ML13169A171

2013 Byron Nuclear Station Initial License Examination Administered Simulator Scenarios

ML13169A171
Person / Time
Site:	Byron
Issue date:	04/29/2013
From:	NRC/RGN-III/DRS/OLB
To:	Exelon Generation Co
References
50-454/13-301, 50-455/13-301
Download: ML13169A171 (96)

Text

Facility: _Byron Nuclear Station Scenario No.: __1__ Op-Test No.: _2013301_

Examiners: _D. McNeil__________________ Operators: _____________________________

_R. Baker___________________ _____________________________

_D. McNeil__________________ _____________________________

Initial Conditions: __IC-22____________________________________________________________

Turnover:

Unit 1 is at 100% power, steady state, equilibrium xenon; MOL. Unit output is 1203.4 MW. Boron concentration is 892 ppm. Online risk is green. A TV/GV surveillance is scheduled to be performed. The unit will be ramped to 89% power at 3MW/min for the surveillance.

Event Event Event No. Malf. No.

Type* Description ZDI 11CS01PB(2) PTL IRF ED071G OPEN IOR ZLO1CS010B1- OFF 1B CS pump O.O.S.

IOR ZDI1CS010B-CLS 1CS007B OOS IRF ED063H- OPEN 1CS010B OOS IRF ED063G OPEN 1CS0010B close IRF ED071C OPEN 1CS019B OOS Preload IMF RP26C 1CS009B OOS IMF RP28C 1CS001B OOS Trgset 3 ESF relay failure of 1A RH pump zdi1fw012c(1).gt.0 ESF relay failure of 1B RH pump Trg 3 dor zlo1fw012c1 1FW012C recirc valve fails open. Manual close available.

Trgset 5 fwv1fw012c.gt.0.9 Trg 5 ior zlo1fw012c1 off R (RO)

(SRO) 1 Ramp down for TV/GV surveillance N (BOP, SRO)

IMF PA0253 ON 2 IMF PA0252 ON TS (SRO) S/G PORV 1MS018A Inop IOR ZDI1MS018A CLS I (BOP, 3 IMF FW16 0 1PT508 fails low SRO)

C (RO, 4 IMF CV10 200 60 134 1CV121 slowly fails open. Manual control is available.

SRO)

I (RO, SRO) 5 IMF RX10A 0 30 1PT 505 fails low TS (SRO)

Loss of IB 114 due to a bus fault. Tech Spec 3.8.9 required 6 IMF ED11D TS (SRO) shutdown within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> Ramp fwv1FW012C 1 1 C (BOP, 7 1FW012C recirc fails open 1200 SRO) 8 IMF TH04C 540000 M (all) LB LOCA terminating in transfer to Cold Leg Recic ESF relay failure of 1A & B RH pumps - manual start 9 Pre-load C (all) required

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

SCENARIO OVERVIEW Unit 1 is at 100% power, steady state, equilibrium xenon, MOL. Online risk is green. CBD @ 221 steps, and boron concentration is 892 ppm. 1BOSR 3.g.4-1, Turbine Throttle and Governor Valve surveillance is scheduled later on in this shift and requires the unit to be ramped to 89% power at 3MW/min. The 1B CS pump is O.O.S. for pump impellor replacement. Grid status is green. Unit status is yellow based on the CS pump work window.

After completing shift turnover and relief, the crew will ramp the unit to 89% power at 3MW/min After the ramp is in-progress, steam generator 1A atmospheric relief valve 1MS018A, will develop a hydraulic leak. The Unit Supervisor will enter Tech Spec 3.7.4, Condition A and Tech Spec 3.6.3, Condition C. The crew will dispatch an operator to close 1MS019A to comply with TS 3.6.3, condition C. 1MS018A will remain unavailable for the remainder of the scenario. On line risk remains green.

After the Unit supervisor makes the TS call, 1PT 508 will fail low causing feed pump speed to rise. The BOP will respond and manual FW pp speed control will be available. AUTOMATIC operation of Feedwater pump speed control will not be available for the remainder of the scenario.

After the 1PT-508 failure has been addressed, 1CV121 will slowly fail in automatic. The RO will take manual control and restore normal charging flow. AUTOMATIC operation of 1CV121 will not be available for the remainder of the scenario.

After the crew has taken actions for the failure of 1CV121, turbine impulse pressure channel 1PT-505 will fail low over a 30 second period. Control rods will begin automatically inserting. After recognizing the instrument failure and checking turbine power stable, the RO will place rod control in manual to stop the inward rod motion. 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment D, will be implemented. The crew will defeat the failed instrument and the RO will restore Tave - Tref deviation. Technical specification 3.3.1, conditions A and P apply.

After the PT-505 failure is addressed, a loss of IB 114 will occur due to a fault on the instrument bus, This will require performance of BOA ELEC-2 to stabilize and recover the plant. The US will address Tech Spec 3.8.9, which requires a shutdown to Hot Standby within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. Several actions will be required as a result of not being able to power the Instrument Bus. These include implementation of 1BOA Instrument 1 for the failed N.I. Channel and dispatching an EO to fail open 1AF005E-H and locally controlling flow as needed or using 1AF013E-H After the Unit Supervisor has evaluated the failed Instrument Bus, 1FW-012C fails open. The BOP will take manual control and restore normal feedwater flow.

After normal feedwater flow is restored and the plant stabilized, a LB LOCA occurs in the 1C hot leg.

The crew will respond utilizing 1BEP-0, 1BEP-1 and will eventually transition to 1BEP ES-1.3 Transfer to Cold Leg Recirculation. 1A and B RH pumps will fail to start on the SI signal but start if a manual start is attempted. The cause of the auto start failure is two ESF relay failures. Additionally, all B Train ESF equipment will NOT auto start due to the failed instrument bus. Containment pressure will rise to the phase B actuation setpoint requiring the RCP to be tripped.

Completion criteria is selection of and transition to 1BEP ES-1.3, Transfer to Cold Leg Recirculation and completion of the first 7 steps.

Page 2

Critical Tasks

1. Manually start at least 1 RH pump.

(ERG Critical Task number - E-0--H)

2. Swap to Cold Leg Recirc.

(ERG Critical Task number - ES-1.3--A)

SIMULATOR SETUP GUIDE:

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

• Establish the conditions of IC 22, 100% 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).

• Verify RM-11 is on grid 1. Ensure horns are turned ON. Set BA and PW controllers to Rema numbers or 0 and reset.

• Place Turnover and ReMa, 1BGP 100-4T3 and Load Change Instruction Sheet on desk

• Ensure Rema placard is updated

• Ensure rods are in auto.

• Align U-0 CC HX to U-2 to avoid distracting alarm

• Place O.O.S. cards on 1B CS pump

• Provide candidates with 1BGP 100-4T3, Load Change Instruction Sheet and ReMa In caep NRC 13-1.cae from thumb drive and verify the following:

• IMF RP26C

• IMF RP28C

• Trgset 1 zdi1fw012c(1).gt.0

• Trg 1 ramp fwv1fw012c 1 0 7

• Trgset 3 zdi1fw012c(1).gt.0

• Trg 3 dor zlo1fw012c1

• Trgset 5 fwv1fw012c.gt.0.9

• Trg 5 ior zlo1fw012c1 off Page 3

Page 4 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Ramp to 89% power for TV/GV surveillance SM acknowledge start of ramp when notified.

TSO acknowledge start of ramp when notified.

In order to get rods control back in auto prior to event 5, as soon as the Chief Examiner is satisfied with the reactivity change, call the Unit Supervisor as Shift Manager and report that TSO may need Byron U-1 to return to 100% power, stop the ramp and return rods to automatic.

Event 2: SG PORV 1MS018A inoperable (Tech Spec)

Insert the following from the CAEP and verify the following actuate:

• IMF PA0252 ON

• IMF PA0253 ON

• IOR ZDI1MS018A CLS As SM acknowledge the failure, LCO 3.6.3, condition C and LCO 3.7.4, condition A, and requests for on line risk assessment, maintenance support, and IR initiation.

If dispatched as EO, report 1MS018A has a broken hydraulic line and a small puddle of hydraulic fluid is present beneath the valve.

As WEC supervisor. acknowledge request for EST for 1MS018A C/S, if EST is requested.

If dispatched as EO to close 1MS019A, perform the following:

• MRF MS51 0 Event 3: Feedwater header pressure 1PT508 fails low.

As WEC or Extra NSO, acknowledge request to trip bistables.

SM Acknowledge entry into TS SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

SM is to prompt the crew to stop the ramp and place control systems into automatic (specifically Rod Control) if they have not done this previously. SM states his desire to stabilize the plant.

Page 5

Event 4: 1CV121, fails open in auto. Manual control is taken. This valve will remain in manual through out the rest of the scenario.

Initiate event after load ramp down is commenced, with the lead examiners concurrence.

Acknowledge info to SM, WEC, and maintenance.

SDG: CV5 IMF CV10 200 180 134 If the crew decides to isolate 1CV-121 refer to:

SDG: CV5 Throttle Open 1CV8387A and Close 1CV8483A Event 5: Turbine impulse pressure 1PT505 fails low NOTE: Ensure control rods are in AUTO before inserting this MF.

Insert IMF RX10A 0 30 to fail 1PT-505 low over a 30 second period.

If lead examiner desires the bistables tripped, participate in brief and perform the following:

• As extra NSO contact Unit 1 (X-2209)

• Insert the following:

• MRF RP20 OPEN (open protection cabinet #1 door)

• MRF RX143 TRIP (trip turbine power P-13 bistable PB505A)

• MRF RP20 CLOSE (close protection cabinet #1 door)

If lead examiner desires the AMS bistables tripped, participate in brief and perform the following:

• As extra NSO contact Unit 1 (X-2209)

• Insert the following:

• MRF RX 149 SW12 to TIP1

• MRF RP91 Test-Trip Switch to Test-Trip (place operating bypass input switch 11 to test-trip)

Acknowledge as Shift Manager the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.

If the Lead Examiner does not desire to see bistables tripped, then inform the crew as Shift Manager when called that the bistables will be tripped when personnel are available in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />..

Page 6

Event 6: Event 5 Loss of Instrument Bus 114 Initiate event after event 4 actions are completed, with the lead examiners concurrence. Acknowledge info passed to SM, WEC, and maintenance. When asked, report the bus appears to be damaged and the Inverter 114 AC output breaker is tripped.

SDG: ED7 IMF ED11D SDG FW13 If the crew decides to fail the B train AF005 valves open, utilize the following malfunctions:

IMF FW45E, F, G, and H to 100 (to fail open)

To throttle the same valves use Remote Functions FW161 (E), 162 (F), 163 (G) and 164 (H) to use the Manual Handwheel to the desired position.

Event 7: 1C FW pump recirc valve (1FW012C) fails open in auto, manual closure will function Ramp FWV1FW012C I I 08:00:00 Have trigger ramp 1FW012C closed over 7 seconds (stroke time) when CS taken to close If dispatched as EO to investigate 1FW-012C, report valve is responding normally.

SM acknowledge failure, online risk evaluation and IR initiation Event 8: Large Break LOCA with failure of ESF start relays on both RH pumps, requiring manual start, which functions IMF TH04C Large Break LOCA on 1C Hot leg.

SM acknowledge procedure entry and E Plan evaluations.

After entering 1BEP-1, at about step 5, the STA notifies the crew that a red path condition exists and recommends 1BFR P.1 be implemented.

If requested to de-energize 1cv112D and and 1CV112E 112D - MRF ED053O to OPEN 112E - MRF ED071J to OPEN To vary SX flow to U-0 CC HX use sim dwrg SW2 and vary 0SX007 to 40%

If the crew decides to fail the B train AF005 valves open, utilize the following malfunctions:

IMF FW45E, F, G, and H to 100 (to fail open)

To throttle the same valves use Remote Functions FW161 (E), 162 (F), 163 (G) and 164 (H) to use the Manual Handwheel to the desired position Event 9: LOCA 1A and 1B RH pump relay failure requiring manual start (In Preload) IMF RP26C and RP28C to prevent SI auto start of 1A and 1B RH pumps.

Page 7

Page 8 Scenario No: 001 Event No. 1 Event Ramp unit to 89% power

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Provide candidates with 1BGP 100-4T2 or T3, Load Change Instruction Sheet and ReMa US

• Implement 1BGP 100-4T2 or T3 for a normal ramp

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

• Instructs RO to conduct reactivity brief NOTE to Evaluator: The crew should calculate about 125 total gallons of boron to add in about 20 to 40 gallon batches RO

• Conducts reactivity brief

• Set up boration IAW ReMa and BOP CV-6

• Places rods to manual

• Energizes PZR back-up heaters

• 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 100-4T3

• Enter desired ramp rate (3 from ReMa) in the RATE window

• Press ENTER

• Enter desired MW output (from ReMa) in the REF DEMAND window (1118)

• Press ENTER

• Press GO/HOLD

• Press GO and verify load lowers

• Initiate ramp

• Coordinate ramp with boration by RO.

EVALUATOR NOTE: When reactivity ramp observation is accomplished and at evaluators cue, the second event will be inserted.

Comments:

Byron NRC 13-1 Page 9

Scenario No: NRC 001 Event No. 2 Event SG PORV 1MS018A inoperable

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator S/G 1A PORV TROUBLE (1-15-A10).

• SER 0252, 1A PORV HYDRAULIC FLUID RESERVOIR LOW.

• SER 0253, S/G PORV 1A ACCUMULATOR PRESSURE LOW.

BOP o Identify/report trouble alarm on 1MS018A.

o Refer to BAR 1-15-A10.

o Dispatch operator to 1MS018A.

• Place 1MS018A C/S in close at 1PM04J to stop hydraulic pump.

Request Equipment Status Tag for 1MS018A.

RO

• Assist BOP as requested. Refer to BARs as available.

• Monitor reactivity changes

• Adjust reactivity with turbine ramp o Rods o Boron US

• Identify entry conditions for TS 3.7.4, condition A Restore to Operable in 30 days

• Identify entry conditions for TS 3.6.3, condition C.: Close 1MS019A in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and verify closed once per 31 days

• Direct operator to close 1MS019A US

• Inform SM of 1MS018A status, TS Status, request IR, On Line Risk Assessment, maintenance support, and clearance order/EST for 1MS019A.

EVALUATOR NOTE: After the actions for the 1MS018A failure are complete and with lead examiners concurrence, insert the next event.

Comments:

Byron NRC 13-1 Page 10

Scenario No: NRC 001 Event No. 3 Event 1PT508 fails LOW

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator SG 1_ LEVEL DEVIATION HIGH LOW(1-15-A9/B9/C9/D9)

• FWRVs (1FW510/20/30/40) closing

• 1B/1C FW turbine speed rising

• 1A/B/C/D SG levels rising

• Master Feed Pump Speed controller output rising RO/

• Determine 1PT508 is failing LOW BOP

• Reference BARs as time permits BOP

• Determine all SG levels are rising

• Take manual control of Feed Pump Speed Master Controller Individual Feed Pump Speed Controllers

• Lower feed pump speed to recover S/G levels Uses alternate pressure indication (1PI-FW015)

Establishes proper d/p for power level using alternate indication per placard Remove controller integral by momentarily going to manual on each FWRV US

• Notify SM of PT-508 failure, request IR, and maintenance.

CREW

• Check SG levels normal and stable NOTE: FW pp speed control will be in manual for the remainder of the scenario NOTE: Ensure ramp is stopped and rods are placed back in auto before continuing.

EVALUATOR NOTE: After the actions for PT-508 are complete and with Lead Examiner concurrence, insert event 4.

Comments:

Byron NRC 13-1 Page 11

Scenario No: NRC 001 Event No. 4 Event 1CV121 fails open in auto.

==

Description:==

Time Positio Applicants Actions or Behavior n

CUES: Annunciators:

• 1-9-D3 CHG LINE FLOW HIGH LOW

• 1FI-121A Charging Header Flow rising o 1LI-112 VCT level lowering RO

• Place 1FK-121 in MANUAL

• Lower charging flow

• Balance charging flow with letdown to restore and stabilize Pzr level

• Identify/report failure of 1CV-121 Comments:

Byron NRC 13-1 Page 12

Scenario No: NRC 001 Event No. 5 Event 1PT505 fails low

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator 1-14-D1, TAVE CONT DEV HIGH

• 1PI-505, first stage pressure, indication lowering.

• Bypass Permissive C-5 Turbine Low Power annunciates

• Bypass Permissive C-20 AMS Permissive annumciates

• Control rod inward motion.

• 1TR-0412, Auct Tave/Tref recorder, Tref indication dropping

• 1SI-412, Rod Speed, indicates 72 step per minute

• Steam Dump Actuated light LIT on 1PM02J RO/BO

• Perform the following at 1PM05J:

P

• Determine control rods inserting.

• Identify 1PT-505 is failing low.

• Report failure to US

• Determine turbine power stable at 1PM06J or OWS drop 210.

• Place rod bank select switch to manual at 1PM05J to stop uncontrolled rod insertion.

CREW

• Reference BARs 1-14-D1.

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

o The crew may enter 1BOA ROD-1, Uncontrolled Rod Motion, if they do, the steps they will take are italicized below

• Check turbine power stable

• Check Rods in manual, if not place in manual

• Check power range N.I.s operable

• Check Tave instruments operable

• Check Turbine first stage pressure operable

• Go to 1BOA Inst. 2 Operation with a failed Instrument Channel, Attachment D 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 D "TURBINE IMPULSE PRESSURE CHANNEL FAILURE" and direct operator actions of 1BOA INST -2 to establish the following conditions.

RO/BO

• Restore steam dumps.

P

• Check C-7 bypass permissive NOT LIT at 1PM05J.

• Perform the following at 1PM02J:

• Place 1PK-507, MS header pressure controller, in manual.

• Lower 1PK-507 demand to 0%.

Comments:

Byron NRC 13-1 Page 13

Scenario No: NRC 001 Event No. 5 Event 1PT505 fails low

==

Description:==

Time Position Applicants Actions or Behavior

• Place steam dump mode select switch to STM PRESS mode.

• Place 1PK-507 in auto.

• Check reactor power <100 % on NIs

• Defeat 1PT-505 at 1PM05J

• Place 1PS505Z, turbine impulse pressure defeat C/S, to DEFEAT 505 RO

• Check if rod control can be placed in auto

• Check C-5 bypass permissive LIT at 1PM05J.

• Check Tave/Tref stable and within 1°F.

• 1TR-412 at 1PM05J

• PPC display o Adjust Tave - Tref within 1°F by manually withdrawing control rods at 1PM05J Place rod bank select switch in AUTO.

RO/

• Check P13 interlock BOP

• Turbine power > 10%

• Check P-13 bypass permissive NOT LIT at 1PM05J NOTE to Evaluator: The next 4 steps may be bypassed for tripping by bistables and then go directly to the Tech Spec. portion of the exam at the end of this page.

US Direct or perform pre-job brief per HU-AA-1211 for bistable tripping.

Extra o Locally trip bistable for PT-505/BOP verifies correct bistable operation at 1PM05J.

NSO/ o PB505A - C1-742 BS-1.

BOP Extra

• Check status of AMS system NSO

• Operating Bypass switch in OFF locally.

Extra

• Locally trip bistables for AMS/BOP verifies correct bistable operation at 1PM05J.

NSO/

• Place Operating Bypass switch to TIP-1 locally.

BOP

• Place Operating Bypass Input to TEST-TRIP locally.

US

• Determine TS 3.3.1 conditions A and P are applicable:

• Condition A: Enter table immediately

• Condition P: Verify interlock is in required state for existing unit conditions in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in MODE 2 in 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

• Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure and rod control malfunction NOTE: After the actions for the turbine impulse pressure channel failure are complete and with Lead Examiners concurrence, insert event 6.

Comments:

Byron NRC 13-1 Page 14

Comments:

Byron NRC 13-1 Page 15

Scenario No: NRC 001 Event No. 6 Event Loss of Instrument Bus 114

==

Description:==

Time Positio Applicants Actions or Behavior n

CUES: Annunciators:

• 1-3-D7 AF FLOW CONT VLV SETTING LOW

• 1 D5 BUS 114 INVERTER TROUBLE and numerous (6) others on this alarm module.

• 1-10-A3 PWR RNG HIGH STPT RX TRIP ALERT and numerous (~10) others on this module.

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

• 1-13-A2 RCP BUS UNDERVOLTAGE RX TRIP ALERT

• 1-13-B2 RCP BUS UNDERFREQUENCY RX TRIP ALERT

• 1-13-D3 RCP 1D BRKR OPEN OR FLOW ALERT

• 1-18-A4 TURB STOP VLV CLOSED ALERT

• 1-18-E16 C-16 STPT EXCEEDED

• The right side of 1PM07J (NIs) is DARK including PR N44 RO/US Identify/report failure of Instrument Bus 114.

US Refer to 1BOA ELEC-2 for operator actions RO/ Verify control channels are operable for BOP

• PZR pressure

• PZR level

• Tave

• Delta-T

• P Impulse

• SG level

• Steam flow

• Feed flow US o Rods to Manual RO Comments:

Byron NRC 13-1 Page 16

Scenario No: NRC 001 Event No. 6 Event Loss of Instrument Bus 114

==

Description:==

Time Positio Applicants Actions or Behavior n

RO/US

• Prepare to energize Bus 114 from the CVT: (Directing EO actions in the field)

• Verify OPEN

• Inverter 114 Output breaker

• Bus 114 Main feed breaker o Verify CLOSED Instr. Bus 114 CVT Feed bkr o Close Inst. Bus 114 CVT Input bkr NOTE: EO will report BUS DAMAGE

• Contact EMD to investigate damage to bus 114.

• Notify Shift Manager

• Perform actions associated with 1BOA INST see next step.

• Refer to Tech Specs 3.8.9 Condition B for action

• Condition B: Restore I.B. in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> (if not restored go to Cond. D)

• Condition D: If Condition B not met, be in Mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hrs.

• Direct local Inverter 114 shutdown.

Review Table D impacts for loss of Inst Bus 114 (Below is a portion of the list that will be impacted at this time.)

o Train B ESF loads will require manual actuation and no reset.

o Rods will not withdraw in Manual o PORV 1RY455A will not open in Auto o VCT Auto makeup will not occur.

o 1AF005E-H will close as soon as flow starts and cannot be controlled from the MCR.

o 1SD054A-D, SD Blowdown failed closed o RCPs 1D and 1B Seal Leakoff Flow Recorders are inoperable o 1PR-403, RC WR Pressure recorder is inoperable o PR N44 is lost o SR audio counts are lost o Several TSLBs lit and 1PM05J CRTs are lost NOTE: Actions in 1BOA INST-1 are contained on the next page (IF evaluator deems this action is necessary). These can be deferred to a request for additional NSOs to assist.

With the bus damaged, this is directed action as part of this BOA action.

If action is taken in 1BOA Inst-1, the first 6 steps are included on the next page.

The steps to remove computer points from scan (step 7) and the bypassing or tripping of bistables associated with the failed channel have intentionally been omitted from this document Comments:

Byron NRC 13-1 Page 17

Scenario No: NRC 001 Event No. 6 Event Loss of Instrument Bus 114

==

Description:==

Time Positio Applicants Actions or Behavior n

BOA INST-1 Actions

• Rod Bank Selector switch to Manual

• Check for Rod Stop

• PWR RNG FLUX HIGH ROD STOP -LIT

• Place Rod stop bypass switch for N-44 on 1PM07J in BYPASS

• Check Tave-Tref stable and within 1°F o Adjust rods/boron/turbine load as necessary

• SG levels NORMAL

• Bypass/Defeat PR Channel Functions at 1PM07J

• Upper section and Lower section Current Comparator

• Misc Control and Indication section

• Power mismatch bypass

• Rod stop bypass

• Camparator and Rate Panel

• Comparator Channel Defeat

• Check Flux Rate Trip Alarm

• Reset N-44 at 1PM07J The crew may fail air to the 1AF-005E-H and direct an EO to locally throttle these valves using the associated handwheels, if needed.

BOP Monitor plant for effects, address BARs, and take any actions directed by the US NOTE: When actions have been completed to respond to loss of Inst Bus 114 and Lead Evaluators concurrence, Event 7 is entered.

Comments:

Byron NRC 13-1 Page 18

Scenario No: NRC 001 Event No. 7 Event 1FW012C fails open

==

Description:==

Time Position Applicants Actions or Behavior EVALUATOR NOTE: Depending on how far the crew has ramped the unit, will determine if all actions listed below will occur. The automatic actions associated with FW pp NPSH low alarm will only occur if FW pump suction pressure reaches 400 psig CUE

• Annunciator 1-16-D2, FW PUMP DISC FLOW HIGH

• Annunciator 1-16-E1, FW PUMP NPSH LOW

• Annunciator 1-15-A/B/C/D4, SG 1_ FLOW MISMATCH FW FLOW LOW

• Open light lit on 1FW012C

• FW flow to all SG LOWERING

• SG level LOWERING o FWRVs OPENING BOP

• Recognizes 1C FW pp recirc valve, 1FW12C, OPEN

• Takes 1FW012C control switch to close CREW o Review BARs

• Monitor primary and secondary panels as BOP responds to FW malfunction BOP o Reviews automatic actions for NPSH LOW annunciator o Standby Cond/Cond Bstr pump STARTS o 1CD157A/B, GS Cond. Bypass valves, OPEN o 1CD152, Cond. PPs Recirc Valve CLOSES o 1HD046A/B, Heater Drain PP Combined Disch. Valves OPEN US

• Notify SM for IR EVALUATOR NOTE: After the actions to close 1FW012C are complete and with lead examiners concurrence, insert event 8.

EVALUATOR NOTE: If the crew trips the unit based on the FW transient the LOCA will be inserted at step 2 of 1BEP ES 0.1. The first 4 steps of 1BEP-0 along with the transition to ES 0.1 step 2 are included below.

CUE

• Reactor Trip first out annunciator

• Rod Bottom Lights

• Automatic or manual reactor trip CREW

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

• 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 Comments:

Byron NRC 13-1 Page 19

Scenario No: NRC 001 Event No. 7 Event 1FW012C fails open

==

Description:==

Time Position Applicants Actions or Behavior

• 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)

CREW

• Check SI Status

• SI First OUT annunciator -NOT LIT

• SI ACTUATED Permissive Light - NOTLIT

• SI Equipment - NOT ACTUATED

• Check if SI is required o Pzr Press > 1829 psig o Steam Line Press > 640 psig o Cont. Pressure < 3.4 psig Crew

• Transition to 1BEP ES-0.1 Reactor Trip Response, step 1 US

• Notify SM of plant status and procedure entry

• Request evaluation of Emergency Plan conditions

• Enter/Implement 1BEP ES-0.1 and direct operator actions

• Request STA to monitor Status Trees RO

• Check RCS Average Temperature stable or trending to 557 degrees

• Check Shutdown reactivity status

• Rod bottom lights-All Lit

• RCPs- Any Running EVALUATOR NOTE: If the crew tripped due to the feedwater transient, then initiate the next event (Large Break LOCA).

Comments:

Byron NRC 13-1 Page 20

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Pzr level is dropping

• Annunciator CNMT PRESS HIGH (0-33-D6) is LIT

• Automatic reactor trip and/or safety injection actuation CREW

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

• 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)

CREW

• Check SI Status

• SI First Out annunciator -LIT

• SI ACTUATED Permissive Light -LIT

• SI Equipment - ACTUATED

• Either SI pump - RUNNING

• Either CV pump to cold leg isolation valve - OPEN - 1SI8801A Note: examinee may open 1SI8801B at this time

• 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 EVALUATOR NOTE: The crew may identify 1A/B RH pumps are not running and may start them before step 6.

If evaluating either the SRO or RO move to step 6 on page 19 BOP Attachment B actions for the BOP are as follows:

• Verify FW isolated at 1PM04J:

• FW pumps - TRIPPED.

• Isolation monitor lights - LIT.

Comments:

Byron NRC 13-1 Page 21

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior

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

• Verify DGs running at 1PM01J:

• DGs - BOTH DG 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 for train B.

• 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:

• 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

• Check 1 AB exhaust fan running for every running supply fan

• Verify 1 FHB ventilation aligned at 0PM02J:

• Fan - RUNNING Comments:

Byron NRC 13-1 Page 22

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior

• 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 Maintain UHS basin level greater than 80%

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 Initiate periodic checking of spent fuel cooling o Locally verify Spent fuel pool level is > 420 Elev o Locally verify SFP temperature stable o Notify STA of SFP cooling status Notify US that Attachment B is complete and actions taken RO/

• Step 6: Verify ECCS pumps running BOP

• Both CV pumps - RUNNING

[CT]

• Manually start 1B CV pump due to loss of I.B. 114 E-0--J

• Both RH pumps - RUNNING

• Manually start 1A and 1B RH pumps prior to completion of step 6 of 1BEP-0.

• Both SI pumps - RUNNING

• Manually start 1B SI pump due to loss of I.B. 114 BOP/

• Perform the following at 1PM06J:

RO

• Step 7: Verify RCFCs running in Accident Mode:

• Group 2 RCFC Accident Mode lights - 4 LIT.

• STOP 1B RCFC in Fast Speed

• CLOSE CNMT chiller inlet and outlet valves 1SX112B and 1SX114B

• OPEN CNMT chiller bypass valve o OPEN RCFC inlet and outlet valves 1SX016B and 1SX027B

• START B and D RCFCs in LO speed Comments:

Byron NRC 13-1 Page 23

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior

• Step 8: Verify Phase A isolation:

• Group 3 Cnmt Isol monitor lights - ALL LIT. NOTE: NOT MET

• Manually Actuate CNMT ISOL Phase A o Manually close valves o Any valve outside of CNMT locally CLOSE while continuing with step 9

• Step 9: Verify Cnmt Vent isolation:

• Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

o Verify MSIV and Bypass Valves - CLOSED BOP/

• Step 10: Verify AF system:

RO

• AF pumps - BOTH AF pumps RUNNING. Note: B pump is NOT

• Start 1B AF pump

• AF isolation valves - 1AF13A-H OPEN.

• AF flow control valves - 1AF005A-H THROTTLED. (NOTE: unless manual action is taken 1AF005E-H will be closed due to loss of IB 114)

• Step 11: Verify CC pumps - BOTH RUNNING.

• Start 1B CC pump

• Step 12: Verify SX pumps - BOTH RUNNING.

• Start 1B SX pump

• Step 13: Check if Main Steamline Isolation -required:

o All S/G pressures > 640 psig (at 1PM04J).

o CNMT pressure > 8.2 psig.

Crew o Verify MSIVs and Bypass valves closes o Announces containment is adverse 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 BOP/

• Step 14: Check if CS is required.

RO

• CNMT pressure has risen > 20 psig.

• Group 6 CS monitor lights - ALL LIT. NOTE: B Train NOT LIT

• Manually actuate CS and Phase B Isolation- 2 out of 2 switches at (at least) 1 out of 2 locations o Go to Attachment C o Check 1CS001B OPEN o Open 1CS007B o Open 1CS019B by:

o Place 1 CS pump test switch in TEST o Manually open 1CS019B Comments:

Byron NRC 13-1 Page 24

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior o Place CS pump test switch in NORMAL o Open 1CS010B

• Check one CS pump running

• CHECK At Least 1 CS pump running

• Returns to step 14c, page 10 of 1BEP-0

• Group 6 phase B lights - ALL LIT. NOTE: B train NOT LIT o Manually actuate CS and Phase B Isolation- 2 out of 2 switches at 1 out of 2 locations o Manually CLOSE o 1CC9413B o 1CC685 o 1CC9414

• Verify/Stop ALL RCPs (at 1PM05J).

• CS eductor suction flow - > 15 gpm on 1FI-CS013.

• CS eductor additive flow - > 5 gpm on 1FI-CS015.

BOP

• Align SX Towers

• 8 Riser valves OPEN

• OPENS 0SX163C and D

• All 4 Bypass valves CLOSED

• 8 fans running in HIGH speed

• Starts 0c, 0D and 0G Fans in Hi-speed BOP/

• Step 15: Verify Total AF flow:

RO

• AF flow > 500 gpm

• S/G NR levels - NOT rising in an uncontrolled manner and between 31 and 50%

RO/

• Step 16: Verify ECCS valve alignment BOP

• Determine Group 2 Cold Leg Injection monitor lights required for injection - NOT All lit o Manually aligns valves as necessary RO/

• Step 17: Verify ECCS flow BOP

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

• RCS pressure < 1700 psig

• SI pump Discharge flow greater than 200 gpm

• RCS pressure < 325 psig

• RH flow > 1000 GPM RO

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

• 1RY455 & 1RY456 CLOSED

• PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED Comments:

Byron NRC 13-1 Page 25

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior

• PORV relief path - Both PORVs in AUTO, Both isolation valves - OPEN. (NOTE:

1RY455A will NOT operate in Auto because I.B. 114 is de-energized)

• Normal PZR Spray Valves CLOSED RO

• Step 19: Maintain RCS temperature control at 1PM05J:

• Check RCPs - NONE RUNNING.

• Verify RCS average temperature stable at or trending to 557oF.

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

• MSIVs closed RO

• Step 20: Check status of RCPs at 1PM05J:

o All RCPs - NONE RUNNING.

o Any RCPs still running - TRIP All RCPs BOP/

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

RO

• Check pressure in all SGs:

• None dropping in an uncontrolled manner.

• None completely depressurized.

BOP/

• Step 22: Check S/G tubes are intact at RM-11 console:

RO

• 1PR08J SG Blowdown.

• 1PR27J SJAE/GS.

• 1AR22/23A-D Main steam Lines.

CREW

• Step 23: Determine RCS is NOT intact:

o CNMT area rad monitors > alert alarm setpoint at RM-11 console.

o CNMT pressure > 3.4 psig (1PI-CS 934-937) at 1PM06J.

o CNMT floor drain sump level > 46 inches (1LI-PC002/003) at 1PM06J.

CREW Transition to 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT EVALUATORS NOTE: The crew will transition to 1BEP ES-1.3 when RWST Lo-2 level (<46%) is reached. May occur before step 13. 1BEP ES-1.3 actions are listed in italics below.

US

• Notify SM of plant status and procedure entry

• Request evaluation of Emergency Plan conditions

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

• Step 1: Check Status of RCPs:

• RCPs - NONE RUNNING RO/

• Step 2: Check if SG secondary pressure boundaries are intact:

BOP

• Check pressure in all SGs:

• None dropping in an uncontrolled manner

• None completely depressurized

• Step 3: Check intact SG levels

• SG levels maintained between 10% (31%) and 50%

Comments:

Byron NRC 13-1 Page 26

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior

• SG NR levels - NOT rising in an uncontrolled manner

• Step 4: Check secondary radiation normal.

• Reset Phase A

• Depress BOTH Phase A Reset Pushbuttons at 1PM06J

• OPEN 1SD005A-D at 1PM11J

• At RM-11 or HMI Check secondary rad trends on :

• 1PR08J SG Blowdown

• 1PR27J SJAE/GS

• 1AR22/23A-D Main steam lines

• Secondary activity samples (when available)

RO

• Step 5: Check at least ONE PZR PORV relief path available:

• PORV isol valves - BOTH ENERGIZED

• PORVs closed

• PORV relief path - BOTH PORVs in AUTO, 1RY8000A & B - OPEN EVALUATORS Prompt booth to have the STA report a RED PATH exists for 1BFR P-1.

US

• When informed of the red path on 1BFR-P.1 the U.S. should

• Inform the SM of the transition to P.1 and request evaluation of the Emergency Plan

• Direct crew actions contained below in italic RO

• Check RCS pressure greater than 325 psig

• Check RH flow Greater than 1000 GPM US

• Transitions back to 1BEP-1 Step 6

• Informs SM of procedure transition and requests evaluation of Emergency Plan.

• Direct crew actions beginning at step 6 CREW

• Step 6: Check if ECCS flow should be reduced

• RCS subcooling - NOT acceptable CREW

• Step 7: Check if CS should be stopped

• Both CS pumps -1 RUNNING

• Reset CS signal

• Check Spray Add Tank Lo-2 lights - NOT lit

• CS termination criteria NOT met - for LOCA, operating time at least 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> CREW

• Step 8: 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 lit at 1PM05J

• RCS pressure - NOT> 325 psig & stable Comments:

Byron NRC 13-1 Page 27

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior CREW

• Step 10: Check if DGs should be stopped o Stop DGs and place in standby CREW

• Step 11: Initiate evaluation of plant status

• Check cold leg recirc capability - BOTH trains available

• Check AB rad trends normal

• Obtain samples o Place H2 monitors in service per BOP PS-9

• Evaluate equipment for long term recovery

• Shutdown chiller on non-operating VC trains o Start additional plant equipment as required CREW

• Step 12: RCS pressure - NOT > 325 PSIG

• RH pump flow > 1000 GPM CREW

• Step 13: Check if transfer to 1BEP ES-1.3 required o RWST level - < 46%

o ECCS - aligned in injection mode o Identify need to perform 1BEP ES-1.3 US

• Transition to 1BEP ES-1.3, Cold Leg Recirculation

• Notify SM of procedure entry and request EAL evaluation EVALUATOR NOTE: If at any time RWST level lowers to 9% any pump taking suction on the RWST must be taken to PTL CREW

• Check/Open 1CC9473A & B

• Check 2 CC Pumps - running

• Open 1CC9412A & B

• Check CC to RH HX flows - >5000GPM

• Check CNMT floor water level - at least 13 inches CREW

• Place control switches for SVAG Valve 480V busses - CLOSE

[CT]

• Check both RH pumps - running ES-1.3 -

• Check both 1SI8811A & B - OPEN (1SI8811B is NOT)

-A

• Goes to Step 4 of Attachment A

• 1SI8811B NOT fully open o Check B RH pp running o Check 1SI8811B Energized

• Place 1B RH pump in PTL

• Close 1SI8812B o Place 1B CS pp in PTL o Close 1CS001B

• Open 1SI8811B

• Start 1B RH pump o Reopen 1CS001B- This valve is O.O.S.

Comments:

Byron NRC 13-1 Page 28

Scenario No: NRC 001 Event No. 8 Event Large Break LOCA with failure of 1A and B RH pumps to automatically start

==

Description:==

Time Position Applicants Actions or Behavior o Restart 1B CS pp- The pump is O.O.S.

• Check 1 Train of Cnmt Sump recirc established

• Return to main body step 4 page 8

• Check SI pump- any running

• Check 1SI8801A or B open: CHG pp to Cold Leg Injection valves CREW

• Align SI and CV pumps for cold leg recirc (Step 5)

• Verify closed: (CV pp mini-flows) 1CV8111, 1CV8114, 1CV8110, 1CV8116

• Close SI pump mini-flow valves 1SI8813, 1SI8814, 1SI8920

• Close (RH HX disc. X-tie vlvs) 1RH8716A & B

• Open/verify open (SI & CV pp suct. Hdr x-tie vlvs) 1SI8807A & B, 1SI8924

• Check 1A RH Pump running

• Open (RH HX to CV pps) 1CV8804A

• Check 1B RH Pump running

• Open (RH HX to SI pps) 1SI8804B

• Start CV pumps and SI pumps as necessary EVALUATOR NOTE: The scenario can be terminated after the first 6 steps of 1BEP ES-1.3 are completed or at lead examiners discretion.

Comments:

Byron NRC 13-1 Page 29

Facility: _Byron Nuclear Station Scenario No.: __2__ Op-Test No.: _2013301_

Examiners: _D. McNeil__________________ Operators: _____________________________

_R. Baker___________________ _____________________________

B. Palagi Initial Conditions: __IC-18, 75% power, steady state, MOL_________________________________

Turnover: Unit 1 is at 75% power, steady state, MOL, CB D is @ 172 steps and boron concentration is 950 ppm.

Online risk is green. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance.

1D CD/CB pump is OOS for maintenance.

Event Event Event Malf. No.

No. Type* Description ZDI 1CD05PD PTL 1D CD/CB pp O.O.S.

ZLO1CB113DOPN OFF 1D CD/CB pp O.O.S.

ZLO1CB113DCLS OFF 1D CD/CB pp O.O.S.

ZDI1CB113D CLS 1D CD/CB pp O.O.S.

Preload ZDI1CD05PDB PTL 1D CD/CB pp O.O.S.

IMF RP02A Rx trip breaker fails to open IMF RP02B Rx trip breaker fails to open IMF TC03 Turbine fails to AUTO trip from Rx trip ZDIHSTG010 NORM Manual Turbine trip PB fails to trip turbine N

1 Switch Bus 156 Electrical Lineup (BOP,SRO)

TS (SRO) 2 None Notified that 1A SI pump failed ASME surveillance I (RO, SRO) 3 MF RX18A 630 1A TCOLD RTD fail High TS (SRO) 4 MF CV16 0 I (RO, SRO) VCT Level Channel LT-112 Fail Low C

(BOP,SRO) 1C CD/CB pp Trip requiring entry to 1BOA SEC-1 and 5 IMF FW22C R Turbine Runback (RO, SRO)

I 6 IMF RX04D 0 30 Feedwater flow channel 1FT-521 fails Low (BOP,SRO) 7 MF CH08 60 120 TS (SRO) CNMT Pressure 1PT-936 Fail High ATWS 8 MF TH16C M (ALL) 1C RCP Trip with Rx Trip Breakers Fail To Open C (BOP, Failure of Main Turbine to Trip on auto signal or manual 9 Pre-load US) push button

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

SCENARIO OVERVIEW Unit 1 is at 75% power, steady state, MOL, CB D is @ 172 steps and boron concentration is 950 ppm.

Online risk is green. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance. 1D CD/CB is OOS for maintenance.

After completing shift turnover and relief, the crew is directed to switch Bus 156 from SAT to UAT following ACB 1561 maintenance using 1BGP 100-3, Step F.43 for reference.

During the Bus power supply swap, the Unit Supervisor will be called by Engineering stating that after reviewing the previously run ASME surveillance the 1A SI pump has failed the acceptance criteria. Entry into Tech Spec 3.5.2 Condition A will be made.

After the Unit Supvr makes the TS call, 1A Tcold RTD fails high, requiring entry to 1BOA Inst-2, Operation with a Failed Instrument Channel. This will require entry into Tech Specs by the SRO. Entry into Tech.

Spec. 3.3.1 Condition A and E is made.

After 1BOA Inst-2 is exited, VCT Level channel 1LT-112 fails low. RMCS auto makeup will start, and the crew will have to place the Makeup Mode Select switch to Off. Any required makeup will have to be done in Manual for the remainder of the scario..

After the level channel failure has been addressed, the 1C CB/CB pump will trip. The crew will enter 1BOA SEC-1, Secondary Pump Trip, Unit 1, attachment B. A reduction in turbine load, via runback will be required.

After the run back is complete and the unit has been stabilized, the controlling feedwater flow channel on the 1B SG fails low. The BOP will take manual control of feedwater flow. 1BOA INST 2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment G, will be implemented. The BOP will restore feedwater flow control to automatic when SG level is restored to normal. On line risk remains green.

After the level channel failure has been addressed, CNMT pressure channel 1PT-936 fails high. This has no immediate required actions, but the US will be responsible to evaluate Tech Specs. Crew will enter 1BOA Inst-2, Operation with a Failed Instrument Channel to address the failure. Entry into TS 3.3.2, conditions A, D & E is applicable.

After the CNMT pressure channel failure has been addressed, the 1C RCP trips. When the crew attempts to trip the reactor, the trip breakers will fail to open. The manual Turbine trip P.B. will also malfunction. The turbine can be tripped via the electronic turbine trip feature associated with DEHC. The crew will enter 1BFR S.1, ATWS. At step 16, the crew will be directed to return to 1BEP-0, Reactor Trip or Safety Injection.

Completion criterion is transition to 1BEP-0, Reactor Trip or Safety Injection. The lead evaluator may end the scenario at the transition.

Byron ILT NRC 13-2 Page 2

Critical Tasks

1. Isolate the main turbine from the SGs before plant- and scenario-specific criteria are exceeded.

(ERG Critical Task number - FR-S.1--A) (K/A: EPE029EA1.13 - IR: 4.1/3.9)

2. Insert negative reactivity into the core by at least one of the following methods before completing the immediate-action steps of FR-S.1:

• De-energize the control rod drive MG sets

• Insert RCCAs

• Establish emergency boration flow to the RCS (ERG Critical Task number - FR-S.1 -- C) (K/A: EPE029EA1.12 - IR: 4.1/4.0)

SIMULATOR SETUP GUIDE:

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

• Establish the conditions of IC 18, 76% power, MOL, steady state.

• 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, Ensure horns are turned ON. Set BA and PW controllers to Rema numbers or 0 and reset.

• Place C/O tags on the 1D CD/CB pump C/S, its aux oil pump C/S, discharge valve C/S, and recirc valve C/S.

• Place Bus 156 on SAT.

• Ensure 1B SG FW Flow Channel is selected to F-521

• Place simulator in RUN and divert 1CV112A to get to approximately 39% VCT level.

• Open cae file: NRC 13-2.cae Byron ILT NRC 13-2 Page 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Switch Bus 156 Electrical Lineup Call on radio as T-1 and advise that you are standing outside of the 6.9 KV Bus Switchgear Room ready for them to perform the breaker operation. The room is clear of personnel.

Event 2: Unit Supervisor is notified that 1A SI pump has failed ASME acceptance criteria listed in 1BOSR 5.5.8.SI.5-1a SM acknowledge T/S 3.5.2 entry conditions Event 3: 1A Tcold RTD Failed High IMF RX18A 630 As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

As SM Acknowledge entry into TS 3.3.1 As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

As SM Inform US that bistables will be tripped when personnel are available As WEC or Extra NSO, acknowledge request to trip bistables, if Lead Examiner desires At 1PA01J:

To open protection cabinet 1, MRF RP20 OPEN To trip bistables:

OPDT trip: MRF RX013 TRIP OPDT RB: MRF RX014 TRIP OTDT Trip: MRF RX135 TRIP OTDT RB: MRF RX136 TRIP Low Tave: MRF RX016 TRIP Lo-Lo Tave: MRF RX015 TRIP To close protection cabinet 1: MRF RP20 CLOSE Acknowledge as SM the 1C CD/CB pump trip, 1BOA SEC-1 entry, request for E-Plan evaluation and requests for on line risk assessment, maintenance support and IR initiation.

If dispatched as EO, report that 1C CD/CB pump appears seized and the ground overcurrent flag has dropped at the breaker cubicle, Bus 159 cub 3 Acknowledge as Power Team load reduction and estimated duration of derate.

Byron ILT NRC 13-2 Page 4

Event 4: VCT Level Channel 1LT-112 Failed Low IMF CV16 0 As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 5: Insert Malfunction FW22C to trip the C CD/CB pp Acknowledge as SM the 1C CD/CB pump trip, 1BOA SEC-1 entry, request for E-Plan evaluation and requests for on line risk assessment, maintenance support and IR initiation.

If dispatched as EO, report that 1C CD/CB pump appears seized and the ground overcurrent flag has dropped at the breaker cubicle, Bus 159 cub 3 Acknowledge as Power Team load reduction and estimated duration of derate.

Event 6: Feedwater flow channel 1FT-521 fails low Insert IMF RX04D 0 30 to fail 1FT-521 low over a 30 second period.

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

Event 7: CNMT Pressure 1PT-936 Failed High IMF CH08C 60 120 As WEC or Extra NSO, acknowledge request to trip bistables.

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.

Acknowledge entry to TS 3.3.2.

Event 8: ATWS - 1C RCP trip with Rx Trip Breakers Fail to Open IMF RP02A and RP02B (in preload)

IMF TH16C to trip 1C RCP As SM 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 at 1RD05E. After crew has gone past step 7 of 1BFR S.1, DMF RP02A and RP02B, and MRF RP01 and RP02 OPEN Byron ILT NRC 13-2 Page 5

Event 9: Main Turbine Fails to trip on auto signal or manual push button IMF TC03 ZDIHSTG010 NORM Byron ILT NRC 13-2 Page 6

Scenario No: NRC 002 Event No. 1 Event Switch Bus 156 Electrical Lineup

==

Description:==

Time Position Applicants Actions or Behavior CUE * (From Turnover) Realign Bus 156 to UAT following maintenance on ACB 1561 US

• Refer to 1BGP 100-3 Step F. 43

• Direct BOP to switch Bus 156 to the UAT per step F.43 BOP

• Switch Bus 156 Electrical Lineup

• Turn on synchroscope for Bus 156

• Close 1561

• Open 1562

• Turn off syncroscope RO

• Monitor primary and secondary panels

• Control Tave with control rods or dilution as needed EVALUATOR NOTE: When electrical swap is complete, insert the next event.

Comments:

Byron ILT NRC 13-2 Page 7

Scenario No: NRC 001 Event No. 2 Event Unit Supervisor notified of 1A SI pump ASME surveillance failure

==

Description:==

Time Position Applicants Actions or Behavior NOTE: At Lead Evaluators Discretion this event may be bypassed.

CUE

• US called by Engineering that 1A SI pump ASME surveillance acceptance criteria has NOT been met.

US

• Refers to TS 3.5.2 determines that Condition A applies:

• Condition A: Restore pump to operable w/i 7 days

• Calls SM and informs same of condition. Requests, evaluation for on-line risk, IR initiation and maintenance informed.

May request BOP/RO to place affected pump in PTL.

EVALUATOR NOTE: After the Tech. Spec. condition has been determined and with lead examiners concurrence, insert the next event.

Comments:

Byron ILT NRC 13-2 Page 8

Scenario No: NRC 002 Event No. 3 Event 1A Tcold RTD Failed High

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator TAVE CONT DEV HIGH (1-14-D1) is LIT

• Annunciator AUCT TAVE HIGH (1-14-E2) is LIT

• Annunciator PZR LEVEL CONT DEV LOW (1-12-B4) is LIT

• Rods stepping in CREW

• Identify instrument failure US

• Enter 1BOA Inst-2, Operation with a Failed Instrument Channel

• Notify SM of procedure entry, request EAL evaluation and IR RO

• Verify/Place Rod Bank Select Switch in MANUAL

• Manually defeat 1A Tave channel

• Manually defeat 1A T channel o Check Rx power <100% RTP

• Select operable RTD for the T recorder

• Check if Rod Control can be placed in AUTO

• Check C-5 NOT LIT (Bypass Permissive 5.7) o If not within 1°F, restore to within 1°F

• Check Pzr level trending to normal

• May take manual control of Master Pzr level controller or 1CV121

• Check P-12 not LIT BOP/R

• Remove SPDS inputs: T0402A placed in TEST O

• Delete T0400 from SCAN BOP

• Assist RO with BAR response US

• Contacts SM to determine if channel is to be tripped or bypassed o Contact the WEC to brief, or personally brief an extra NSO to trip bistables o Direct the crew to coordinate bistable tripping with extra NSO CREW o Verify no previously tripped bistables will cause a reactor or turbine trip o Mark bistables to be tripped with dots CREW o Coordinate with extra NSO to trip Loop A bistables US

• Determines TS 3.3.1 condition A & E is applicable

• Condition A: Immediately enter condition referenced in table

• Condition E: Place channel in TRIP within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in MODE 3 in 78 o Channel may be BYPASSED for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing o TRM 3.h: not applicable because required channels are OPERABLE (PDMS)

EVALUATOR NOTE: After the actions for the instrument failure are complete and Comments:

Byron ILT NRC 13-2 Page 9

Scenario No: NRC 002 Event No. 3 Event 1A Tcold RTD Failed High

==

Description:==

Time Position Applicants Actions or Behavior with Lead Examiners concurrence, insert the event 4.

Comments:

Byron ILT NRC 13-2 Page 10

Comments:

Byron ILT NRC 13-2 Page 11

Scenario No: NRC 002 Event No. 4 Event VCT Level Channel 1LT-112 Failed Low

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator VCT LEVEL HIGH-HIGH LOW is LIT (1-9-A2)

• VCT Level 1LI-112 indicates ZERO

• Automatic RMCS makeup in operation CREW

• Refer to BAR 1-9-A2

• Determine 1LT-112 is failed LOW RO

• Place RMCS makeup switch in OFF

• Monitor VCT level o Makeup to VCT in MANUAL if required US

• Notify SM of failure, request IR BOP

• Monitor primary and secondary panels

• Assist with BAR response EVALUATOR NOTE: Only manual make-up control will be available for the remainder of this scenario EVALUATOR NOTE: After the actions for the VCT level failure are complete and with Lead Examiners concurrence, insert the event 5.

Comments:

Byron ILT NRC 13-2 Page 12

Scenario No: NRC 002 Event No. 5 Event 1C CD/CB Pump Trip with Runback required

==

Description:==

Time Positio Applicants Actions or Behavior n

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: > 700 MW

• Check a Standby CD/CB pump cannot be started

• Determines 3 CD/CB pps NOT running

• Initiates a CD/FW runback by push button or panel G5512

• Check Turbine Load DROPPING RO o Monitor RCS Tave and reactivity effects caused by secondary feedflow changes.

• Places Rods in AUTO

• Initiates boration as necessary

• 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 (NOTE to Evaluator: 295 gals of BA needed to reduce power from 1200 MW to 700 MW. RO should deliver about 100 gals of BA to reduce load by approximately 150 MW from current conditions)

• Turn ON RMCS Makeup Control Switch

• Verify 1CV110B OPEN

• Verify 1CV110A MODULATING

• Verify 1AB03P STARTS

• Verify proper AB flow on 1FR110

• Coordinate boration with unit ramp by BOP

• Maintain Tave-Tref within 3°F o Assist BOP with BAR response BOP

• Check FW pumps not cavitating

• Close 1CB113C o Check FW pump discharge flow: NOT oscillating o Reduce FW pp flow while maintaining >50% level in SGs

• Continue to monitor FW pp performance

• Check Alarms NOT LIT o CB PP DSCH Flow High (1-17-B11)

Comments:

Byron ILT NRC 13-2 Page 13

Scenario No: NRC 002 Event No. 5 Event 1C CD/CB Pump Trip with Runback required

==

Description:==

Time Positio Applicants Actions or Behavior n

o FWpp NPSH LOW (1-16-E1)

RO/BOP

• Check Plant Status 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:

o Notify Chemistry and RP to perform the power change surveillances

• Notify Shift Manager to perform step 8 of 1BOA SEC-1 Attachment B for CD/CB Trip EVALUATOR NOTE: After the unit has stabilized and with Lead Examiners concurrence, insert event 6.

Comments:

Byron ILT NRC 13-2 Page 14

Scenario No: NRC 002 Event No. 6 Event Feedwater flow channel 1FT-521 fails low

==

Description:==

Time Positio Applicants Actions or Behavior n

CUE

• Annunciator 1B SG FW FLOW MISMATCH (1-15-B4)

• FW flow indicator 1FI-521A lowering

• FW flow indicator 1FI-520A rising

• FWRV 1FW-520 opening

• SG level indicators 1LI-527, 528, 529, 557 rising BOP

• Identify 1FT-521 failed low

• Report failure to US

• Perform the following at 1PM04J

• Place 1FW-520 in MANUAL

• Lower FW flow to match or slightly lower than steam flow

• Monitor 1B SG level and control 1FW-520 in MANUAL RO

• Assist BOP as requested

• Monitor reactor panel for reactivity changes CREW o Refer to BARs

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

US

• Notify SM of plant status and procedure entry.

• Request evaluation of Emergency Plan conditions.

• Enter/Implement "1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment G.

BOP

• Select operable SG level channel F-520 on 1FS-520C

• Check 1B SG level - normal on 1LI-527, 528, 529, 557

• Place 1FW-520 in AUTOMATIC Crew

• Check reactor power <100%

BOP

• HD pp disc. flow control valve position - Normal Crew o Evaluate impact on calorimetric EVALUATOR NOTE: After the actions for the feedwater flow channel failure are complete and with Lead Examiners concurrence, insert the event 7.

Comments:

Byron ILT NRC 13-2 Page 15

Scenario No: NRC 002 Event No. 7 Event CNMT Pressure 1PT-936 Failed High

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator CNMT PRESS HI-3 (1-3-D4) is LIT

• Annunciator CNMT PRESS HI-2 (1-3-C4) is LIT

• Annunciator CNMT PRESS HIGH (1-3-B4) is LIT

• Indicator 1PI-CS936 indicates 60 PSIG US

• Enter 1BOA Inst-2, Operation with a Failed Instrument Channel, Att K

• Notify SM of procedure entry, request E-Plan evaluation and IR

• Contacts SM to determine if channel is to be tripped or bypassed o Contact the WEC to brief, or personally brief an extra NSO to trip bistables o Direct the crew to coordinate bistable tripping with extra NSO US

• Notify WEC to, or perform brief of extra NSO to trip bistables

• Direct crew to coordinate tripping bistables with extra NSO CREW o Verify no previously tripped bistables will cause a reactor or turbine trip o Mark bistables to be tripped with dots US

• Enter TS 3.3.2, conditions A, D & E

• Condition A: Immediately enter condition referenced in table

• Condition D: (Cont Press Hi-1) Place channel in TRIP within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in MODE 3 in 78 and MODE 4 in 84

• Condition E: (Cont Press Hi-3) Place channel in BYPASS within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in MODE 3 in 78 and MODE 4 in 84

• One additional channel may be BYPASSED for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing EVALUATOR NOTE: After the actions for the failed pressure channel are complete and with Lead Examiners concurrence, insert event 8.

Comments:

Byron ILT NRC 13-2 Page 16

Scenario No: NRC 002 Event No. 8 Event 1C RCP Trip with ATWS

==

Description:==

Time Position Applicants Actions or Behavior CUE

• The following annunciators are LIT:

• RCP TRIP (1-13-E3)

• RCP 1C BRKR OPEN OR FLOW LOW ALERT (1-13-C3)

CREW

• Identify entry conditions for 1BEP-0, REACTOR TRIP OR SAFETY INJECTION EVALUATOR NOTE: The crew may dispatch an operator to open the reactor trip breakers before reaching step 6.

US

• Enters 1BEP-0, REACTOR TRIP OR SAFETY INJECTION

• Transition to 1BFR S.1, ATWS

• Notify SM of procedure entry

• Request EAL evaluation and STA to monitor BSTs RO o Rod Bottom lights -NOT LIT o Rx Trip and Bypass Bkrs- NOT ALL OPEN

• Manually TRIP the Reactor from BOTH locations

• Allow rods to insert automatically until rod speed less than 48 SPM, then manually insert rods CREW

• Manually trip the Turbine

[CT] o All Turbine throttle valves - CLOSED.

FR-S.1- o All Turbine governor valves - CLOSED.

-A

• Recognizes the Turbine did not auto trip from Reactor trip

• Manually trip the turbine o Actuate manual trip P.B.

o Operate the manual trip soft key on the OWS G-5512 panel

• Select turbine manual on G-5501 panel

• Select RAPID

• Select and hold GV lower arrow OR o Manually actuate Mainsteam Line Isolation CREW

• Manually start both AF pumps RO/BO

• Verify/ensure Control Rods inserting in Manual or Auto at least 48 steps per minute P

• Check at least 1 CV pump running

[CT]

• Initiate emergency boration by FR-S.1-

• Open 1CV8104

-C

• Start boric acid transfer pump

• Check emergency boration and charging flows > 30 GPM Comments:

Byron ILT NRC 13-2 Page 17

Scenario No: NRC 002 Event No. 8 Event 1C RCP Trip with ATWS

==

Description:==

Time Position Applicants Actions or Behavior RO/BO

• Check Pzr pressure < 2335 PSIG P

• Verify Group 6 CVI monitor lights LIT CREW

• Check if Reactor Trip has occurred

• Dispatch EO to locally open Rx Trip Breakers

• Check Turbine Trip occurred EVALUATOR NOTE: Depending on timeframe, the crew may go to either step 8 or step 16 at this point. Steps 8-15 are in italics.

CREW

• Check if Reactor is subcritical

• PR channels <5%

• IR channels - negative SUR CREW

• Check SG NR levels > 1 SG >10%

• Control feed flow to maintain SG NR level 10% - 50%

• Check 1SD002A-H closed

• Check 1CV111A & B closed

• Verify BTRS MODE SELECTOR SWITCH is OFF

• Dispatch operator to verify dilution paths are isolated o Check for RCS temperature NOT dropping uncontrollably o Check for any SG pressure NOT dropping uncontrollably

• EVALUATOR NOTE: If RCS is cooling down or SG are depressurizing, the crew will perform steps 11-13 CREW o Step 11: Check/close MSIVs and bypass valves closed o Step 12: Check SG pressure NOT dropping uncontrollably or depressurized o Step 13: Isolate Faulted SG CREW

• Step 14: Check CETC < 1200°F

• Step 15: Verify reactor subcritical

• PR channels < 5%

• IR channels - negative SUR Crew

• Return to procedure and step in effect US

• Announces transition to 1BEP-0, Reactor Trip or Safety Injection EVALUATOR NOTE: The scenario can be terminated after the transition to 1BEP-0 is announced or at Lead Examiners discretion.

Comments:

Byron ILT NRC 13-2 Page 18

Comments:

Byron ILT NRC 13-2 Page 19

Facility: _Byron Nuclear Station Scenario No.: __3__ Op-Test No.: _2013301_

Examiners: _D. McNeil__________________ Operators: ____________________________

_R. Baker___________________ ____________________________

_B. Palagi__________________ ____________________________

Initial Conditions: IC-18, 75 power, steady state, equilibrium xenon, MOL Turnover:

Unit 1 is at 75% power, steady state, equilibrium xenon, MOL, CB D is at 172 steps and boron concentration is 950 ppm. Preconditioned to 100% power at 6400 EFPH. Online risk is yellow. 1A CS pp is O.O.S. for a motor lube oil change and is scheduled to be released at the end of shift. Power Team requests the unit to be ramped down to 700 MWe at 3.0 MW/min. Main Generator output is 858 megawatts.

Event Event Event Malf. No.

No. Type* Description IOR ZDI1CS01PA PTL 1A CS pp O.O.S.

IMF CS01A 1A CS pp fails to start Preload IRF CS05 OVER Preload Prevents 1B CS pp from Auto start IMF CH01B 1B RCFC fails to start in Lo Speed IMF CH01C 1C RCFC fails to start in Lo Speed N (BOP, SRO) 1 None Ramp unit down from 858 to 700 MW @ 3 MW/min R (RO, SRO) 2 IMF RD13AK08 TS (SRO) DRPI failure (1 rod) in CB A for 1 train C (RO, 3 IMF CV07A 80 60 RCP Seal Injection Filter Clogged SRO)

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

(SRO)

C (BOP, 5 IMF FW02A 1B TDFP Trip SRO)

Steam Generator 1D controlling Steam Pressure I (BOP, IMF RX01K 0-(from 10- channel fails low requiring Manual control of 1D SG 6 SRO) 1-1 cert) Main Feed Reg Valve. Enter Tech Spec 3.3.2 for TS (SRO) actions.

7 IMF MS07D 4 240 M (ALL) 1D Steam Line Break inside CNMT CS Pumps Auto Start Failure, Manual Start required; (Preloaded) 1B CS pump fail to auto start due to 1CS019B failure MF CS01A C (SRO, to auto open 8 RF CS05 OVER CREW)

IMF CH01B 1B RCFC fails to start in Lo Speed IMF CH01C 1C RCFC fails to start in Lo Speed

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

SCENARIO OVERVIEW Unit 1 is at 75% power, steady state, equilibrium xenon, MOL CB D is at 172 steps and boron concentration is 950 ppm. Online risk is yellow due to the 1A CS pp being out of service. The crew is to ramp the unit to 700 MWe at 3.0 MW/min After completing shift turnover and relief, the crew will commence the ramp down by boration to 700 MWe.

Before the ramp has commenced, a DRPI failure will occur on Rod K-8 requiring the U.S. to determine if Tech Spec. 3.1.7 is applicable.

After the ramp has commenced, 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. Since the standby filter is placed in service, 1BOSR 5.5.1-1 is required to be performed IAW Tech Spec 3.5.5. This evolution is NOT included with this material.

After normal seal injection flow is restored and the plant stabilized, 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 eventually tripped. The SRO will refer to Tech. Specs 3.3.1, 3.3.4 and 3.3.3. TS 3.3.1, conditions A and K are applicable.

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 perform a fast start of the motor driven feedwater pump After taking actions for the Feedwater pump trip and the plant stabilizes, the 1D SG controlling steam pressure channel, 1PT 545A, will fail low requiring manual control of the 1D SG feedwater regulating valve.

The SRO will enter 1BOA INST-2, for the failed SG Steam pressure channel and direct actions to restore the 1D feedwater regulating valve to automatic control. Tech Spec 3.3.2, Conditions A and D apply.

After the ramp has been initiated, a 4 Mlb/hour fault develops and ramps in over 240 seconds in the 1D 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. Manual action must be taken to start the 1B CS pump. In addition, 2 RCFC will not start in low speed which will require a CS pump to function.

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)

Page 2

SIMULATOR SETUP GUIDE:

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

• Establish the conditions of IC 16, 56% 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 C/O tags on 1A CS pp MCB C/S

• 1A Seal Injection filter on line placard placed on 1PM05J

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

• Verify RM-11 is on grid 1, Ensure horns are turned ON. Set BA and PW controllers to Rema numbers or 0 and reset.

• Ensure 1D SG STEAM FLOW channel selected to F-543

• Open Cae file: NRC 13-3.cae Page 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Ramp Unit 1 to 700 MWe at 0.66 MWe/min.

Event 2: 1 Rod DRPI Failure IMF RD13AK08 As SM Acknowledge Tech Spec entry.

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

As SM inform crew that an Extra NSO will perform RD-8 As SM inform crew to NOT select DATA B ONLY to allow for troubleshooting Event 3: 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.

A few minutes after filters are swapped call as the A.B. E.O. and inform U.S. of step in procedure to perform 1BOSR 5.5.1-1 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 4: Respond to Pressurizer Level Channel Failure NOTE: Ensure 1CV121 is in auto IMF RX13A 100 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.

As SM inform US that bistables will be tripped when personnel are available 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 Page 4

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.

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

Event 6: Steam Generator 1D controlling Steam Pressure channel fails low (1PT545A).

Initiate event after event 5 actions completed Acknowledge all info passed to the SM, WEC, and maintenance.

SDG: RX16 IMF RX01K 100 If requested to trip bistables, and Lead Examiner wants to see this action:

MRF RP21 OPEN/CLOSE MRF RX 095 Trip MRF RX 096 Trip Otherwise, there are NO NSOs available to trip bistables for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> As SM Acknowledge procedure entry and request for Emergency Plan evaluation As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

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 Page 5

Scenario No: NRC 003 Event No. 1 Event Reduce power at 3.0 MW/min

==

Description:==

Time Positio Applicants Actions or Behavior n

CUE o Direction from Power Team to lower power to 700 MW at 3.0 Mw/min.

US

• Acknowledge request to lower power to 700 MW at 0.66 Mw/min.

• Implement actions of 1BGP 100-4T3 o Perform pre-job brief per HU-AA-1211 PRE-JOB, HEIGHTENED LEVEL OF AWARENESS, INFREQUENT PLANT ACTIVITY, AND POST JOB BRIEFINGS for load ramp.

US

• Direct lowering load to 700MW at 3.0 MW/min.

• Initiate load swing instruction sheet, 1BGP 100-4T3.

CREW

• Review applicable Precautions, and Limitations and Actions.

NOTE: The ramp strategy will be to add about 30-40 gallons of Boric Acid about every 20 minutes and supplement with rods to control temperature. This will result in about a 13%

per hour change in Rx power. Total calculation will be rods starting at 172 steps and ending about 148 steps as determined by ReMa thumb rules. A total of 200 gallons of Boric Acid will be calculated. The crew should calculate to add about 50% of that value (100 gallons). Batches should be sized to control temp between 1 and 2°F which will be between 25 and 50 gallons (about 30-40 gallon batches are expected).

RO

• Conducts reactivity brief

• Set up boration IAW Figure 35 and BOP CV-6

• Places rods to manual

• Energizes PZR back-up heaters

• 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

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

• Select SETPOINT.

• Enter 3.0 MW/min into the RATE window.

• Select ENTER.

• Enter 700 MW into REF DEMAND window.

Comments:

Byron ILT NRC 10-1 Page 6

Scenario No: NRC 003 Event No. 1 Event Reduce power at 3.0 MW/min

==

Description:==

Time Positio Applicants Actions or Behavior n

• 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 lower.

RO/

• Monitor reactor power and load ascension:

BOP

• Monitor NIs, Tave, I, Pzr press/level at 1PM05J.

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

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

• VCT level.

• RCS Tave lowering.

• AB/Total flow predet counter responding correctly.

• Verify boration auto stops at preset value.

• Return Reactor Makeup System to automatic.

After measurable change in power and Lead Examiner approval, initiate the event 2.

Comments:

Byron ILT NRC 10-1 Page 7

Scenario No: NRC 003 Event No. 2 Event DRPI Failure 1 rod in 1 train on CB A (Data A failure)

==

Description:==

Time Positio Applicants Actions or Behavior n

CUE

• Annunciator 1-10-D6 Rod Cont Non-Urgent Failure

• SER 2150 in alarm

• Data A failure on Rod K-8 Crew

• Acknowledge annunciator.

• Open BAR

• Check SER alarm: point 2150 is in alarm RO o Place Bank Select Switch in Manual US

• Notify SM and requests IR generation

• Requests an extra NSO perform BOP RD-8, DRPI System Troubleshooting o Verify the RD Power Cabinets Group Select Lights indicate properly for the bank selected for motion.

o CB A should not move

• Review Tech Specs

• Per BAR 1-10-D6, if SER 2150 is in alarm and 2151 is NOT in alarm then:

• Operability requirements are met for

• Tech Spec 3.1.7 and

• TRM 3.1.g Comments:

Byron ILT NRC 10-1 Page 8

Scenario No: NRC 003 Event No. 3 Event RCP Seal Injection Filter Clogged

==

Description:==

Time Positio Applicants Actions or Behavior n

CUE

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

• Annunciator RCP Seal Water Inj. Flow Low (1-7-B2) LIT

• Seal injection flows lowering RO

• Adjust 1CV182 to maintain about 8 GPM (6-8) seal injection flow per RCP o Adjust 1CV121, if necessary NOTE: The above RO adjustments have the RO balance charging flow into the RCS via the Regen HX versus maintaining seal injection flow. Letdown stream temperatures may rise as 1CV182 is throttled closed. If Seal Injection flow goes < about 6 gpm the crew may check CC flow is supplied to the TBHX for proper seal cooling.

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.

US

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

• 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 approximately 8 - 13 GPM per RCP BOP

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

• Provide assistance in diagnosis and BAR response.

US

• Direct initiation of or initiate 1BOSR 5.5.1-1, RCS Seal Water Injection Flow Monthly Surveillance after standby filter is placed on line.

EVALUATOR NOTE: After the actions for the seal filter malfunction are complete and with Lead Examiners concurrence, insert event 4.

Comments:

Byron ILT NRC 10-1 Page 9

Scenario No: NRC 003 Event No. 4 Event Pressurizer level channel 1LT-459 failed high

==

Description:==

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, and/or 1LK-459, PZR master level controller, in manual.

• Raise demand on 1FK-121 and/or 1LK-459 in conjunction with controlling demand on 1CV182 to raise charging flow.

• Operate 1FK-121 and/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- 461/460

• Select an operable Pzr level channel to the recorder

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

US

• Contact SM or WEC for tripping bistables o Verifies tripping bistables will NOT result in a Rx TRIP o Perform pre-job brief per HU-AA-1211 for bistable tripping.

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

Extra o Locally trip bistable for 1LT-459 / RO verifies correct bistable operation NSO/

RO US

• Determine TS 3.3.1 conditions A and K are applicable.

• Condition A- Immediately enter the table

• Condition K- Place channel in TRIP in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or reduce power to < P-7 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />

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

o May decide to make a Degraded Equipment Log Entry Comments:

Byron ILT NRC 10-1 Page 10

Scenario No: NRC 003 Event No. 4 Event Pressurizer level channel 1LT-459 failed high

==

Description:==

Time Position Applicants Actions or Behavior

• 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 event 5.

Comments:

Byron ILT NRC 10-1 Page 11

Scenario No: NRC 003 Event No. 5 Event 1B TDFP trip

==

Description:==

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 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 FW pp available

• Start 1A FW pp aux. oil pump

• Verify 1FW016 controller in manual and at 20% demand

• Start 1A FW pp o Check FW pump 1A disc. flow greater than 3.0 MLB/hr

• Start stby CD/CB pump aux oil pump

• Start stby CD/CB pump

• Check FW PUMP NPSH LOW alarm LIT

• Verify CP bypass valves are open: 1CD210A and B.

US/

• Restore Plant Conditions CREW

• 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 Shutdown unnecessary CD/CB pump per BOP CD/CB-2, Comments:

Byron ILT NRC 10-1 Page 12

Scenario No: NRC 003 Event No. 5 Event 1B TDFP trip

==

Description:==

Time Position Applicants Actions or Behavior 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

• 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 US

• Notify SM to perform:

• Risk evaluation

• Initiate IR

• Evaluate for reactivity screening

• Notify QNE

• Notify as appropriate: WWM, SDM, SDO, NDO EVALUATOR NOTE: After the actions for the feed pump trip are complete and with Lead Examiners concurrence, insert event 6.

Comments:

Byron ILT NRC 10-1 Page 13

Scenario No.: NRC 003 Event No.: 6 Event Steam Generator 1D controlling steam pressure channel fails low (1PT545A)

Description:

Time Positio Applicants Actions or Behavior n

CUE: Annunciators:

1-15-D1 S/G 1D LOW PRESS STEAMLINE ISOL ALERT 1-15-E1 MS PRESS RATE STM LINE ISOL ALERT 1-15-D3 S/G 1D FLOW MISMATCH STM FLOW LOW 1-15-D4 SG 1D FLOW MSMATCH FW FLOW LOW 1-15-D9 S/G 1D LEVEL DEVIATION HIGH LOW 1D SG steam pressure indication zero on 1PT545A 1D SG steam flow low 1D SG feedwater flow dropping 1C FW Pump Speed dropping 1D SG Level dropping BOP/US

• Identify/report failure of 1PT-545A, 1D steam generator steam pressure channel.

o Address 1-15-D9 alarm response

• Check 1D SG level, steam flow, feed flow, and determine cause.

• Take Manual control feed flow to 1D SG.

US Enter and direct actions of 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL Attachment F

• Notifies SM of BOA entry

• Requests Emergency Plan evaluation BOP Check affected SG level:

o Determine SG level not normal

• Take manual control of 1FW540 M/A station and restore SG level to normal

• Take manual control of 1SK-509A M/A station to maintain MFPs speed to maintain MFRV D/P

• Select an operable steam flow channel (F-542)

• Restore Automatic level control o Restore Automatic MFP speed control o Check reactor power less than 100%

ALL

• Identify/flag TSLB lites associated with failed channel Identify/flag failed channel

• Request operator to locally trip bistables for the affected channel Comments:

Byron ILT NRC 10-1 Page 14

Scenario No.: NRC 003 Event No.: 6 Event Steam Generator 1D controlling steam pressure channel fails low (1PT545A)

Description:

Time Positio Applicants Actions or Behavior n

US Performs administrative requirements

• Determines Tech Spec for 3.3.2 ESFAS Instrumentation Condition A and D apply

• Condition A: Immediately enter Table

• Condition D: Place channel in TRIP in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or being in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> and in Mode 4 in 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />

• Requests IR/WR/LCOAR Considers recommencing ramp RO Monitor plant response to FW transient and take actions directed by the US NOTE: When the above actions have been initiated for the failed SG steam pressure channel and with Lead Evaluators concurrence, Event 7 is entered.

(Bistables may be tripped at lead examiners discretion)

Comments:

Byron ILT NRC 10-1 Page 15

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

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 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

• 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 CREW

• Step 4: Check SI Status o SI First OUT annunciator - LIT o SI ACTUATED Permissive Light - LIT Comments:

Byron ILT NRC 10-1 Page 16

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior 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 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: RO and SRO actions start again on page 17, step 6.

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 Comments:

Byron ILT NRC 10-1 Page 17

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior

• 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:

• 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 Comments:

Byron ILT NRC 10-1 Page 18

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior 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

• Initiate periodic checking of Spent Fuel Cooling o Notify US of actions taken, equipment status, and 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 - B and C RCFCs are not running in accident Mode

• Stop any RCFC running in High speed

• Close CNMT chiller inlet and outlet valves 1SX112B/114B

• Open CNMT chiller bypass valve 1SX147B o Open 1SX016B and 027B o Start all RCFCs in low speed: NOTE to Evaluator: RCFC B and C will NOT start

• Step 8: Verify Phase A isolation:

• Group 3 Cnmt Isol monitor lights - ALL LIT.

• Step 9: Verify Cnmt Vent isolation:

• 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 Comments:

Byron ILT NRC 10-1 Page 19

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior 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

• Go to Attachment C o Check CS001B OPEN o OPEN 1CS007B

• 1CS019B is NOT OPEN

• Place 1A CS pump test switch in TEST

• OPEN 1CS019B

• Place 1A CS pump test switch in NORMAL

• OPEN 1CS010B

• Check 1A CS pump Running

• Group 6 phase B lights - LIT

• Verify/Stop ALL RCPs (at 1PM05J).

• 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 BOP

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

• When RCS pressure < 1700 psig Comments:

Byron ILT NRC 10-1 Page 20

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior

• 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.

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

• 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.

Comments:

Byron ILT NRC 10-1 Page 21

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior CREW

• Identify faulted SG at 1PM04J:

• 1D SG pressure decreasing in an uncontrolled manner.

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.

CREW

• 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 1PR27J SJAE/GS 1PR08J SG Blowdown.

o 1PR08J SG Blowdown.

o 1AR 22/23D 1D Main steam Line o Secondary activity samples normal (when available)

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 At lead Evaluators discretion the scenario may be terminated here. SI Termination steps are contained in the next two pages up to securing the CS pump.

Comments:

Byron ILT NRC 10-1 Page 22

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior 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

• Reset Phase B BOP

• Establish IA to CNMT

• Check SACs - ANY Running

• Open 1IA065 and 1IA066 RO/

• Realign CV Pump BOP

• Stop all but one CV pump CREW

• Check RCS pressure - Stable or rising RO/

• Terminate High-head SI BOP

• CV pump suction aligned to RWST

• 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 Comments:

Byron ILT NRC 10-1 Page 23

Comments:

Byron ILT NRC 10-1 Page 24

Scenario No: NRC 003 Event No. 7&8 Event 1D Steam Line Break inside Containment

==

Description:==

Time Position Applicants Actions or Behavior

• Step 10: Check if RH pumps should be stopped

• Any running with suction aligned to RWST

• Stop both RH pumps and place in standby

• Verify ECCS flow not required

• Subcooling acceptable

• PZR level > 12% (28% adverse)

• Check if CS should be stopped

• Reset CS signal

• Close 1CS019B

• CNMT pressure less than 15 psig

• Stop 1B CS pump and place in standby

• Verify 1CS019B closed

• Close 1CS007B EVALUATOR NOTE: The scenario can be terminated.

Comments:

Byron ILT NRC 10-1 Page 25

Appendix D Scenario Outline Form ES-D-1 Facility: _Byron Nuclear Station Scenario No.: __3__ Op-Test No.: _2013301_

Examiners: _D. McNeil__________________ Operators: ____________________________

_R. Baker___________________ ____________________________

_B. Palagi__________________ ____________________________

Initial Conditions: IC-18; ~75% power, ~858 Mwe, MOL, equilibrium Xenon, steady state, 1B Diesel Generator OOS and 1A FW pump OOS.

Turnover: The plant is at 75% power, as requested by the Power Team to support a grid outage, MOL, equilibrium Xenon, steady state, 3500 EFPH, and 950 ppm boron concentration. Control Bank D is at 172 steps. The 1B DG is OOS for Turbo Charger work. The 1B DG has been OOS for 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> and is expected to be returned to service by the end of the shift. LCOAR for Tech Spec 3.8.1 Condition B has been entered; 1BOSR 8.1.1-1 was performed 30 minutes prior to shift turnover. 1A FW pump is OOS for work on the speed increaser and not expected back for 2 more days. On-line Risk is yellow Event Malf. Event Event No. No. Type* Description MRF EG09 MAINT_O 1B DG OOS IOR ZDI1HSDG028 PTL ACB 1423 OOS IOR ZLO1HSDG0201 OFF 1B DG STOP Light MRF FW024 0 1A FW Pump suction isol valve Preload MRF FW027 0 1A FW Pump recirc isol valve MRF ED091C OPEN Deenergize 1FW002A, 1A FW Pump discharge valve IOR ZDI1FW01PA PTL 1A FW Pump OOS IOR ZDIFW01PAB PTL 1A FW Pump Aux Oil Pump OOS IOR ZLO1FW012A1 OFF 1FW12A Open light TS US 1 IMF RX21A 2500 15 Pressurizer pressure channel 1PT-455 fails High I RO ALL SG Tube Leak in 1C SG at 30 gpm requiring plant shutdown per 1BOA SEC-8 and Tech Spec 3.4.13 application.

IMF TH03C 30 100 TS US Direct the Unit ramp down to 50% power 2

RO Perform Reactivity calculation for ramp to 50% power R RO Ramp the Unit to 50% power N BOP Ramp the Unit to 50% power I BOP MS Header PT, 1PT-507, fails low requiring manual FW pump 3 IMF RX05 0 speed control to stabilize the secondary plant.

C RO PCV-131 controller fails closed in AUTO. This will require 4 IMF CV05 600 Manual control to maintain Letdown backpressure.

C BOP 1B FW Pump trips, followed shortly (~45 seconds) by 1C FW IMF FW02A 5 M ALL Pump speed ramping to minimum, resulting in no FW flow IMF FW02B requiring a manual reactor trip.

IMF FW13B 100 C ALL 1B FWIV fails to close 6

IMF FW09B 100 C ALL 1FW520 fails to close 7 IMF TH03C 350 60 M ALL Increases 1C SG Tube Leak to a 350 gpm SGTR IMF FW45C 100 C ALL MRF ED53E OPEN 1AF005C and 13C fail open requiring operator to close 1AF005 8

IMF FW45C 0 120 to close LOCALLY.

1AF005C locally

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

SCENARIO 13-3 OVERVIEW The scenario will begin at 75% power, MOL, equilibrium Xenon, steady state. The 1B DG is OOS for Turbo Charger work. The 1B DG has been OOS for 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> and is expected to be returned to service by the end of the shift. LCOAR for Tech Spec 3.8.1 Condition B has been entered; 1BOSR 8.1.1-1 was completed 30 minutes ago. 1A FW pump is OOS for work on the speed increaser and not expected back for 2 days.

After a board walk down and turnover, 1PT455 will fail high. The RO will take manual control and stop RCS pressure lowering caused by this instrument malfunction. The crew will enter 1BOA Instrument-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL ATTACHMENT B. The SRO will review Tech Specs. 3.3.1 conditions A, E & K, 3.3.2 condition D, 3.3.4 Condition A and inform the SM of same.

After the instrument failure actions are complete, a 30 gpm tube leak will be initiated in the 1C SG. The crew must identify primary to secondary leakage based on SJAE/GS condenser and main steam line Radiation Monitors. There may also be a charging/letdown mismatch. This will require actions in 1BOA SEC-8 requiring plant power reduction to 50% power within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and shutdown to Hot Standby within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> after reaching 50%. Tech Spec 3.4.13 actions are addressed also requiring shut down to MODE 3 within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

After the crew has taken actions for the SG tube leak and commenced the down power to 50%, Main Steam Pressure transmitter, 1PT-507, fails low causing the Master Feed Pump Speed controller to lower FW Pumps speed, which results in loss of FW flow to all SGs. Action is required to take Manual control of FW pump speed to restore and maintain SG levels at program level for the remainder of the scenario. This failure is not addressed in a BOA or in Tech Specs but actions are driven by the BAR. Maintenance should be notified and specific directions should be given to the BOP for controlling FW pump speed in Manual to maintain SG levels and proper FW discharge pressure to SG delta pressure I.A.W. d/p placard on 1PM04J.

Feed pump speed control will remain in manual for the remainder of the scenario.

While the BOP is stabilizing the MFP speed control, PCV-131, L/D backpressure control valve, will fail closed. This malfunction can occur independently or simultaneously with the failure of 1PT-507. This will require manual control to restore backpressure and prevent the L/D line relief to lifting, if left in Auto.

This failure is not addressed in a BOA or in Tech Specs. Actions are driven by the appropriate Annunciator Response procedure. Maintenance should be notified and specific directions should be given to the RO for controlling letdown backpressure.

Once FW Pump P, and PCV-131 manual controls have been directed, the 1B FW pump will trip requiring actions in 1BOA SEC-1 to runback the turbine, since the 1A FW pump is OOS, to maintain SG levels with only 1 FW pump running. Once the initial actions for the runback have been taken and turbine load is dropping, boration is commenced and/or rod insertion, the 1C FW pump will trip, resulting in no feed to the SGs resulting in a Reactor trip and entry into 1BEP-0. The crew may transition to 1BEP ES-0.1.

Following the reactor trip, a Steam Generator Tube Rupture (350 gpm in 1C SG) will occur requiring a Safety Injection and continuation in or reentry into 1BEP-0. The crew will diagnose the SGTR and transition to 1BEP-3.

Following the SI initiation, the 1AF005C will fail open (can be closed locally) and 1AF013C 480V M.C.C.

breaker will trip open. These failures will require the 1AF005C to be locally closed to stop feeding the ruptured 1C S/G.

The scenario ends with termination of high head ECCS and establishing charging flow per 1BEP-3.

Page 2

ERG Based Critical Tasks:

1. E-3A: Identify the 1C Steam Generator as the ruptured SG and isolate prior to transition to 1BCA-3.1.

2. E-3----B: Cooldown to establish RCS subcooling margin, but prevent entry into 1BFR-P.1.

3. E-3----C: Depressurize RCS to restore RCS inventory prior to 1C SG PORV or Safety valve water release.

SCENARIO NRC 13-3 SIMULATOR OPERATOR NOTES Simulator Setup:

Reset to IC-18; 75% power, MOL, equilibrium Xenon, steady state.

Go to run.

Align switches:

1B DG C/S PTL and OOS ACB 1423 PTL and OOS 1A FW Pp Aux Oil Pp OOS 1A FW Pp OOS 1FW002A OOS Place LCOAR placards for: 1B DG LCO 3.8.1 Condition B Place On-Line risk to YELLOW Place Protected Equipment placards on 1A DG and ACB 1413 C/Ss, and ACB 1424 Provide copies of turnover sheets Provide a copy of 1BOL 8.1 for 1B DG inoperability Perform Ready for Training checklist.

Insert all PRELOAD Events from page 1 Set AB Pot to 3.71 for 950 ppm boron Open Cae file: NRC 13-4. cae Event 1 1PT-455 fails High Insert IMF RX21A 2500 15 to fail 1PT-455 high over a 15 second period.

SDG RX8 To trip the required bistables, participate in brief and perform the following:

• As extra NSO contact Unit 1 (X-2208)

• Insert the following:

• MRF RP20 OPEN (open protection cabinet #1 door)

• MRF RX032 TRIP (trip PZR hi press Rx trip bistable PB455A)

• MRF RX034 TRIP (trip PZR low press Rx trip bistable PB455C)

• MRF RX035 TRIP (trip PZR low press SI bistable PB455D)

• MRF RX033 TRIP (trip P11 bistable PB455B)

• MRF RX013 TRIP (trip OTT Rx trip bistable TB411C)

• MRF RX135 TRIP (trip OTT Runback bistable TB411D)

• MRF RP20 CLOSE (close protection cabinet #1 door)

Page 3

As SM acknowledge the failure, LCOs 3.3.1, conditions A, E and K, 3.3.2, conditions A and D, and 3.3.4, condition A entries, on line risk assessment, request for maintenance support, and IR requests.

As SM, inform US that the WEC will conduct PJB for tripping bistables associated with 1PT-455 when personnel are available.

Event 2 SG Tube leak in 1C SG at 30 gpm.

Initiate event upon completion of event 1, with Lead Examiners concurrence.

Acknowledge info to SM, WEC, and maintenance.

SDG: TH5 IMF TH03C 30 100 Event 3 Main Steam header PT, 1PT-507, fails low. (Ensure BOP is in the vicinity to prevent RO responding)

Initiate event upon completion of event 2, with Lead Examiners concurrence.

IMF RX05 0 SDG RX22 Acknowledge info to SM, WEC, and maintenance.

Event 4 Letdown Line Back Pressure Control valve 1CV-131 (1PK-131) fails closed.

Initiate event after BOP has gained control of MFP speed in manual and is restoring SG levels to normal and with the Lead Examiners concurrence.

SDG: CV2 IMF CV05 600 Acknowledge info to SM, WEC, and maintenance Event 5 1B FW Pp trips (5) followed by 1C FW Pp trip (6), after a Manual Runback is initiated, causing a loss of all feedwater flow, resulting a Reactor Trip.

Initiate malfunction after actions are completed to stabilize the secondary plant and letdown backpressure, with the Lead Examiners concurrence.

SDG: FW7 IMF FW02A IMF FW02B Acknowledge info to SM, WEC, and maintenance.

Page 4

Event 6: Manual feedwater isolation to 1B SG required Malfunction occurs upon reactor trip to cause FWRV (1FW520) to fail OPEN and 1FW009B fails to CLOSE causing manual action to isolate main feedwater to the 1B SG Acknowledge info to SM, Acknowledge info to SM, WEC, and maintenance.

Event 7 1C SGTR on Reactor trip.

Malfunction occurs upon reactor trip to cause a SGTR at 350 gpm in 1C SG.

SDG: TH5 IMF TH03C (0 0) 350 60 30 (from trigger)

Acknowledge info to SM, WEC, and request for STA.

Event 8 1AF005C Fails open and 1AF013C M.C.C. Breaker Trips Malfunction occurs upon Safety Injection. Train A AF to the 1C (ruptured) S/G will not be able to be isolated from the MCR but local isolation is possible.

SDG: AFP MRF ED53E- 131X1 E2: Open SDG: FW13 IMF FW45C: 100 To close 1AF005A Locally IMF FW45C 0 120 Acknowledge info to SM.

Page 5

Scenario No: NRC Spare Event No. 1 Event Pressurizer pressure channel 1PT-455 fails high.

==

Description:==

Time Position Applicants Actions or Behavior CUE

• Annunciator PZR PRESS HIGH RX TRIP STPT ALERT (1-12-A2)

• Annunciator PZR PORV OR SAFETY VALVE OPEN (1-12-B2)

• Annunciator PZR PRESS CONT DEV HIGH (1-12-D2)

• Annunciator PZR PORV DSCH TEMP HIGH (1-9-C6)

• PZR pressure indicators 1PI-456, 457, and 458 lowering

• PZR PORV 1RY-455A open light lit at 1PM05J.

RO

• Identify 1PT-455 is failing high.

• Identify 1RY455A is open.

• Report failure to US.

• Perform the following at 1PM05J:

• Place 1RY455A, PZR PORV, C/S in close prior to reactor trip or SI occurring.

• Place 1PK-455A, master PZR pressure controller, in manual.

• Lower demand on 1PK-455A sufficiently to close PZR spray valves and energize PZR heaters prior to reactor trip or SI occurring.

• Operate 1PK-455 in manual to restore PZR pressure to normal operating band.

• Monitor reactor response to RCS pressure transient.

CREW o Refer to BARs.

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

• Identify TS 3.4.1 entry required if RCS pressure lowers < 2209 psig.

BOP o Refer to BARs

• Monitor secondary panels

• Assist RO as requested US

• Notify SM of plant status and procedure entry.

• Request evaluation of Emergency Plan conditions.

• Enter/Implement "1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment B, PRESSURIZER PRESSURE CHANNEL FAILURE and direct operator actions of 1BOA INST-2 to establish the following conditions:

RO

• Check PZR pressure at 1PM05J:

• PZR pressure - normal on 1PI-456, 457, & 458.

• Manually restore PZR pressure using 1PK-455A.

• Select operable PZR pressure control channel o Place 1PK-455A in manual and restore PZR pressure to normal.

• Place PZR pressure control select C/S to CH-457/CH-458.

Page 6

Scenario No: NRC Spare Event No. 1 Event Pressurizer pressure channel 1PT-455 fails high.

==

Description:==

Time Position Applicants Actions or Behavior RO

• Check PZR PORVS, spray valves, and heaters at 1PM05J:

• PZR PORVs closed.

• PZR spray valves normal for plant conditions.

• PZR heaters normal for plant conditions.

• Check PZR pressure control in auto at 1PM05J:

• Check the following components in AUTO:

• PZR PORV 1RY455A

• If 1RY455A is closed from initial response, place C/S in AUTO

• PZR PORV 1RY456

• PZR spray valve 1RY455B

• PZR spray valve 1RY455C

• Master PZR pressure controller 1PK-455A.

• If 1PK-455A in manual from initial response, place in AUTO.

• Select operable recorders at 1PM05J:

• Place PZR pressure select switch to CH-456, CH-457, or CH-458.

• Place loop T recorder select switch to 1B, 1C, or 1D.

CREW

• Check P-11 interlock

• RCS press > 1930 psig

• PZR LO PRESS SI BLOCK PERMISSIVE P11 (1-BP-3.3) NOT LIT US

• Contacts SM for direction on bistable trip or bypass function Extra o Locally trip bistable for 1PT-455/RO verifies correct bistable operation at 1PM05J.

NSO/ o PB455A - C1-153 BS-1.

RO o PB455C - C1-153 BS-4.

o PB455D - C1-153 BS-3.

o PB455B - C1-153 BS-2.

o PB411C - C1-124 BS-3.

o PB411D - C1-124 BS-4.

US

• Determine TS 3.3.1, conditions A, E, and K, 3.3.2, conditions A and D, and 3.3.4, condition A are applicable.

• 3.3.1.

• Condition A: Immediately reference table

• Condition E: Place channel in trip in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />

• Condition K: Place channel in trip in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or reduce power < P-7 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />

• 3.3.2.

• Condition A: Immediately reference table

• Condition D: Place channel in trip in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> and Mode 4 in 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br />

• 3.3.4.

• Condition A: Restore required function to Operable in 30 days

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

EVALUATOR NOTE: After the actions for the pressurizer pressure channel failure are complete and with Lead Examiners concurrence, insert the next event.

Page 7

Page 8 Scenario No.: NRC Spare Event No.: 2 Event SG 1C tube leak

==

Description:==

Time Position Applicants Actions or Behavior CUES: Annunciators:

• 1-16-A5 SG Leakage Exceeded

• RM-11 Secondary rad monitor alarms/levels rising o SG BLDN RAD HIGH - 1PR08J o SJAE/GLAND STEAM EXHAUSTER HIGH - 1PR027J o MAIN STEAM LINE RAD HIGH - 1AR022J/23J

• PZR level dropping

• PZR pressure dropping

• Charging/letdown mismatch o Charging Flow HIGH annunciator may alarm CREW

• Refer to BAR 1-16-A5 for operator actions

• Implement 1BOA SEC-8, Steam Generator Tube Leak RO/US

• Maintain PZR level:

o Throttle 1CV121 & 1CV182 as necessary

• Check PZR level stable or rising (Note: US may direct reducing L/D to 75 gpm)

• Monitor VCT level

• Verify makeup is adequate to maintain VCT level BOP

• Minimize Secondary Contamination

• Perform BOP MS-11, Operation with SG Tube Leakage (Note: US may call the WEC or SM to have another NSO perform this procedure)

• Notify RP to monitor and initiate 0BCSR 11.i.1-1, Gaseous RW Treatment Eff Dose Calc Monthly.

• Identify 1C as the leaking SG Trend Main Steam Line monitors Dropping Feed Flow with stable SG level Unexpected rise in any NR SG level Chemistry reports high activity via sample or N-16 monitor

• Determine SG Tube leak rate

• Estimate leak rate o Computer point on HMI display o Charging/letdown/RCP leakoff flow balance o Change in VCT level o Grab sample o 1BOSR SG-1 SG Pri to Sec Leakage Estimation

• Estimate leak rate > 10 gpm - GO TO STEP 9 of 1BOA SEC-8 US/ Confirm SG leak rate BOP

• At least 2 independent indications - TREND in the same direction.

o Main steam line radiation monitors o SJAE/GS Exh radiation monitors o SG Bldn radiation monitors o N-16 radiation monitors o Grab sample Page 9

Scenario No.: NRC Spare Event No.: 2 Event SG 1C tube leak

==

Description:==

Time Position Applicants Actions or Behavior ALL

• Initiate Unit Shutdown

• Check leak rate < 100 GPD: NO

• Reduce power to < 50% w/I 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of exceeding 100 GPD per 1BGP 100-4T1.1 AND

• Shut down unit within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> of being at 50%

• Shutdown Unit to MODE 3

• Continue in this procedure while performing Unit shutdown per 1BGP 100-4 US

• Determines 3.4.13 condition B applies

• 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> to MODE 3 AND 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> to be in MODE 5 RO

• Performs reactivity calculation for Unit 1 ramp down to 50% power.

(Should calculate ~420- 470 gal Boration and setup to add 40-70%

US

• Direct a ramp rate to achieve 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (MWe/minute)

RO Initiate boration (BOP CV-6)

• Place MU MODE CONT SWITCH to STOP position.

• Set MU MODE SELECT to BOR position.

• Set 1FK-110 Boric Acid Flow Cont Pot to desired boration rate.

• Verify/enter gallons for batch into the Boric Acid Totalizer

• Verify 1CV110A in AUTO

• Verify 1CV110B in AUTO

• Ensure Boric Acid Transfer Pump Control Switch is NOT in PULL OUT

• Place MAKE-UP CONTROL Switch to START

• Verify proper operation of valves & BA Transfer pump (1CV110A, modulates OPEN, and 110B open, BA Xfer pump is running)

• Verify expected BA flow on recorder 1FR-110

• Monitor Boration effects

• Verify at least two B/U Heater groups ON and spray valves 1RY455B/C modulate OPEN.

BOP Initiate turbine load ramp down: Using graphic 5501

• SELECT SETPOINT - (Note: Rate and final target for Mwe is dependent on being <50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.)

• ENTER desired MW/MIN rate into the RATE window

• SELECT ENTER

• ENTER 580-630 MW in the REF DEMAND window

• SELECT ENTER

• SELECT EXIT Inform US/RO of pending drop in turbine load

• SELECT GO

• Verify load dropping as expected.

NOTE: The next malfunctions may be entered at Lead Examiners direction after required power change.

Page 10

Scenario No.: NRC Spare Event No.: 3 Event Main Steam Header Pressure Transmitter (1PT-507) fails Low

==

Description:==

Time Position Applicants Actions or Behavior CUE: Annunciators:

• 1-15-A4 thru D4, SG 1A/B/C/D FLOW MISMATCH FW FLOW LOW

• 1-15-A9 thru D9, SG 1A/B/C/D LEVEL DEVIATION HIGH LOW

• Steam flow/feed flow mismatch on all SGs

• All Feed Regulating Vlvs opening

• 1B/1C FW Pumps speed dropping

• Master and 1B/1C FW Pumps speed controller demand rising

• All SG levels dropping BOP

• Identify/report feedwater control system indications

• Take Manual control of Master or 1B and 1C speed control

• Manually adjust FW Pumps speed to restore Delta-P and SG levels o Identify/flag components US

• Direct stabilizing SG levels

• Inform SM/Maintenance to investigate CREW o Review impact of failure on Steam Dumps in Steam Pressure MODE RO o Monitors the plant, performs as directed by the Unit Supervisor Page 11

Scenario No.: NRC Spare Event No.: 4 Event PCV-131 (1PK-131), Letdown Line Backpressure Controller fails closed in AUTO

==

Description:==

Time Positio Applicants Actions or Behavior n

CUES: Annunciators:

• 1-8-B5 LTDWN HX OUTLT PRESS HIGH Letdown flow rate drop < 120 or 75 (based on actions in event 2) gpm on 1PM05J -

1FI-132 Letdown line pressure ~ 600 psig on 1PM05J - 1PI-131 RO/US Identify/report failure of 1PK-131 in auto.

• Direct Manual operation of PCV-131 RO

• Take Manual control of 1PK-131 and adjust letdown backpressure to ~ 370 psig Identify/flag the controller to remain in Manual control.

US Discuss how letdown backpressure will be maintained with the RO Notify SM/Maintenance to investigate cause of failure NOTE: When actions have been completed for the 1PT-507 failure and PCV-131, with Lead Evaluators concurrence, event 5 and 6 are entered.

Page 12

Scenario No.: NRC Spare Event No.: 5 Event 1B FW Pump trips requiring a turbine runback (6). 1C FW Pump trips causing a loss

==

Description:==

of feedwater requiring a Manual Reactor Trip(7)

Time Position Applicants Actions or Behavior CUE: Annunciators:

1-16-B1 FW PUMP 1B TRIP 1-16-D2 FW PUMP DSCH FLOW LOW Feed flow dropping to all SGs ALL

• Identify/report loss of 1B FW Pump US/BO Direct implementation of 1BOA SEC-1, Secondary Pump Trip P

• Close 1B FW pump recirc valve - 1FW012B o Check turbine load > 700 MW (Note: Load may be less than 700MWe due to ramp from SG Tube Leak)

• Verify 1C FW Pump is running - recognize 1A FW Pump is not available o Initiate turbine runback - pushbutton or mouse selection on OWS panel G-5512 o Check turbine load is dropping RO

• Verify Rod Control is in AUTO

• Initiate Boration as necessary - per REMA plaque (Use judgement since starting at lower power)

NOTE: RO may adjust rate of boration, i.e. raise it, if already borating for the ramp ALL

• Recognize 1C FW Pump tripped and SG levels are dropping US

• Direct a Manual Reactor Trip and operators to perform immediate actions of 1BEP-0, reactor Trip or Safety Injection.

• Notify SM to evaluate for E Plan NOTE: Event 7 will initiate with the reactor trip but probably wont be diagnosed until the crew transitions to 1BEP ES 0.1 Page 13

Scenario No.: NRC Spare Event No.: 6 Event Main Feedwater does not auto isolate on Rx Trip requiring manual action

==

Description:==

Time Position Applicants Actions or Behavior NOTE: This event action may be taken in ATTACHMENT B of 1BEP-0 step 1 or from a transition to 1BEP ES 0.1 step 6. Either waythe same (below) action is taken.

CUE: Annunciators:

1FW009B open indicating light LIT on 1PM04J or on 1PM05J 1FW520 open indicating light LIT on 1PM04J ALL

• Identify/report No FW isolation to the 1B SG BOP Implement Attachment B of 1BEP-0, step 1

• Close 1FW006B NOTE: Event 7 will initiate with the reactor trip but probably wont be diagnosed until the crew transitions to 1BEP ES 0.1 Page 14

Scenario No.: NRC Spare Event No.: 7 Event Loss of feedwater requiring a Manual Reactor Trip(7)

==

Description:==

Time Position Applicants Actions or Behavior 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 Verify Turbine Trip

• Turbine throttle valves closed

• Turbine governor valves closed BOP Verify power to 4KV busses

• Bus 141 alive light lit

• Bus 142 alive light lit CREW

• Check SI Status

• SI First Out annunciator -NOT LIT

• SI ACTUATED Permissive Light -NOT LIT

• SI Equipment - NOT ACTUATED

• NO SI pump - RUNNING

• NO CV pump to cold leg isolation valve - OPEN - 1SI8801A

• Recognize NO SI Actuated

• NO SI required because

• PZR Pressure is > 1829 psig

• Stm line pressure is > 640 psig

• Containment pressure is < 3.4 psig CREW o Transitions to 1BEP ES-0.1, REACTOR TRIP RESPONSE US

• Informs SM

• Requests E-plan evaluation

• Requests STA NOTE to Evaluator: The first 3 steps of 1BEP ES-0.1 REACTOR TRIP RESPONSE, are included below in italics should the operators pursue this path until confirming an SI is required CREW Step 1 Check RCS Temperatures

• RCPs running

• Temperature trending to 557°F CREW Step 2 Check shutdown reactivity status

• Rod Bottom Lights: ALL LIT

• Check RCPs- ANY Running CREW Step 3 Check PZR Level Control

• Level greater than 17%

• Charging and letdown in service

• Level- trending to program Note to Evaluator: It is anticipated that at about this time, if they havent already, the crew will initiate a Manual SI and return to 1BEP-0, Rx Trip or Safety Injection US Directs the crew back into 1BEP 0 Directs RO to manually actuate Safety Injection Directs crew to reperform their immediate actions Byron Spare.docx Page 15 4/18/2013

Scenario No.: NRC Spare Event No.: 7 Event Loss of feedwater requiring a Manual Reactor Trip(7)

==

Description:==

Time Position Applicants Actions or Behavior 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 Verify Turbine Trip

• Turbine throttle valves closed

• Turbine governor valves closed BOP Verify power to 4KV busses

• Bus 141 alive light lit

• Bus 142 alive light lit CREW

• Check SI Status

• SI First Out annunciator -LIT

• SI ACTUATED Permissive Light -LIT

• SI Equipment - ACTUATED

• Either SI pump - RUNNING

• Either CV pump to cold leg isolation valve - Both 1SI8801A/B open

• 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 (contained immediately below)

The crew may identify 1A/B RH pumps are not running and may start them before step 6.

If evaluating the either SRO or RO move to step 6 on page 16 (next page)

BOP Attachment B actions for the BOP are as follows:

• 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 DG 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.

Byron Spare.docx Page 16 4/18/2013

Scenario No.: NRC Spare Event No.: 7 Event Loss of feedwater requiring a Manual Reactor Trip(7)

==

Description:==

Time Position Applicants Actions or Behavior

• VC train M/U filter light - LIT.

• Operating VC train Charcoal Absorber aligned for train B.

• 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:

• 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

• Check 1 AB exhaust fan running for every running supply fan

• Verify 1 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 Maintain UHS basin level greater than 80%

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 Initiate periodic checking of spent fuel cooling o Locally verify Spent fuel pool level is > 420 Elev o Locally verify SFP temperature stable o Notify STA of SFP cooling status Notify US that Attachment B is complete and actions taken RO/

• Step 6: Verify ECCS pumps running BOP

• Both CV pumps - RUNNING

• Both RH pumps - RUNNING Byron Spare.docx Page 17 4/18/2013

Scenario No.: NRC Spare Event No.: 7 Event Loss of feedwater requiring a Manual Reactor Trip(7)

==

Description:==

Time Position Applicants Actions or Behavior

• 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 - 4 LIT.

• Step 8: Verify Phase A isolation:

• Group 3 Cnmt Isol monitor lights - ALL LIT.

• Step 9: Verify Cnmt Vent isolation:

• 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.

• NOTE: 1AF05C has FAILED OPEN

• Step 11: Verify CC pumps - BOTH RUNNING.

• Step 12: Verify SX pumps - BOTH RUNNING.

o Step 13: Check if Main Steamline Isolation -required:

o All S/G pressures > 640 psig (at 1PM04J).

Crew o CNMT pressure < 8.2 psig.

BOP/

• Step 14: Check if CS is required.

RO o CNMT pressure has risen > 20 psig.

BOP/ NOTE to Evaluator: The C SG should be recognized as ruptured at this point. When RO the US directs the crew to close 1AF013C, the circuit breaker at the MCC trips

• Step 15: Verify Total AF flow:

• AF flow > 500 gpm

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

• 1C SG is identified as ruptured

• Close o 1AF013C

• 1AF013G RO/

• Step 16: Verify ECCS valve alignment BOP

• Group 2 Cold Leg Injection monitor lights- LIT RO/

• Step 17: Verify ECCS flow BOP

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

• RCS pressure < 1700 psig

• SI pump Discharge flow greater than 200 gpm 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

• Normal PZR Spray Valves CLOSED RO

• Step 19: Maintain RCS temperature control at 1PM05J:

• Check RCPs - Any RUNNING.

• Verify RCS average temperature stable at or trending to 557oF.

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

• Step 20: Check status of RCPs at 1PM05J:

Byron Spare.docx Page 18 4/18/2013

Scenario No.: NRC Spare Event No.: 7 Event Loss of feedwater requiring a Manual Reactor Trip(7)

==

Description:==

Time Position Applicants Actions or Behavior

• Any RCP - RUNNING.

BOP/

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

RO

• Check pressure in all SGs:

• None dropping in an uncontrolled manner.

• None completely depressurized.

BOP/

• Step 22: Check S/G tubes are intact at RM-11 console:

RO

• 1PR08J SG Blowdown.

• 1PR27J SJAE/GS.

• 1AR22/23A-D Main steam Lines.

CREW Transition to 1BEP-3, STEAM GENERATOR TUBE RUPTURE Byron Spare.docx Page 19 4/18/2013

Scenario No.: NRC Spare Event No.: 8 Event

Description:

SGTR Time Position Applicants Actions or Behavior US Implement 1BEP-3 "STEAM GENERATOR TUBE RUPTURE and direct operator actions.

• Notifies SM of BEP entry

• Requests Emergency Plan evaluation RO/US Check status of RCPs and determine none running If any running, Check trip criteria satisfied

• HHSI flow >100 gpm OR SI flow > 200 gpm AND o RCS pressure > 1425 psig Controlled cooldown NOT in progress or previously initiated Stop all RCPs ALL Identify ruptured SG Unexpected rise in NR level, OR Main steamline rad monitor, OR 1RT-AR022 Grid 1 4AC322 1RT-AR023 Grid 1 4AC323 High activity for any SG sample Reset CNMT isol Phase A Notify Chem to locally sample Open SG blowdown sample valves at Chem request ALL Identify/report 1C SG as ruptured BOP Isolate flow from ruptured SG by verifying

• SG PORV MS018C in AUTO

• Check SG PORV MS018C closed

• Verify closed when SG pressure < 1115 psig

• Verify SG blowdown valves closed unless open for sampling

• 1SD002G

[ CT ]

• 1SD002H

[E-3-A]

• MSIV and MSIV bypass valves closed for 1C SG

• Check PORVs on intact SGs available for RCS cooldown BOP Check ruptured SG level

• Narrow Range >10%

• Verify/Close AF isol valves (should have been closed earlier)

[ CT ]

• 1AF013C (has failed to close)

[E-3-A]

• 1AF005C ( failed to close using positioner)

• Dispatch operator to Locally CLOSE 1AF005C

• 1AF013G BOP Check ruptured SG pressure

• Ruptured SG pressure greater than 320 psig US Byron Spare.docx Page 20 4/18/2013

Scenario No.: NRC Spare Event No.: 8 Event

Description:

SGTR Time Position Applicants Actions or Behavior US/RO Initiate RCS Cooldown

• Determine required CETC from Table (516 degrees F)

• Block Main Steamline SI when PZR pressure is < 1930 psig BOP

• Dump steam from the Intact SGs at MAXIMUM rate using Steam Dumps

• Place MS header pressure controller in Manual at 0

• Place steam dump MODE select to Steam Press

• This will have to be opened in Manual since AUTO was lost due to 1PT-507 failure.

• Dispatch operator with keys to standby 1SI101A/B US/BOP

• Cooldown to < 516 °f

[CT]

• Stop cooldown

[E-3-B]

• Maintain CETC < 516 degrees F Establish a range of control (i.e. 500 - 515ºF)

BOP Check Intact SG levels

• NR levels > 10%

• Maintain 30-50% NR BOP/US Check PZR PORVs an Isolation Valves

• PORV Isol Valves Energized - 1RY8000A and B

• PORVs Closed - 1RY455A and 456

• At least 1 PORV Isol Valve open - 1RY8000A or B US/BOP Reset SI

• Depress both SI reset pushbuttons

• Verify SI ACTUATED permissive light is NOT LIT

• Verify AUTO SI BLOCKED permissive light is LIT US/BOP Reset CNMT Isolation

• Reset CNMT Phase A

• Check SACs-any running

• Open IA065 and 66 US/BOP Verify all AC Buses energized by offsite power:

• Check 4KV ESF Buses 141 and 142 energized from offsite power.

• Check 4KV Non-ESF buses 143 and 144 energized by offsite power.

• Check 6.9KV buses 156, 157, 158, and 159 energized from offsite power.

US/BOP Establish IA to containment US/RO Check if RH pumps should be stopped:

• Check suction aligned to the RWST

• RCS pressure > 325 psig

• Stop RH pump US/RO Verify RCS temp < CETCs target of 516 degrees F and cooldown is stopped US/BOP Check ruptured SG pressure stable or rising Byron Spare.docx Page 21 4/18/2013

Scenario No.: NRC Spare Event No.: 8 Event

Description:

SGTR Time Position Applicants Actions or Behavior US/RO

• Depressurize RCS using PZR Sprays (PORVs are optional) to minimize break flow and refill the PZR

[ CT ]

• Spray with Max spray available (or PORVs) until:

[ E-3-C] o Both RCS pressure is < 1C SG press AND PZR level is > 12%, OR o PZR level is >69%, OR o RCS subcooling is NOT acceptable Close spray valves when criteria is met NOTE: With lead examiners concurrence, this scenario can be terminated Byron Spare.docx Page 22 4/18/2013

Information Use BORATION / DILUTION CALCULATIONS

Purpose:

The purpose of this power change reactivity worksheet is to establish a boundary for the amount of boration / dilution that may be required and to assist in meeting industry expectations for reactivity control during a power ramp. The worksheet assumes steady state reactor power prior to the ramp and DOES NOT consider Xenon effects. Since the worksheet establishes a boundary, the operator experience plays an equal if not more important role in ensuring proper reactivity controls. 40% to 70% of the boration / dilution amount will normally be added.

CALCULATION:

1. Basis: Approx Cycle Burnup: __6900____ EFPH Initial Cb: _1000___ ppm Initial Reactor Power: __75_____ % Initial CBD: __171___ steps Final Reactor Power: __50____ % Final CBD: __130___ steps (est)

2. Determine the change in power defect:

Use BCB-1 Figure 17A, pages 1-4 or Table 2-1:

(-)__950______ - (-)___1375______ = ____+425_________pcm final power defect present power defect Change in power defect

3. Determine the amount of reactivity change due to control rod repositioning:

Use BCB-1 Figure 2C, pages 1-4 or Table 1-7 (Ensure correct curve w/respect to core life):

____140_________ - _____250_________ = _____-110___________pcm present inserted rod worth final inserted rod worth Change in control rod worth

4. Determine the reactivity the boration / dilution will compensate for:

___425________ + ____-110_________ = ___+315___________

step 2 result step 3 result Reactivity to compensate for

5. Determine the Differential Boron Worth (DBW):

Use BCB-1 Figure 10B, pages 1-4 or Table 2-4: 7.42 pcm/ppm (Avg of 2 values)

(Use the DBW absolute value, i.e., positive)- differential boron worth

6. Determine the ppm change in RCS boron concentration:

(NOTE: + number indicates boration; - number indicates dilution)

(step 4 result) _+315/7.42___ = __+42.5____ ppm change in RCS boron conc.

(step 5 result)

7. Determine the amount of boration / dilution required: (Data taken using 570ºF)

Use Table 3-1 __~ 455 gallons BA BORATION or DILUTION required

( circle one )(BOLDED)

(Final)

Byron Spare.docx Page 23 4/18/2013