Text

2010 Byron Nuclear Station Initial License Examination as Administered Dynamic Simulator Scenarios
	ML11145A028
Person / Time
Site:	Byron
Issue date:	09/30/2010
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Simulation Facility Byron Scenario No.: Operating Test No. 2010 ILT NRC 10-1 Examination Examiners: Applicant: SRO RO BOP Initial Conditions: IC-152, 95.5% power, steady state, equilibrium xenon, BOL Turnover: Unit 1 is at 95% power per Load Dispatcher orders, steady state, equilibrium xenon, BOL CB D is at 221 steps and boron concentration is 819 ppm. Online risk is green. Crew is to start the 1D CD/CB pump and secure the 1B CD/CB pump for maintenance work on the 1B CD/CB pump. Leave the pump in standby while the C/O is being prepared. Alarm 1-1-B7 came in 30 minutes ago and Chemistry is taking samples.

Event No. Malf. No. Event Event Type* Description N (BOP, Swap running CD/CB pumps for maintenance 1

SRO)

MF CV07A 80 60 C (RO, RCP Seal Injection Filter Clogged 2

SRO)

IOR ZDI0CW03PA TRIP C (BOP, CW Makeup Pump Trip 3

SRO) 4 MF RX13A 100 I (RO, SRO) Pzr LT-459A Fail High (controlling channel)

TS (SRO)

IMF FW02A C (BOP, 1B TDFP Trip with 1A MFP available for manual start 5

SRO)

Cue from Chemistry R (RO, High Secondary Chemistry requiring unit ramp offline 6

SRO)

TS (SRO)

MF MS07D 4 240 M (ALL) 1D Steam Line Break inside CNMT 7

(Preloaded) C (SRO/ CS Pumps Auto Start Failure, Manual Start required; 1A CS 8

MF CS01A BOP) pump fail to start.

RF CS04 OVER RF CS05 OVER

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

SCENARIO OVERVIEW Unit 1 is at 95% power per Load Dispatcher orders, steady state, equilibrium xenon, BOL CB D is at 221 steps and boron concentration is 819 ppm. Online risk is green. Crew is to start the 1D CD/CB pump and secure the 1B CD/CB pump for maintenance work on the 1B CD/CB pump. Leave the pump in standby while the C/O is being prepared.

Alarm 1-1-B7 came in 30 minutes ago and Chemistry is taking samples.

After completing shift turnover and relief, the crew will start the 1D CD/CB pump and secure the 1B CD/CB pump for maintenance on the 1B CD/CB pump, using BOP CD/CB-1, CD/CB Pump Operation After System Startup.

After the CD/CB pump swap is complete, the annunciator for RCP Seal Injection High DP will alarm. BOP CV-10, CV Filter Operations will be utilized to swap Seal Injection Filters. The crew may enter 1BOA RCP-2, Loss of Seal Cooling, which directs the use of BOP CV-10 to swap filters.

After normal seal injection flow is restored and the plant stabilized, 0A CW Makeup Pump will spuriously trip. The crew 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.

After the 0B CW Makeup pump has been started, Pressurizer level transmitter 1LT-459A, the controlling channel, fails high. The RO will take manual control of either the master Pzr level controller or 1CV121 to raise charging. The crew will enter 1BOA Inst-2, and there is a high level bistable to be tripped.

After the actions for the Pzr control malfunction are completed, 1B TDFP spuriously trips, causing a reduction in feedwater flow. The crew will enter 1BOA Sec-1 and start the 1A MFP.

After 1BOA Sec-1 is exited, Chemistry Department will call with confirmed sample results of the U-1 Condenser.

Sodium concentration is 300 ppb, which is above the Action Level 3 threshold of 250 ppb. The crew will enter 1BOA Sec-2, Abnormal Secondary Chemistry and initiate a ramp offline to be completed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

After the ramp has been initiated, a 4 Mlb/hour fault develops and ramps in over 240 seconds in the 1B Steam Line inside Containment. The crew will trip or verify a trip of the reactor, initiate or verify Main Steam Line isolation, and initiate or verify Safety Injection. The crew will enter 1BEP-0, Reactor Trip or Safety Injection, transition to 1BEP-2, Faulted Steam Generator Isolation, then transition to 1BEP ES-1.1, SI Termination.

The Containment Spray pumps will not automatically start, requiring the crew to manually actuate Containment Spray.

Only the 1B CS pump will start.

Completion criterion is transition to 1BEP ES-1.1, SI Termination. The lead evaluator may end the scenario at the transition, or after SI has been terminated.

Critical Tasks

1. Manually actuate at least the minimum required complement of containment cooling equipment before an extreme (red-path) challenge develops to the containment CSF.

(ERG Critical Task number - E-0--E) (K/A: 026000A4.01 - IR: 4.5/4.3)

2. Isolate the faulted SG before transition out of E-2.

(ERG Critical Task number - E-2--A) (K/A: APE040AA1.10 - IR: 4.1/4.1)

Byron ILT NRC 10-1 Page 2

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, BYRON TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.

Establish the conditions of IC 152, 95% power, MOL, steady state, equilibrium xenon.

Complete items on Simulator Ready for Training Checklist.

Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.

Place simulator in RUN (allow simulator to run during board walk down and turnover).

IMF PN1422 ON to turn on Annunciator Secondary Sampling Panel/Sink Trouble (1-1-B7)

Verify RM-11 is on grid 1, CRT 1 is NR SPDS, CRT 2 is DI Summary, CRT 3 is Plant Status, HMI 1 is TR 1, and HMI 2 is TR 2. Reset SER screens and chart recorders. Ensure horns are turned ON. Set BA and PW controllers to Rema numbers or 0 and reset.

From the Expert Command Window type: cae caep\N10-1SETUP.cae (If from thumb drive or CD, run cae (DRIVE LETTER):\caep\N10-1SETUP.cae)

Byron ILT NRC 10-1 Page 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: CD/CB Pump Swap As EO, perform the local actions of BOP CD/CB-1 to report the 1D CD/CB pump has oil flow and > 6 PSIG Lube Oil Pressure (after the MCR starts the aux oil pumps), proper gland water flow, the pump has been vented and the suction and discharge valves are open.

Event 2: RCP Seal Injection Filter clogged IMF CV07A 80 60 AS EO, report 1A Seal Injection filter DP at 35 PSID (High alarm setting is 29 PSID).

When directed, swap to the 1B filter IAW BOP CV-10. Open 1CV8384B by MRF CV42 100 and close 1CV8384A by MRF CV41 0.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

Event 3: 0A CW Makeup Pump trip IOR ZAO0IICS03PC 365 IOR ZDI0CW03PA TRIP AFTER pump stops, DOR ZDI0CW03PA2 As EO, acknowledge order to investigate cause of pump trip. Report you are at the RSH doing rounds, and that the overcurrent target flag is up.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

Event4: Respond to Pressurizer Level Channel Failure IMF RX13A 100 As WEC or Extra NSO, acknowledge request to trip bistables.

To trip bistables, MRF RP20 OPEN to open Protection Cabinet 1, MRF RX029 TRIP for LB459A As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

As SM Acknowledge entry into Tech Spec LCOAR As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 5: 1B TDFP Trip IMF FW02A As EO, if asked to investigate the cause of the pump trip, report no visible cause, but there is scaffold material piled on the floor by the local control panel, and that you (the EO) will talk to the carpenters.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

Byron ILT NRC 10-1 Page 4

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

Event 6: High Secondary Chemistry As Chemistry, call the Unit desk at 2208 and report confirmed sample results of the U-1 Condenser. Sodium concentration is 300 ppb, which is above the Action Level 3 threshold of 250 ppb.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

As SM Grant permission to ramp the unit offline and begin the ramp as soon as possible. Sign the BGP flowchart at the Unit desk. IF the candidate asks whether to use the normal or rapid reduction flow, ask for their recommendation and concur with that decision.

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

As Chemistry, report Chemistry Dept is co-ordinating with the Field Supervisor to maximize secondary cleanup.

Chemistry Department is taking actions per CY-AP-120-201, looking for a likely condenser tube leak.

Event 7: 1D Steam Line Break inside Containment IMF MS07D 4 240 to cause a 4 MLB/hr steam line break on the 1D Steam Line inside CNMT.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

After transition to 1BEP-2, Acknowledge request for STA and begin monitoring BSTs.

Event 8: CS Pump Failure to automatically start Byron ILT NRC 10-1 Page 5

Scenario NRC 10-1 Event 1 No: No.

Event

Description:

CD/CB Pump Swap Time Position Applicants Actions or Behavior CUE

From turnover, swap CD/CB pumps per BOP CD/CB-1, CD/CB Pump Operation After System Startup US

Direct BOP to perform BOP CD/CB-1 BOP

Refer to BOP CD/CB-1.

Place Standby Pump Selector in OFF

Verify with EO to ensure proper oil levels

Start 1D CD/CB pump Lube Oil pump.

o Verify with EO to ensure proper oil pressure > 6 PSIG o Check OIL PRESS UP light is LIT

Verify with EO to ensure proper oil flow and gland water is cut in

Verify/locally open 1CD037D, Suction Valve

Verify/ locally open 1CD041D, Discharge Valve

Verify/locally open 1CD099D, Suction Valve

Verify/ locally open 1CB002D, Discharge Isol Valve

Locally vent the 1D CD/CB pump

Open 1CB113D, 1D CD/CB pump Recirc Valve o Make page announcement for pump start

Start 1D CD/CB pump at 1PM03J.

Place 1CB113D C/S in AUTO.

Locally verify speed reducer oil pressure (is 20-35 PSIG)

Shutdown 1D CD/CB pump Lube Oil pump

Locally ensure lube oil pressure > 6 PSIG

Locally throttle WS cooling valves for 1D CD/CB pump o Monitor pump parameters on process computer

Refer to BOP CD/CB-2

Start the 1B CD/CB pump Lube Oil pump

Verify 1B CD/CB pump Lube Oil pump RUN LIGHTS are LIT

Verify/ Place Standby Pump Selector in OFF

Place 1CB113B C/S in OPEN.

o Make page announcement for pump shutdown

Shutdown 1B CD/CB pump

Place 1CB113B C/S in CLOSE.

Comments:

Byron ILT NRC 10-1 Page 6

Scenario NRC 10-1 Event 1 No: No.

Event

Description:

CD/CB Pump Swap Time Position Applicants Actions or Behavior o Verify/Place Standby Pump Selector in B

Stop Lube Oil pump 5 minutes after CD/CB shutdown o Locally throttle WS cooling valves for 1B CD/CB pump

Inform US the pump swap is complete.

RO

Monitor primary and secondary panels while BOP performing BOP CD/CB-1 and 2.

Provide support as requested to BOP.

US

Acknowledge report.

o Notify SM BOP CD/CB-1 is complete.

EVALUATOR NOTE: When pump swap is complete, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 7

Scenario NRC 10-1 Event 2 No: No.

Event RCP Seal Injection Filter Clogged

==

Description:==

Time Position Applicants Actions or Behavior

Annunciator RCP Seal Inj Filter High DP (1-7-A2) LIT CUE

Seal injection flows lowering o Adjust 1CV182 to maintain at least 8 GPM seal injection flow per RCP RO o Dispatch EO to check 1A Seal Injection filter DP CREW

Dispatch EO to swap seal injection filters using BOP CV-10, CV Filter Operations Evaluator Note: The crew may enter 1BOA RCP-2 for the loss of seal cooling. This will direct swapping filters using BOP CV-10. Actions of 1BOA RCP-2 follow in italics.

Implement 1BOA RCP-2, Loss of Seal Cooling US

Notify SM of procedure entry, requests IR and EAL evaluation o Verify RCP seal cooling is met with RCP temperatures within limits RO

Restore Seal Injection

Dispatch EO to swap seal injection filters using BOP CV-10, CV Filter Operations

Control seal injection flow with 1CV182 and 1CV121 to 8 - 13 GPM per RCP

Assist in monitoring primary plant while RO controls seal injection flow.

BOP

Provide assistance in diagnosis and BAR response.

o Direct initiation of or initiate 1BOSR 5.5.1-1, RCS Controlled Leakage Monthly Surveillance after US standby filter is placed on line.

EVALUATOR NOTE: After the actions for the seal filter malfunction are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 8

Scenario NRC 10-1 Event 3 No: No.

Event

Description:

0A CW Makeup Pump Trip Time Position Applicants Actions or Behavior CUE

Annunciator CW Makeup Pump Trip (0-38-A11) is LIT

0A CW Makeup pump disagreement light LIT US

Direct operator to respond to alarm BOP

Refer to BAR for 0-38-A11

Start the standby CW Makeup Pump using BOP CW-9 o Dispatch EO to RSH to investigate the cause of the trip and take actions to secure the tripped 0A CW makeup pump.

RO

Monitor primary and secondary parameters while BOP is involved in the pump trip EVALUATORS NOTE: The crew will refer to or enter 0BOA Sec-11 for inadequate makeup flow. Actions of 0BOA Sec-11 follow in italics.

US o Enter 0BOA Sec-11 o Notify SM of procedure entry and request EAL evaluation BOP

Check at least 2 pumps-NOT running

Using BOP CW-9:

Direct EO to perform local actions by procedure or direct the EOs actions

F.1 blowdown oil cooler cooling line

F.2 Verify open suction valve

F.3 Verify open recirc valve

F.4 Verify closed discharge valve

F.8 Throttle open 0CW217B

Start 0B CW Makeup pump

Direct EO to lineup oil cooling water

Throttle open 0CW220

Verify 0B CW MU discharge valve 0CW216B opens

Verify 0B CW MU recirc valve closes

Verify open 0B CW MU Pump discharge isolation valve 0CW217B

Throttle open 0CW278B, recirc valve locally

Verify pump current of 300 to 343 amps

Adjust 0CW220

Direct EO to Locally check motor and bearing temperatures o Check outside air temperature > 40°F o Dispatch operator to investigate cause of trip o Verify adequate Makeup capability EVALUATOR NOTE: After the actions to control CW makeup pump trip are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 9

Scenario NRC 10-1 Event 4 No: No.

Event

Description:

Pressurizer level channel 1LT-459 failed high Time Position Applicants Actions or Behavior CUE

Annunciator PZR LEVEL HIGH RX TRIP STPT ALERT (1-12-A3) is LIT

Annunciator PZR LEVEL HIGH CONT DEV HTRS ON (1-12-C3) is LIT

1LI-459A indicates 100% level

Charging flow lowering o Refer to BARs.

CREW

Identify entry conditions for 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Implement 1BOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment C "PRESSURIZER LEVEL CHANNEL FAILURE" and direct operator actions of 1BOA INST-2 RO

Perform the following at 1PM05J:

Place 1FK-121, CV pumps flow control valve, OR 1LK-459, PZR master level controller, in manual.

Raise demand on 1FK-121 OR 1LK-459 in conjunction with controlling demand on 1CV182 to raise charging flow.

Operate 1FK-121 OR 1LK-459 in manual to minimize PZR level drop and maintain 8-13 gpm RCP seal injection flow.

Select an operable Pzr level channel for control

Select an operable Pzr level channel to the recorder

Place 1FK-121, CV pumps flow control valve, OR 1LK-459, PZR master level controller, as appropriate, in automatic.

US

Perform pre-job brief per HU-AA-1211 for bistable tripping.

o Complete 1BOL 3.1, Attachment B, INSTRUMENT CONDITION TRACKING LOG.

Extra

Locally trip bistable for 1LT-459 / RO verifies correct bistable operation.

NSO/

LB459A RO US

Determine TS 3.3.1 conditions A and K are applicable.

Determine TS 3.3.3 and 3.3.4 are NOT applicable - minimum channels operable requirement is met.

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

BOP

Monitor secondary systems

Assist RO with annunciator response EVALUATOR NOTE: After the instrument failure has been addressed and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 10

Scenario NRC 10-1 Event 5 No: No.

Event

Description:

1B TDFP trip with 1A MFP available Time Position Applicants Actions or Behavior CUE

Annunciator FW Pump 1B Trip (1-16-B2) is LIT

Annunciators SG 1A-D Flow Mismatch FW Flow Low (1-16-A:D4) are LIT

Annunciator FW Pump Discharge Flow High (1-16-D2) is LIT o Auto start of standby CD/CB pump with associated alarms LIT

SG levels lowering EVALUATORS NOTE: If NO action is taken, a reactor trip on Low-2 SG level will occur in about 2 minutes.

EVALUATORS NOTE: The crew may elect to runback the turbine if difficulty is experienced when starting the 1A MFP. Those actions are listed in italics below.

US

Enter 1BOA Sec-1, Secondary Pump Trip, Attachment A for FW Pump trip o Direct BOP to close 1FW012B o Direct RO/BOP to monitor SG levels for Reactor Trip criteria

Notify SM of plant status, procedure entry, request IR and maintenance notification and EAL evaluation BOP

Close 1FW012B

Check Turbine load > 700 MW

Check at least 1 FW pump running

Restore feed flow

Check 1A MFP is available

Start 1A MFP aux oil pump

Verify 1FW016 in Manual at 20%

Start 1A MFP

Check 1A MFP discharge flow > 3 MLB/hr

Start the standby CD/CB pump aux oil pump

Start the standby CD/CB pump

Check feed flow > steam flow and adjust 1FW016 as needed.

RO o Monitor RCS Tave and reactivity effects caused by secondary feedflow changes.

o Assist BOP with BAR response EVALUATORS NOTE: Listed below are the actions to runback the turbine if the crew chooses to perform that step.

BOP

Reduce Turbine load by pushing Runback Pushbutton or Runback Box on OWS panel G-5512

Check Turbine load dropping RO

Verify rod control in AUTO

Initiate boration according to Runback Placard or Rema BOP

Start the standby CD/CB pump aux oil pump

Start the standby CD/CB pump Comments:

Byron ILT NRC 10-1 Page 11

Scenario NRC 10-1 Event 5 No: No.

Event

Description:

1B TDFP trip with 1A MFP available Time Position Applicants Actions or Behavior CREW

Check FW Pump NPSH Low alarm is LIT (If not, bypass the steps below and go to Check Feed Flow Restored).

o Check CP Bypass valves OPEN o Check standby CD/CB pump running o Verify HD pump discharge valves RESPONDING o Check CB pump recirc valves in AUTO o Check CD pumps recirc valve CLOSED o Check GS Condenser bypass valves OPEN BOP

Check Feed Flow restored

Feed flow > steam flow

SG levels at or trending to normal

Turbine Runback NOT lit

FW Pump Discharge Flow High alarm NOT lit o Momentarily place each FWRV in MANUAL to remove integrated error signal RO/BOP

Check Plant Status o PDMS INOPERABLE alarm (1-10-E8) is NOT lit o 1BOL 3.h NOT implemented o PDMS Limit Exceeded alarm (1-10-D7) is NOT lit o Control DI near target o Rod bank RIL alarm (1-10-B6) is NOT lit o C-7 NOT lit CREW

Restore Plant Conditions

Adjust RCS boron concentration as necessary

Balance FW pump flows as necessary

Verify FW pump recirc valves on running FW pumps in - MODULATE

Verify valve controls for running equipment in - AUTO:

o HD pump discharge o CB pump recircs o CD pumps recirc o GS condenser bypasses o Review start-up procedure for 1A MFP o Shutdown unnecessary CD/CB pump per BOP CD/CB-2, CONDENSATE/CONDENSATE BOOSTER SYSTEM SHUTDOWN o Complete shutdown of tripped FW pump per BOP FW-2, SHUTDOWN OF A TURBINE DRIVEN MAIN FEEDWATER PUMP o Adjust SG blowdown flows and calorimetric inputs as necessary CREW

Verify DEHC feedback loop in service Comments:

Byron ILT NRC 10-1 Page 12

Scenario NRC 10-1 Event 5 No: No.

Event

Description:

1B TDFP trip with 1A MFP available Time Position Applicants Actions or Behavior

Notify Chemistry to monitor secondary chemistry o Complete applicable section(s) of 1BGP 100-4 (if runback performed)

Check Reactor power change > 15% in one hour. If so:

o Notify Chemistry and RP to perform the power change surveillances EVALUATOR NOTE: After the actions for the feed pump trip are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 13

Scenario NRC 10-1 Event 6 No: No.

Event

Description:

High Secondary Chemistry requiring Ramp Offline Time Position Applicants Actions or Behavior CUE

Annunciator Secondary Sampling Panel/Sink Trouble (1-1-B7) is LIT

Chemistry department reports that Sodium is at 300 ppb, Action Level 3 US

Enter 1BOA Sec-2

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Initiate Secondary cleanup

Maximize CP usage and SG blowdown as Chemistry directs

Determine required action for Action Level 3

Direct Unit shutdown to MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months BOP

Check CSTs NOT crosstied US

Notify Chemistry to perform TS 3.4.16 sampling as required

Determine source of water for MODE 3

Initiate 1BGP 100-4 flowchart for shutdown

Notify SM of required shutdown EVALUATORS NOTE: Either the normal (1BGP 100-4T1) or rapid reduction (1BGP 100-4T1.1) flowchart may be used at the SM discretion. The examiner will ask the US for a recommendation and concur with the decision.

RO

Calculate reactivity change for shutdown using Rema US

Implement 1BGP 100-4T1 for a normal ramp or 4T1.1 for a rapid reduction

Instruct RO and BOP to review P, P, L & A of 1BGP 100-4.

Direct RO to borate in accordance with ReMa (Initial boration of 240 gal to 80%, rod position at 178 steps at 80% for a ramp rate of 5 MW/minute)

Direct BOP to ramp in accordance with 1BGP 100-4T1 ( or 4T1.1) and supplied Rema RO

Set up boration IAW ReMa and BOP CV-6

Initiate boration using BOP CV-6 or BOP CV-6T1 checklist

Select STOP on RMCS Makeup Control Switch

Select BORATE on RMCS Mode Select Switch

Enter desired boration amount in BA totalizer

Turn ON RMCS Makeup Control Switch

Verify 1CV110B OPEN

Verify 1CV110A MODULATING

Verify 1AB03P STARTS

Verify proper AB flow on 1FR110

Coordinate boration with start of unit ramp by BOP BOP

Set up DEH for ramp IAW 1BGP 100-4T1 (or 4T1.1)

Comments:

Byron ILT NRC 10-1 Page 14

Scenario NRC 10-1 Event 6 No: No.

Event

Description:

High Secondary Chemistry requiring Ramp Offline Time Position Applicants Actions or Behavior

Enter desired ramp rate (from Rema) in the RATE window

Press ENTER

Enter desired MW output (from Rema) in the REF DEMAND window

Press ENTER

Press GO/HOLD

Press GO and verify load lowers

Coordinate ramp with boration by RO.

EVALUATOR NOTE: After the ramp has been inititated and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-1 Page 15

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior CUE

Annunciator CNMT Drain Leak Det Flow High Alarm (1-1-A2) is LIT

Annunciator CNMT Press High Alarm (0-33-D6) is LIT CREW

Identify entry conditions for 1BEP-0, REACTOR TRIP OR SAFETY INJECTION US

Order U-1 Reactor trip

Notify SM of plant status and procedure entry

Request evaluation of Emergency Plan conditions

Enter/Implement 1BEP-0 and direct operators to perform the immediate actions of 1BEP-0 RO Perform immediate operator actions of 1BEP-0:

Step 1: Verify reactor trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux - DROPPING BOP Perform immediate operator actions of 1BEP-0:

Step 2: Verify Turbine Trip

All Turbine throttle valves - CLOSED

All Turbine governor valves - CLOSED

Step 3: Verify power to 4KV busses

ESF Buses - BOTH ENERGIZED (141 & 142)

EVALUATORS NOTE: The crew may decide to actuate Main Steam Line Isolation after completion of Immediate Actions CREW o Manually actuate MSLI and verify MSIV and bypass valves are CLOSED EVALUATORS NOTE: The crew may decide to actuate Safety Injection before actuation pressures are reached. SI will automatically actuate about 90 seconds after the malfunction is inserted.

CREW

Step 4: Check SI Status o SI First OUT annunciator - LIT o SI ACTUATED Permissive Light - LIT o SI Equipment - AUTOMATICALLY ACTUATED o Either SI pumps - RUNNING o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J Comments:

Byron ILT NRC 10-1 Page 16

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior EVALUATORS NOTE: Action to trip the RCPs should be initiated within 10 minutes of the RCP Phase B Isolation RO

Determine RCP trip required

Phase B Isolation actuated o RCS pressure < 1425 psig & High head SI flow (1FI-917) > 100 gpm

Trip ALL RCPs US

Step 5: Direct BOP to perform Attachment B of 1BEP-0 EVALUATOR NOTE: US and RO will continue in 1BEP-0 while BOP is performing Attachment B:

BOP

Perform 1BEP-0 Attachment B

Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.

Verify DGs running at 1PM01J:

DGs - BOTH DGs running

1SX169A & B OPEN.

Dispatch operator locally to check operation

Verify Generator Trip at 1PM01J:

OCB 3-4 and 4-5 open.

PMG output breaker open.

BOP

Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

Supply fan

Return fan

M/U fan

Chilled water pump

Chiller

Operating VC train dampers - ALIGNED.

M/U fan outlet damper - NOT FULLY CLOSED.

VC train M/U filter light - LIT.

Operating VC train Charcoal Absorber aligned

Bypass damper - CLOSED

Inlet damper - OPEN

Outlet damper - OPEN

Control Room pressure greater than +0.125 inches water on 0PDI-VC038.

Verify Auxiliary Building ventilation aligned at 0PM02J:

Comments:

Byron ILT NRC 10-1 Page 17

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior

Two inaccessible filter plenums aligned.

Plenum A or B or C:

Fan - RUNNING

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED

Plenum A or B or C:

Fan - RUNNING

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED

Verify FHB ventilation aligned at 0PM02J:

Fan - RUNNING

Inlet Isolation damper - OPEN

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED EVALUATOR NOTE: The remaining steps of Attachment B may be designated to be performed by WEC personnel or the Field Supervisor and extra operators.

o Trip all running HD Pumps o Shutdown FW pump as necessary using BOP FW-2 for a TDFP or BOP FW-8 for the MDFP o Shutdown unnecessary CD/CB Pumps using BOP CD/CB-2 o Align SX MDCT per BOP SX-T2 o Maintain SX Basin level > 80%

o Align NDCT o Verify CW intake bay level within band o Dispatch operator to locally verify NDCT basin level acceptable o Align NDCT per BOP CW-25 o Shutdown all unnecessary CW pumps per BOP CW-2 o Notify US that Attachment B is complete RO/

Step 6: Verify ECCS pumps running BOP

Both CV pumps - RUNNING

Both RH pumps - RUNNING

Both SI pumps - RUNNING BOP/

Perform the following at 1PM06J:

RO

Step 7: Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode lights - All LIT.

Step 8: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - ALL LIT.

Step 9: Verify Cnmt Vent isolation:

Comments:

Byron ILT NRC 10-1 Page 18

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

BOP/

Step 10: Verify AF system:

RO

AF pumps - BOTH AF pumps RUNNING.

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

Step 11: Verify CC pumps - BOTH RUNNING.

Step 12: Verify SX pumps - BOTH RUNNING.

Step 13: Check if Main Steamline Isolation -required:

o 1D SG pressure < 640 psig (at 1PM04J) o CNMT pressure > 8.2 psig.

o Verify MSIV and Bypass Valves - CLOSED EVALUATORS NOTE: CS may have an actuation signal at this time. If it has not, the crew must return to this step to verify proper alignment when CNMT pressure exceeds 20 psig. CS will NOT automatically actuate and must be manually actuated.

BOP/

Step 14: Check if CS is required.

RO

CNMT pressure has risen > 20 psig.

[CT]

Group 6 CS monitor lights - NOT ALL LIT.

E-0--E

Manually actuate CS and Phase B Isolation

Check CS valve alignment - Listed valves are all open

1B CS pump is running

Group 6 phase B lights - ALL LIT except CS PUMP A RUNNING light is NOT LIT

Verify/Stop ALL RCPs (at 1PM04J).

CS eductor suction flows - > 15 gpm

CS eductor additive flows - > 5 gpm

Align SX Towers

All 8 Riser valves OPEN

All 4 Bypass valves CLOSED

All 8 fans running in HIGH speed CREW

Recognize and announce ADVERSE CNMT BOP/

Step 15: Verify Total AF flow:

RO

AF flow > 500 gpm

S/G NR levels - NOT rising in an uncontrolled manner RO/

Step 16: Verify ECCS valve alignment BOP

Determine Group 2 Cold Leg Injection monitor lights required for injection - All lit RO/

Step 17: Verify ECCS flow Comments:

Byron ILT NRC 10-1 Page 19

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior BOP

High Head SI flow >100 gpm (1FI-917)

RCS pressure < 1700 psig

BOTH SI pump discharge flows > 200 gpm

RCS pressure > 325 psig RO

Step 18: Check PZR PORVs and SPRAY VALVES at 1PM05J:

1RY455 & 1RY456 CLOSED

PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED

PORV relief path - Both PORVs in AUTO, Both isolation valves - OPEN.

Normal PZR Spray Valves CLOSED RO

Step 19: Maintain RCS temperature control at 1PM05J:

Check RCPs - NONE RUNNING.

o

Verify RCS cold leg temperature stable at or trending to 557 F.

Throttle AF maintaining >500 GPM until SG minimum level is met o AF flow to 1D SG may be throttled to 0 GPM

MSIVs closed RO

Step 20: Check status of RCPs at 1PM05J:

o All RCPs - NONE RUNNING.

o Any RCPs still running - TRIP All RCPs IF Phase B isolation occurred or RCS pressure trip criteria is met BOP/

Step 21: Check if SG secondary pressure boundaries are intact at 1PM04J:

RO

Check pressure in all SGs:

1D SG dropping in an uncontrolled manner.

CREW

Transition to 1BEP-2, FAULTED STEAM GENERATOR ISOLATION US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Request STA evaluation of status trees.

Enter/Implement 1BEP-2 and direct operator actions of 1BEP-2 to establish the following conditions.

RO/

Check MS isolation at 1PM06J:

BOP

All MSIVs and bypass valves - CLOSED BOP

Check if any SG secondary pressure boundary is intact at 1PM04J:

1A, 1B, & 1C SG pressures stable.

CREW

Identify faulted SG at 1PM04J:

Comments:

Byron ILT NRC 10-1 Page 20

Scenario NRC 10-1 Event 7&8 No: No.

Event

Description:

1D Steam Line Break inside Containment Time Position Applicants Actions or Behavior

1D SG pressure decreasing in an uncontrolled manner.

Comments:

Byron ILT NRC 10-1 Page 21

RO/ BOP

Isolate 1D Steam Generator at completion of step 4 of 1BEP-2:

[CT]

Verify/close 1AF013D & H at 1PM06J E-2--A

Bottom row of FW isolation monitor lights - lit.

1MS018D closed.

1SD002C & D closed.

1SD005B closed.

BOP

Monitor AF pump suction pressure.

Annunciator AF PUMP SX SUCTION VLVS ARMED (1-3-E7) - NOT LIT.

CREW

Determine 1D S/G tubes are intact:

Reset Phase A isolation

Open 1SD005A-D

Request Chemistry Dept samples all SG for activity

Check there are NO RM-11 or HMI Rad Monitor ALERT/HI RAD Alarms.

o 1PR08J SG Blowdown.

o 1PR27J SJAE/GS.

o 1AR 22/23D 1D Main steam Line.

CREW

Check if ECCS flow should be reduced

RCS subcooling -ACCEPTABLE

Secondary heat sink-total feed flow to INTACT SGs > 500 GPM or NR level in at least 1 SG > 10% (31% Adverse CNMT)

RCS pressure - stable or rising

Pzr level - > 12% (28% Adverse CNMT

Determine transition to 1BEP ES-1.1, SI TERMINATION CREW

Transition to 1BEP ES-1.1, SI TERMINATION EVALUATOR NOTE: The scenario can be terminated after the transition to 1BEP ES-1.1 is announced or at lead examiners discretion.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Enter/Implement 1BEP ES-1.1 and direct operator actions of 1BEP ES-1.1 RO/

Reset SI BOP

Depress both SI reset PB

Verify SI Actuated light - NOT LIT

Very Auto SI Blocked light - LIT RO/

Reset Cnmt Isolation BOP

Reset Phase A BOP

Establish IA to CNMT

Check SACs - ANY Running Comments:

Byron ILT NRC 10-1 Page 22

Open 1IA065 and 1IA066 RO/

Realign CV Pump BOP

Stop one CV pump CREW

Check RCS pressure - Stable or rising RO/

Terminate High-head SI BOP

Reset SI recirc sump isolation valves - 1SI8811A & B and 1CV8110 & 1CV8111

Reset CV pump miniflow valves - 1CV8114 and 1CV8116

Verify CV pump miniflow valves - OPEN

Close CV injection valves - 1SI8801A & B RO/

Establish Charging Flow BOP

Place 1CV182 at 0% demand

Open CNMT isolation valves 1CV8105 and 1CV8106

Set seal injection flow to 8-13 GPM per RCP RO/

Control Charging flow to maintain Pzr level stable BOP RO/

Check if SI pumps should be stopped BOP

RCS pressure - Stable or rising and > 1700 PSIG

Stop BOTH SI pumps and place in standby

Step 10: Check if RH pumps should be stopped

Reset SI

Depress BOTH SI Reset Pushbuttons at 1PM06J

Verify SI ACTUATED BP light NOT lit at 1PM05J

Verify AUTO SI BLOCKED BP light NOT lit at 1PM05J

RCS pressure > 325 psig & stable

Stop both RH pumps and place in standby EVALUATOR NOTE: The scenario can be terminated after the transition to 1BEP ES-1.1 is announced or at lead examiners discretion.

Comments:

Byron ILT NRC 10-1 Page 23

Simulation Facility Byron Scenario No.: Operating Test No. 2010 ILT NRC 10-2 Examination Examiners: Applicant: SRO RO BOP Initial Conditions: IC-151 Turnover: Unit 1 is at 12% power, BOL, ready to synchronize Main Generator. Online risk is green. CBD @

147 steps, and boron concentration is 1300 ppm. 1BGP 100-3, step F.27 is the next step to perform.

Steam dump demand must be raised to 25% to 35% as directed by step 23.o. The offgoing shift has just diluted 100 gallons. 1A MDFP is OOS for maintenance.

Event No. Malf. No. Event Event Type* Description 1 R (RO, Power ascension SRO) 2 N (BOP, Synchronize Main Generator to grid SRO) 3 IOR ZDI1CV8149B CLS C (RO, 75 GPM LD Isolation Valve 1CV8149B Fail Closed SRO) 4 MF RX06D 0 I (BOP, 1A SG LT-556 Fail Low (controlling channel)

SRO) TS (SRO) 5 MF RX13A 100 I (RO, SRO) Pzr 1LT-459A Fail High (controlling channel)

TS (SRO) 6 MF FW22C C (BOP, 1C CD/CB Pump Trip with manual start required SRO) 7 MF TH03A 400 M (ALL) 1A SGTR (normal cooldown and depressurization) 8 MF RP04A, RP04B C Automatic Phase A Isolation Actuation Failure (manual (SRO/BOP) required)

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

SCENARIO OVERVIEW Unit 1 is at 12% power, BOL, ready to synchronize Main Generator. Online risk is green. CBD @ 147 steps, and boron concentration is 1300 ppm. 1BGP 100-3, step F.27 is the next step to perform. Steam dump demand must be raised to 25% to 35% as directed by step 23.o. The offgoing shift has just diluted 100 gallons. 1A MDFP is OOS for maintenance.

After completing shift turnover and relief, the crew will continue 1BGP 100-3, step F.27 to synchronize the main generator to the grid. The RO will dilute or withdraw control rods to raise steam dump demand from current demand to 25% to 35% IAW 1BGP 100-3.

After power has been raised and the synchronization is complete, 1CV8149B, 75 GPM Letdown valve spuriously closes. The crew will restore letdown using BOP CV-17, Establishing and Securing Normal and RH Letdown Flow.

After letdown is restored, 1LT-556, the 1A SG NR level controlling channel, fails low. The BOP will take manual control of the FWRV to lower feedwater flow, and the crew will enter 1BOA Inst-2, Operation with a Failed Instrument Channel. There is a low SG level bistable to be tripped as part of the BOA.

After the actions for 1LT-556 are completed, Pressurizer level transmitter 1LT-459A, the controlling channel, fails high. The RO will take manual control of either the master Pzr level controller or 1CV121 to raise charging. The crew will re-enter 1BOA Inst-2, and there is a high level bistable to be tripped.

After BOA actions are completed, 1C CD/CB pump trips. The crew will enter 1BOA Sec-1, Secondary Pump Trip and start the standby pump.

After 1BOA Sec-1 is exited, 1A SG develops a 400 gpm tube rupture. The crew will trip the reactor, and actuate safety injection. The crew will enter 1BEP-0, Reactor Trip or Safety Injection, and transition to 1BEP-3, Steam Generator Tube Rupture. Automatic Phase A isolation will fail, and the crew will manually actuate Phase A. The crew will perform a cooldown using the main steam dumps, and depressurize using normal Pzr spray.

Completion criterion is RCS depressurization to match ruptured SG pressure, and SI termination in 1BEP-3. The lead evaluator may end the scenario when pressures have been matched, or after SI has been terminated.

Critical Tasks

1. Close containment isolation valves such that at least one valve is closed on each critical phase-A penetration before the end of the scenario (ERG Critical Task number - E-0--0) (K/A number - 103000A2.03. importance - 3.5/3.8)

2. Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs (ERG Critical Task number - E-3--A) (K/A number - EPE038EA1.32. importance - 4.6/4.7)

3. Establish/maintain an RCS temperature so that transition from E-3 does not occur because the RCS temperature is in either of the following conditions:

o Too high to maintain minimum required subcooling OR o Below the RCS temperature that causes an extreme (red-path) or a severe (orange-path) challenge to the subcriticality and/or the integrity CSF (ERG Critical Task number - E-3--B) (K/A number - EPE038EA1.36. importance - 4.3/4.5)

4. Depressurize RCS to meet SI termination criteria before plant-specific criteria exceeded.

(ERG Critical Task number - E-3--C) (K/A number -EPE038EA1.05. importance - 4.1/4.3)

Byron ILT NRC 10-2 Page 2

SIMULATOR SETUP GUIDE:

Verify/perform TQ-BY-201-0113, BYRON TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.

Establish the conditions of IC151, 14% power, BOL, ready to synchronize main generator.

Shutdown 1CD/CB pump if necessary so that only 2 CD/CB pumps are running.

Complete items on Simulator Ready for Training Checklist.

Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.

Place simulator in RUN (allow simulator to run during board walk down and turnover).

Verify RM-11 is on grid 1, CRT 1 is NR SPDS, CRT 2 is DI Summary, CRT 3 is Plant Summary, HMI 1 is TR 1, and HMI 2 is TR 2. Reset SER screens and chart recorders. Ensure horns are turned ON. Set BA and PW controllers to Rema numbers or 0 and reset.

Set main generator VPL to 25% on Graphic 5501.

Adjust incoming voltage about 2 - 4 volts > running voltage.

Adjust generator speed so that synchroscope is running slowly in the fast direction.

Dilute 100 Gallons. Provide a boration/dilution log with 100 Gallons Dilution for Temperature Control to the oncoming crew. Provide 1BGP 100-3T1 initialed up to step 27.

Place C/O tags on the 1A MDFP C/S, its aux oil pump C/S, discharge valve C/S, and recirc valve C/S.

From the Expert Command Window type: cae caep\N10-2SETUP.cae (If from thumb drive or CD, run cae (DRIVE LETTER):\caep\N10-2SETUP.cae)

Byron ILT NRC 10-2 Page 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Power ascension As EO, perform the local actions of 1BGP 100-3 as directed by the crew.

Event 2: Synchronize Main Generator to grid As EO, perform the local actions of 1BGP 100-3 as directed by the crew.

Event 3: 75 GPM LD Isolation Valve 1CV8149B failed closed IOR ZDI1CV8149B CLS As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 4: 1A SG LT-556 failed low IMF RX06D 0 As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

Event 5: Pzr LT-459A failed high IMF RX13A 100 As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

Event 6: 1C CD/CB pump trip with manual start required IMF FW22C As EO, if asked to investigate the cause of the pump trip, report an overcurrent trip.

As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

Event 7: 1A SGTR IMF TH03A 400 As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

After transition to 1BEP-3, Acknowledge request for STA and begin monitoring BSTs.

Event 8: Automatic Phase A Isolation actuation failure (Manual required)

Verify in Preload: IMF RP04A, RP04B Byron ILT NRC 10-2 Page 4

Scenario NRC 10-2 Event 1 No: No.

Event

Description:

Power Ascension Time Position Applicants Actions or Behavior US

Direct power ascension per 1BGP 100-3

Placekeep procedure appropriately

Approve reactivity changes for RO RO

Raise reactor power appropriately to raise steam dump demand to 25% to 35% to support generator synchronization.

o Dilute as necessary

Turn OFF RMCS Makeup CS

Select DILUTE on the RMCS Mode Select Switch

Enter the desired dilution amount in the PW Flow Totalizer

Turn ON RMCS Makeup CS o Turn on Pzr Backup heaters as needed o Withdraw control rods as necessary

Select MANUAL

Withdraw control rods to desired height BOP/RO

When steam dumps are closed, transfer control to Tave Mode

Place 1PK-507 to MANUAL and adjust to 0%

Place Mode switch to RESET then to Tave

Ensure C-7 is OFF

Place 1PK-507 in AUTO EVALUATOR NOTE: After the ramp has continued to the lead examiners satisfaction, insert the next event.

Comments:

Byron ILT NRC 10-2 Page 5

Scenario NRC 10-2 Event 2 No: No.

Event

Description:

Synchronize Main Generator to grid Time Position Applicants Actions or Behavior CUE o From turnover, synchronize the Main Generator to the grid and continue with 1BGP 100-3 at Step 27.

US

Direct BOP and RO to perform 1BGP 100-3

Hold a reactivity and pre-job brief before beginning the synchronization BOP

Refer to BOP 1BGP 100-3, step 27 o Turn on 1 synch switch for either BT 3-4 or 4-5 o Adjust Generator voltage about 4 volts > grid voltage o Adjust Generator speed to obtain synch rotation slowly in the FAST direction

Close selected output breaker

Raise turbine power as necessary using graphic 5501

Adjust MVARS to about 100 MVAR OUT

Turn off Synch switch

Turn on remaining Synch switch

Close remaining output breaker

Turn off Synch switch

Match CS targets for 0PM03J BT breakers BOP/RO o Adjust Feedwater Flow as needed

Verify TGTMS graphics are displayed

Set VPL to 120%

Select LIMITERS

Select VPL up arrow until 120% is reached

Select EXIT

Place 2 SJAE in service

Transfer Gland Sealing Steam to the unit RO

Monitor primary and secondary panels while BOP is synchronizing the generator

Provide support as requested to BOP.

Control rod position and dilute as required to maintain temperature and power.

BOP

Continue with 1BGP 100-3

Initial flowchart US

Acknowledge reports

Placekeep procedure steps appropriately Comments:

Byron ILT NRC 10-2 Page 6

Scenario NRC 10-2 Event 3 No: No.

Event

Description:

1CV8149B Failed Closed Time Position Applicants Actions or Behavior CUE

Letdown flow has lowered to 45 GPM

Charging flow and seal injection flows are lowering

Annunciator RCP SEAL WATER INJ FLOW LOW (1-7-B2) is LIT

Annunciator CHG LINE FLOW HIGH LOW (1-9-D3) is LIT

Pressurizer level is higher than program US

Direct RO actions to restore letdown per BOP CV-9, BOP CV-17, or 1BOA ESP-2 EVALUATORS NOTE: The crew may restore 120 GPM letdown using BOP CV-9, BOP CV-17, or 1BOA ESP-2.

EVALUATORS NOTE: The steps of BOP CV-9 follow.

RO

Enter BOP CV-9, Letdown Orifice Operation

Throttle 1CV121 to raise charging flow to approximately 100 GPM

Place 1CV131 Controller to MANUAL with letdown pressure at ~180 PSIG o Place 1CC130A Controller to MANUAL & adjust as needed.

Open 1CV8149C

Adjust 1CV131 to control letdown pressure at 370 PSIG and place in AUTO when pressure stabilizes

Ensure 1CC130 is maintaining temperature at 105° to 115° and place in AUTO

Adjust 1CV121 to match charging and letdown flow and restore Pzr level to Program Level and place in AUTO EVALUATORS NOTE: The crew may restore 120 GPM letdown by opening 1CV8149C, or may isolate letdown and then restore 120 GPM letdown. The actions if the crew isolates letdown first are in italics.

RO

Close 1CV8149A and place CS for 1CV8149B to CLOSE

Close 1CV459 and 1CV460 o Minimize charging flow using 1CV121 EVALUATORS NOTE: The steps of BOP CV-17 follow.

RO

Enter BOP CV-17. Establishing and Securing Normal and RH Letdown Flow

Verify/Close 1CV8149A-C

Verify/Open 1CC9452A

Verify/Open 1CC9452B

Place 1CC130A Controller to MANUAL at 60% demand

Place 1CV131 Controller to MANUAL at 40% demand

Verify/Open 1CV8401A

Verify 1TK-0381A is in MANUAL at 0% demand

Verify/Open 1CV8152 and 1CV8160

Verify/Open 1CV8389A Comments:

Byron ILT NRC 10-2 Page 7

Scenario NRC 10-2 Event 3 No: No.

Event

Description:

1CV8149B Failed Closed Time Position Applicants Actions or Behavior

Verify/Open 1CV459 and 1CV460

Throttle 1CV182 to maintain seal injection flow at 8-13 GPM per pump

Throttle 1CV121 to raise charging flow to 100 GPM

Open 1CV8149A and 1CV8149C

Adjust 1CV131 to control letdown pressure at 370 PSIG and place in AUTO

Ensure 1CC130 is maintaining temperature at 105° to 115° and place in AUTO

Adjust 1CV121 to match charging and letdown flow and restore Pzr level to Program Level and place in AUTO

Throttle 1CV182 to maintain seal injection flow at 8-13 GPM per pump EVALUATORS NOTE: The steps of 1BOA ESP-2 follow.

RO

Enter 1BOA ESP-2, Re-establishing CV Flow

Verify/Close 1CV8149A-C

Verify/Close 1CV459 and 1CV460

Verify 1CV8401A is OPEN

Verify 1CV8324A & B are OPEN

Verify 1CV8152 and 1CV8160 are OPEN

Verify BTRS MODE SELECTOR SWITCH is OFF

Place 1CV131 Controller to MANUAL at 40% demand

Place 1CC130A Controller to MANUAL at 60% demand

Verify 1CV8105 and 1CV8106 are OPEN

Throttle 1CV182 to maintain seal injection flow at 8-13 GPM per pump

Throttle 1CV121 to raise charging flow to 100 GPM

Open 1CV8152 and 1CV8160 o Open 1CV8149A

Open 1CV8149C

Adjust 1CV131 to control letdown pressure at 360 PSIG and place in AUTO

Adjust 1CV121 to match charging and letdown flow and restore Pzr level to Program Level and place in AUTO

Ensure 1CC130 is maintaining temperature at 90° to 115° and place in AUTO

Verify 1PR06J is in service BOP/RO o Control 1CV182 and 1CV121 as necessary to maintain seal injection flow at 8-13 GPM per pump BOP o Monitor Primary and Secondary panels o Assist RO with balancing charging and seal injection flow o Followup with BAR response US

Notify SM/WEC of failure, request IR Comments:

Byron ILT NRC 10-2 Page 8

Scenario NRC 10-2 Event 3 No: No.

Event

Description:

1CV8149B Failed Closed Time Position Applicants Actions or Behavior EVALUATOR NOTE: After the actions to restore letdown are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-2 Page 9

Scenario NRC 10-2 Event 4 No: No.

Event

Description:

1A SG LT-556 Fail Low Time Position Applicants Actions or Behavior CUE

Annunciator SG 1A LVL LOW-2 RX TRIP ALERT (1-17-A5) is LIT

Annunciator SG 1A LEVEL DEVIATION HIGH LOW (1-17-A9) is LIT

1LI-556 indicates 0% level

1A SG feedwater flow rising CREW o Refer to BARs.

Identify entry conditions for 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Implement 1BOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment E "NARROW RANGE SG LEVEL CHANNEL" and direct operator actions of 1BOA INST-2 BOP

Control 1A Feed Reg Bypass Valve in MANUAL

Lower 1A SG FW flow to match steam flow

Select an operable SG level channel

Re-establish automatic level control US

Perform pre-job brief per HU-AA-1211 for bistable tripping.

o Complete 1BOL 3.1, Attachment B, INSTRUMENT CONDITION TRACKING LOG.

Extra

Locally trip bistables for 1LT-556 / BOP verifies correct bistable operation.

NSO/

LB556B BOP

LB556C

Locally place AMS SW1 in TEST/BYPASS

Locally place AMS Operating Bypass SW12 to LSGA and SW11 to TEST-TRIP US

Determine TS 3.3.1 conditions A and E and TS 3.3.2 conditions A and D are applicable.

Determine TS 3.3.3 and 3.3.4 are NOT applicable - minimum channels operable requirement is met.

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

RO

Monitor primary for effects of feedwater transient

Assist BOP with annunciator response EVALUATOR NOTE: After the instrument failure has been addressed and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-2 Page 10

Scenario NRC 10-2 Event 5 No: No.

Event

Description:

Pzr LT-459A Failed High Time Position Applicants Actions or Behavior CUE

Annunciator PZR LEVEL HIGH RX TRIP STPT ALERT (1-12-A3) is LIT

Annunciator PZR LEVEL HIGH CONT DEV HTRS ON (1-12-C3) is LIT

1LI-459A indicates 100% level

Charging flow lowering CREW o Refer to BARs.

Identify entry conditions for 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Implement 1BOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment C "PRESSURIZER LEVEL CHANNEL FAILURE" and direct operator actions of 1BOA INST-2 RO

Perform the following at 1PM05J:

Place 1FK-121, CV pumps flow control valve, OR 1LK-459, PZR master level controller, in manual.

Raise demand on 1FK-121 OR 1LK-459 in conjunction with controlling demand on 1CV182 to raise charging flow.

Operate 1FK-121 OR 1LK-459 in manual to minimize PZR level drop and maintain 8-13 gpm RCP seal injection flow.

Select an operable Pzr level channel for control

Select an operable Pzr level channel to the recorder

Check Pzr level > 17%

Check Letdown established

Check Pzr heaters normal

Place 1FK-121, CV pumps flow control valve, OR 1LK-459, PZR master level controller, as appropriate, in automatic.

US

Perform pre-job brief per HU-AA-1211 for bistable tripping.

o Complete 1BOL 3.1, Attachment B, INSTRUMENT CONDITION TRACKING LOG.

Extra

Locally trip bistable for 1LT-459 / RO verifies correct bistable operation.

NSO/

LB459A RO US

Determine TS 3.3.1 conditions A and K are applicable.

Determine TS 3.3.3 and 3.3.4 are NOT applicable - minimum channels operable requirement is met.

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

Comments:

Byron ILT NRC 10-2 Page 11

Scenario NRC 10-2 Event 5 No: No.

Event

Description:

Pzr LT-459A Failed High Time Position Applicants Actions or Behavior BOP

Monitor secondary systems

Assist RO with annunciator response EVALUATOR NOTE: After the instrument failure has been addressed and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-2 Page 12

Scenario NRC 10-2 Event 6 No: No.

Event 1C CD/CB Pump Trip with manual start required

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator CD/CB PUMP TRIP (1-17-A9) is LIT US

Enter and direct actions of 1BOA Sec-1, Secondary Pump Trip

Notify SM of procedure entry and request EAL evaluation BOP

Check turbine load: NOT > 700 MW

Start a Standby CD/CB pump and check CD/CB flow restored

Check FW pumps not cavitating

Close 1CB113C

Check FW pump discharge flow: NOT oscillating RO o Monitor RCS Tave and reactivity effects caused by secondary feedflow changes.

o Assist BOP with BAR response RO/BO

Check Plant Status P o PDMS INOPERABLE alarm (1-10-D8) IS lit o 1BOL 3.h IS implemented o Control DI near target o Rod bank RIL alarm (1-10-B6) NOT lit o Turbine RB Light (OWS graphic 5501) is NOT lit o C-7 (BP 4.6) NOT lit US o IF RCS pressure lowers to less than 2209 PSIG, evaluate DNB TS 3.4.1 CREW

Restore Plant Conditions

Adjust RCS boron concentration as necessary

Verify controls for running equipment in - AUTO:

o TDFP o HD pump discharge o CB pump recircs o CD pumps recirc o GS condenser bypasses

Complete shutdown of tripped CD/CB pump per BOP CD/CB-2, CONDENSATE/CONDENSATE BOOSTER SYSTEM SHUTDOWN

Adjust SG blowdown flows and calorimetric inputs as necessary

Verify DEHC feedback loop in service

Notify Chemistry to monitor secondary chemistry o Complete applicable section(s) of 1BGP 100-4 (if runback performed)

Check Reactor power change > 15% in one hour. If so:

Notify Chemistry and RP to perform the power change surveillances EVALUATOR NOTE: After the actions for the CD/CB pump trip are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 10-2 Page 13

Comments:

Byron ILT NRC 10-2 Page 14

Scenario NRC 10-2 Event 7&8 No: No.

Event

Description:

1A Steam Generator Tube Rupture & Automatic Phase A Actuation Failure Time Position Applicants Actions or Behavior CUE

ALERT/ALARM on 1A Main Steam Line detectors 4AA122 and 4AA123

1A SG FW flow lowering

Pzr level lowering EVALUATORS NOTE: The crew may initially enter 1BOA SEC-8, Steam Generator Tube Leak. The actions are listed in italics below.

CREW

Identify entry conditions for 1BOA Sec-8, Steam Generator Tube Leak US

Direct the actions of 1BOA SEC-8 RO

Throttle open 1CV121 and 1CV182 attempting to maintain Pzr level

Lower letdown flow to 75 GPM

Report that Pzr level can NOT be maintained >17%.

US

Order crew to trip the reactor, verify the reactor trip, and actuate SI.

CREW

Identify entry conditions for 1BEP-0, REACTOR TRIP OR SAFETY INJECTION US

Order U-1 Reactor trip

Notify SM of plant status and procedure entry

Request evaluation of Emergency Plan conditions

Enter/Implement 1BEP-0 and direct operator actions of 1BEP-0 RO Perform immediate operator actions of 1BEP-0:

Step 1: Verify reactor trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

Neutron flux - DROPPING BOP Perform immediate operator actions of 1BEP-0:

Step 2: Verify Turbine Trip

All Turbine throttle valves - CLOSED

All Turbine governor valves - CLOSED

Step 3: Verify power to 4KV busses

ESF Buses - BOTH ENERGIZED (141 & 142)

US

Direct manual SI actuation RO/BOP

Manually actuate SI CREW

Step 4: Check SI Status Comments:

Byron ILT NRC 10-2 Page 15

Scenario NRC 10-2 Event 7&8 No: No.

Event

Description:

1A Steam Generator Tube Rupture & Automatic Phase A Actuation Failure Time Position Applicants Actions or Behavior o SI First OUT annunciator -NOT LIT o SI ACTUATED Permissive Light - LIT o SI Equipment - AUTOMATICALLY ACTUATED o Either SI pumps - RUNNING o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J US

Step 5: Direct BOP to perform Attachment B of 1BEP-0 EVALUATOR NOTE: US and RO will continue in 1BEP-0 while BOP is performing Attachment B:

BOP

Perform 1BEP-0 Attachment B

Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.

Verify DGs running at 1PM01J:

DGs - BOTH DGs running

1SX169A & B OPEN.

Dispatch operator locally to check operation

Verify Generator Trip at 1PM01J:

OCB 3-4 and 4-5 open.

PMG output breaker open.

BOP

Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

Supply fan

Return fan

M/U fan

Chilled water pump

Chiller

Operating VC train dampers - ALIGNED.

M/U fan outlet damper - NOT FULLY CLOSED.

VC train M/U filter light - LIT.

Operating VC train Charcoal Absorber aligned

Bypass damper - CLOSED

Inlet damper - OPEN

Outlet damper - OPEN

Control Room pressure greater than +0.125 inches water on 0PDI-VC038.

Comments:

Byron ILT NRC 10-2 Page 16

Scenario NRC 10-2 Event 7&8 No: No.

Event

Description:

1A Steam Generator Tube Rupture & Automatic Phase A Actuation Failure Time Position Applicants Actions or Behavior

Verify Auxiliary Building ventilation aligned at 0PM02J:

Two inaccessible filter plenums aligned.

Plenum A or B or C:

Fan - RUNNING

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED

Plenum A or B or C:

Fan - RUNNING

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED

Verify FHB ventilation aligned at 0PM02J:

Fan - RUNNING

Inlet Isolation damper - OPEN

Flow Control damper - OPEN

Bypass Isolation damper - CLOSED EVALUATOR NOTE: The remaining steps of Attachment B may be designated to be performed by WEC personnel or the Field Supervisor and extra operators.

o Trip all running HD Pumps o Shutdown FW pump as necessary using BOP FW-2 for a TDFP or BOP FW-8 for the MDFP o Shutdown unnecessary CD/CB Pumps using BOP CD/CB-2 o Align SX MDCT per BOP SX-T2 o Maintain SX Basin level > 80%

o Align NDCT o Verify CW intake bay level within band o Dispatch operator to locally verify NDCT basin level acceptable o Align NDCT per BOP CW-25 o Shutdown all unnecessary CW pumps per BOP CW-2 o Notify US that Attachment B is complete RO/

Step 6: Verify ECCS pumps running BOP

Both CV pumps - RUNNING

Both RH pumps - RUNNING

Both SI pumps - RUNNING BOP/

Perform the following at 1PM06J:

RO

Step 7: Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode lights - ALL LIT.

Step 8: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - NOT all LIT.

Comments:

Byron ILT NRC 10-2 Page 17

Scenario NRC 10-2 Event 7&8 No: No.

Event

Description:

1A Steam Generator Tube Rupture & Automatic Phase A Actuation Failure Time Position Applicants Actions or Behavior Comments:

Byron ILT NRC 10-2 Page 18

CREW

Manually actuate Phase A Isolation

[CT]

Group 3 Cnmt Isol monitor lights - ALL LIT E-0--O BOP/

Step 9: Verify Cnmt Vent isolation:

RO

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

Step 10: Verify AF system:

AF pumps - BOTH AF pumps RUNNING.

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

Step 11: Verify CC pumps - BOTH RUNNING.

Step 12: Verify SX pumps - BOTH RUNNING.

Step 13: Check if Main Steamline Isolation - NOT required:

o All SG pressure > 640 psig (at 1PM04J) o CNMT pressure < 8.2 psig.

Step 14: Check if CS is required.

CNMT pressure has NOT risen > 20 psig.

BOP/

Step 15: Verify Total AF flow:

RO

AF flow > 500 gpm

S/G NR levels - 1A SG level rising in an uncontrolled manner

CLOSE 1AF013A and 1AF013E RO/

Step 16: Verify ECCS valve alignment BOP

Determine Group 2 Cold Leg Injection monitor lights required for injection - All lit RO/

Step 17: Verify ECCS flow BOP

High Head SI flow >100 gpm (1FI-917)

RCS pressure > 1700 psig RO

Step 18: Check PZR PORVs and SPRAY VALVES at 1PM05J:

1RY455 & 1RY456 CLOSED

PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED

PORV relief path - Both PORVs in AUTO, Both isolation valves - OPEN.

Normal PZR Spray Valves CLOSED RO

Step 19: Maintain RCS temperature control at 1PM05J:

Check RCPs - ALL RUNNING.

o

Verify RCS average temperature stable at or trending to 557 F.

Throttle AF maintaining >500 GPM until SG minimum level is met RO

Step 20: Check status of RCPs at 1PM05J:

All RCPs - ALL RUNNING.

Comments:

Byron ILT NRC 10-2 Page 19

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

Step 21: Check if SG secondary pressure boundaries are intact at 1PM04J:

RO

Check pressure in all SGs:

NO SG dropping in an uncontrolled manner.

BOP/

Step 22: Check S/G tubes are NOT intact at RM-11 console:

RO

1PR08J SG Blowdown

1PR27J SJAE/GS - IN ALERT/ALARM

1AR22/23A Main steam Lines - Trending up or in ALERT/ALARM CREW Transition to 1BEP-3, Steam Generator Tube Rupture US Implement 1BEP-3 "STEAM GENERATOR TUBE RUPTURE and direct operator actions.

Notifies SM of BEP entry

Requests Emergency Plan evaluation RO Check status of RCPs and determine all running If any running, Check trip criteria NOT satisfied

HHSI flow >100 gpm OR SI flow > 200 gpm AND

RCS pressure > 1425 psig CREW Identify ruptured SG Unexpected rise in NR level Main steamline rad monitor 1RT-AR022 Grid 1 4AA122 1RT-AR023 Grid 1 4AA123 High activity for any SG sample

Reset CNMT isol Phase A

Notify Chem to locally sample

Open SG blowdown sample valves at Chem request

Identify 1A SG ruptured BOP/ Isolate flow from ruptured SG by verifying RO

SG PORV MS018A in AUTO

Check SG PORV MS018A closed

[CT]

Verify closed when SG pressure < 1115 psig E-3A

Verify SG blowdown valves closed unless open for sampling

1SD002A (critical

1SD002B steps

Close MSIV and MSIV bypass valves for 1A SG are bold)

Check PORVs on intact SGs available for RCS cooldown Check ruptured SG level Comments:

Byron ILT NRC 10-2 Page 20

Narrow Range >10%

Verify/Close AF isol valves (should have been closed earlier in 1BEP-0)

1AF013A

1AF013E BOP Check ruptured SG pressure o Ruptured SG pressure greater than 320 psig Crew

Initiate RCS cooldown

Determine required CETC from table (step 6a)

RO/

Check Pzr Pressure - >1930 #

BOP

When < 1930#, block Steamline Isol SI BOP

Dump steam to condenser from intact SGs at maximum rate using steam dumps or SG

[CT] PORVs E-3--B o Check steam dumps available

Place MS controller in Manual, reduce demand to 0

Select Steam Pressure Mode

Adjust MS controller to initiate cooldown o When necessary, bypass P-12 interlock using Bypass Interlock Switches A & B o Dump steam at maximum rate using SG PORVs Crew

Check average of 10 highest CETC - < required temperature from step 6a Crew

Continue with step 7; come back to step 6f when cooldown target temperature is achieved.

BOP

Check intact SG levels > 10%

Control FF to maintain NR levels 30 - 50%

RO

Check Pzr PORVs and isolation valves

PORV isolation valves energized

PORVs closed

PORV isolation valves both open RO/

Reset SI BOP

Verify SI actuated permissive light NOT LIT

Verify Auto SI blocked light LIT RO/ Reset Phase A isolation BOP Crew

Verify all AC busses energized by offsite power BOP

Establish IA to containment

Check SACs- any running

Open 1IA065 and 1IA066 CREW

Check if RH pumps should be stopped

Any RH pump running and aligned to RWST

RCS pressure >325#

Stop both RH pumps CREW

Check if RCS Cooldown should be stopped Comments:

Byron ILT NRC 10-2 Page 21

Ave of 10 highest CETC < required temperature in Step 6

When met, stop cooldown and maintain temperature < required temperature CREW

Check ruptured SG pressure - stable for plant conditions CREW

Check RCS subcooling - acceptable per figure 1BEP 3-2 and Attachment A RO/

Depressurize RCS BOP

Normal Spray -available RO

Depressurize RCS using maximum available spray until

[CT] o RCS Pressure < Ruptured SG pressure and Pzr level > 12%

E-3--C o Pzr level > 69%

o RCS subcooling NOT acceptable

Close spray valves CREW

Check if ECCS flow should be terminated

RCS subcooling - Acceptable

Secondary heat sink o > 500 FF to SG - available o At least 1 intact SG > 10% NR

RCS pressure - rising

Pzr level > 12%

RO/

Stop both SI pumps and 1 CV pump BOP EVALUATOR NOTE: When the CREW determines SI should be terminated, conclude the scenario.

Comments:

Byron ILT NRC 10-2 Page 22

Simulation Facility Byron Scenario No.: Operating Test No. 2010 ILT NRC 10-2 Examination Examiners: Applicant: SRO RO BOP Initial Conditions: IC-151 Turnover: Unit 1 is at 12% power, BOL, ready to synchronize Main Generator. Online risk is green. CBD @

147 steps, and boron concentration is 1300 ppm. 1BGP 100-3, step F.27 is the next step to perform.

Steam dump demand must be raised to 25% to 35% as directed by step 23.o. The offgoing shift has just diluted 100 gallons. 1A MDFP is OOS for maintenance.

Event No. Malf. No. Event Event Type* Description 1 R (RO, Power ascension SRO) 2 N (BOP, Synchronize Main Generator to grid SRO) 3 IOR ZDI1CV8149B CLS C (RO, 75 GPM LD Isolation Valve 1CV8149B Fail Closed SRO) 4 MF RX06D 0 I (BOP, 1A SG LT-556 Fail Low (controlling channel)

SRO) TS (SRO) 5 MF RX13A 100 I (RO, SRO) Pzr 1LT-459A Fail High (controlling channel)

TS (SRO) 6 MF FW22C C (BOP, 1C CD/CB Pump Trip with manual start required SRO) 7 MF TH03A 400 M (ALL) 1A SGTR (normal cooldown and depressurization) 8 MF RP04A, RP04B C Automatic Phase A Isolation Actuation Failure (manual (SRO/BOP) required)

(N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient Deleted Event 6, not required for evaluation, did not affect scenario, interest of saving exam time.