ML14248A531

2014 Byron Nuclear Station Initial License Examination Proposed Simulator Scenarios

ML14248A531
Person / Time
Site:	Byron
Issue date:	06/13/2014
From:	Walton R K NRC/RGN-III/DRS/OLB
To:	Exelon Generation Co
Shared Package
ML14140A562	List: ML14247A248 ML14247A257 ML14247A270 ML14248A490 ML14248A493 ML14248A499 ML14248A505 ML14248A514 ML14248A531 ML14248A542
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Download: ML14248A531 (96)

Text

Simulation Facility Byron Scenario No.:

N 1 4-1 Operating Test No. Byron NRC 2014 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 Type* Event Description Preload RP02A RP02B TC03 ZDIHSTG010 NORM Turbine fails to AUTO trip from Rx trip Manual Turbine trip PB fails to trip turbine 1 None N (BOP,SRO) Switch Bus 156 Electrical Lineup 2 None R (RO, SRO) Raise power to full power 3 None TS (SRO) Notified that 1A SI pump failed ASME surveillance 4 PA0154 ON PA0152 ON zao0iisx032 95 C (BOP,SRO) TS (SRO) SX Fan high vibration requiring fan swap 5 RX18A 630 I (RO, SRO) TS (SRO) 1A TCOLD RTD Fail High 6 RX04D 0 30 I (BOP,SRO) Feedwater flow channel 1FT

-521 fails Low 7 CV16 0 I (RO, SRO)

VCT Level Channel 1 LT-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

2 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 address ed 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 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

3 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

4 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

5 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 ZDIHSTG0 10 NORM Comments:

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

Description:

Switch Bus 156 Electrical Lineup Time Position Applicant's 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 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 7 Scenario No: NRC 14-1 Event No. 2 Event

Description:

Raise power at 0.5 MW/min Time Position Applicant's 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 8 Scenario No: NRC 14-1 Event No. 2 Event

Description:

Raise power at 0.5 MW/min Time Position Applicant's Actions or Behavior RO/BOP Monitor reactor power and load ascension:

Monitor NI's, 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 9 Scenario No: NRC 14-1 Event No. 3 Event

Description:

Unit Supervisor notified of 1A SI pump ASME surveillance failure Time Position Applicant's 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 10 Scenario No: NRC 14-1 Event No. 4 Event

Description:

0B SX MDCT Fan High Vibration requiring a Fan Trip Time Position Applicant's Actions or Behavior CUE Annunciator s SX CLG TWR FAN VIBRATION HIGH (0 E6) and OIL PRESSURE LOW (0 D6) are LIT 0B SX High Speed Fan Amps indicate High in Red Band BOP Refer to BAR 0 D6 and E6 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 EVALUATOR'S 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.

US o Direct BOP to start an alternate SX Fan 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 BOP o Start 0C or 0D SX fan in High Speed o Close 0SX163B, 0B SX Fan Riser Valve if another riser is opened.

RO Monitor primary and secondary panels 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 11 Scenario No: NRC 14-1 Event No. 5 Event

Description:

1A Tcold RTD Failed High Time Position Applicant's Actions or Behavior CUE Annunciator TAVE CONT DEV HIGH (1 D1) is LIT Annunciator AUCT TAVE HIGH (1 E2) is LIT Annunciator PZR LEVEL CONT DEV LOW (1 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 12 Scenario No.: NRC 14-1 Event No.: 6 Event

Description:

Feedwater flow channel 1FT

-521 fails low Time Position Applicant's Actions or Behavior CUES: o Annunciator 1B SG FW FLOW MISMATCH (1 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 13 Scenario No: NRC 14-1 Event No. 7 Event

Description:

VCT Level Channel 1LT

-112 Failed Low Time Position Applicant's 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 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 14 Scenario No: NRC 14-1 Event No. 8 & 9 Event

Description:

1C RCP Trip with ATWS Time Position Applicant's Actions or Behavior CUE The following annunciators are LIT:

RCP TRIP (1 E3) RCP 1C BRKR OPEN OR FLOW LOW ALERT (1 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 CT-50 Manually trip the Turbine 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 CT-52 Verify/ensure Control Rods inserting in Manual or Auto at least 48 steps per minute 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 15 Scenario No: NRC 14-1 Event No. 8 & 9 Event

Description:

1C RCP Trip with ATWS Time Position Applicant's 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 Examiner's discretion.

Simulation Facility Byron Scenario No.:

N 14-2 Operating Test No.: Byron NRC 2014 Examiners:

______________________

Applicant:

____________________

SRO ______________________

____________________

RO ______________________

____________________

BOP Initial Conditions:

IC-10 5 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 shift s. 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 Type Event Description Preload FW44 IZDI1FW01PA ptl ZDI1FW002A cls ZLO1FW002A1 off ZDI1FW012A cls ZLO1FW012A1 off ZDI1FW01PAB ptl FW027 0 ZLO1FW002A 2 off 1B AF pump fail to start 1A MDFW pp O.O.S.

1 None C (BOP, US) TS (US) Local report of hot AFW piping at 1AF005A (Replaces "N")

2 CV01A C (RO, US)

TS (US) 1A CV pump trip.

3 ED07A C (US, BOP)

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

5 RD09 1 R (RO, US)

Auto rod speed fails to 1 SPM 6 RX21A 2500 10 TH11A 25 90 I (RO, US)

Pressurizer pressure channel 1PT

-455 fails high 1RY455A stuck partially open 7 Preload M (ALL) Loss of heat sink

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

NRC 10-2 Page 2 of 21 2 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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

. 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 3 of 21 3 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 4 of 21 4 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 5 of 21 5

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.

Comments:

NRC 10-2 Page 6 of 21 Scenario No: NRC 14-2 Event No. 1 Event

Description:

Elevated AF piping temperatures Time Position Applicant's 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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 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 7 of 21 Scenario No: NRC 14-2 Event No. 2 Event

Description:

1A CV Pump Trip Time Position Applicant's Actions or Behavior CUE Annunciator CHG PUMP TRIP (1 A3) is LIT Annunciator CHG LINE FLOW HIGH LOW (1 D3) is LIT Annunciator SEAL INJ FLOW LOW (1 B2) is LIT 1PR06J loss of flow alarm US o Direct use of BAR 1 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 1CV8149 A-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 8 of 21 Scenario No: NRC 14-2 Event No. 2 Event

Description:

1A CV Pump Trip Time Position Applicant's 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 9 of 21 Scenario No: NRC 14-2 Event No. 3 Event

Description:

Loss of 4KV ESF Bus 141 Time Position Applicant's Actions or Behavior CU E Annunciator BUS 141 FD BRKR 1412 TRIP (1 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 RO BOP Verify required ESF loads energized on Bus 142 Bus 132X and 132Z 1B CV pump o 1B RH pump o 1B SI pump 1B and 1D RCFC o 1B CS pump 1B CC pump BOP CT-9 1B SX pump 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 10 of 21 Scenario No: NRC 14-2 Event No. 3 Event

Description:

Loss of 4KV ESF Bus 141 Time Position Applicant's Actions or Behavior Bus 141 FD BRKR 1412 TRIP (1 A7). (THIS WILL BE LIT)

BRKR 1414 CROSS

-TIE OVERCURRENT (1 B8). DG 1A OVERLOAD (1 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 <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 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 t o 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 11 of 21 Scenario No: NRC 14-2 Event No. 4 and 5 Event

Description:

MFW Pump Trip and Auto Rod Control Speed fails to 1 step per minute Time Position Applicant's 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/ BOP Direct implementation of 1BOA SEC

-1, SECONDARY PUMP TRIP 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 condition s (@ 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 12 of 21 Scenario No: NRC 14-2 Event No. 4 and 5 Event

Description:

MFW Pump Trip and Auto Rod Control Speed fails to 1 step per minute Time Position Applicant's 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 13 of 21 Scenario No: NRC 14-2 Event No. 6 Event

Description:

Pressurizer pressure channel 1PT

-455 fails high resulting in a Reactor Trip due to failed partially open PZR PORV. Time Position Applicant's Actions or Behavior CUE Annunciator PZR PRESS HIGH RX TRIP STPT ALERT (1 A2) Annunciator PZR PORV OR SAFETY VALVE OPEN (1 B2) Annunciator PZR PRESS CONT DEV HIGH (1 D2) Annunciator PZR PORV DSCH TEMP HIGH (1 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 14 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's Actions or Behavior CUE Annunciator MANUAL RX TRIP (1 A1) Annunciator MANUAL SI/RX TRIP (1 A2 Annunciator PZR PRESS LOW SI/RX TRIP (1 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 pump s RUNNING.

Comments:

NRC 10-2 Page 15 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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/ BOP Step 2: Check if SG secondary pressure boundaries are intact:

Check pressure in all SGs:

Comments:

NRC 10-2 Page 16 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 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 17 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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 > 350F. 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 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 18 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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 p

p. Review Attachment B Crew Determine the SGs are NOT DRY Determine SG feed lines are NOT VOIDED Determine that a minimum of 2 SG's must be fed.

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

NRC 10-2 Page 19 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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.

BOP Att B, Step 1: Verify ECCS pumps running 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

-9 17) 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, Ste p 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 20 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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 21 of 21 Scenario No: NRC 14-2 Event No. 7 Event

Description:

Rx Trip/Loss of Heat Sink Time Position Applicant's 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)

Simulation Facility Byron Scenario No.:

N 14-3 Operating Test No. Byron NRC 2014 Examiners:

_ ___________________

Applicant:

____________________

SRO ____________________

____________________

RO ____________________

____________________

BOP Initial Conditions:

IC-99 Turnover: Unit 1 is in MODE 2 at 2% power, BOL, at 1BGP 10 0-2, 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 Type* Event Description 1 None N (BOP, SRO) Realign Feedwater through 1FW039 valves 2 None R (RO) (SRO) Power ascension to 2% - 3% power. 3 CV07A 80 60 C(RO, SRO) CV Seal Injection Filter Clogged 4 SW01A C (BOP, SRO) TS (SRO) SX Pump trip 5 RX21A 2500 10 I (RO, SRO)

TS (SRO) Pressurizer Pressure channel 1PT

-455 fails high 6 PA0005 ON PB2400 ON TS (SRO) MSIV inoperability; MSIV 1A HYD/PNEU PRESS HIGH/LOW, 1 B5 alarm 7 SET FWV1WG046=0.05 IOR ZLO1WG0462 OFF C (B OP, SRO) Loss of vacuum causing loss of steam dumps 8 MS03Q 100 M (all) 1D SG Safety valve stu ck open on reactor trip 9 MS01A 100 (in preload)

MS01B 100 MS01C 100 MS01D 100 C (all) All MSIVs failed open

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

Page 2 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 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 investigate d , 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 fail ed 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 3 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 4 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Realign Feedwater through 1FW039 valves.

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

Event 3: CV Seal Injection filter clogg ed 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 a nd 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 SW01 A 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 5 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.

Comments:

Byron NRC 14

-3 Page 6 Scenario No: NRC 14-3 Event No. 1 Event

Description:

Realign feedwater through 1FW039 valves Time Position Applicant's 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 7 Scenario No: NRC 14-3 Event No. 2 Event

Description:

Ramp unit to 2% - 3% power Time Position Applicant's 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 8 Scenario No: NRC 14-3 Event No. 3 Event

Description:

CV Seal Injection Filter Clog ged Time Position Applicant's Actions or Behavior CUE Annunciator RCP Seal Inj Filter High DP (1-7-A2) LIT Seal injection flows lowering RO o Adjust 1CV182 to maintain at least 8 GPM seal injection flow per RCP CREW o Dispatch EO to check 1A Seal Injection filter DP Dispatch EO to swap seal injection filters using BOP CV

-10, CV Filter Operations Evaluator Note: The crew may enter 1BOA RCP

-2 for the loss of seal cooling. This will direct swapping filters using BOP CV

-10. Actions of 1BOA RCP

-2 follow in italics. US Implement 1BOA RCP-2, Loss of Seal Cooling Notify SM of procedure entry, requests IR and EAL evaluation RO o Verify RCP seal cooling is met with RCP temperatures within limits 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 BOP Assist in monitoring primary plant while RO controls seal injection flow.

Provide assistance in diagnosis and BAR response.

US o Direct initiation of or initiate 1BOSR 5.5.1

-1, RCS Controlled Leakage Monthly Surveillance after standby filter is placed on line.

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

Comments:

Byron NRC 14

-3 Page 9 Scenario No: NRC 14-3 Event No. 4 Event

Description:

SX Pump Trip Time Position Applicant's Actions or Behavior CUE Annunciator 1 A1,"SX PUMP TRIP" and 1 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 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. EVALUATOR'S 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 10 Scenario No: NRC 14-3 Event No. 5 Event

Description:

Pressurizer pressure channel 1PT

-455 fails high.

Time Position Applicant's Actions or Behavior CUE Annunciator PZR PRESS HIGH RX TRIP STPT ALERT (1 A2) Annunciator PZR PORV OR SAFETY VALVE OPEN (1 B2) Annunciator PZR PRESS CONT DEV HIGH (1 D2) Annunciator PZR PORV DSCH TEMP HIGH (1 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 entr

y. 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 11 Scenario No: NRC 14-3 Event No. 5 Event

Description:

Pressurizer pressure channel 1PT

-455 fails high.

Time Position Applicant's 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 evaluator's cue, insert the next event.

Comments:

Byron NRC 14

-3 Page 12

Scenario No: NRC 14-3 Event No. 6 Event

Description:

MSIV Inoperability Time Position Applicant's 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 1 A MSIV US Evaluates TS 3.7.2, Condition C (for MODE 2), close MSIV within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

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 13 Scenario No: NRC 14-3 Event No. 7 Event

Description:

Loss of vacuum causing loss of steam dumps Time Position Applicant's Actions or Behavior CUE Annunciator 1 D4, CNDSR VACUUM LOW is LIT Condenser pressure is rising on MCB gauges and recorder Steam dump valve s 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 CT-1 Initiate a manual reactor trip and transition to 1BE P-0. 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 14 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's 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.

EVALUATOR'S 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 15 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's Actions or Behavior US Orders Manual Safety Injection actuation o Orders Main Steam Line Isolation actuation RO/ BOP o Attempts manual MSLI from 1PM05J and 1PM06J o Attempts to manually close MSIVs w ith individual switches on 1PM06 J. RO/ BOP Manually actuate s SI from 1PM05J and/or 1PM06J 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 pump s 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 16 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's Actions or Behavior RO CT-33 (CT may be met in 1BCA 2.1) Step 8: Maintain RCS temperature control at 1PM05J: <Cont Action Step>

Verify RCS average temperature stable at or trending to 557 oF. Throttle AF maintaining >500 GPM until SG minimum level is met MSIVs NOT closed Attempts manual MSLI from 1PM05J and 1PM06J Attempts to manually close MSIVs with individual switches on 1PM06J.

RO Step 9: Check status of RCPs at 1PM05J:

Determine RCP trip NOT required RCS pressure > 1425 psig RO/ SRO Step 10: Check if SG secondary pressure boundaries are intact at 1PM04J:

Check pressure in all SGs:

All SG pressure s 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, St ep 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 17 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's 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 18 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's 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/ BOP Check MS isolation at 1PM06J:

All MSIVs and bypass valves

- OPEN.

Comments:

Byron NRC 14

-3 Page 19 Scenario No: NRC 14-3 Event No. 8 & 9 Event

Description:

Safety Valve Open with ALL MSIVs Failed Open Time Position Applicant's 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 CT-33 (CT may have been met in 1B EP 1) Reduces feed flow to 45 GPM for each SG.

Check RCS hot leg temperatures

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

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)

Simulation Facility Byron Scenario No.:

N14-4 Operating Test No.: Byron NRC 2014 Examiners:

______________________

Applicant:

____________________

SRO ______________________

____________________

RO ______________________

____________________

BO P 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 No. Malf. No. Event Type* Event Description Preload FW35C RP15A RP83 OPEN TRGSET 2 ZLO1SI01PB(3).eq.

1 CV01B (2 0) 1C HD pump Trip/fail to start 1A CV pump auto start failure

1B CV pump trip

1 PB2411 ON PB2412 ON ZDI1MS018B CLS TS (US) SG PORV 1MS018B inoperable (Tech Spec) 2 RX13A 10 0 15 I (RO, US)

TS (US) Pressurizer level channel 1LT

-459 fails high (Tech Spec) 3 RX03B 4.8 30 I (BOP, US)

Steam flow channel 1FI

-5 13A fails high 4 FW35A C (B O P , US) 1A Heater Drain Pump trip.

5 None R (RO, US)

Runback Main Turbine 6 CV03 C (RO, US)

TS (US) Boric acid transfer pump trip.

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

NRC 14-4 Page 2 of 19 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 1MS018 B, 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 1MS019 B 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 A-D9 (SG Level deviation Hi/Lo)

After the PT-507 failure and Boric Acid Pump trip have been addressed, the 1 A 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 2 1 of 1BEP-3. Critical Tasks

1. CT-6: Establish flow fro m 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 3 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 highl00:00:07l1 0 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 4 of 19 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: SG PORV 1MS018B inoperable (Tech Spec)

Insert the following from th e 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 1MS018 B 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 1MS018 B C/S, if EST is requested.

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

MRF MS5 2 0 Event 2: Pressurizer level channel 1LT

-459 fails high

. Insert IMF RX13A 10 0 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 RX03 B 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 1 C HD pump appears normal, no obvious problem.

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

NRC 14-4 Page 5 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 fail ed 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 15 0 0 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 35 0 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.

Comments:

NRC 14-4 Page 6 of 19 Scenario No: NRC 14-4 Event No. 1 Event

Description:

SG PORV 1MS018B inoperable Time Position Applicant's Actions or Behavior CUE Annunciator S/G 1B PORV TROUBLE (1 B10). SER 2411, 1B PORV HYDRAULIC FLUID RESERVOIR LOW.

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

BOP Identify/report trouble alarm on 1MS018 B. Refer to BAR 1 B 10. Dispatch operator to 1MS018B

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

Request Equipment Status Tag for 1MS018B

. R O 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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> and verify closed once per 31 days Direct operator to close 1MS019 B within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

US Inform SM of 1MS01 8B 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 7 of 19 Scenario No: NRC 1 4-4 Event No. 2 Event

Description:

Pressurizer level channel 1LT

-459 failed high Time Position Applicant's Actions or Behavior CUE Annunciator PZR LEVEL HIGH RX TRIP STPT ALERT (1 A3) is LIT Annunciator PZR LEVEL HIGH CONT DEV HTRS ON (1 C3) is LIT 1LI-459A indicates 100% level Charging flow lowering CREW o Refer to BARs.

Identify entry conditions for 1BOA INST

-2, "OPERATION WITH A FAILED INSTRUMENT CHANNEL". US Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Implement 1BOA INST

-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment C "PRESSURIZER LEVEL CHANNEL FAILURE" and direct operator actions of 1BOA INST-2 RO Perform the following at 1PM05J:

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

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

Operate 1FK

-121 OR 1LK-459 in manual to minimize PZR level drop and maintain 8

-13 gpm RCP seal injection flow.

Select an operable Pzr level channel for control

. Select an operable Pzr level channel to the recorder

. 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 8 of 19 Scenario No: NRC 14-4 Event No. 3 Event

Description:

Steam flow channel 1FI

-513A fails High Time Position Applicant's Actions or Behavior CUE o Annunciator 1A SG FLOW MISMATCH FW FLOW L OW(1-15-A 4) o Annunciator 1A SG FLOW MISMATCH STM FLOW L OW(1-15-A 3) o Annunciator 1A SG LEVEL DEVIATION HI/LOW(1 A9) o Steam flow indicator 1FI

-5 1 3 A 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 9 of 19 Scenario No: NRC 14-4 Event No. 4 & 5 Event

Description:

1A Heater Drain Pump trip Time Position Applicant's Actions or Behavior CUE Annunciator HD PUMP TRIP (1 D2). HD Tank level rising.

HD Pump discharge valves opening.

BOP Recognizes 1A HD pump tripped.

o Refer to BAR 1 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 E8). 1BOL 3.h not implemented.

Annunciator PDMS LIMIT EXCEEDED not lit (1 D7).

Comments:

NRC 14-4 Page 10 of 19 Scenario No: NRC 14-4 Event No. 4 & 5 Event

Description:

1A Heater Drain Pump trip Time Position Applicant's 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. 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 <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR (2) initiate boration to restore SDM to w/i limit in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND (3) restore control banks to w/i limits in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

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 vol ume (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 11 of 19 Scenario No: NRC 14-4 Event No. 6 Event

Description:

Boric acid transfer pump trip Time Position Applicant's 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 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 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 12 of 19 Scenario No: NRC 14-4 Event No. 7 Event

Description:

1PT507 Fails High Time Position Applicant's 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 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 B O P 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 13 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's Actions or Behavior CUE PZR LEVEL CONT DEV LOW (1-12-B 4). PZR PRESS LOW (1 B1) S/G TUBE LEAK RATE EXCEEDED (1 A5) CHG LINE FLOW HIGH LOW (1 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 14 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's 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 pump s RUNNING. AF isolation valves

- 1AF13A-H OPE N. 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>

Verify RCS average temperature stable at or trending to 557 oF. 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/ SRO Step 10: Check if SG secondary pressure boundaries are intact at 1PM04J:

Check pressure in all SGs:

NO SG pressure decreasing in an uncontrolled manner.

NO SG completely depressurized.

RO/ SRO Check S/G tubes are NOT intact at RM

-11 console:

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 15 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's Actions or Behavior BOP CT-6 Att B, Step 1: Verify ECCS pumps running CV pumps - NONE RUNNING.

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 alignme nt 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 16 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's 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 f an 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.

0VC44 Y - 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 17 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's 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 4AA 122 1RT-AR023 Grid 1 4AA 123 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/ BO P CT-18 Isolate flow from 1A SG by verifying SG PORV 1MS018A in AUTO 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 CT-18 Check ruptured SG level 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 18 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's Actions or Behavior BOP Check ruptured SG pressure Ruptured SG pressure greater than 320 psig CREW Determine required CETC from table (step 6a)

RO/ BOP Check Pzr Pressure

- >1930 # When < 1930#, block Steamline Isol SI BOP CT-19 Dump steam to condenser from intact SG at maximum rate 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 cooldow n 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 1MS01 8D 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/ BOP Reset SI Verify SI actuated permissive light NOT LIT Verify Auto SI blocked light L IT RO/ BOP Reset Phase A isolation 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 19 of 19 Scenario No: NRC 14-4 Event No. 8 & 9 Event

Description:

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

Time Position Applicant's 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 CT-20 Depressurize RCS using PZR spray valves until 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/ BOP Stop both SI pumps 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

.

Simulation Facility Byron Scenario No.:

N 14-5 Operating Test No. Byron NRC 2014 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 Type* Event Description Preload RP26C RP28C ESF relay failure of 1A RH pump ESF relay failure of 1B RH pump 1 None R (RO) (SRO) N (BOP , SRO) Ramp down for TV/GV surveillance 2 FW16 0 I (BOP, SRO) 1PT508 fails low 3 CV10 0 6 0 134 C (RO, SRO) 1CV121 slowly fails closed. Manual control is available.

4 RX10A 0 30 I (BOP , SRO) TS (SRO) 1PT 505 fails low 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 6 TH04C 5 0 120 C (RO, SRO) 50 GPM primary leak 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

Page 2 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 close d 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 contro l 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />. Several actions will be required as a result of not being able to power th e

Instrument Bus. These include implementation of 1BOA Instrument 1 for the failed N.I. Channel and dispatching an EO to fail open 1AF005 E-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 failure

s. 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 trip ped. 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 3 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

-4l00:00:00 l1 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 4 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 6 0 134 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 3 0 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 5 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 acknowledge s 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 acknowledge s 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 RP 26C and RP28C to prevent SI auto start of 1A and 1B RH pumps

.

Comments:

Byron NRC 14-5 Page 6 Scenario No: NRC 14-5 Event No. 1 Event

Description:

Ramp unit to 89% power Time Position Applicant's 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 heater s 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 7 Scenario No: NRC 14-5 Event No. 2 Event

Description:

1PT508 fails LOW Time Position Applicant's Actions or Behavior CUE Annunciator SG 1_ FLOW MISMATCH FW FLOW LOW (1 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/ BOP Determine 1PT508 is failing LOW 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 fo r PT-508 are complete , insert next event.

Comments:

Byron NRC 14-5 Page 8 Scenario No: NRC 14-5 Event No. 3 Event

Description:

1CV121 fails closed in auto. Time Position Applicant's 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/ BOP o May isolate letdown 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 9 Scenario No: NRC 14-5 Event No. 4 Event

Description:

1PT505 fails low Time Position Applicant's Actions or Behavior CUE Annunciator 1 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 1S I-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 D 1. 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 10 Scenario No: NRC 14-5 Event No. 4 Event

Description:

1PT505 fails low Time Position Applicant's Actions or Behavior Check Tave/Tref stable and within 1F. 1TR-412 at 1PM05J PPC display o Adjust Tave

- Tref within 1F by manually withdrawing control rods at 1PM05 J Place rod bank select switch in AUTO.

RO/ BOP Check P13 interlock 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, inse rt next event.

Comments:

Byron NRC 14-5 Page 11 Scenario No: NRC 14-5 Event No. 5 Event

Description:

Loss of Instrument Bus 114 Time Position Applicant's 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/ BOP Verify control channels are operable for PZR pressure PZR level Tave Delta-T P Impulse SG level Steam flow Feed flow US RO o Rods to Manual

Comments:

Byron NRC 14-5 Page 12 Scenario No: NRC 14-5 Event No. 5 Event

Description:

Loss of Instrument Bus 114 Time Position Applicant's 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 <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> (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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and Mode 5 in 36 hrs. Direct local Inverter 114 shutdown.

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

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

o Rods will not withdraw in Manua l 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 13 Scenario No: NRC 14-5 Event No. 5 Event

Description:

Loss of Instrument Bus 114 Time Position Applicant's 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 14 Scenario No: NRC 14-5 Event No. 6 Event

Description:

Primary leak inside CNMT Time Position Applicant's Actions or Behavior CUE Annunciator 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 15 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's Actions or Behavior CUE Pzr level is dropping Annunciator CNMT PRESS HIGH (0 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 16 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's Actions or Behavior RO/ BOP CT-5 Att B, Step 1: Verify ECCS pumps running Both CV pumps

- 1B NOT RUNNING Manually start 1B CV pump due to loss of I.B. 114 Both RH pumps

- BOTH NOT RUNNING 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 17 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's 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 1F I-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 Fan s in Hi-speed BOP

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:

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 0 A M/U fan 0A Chilled water pump 0A Chiller Operating VC train dampers

- ALIGNED.

Comments:

Byron NRC 14-5 Page 18 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's Actions or Behavior M/U fan outlet damper

- 0VC24Y NOT FULLY CLOSED.

0A VC train M/U filter light

- LIT. 0VC09Y - OPE N 0VC313Y - CLOSED Operating VC train Charcoal Absorber aligned for train A. 0VC43 Y - CLOSED 0VC21 Y - OPEN 0VC22 Y - 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 0VA022 Y - OPEN 0VA020 Y - CLOSED Plenum C: 0VA03CF - RUNNING 0VA072Y - OPEN 0VA438Y - CLOSE Att B, Step 16: Verify FHB ventilation aligned at 0PM02J:

0VA04CA - RUNNING 0VA060 Y - OPEN 0VA057 Y - OPEN 0VA051 Y - 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 19 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's 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>

Verify RCS average temperature stable at or trending to 557 oF. 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 RCP's

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

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's 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 5 0% SG NR levels

- NOT rising in an uncontrolled manner Step 4: Check secondary radiation normal.

Reset Phase A Depress BOTH Phase A Reset Pushbuttons at 1PM06J OPEN 1SD005A

-D at 1PM11J At RM-11 or HMI Check secondary rad trends on :

1PR08J SG Blowdown 1PR27J SJAE/GS 1AR22/23A-D Main steam lines Secondary activity samples (when available)

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

PORV isol valves

- BOTH ENERGIZED PORVs closed PORV relief path

- BOTH PORVs in AUTO, 1RY8000A & B

- OPEN EVALUATORS Prompt booth to have the STA report a RED PATH exists for 1BFR P

-1. US When informed of the red path on 1BFR

-P.1 the U.S. should Inform the SM of the transition to P.1 and request evaluation of the Emergency Plan Direct crew actions contained below in italic s RO Check RCS pressure greater than 325 psig Check RH flow Greater than 1000 GPM US Transitions back to 1BEP-1 Step 6 Informs SM of procedure transition and requests evaluation of Emergency Plan.

Direct crew actions beginning at step 6 CREW Step 6: Check if ECCS flow should be reduced RCS subcooling

- NOT acceptable CREW Step 7: Check if CS should be stopped Both CS pumps

-1 RUNNING Reset CS signal Check Spray Add Tank Lo

-2 lights - NOT lit CS termination criteria NOT met

- for LOCA, operating time at least 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> CREW Step 8: Check if RH pumps should be stopped Reset SI Depress BOTH SI Reset Pushbuttons at 1PM06J Verify SI ACTUATED BP light NOT lit at 1PM05J Verify AUTO SI BLOCKED BP light lit at 1PM05J RCS pressure

- NOT> 325 psig & stable CREW Step 10: Check if DGs should be stopped o Stop DG s 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 21 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's 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 CT-36 Place control switches for SVAG Valve 480V busses

- CLOSE Check both RH pumps

- running 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 22 Scenario No: NRC 14-5 Event No. 7& 8 Event

Description:

Large Break LOCA with failure of 1A and B RH pumps to automatically start Time Position Applicant's 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 examiner's discretion.