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2014 Byron Nuclear Station Initial License Examination Proposed Simulator Scenarios
	ML14248A531
Person / Time
Site:	Byron
Issue date:	06/13/2014
From:	Walton R; NRC/RGN-III/DRS/OLB
To:	; Exelon Generation Co
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ML14140A562	List: ML14247A248; ML14247A257; ML14247A270; ML14248A490; ML14248A493; ML14248A499; ML14248A505; ML14248A514; ML14248A531; ML14248A542;
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Simulation Facility Byron Scenario No.: Operating Test No. Byron NRC 2014 N14-1 Examiners: Applicant: SRO

____________________ ____________________

RO

____________________ ____________________

BOP

____________________ ____________________

Initial Conditions: IC-107, 74% power, steady state, MOL Turnover: Unit 1 is at 74% power, steady state, MOL, CB D is @ 172 steps and boron concentration is 944 ppm.

Crew is to raise power to 100% for grid demand @ 0.5 MW/min. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance.

Event No. Malf. No. Event Event Type* Description Preload RP02A Turbine fails to AUTO trip from Rx trip RP02B Manual Turbine trip PB fails to trip turbine TC03 ZDIHSTG010 NORM 1 None N Switch Bus 156 Electrical Lineup (BOP,SRO) 2 None R (RO, Raise power to full power SRO) 3 None TS (SRO) Notified that 1A SI pump failed ASME surveillance 4 PA0154 ON C SX Fan high vibration requiring fan swap PA0152 ON (BOP,SRO) zao0iisx032 95 TS (SRO) 5 RX18A 630 I (RO, SRO) 1A TCOLD RTD Fail High TS (SRO) 6 RX04D 0 30 I Feedwater flow channel 1FT-521 fails Low (BOP,SRO) 7 CV16 0 I (RO, SRO) VCT Level Channel 1LT-112 Fail Low 8 TH16C M (ALL) ATWS 1C RCP Trip with Rx Trip Breakers Fail To Open 9 Pre-load C (ALL) Failure of Main Turbine to Trip on auto signal or manual push button (OWS PB will trip it)

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

SCENARIO OVERVIEW Unit 1 is at 74% power, steady state, MOL, CB D is @ 172 steps and boron concentration is 944 ppm. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance.

After completing shift turnover and relief, the crew is directed to switch Bus 156 from SAT to UAT following ACB 1561 maintenance using provided PMT.

After the Bus power supply swap, the crew will begin a ramp to full power at 0.5 MW/minute.

After the ramp has begun, 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. SRO evaluates TS 3.5.3, Condition A.

After the SRO has addressed the SI pump issue, 0B SX MDCT Fan High Vibration will alarm and amps will go high, requiring the 0B SX fan be tripped IAW BAR 0-37-E6 directions. The crew will evaluate SX temperature and decide whether to start 0C or 0D Fan. If sent to the SX Tower for a local inspection, the EO will report the fan gearbox is leaking oil. The US will refer to TS 3.7.9 and determine the LCO is satisfied.

After the SX fan vibration has been addressed, 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.

After RTD failure is addressed, 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.

After the FW flow failure has been corrected, 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.

After the VCT level 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 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.

After the crew enters 1BFR S.1, the auto turbine trip from a reactor trip signal will not function. The manual Turbine trip P.B. will also malfunction. The turbine can be tripped via the electronic turbine trip feature associated with DEHC.

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

Critical Tasks

1. CT-50: Isolate the main turbine from the SGs during ATWS

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

References:

1BGP 100-3 BAR 0-37-E6 1BOA INST-2, Att A & G 1BFR-S.1 1BEP-0 SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 107 (password: nrc14), 74% power, BOL, steady state.

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).

Place Bus 156 on SAT (in IC-107).

Ensure 1B SG FW Flow Channel is selected to F-521 (in IC-107).

Divert 1CV112A to get to approximately 40% VCT level on 1LI-112 (in IC-107).

Verify Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N14-1 from thumb drive and verify the following actions load in the CAEP:

Byron 2014 ILT NRC scenario 14-1l00:00:01l0 Event 4: 0B MDCT fan high vibration alarml00:00:02l2 IMF pa0152 onl10:00:00l3 IMF PA0154 ONl10:00:00l4 IOR zao0iisx032 95l10:00:00l5 Event 5: 1A Tc RTD fails highl00:00:03l7 IMF RX18A 630l10:00:00l8 Event 6: 1FT-521 fails lowl00:00:04l10 IMF RX04D 0 30l10:00:00l11 Event 7: 1LT-112 fails lowl00:00:05l13 IMF CV16 0l10:00:00l14 Event 8: 1C RCP tripl00:00:06l16 IMF TH16Cl10:00:00l17 Preload: l00:00:07l19 RTB fail to openl00:00:08l20 IMF RP02Al00:00:09l21 IMF RP02Bl00:00:10l22 Turbine trip failurel00:00:11l23 IMF TC03l00:00:12l24 IOR ZDI1HSTG010 NORMl00:00:13l25 trgset 10 "zlo0sx03cbhi(1).gt.0"l00:00:14l30 trgset 11 "zlo0sx03cbhi(1).gt.0"l00:00:15l31 trgset 12 "zlo0sx03cbhi(1).gt.0"l00:00:16l32 trg 10 "dor zao0iisx032"l00:00:17l33 trg 11 "dmf pa0152"l00:00:18l34 trg 12 "dmf pa0154"l00:00:19l35 To trip the Rx locallyl00:00:20l37 dmf rp02Al10:00:00l38 dmf rp02bl10:00:00l39 mrf rp01 tripl10:00:00l40 mrf rp02 tripl10:00:00l41 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Switch Bus 156 Electrical Lineup Event 2: Ramp unit to full power (1240 MW) at 0.5 MW per minute.

Event 3: Unit Supervisor is notified that SI pump has failed ASME acceptance criteria SM acknowledge T/S 3.5.2 entry conditions Event 4: 0B SX MDCT Fan High Vibration IMF PA0154 ON IOR zao0iisx032 95 AS EO, report 0B SX fan is vibrating excessively, and the fan gearbox is leaking.

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

Event 5: 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 WEC or Extra NSO, acknowledge request to bypass or trip bistables.

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

IMF TH16C to trip 1C RCP 4

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. After crew has gone past step 7 of 1BFR S.1, DMF RP02A and RP02B, and MRF RP01 and RP02 OPEN Event 9: Main Turbine Fails to trip on auto signal or manual push button IMF TC03 IOR ZDIHSTG010 NORM 5

Scenario NRC 14-1 Event 1 No: No.

Event

Description:

Switch Bus 156 Electrical Lineup 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 o Prebrief annunciator 1-20-E1as expected OR respond to parallel alarm with BAR.

RO

Monitor primary and secondary panels

Control Tave with control rods or dilution as needed EVALUATOR NOTE: Crew will initiate ramp after bus swap.

Comments:

NRC 14-1 Page 6

Scenario NRC 14-1 Event 2 No: No.

Event

Description:

Raise power at 0.5 MW/min Time Position Applicants Actions or Behavior CUE o Direction from Power Team to raise power to 1240 MW at 0.5 Mw/min.

US

Acknowledge request to raise power to 1240 MW at 0.5 Mw/min.

Implement actions of 1BGP 100-3.

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 raising load to 1240 MW at 0.5 MW/min.

Initiate load swing instruction sheet, 1BGP 100-3T5.

CREW

Review applicable Precautions, and Limitations and Actions.

RO

Verify rod position and boron concentration.

o Perform dilution boundary calculation per 1BGP 100-3T5.

Determine required PW volume: (approximate band: 1200 gal - 1400 gal).

Rema

Determine required PW flow rate.

Initiate dilution as required (BOP CV-5).

Perform the following at 1PM05J:

Set 1FK-111 PW/Total Flow Cont POT to the desired PW flow rate.

Set 1FY-0111 PW Control Predet Counter to desired PW volume.

Place MAKE-UP CONT SWITCH to STOP position.

Set MODE SELECT to DIL/ALT DIL position.

Place MAKE-UP CONT Switch to START.

Verify proper operation of valves and PW makeup pump (1CV111B open, 1CV111A throttled, 1CV110B open (ALT DIL only), PW pump running, PW flow on recorder).

Turn on PZR backup heaters.

BOP

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

Select SETPOINT.

Enter 0.4 MW/min into the RATE window.

Select ENTER.

Enter 1240 MW into REF DEMAND window.

Select ENTER.

Select EXIT.

o Notify US and RO of pending ramp.

Select GO/HOLD.

Verify GO/HOLD button illuminates.

Verify HOLD illuminated RED.

Select GO.

Verify GO illuminates RED.

Verify main turbine load begins to rise.

Comments:

NRC 14-1 Page 7

Scenario NRC 14-1 Event 2 No: No.

Event

Description:

Raise power at 0.5 MW/min Time Position Applicants Actions or Behavior RO/BOP

Monitor reactor power and load ascension:

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

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

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

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow predet counter responding correctly.

Verify dilution auto stops at preset value.

Return Reactor Makeup System to automatic.

After measurable change in power and lead examiner approves, initiate the next event.

Comments:

NRC 14-1 Page 8

Scenario NRC 14-1 Event 3 No: No.

Event

Description:

Unit Supervisor notified of 1A SI pump ASME surveillance failure Time Position Applicants Actions or Behavior 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: Restore pump to operable w/i 7 days o 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.

If SI pump control switch is placed in PTL, designates an operator to return switch to AT if required to start.

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

Comments:

NRC 14-1 Page 9

Scenario NRC 14-1 Event 4 No: No.

Event 0B SX MDCT Fan High Vibration requiring a Fan Trip

==

Description:==

Time Position Applicants Actions or Behavior

Annunciators SX CLG TWR FAN VIBRATION HIGH (0-37-E6) and OIL PRESSURE LOW (0-CUE 37-D6) are LIT

0B SX High Speed Fan Amps indicate High in Red Band

Refer to BAR 0-37-D6 and E6 BOP

Monitor amps NOT normal

Manually trip 0B SX Fan o Monitor SX system temperature and provide recommendation to US as to need for 2 SX fans o Dispatch EO to inspect fan and motor and check breaker for relay targets EVALUATORS NOTES: BOP SX-1 for SX PUMP operation requires at least 2 riser valves or 1 bypass valve open per SX pump. The crew must maintain 2 risers open.

The crew may not start another fan until SX temperatures rise enough to determine a second fan is required.

o Direct BOP to start an alternate SX Fan US o Evaluate TS 3.7.9; >6 fans are OPERABLE, so LCOAR entry is not required o Notify SM to evaluate online risk and create IR o Start 0C or 0D SX fan in High Speed BOP o Close 0SX163B, 0B SX Fan Riser Valve if another riser is opened.

Monitor primary and secondary panels RO o Assist with notifications EVALUATOR NOTE: After the actions for the fan trip are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-1 Page 10

Scenario NRC 14-1 Event 5 No: No.

Event

Description:

1A Tcold RTD Failed High 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 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 o Order ramp in HOLD RO

Verify/Place Rod Bank Select Switch in MANUAL

Manually defeat 1A Tave channel

Manually defeat 1A T channel

Select operable RTD for the T recorder

Check if Rod Control can be placed in AUTO

Check C-5 NOT LIT o May place rods in AUTO if Tave within 1° of Tref

Check Pzr level trending to normal

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

Assist RO with BAR response o Place ramp in HOLD CREW

Verify no previously tripped bistables will cause a reactor or turbine trip o Mark bistables to be tripped with dots CREW

Coordinate with WEC to trip or bypass Loop A bistables o Defeat T0402 in PDMS input US

Determines TS 3.3.1 condition A & E is applicable; DEL 3.3.2 for P-12 EVALUATOR NOTE: After the actions for the instrument failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-1 Page 11

Scenario NRC 14-1 Event 6 No.: No.:

Event Feedwater flow channel 1FT-521 fails low

==

Description:==

Time Position Applicants Actions or Behavior CUES: o Annunciator 1B SG FW FLOW MISMATCH (1-15-B4) o FW flow indicator 1FI-521A lowering o FW flow indicator 1FI-520A rising o FWRV 1FW-520 opening o 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 Place ramp on hold 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.

Consider recommencing the ramp 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 US Request maintenance to troubleshoot. Notify SM for IR/WR EVALUATOR NOTE: After the actions for the feedwater flow channel failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-1 Page 12

Scenario NRC 14-1 Event 7 No: No.

Event

Description:

VCT Level Channel 1LT-112 Failed Low Time Position Applicants Actions or Behavior CUE

Annunciator VCT LEVEL HIGH-HIGH LOW is LIT

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 STOP

Monitor VCT level o Makeup to VCT in MANUAL if required (BOP CV-7)

US

Notify SM of failure, request IR BOP

Monitor primary and secondary panels

Assist with BAR response EVALUATOR NOTE: After the actions for the VCT level failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-1 Page 13

Scenario NRC 14-1 Event 8&9 No: No.

Event

Description:

1C RCP Trip with ATWS 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-50 o All Turbine throttle valves - CLOSED.

o All Turbine governor valves - CLOSED.

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/BOP

Verify/ensure Control Rods inserting in Manual or Auto at least 48 steps per minute CT-52

Check at least 1 CV pump running

Initiate emergency boration by

Open 1CV8104

Start boric acid transfer pump

Check emergency boration and charging flows > 30 GPM OR

Open 1CV112D and/or 1CV112E

Close 1CV112B and/or 1CV112C

Maximize charging flow Comments:

NRC 14-1 Page 14

Scenario NRC 14-1 Event 8&9 No: No.

Event

Description:

1C RCP Trip with ATWS Time Position Applicants Actions or Behavior

Verify letdown established RO/BOP

Check Pzr pressure < 2335 PSIG

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:

NRC 14-1 Page 15

Simulation Facility Byron Scenario No.: Operating Test No.: Byron NRC 2014 N14-2 Examiners: Applicant:

______________________ ____________________ SRO

______________________ ____________________ RO

______________________ ____________________ BOP Initial Conditions: IC-105 Turnover: Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm.

1A MDFW pump has been OOS for the last 2 days for motor replacement and is expected back in 2 shifts. At the end of last shift, following an ASME run of the 1A AF pump it was noticed that the temperature on the 1A Train of AFW to the 1A S/G has elevated temperature of 160 degrees. No actions have been taken.

Event No. Malf. No. Event Event Type Description Preload FW44 1B AF pump fail to start IZDI1FW01PA ptl 1A MDFW pp O.O.S.

ZDI1FW002A cls ZLO1FW002A1 off ZDI1FW012A cls ZLO1FW012A1 off ZDI1FW01PAB ptl FW027 0 ZLO1FW002A2 off 1 None C (BOP, US) Local report of hot AFW piping at 1AF005A (Replaces N)

TS (US) 2 CV01A C (RO, US) 1A CV pump trip.

TS (US) 3 ED07A C (US, BOP) Loss of bus 141 TS (US) 4 FW02A C (BOP, US) 1B FW pp Trips requiring a main turbine runback.

5 RD09 1 R (RO, US) Auto rod speed fails to 1 SPM 6 RX21A 2500 10 I (RO, US) Pressurizer pressure channel 1PT-455 fails high TH11A 25 90 1RY455A stuck partially open 7 Preload M (ALL) Loss of heat sink

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

SCENARIO OVERVIEW Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration in 911 ppm. Control bank D rods are at 193 steps. The crew will come in and after their turnover will discover that 1AF005A has elevated temperature of 160 degrees.

After completing shift turnover and relief, the crew will assess the AFW elevated temperature condition and enter 1BOA SEC-7, Auxiliary Feedwater Check Valve Leakage. The BOP will be directed to close 1AF013A. The SRO will refer to Tech. Spec. 3.7.5 Condition A, making one train of AF inoperable and must restore within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

After completing the initial actions of 1BOA SEC-7, 1A CV pump trips. The RO will verify suction path and start the 1B CV pump to restore charging flow. The Unit Supervisor will determine that entry into TS 3.5.2 Condition A is necessary.

Following the CV pump trip, a ground fault will occur on Bus 141. The crew will enter 1BOA ELEC-3, LOSS OF 4KV ESF BUS. The 1B SX pump must be manually started along with 1D RCFC.

After the Bus 141 fault has been addressed, the 1B MFW pp will trip which will require a turbine runback to 700 MWe due to the MDFW pp being out of service. The crew will enter 1BOA SEC-1, SECONDARY PUMP TRIP.

During the runback, Auto Rod Speed will fail to 1 SPM, manual rod speed will be available at 48 SPM. This will require the RO to borate during the runback and manually drive rods in.

After stabilization of SG levels due to the runback, the controlling pressurizer pressure channel will fail high.

Pressurizer PORV 1RY-455A will open and fail to fully close. The PORV Isolation valve, 1RY8000A, is deenergized due to the Bus 141 fault, resulting in the control room inability to isolate the failed PZR PORV. The crew will manually trip the reactor and initiate Safety Injection due to lowering pressurizer pressure.

The 1B AF pump engine will seize. The crew will perform 1BEP-0, REACTOR TRIP OR SAFETY INJECTION, and either transition to 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK, at step 15 of 1BEP-0, or after transitioning to 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT, they will commence monitoring the STATUS TREES which will direct them to 1BFR-H.1. Feedwater isolation must be manually completed. The scenario is complete when the crew has established adequate feedwater pump flow from the Startup Feedwater pump to the non-faulted SGs in step 9 of 1BFR-H.1.

Critical Tasks CT-9: Manually start SW (SX) pumps for safeguards equipment cooling.

CT-43: Establish main feedwater or condensate flow to SG(s) before bleed and feed is required.

References 1BOA SEC-7 BAR 1-9-A3 1BOA ESP-2 TS 3.5.2 1BOA ELEC-3 1BOA SEC-1 1BEP 0 1BEP 1 1BFR H.1 NRC 10-2 Page 2 of 21

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 105 (password nrc14), 89% power, MOL, steady state.

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).

Ensure Rod Control is in auto.

Verify/Place 1A CV pump in service, shut down 1B CV pump.

Verify/Place 0B VC Train in service

Verify/Place 1B VP Chiller in service

Verify/Place Div. 12 AB supply and return fan in service.

Place 1A MDFW pp C/S in Pull-Out

Place 1A MDFW pp Aux. L/O pp C/S in Pull-Out

Verify/Close 1FW002A: 1A FW pump discharge valve

Verify Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N14-2 from thumb drive and verify the following actions load in the CAEP:

Byron 2014 ILT NRC scenario 14-2l00:00:00l1 Event 2: 1A CV pump tripl00:00:02l3 IMF CV01Al10:00:00l4 Event 3: Loss of Bus 141l00:00:03l6 IMF ED07Al10:00:00l7 Crosstie DC 111 from DC211l00:00:04l8 irf ed111 closel10:00:00l9 Event 4 & 5: 1B MFW pump trip and rod speed failurel00:00:04l11 IMF FW02Al10:00:00l12 IMF RD09 1l10:00:00l13 Event 6: Pressure channel and PORVl00:00:05l15 IMF RX21A 2500 10l10:00:00l16 IMF TH11A 25 90l10:00:00l17 Preloadl00:00:06l19 IMF FW44l00:00:07l20 IOR ZDI1FW01PA ptll00:00:08l21 IOR ZDI1FW002A clsl00:00:09l22 IOR ZLO1FW002A1 offl00:00:10l23 IOR ZDI1FW012A clsl00:00:11l24 IOR ZLO1FW012A1 offl00:00:12l25 IOR ZDI1FW01PAB ptll00:00:13l26 MRF FW027 0l00:00:14l27 IOR ZLO1FW002A2 offl00:00:15l28 NRC 10-2 Page 3 of 21

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Elevated AF piping piping temperature As SM Acknowledge entry into 1BOA SEC-7 and performing risk assessment and making appropriate notifications.

If called as Aux. Building E.O. report that temperature at the 1AF005A and 1A AF Pp discharge are slowly lowering after 1AF013A was closed.

Event 2: 1A CV Pump Trip IMF CV01A As EO, report overcurrent trip on 1A CV pump, and 1B CV pump is running normally after the start.

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

Acknowledge as Shift Manager commencement and completion of all procedures performed by the crew when notified.

Event 3: Loss of 4KV ESF Bus 141 Insert IMF ED07A to cause a loss of Bus 141 As EO inform crew that a ground overcurrent relay target for the BKR 1412 has dropped, after being dispatched If requested and at Lead Examiners discretion as Equipment Operator to cross-tie 125 VDC bus 111 to 125VDC bus 211 wait five minutes and call the Control Room as the EO and say you are ready to cross-tie.

Insert the following:

MRF ED111 CLOSE If dispatched as Equipment Operator to depress 1A DG emergency stop push button insert the following:

MRF EG19 TRIP As SM acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

SM Acknowledge entry into Tech Specs NOTE to EVALUATORS: Events 4 and 5 (next page) will be run simultaneously.

Event 4: 1B FW pp Trip Insert IMF FW02A to trip the 1B FW pump..

If dispatched as Equipment Operator to the FW pumps, report no abnormal indications present.

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

Acknowledge as chemistry/rad protection requests for RCS samples and surveillance performance.

NRC 10-2 Page 4 of 21

Event 5: Auto Rod speed failure to 1 step per minute in auto Insert IMF RD09 1 to fail rod speed to 1 SPM in auto.

Unit 1 will lower power to 700 MW at 250 MW/min due to FW pump trip Acknowledge as chemistry/rad protection requests for RCS samples (if required).

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

Event 6: Pressurizer pressure channel 1PT-455 fails high: resulting in a Reactor trip due to failed partially open PZR PORV Insert IMF RX21A 2500 10 to fail 1PT-455 high over a 10 second period.

Insert IMF TH11A 25 90 to fail 1RY455A to 25% open over 90 seconds As SM acknowledge the entry into 1BEP-0 Acknowledge as SM procedure changes, E Plan evaluations, and STA request.

After STA requested, as STA report CSF status - Red path on heat sink (until feed flow established).

If dispatched as Equipment Operator, report 1B AF pump has large lube oil leak and engine damage.

Acknowledge as U2 NSO request to remove FW isolation fuses insert the following:

MRF FW150 REMOVED

MRF FW151 REMOVED Acknowledge as Equipment Operator to start Startup FW pump aux oil pump and insert the following:

MRF FW149 START To complete Phase A isolation as requested

Set chv1wo006A=0 (1WO006A)

Set chv1wo020A=0 (1WO020A)

MRF CV17 0 (1CV8100)

If directed to close 1WO056B as E.O. inform the crew that the WEC is briefing an operator to close it.

NRC 10-2 Page 5 of 21

Scenario NRC 14-2 Event 1 No: No.

Event

==

Description:==

Elevated AF piping temperatures Time Position Applicants Actions or Behavior CUE

From turnover that AFW piping has elevated temperature at 1AF005A of 160 degrees US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Request On-Line risk evaluation.

Enter/Implement 1BOA SEC-7 AUXILIARY FEEDWATER CHECK VALVE LEAKAGE, and direct operator actions of 1BOA SEC-7.

US

Directs BOP to close 1AF013A BOP

Close 1AF013A US

Refers to Tech. Spec. 3.7.5

Determines 1A AF Train is inoperable: Enters Condition A: Action: Restore train within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months EVALUATOR NOTE: After the 1AF013A has been closed and notifications made, and with lead examiners concurrence, insert the next event.

Comments:

NRC 10-2 Page 6 of 21

Scenario NRC 14-2 Event 2 No: No.

Event

==

Description:==

1A CV Pump Trip Time Position Applicants Actions or Behavior CUE

Annunciator CHG PUMP TRIP (1-9-A3) is LIT

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

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

1PR06J loss of flow alarm US o Direct use of BAR 1-9-A3 RO

Identifies 1A CV pump trip CREW

Identifies Letdown needs to be isolated RO

Close 1CV8149A and 1CV8149B, Orifice Isol Valves

Close 1CV459 and 1CV460, Letdown Isol Valves RO

Verify available suction path with no gas binding concerns o VCT level is adequate o 1CV112B and 1CV112C are open o Check computer group TR28

Verify 1CV8110 and 1CV8116 are open

Adjust 1CV121 to 10% open

Start 1B CV pump Adjust charging flow to minimize PZR level rise EVALUATOR NOTE: The steps to restore letdown per 1BOA ESP-2 follow below.

CREW

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

Verify/Close 1CV8149A-C and 1CV459 and 1CV460

Verify/Open 1CV8401B

Verify/Open 1CV8324B

Verify/Open 1CV8389B

Verify/Open 1CV8152 and 1CV8160

Verify BTRS Mode Selector Switch is OFF

Place 1CV131 Controller to MANUAL at 40% demand

Place 1CC130A Controller to MANUAL at 60% demand

Verify/Open 1CV8105 and 1CV8106

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

Throttle 1CV121 to raise charging flow to 100 GPM

Open 1CV459 and 1CV460

Open 1CV8149A and 1CV8149B/C

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

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

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

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

NRC 10-2 Page 7 of 21

Scenario NRC 14-2 Event 2 No: No.

Event

==

Description:==

1A CV Pump Trip Time Position Applicants Actions or Behavior

Verify 1PR06J is in service Crew o Dispatch EO to check 1A CV pump breaker o Dispatch EO to check 1B CV pump after start for normal operation BOP

Assist in monitoring primary plant while RO starts 1B CV pump

Provide assistance in diagnosis and BAR response.

US

Notify SM of pump trip and request IR and request an on-line risk assessment.

Evaluate TS 3.5.2 Condition A: Restore train to operable in 7 days

Evaluate TRM 3.1.d Condition A: Restore CV pump to operable in 7 days EVALUATOR NOTE:

After the actions for the pump trip are complete and with lead examiner concurrence, enter next event.

Comments:

NRC 10-2 Page 8 of 21

Scenario NRC 14-2 Event 3 No: No.

Event Loss of 4KV ESF Bus 141

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator BUS 141 FD BRKR 1412 TRIP (1-21-A7)

ESF bus alive light (141) NOT lit.

No voltage indicated on Bus 141.

BOP

Determine Bus 141 deenergized.

Reference BARs.

CREW

Identify entry conditions for 1BOA ELEC-3, LOSS OF 4KV ESF BUS.

Dispatch operators to investigate status of bus 141.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Enter/Implement 1BOA ELEC-3 "LOSS OF 4KV ESF BUS " and direct operator actions of 1BOA ELEC-3 to establish the following conditions:

BOP

Check ESF Buses energized:

Bus 141 (Deenergized)

BOP Verify required ESF loads energized on Bus 142

Bus 132X and 132Z RO

1B CV pump o 1B RH pump BOP o 1B SI pump

1B and 1D RCFC o 1B CS pump

1B CC pump BOP

1B SX pump CT-9

Start 1B SX pump

0B VC Train

VA Supply and Exhaust fans BOP Check Bus 141 not faulted

Place ACB 1413 in Pull Out

Place ACB 1411 in Pull Out

Place ACB 1412 in Pull Out

Place ACB 1414 in Pull Out BOP

Check Bus 141 lock out alarms NOT lit:

Comments:

NRC 10-2 Page 9 of 21

Scenario NRC 14-2 Event 3 No: No.

Event Loss of 4KV ESF Bus 141

==

Description:==

Time Position Applicants Actions or Behavior

Bus 141 FD BRKR 1412 TRIP (1-21-A7). (THIS WILL BE LIT)

BRKR 1414 CROSS-TIE OVERCURRENT (1-21-B8).

DG 1A OVERLOAD (1-21-B9).

US GO TO STEP 6 of 1BOA ELEC-3 ATTACHMENT A

Direct WEC to X-tie DC Buses with U-2 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

Refer to Tech Specs 3.8.1 and others as applicable o Refer to Table A (pgs 45-48) for containment isolation valves affected US

Evaluate Tech Specs

3.8.1 Condition A, B & e

3.8.4 Condition A

3.8.9 Condition A o Unit 2 is in 3.8.4 Condition B and 3.8.1 Condition A

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

EVALUATOR NOTE:

After the actions for the Loss of Bus 141 are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 10-2 Page 10 of 21

Scenario NRC 14-2 Event 4 and 5 No: No.

Event MFW Pump Trip and Auto Rod Control Speed fails to 1 step per minute

==

Description:==

Time Position Applicants Actions or Behavior CUE Annunciators:

1-16-B1 FW PUMP 1B TRIP 1-16-D2 FW PUMP DSCH FLOW LOW Rod IN lit is LIT with 1SPM indicated (after runback is initiated)

Feed flow dropping ALL

Identify/report loss of 1B FW pump US/ Direct implementation of 1BOA SEC-1, SECONDARY PUMP TRIP BOP

Close 1B FW pump recirc valve- 1FW012B

Check turbine load > 700MW

Verify 1C FW Pump is running- recognize 1A FW pump is not available

Initiate turbine runback- pushbutton on 1PM03J OR select CD/FW Runback on OWS panel Graphic 5512 and select execute.

Check turbine load dropping RO

Verify Rod Control in AUTO

Recognizes rod speed is improper for conditions (@ 1 spm and should be much greater)

Takes manual control after boration is started and drives rods in, in manual

Initiate boration as necessary- per REMA plaque Note: value should be between 150 and 280 gallons of boric acid

Determine required boric acid volume.

o Refer to Rema for ramp.

Perform the following at 1PM05J:

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

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

Place MAKE-UP MODE CONT SWITCH to STOP position.

Place MODE SELECT SWITCH to BORATE position.

Place MAKE-UP MODE CONT SWITCH to START.

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

o Turn on PZR backup heaters BOP

Start standby CD/CB pump

Start aux. oil pump for standby CD/CB pump

Start standby CD/CB pump BOP

Check FW PUMP NPSH LOW alarm LIT o Check CP bypass valves 1CD210A and B open o Check standby CD/CB pump running o Verify Heater Drain pump discharge valves responding- 1HD046A and B o Check CB pump recirc valves in auto- 1CB113A-D Comments:

NRC 10-2 Page 11 of 21

Scenario NRC 14-2 Event 4 and 5 No: No.

Event MFW Pump Trip and Auto Rod Control Speed fails to 1 step per minute

==

Description:==

Time Position Applicants Actions or Behavior o Check CD pump recirc valve closed-1CD152 o Check Gland steam condenser valves open- 1CD157A and B BOP

Check Feed Flow Restored Feed flow greater than or equal to steam flow (unless operator action is taken to prevent overfeeding)

SG levels stable at or trending to normal

Turbine runback not lit / reset Turbine Runback (pull out button)

EVALUATOR NOTE:

When feed flow is > steam flow and SG levels are rising and with lead examiners concurrence, insert the next event.

Comments:

NRC 10-2 Page 12 of 21

Scenario NRC 14-2 Event 6 No: No.

Event Pressurizer pressure channel 1PT-455 fails high resulting in a Reactor Trip due to failed partially

==

Description:==

open PZR PORV.

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.

BOP o Refer to BARs

Monitor secondary panels

Assist RO as requested RO

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

PZR PORVs closed.

1RY455A indicates partially open

Recognizes can not close 1RY8000A

Determines PZR Pressure can not be maintained then:

Recommend/TRIP the reactor and manually Safety Inject US

Concur/Direct CREW actions

GO to 1BEP 0 REACTOR TRIP OR SAFETY INJECTION Comments:

NRC 10-2 Page 13 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior CUE Annunciator MANUAL RX TRIP (1-11-A1)

Annunciator MANUAL SI/RX TRIP (1-11-A2 Annunciator PZR PRESS LOW SI/RX TRIP (1-11-C1)

Reactor trip indications at 1PM05J.

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 to establish the following conditions:

RO Perform immediate operator actions of 1BEP-0 at 1PM05J:

Verify reactor trip:

Rod bottom lights - ALL LIT.

Reactor trip & Bypass breakers - OPEN.

Neutron flux - DROPPING.

BOP Perform immediate operator actions of 1BEP-0 at 1PM02J Verify Turbine Trip:

All Turbine throttle valves - CLOSED.

All Turbine governor valves - CLOSED.

BOP Perform immediate operator actions of 1BEP-0 at 1PM01J:

Verify power to 4KV busses:

ESF bus 141 - DEENERGIZED.

ESF bus 142 - ENERGIZED.

CREW

Manually actuate SI at 1PM05J & 1PM06J. (If not already performed)

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. Only 1 train of ESF equipment will be operating.

EVALUATOR NOTE: 1BEP-0, Attachment B is continued at the end of the scenario guide.

RO

Step 6: Verify AF system:

AF pumps - NO AF pumps RUNNING.

Comments:

NRC 10-2 Page 14 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

Attempt to start 1B AFP

AF isolation valves - 1AF13A-H OPEN. (1AF013A-D are deenergized)

AF flow control valves - 1AF005A-H THROTTLED.

AF flow - < 500 GPM o Identify transition to 1BFR-H.1 (IF all SG levels are <10% NR level)

CREW Identify entry conditions for 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

EVALUATOR NOTE:

NR SG Level may not be <10% at this point. In that case, the crew will continue in 1BEP-0, transitioning to 1BEP-

1. When all SG NR levels are <10%, the crew will transition to 1BFR-H.1 on a BST Heat Sink Red Path.

BOP will continue in 1BEP-0 Attachment B verification, and may periodically be directed to perform steps of 1BFR-H.1 by the SRO. 1BEP-0 Attachment B steps are continued at the end of the scenario guide.

The following italicized step is the step of 1BEP-0 that results in the transition to 1BEP-1.

RO

Step 7: Check PZR PORVs and SPRAY VALVES at 1PM05J:

1RY455A & 1RY456 CLOSED (1RY455A is open)

PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED (1RY800A is deenergized)

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

Normal PZR Spray Valves CLOSED US

Identify transition to 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT

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

Request STA to initiate monitoring of the status trees EVALUATOR NOTE:

Once the transition is made to 1BEP-1 LOSS OF REACTOR OR SECONDARY COOLANT, the STA will be monitoring Status Trees for transition to 1BFR-H.1 RESPONSE TO LOSS OF SECONDARY HEAT SINK.

(ALL WE ARE WAITING FOR IS ALL SG NR LEVELS TO BE < 10%)

The 1BEP 1 actions (italicized) below are contained until it is anticipated that a transition will be made to 1BFR-H.1.

RO

Step 1: Check Status of RCPs:

RCPs - ALL RUNNING RO/

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

BOP

Check pressure in all SGs:

Comments:

NRC 10-2 Page 15 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

None dropping in an uncontrolled manner

None completely depressurized

Step 3: Check intact SG levels

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

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 RO

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

PORV isol valves - BOTH ENERGIZED (1RY8000A is deenergized)

PORV relief path - BOTH PORVs in AUTO, 1RY8000A & B - OPEN (PORV 1RY455A is OPEN)

CREW

Step 6: Check if ECCS flow should be reduced

RCS subcooling -(will be acceptable)

Secondary heatsink (may or may not be acceptable-if NOT transition to 1BFR-H.1)

RCS stable or rising

PZR level >12%

Transition to 1BEP ES-1.1 EVALUATOR NOTE: 1BEP-1 actions continue below.

If crew requests permission from SM to transition to 1BFR H.1 before all SG levels are <10% NR (31% NR/adverse CNMT), AS SM instruct US to perform the procedures as written.

CREW

Step 7: Check if CS should be stopped

Both CS pumps -BOTH 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 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

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 Comments:

NRC 10-2 Page 16 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

Verify AUTO SI BLOCKED BP light NOT lit at 1PM05J RCS pressure - NOT> 325 psig & stable

Step 9: Determine there are no faulted SGs

Step 10: Stop running Diesel Generators

Step 11: Initiate evaluation of plant status EVALUATOR NOTE:

When ALL NR levels are <10% the crew will transition to 1BFR-H.1.

CREW Identify entry conditions for 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK.

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Request STA evaluation of status trees.

Enter/Implement 1BFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK and direct operator actions of 1BFR-H.1 to establish the following conditions:

RO

Check if secondary heat sink is required:

RCS pressure > intact SG pressures.

RCS temperature > 350°F.

US/RO

Check CV pump status at 1PM05J:

CV pumps - 1 RUNNING.

RO

Check if Bleed and Feed is required

Wide range level in any 3 SGs <27% or

PZR pressure > 2335 BOP

Try to establish AF flow to at least 1 SG (Note: 1A AF pump has no electrical power and 1 B AF pump is inoperable)

All SG BD iso. Valves (1SD002A-H) closed

All SG sample isolation valves (1SD005A-D) closed o Review attachment B prior to FW flow initiation

Check AF pump SX suction valves armed alarm NOT Lit (1-3-E7)

Check AF test valves open (1AF004A and B)

Check AF pumps-Both running

Dispatch an operator to locally start

Check AF isol. valves (1AF013A-H)for selected SG open Comments:

NRC 10-2 Page 17 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

Check AF flow control valves (1AF005A-H) throttled

Check total feed flow to SG >500 gpm.

GO TO STEP 5 RO

Stop all RCPs.

CREW

GO TO STEP 7 BOP

Check at least 1 CD/CB pump running

Place FWRV (1FW510,20,30,and 40) in manual at 0

Place FWRV Bypass valves (1FW510A,20A,30A,and 40A) in manual at 0

Place Tempering Flow control valves (1FW034A,B,C and D) in manual at 0.

BOP

Reset FW Isolation

Check FW Isol. Aux. relays light any lit. (go to step 8.f.)

Dispatch an operator to pull Feedwater Isolation Aux. Relay Fuses

1PA 27J: FU 24 and 27

1PA 28J: FU 24 and 27 BOP

Try to establish FW flow to at least 1 SG:

Open FW Tempering iso valve on selected SG(s) (1FW035A-D)

Check S/U FW pump available

Check at least 2 CD/CB running BOP

Prepare SU FW pump for operation:

Bus 159 energized

Dispatch operator to start aux oil pump for S/U FW pp.

Check 1FW059 (disc. valve ) open

Place recirc valve in modulate (1FW076)

Close MFW pp recirc valves (1FW012A,B, C)

Start S/U FW pp.

Review Attachment B Crew

Determine the SGs are NOT DRY

Determine SG feed lines are NOT VOIDED

Determine that a minimum of 2 SGs must be fed.

BOP

Establish and throttle Tempering Flow Control Valve(s) on selected SGs CT-43 1FW034A 1FW034B 1FW034C 1FW034D Comments:

NRC 10-2 Page 18 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

Maintain hotwell level > 7 inches

S/G NR Level rising NOTE: At Evaluators discretion this scenario may be terminated EVALUATOR NOTE:

1BEP-0 Attachment B steps are continued here for verification as the BOP performs them.

Att B, Step 1: Verify ECCS pumps running BOP

1B CV pump - RUNNING

1B RH pump - RUNNING

1B SI pump - RUNNING BOP

Att B, Step 2: Verify ECCS valve alignment

Determine Group 2 Cold Leg Injection monitor lights required for injection - All available lights are lit BOP

Att B, Step 3: Verify ECCS flow

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

RCS pressure >1700 psig BOP

Perform the following at 1PM06J:

Att B, Step 4: Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode lights - 2 LIT.

Att B, Step 5: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - ALL AVAILABLE LIT.

Att B, Step 6: Verify Cnmt Vent isolation:

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

o Verify MSIV and Bypass Valves - CLOSED

Att B, Step 7: Verify CC pumps - 1B RUNNING.

Att B, Step 8: Verify SX pumps - 1B RUNNING.

Att B, Step 9: Check if Main Steamline Isolation -required:

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

CNMT pressure < 8.2 psig.

BOP

Att B, Step 10: Check if CS is required <Cont Action Step>

CNMT pressure has NOT risen > 20 psig.

Comments:

NRC 10-2 Page 19 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior BOP

Att B, Step 11: Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

FW pumps discharge valves - 1FW002A-C CLOSED

Trip all running HD pumps.

Att B, Step 12: Verify DGs running at 1PM01J:

DGs - 1B DG running

1SX169B OPEN.

Dispatch operator locally to check operation

Att B, Step 13: Verify Generator Trip at 1PM01J:

OCB 1-8 and 7-8 open.

PMG output breaker open.

BOP

Att B, Step 14: Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0B Supply fan

0B Return fan

0B M/U fan

0B Chilled water pump

0B Chiller

Operating VC train dampers - ALIGNED.

M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.

0B VC train M/U filter light - LIT.

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED

0VC05Y - OPEN

0VC06Y - OPEN

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

BOP

Att B, Step 15: Verify Auxiliary Building ventilation aligned at 0PM02J:

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CB - RUNNING Comments:

NRC 10-2 Page 20 of 21

Scenario NRC 14-2 Event 7 No: No.

Event Rx Trip/Loss of Heat Sink

==

Description:==

Time Position Applicants Actions or Behavior

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

Att B, Step 16: Verify FHB ventilation aligned at 0PM02J:

0VA04CB - RUNNING

0VA055Y - OPEN

0VA062Y - OPEN

0VA435Y - CLOSED BOP

Att B, Step 17: Maintain UHS Basin Level - >80% <Cont Action Step>

Att B, Step 18: Initiate periodic checking of Spent Fuel Cooling

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

Att B, Step 19: Notify US of actions taken, equipment status, CAS ownership and that Attachment B is completed o Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100 May notify WEC of this step.

(Final)

Comments:

NRC 10-2 Page 21 of 21

Simulation Facility Byron Scenario No.: Operating Test No. Byron NRC 2014 N14-3 Examiners: Applicant: SRO

_ ___________________ ____________________

RO

____________________ ____________________

BOP

____________________ ____________________

Initial Conditions: IC-99 Turnover: Unit 1 is in MODE 2 at 2% power, BOL, at 1BGP 100-2, step 21, raising power to 2% - 3% power.

Boron concentration is 1316 ppm. Permission has been given to go to MODE 1. An extra NSO will perform 1BOSR NR-1.

Event No. Malf. No. Event Event Type* Description 1 None N (BOP, Realign Feedwater through 1FW039 valves SRO) 2 None R (RO) Power ascension to 2% - 3% power.

(SRO) 3 CV07A 80 60 C(RO, SRO) CV Seal Injection Filter Clogged 4 SW01A C (BOP, SX Pump trip SRO)

TS (SRO) 5 RX21A 2500 10 I (RO, SRO) Pressurizer Pressure channel 1PT-455 fails high TS (SRO) 6 PA0005 ON TS (SRO) MSIV inoperability; MSIV 1A HYD/PNEU PRESS PB2400 ON HIGH/LOW, 1-1-B5 alarm 7 SET FWV1WG046=0.05 C (BOP, Loss of vacuum causing loss of steam dumps IOR ZLO1WG0462 OFF SRO) 8 MS03Q 100 M (all) 1D SG Safety valve stuck open on reactor trip 9 MS01A 100 (in preload) C (all) All MSIVs failed open MS01B 100 MS01C 100 MS01D 100

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

SCENARIO OVERVIEW Unit 1 is in MODE 2 at 2% power, BOL, at 1BGP 100-2, step 21, raising power to 2% - 3% power. Boron concentration is 1316 ppm. Permission has been given to go to MODE 1. An extra NSO will perform 1BOSR NR-1.

After completing shift turnover and relief, the BOP will realign feedwater from the tempering line through the 1FW039 valves in accordance with 1BGP 100-2, step 21.

After feedwater is realigned, the crew will ramp the unit to 3% - 5% power in accordance with 1BGP 100-2, step 17.

With the ramp in-progress, the annunciator for RCP Seal Injection High DP will alarm. BOP CV-10, CV Filter Operations will be utilized to swap Seal Injection Filters. The crew may enter 1BOA RCP-2, Loss of Seal Cooling, which directs the use of BOP CV-10 to swap filters.

After the seal injection filter is put in service, the 1A SX pump will trip. The crew will start the 1B SX pump manually in accordance with BAR 1-1-A1 and 1BOA PRI-7, Loss of SX. The SRO will evaluate TS 3.7.8. condition A for Unit 1, and LCO is fully met for Unit 2.

After the SX pump trip actions have been completed, the controlling pressurizer pressure channel will fail high.

Pressurizer PORV 1RY-455A will open, both pressurizer spray valves will open, and all pressurizer heaters will deenergize, causing RCS pressure to lower. The RO will take manual control of RCS pressure control and stabilize RCS pressure. 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment B, will be implemented. The RO will restore RCS pressure control to automatic after pressure is restored to normal and an operable pressure control channel is selected. Technical specifications 3.3.1, conditions A, E, and K, 3.3.2, conditions A and D, and 3.3.4, condition A apply.

After the pressurizer pressured channel failure has been addressed, MSIV 1A HYD/PNEU PRESS HIGH/LOW, 1-1-B5 alarm comes in. The crew will dispatch an operator to investigate, and the SRO will evaluate TS 3.7.2.

After the MSIV alarm has been investigated, Main Condenser vacuum will degrade. The crew will enter 1BOA SEC-3, Loss of Vacuum, and upon having steam dumps close on condenser unavailable, will trip the reactor. On the reactor trip, 1MS017A, 1D SG Safety Valve will stick full open, lowering steam pressure in all SGs. All 4 MSIVs will be failed open and cannot be closed automatically or manually. Crew will use 1BEP-0, 1BEP-2 and 1BCA 2.1.

Completion criteria is when feed flow has been lowered to 45 GPM for each SG in 1BCA 2.1.

Critical Tasks CT-1: Manually trip the reactor.

CT-33: Control AFW to minimize RCS cooldown.

Reference:

1BGP 100-2 1BOA RCP-2 BOP CV-10 1BOA PRI-7 BAR 1-1-A1 1BOA INST-2 BAR 1-1-B5 1BOA SEC-3 1BEP-0 1BEP-2 1BCA 2.1.

Page 2

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 99 (password nrc14), 2% power, BOL, steady state. (from IC-12)

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 Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N14-3 from thumb drive and verify the following actions load in the CAEP:

Byron 2014 ILT NRC scenario 14-3l00:00:01l0 Event 3: CV Seal Injection Filter Cloggedl00:00:08l2 IMF CV07A 80 60l10:00:00l3 Open 1CV8384Bl00:00:09l4 MRF CV42 100l10:00:00l5 close 1CV8384Al00:00:10l6 MRF CV41 0l10:00:00l7 Event 4: SX Pump tripl00:00:11l9 IMF SW01Al10:00:00l10 Event 5: Pressurizer Pressure channel 1PT-455 fails highl00:00:12l12 IMF RX21A 2500 10l10:00:00l13 Event 6: MSIV inoperabilityl00:00:13l15 IMF PA0005 ONl10:00:00l16 IMF PB2400 ONl10:00:00l17 Event 7: Loss of vacuum causing loss of steam dumpsl00:00:14l19 IOR ZLO1WG0462 OFFl10:00:00l20 SET FWV1WG046=0.05l10:00:00l21 Event 8 & 9: 1D SG Safety valve stuck open on reactor tripl00:00:15l23 trgset 12 "zlo52brka(2).gt.0"l00:00:02l24 trg 12 "imf ms03q 100"l00:00:03l25 IMF MS01A 100l00:00:04l26 IMF MS01B 100l00:00:05l27 IMF MS01C 100l00:00:06l28 IMF MS01D 100l00:00:07l29 Page 3

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Realign Feedwater through 1FW039 valves.

Event 2: Ramp unit to 2% - 3% power SM acknowledges start of ramp when notified.

Event 3: CV Seal Injection filter clogged IMF CV07A 80 60 AS EO, report 1A Seal Injection filter DP at 35 PSID (High alarm setting is 29 PSID).

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

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

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

If the crew requests permission from the SM to perform 1BOSR 5.5.1.1 after changing out the clogged seal injection filter acknowledge and inform the crew that this task will be completed by an extra NSO.

Event 4: 1A SX Pump trip IMF SW01A to trip the 1A SX pump.

AS EO, report 1A SX pump has an overcurrent relay tripped on Bus 141.

AS EO, (if requested per 1BOA PRI-7) report: 1A SX pump - NOT ROTATING Event 5: Pressurizer Pressure channel 1PT-455 fails high Insert IMF RX21A 2500 10 to fail 1PT-455 high over a 10 second period.

As the WEC, asknowledge request to bypass or trip bistables and report that operators are being briefed for the task.

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.

Event 6: MSIV inoperability IMF PA0005 ON and PB2400 ON As the EO, report 1A MSIV accumulators have both completely depressurized. No oil spill is present.

As SM acknowledge the failure, LCO 3.7.2, on line risk assessment, request for maintenance support, and IR request.

Event 7: Loss of vacuum causing loss of steam dumps SET FWV1WG046=0.05 to cause loss of Main Condenser vacuum (by slightly opening the vacuum breaker).

IOR ZLO1WG0462 OFF to override vacuum breaker OPEN light off As the EO, report hearing air leakage into Main Condenser hood on TB 426, but there is no way to seal it.

As SM Acknowledge 1BEP-0 entry and request for Emergency Plan evaluations.

Page 4

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

Event 8: Safety valve stuck open with ALL MSIVs failed open Verify MS01A 100, MS01B 100, MS01C 100, MS01D 100 (in preload) to fail all MSIVs fully open.

Verify MS03Q 100 on reactor trip to fail open 1D SG Safety Valve 1MS017A at 100%.

TR Operator calls on the radio and report there is a steam coming from the A/D safety valve room pipe.

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

Page 5

Scenario NRC 14-3 Event 1 No: No.

Event

Description:

Realign feedwater through 1FW039 valves Time Position Applicants Actions or Behavior Crew o Reviews 1BGP 100-2 precautions, limitations and actions.

US o Supervises performance of feedwater valve realignment BOP

Performs step 21 of 1BGP 100-2 to realign feedwater

Verifies FWRV Bypass valves 1FW510A-540A are closed

Dispatches EO to check closed FWRV 1FW510-540

Check SG pressures equal to FW inlet pressure

Open SG FW isolation valves 1FW041A-041D

Open FW Isolation valves 1FW039A-039D

Control SG levels with FWRV Bypass valves in MANUAL or AUTO.

RO

Maintains primary plant and power stable in MODE 2 while feedwater alignment is changed.

Comments:

Byron NRC 14-3 Page 6

Scenario NRC 14-3 Event 2 No: No.

Event

Description:

Ramp unit to 2% - 3% power Time Position Applicants Actions or Behavior CUE

Provide candidates with 1BGP 100-2 flowchart and ReMa US

Implement 1BGP 100-2 for a normal ramp

Instruct RO and BOP to review P, L & A of 1BGP 100-2.

Instructs RO to conduct reactivity brief to raise power to 2% - 3%.

RO

Conducts reactivity brief o Set up dilution IAW ReMa and BOP CV-6 o Initiate dilution using BOP CV-5 or BOP CV-5T1 checklist OR withdraws control rods.

Select STOP on RMCS Makeup Control Switch

Select DIL or ALT DIL on RMCS Mode Select Switch

Enter desired dilution amount in PW totalizer

Turn ON RMCS Makeup Control Switch

Verify 1CV110B OPEN if in ALT DIL

Verify 1CV111A and B OPEN

Verify proper PW flow on flow recorder

Monitors effects of reactivity addition: reactor power rise, more demand on steam dumps BOP

Monitors steam dump demand on UI-500

Monitors feedwater flow to maintain SG levels stable EVALUATOR NOTE: When reactivity ramp observation is accomplished and at evaluators cue, insert the next event.

Comments:

Byron NRC 14-3 Page 7

Scenario NRC 14-3 Event 3 No: No.

Event CV Seal Injection Filter Clogged

==

Description:==

Time Position Applicants Actions or Behavior

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

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

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

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

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

Restore Seal Injection

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

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

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

BOP

Provide assistance in diagnosis and BAR response.

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

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

Comments:

Byron NRC 14-3 Page 8

Scenario NRC 14-3 Event 4 No: No.

Event

Description:

SX Pump Trip Time Position Applicants Actions or Behavior CUE

Annunciator 1-2-A1,SX PUMP TRIP and 1-2-A2, SX PUMP DISCH HDR PRESS LOW are LIT

1A SX pump control switch breaker position disagreement light is LIT.

Crew o Acknowledge annunciator.

o Check BAR o Check SER alarm

Verifies voltage on all 3 phases of Bus 141 to be >3850 volts (per BAR 1-2-A1)

BOP

Start 1B SX pump

Holds switch until oil pump starts and SX pump starts RO o Performs support actions such as making a plant announcement, dispatching EO to pump and/or bus, and checking BAR US

Notify SM and requests IR generation

Review Tech Specs

3.7.8 Condition A applies to Unit 1. Since 1 Unit 1 SX pump is available, 3.7.8 is MET for Unit 2.

EVALUATORS NOTE:

The US may enter 1BOA PRI-7, but it is not necessary because the BAR response fulfills the required actions for this event. TS 3.7.8 must be evaluated.

US o (OPTIONAL) Implements 1BOA PRI-7, Essential Service Water Malfunction o Directs 1B SX pump to be started o Notifies SM of procedure entry and requests Emergency Plan evaluation o Dispatches EO to check 1A SX pump - NOT ROTATING o Orders SX pump discharge temperature verified between 50° and 80°F o Orders SX tower basin level verified between 100% and 80% and stable.

o Orders CC HX outlet temperature checked to be less than 105°F.

o Orders steps 5 performed to Check SX System Intact.

When the SX pump is started and actions are complete, and at evaluators cue, initiate the next event.

Comments:

Byron NRC 14-3 Page 9

Scenario NRC 14-3 Event 5 No: No.

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.

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.

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 Comments:

Byron NRC 14-3 Page 10

Scenario NRC 14-3 Event 5 No: No.

Event Pressurizer pressure channel 1PT-455 fails high.

==

Description:==

Time Position Applicants Actions or Behavior

If 1RY455A in 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.

US

Notify WEC to perform pre-job brief per HU-AA-1211 for bistable tripping or bypassing.

RO

Check P11 interlock at 1PM05J:

RCS pressure >1930 - P11 NOT LIT.

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.

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

After the actions for the pressurizer pressure channel failure are complete and at evaluators cue, insert the next event.

Comments:

Byron NRC 14-3 Page 11

Scenario NRC 14-3 Event 6 No: No.

Event

Description:

MSIV Inoperability Time Position Applicants Actions or Behavior CUE

Annunciator 1-1-B5, MSIV 1A HYD/PNEU PRESS HIGH/LOW alarm is LIT

SER points 0005 and 2400 are printed Crew

Check BAR for alarm

Dispatch EO to check on 1A MSIV US

Evaluates TS 3.7.2, Condition C (for MODE 2), close MSIV within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

Notifies SM of failure and requests risk evaluation and IR, and maintenance support EVALUATOR NOTE: When US have evaluated TS and at evaluators cue, the next event will be inserted.

Comments:

Byron NRC 14-3 Page 12

Scenario NRC 14-3 Event 7 No: No.

Event

Description:

Loss of vacuum causing loss of steam dumps Time Position Applicants Actions or Behavior CUE

Annunciator 1-18-D4, CNDSR VACUUM LOW is LIT

Condenser pressure is rising on MCB gauges and recorder

Steam dump valves CLOSE US

Enters 1BOA SEC-3

Notifies SM of procedure entry and requests E Plan evaluation

Determines condenser pressure - NOT ACCEPTABLE BOP

Verifies CW flow - NORMAL

Reports condenser pressure rising.

Reports loss of steam dumps US

Orders reactor trip and 1BEP-0 entry CREW

Initiate a manual reactor trip and transition to 1BEP-0.

CT-1 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 at 1PM05J:

Verify reactor trip.

Rod bottom lights - ALL LIT.

Reactor trip & Bypass breakers - OPEN.

Neutron flux - DROPPING.

BOP Perform immediate operator actions of 1BEP-0 at 1PM02J or OWS drop 210:

Verify Turbine Trip.

All Turbine throttle valves - CLOSED.

All Turbine governor valves - CLOSED.

BOP Perform immediate operator actions of 1BEP-0 at 1PM01J:

Verify power to 4KV busses.

ESF Buses - BOTH ENERGIZED (141 & 142).

EVALUATOR NOTE: The safety valve failure automatically inserts with the reactor trip.

Comments:

Byron NRC 14-3 Page 13

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior EVALUATORS NOTE:

Crew will most likely NOT actuate SI at this time, but will transition to 1BEP ES-0.1. After the TR Operator reports steam from the roof, the crew will attempt a manual Main Steam Line Isolation actuation and Safety Injection. If the crew does actuate MSLI/SI, the steps follow on the next page.

CREW

Step 4: Check SI Status

SI First OUT annunciator - NOT LIT

SI ACTUATED Permissive Light - NOT LIT

SI Equipment - NOT ACTUATED

Either SI pump - NOT RUNNING

Either CV pump to cold leg isolation valve - NOT OPEN - 1SI8801A/B

Recognize SI NOT Actuated

Check if SI Required

Pzr Pressure - NOT < 1829 #

Steamline Pressure - NOT < 640#

CNMT Pressure - NOT > 3.4#

Recognize SI is NOT required US

Transition to 1BEP ES-0.1, Reactor Trip Response

Direct STA to monitor BST

Notify SM of procedure entry

Request evaluation of Emergency Plan conditions CUE

TR Operator reports steam is coming from A/D Safety Valve room roof.

EVALUATORS NOTE: Crew will transition from 1BEP ES-0.1 back to 1BEP-0 when actuating SI. The steps in italics from 1BEP ES-0.1 will not be done after transitioning back to 1BEP-0 US

Direct the actions of 1BEP ES-0.1 RO

Step 1: Check RCS temperatures

Maintain RCS temperature at 557°F BOP

Control feed flow >500 gpm until > 1 SG level is > 10%

RO

Step 2: Check Shutdown Reactivity

All rod bottom lights LIT

Step 3: Control charging to control Pzr Level at normal level

Step 4: Check Pzr pressure trending to normal pressure Comments:

Byron NRC 14-3 Page 14

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior US

Orders Manual Safety Injection actuation o Orders Main Steam Line Isolation actuation RO/ o Attempts manual MSLI from 1PM05J and 1PM06J BOP o Attempts to manually close MSIVs with individual switches on 1PM06J.

RO/

Manually actuates SI from 1PM05J and/or 1PM06J BOP Crew

Re-enters 1BEP-0 US

Transition to 1BEP-0

Notify SM of procedure entry

Request evaluation of Emergency Plan conditions o Request STA to monitor BST (if not requested earlier)

Direct crew to re-perform Steps 1 - 3 of 1BEP-0

Verify Reactor Trip

Verify Turbine Trip

Verify 4KV busses energized CREW

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

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J US

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

RO

Step 6: Verify AF system:

AF pumps - BOTH AF pumps RUNNING.

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

AF flow - >500 GPM

Check SG tubes - INTACT and SG NR levels - NOT RISING UNCONTROLLED RO

Step 7: 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 Comments:

Byron NRC 14-3 Page 15

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior RO

Step 8: Maintain RCS temperature control at 1PM05J: <Cont Action Step>

o CT-33

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

(CT

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

MSIVs NOT closed met in

Attempts manual MSLI from 1PM05J and 1PM06J 1BCA

Attempts to manually close MSIVs with individual switches on 1PM06J.

2.1)

RO

Step 9: Check status of RCPs at 1PM05J:

Determine RCP trip NOT required

RCS pressure > 1425 psig RO/

Step 10: Check if SG secondary pressure boundaries are intact at 1PM04J:

SRO

Check pressure in all SGs:

All SG pressures are lowering in an uncontrolled manner.

Transition to 1BEP-2, Faulted Steam Generator Isolation (1BEP-2 follows the Attachment B steps that are listed below)

EVALUATOR NOTE: BOP is performing Attachment B:

BOP

Att B, Step 1: Verify ECCS pumps running

Both CV pumps - RUNNING.

Both RH pumps - RUNNING

Both SI pumps - RUNNING

Att B, Step 2: Verify ECCS valve alignment

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

Att B, Step 3: Verify ECCS flow

High Head SI flow >100 gpm (1FI-917) o RCS pressure > 1700 psig OR o RCS pressure < 1700 psig

1B SI pump discharge flow > 200 gpm o RCS pressure > 325 psig

Att B, Step 4: Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode lights - 4 LIT.

Att B, Step 5: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - ALL LIT.

Att B, Step 6: Verify Cnmt Vent isolation:

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

Att B, Step 7: Verify CC pumps - BOTH RUNNING.

Comments:

Byron NRC 14-3 Page 16

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior

Att B, Step 8: Verify SX pumps - BOTH RUNNING.

Att B, Step 9: Check if Main Steamline Isolation - REQUIRED:

o SG pressures > 640 psig - continue on in 1BEP-0 o 1A S/G pressure < 640 psig

Check MSIVs and bypass valves - CLOSED

1A MSIV - OPEN

Attempt to close 1A MSIV with BOTH MSLI switches and 1A MSIV switch

Att B, Step 10: Check if CS is required <Cont Action Step>

CNMT pressure has NOT risen > 20 psig.

Att B, Step 11: Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

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

Trip all running HD pumps.

Att B, Step 12: Verify DGs running at 1PM01J:

DGs - BOTH DG running

1SX169A/B OPEN.

Dispatch operator locally to check operation

Att B, Step 13: Verify Generator Trip at 1PM01J:

o OCB 1-8 and 7-8 open (NOT required because TG was NOT online)

PMG output breaker open.

Att B, Step 14: Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0B Supply fan

0B Return fan

0B M/U fan

0B Chilled water pump

0B Chiller

Operating VC train dampers - ALIGNED.

M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.

0B VC train M/U filter light - LIT.

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED Comments:

Byron NRC 14-3 Page 17

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior

0VC05Y - OPEN

0VC06Y - OPEN

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

Att B, Step 15: Verify Auxiliary Building ventilation aligned at 0PM02J:

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CB - RUNNING

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

Att B, Step 16: Verify FHB ventilation aligned at 0PM02J:

0VA04CB - RUNNING

0VA055Y - OPEN

0VA062Y - OPEN

0VA435Y - CLOSED

Att B, Step 17: Maintain UHS Basin Level - >80% <Cont Action Step>

Att B, Step 18: Initiate periodic checking of Spent Fuel Cooling

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

Att B, Step 19: Notify US of actions taken, equipment status, CAS ownership and that Attachment B is completed

Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100 May notify WEC of this step 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 - OPEN.

Comments:

Byron NRC 14-3 Page 18

Scenario NRC 14-3 Event 8&9 No: No.

Event Safety Valve Open with ALL MSIVs Failed Open

==

Description:==

Time Position Applicants Actions or Behavior

Attempt to close ALL MSIVs

Identify ALL MSIV failed to close BOP

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

NO SG pressures stable.

US

Transitions to 1BCA-2.1

Directs actions of 1BCA-2.1

Notify SM of plant status and procedure entry.

Requests evaluation of Emergency Plan conditions.

RO/BOP

Attempts to close MSIVs - NO MSIV will close

Checks SG PORV - ALL CLOSED

Checks FW ISOLATION MONITOR LIGHTS - ALL LIT

Checks SG blowdown isolation and sample valves - ALL CLOSED Crew

Reduces feed flow to 45 GPM for each SG.

CT-33

Check RCS hot leg temperatures - stable or dropping (CT may

If RCS temperatures are rising, crew controls feed flow or dumps steam to stabilize hot leg have temperatures.

been met in 1BEP 1)

EVALUATOR NOTE: The scenario will be terminated when the crew has identified RCS temperatures as stable or dropping, OR, if temperatures are rising, has taken action to control hot leg temperatures.

(Final)

Comments:

Byron NRC 14-3 Page 19

Simulation Facility Byron Scenario No.: Operating Test No.: Byron NRC 2014 N14-4 Examiners: Applicant:

______________________ ____________________ SRO

______________________ ____________________ RO

______________________ ____________________ BOP Initial Conditions: IC-105 Turnover: Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm. On line risk is green.

Event Malf. No. Event Event No. Type* Description Preload FW35C 1C HD pump Trip/fail to start RP15A 1A CV pump auto start failure RP83 OPEN TRGSET 2 1B CV pump trip ZLO1SI01PB(3).eq.1 CV01B (2 0) 1 PB2411 ON TS (US) SG PORV 1MS018B inoperable (Tech Spec)

PB2412 ON ZDI1MS018B CLS 2 RX13A 100 15 I (RO, US) Pressurizer level channel 1LT-459 fails high (Tech Spec)

TS (US) 3 RX03B 4.8 30 I (BOP, US) Steam flow channel 1FI-513A fails high 4 FW35A C (BOP, 1A Heater Drain Pump trip.

US) 5 None R (RO, US) Runback Main Turbine 6 CV03 C (RO, US) Boric acid transfer pump trip.

TS (US) 7 RX05 1500 I (BOP, US) PT-507 fails high 8 TH03A 350 M (ALL) Ruptured 1A SG 9 Preload C (RO, US) 1B CV pump trips/1A CV pump fails to auto start.

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

SCENARIO OVERVIEW Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm. On line risk is green.

After completing shift turnover and relief, steam generator 1B atmospheric relief valve 1MS018B, 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 may dispatch an operator to close 1MS019B to comply with TS 3.6.3, condition C. 1MS018B will remain unavailable for the remainder of the scenario.

After the 1MS018B failure has been addressed, Pressurizer level transmitter 1LT-459A, the controlling channel, fails high. The RO will take manual control of either the master Pzr level controller or 1CV121 to raise charging. The crew will enter 1BOA Inst-2, and there is a high level bistable to be tripped or bypassed. Technical specification 3.3.1 conditions A and K will be entered.

After the pressurizer level channel failure has been addressed, the controlling steam flow channel on the 1A SG fails high. The BOP will take manual control of feedwater flow. 1BOA INST 2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment H, will be implemented. The BOP will restore feedwater flow control to automatic when SG level is restored to normal.

After the feedwater flow channel failure has been addressed, 1A Heater Drain Pump will trip. 1BOA SEC-1, SECONDARY PUMP TRIP, Attachment C, will be entered. The BOP will attempt a start of the 1C HDP but it will not start. The BOP will then initiate a turbine load reduction to 780 MW at 20 MW/minute. The RO will borate the RCS as necessary to stabilize RCS temperature.

While borating in response to the 1A Heater Drain Pump trip, the Unit 1 Boric Acid pump motor bearing will seize while the pump is running. MCC 133X3, cubicle A4 will open, causing a trip of the Unit 1 Boric Acid Transfer Pump.

The crew will align the Unit 0 Boric Acid Transfer Pump to Unit 1 per BOP AB-17, UNIT 0 BORIC ACID TRANSFER PUMP OPERATIONS step F.1.

After the Boric Acid Transfer Pump alignment is complete, 1PT507 will Fail High. This will require the BOP to take manual control of TDFW pump speed. Actions will be directed by BAR 1-15-A-D9 (SG Level deviation Hi/Lo)

After the PT-507 failure and Boric Acid Pump trip have been addressed, the 1A SG will develop a 350 gpm SGTR.

The crew will implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION. When safety injection is actuated, the 1B CV pump will trip. The 1A CV pump must be manually started to establish high head ECCS flow.

After determining 1A SG has a tube rupture the crew will transition to 1BEP-3, STEAM GENERATOR TUBE RUPTURE.

The scenario is complete when the crew isolates high head injection at step 21 of 1BEP-3.

Critical Tasks

1. CT-6: Establish flow from at least one Charging/SI pump.

2. CT-18: Isolate ruptured SG.

3. CT-19: Control initial RCS cooldown.

4. CT-20: Depressurize RCS to E-3 SI termination criteria.

References:

1BOA Inst-2 1BOA SEC-1 BOP AB-17 BAR 1-15-A-D9 1BEP-0 1BEP-3 NRC 14-4 Page 2 of 19

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC-105 (password nrc14), 89% power.

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).

Start 1B CV Pump and shutdown 1A CV Pump.

Verify Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N14-4 from thumb drive and verify the following actions load in the CAEP:

Byron 2014 ILT NRC scenario 14-4l00:00:00l1 EVENT 1: 1MS018B inoperablel00:00:01l2 IMF PB2411 ONl10:00:02l3 IMF PB2412 ONl10:00:03l4 IOR ZDI1MS018B CLSl10:00:04l5 EVENT 2: 1LT-459 fails highl00:00:05l7 IMF RX13A 100 15l10:00:06l8 EVENT 3: 1FI-513A fails highl00:00:07l10 IMF RX03B 4.8 30l10:00:08l11 EVENT 4 & 5: 1A Heater Drain Pump trip.l00:00:09l13 IMF FW35Al10:00:10l14 EVENT 6: Boric acid transfer pump trip.l00:00:11l16 IMF CV03l10:00:12l17 To swap BATPl00:00:12l18 ior zlo0ab03p onl10:00:12l19 dmf cv03l10:00:12l20 EVENT 7: PT-507 fails highl00:00:13l22 IMF RX05 1500l10:00:14l23 EVENT 8: Ruptured 1A SGl00:00:15l25 IMF TH03A 350l10:00:16l26 Preloadl00:00:17l31 1C HD pump Trip/fail to startl00:00:18l32 IMF FW35Cl00:00:19l33 1A CV pump auto start failurel00:00:20l34 IMF RP15Al00:00:21l35 MRF RP83 OPENl00:00:22l36 1B CV pump tripl00:00:23l37 TRGSET 2 "ZLO1SI01PB(3).eq.1"l00:00:24l38 IMF CV01B (2 0)l00:00:25l39 NRC 14-4 Page 3 of 19

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: SG PORV 1MS018B inoperable (Tech Spec)

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

IMF PB2411 ON

IMF PB2412 ON

IOR ZDI1MS018B 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 1MS018B has a cracked hydraulic line, it is still dripping into a small puddle of hydraulic fluid that is present beneath the valve.

As WEC supervisor. acknowledge request for EST for 1MS018B C/S, if EST is requested.

If dispatched as EO to close 1MS019B, perform the following:

MRF MS52 0 Event 2: Pressurizer level channel 1LT-459 fails high.

Insert IMF RX13A 100 15 to fail 1LT-459 high over a 15 second period.

AS WEC supervisor, acknowledge request to trip or bypass bistable. Inform the US the operators are being briefed.

As SM acknowledge the failure, LCOs 3.3.1, conditions A and K entry, on line risk assessment, request for maintenance support, and IR requests.

Event 3: Steam flow channel 1FT-513A fails high Insert IMF RX03B 4.8 30 to fail 1FT-513A high over a 30 second period.

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

Event 4 & 5: 1A Heater Drain Pump trip and load reduction Insert IMF FW35A to trip the 1A Heater Drain Pump.

Acknowledge as SM the 1A HD 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 1A Heater Drain pump is seized and report ground overcurrent flag at breaker cubicle. Report that 1C HD pump appears normal, no obvious problem.

Acknowledge as Power Team load reduction and estimated duration of derate.

NRC 14-4 Page 4 of 19

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 6: Boric acid transfer pump trip Note: Ensure a boration is in progress prior to inserting the next malfunction.

Insert IMF CV03 to trip the Unit 1 boric acid pump.

If dispatched as EO, report Unit 1 AB pump breaker 133X3 is tripped and does not appear to be damaged. If breaker re-closure is requested, report breaker is closed. DO NOT DELETE MALFUNCTION. If pump restart is attempted, report the breaker is open.

If dispatched as EO, report the Unit 1 AB pump bearing is hot and appears to be damaged.

If contacted as Unit 2, report Unit 0 AB pump is NOT supplying Unit 2 demands and is NOT electrically aligned to Unit 2.

If dispatched as EO, align the Unit 0 AB pump to Unit 1 demands per BOP AB-17 as follows:

Verify w/MCR AB pump 1 + 0 c/s is in PTL (BOP AB-17, step F.1.a)

Verify w/MCR U-1 makeup c/s is in STOP (BOP AB-17, step F.1.b)

Insert IOR ZLO0AB03P ON

Wait approximately two minutes then perform the following:

Delete malfunction DMF CV03

Report Unit 0 AB pump aligned for Unit 1 demands (BOP AB-17 is complete up to step F.1.j)

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

If the crew asks about desired state of U-1 Boric Acid state as SM that U-0 boric acid pump needs to be aligned in place of the failed U-1 Boric Acid pump. In addition, the SM does NOT want to use the RWST as a boric acid source. The SM desires the Unit to remain on-line.

Event 7: 1PT507 fails High Insert IMF RX05 1500 to fail 1PT507 to 1500 psig.

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

Event 8: Ruptured 1B SG Insert IMF TH03B 350 to cause a rupture in the 1B SG steam generator.

Acknowledge as SM procedure changes, E Plan evaluations, and STA request.

After STA requested, as STA report CSF status:

Event 9: 1B CV pump trips/1A CV pump fails to auto start (preload)

If dispatched as EO to investigate 1B CV pump, report ground overcurrent flag at breaker cubicle.

NRC 14-4 Page 5 of 19

Scenario NRC 14-4 Event 1 No: No.

Event

Description:

SG PORV 1MS018B inoperable Time Position Applicants Actions or Behavior CUE

Annunciator S/G 1B PORV TROUBLE (1-15-B10).

SER 2411, 1B PORV HYDRAULIC FLUID RESERVOIR LOW.

SER 2412, S/G PORV 1B ACCUMULATOR PRESSURE LOW.

BOP

Identify/report trouble alarm on 1MS018B.

Refer to BAR 1-15-B10.

Dispatch operator to 1MS018B.

Place 1MS018B C/S in close at 1PM04J to stop hydraulic pump.

Request Equipment Status Tag for 1MS018B.

RO

Assist BOP as requested. Refer to BARs as available.

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 1MS019B in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verify closed once per 31 days

Direct operator to close 1MS019B within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

US

Inform SM of 1MS018B status, TS Status, request IR, On Line Risk Assessment, maintenance support, and clearance order/EST for 1MS019B.

EVALUATOR NOTE: After the actions for the 1MS018B failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-4 Page 6 of 19

Scenario NRC 14-4 Event 2 No: No.

Event

Description:

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

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

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

1LI-459A indicates 100% level

Charging flow lowering o Refer to BARs.

CREW

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

US

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

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

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

Perform the following at 1PM05J:

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

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

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

Select an operable Pzr level channel for control.

Select an operable Pzr level channel to the recorder.

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

US

Notify WEC to perform pre-job brief per HU-AA-1211 for bistable tripping or bypassing.

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

US

Determine TS 3.3.1 conditions A and K are applicable.

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

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

BOP

Monitor secondary systems

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

Comments:

NRC 14-4 Page 7 of 19

Scenario NRC 14-4 Event 3 No: No.

Event Steam flow channel 1FI-513A fails High

==

Description:==

Time Position Applicants Actions or Behavior CUE o Annunciator 1A SG FLOW MISMATCH FW FLOW LOW(1-15-A4) o Annunciator 1A SG FLOW MISMATCH STM FLOW LOW(1-15-A3) o Annunciator 1A SG LEVEL DEVIATION HI/LOW(1-15-A9) o Steam flow indicator 1FI-513A rising o FWRV 1FW-510 opening o SG level indicators 1LI-517, 518, 519, 556 rising BOP

Identify 1FT-513A failed high

Report failure to US

Perform the following at 1PM04J

Place 1FW-510 in MANUAL

Lower FW flow to match or slightly lower than steam flow

Monitor 1A SG level and control 1FW-510 in MANUAL

Place Master FW pump speed controller in MANUAL

Verify adequate feedwater delta-P 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 flow channel F-512

Check 1A SG level - normal on 1LI-517, 518, 519, 556

Place 1FW-510 in AUTOMATIC

Place Master FW pump speed controller in AUTOMATIC

Verify steam pressure channels normal EVALUATOR NOTE: Ensure auto control is reestablished prior to inserting the next event.

After the actions for the steam flow channel failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-4 Page 8 of 19

Scenario NRC 14-4 Event 4&5 No: No.

Event 1A Heater Drain Pump trip

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator HD PUMP TRIP (1-17-D2).

HD Tank level rising.

HD Pump discharge valves opening.

BOP

Recognizes 1A HD pump tripped.

o Refer to BAR 1-17-D2.

Reports failure to US.

Recognizes one Heater Drain Pump running.

CREW

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

US

Acknowledge 1A HD pump trip.

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

Implement 1BOA SEC-1, SECONDARY PUMP TRIP Attachment C "HD PUMP TRIP" and direct operator actions of 1BOA SEC-1 to establish the following conditions.

BOP

Recognizes standby HD pump NOT AVAILABLE.

Check HD pump status at 1PM03J.

ONLY 1B HD pump running.

Initiate HD runback on OWS graphic 5512 at 1PM02J.

Verify turbine load lowering.

BOP

Check HD Tank level at 1PM03J:

Level > 72% and rising.

Maintain HD tank level.

o Verify 1HD046A &B in AUTO.

o Open 1CB113A-D.

o Manually open 1HD117, HD tank overflow valve.

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

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

o Lower turbine load as necessary to close 1HD117.

Check 1B HD pump parameters at 1PM03J.

1B HD pump amps < 168 amps.

1B HD pump flow < 2950 KLB/HR.

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

Deactivate turbine runback:

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

US/RO

Check PDMS operable.

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

1BOL 3.h not implemented.

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

Comments:

NRC 14-4 Page 9 of 19

Scenario NRC 14-4 Event 4&5 No: No.

Event 1A Heater Drain Pump trip

==

Description:==

Time Position Applicants Actions or Behavior RO

Control I near target.

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

Monitor RCS parameters.

o If RCS pressure lowers < 2209 psig, notify US.

o If control rods < low - 2 rod insertion limit, notify US.

US o Enter TS 3.4.1, RCS DNB Limits, Condition A- Restore RCS Pressure to within limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

o Enter TS 3.1.6, Control Bank Insertion Limits Condition A and (1)- verify SDM is within limit in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR (2) initiate boration to restore SDM to w/i limit in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND (3) restore control banks to w/i limits in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

RO NOTE TO EVALUATOR: The boric acid pump will trip during this event-see event 6 for specifics.

Initiate RCS boration at 1PM05J:

Determine required boric acid volume (approximate band: 50 gal - 200 gal).

o Determine from Rema.

Determine desired boric acid flow rate.

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

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

Place MAKE-UP MODE CONT SWITCH to STOP position.

Place MODE SELECT SWITCH to BORATE position.

Place MAKE-UP MODE CONT SWITCH to START.

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

o Turn on PZR backup heaters.

BOP

Verify running CB pump recirc valves in auto.

1CB113A-D on running pumps.

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

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

US

Notify chemistry to monitor secondary plant chemistry.

Notify SM to perform risk assessment.

Check reactor power change > 15% in one hour.

o Notify chemistry to perform TS 3.4.16 sampling.

o Notify rad protection to perform TS sampling.

Contact Power Team and inform Power Team of load reduction and estimated duration of power derate.

The next event is to be inserted with lead examiners concurrence while a boration is in progress in response to the heater drain pump trip.

Comments:

NRC 14-4 Page 10 of 19

Scenario NRC 14-4 Event 6 No: No.

Event

Description:

Boric acid transfer pump trip Time Position Applicants Actions or Behavior EVALUATOR NOTE: If the crew would like to borate via the RWST, the Shift Manager will inform the crew to place the U-0 Boric Acid pump in service on Unit 1.

CUE

Annunciator BA FLOW DEVIATION (1-9-A6)

Trip/yellow disagreement light on Boric Acid Transfer pump 1 + 0 C/S (if pump control switch is taken to start)

RO

Identify/report trip of Unit 1 Boric Acid Transfer pump

Refer to BAR 1-9-A6 and/or 1-9-A4

Dispatch operator to Unit 1 Boric Acid Transfer pump and breaker US

Notify SM of Unit 1 Boric Acid Transfer pump trip.

Direct operators to align the Unit 0 Boric Acid Transfer pump for Unit 1 demand o Direct BOP to control load ramp RO

Determine Unit 1 Boric Acid Transfer pump bearing is damaged

Report from EO

Align 0AB03P, Boric Acid Transfer pump 0 for Unit 1 demands per BOP AB-17 Verify 0AB03P NOT supplying Unit 2 boric acid demands Verify 0AB03P NOT connected to Unit 2 power supply

MAKE-UP MODE CONT SWITCH to STOP at 1PM05J.

Place Boric Acid Transfer pump 1 + 0 C/S in PULL OUT at 1PM05J.

Dispatch operator to align 0AB03P to Unit 1 per BOP AB-17

Verify 1CV110A in AUTO at 1PM05J.

Place Boric Acid Transfer pump 1 + 0 C/S in AFTER TRIP at 1PM05J.

Return Unit 1 RMCS to AUTO at 1PM05J.

EVALUATOR NOTE: After the actions for the boric acid pump trip are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-4 Page 11 of 19

Scenario NRC 14-4 Event 7 No: No.

Event

Description:

1PT507 Fails High Time Position Applicants Actions or Behavior EVALUATOR NOTE: With 1PT-507 failed high, and if the steam dumps were placed in the steam pressure mode before taking the controller to manual and lowering the output to 0, ALL steam dump valves (12) will fail open until the P-12 interlock at Tave at 550 degrees RCS temperature will send a signal to close all steam dump valves.

CUE

Annunciators S/G 1_ LEVEL DEVIATION HIGH LOW (1-15-A/B/C/D 9)

1PK507 MS HDR PRESSURE CONTROLLER METER @ 100%

1PI-507 SG HDR PRESS - 1500 psig

1PI-508 FW HTR DISCH. PRESSURE RISING

1PI-509 MS/FW HDR D/P LOWERING TO 0

1PI-MS021 STM HDR PRESS - 1500 psig BOP

Identify/report Failure of 1PT-507

Refer to BAR 1-15-A/B/C/D 9

Inform US of instrument failure Take manual control of FW pp turbine speed control US

Notify SM of instrument failure.

Direct BOP To take manual control of FW pp speed control Direct BOP to stop load ramp Discuss effects of failure on Steam Dump Control System EVALUATOR NOTE: After the actions for PT-507 failure are complete and with lead examiners concurrence, insert the next event.

Comments:

NRC 14-4 Page 12 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior CUE

PZR LEVEL CONT DEV LOW (1-12-B4).

PZR PRESS LOW (1-12-B1)

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

CHG LINE FLOW HIGH LOW (1-9-D3)

PZR Level and Pressure dropping.

1A SG level rising or 1FW510 open less than other 3 FWRVs Possible RM-11 Rad Monitor ALERT/HI RAD Alarms.

1AR 22/23A 1A Main Steam line.

1PR27J SJAE RO

Reports lowering PZR level and pressure Recommends Reactor trip and Safety Injection US

Directs

Manual reactor trip

Initiate a manual SI.

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 at 1PM05J:

Verify reactor trip.

Rod bottom lights - ALL LIT.

Reactor trip & Bypass breakers - OPEN.

Neutron flux - DROPPING.

BOP Perform immediate operator actions of 1BEP-0 at 1PM02J or OWS drop 210:

Verify Turbine Trip.

All Turbine throttle valves - CLOSED.

All Turbine governor valves - CLOSED.

BOP Perform immediate operator actions of 1BEP-0 at 1PM01J:

Verify power to 4KV busses.

ESF Buses - BOTH ENERGIZED (141 & 142).

CREW (If manual SI not previously performed) Recognize and respond to conditions requiring a Safety Injection in accordance with 1BEP-0 REACTOR TRIP OR SAFETY INJECTION, Step 4:

PZR pressure cannot be maintained > 1829 psig.

Manually actuate SI.

CREW

Check SI Status at 1PM05J/1PM06J:

o SI ACTUATED Permissive Light - LIT.

o SI Equipment - AUTOMATICALLY ACTUATED.

o Either SI pumps - RUNNING.

o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B.

US

Step 5: Direct BOP to perform Attachment B of 1BEP-0 Comments:

NRC 14-4 Page 13 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B.

RO

Step 6: Verify AF system:

AF pumps - BOTH AF pumps RUNNING.

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

AF flow - >500 GPM

Check SG tubes intact - 1A SG radiation RISING and 1A SG level RISING in an uncontrolled manner

Verify/Close AF isol valves

1AF013A

1AF013E

1AF005A

1AF005E RO

Step 7: 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 8: Maintain RCS temperature control at 1PM05J: <Cont Action Step>

o

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

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

MSIVs closed RO

Step 9: Check status of RCPs at 1PM05J:

Determine RCP trip NOT required

RCS pressure > 1425 psig RO/

Step 10: Check if SG secondary pressure boundaries are intact at 1PM04J:

SRO

Check pressure in all SGs:

NO SG pressure decreasing in an uncontrolled manner.

NO SG completely depressurized.

RO/

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

SRO o 1PR08J SG Blowdown o 1PR27J SJAE/GS - IN ALERT/ALARM

1AR22/23A Main steam Lines - Trending up or in ALERT/ALARM

Transition to 1BEP-3, Steam Generator Tube Rupture (1BEP-3 follows the Attachment B steps that are listed below)

EVALUATOR NOTE: BOP is performing Attachment B:

Comments:

NRC 14-4 Page 14 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior BOP

Att B, Step 1: Verify ECCS pumps running

CV pumps - NONE RUNNING.

CT-6

Manually start the 1A CV pump prior to exiting 1BEP-0.

Both RH pumps - RUNNING

Both SI pumps - RUNNING

Att B, Step 2: Verify ECCS valve alignment

Determine Group 2 Cold Leg Injection monitor lights required for injection - All lit (except 1B CV pump is NOT running)

Att B, Step 3: Verify ECCS flow

High Head SI flow >100 gpm (1FI-917) o RCS pressure > 1700 psig OR o RCS pressure < 1700 psig

1B SI pump discharge flow > 200 gpm o RCS pressure > 325 psig

Att B, Step 4: Verify RCFCs running in Accident Mode:

Group 2 RCFC Accident Mode lights - 4 LIT.

Att B, Step 5: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - ALL LIT.

Att B, Step 6: Verify Cnmt Vent isolation:

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

Att B, Step 7: Verify CC pumps - BOTH RUNNING.

Att B, Step 8: Verify SX pumps - BOTH RUNNING.

Att B, Step 9: Check if Main Steamline Isolation - REQUIRED:

o SG pressures > 640 psig - continue on in 1BEP-0

Att B, Step 10: Check if CS is required <Cont Action Step>

CNMT pressure has NOT risen > 20 psig.

Att B, Step 11: Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

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

Trip all running HD pumps.

Att B, Step 12: Verify DGs running at 1PM01J:

DGs - BOTH DG running

1SX169A/B OPEN.

Dispatch operator locally to check operation Comments:

NRC 14-4 Page 15 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior

Att B, Step 13: Verify Generator Trip at 1PM01J:

OCB 1-8 and 7-8 open.

PMG output breaker open.

Att B, Step 14: Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0B Supply fan

0B Return fan

0B M/U fan

0B Chilled water pump

0B Chiller

Operating VC train dampers - ALIGNED.

M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.

0B VC train M/U filter light - LIT.

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED

0VC05Y - OPEN

0VC06Y - OPEN

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

Att B, Step 15: Verify Auxiliary Building ventilation aligned at 0PM02J:

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CB - RUNNING

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

Att B, Step 16: Verify FHB ventilation aligned at 0PM02J:

0VA04CB - RUNNING

0VA055Y - OPEN

0VA062Y - OPEN

0VA435Y - CLOSED Comments:

NRC 14-4 Page 16 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior

Att B, Step 17: Maintain UHS Basin Level - >80% <Cont Action Step>

Att B, Step 18: Initiate periodic checking of Spent Fuel Cooling

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

Att B, Step 19: Notify US of actions taken, equipment status, CAS ownership and that Attachment B is completed

Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100 May notify WEC of this step CREW

Transition to 1BEP-3, STEAM GENERATOR TUBE RUPTURE US Implement 1BEP-3 "STEAM GENERATOR TUBE RUPTURE and direct operator actions.

Notifies SM of BEP entry and calls for STA

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

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

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

Reset CNMT isol Phase A

Notify Chem to locally sample

Open SG blowdown sample valves at Chem request RO/ Isolate flow from 1A SG by verifying BOP

SG PORV 1MS018A in AUTO CT-18

Check SG PORV 1MS018A closed

Verify closed when SG pressure < 1115 psig

Verify SG blowdown valves closed unless open for sampling

1SD002A

1SD002B

Close MSIV and MSIV bypass valves for 1A SG

Check PORVs on intact SGs available for RCS cooldown (C and D will be available)

BOP Check ruptured SG level CT-18

Narrow Range >10%

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

1AF013A & E

1AF005A & E Comments:

NRC 14-4 Page 17 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior BOP Check ruptured SG pressure

Ruptured SG pressure greater than 320 psig CREW

Determine required CETC from table (step 6a)

RO/

Check Pzr Pressure - >1930 #

BOP

When < 1930#, block Steamline Isol SI BOP

Dump steam to condenser from intact SG at maximum rate CT-19 NOTE: Steam dump control NOT available in AUTOMATIC

Check steam dumps available

Place MS controller in Manual, reduce demand to 0

Select Steam Pressure Mode

Adjust MS controller to initiate cooldown

Bypass P-12 interlock when RCS <550°F NOTE: It is acceptable to hold Bypass Switches to BYPASS as RCS temperature goes below 550°F.

o If MSIVs close due to rate of dumping steam or if crew decides not to USE steam dumps:

Dump steam using 1MS018C and 1MS018D Crew Dispatch operators to standby

1SI8801A/B

MCC 131X1 (F4) and 132X5 (A4)

Crew

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

Stop RCS cooldown

Maintain CETC temps. < required temp.

BOP

Check intact SG levels > 10%

Control FF to maintain NR levels 30 - 50%

RO

Check Pzr PORVs and isolation valves

PORV isolation valves energized

PORVs closed

PORV isolation valves both open RO/

Reset SI BOP

Verify SI actuated permissive light NOT LIT

Verify Auto SI blocked light LIT RO/

Reset Phase A isolation BOP BOP

Establish IA to containment

Check SACs- any running

Open 1IA065 and 1IA066 CREW

Check if RH pumps should be stopped

Any RH pump running and aligned to RWST

RCS pressure >325#

Stop both RH pumps CREW

Check if RCS Cooldown should be stopped

Ave of 10 highest CETC < required temperature in Step 6

When met, stop cooldown and maintain temperature < required temperature Comments:

NRC 14-4 Page 18 of 19

Scenario NRC 14-4 Event 8&9 No: No.

Event 1A SG Rupture, 1B CV pump trips/1A CV pump fails to auto start.

==

Description:==

Time Position Applicants Actions or Behavior CREW

Check ruptured SG pressure - stable or rising CREW

Check RCS subcooling - acceptable by using CETC, RCS WR Press. and Fig. 1BEP 3-2 RO

Depressurize RCS using PZR spray valves until CT-20 o RCS Pressure < Ruptured SG pressure and Pzr level > 12%

o Pzr level > 69%

o RCS subcooling NOT acceptable CREW

Check if ECCS flow should be terminated

RCS subcooling - Acceptable

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

RCS pressure - rising

Pzr level > 12%

RO/

Stop both SI pumps BOP

Reset SI Recirc Sump Isolation Valves

Reset CV pp mini-flow valves

Verify open:

1CV8110, 8111, 8114 and 8116

Close 1SI8801A and B EVALUATOR NOTE: When the CREW isolates High Head Injection the scenario should be terminated.

Comments:

NRC 14-4 Page 19 of 19

Simulation Facility Byron Scenario No.: Operating Test No. Byron NRC 2014 N14-5 Examiners: Applicant: SRO

_ ___________________ ____________________

RO

____________________ ____________________

BOP

____________________ ____________________

Initial Conditions: IC-22 Turnover: Unit 1 is at 100% power, steady state, equilibrium xenon; MOL. 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 No. Malf. No. Event Event Type* Description RP26C ESF relay failure of 1A RH pump Preload RP28C ESF relay failure of 1B RH pump 1 None R (RO) Ramp down for TV/GV surveillance (SRO)

N (BOP, SRO) 2 FW16 0 I (BOP, 1PT508 fails low SRO) 3 CV10 0 60 134 C (RO, 1CV121 slowly fails closed. Manual control is available.

SRO) 4 RX10A 0 30 I (BOP, 1PT 505 fails low SRO)

TS (SRO) 5 ED11D TS (SRO) Loss of IB 114 due to a bus fault. Tech Spec 3.8.9 required shutdown within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 6 TH04C 50 120 C (RO, 50 GPM primary leak SRO) 7 TH04C 540000 M (all) LB LOCA terminating in transfer to Cold Leg Recic 8 Pre-load C (all) ESF relay failure of 1A & B RH pumps - manual start 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.

After completing shift turnover and relief, the crew will ramp the unit to 89% power at 3MW/min After the ramp has begun, 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 closed in automatic. Charging and seal injection flow will lower. 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 1BOA 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 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . 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, a 50 GPM RCS leak develops inside CNMT. .

The crew will enter 1BOA PRI-1, Excessive Primary Plant Leakage, and the RO will raise charging and isolate letdown to stabilize Pzr level.

When the RO has successfully taken action to raise Pzr level, 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.

Critical Tasks

1. CT-5: Manually start at least one low-head ECCS pump.

2. CT-36: Transfer to cold leg recirculation.

References 1BOA INST-2 1BOA ELEC-2 1BEP-0 1BEP-1 1BEP ES-1.3 Page 2

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.

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 Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N14-5 from thumb drive and verify the following actions load in the CAEP:

Byron 2014 ILT NRC scenario 14-4l00:00:00l1 EVENT 2: 1PT508 fails lowl00:00:01l2 IMF FW16 0l10:00:02l3 EVENT 3: 1CV121 fails closedl00:00:03l5 IMF CV10 0 60 134l10:00:04l6 EVENT 4: 1PT505 fails lowl00:00:05l8 IMF RX10A 0 30l10:00:06l9 EVENT 5: AC IB 114 failurel00:00:07l11 IMF ED11Dl10:00:08l12 EVENT 6: RCS leakl00:00:09l14 IMF TH04C 50 120l10:00:00l15 EVENT 7: LB LOCAl00:00:10l17 IMF TH04C 540000l10:00:00l18 RH pump relay failuresl00:00:11l20 IMF RP26Cl00:00:12l21 IMF RP28Cl00:00:13l22 Page 3

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

Power Systems acknowledge start of ramp when notified.

Event 2: Feedwater header pressure 1PT508 fails low.

As SM, acknowledge the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.

As the WEC supervisor, acknowledge crew request to bypass or trip bistables. Report operators are being briefed.

Event 3: 1CV121, fails open in closed. 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.

As SM, acknowledge the failure, request for maintenance support, and IR request.

SDG: CV5 IMF CV10 0 60 134 If the crew decides to isolate and bypass 1CV121 refer to:

SDG: CV5 Throttle Open 1CV8387A and Close 1CV8483A Event 4: 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.

As SM, acknowledge the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.

As the WEC supervisor, acknowledge crew request to bypass or trip bistables. Report operators are being briefed.

Event 5: Event 5 Loss of Instrument Bus 114 Initiate event after event 4 actions are completed, with the lead examiners concurrence.

As SM, acknowledge the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request. If crew requests permission to take the unit offline, direct them to make preparations to ramp offline.

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)

Page 4

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 6: Primary leak inside CNMT IMF TH04C 50 120 SM acknowledges procedure entry and E Plan evaluations.

Event 7: Large Break LOCA with failure of ESF start relays on both RH pumps, requiring manual start, which functions IMF TH04C 540000 SM acknowledges 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.

When requested to de-energize 1CV112D and 1CV112E in 1BEP ES-1.3 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 8: ESF failure of RH pumps 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 5

Scenario NRC 14-5 Event 1 No: No.

Event

Description:

Ramp unit to 89% power 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 140 total gallons of boron to add in about 20 to 40 gallon batches and about 29 rod steps.

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 14-5 Page 6

Scenario NRC 14-5 Event 2 No: No.

Event

Description:

1PT508 fails LOW Time Position Applicants Actions or Behavior CUE

Annunciator SG 1_ FLOW MISMATCH FW FLOW LOW (1-15-A4/B4/C4/D4)

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 EVALUATOR NOTE: After the actions for PT-508 are complete, insert next event.

Comments:

Byron NRC 14-5 Page 7

Scenario NRC 14-5 Event 3 No: No.

Event

Description:

1CV121 fails closed in auto.

Time Position Applicants Actions or Behavior CUES:

Annunciator 1-9-D3 CHG LINE FLOW HIGH LOW

1FI-121A Charging Header Flow lowering o 1LI-112 VCT level rising RO/ o May isolate letdown BOP o If letdown is isolated, restore letdown using BOP CV-17 RO

Place 1FK-121 in MANUAL

Raise charging flow

Balance charging flow with letdown to restore and stabilize Pzr level

Identify/report failure of 1CV-121 EVALUATOR NOTE: When charging flow is stabilized, insert the next event.

Comments:

Byron NRC 14-5 Page 8

Scenario NRC 14-5 Event 4 No: No.

Event

Description:

1PT505 fails low 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 o 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/BOP

Perform the following at 1PM05J:

o Determine control rods inserting.

Identify 1PT-505 is failing low.

Report failure to US

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

o 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/BOP

Restore steam dumps.

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%.

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.

Comments:

Byron NRC 14-5 Page 9

Scenario NRC 14-5 Event 4 No: No.

Event

Description:

1PT505 fails low Time Position Applicants Actions or Behavior

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 US Direct WEC to get operators to trip or bypass bistables US

Determine TS 3.3.1 conditions A and P are applicable:

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

Comments:

Byron NRC 14-5 Page 10

Scenario NRC 14-5 Event 5 No: No.

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior 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 CREW Identify/report failure of Instrument Bus 114.

US Enter 1BOA ELEC-2, Loss of Instrument Bus 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 14-5 Page 11

Scenario NRC 14-5 Event 5 No: No.

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior 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

Verify CLOSED Instr. Bus 114 CVT Feed bkr

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 3.8.7, Condition A for loss of inverter.

Refer to Tech Specs 3.8.9 Condition B

Condition B: Restore I.B. in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months (if not restored go to Cond. D) o Condition D: If Condition B not met, be in Mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 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 14-5 Page 12

Scenario NRC 14-5 Event 5 No: No.

Event

Description:

Loss of Instrument Bus 114 Time Position Applicants Actions or Behavior 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 CREW Because of damage to bus and short timeframe, crew may contact the SM for guidance or request concurrence to ramp the unit offline.

EVALUATOR NOTE: When actions have been completed to respond to loss of Inst Bus 114 enter the next event.

Comments:

Byron NRC 14-5 Page 13

Scenario NRC 14-5 Event 6 No: No.

Event

Description:

Primary leak inside CNMT Time Position Applicants Actions or Behavior CUE

Annunciator 1-1-A2, CNMT DRAIN LEAK DETECT FLOW HIGH alarm is LIT

Rising radiation levels on area monitors inside CNMT

Lowering Pzr level (Charging flow will not rise because 1CV121 is in MANUAL)

RO

Determine Pzr level is lowering

Throttle open 1CV121 to raise charging flow

Isolate letdown US Enter 1BOA PRI-1, Excessive Primary Plant Leakage Direct RO to raise charging flow Direct RO to isolate LD US

Notify SM of procedure entry and request E Plan evaluation CREW

Check Pzr level stable or rising EVALUATOR NOTE: When the RO has isolated LD and Pzr level is stable or rising, insert next event.

Comments:

Byron NRC 14-5 Page 14

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start 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 RO o Trip RCPs based on OAS for Phase B isolation or Pressure <1425 PSIG. Can be done after immediate actions are completed.

Step 6: Verify AF system:

AF pumps - 1A AF pump RUNNING.

Start 1B AF pump

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

AF flow - >500 GPM

Check SG tubes - INTACT and SG NR levels - NOT RISING UNCONTROLLED EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B, SI Verification.

1BEP-0 steps continue after the Att B steps listed next.

Comments:

Byron NRC 14-5 Page 15

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior RO/

Att B, Step 1: Verify ECCS pumps running BOP

Both CV pumps - 1B NOT RUNNING

Manually start 1B CV pump due to loss of I.B. 114

Both RH pumps - BOTH NOT RUNNING CT-5

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

Both SI pumps - 1B NOT RUNNING

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

Att B, Step 2: Verify ECCS valve alignment

Determine Group 2 Cold Leg Injection monitor lights required for injection - NOT All lit

Manually aligns valves as necessary BOP

Att B, Step 3: Verify ECCS flow

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

RCS pressure < 1700 psig

1B SI pump discharge flow > 200 gpm

RCS pressure > 325 psig BOP

Perform the following at 1PM06J:

Att B, Step 4: 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

Att B, Step 5: 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

Att B, Step 6: Verify Cnmt Vent isolation:

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

o Verify MSIV and Bypass Valves - CLOSED

Att B, Step 7: Verify CC pumps - BOTH RUNNING.

Start 1B CC pump

Att B, Step 8: Verify SX pumps - BOTH RUNNING.

Start 1B SX pump

Att B, Step 9: Check if Main Steamline Isolation -required:

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

CNMT pressure > 8.2 psig.

MSIVs and bypass valves - CLOSED Comments:

Byron NRC 14-5 Page 16

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior CREW Recognize and announce ADVERSE CNMT BOP

Att B, Step 10: Check if CS is required <Cont Action Step>

CNMT pressure has risen > 20 psig.

Group 6 CS monitor lights - ALL LIT.

Group 6 phase B 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

Verify/Stop ALL RCPs (at 1PM04J).

CS eductor suction flow - > 15 gpm on 1FI-CS013 & 1FI-CS014.

CS eductor additive flow - > 5 gpm on 1FI-CS015 & 1FI-CS016.

Align SX Cooling Towers

All 8 riser valves - OPEN

OPENS 0SX163C and D

All 4 Bypass valves CLOSED

8 fans running in HIGH speed

Starts 0C, 0D & 0G Fans in Hi-speed BOP

Att B, Step 11: Verify FW isolated at 1PM04J:

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

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

Trip all running HD pumps.

Att B, Step 12: Verify DGs running at 1PM01J:

BOP

DGs - 1A DG running

Start 1B DG

1SX169A/B OPEN.

Dispatch operator locally to check operation

Att B, Step 13: Verify Generator Trip at 1PM01J:

OCB 1-8 and 7-8 open.

PMG output breaker open.

BOP

Att B, Step 14: Verify Control Room ventilation aligned for emergency operations at 0PM02J:

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0A Supply fan

0A Return fan

0A M/U fan

0A Chilled water pump

0A Chiller

Operating VC train dampers - ALIGNED.

Comments:

Byron NRC 14-5 Page 17

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior

M/U fan outlet damper - 0VC24Y NOT FULLY CLOSED.

0A VC train M/U filter light - LIT.

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train A.

0VC43Y - CLOSED

0VC21Y - OPEN

0VC22Y - OPEN

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

BOP

Att B, Step 15: Verify Auxiliary Building ventilation aligned at 0PM02J:

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CA - RUNNING

0VA022Y - OPEN

0VA020Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

Att B, Step 16: Verify FHB ventilation aligned at 0PM02J:

0VA04CA - RUNNING

0VA060Y - OPEN

0VA057Y - OPEN

0VA051Y - CLOSED BOP

Att B, Step 17: Maintain UHS Basin Level - >80% <Cont Action Step>

Att B, Step 18: Initiate periodic checking of Spent Fuel Cooling

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

Att B, Step 19: Notify US of actions taken, equipment status, CAS ownership and that Attachment B is completed o Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100 May notify WEC of this step EVALUATOR NOTE: 1BEP-0 main body continues here.

RO

Step 7: Check PZR PORVs and SPRAY VALVES at 1PM05J:

1RY455 & 1RY456 CLOSED

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

Byron NRC 14-5 Page 18

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior

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

Normal PZR Spray Valves CLOSED RO

Step 8: Maintain RCS temperature control at 1PM05J: <Cont Action Step>

o

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

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

Step 9: Check status of RCPs at 1PM05J:

o All RCPs - NONE RUNNING.

o Any RCPs still running - TRIP All RCPs RO

Step 10: Check if SG secondary pressure boundaries are intact at 1PM04J:

Check pressure in all SGs:

None dropping in an uncontrolled manner.

None completely depressurized.

RO

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

1PR08J SG Blowdown.

1PR27J SJAE/GS.

1AR22/23A-D Main steam Lines.

CREW

Step 12: 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 SRO

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 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 on page 20.

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/ BOP

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

Check pressure in all SGs:

Comments:

Byron NRC 14-5 Page 19

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior

None dropping in an uncontrolled manner

None completely depressurized

Step 3: Check intact SG levels

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

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 italics 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 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 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 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 Comments:

Byron NRC 14-5 Page 20

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior

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

Check both RH pumps - running CT-36

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

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 o Restart 1B CS pp

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 Comments:

Byron NRC 14-5 Page 21

Scenario NRC 14-5 Event 7& 8 No: No.

Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicants Actions or Behavior

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 14-5 Page 22

ML14248A531: Difference between revisions

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