig.

When asked as an EO, report 1A EH Pump started with a local pressure of 2050 psig.

When asked as an EO, report after EH pump swap is complete System pressure 2100 psig.

As SM, acknowledge the completion of the surveillance.

Event 2: Ramp up to 1120 MWe Acknowledge as Chemistry/Rad Protection requests for RCS samples (if required).

As SM, acknowledge the reactivity plan and initiation of the ramp.

Event 3: 1B RCP #3 Seal Standpipe level low At Lead Evaluators cue, use Smart Scenario initiate failure of 1CV180 to open in auto by right clicking on the box titled, Event 3, RCP Standpipe Low, and select, Release.

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

Event 4: 0C WS pump will trip and 0B WS pump will fail to start in auto At Lead Evaluators cue, use Smart Scenario initiate failure of 0C WS pump and failure of the auto start of the 0B WS in auto by right clicking on the box titled, Event 4, WS Pump, and select, Release.

When asked as an EO to check on 0C WS pump, after 4 minutes, report 0C WS is stopped and NOT spinning.

When asked as an EO to check on 0B WS pump after start, report 0B WS pump is running and everything looks normal.

If asked as an EO to check the breaker of the 0C WS pump, report Breaker Bus 243 Cub 9 for the 0C WS Pump has an Overcurrent flag up.

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

Event 5: Loss of 1LT-933 At Lead Evaluators cue, use Smart Scenario initiate failure of channel 1LT-933 by right clicking on the box titled, Event 5, 1LT-933, and select, Release.

As SM, if asked, respond Channel bistables should be placed in bypass.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 10 of 34 As SM acknowledge the failure, Tech Spec entry, on line risk assessment, request for maintenance support, and IR requests Event 6: Loss of Bus 131Z At Lead Evaluators cue, use Smart Scenario initiate failure of channel 1LT-933 by right clicking on the box titled, Event 6, Bus 131Z, and select, Release.

If asked as an EO to investigate the breaker(s), report, after 3 minutes, MCC breaker 131Z Compartment 3A is tripped free and will not close.

If requested, FLS will report Wet Bulb Temperature is 75 degrees F.

As SM acknowledge the failure, Tech Spec entry, on line risk assessment, request for maintenance support, and IR requests.

Event 7& 8: Loss of Bus 143, Large Break LOCA, and Loss of Containment Sump Recirc At Lead Evaluators cue, use Smart Scenario to trip Bus 143 by right clicking on the box titled, Event 7 Bus 143, and select, Release.

Smart Scenario for Event 8 & 9 LOCA and RH will occur automatically after initiation of a manual RX trip.

If asked as an EO to check the breakers of the Bus 143, report ACB 1431 UAT to Bus 143 Feed Breaker has an Overcurrent flag up.

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

If asked as TSO or Shift Manager, Offsite power is available.

As Shift Manager, acknowledge transition to 1BCA-1.1 procedure entry and request for Emergency Plan evaluations.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 11 of 34 Op. Test No.: 2022-301_ Scenario No.: N22-4 Event No.: __1___

Event

Description:

Perform 1BOSR EH-M2 Symptoms/Cues: From turnover, perform 1BOSR EH-M2 Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The evaluator may time compress the 10-minute duration for the EH pumps to run simultaneously. There is no benefit to the scenario or evaluation to allow the pumps to run for 10 minutes to stabilize the system and ensure the reliability of the standby pump.

BOP Refer to 1BOSR EH-M2 and perform the following actions:

Enter running (1A) and standby (1B) pumps on the Data Sheet.

Record system temperature from HMI on Data Sheet.

Record system pressure from HMI on Data Sheet Mark Mode 1 evolution on Data Sheet.

Mark MPT-20 method on the Data Sheet.

Notify EO of pending start.

Depress the EH PP LO PRESS AUTO START TEST pushbutton and auto start 1B EH pump.

Verify pressure and document on Data Sheet.

Allow both pumps to run concurrently for 10 minutes.

Secure the 1A EH Pump.

Notify EO of pending start.

Depress the EH PP LO PRESS AUTO START TEST pushbutton and auto start 1A EH pump.

Secure the 1A EH Pump.

Complete the Data Sheet US o Acknowledge surveillance complete report.

Notify SM that 1BOSR EH-M2 complete.

EVALUATOR NOTE:

After the surveillance is complete, and with lead examiners concurrence, proceed with Event 2.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 12 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __2___

Event

Description:

Ramp up to 1120 MWe at 01.6 MWe/min Symptoms/Cues: Directed at turnover Time Position Applicants Actions or Behavior US Direct raising load to 1120MW at 1.6 MW/min.

Implement actions of 1BGP 100-3T5, LOAD CHANGE INSTRUCTION SHEET FOR RAISING POWER < 15% IN ONE HOUR.

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

ATC Verify rod position and boron concentration.

o Conducts reactivity brief o Initiate dilution using BOP CV-5 or BOP CV-5T1 checklist Select STOP on RMCS Makeup Control Switch Select DIL or ALT DIL on RMCS Mode Select Switch Enter desired amount of Primary Water in the PW/Makeup Totalizer Place RMCS Makeup Control Switch to START o 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.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 13 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __2___

Event

Description:

Ramp up to 1120 MWe at 01.6 MWe/min Symptoms/Cues: Directed at turnover 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.

o 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.

ATC/BOP Monitor reactor power and load ascension:

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

Monitor MW and DEHC system response at 1PM02J or OWS drop 210.

During dilution, monitor the following at 1PM05J, Ovation and/or PPC:

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow counter responding correctly.

Verify dilution auto stops at preset value.

Return Reactor Makeup System to automatic.

EVALUATOR NOTE:

After the ramp is initiated and sufficient reactivity control has been observed, and with lead examiners concurrence, continue with the Event 3.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 14 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: _ N22-4__ Event No.: __3___

Event

Description:

1B RCP #3 Seal Standpipe level low Symptoms/Cues: Annunciator 1-7-B7 RCP 1B STANDPIPE LEVEL LOW Time Position Applicants Actions or Behavior ATC Respond to Annunciator 1-7-B7 Inform US of 1CV180 closed with the alarm present OPEN 1CV180 until annunciator clears US Notify the SM to perform risk assessment, initiate IR and contact maintenance to investigate/correct failure.

EVALUATOR NOTE:

After the annunciator is clear, with lead examiners concurrence, initiate the Event 4.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 15 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __4___

Event

Description:

0C WS pump trip and 0B WS failure to auto start Symptoms/Cues: Annunciator 0-38-A10 WS PUMP TRIP OR AUTO START Annunciator 0-38-B10 WS HDR PRESS LOW 0C WS Pump disagreement light LIT Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The crew may reference, or enter, 0BOA SEC-5 WS SYSTEM MALFUNCTION UNIT 0. This is not required to address the failure. The steps to address the issue in the BOA parallel the BAR response.

BOP Determine that 0C WS pump has tripped and inform the SRO.

Refer to BAR 0-38-A10 Determine that 0B WS pump did not auto start with pressure less than 75 psig.

Manually start the 0B WS pump Dispatch an operator to check on the WS pumps Determine the cause of the pump trip and place 0C WS pump C/S in Pull to Lock EVALUATOR NOTE:

Annunciator 1-10-E4 OVATION SYSTEM TROUBLE may alarm during this event due to Generator WS Controller slow response changing WS system pressure.

US Notify the SM to perform risk assessment, initiate IR and contact maintenance to investigate/correct failure.

EVALUATOR NOTE:

After the 0B WS is started and WS system header pressure stabilized, and with lead examiners concurrence, initiate the Event 5.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 16 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-4__ Event No.: __5___

Event

Description:

Loss of 1LT-933 Symptoms/Cues: Annunciator 1-6-C7 RWST LEVEL LOW Annunciator 1-6-B7 RWST LEVEL LO-2 Annunciator 1-6-A7 RWST LEVEL LO-3 Time Position Applicants Actions or Behavior ATC Respond to Annunciator 1-6-B7.

Determine channel 1LI-933 has failed low Inform US of failed channel US Direct entry into 1BOA INST-2.

Directs WEC to dispatch personnel to BYPASS/TRIP bistables Notify the SM to perform risk assessment, initiate IR and contact maintenance to investigate/correct failure.

US (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.

A.1

• RA - Enter the Condition referenced in Table 3.3.2-1 for the channel (s) or train(s). (Function 7.b)

• CT - Immediately CONDITION K, One channel inoperable.

K.1 RA - Place channel in trip.

CT - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> EVALUATOR NOTE:

After the US has made the Tech Spec call, with lead examiners concurrence, continue with Event 6.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 17 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: __N22-4__ Event No.: __6___

Event

Description:

Loss of Bus 131Z Symptoms/Cues: Annunciator 1-21-A10 BUS 131X/131Z MCC FD BRKR TRIP Annunciator 0-37-E6 SX CLG TWR FAN VIBRATION HIGH Annunciator 0-37-D6 SX CLG TWR FAN GEARBOX OIL PRESS LOW ACB 1415Z disagreement light LIT Time Position Applicants Actions or Behavior EVALUATOR NOTE:

Entry into 1BOA ELEC-9 LOSS OF 480 MCC UNIT 1 is not required. The BOA is a reference for equipment impacted by the loss. The actions taken per the BARs will address the malfunctions.

BOP

• Determine Loss of Bus 131Z

• Dispatch operator to determine status of the breaker BOP Verify only 2 Nonaccessible VA plenums aligned for operation Dispatch operator to switch the vibration monitor to reserve power for SX Tower vibration monitor EVALUATOR NOTE:

Due to the loss of the bus, two SX Tower fans will lose power, but continue to indicate as running because of C/S positioning. The crew may recognize the situation and take actions to open 0SX163C & D and start the associated fans.

This not required at this time and will be addressed later in the scenario.

US

• Notify SM of failure, Tech Spec entry, request risk evaluation and IR initiation.

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 A, One AC electrical power distribution subsystem inoperable.

A.1

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

• CT - 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 18 of 34 Op. Test No.: 2022-301_ Scenario No.: __N22-4__ Event No.: __6___

Event

Description:

Loss of Bus 131Z Symptoms/Cues: Annunciator 1-21-A10 BUS 131X/131Z MCC FD BRKR TRIP Annunciator 0-37-E6 SX CLG TWR FAN VIBRATION HIGH Annunciator 0-37-D6 SX CLG TWR FAN GEARBOX OIL PRESS LOW ACB 1415Z disagreement light LIT Time Position Applicants Actions or Behavior EVALUATOR NOTE:

After US has made Tech Spec determination, with lead examiners concurrence, continue with the next Events 7.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 19 of 34 Form 3.3-2 Required Operator Actions Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The crew may enter into 1BOA SEC-3 LOSS OF CONDENSER VACUUM UNIT 1 when the CW pumps initially trip. This is an acceptable flowpath. It will delay the RX trip, but the RX trip is not required until condenser vacuum exceeds 8 inches HG Absolute.

BOP o Respond to Annunciator 1-17-A13.

Determine a loss of Bus 143 Inform US of bus loss EVALUATOR NOTE:

The loss of the bus impacts several components that may slow subsequent actions in 1BEP-0. Most noted will be TSLBs (FW Isolation indications) and Boric Acid Transfer pump.

ATC, BOP, US Identify less than 2 CW pumps running Recognize imminent loss of condenser vacuum EVALUATOR NOTE:

ACB 1432 has failed to auto close. If attempted to manually close, the breaker will close and re-energize the bus. This is not an expected action as it is not directed by procedure.

US Acknowledge Loss of condenser vacuum Direct RX trip Directs entry into 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 Notify the SM to perform risk assessment, initiate IR and contact maintenance to investigate/correct failure.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 20 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The Large Break LOCA will initiate 90 seconds after the manual RX trip is initiated. The 1SI8811B CNMT SUMP ISOLATION VALVE breaker will open 90 seconds after the auto start of the 1B RH pump.

EVALUATOR NOTE:

Actions for 1BEP-0 REACTOR TRIP OR SAFETY INJECTION UNIT 1 are identified in the following steps.

[CT]

ATC

[CT-1]

Manually Reactor Trip Actuate RX trip from MCR US Implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and directs operator actions.

Notifies SM of 1BEP-0 entry.

Requests Emergency Plan evaluation.

ATC Verify Reactor Trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - NO, Bypass Breaker TSLB not available for confirmation Neutron flux DROPPING Manual trip both RX trip switches BOP Verify Turbine Trip Turbine throttle valves - CLOSED Turbine governor valves - CLOSED BOP Verify power to 4KV busses Bus 141 - ENERGIZED Bus 142 - ENERGIZED

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 21 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior EVALUATOR NOTE:

It is possible for the crew to enter 1BEP ES-0.1 REACTOR TRIP RESPONSE UNIT 1 prior to actuation of the LOCA. The crew will be required to recognize the LOCA and return to 1BEP-0 and actuate a Safety Injection. Auto actuation for SI is failed.

[CT]

ATC

[CT-2]

Check SI status SI actuated SI First OUT annunciator lit (1-11-B1, 1-11-C1, 1-11-D1, 1-11-E1) - no SI ACTUATED lit (1-BP-4.1) - no SI Equipment running (SI pumps running, CV Cold leg injection SI8801A/B open) - no Determine if SI required:

o Check PZR pressure < 1829 psig o Check Steamline pressure < 640 psig o Check CNMT pressure > 3.4 psig SI is required: - YES EVALUATOR NOTE:

Crew actions of 1BEP-0 continue below.

BOP actions of 1BEP-0, Attachment B continue on page 27.

ATC/BOP 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

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 22 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior 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 Isol valve - open Normal spray valves - CLOSED ATC ADJUST AF FLOW:

Lower total Feed Flow to approximately 600 gpm ATC Check steam dumps - AVAILABLE - NO C-9 Permissive light - NOT LIT - NO CW Pump - AT LEAST ONE RUNNING - NO Actuate MS Isolation

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 23 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior ATC Check RCS temperature:

o RCPs - ANY RUNNING o Tave between 552°F and 561°F o RCPs -NONE RUNNING o Tcold between 552°F and 561°F Control RCS temperature by performing the following:

Temperature greater than 561°F Verify/open Steam Dumps and / or SG PORVs as necessary Raise AF flow as necessary Temperature less than 552°F Verify/Close Steam Dumps and SG PORVs Reduce AF flow as necessary while maintaining 500 gpm total flow IF less than 10% (31% ADVERSE CNMT)

Actuate Main Steam Isolation as necessary ATC Check if RCPs should be stopped:

All RCPs.

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

Stop all RCPs ATC Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 24 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior 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 monitors - Less Than Alert Alarm Setpoints CNMT pressure - Less Than 3.4 psig - NO CNMT floor drain sump level - Less Than 46 inches EVALUATOR NOTE:

The crew actions of 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT UNIT 1 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 Request STA to come to the control room ATC/BOP Check if RCPs should be stopped:

All RCPs - ANY RUNNING.

High Head Flow 1FI-917 > 100 GPM and RCS Pressure >

1425 PSIG.

Stop ALL RCPs ATC/BOP Check if SGs pressure boundaries are Intact NO SG dropping in an uncontrolled manner.

NO SG Completely Depressurized.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 25 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior ATC/BOP Check Intact SG Levels Narrow range levels - GREATER THAN 10% (31%

ADVERSE)

Control feed flow to maintain narrow range levels - BETWEEN 10% (31% ADVERSE) AND 50%

ATC/BOP Check Secondary Radiation Normal Reset CNMT Isol Phase A if necessary Sample all SGs for activity Open SG Blowdown Isol valves: 1SD005A/B/C/D Request Chemistry to sample all SGs for activity Check secondary radiation tends - NORMAL FOR PLANT CONDITIONS SJAE/Gland Steam Exhaust Gas radiation SG Blowdown liquid radiation Main Steamline radiation Secondary activity samples -Normal (When available)

ATC/BOP Check PZR PORVs and Isolation valves PORV isol valve - ENERGIZED PORVs - CLOSED PORV isol valve - at least one OPEN ATC/BOP Check if ECCS Flow Should Be Reduced RCS Subcooling - ACCEPTABLE Secondary heat sink Total feed flow to intact SGs - GREATER THAN500 GPM Narrow range level in at least one intact SG - GREATER THAN 10% (31% ADVERSE)

RCS Pressure - STABLE OR RISING PZR level - GREATER THAN 12% (28% ADVERSE)

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 26 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior ATC/BOP Check if CS Should Be Stopped CS Pumps - ANY RUNNING Determine number of CS Pumps Required from Table:

CNMT Press between 15 and 50 psig and dropping 0 or 1 RCFCs - 2 CS Pumps 2, 3, 4 RCFCs - 1 CS Pumps Cnmt Press less than 15 psig 0 required CS pumps running - GREATER THAN NUMBER REQUIRED Check CS pumps - BOTH RUNNING Reset CS signal Stop one CS pump and place in standby Check if last CS pump can be terminated CNMT pressure - LESS THAN 15 PSIG For loss of reactor coolant only Spray operating time - AT LEAST 8 HOURS - NO Spray Additive Tank LO-2 level lights - LIT ATC/BOP Check if RH pumps Should Be Stopped Reset SI if necessary Depress both SI reset pushbuttons Verify SI ACTUATED permissive light - NOT LIT Verify AUTO SI BLOCKED permissive light - LIT Check RCS pressure Pressure - GREATER THAN 325 PSIG - NO Pressure - STABLE OR RISING EVALUATOR NOTE:

ACB 1432 will not auto close, but can still be manually closed.

Bus 143 may be energized in the next step if attempted.

Candidates are not required to energize the bus.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 27 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior ATC/BOP Check if DGs Should Be Stopped 4KV busses - ENERGIZED FROM OFFSITE POWER Bus 141 Bus 142 Bus 143 - NO Consult with TSO for status of offsite power restoration Sync and close associated 4KV NON-ESF SAT feed breaker ACB1432 Bus 144 Stop any unloaded DG and place in standby per BOP DG-12, DIESEL GENERATOR SHUTDOWN ATC/BOP Initiate evaluation of Plant Status Check cold leg recirculation capability Train A - AVAILABLE 1A RH pump - NO - OOS 1SI8811A valve position light LIT Train B - AVAILABLE 1B RH pump 1SI8811A valve position light LIT - NO - NOT LIT US Implement 1BCA-1.1 LOSS OF EMERGENCY COOLANT RECIRCULATION and direct operator actions.

Notifies SM of BEP entry Requests Emergency Plan evaluation Request STA to come to the control room

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 28 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: __7 & 8__

Event

Description:

Loss of Bus 143 causes Loss of Condenser Vacuum, Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: Annunciator 1-21-A2 BUS 143 FD BRKR 1432 TRIP Annunciator 1-21-C1 BUS 143 VOLT LOW Disagreement light LIT on 1A CW Pump C/S and 1C CW Pump C/S PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior EVALUATOR NOTE:

The scenario can be terminated after the crew has determined 1BCA-1.1 LOSS OF EMERGENCY COOLANT RECIRCULATION UNIT 1 entry or at 1BCA-1.1 Step 2 after dispatching personnel to restore power to 1SI8811B.

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 29 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior EVALUATOR NOTE:

1BEP-0, Attachment B, SI VERIFICATION actions begin on this page.

[CT]

BOP

[CT-1]

Attachment B action VERIFY ECCS PUMPS RUNNING:

CENT CHG pumps RH pumps SI pumps BOP Attachment B action VERIFY ECCS VALVE ALIGNMENT Group 2 Cold Leg Injection monitor lights required for ECCS valve alignment - LIT BOP Attachment B action VERIFY ECCS FLOW HHSI flow >100 gpm RCS pressure NOT <1700 psig

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 30 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior BOP Attachment B actions Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode status lights Verify CNMT isolation Phase A Group 3 CNMT isolation monitor lights Verify CNMT Ventilation isolation Group 6 CNMT Vent Isol monitor lights Verify CC Pumps Verify SX Pumps 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

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 31 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior BOP Attachment B action Check if CS is required Check CNMT pressure risen to greater than 20 psig - YES Group 6 monitor lights lit Stop all RCPs Check CS Eductor suction flow on running pumps greater than 15 gpm Check CS educator additive flow on running pumps greater than 5 gpm Verify all riser valves open 0SX163A through 0SX163H - NO Open all valves Verify 0SX162A - D closed Verify all eight SX Cooling Tower Fans running - NO If any fan does not start in Hi speed, then close its associated riser valve If six or less fans are running in high speed and outside air temperature is greater than 76 degrees F, then stop all but two RCFCs Stop two RCFCs 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 - Start 1B DG SX valves open 1SX169A and B Dispatch operator locally to check operation

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 32 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior 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

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 33 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior BOP Attachment B action VERIFY AUXILIARY BUILDING VENTILATION ALIGNED Two inaccessible filter plenums aligned with charcoal absorbers online 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

Form 3.3-2 Required Operator Actions Scenario N22-4 Page 34 of 34 Op. Test No.: 2022-301_ Scenario No.: _N22-4_ Event No.: _8, & 9_

Event

Description:

Event

Description:

Loss of Bus 143, Large break LOCA and Loss of Containment Sump Recirc Symptoms/Cues: PZR Pressure and level dropping Safety Injection actuation 1SI8811B position indication lights Not lit Time Position Applicants Actions or Behavior ATC, BOP, US 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 20.

The crew actions for of 1BEP-0, Attachment B, SI VERIFICATION begin on page 27.

The crew actions for of 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT begin on page 22.