simulation facility byron scenario no.: byron nrc 2014 n14-2

Simulation Facility Byron Scenario No.: N14-2

Operating Test No.: Byron NRC 2014

Examiners: ______________________

Applicant: ____________________ SRO

______________________

____________________ RO

______________________

____________________ BOP

Initial Conditions: IC-105

Turnover: Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm. Control bank D rods are at 193 steps. 1A MDFW pump has been OOS for the last 2 days for motor replacement and is expected back in 2 shifts.

Event No. Malf. No. Event Type

Event Description

Preload FW44 IZDI1FW01PA ptl ZDI1FW002A cls ZLO1FW002A1 off ZDI1FW012A cls ZLO1FW012A1 off ZDI1FW01PAB ptl FW027 0 ZLO1FW002A2 off

1B AF pump fail to start 1A MDFW pp O.O.S.

1 None TS (US) Local report of hot AFW piping at 1AF005A

2 CV01A C (RO, US) TS (US)

1A CV pump trip.

3 None N (BOP, US) Restore letdown

4 ED07A C (US, BOP) TS (US)

Loss of bus 141

5 FW02A C (BOP, US) 1B FW pp Trips requiring a main turbine runback.

6 RD09 1 R (RO, US) Auto rod speed fails to 1 SPM

7 RX21A 2500 10

I (RO, US) Pressurizer pressure channel 1PT-455 fails high

8 TH11A 25 90 M (ALL) 1RY455A stuck partially open Reactor trip

9 Preload M (ALL) Loss of heat sink with AF pump failure

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

SCENARIO OVERVIEW

Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm. Control bank D rods are at 193 steps. 1A MDFW pump has been OOS for the last 2 days for motor replacement and is expected back in 2 shifts.

After completing shift turnover, the EO will report that 1AF005A has elevated temperature of 160 degrees. 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 hours.

After completing the initial actions of 1BOA SEC-7, 1A CV pump trips. The RO or BOP will isolated letdown. 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. The BOP will restore letdown after the 1B CV pump has been started.

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. 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 before any equipment reaches a high temperature

limit as designated in 1BOA PRI-7 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

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 14-2|00:00:00|1 Event 2: 1A CV pump trip|00:00:02|3 IMF CV01A|10:00:00|4 Event 4: Loss of Bus 141|00:00:03|6 IMF ED07A|10:00:00|7 Crosstie DC 111 from DC211|00:00:04|8 irf ed111 close|10:00:00|9 Event 5 & 6: 1B MFW pump trip and rod speed failure|00:00:04|11 IMF FW02A|10:00:00|12 IMF RD09 1|10:00:00|13 Event 7 & 8: Pressure channel and PORV|00:00:05|15 IMF RX21A 2500 10|10:00:00|16 IMF TH11A 25 90|10:00:00|17 Preload|00:00:06|19 IMF FW44|00:00:07|20 IOR ZDI1FW01PA ptl|00:00:08|21 IOR ZDI1FW002A cls|00:00:09|22 IOR ZLO1FW002A1 off|00:00:10|23 IOR ZDI1FW012A cls|00:00:11|24 IOR ZLO1FW012A1 off|00:00:12|25 IOR ZDI1FW01PAB ptl|00:00:13|26 MRF FW027 0|00:00:14|27 IOR ZLO1FW002A2 off|00:00:15|28

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Elevated AF piping piping temperature When crew has completed turnover, CALL as the AB EO and report that 1AF005A downstream temperature is 160°F. 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 with no visible damage, and 1B CV pump is running normally after the start. As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications. Event 3: Restore Letdown Acknowledge as Shift Manager commencement and completion of all procedures performed by the crew when notified. Event 4: 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 125 VDC 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 5 and 6 (next page) will be run simultaneously. Event 5: 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 on the 1B FW pump, and (the started) CD/CB pump is running normally. 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.

Event 6: 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 7: Pressurizer pressure channel 1PT-455 fails high opening PORV 1RY455A 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 Event 8: Pressurizer PORV 1RY455A stuck open resulting in a Reactor trip due to lowering RCS pressure. As SM acknowledge the entry into 1BEP-0 . Acknowledge as SM procedure changes, E Plan evaluations, and STA request. Event 9: Loss of heat sink due to 1B AFP trip and loss of power to 1A AFP After STA is requested, as STA report CSF status – Red path on heat sink when all SG levels are less than 10% NR. NOTE TO STA: Report BST H Red path and show the US the BST path, but don’t explicitly tell them to enter 1BFR H.1. If dispatched as Equipment Operator, report 1B AF pump has large lube oil leak and engine damage. Acknowledge request to remove FW isolation fuses and 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.

Scenario No:

NRC 14-2 Event No.

1

Event Description:

Elevated AF piping temperatures

Time Position Applicant’s Actions or Behavior

CUE • Field report 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 hours

EVALUATOR NOTE: After the 1AF013A has been closed and notifications made, and with lead examiners concurrence, insert the next event.

Scenario No:

NRC 14-2 Event No.

2

Event Description:

1A CV Pump Trip


CUE

• Annunciator CHG PUMP TRIP (1-9-A3) is LIT • Annunciator CHG LINE FLOW HIGH LOW (1-9-D3) is LIT • Annunciator SEAL INJ FLOW LOW (1-7-B2) is LIT • 1PR06J loss of flow alarm

US o Direct use of BAR 1-9-A3 RO • Identifies 1A CV pump trip CREW • Identifies Letdown needs to be isolated RO • Close 1CV8149A and 1CV8149B, Orifice Isol Valves

• Close 1CV459 and 1CV460, Letdown Isol Valves RO • Verify available suction path with no gas binding concerns

o VCT level is adequate o 1CV112B and 1CV112C are open o Check computer group TR28

• Verify 1CV8110 and 1CV8116 are open • Adjust 1CV121 to 10% open • Start 1B CV pump

ο Adjust charging flow to minimize PZR level rise 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 • Evaluate TRM 3.1.d Condition A

EVALUATOR NOTE:

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

Scenario No:

NRC 14-2 Event No.

3

Event Description:

Restore Letdown


CUE

• Letdown is isolated

BOP • Enter 1BOA ESP-2, Re-establishing CV Letdown • Verify/Close 1CV8149A-C and 1CV459 and 1CV460 • Verify/Open 1CV8401B • Verify/Open 1CV8324B • Verify/Open 1CV8389B • Verify/Open 1CV8152 and 1CV8160 • Verify BTRS Mode Selector Switch is OFF • Place 1CV131 Controller to MANUAL at 40% demand • Place 1CC130A Controller to MANUAL at 60% demand • Verify/Open 1CV8105 and 1CV8106 • Throttle 1CV182 to maintain seal injection flow at 8-13 GPM per pump • Throttle 1CV121 to raise charging flow to 100 GPM • Open 1CV459 and 1CV460 • Open 1CV8149A and 1CV8149B/C • Adjust 1CV131 to control letdown pressure at 360 PSIG and place in AUTO • Ensure 1CC130 is maintaining temperature at 105° to 115° and place in AUTO • Adjust 1CV121 to match charging and letdown flow and restore Pzr level to Program Level and

place in AUTO • Throttle 1CV182 to maintain seal injection flow at 8-13 GPM per pump • Verify 1PR06J is in service

Scenario No:

NRC 14-2 Event No.

4

Event Description:

Loss of 4KV ESF Bus 141


CUE • Annunciator BUS 141 FD BRKR 1412 TRIP (1-21-A7) • ESF bus alive light (141) NOT lit. • No voltage indicated on Bus 141.

BOP • Determine Bus 141 deenergized. • Reference BARs.

CREW • Identify entry conditions for 1BOA ELEC-3, “LOSS OF 4KV ESF BUS.” • Dispatch operators to investigate status of bus 141.

US • Notify SM of plant status and procedure entry. • Request evaluation of Emergency Plan conditions. • Enter/Implement 1BOA ELEC-3 "LOSS OF 4KV ESF BUS " and direct operator actions of 1BOA

ELEC-3 to establish the following conditions:

BOP • Check ESF Buses energized: • Bus 141 (Deenergized)

BOP 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: • Bus 141 FD BRKR 1412 TRIP (1-21-A7). (THIS WILL BE LIT) • BRKR 1414 CROSS-TIE OVERCURRENT (1-21-B8). • DG 1A OVERLOAD (1-21-B9).

US GO TO STEP 6 of 1BOA ELEC-3 ATTACHMENT A • Direct WEC to X-tie DC Buses with U-2 within 1 hour • 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

Scenario No:

NRC 14-2 Event No.

4

Event Description:

Loss of 4KV ESF Bus 141


• 3.8.9 Condition A • Contact SM to perform risk assessment, initiate IR, and contact maintenance to

investigate/correct failure.

EVALUATOR NOTE:

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

Scenario No:

NRC 14-2 Event No.

5 and 6

Event Description:

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


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 conditions (@ 1 spm and should be much greater) • Drives rods in, in MANUAL • Initiate boration as necessary- per REMA plaque

Note: Initial value should be between 150 and 280 gallons of boric acid • Perform the following at 1PM05J:

ο 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 o Check CD pump recirc valve closed-1CD152 o Check Gland steam condenser valves open- 1CD157A and B

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

Scenario No:

NRC 14-2 Event No.

5 and 6

Event Description:

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


event.

Scenario No:

NRC 14-2 Event No.

7 & 8

Event Description:

Pressurizer pressure channel 1PT-455 fails high resulting in a Reactor Trip due to failed partially open PZR PORV.


CUE • Annunciator PZR PRESS HIGH RX TRIP STPT ALERT (1-12-A2) • Annunciator PZR PORV OR SAFETY VALVE OPEN (1-12-B2) • Annunciator PZR PRESS CONT DEV HIGH (1-12-D2) • Annunciator PZR PORV DSCH TEMP HIGH (1-9-C6) • PZR pressure indicators 1PI-456, 457, and 458 lowering • PZR PORV 1RY-455A open light lit at 1PM05J.

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

CUE ο Annunciator MANUAL RX TRIP (1-11-A1) ο Annunciator MANUAL SI/RX TRIP (1-11-A2 ο Annunciator PZR PRESS LOW SI/RX TRIP (1-11-C1) • Reactor trip indications at 1PM05J.

CREW Identify entry conditions for 1BEP-0, “REACTOR TRIP OR SAFETY INJECTION”.

US • Notify SM of plant status and procedure entry. • Request evaluation of Emergency Plan conditions. • Enter/Implement 1BEP-0 and direct operator actions of 1BEP-0 to establish the following

conditions:

RO Perform immediate operator actions of 1BEP-0 at 1PM05J: • Verify reactor trip:

• Rod bottom lights - ALL LIT. • Reactor trip & Bypass breakers – OPEN. • Neutron flux – DROPPING.

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

• All Turbine throttle valves – CLOSED. • All Turbine governor valves – CLOSED.

Scenario No:

NRC 14-2 Event No.

7 & 8

Event Description:

Pressurizer pressure channel 1PT-455 fails high resulting in a Reactor Trip due to failed partially open PZR PORV.


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.

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


RO • Step 6: Verify AF system: • AF pumps – NO AF pumps RUNNING.

• 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:

• 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

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


• 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 –NONE RUNNING

• 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 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

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


operator actions of 1BFR-H.1 to establish the following conditions:

RO • Check if secondary heat sink is required: • RCS pressure > intact SG pressures. • RCS temperature > 350°F.

US/RO • Check CV pump status at 1PM05J:

• CV pumps – 1 RUNNING.

RO • Check if Bleed and Feed is required • Wide range level in any 3 SGs <27% or • PZR pressure > 2335

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

• All SG BD iso. Valves (1SD002A-H) closed • All SG sample isolation valves (1SD005A-D) closed o Review attachment B prior to FW flow initiation • Check AF pump SX suction valves armed alarm NOT Lit (1-3-E7) • Check AF test valves open (1AF004A and B) • Check AF pumps-NONE running • Dispatch an operator to attempt to locally start 1B AFP • Check AF isol. valves (1AF013A-H)for selected SG open • 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 7.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)

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


• Close MFW pp recirc valves (1FW012A,B, C) • Start S/U FW pp. • Review Attachment B

Crew • Determine the SGs are NOT DRY • Determine SG feed lines are NOT VOIDED • Determine that a minimum of 2 SG’s must be fed.

BOP CT-43

• Establish and throttle Tempering Flow Control Valve(s) on selected SGs ο 1FW034A ο 1FW034B ο 1FW034C ο 1FW034D • 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-917) • RCS pressure >1700 psig

BOP

• Perform the following at 1PM06J: • Att B, Step 4: Verify RCFCs running in Accident Mode:

• Group 2 RCFC Accident Mode lights – 2 LIT. • Att B, Step 5: Verify Phase A isolation:

• Group 3 Cnmt Isol monitor lights – ALL AVAILABLE LIT. • Att B, Step 6: Verify Cnmt Vent isolation:

• Group 6 Cnmt Vent Isol monitor lights – ALL AVAILABLE LIT. o Verify MSIV and Bypass Valves – CLOSED

• Att B, Step 7: Verify CC pumps – 1B RUNNING. • Att B, Step 8: Verify SX pumps – 1B RUNNING. • Att B, Step 9: Check if Main Steamline Isolation –required:

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

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


• 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.

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 • 0VA023Y - OPEN • 0VA436Y – CLOSED

• Plenum C:

• 0VA03CF - RUNNING • 0VA072Y – OPEN

Scenario No:

NRC 14-2 Event No.

9

Event Description:

Loss of Heat Sink


• 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 100-5 - May notify

WEC of this step.

(Final)


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 950 MW for grid demand @ 1.5 MW/min. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance. Fuel is preconditioned for full power operations, and QNE recommends maintaining PDMA02 at its current value.

Event No. Malf. No. Event Type*

Event Description

Preload RP02A RP02B TC03 ZDIHSTG010 NORM IMF FW43

Turbine fails to AUTO trip from Rx trip Manual Turbine trip PB fails to trip turbine 1A AFP fails to autostart

1 None N (BOP,SRO)

Switch Bus 156 Electrical Lineup

2 CV16 0 I (RO, SRO) VCT Level Channel 1LT-112 Fail Low

3 None R (RO, SRO) N (BOP, SRO)

Raise power to 950 MW

4 None TS (SRO)

Notified that 1A SI pump failed ASME surveillance

5 PA0154 ON PA0152 ON zao0iisx032 95

C (BOP,SRO) TS (SRO)

SX Fan high vibration requiring fan swap

6 RX18A 630 I (RO, SRO) TS (SRO)

1A TCOLD RTD Fail High

7 RX04D 0 30 I (BOP,SRO)

Feedwater flow channel 1FT-521 fails 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)

10 Pre-load C (ALL) Failure of 1A AFP to auto start


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 raise power to 950 MW for grid demand @ 1.5 MW/min. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance. Fuel is preconditioned for full power operations, and QNE recommends maintaining PDMA02 at its current value.

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, 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 crew will begin a ramp to 950 MW at 1.5 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 3.5.2, Condition A.

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

After the SX fan vibration has been addressed, 1A Tcold RTD fails high, requiring entry to 1BOA Inst-2, Operation with a Failed Instrument Channel. This will require entry into Tech Specs by the SRO, (TS 3.3.1 Conditions A & E).

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, 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. The 1A AF Pump will fail to autostart if an autostart setpoint is reached, and must be manually started in the MCR.

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-51: Start AFW Pumps during ATWS before RCS pressure exceeds and stays above 2335 PSIG with all SG levels below 27% WR.

2. CT-52: Insert negative reactivity into the core by at least one of the following methods: rod insertion or

boration; prior to locally tripping the reactor by in-plant operators. References:

1BGP 100-3 100-3T5 BAR 0-37-E6 1BOA INST-2, Att A & G 1BFR-S.1 1BEP-0



• Establish the conditions of IC 107 (password: nrc14), 74% 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). • 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 14-1|00:00:01|0 Event 2: 1LT-112 fails low|00:00:05|2 IMF CV16 0|10:00:00|3 Event 5: 0B MDCT fan high vibration alarm|00:00:02|5 IMF pa0152 on|10:00:00|6 IMF PA0154 ON|10:00:00|7 IOR zao0iisx032 95|10:00:00|8 Event 6: 1A Tc RTD fails high|00:00:03|10 IMF RX18A 630|10:00:00|11 Event 7: 1FT-521 fails low|00:00:04|13 IMF RX04D 0 30|10:00:00|14 Event 8: 1C RCP trip|00:00:06|16 IMF TH16C|10:00:00|17 Preload: |00:00:07|19 RTB fail to open|00:00:08|20 IMF RP02A|00:00:09|21 IMF RP02B|00:00:10|22 Turbine trip failure|00:00:11|23 IMF TC03|00:00:12|24 IOR ZDI1HSTG010 NORM|00:00:13|25 trgset 10 "zlo0sx03cbhi(1).gt.0"|00:00:14|30 trgset 11 "zlo0sx03cbhi(1).gt.0"|00:00:15|31 trgset 12 "zlo0sx03cbhi(1).gt.0"|00:00:16|32 trg 10 "dor zao0iisx032"|00:00:17|33 trg 11 "dmf pa0152"|00:00:18|34 trg 12 "dmf pa0154"|00:00:19|35 To trip the Rx locally|00:00:20|37 dmf rp02A|10:00:00|38 dmf rp02b|10:00:00|39 mrf rp01 trip|10:00:00|40 mrf rp02 trip|10:00:00|41 imf fw43|00:00:21|45 trgset 15 “zdi1af01pa(4).eq.1” |00:00:22|46 trg 15 “dmf fw43|00:00:23|47

INSTRUCTOR/SIMULATOR RUN AID GUIDE

Event 1: Switch Bus 156 Electrical Lineup Event 2: 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 3: Ramp unit to 950 MW at 1.5 MW per minute. Event 4: Unit Supervisor is notified that SI pump has failed ASME acceptance criteria SM acknowledge T/S 3.5.2 entry conditions Event 5: 0B SX MDCT Fan High Vibration IMF PA0152 ON 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 6: 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 7: 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 8: ATWS – 1C RCP trip with Rx Trip Breakers Fail to Open IMF RP02A and RP02B (in preload) IMF TH16C to trip 1C RCP

As SM Acknowledge procedure entry and request for Emergency Plan evaluations. After transition to 1BFR-S.1, Acknowledge request for STA and begin monitoring BSTs. As EO, acknowledge request for local trip of Reactor Trip Breakers. 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 (in preload) IOR ZDIHSTG010 NORM (in preload) Event 10: 1A AF Pump fails to autostart IMF FW43 (in pre-load)

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 1-20-E1 as ‘expected alarm” 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.

Scenario No:

NRC 14-1 Event No.

2

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 1-9-A2 • Determine 1LT-112 is failed LOW

RO • Place RMCS makeup switch in STOP • Monitor VCT level o Makeup to VCT in MANUAL if required (BOP CV-7)

US • Notify SM of failure, request IR BOP • Monitor primary and secondary panels

• Assist with BAR response EVALUATOR NOTE: After the actions for the VCT level failure are complete and with lead

examiners concurrence, insert the next event.

Scenario No:

NRC 14-1 Event No.

3

Event Description: Raise power at 1.5 MW/min Time Position Applicant’s Actions or Behavior

CUE o Direction from Power Team to raise power to 950 MW at 1.5 Mw/min.

US

• Acknowledge request to raise power to 950 MW at 1.5 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 950 MW at 1.5 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:

o Approximate band (1000-1500 gal) o ~15 steps withdrawal

• 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. ο 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). ο Turn on PZR backup heaters.

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

• Select SETPOINT. • Enter 1.5 MW/min into the RATE window. • Select ENTER. • Enter 950 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.

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.

Scenario No:

NRC 14-1 Event No.

3

Event Description: Raise power at 1.5 MW/min Time Position Applicant’s Actions or Behavior

• 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.

Scenario No:

NRC 14-1 Event No.

4

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


Scenario No:

NRC 14-1 Event No.

5

Event Description:

0B SX MDCT Fan High Vibration requiring a Fan Trip


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

• 0B SX High Speed Fan Amps indicate High in Red Band BOP • Refer to BAR 0-37-D6 and E6

• Monitor amps NOT normal • Manually trip 0B SX Fan • Place 0B SX fan High AND Low speed C/S to PTL 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 4risers 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.

Scenario No:

NRC 14-1 Event No.

6

Event Description: 1A Tcold RTD Failed High Time Position Applicant’s Actions or Behavior

CUE • Annunciator TAVE CONT DEV HIGH (1-14-D1) is LIT • Annunciator AUCT TAVE HIGH (1-14-E2) is LIT • Annunciator PZR LEVEL CONT DEV LOW (1-12-B4) is LIT

CREW • Identify instrument failure US • Enter 1BOA Inst-2, Operation with a Failed Instrument Channel

• Notify SM of procedure entry, request EAL evaluation and IR o Order ramp in HOLD

RO • Verify/Place Rod Bank Select Switch in MANUAL • Manually defeat 1A Tave channel • Manually defeat 1A ∆T channel • Select operable RTD for the ∆T recorder • Check if Rod Control can be placed in AUTO

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

• Check Pzr level trending to normal • May take manual control of Master Pzr level controller or 1CV121

BOP • Assist RO with BAR response o Place ramp in HOLD

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

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

US • Determines TS 3.3.1 condition A & E is applicable; DEL 3.3.2 for P-12 EVALUATOR NOTE: After the actions for the instrument failure are complete and with lead


Scenario No.:

NRC 14-1 Event No.:

7

Event Description:

Feedwater flow channel 1FT-521 fails low


CUES: o Annunciator 1B SG FW FLOW MISMATCH (1-15-B4) o FW flow indicator 1FI-521A lowering o FW flow indicator 1FI-520A rising o FWRV 1FW-520 opening o SG level indicators 1LI-527, 528, 529, 557 rising

BOP • Identify 1FT-521 failed low • Report failure to US • Perform the following at 1PM04J

• Place 1FW-520 in MANUAL • Lower FW flow to match or slightly lower than steam flow • Monitor 1B SG level and control 1FW-520 in MANUAL

ο 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. ο 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.

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 (1-13-E3) • RCP 1C BRKR OPEN OR FLOW LOW ALERT (1-13-C3)

CREW • Identify entry conditions for 1BEP-0, “REACTOR TRIP OR SAFETY INJECTION” EVALUATOR NOTE: The crew may dispatch an operator to open the reactor trip breakers

before reaching step 6. US • Enters 1BEP-0, “REACTOR TRIP OR SAFETY INJECTION”

• Transition to 1BFR S.1, “ATWS” • Notify SM of procedure entry • Request EAL evaluation and STA to monitor BSTs

RO o Rod Bottom lights -NOT LIT o Rx Trip and Bypass Bkrs- NOT ALL OPEN • Manually TRIP the Reactor from BOTH locations • Allow rods to insert automatically until rod speed less than 48 SPM, then manually insert rods

CREW

• Manually trip the Turbine 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 CT-51

• Manually start both AF pumps • 1A AF Pump fails to AUTO start, but must be started manually

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 • Verify letdown established

RO/BOP

• Check Pzr pressure < 2335 PSIG • Verify Group 6 CVI monitor lights LIT

Scenario No:

NRC 14-1 Event No.

8 & 9

Event Description: 1C RCP Trip with ATWS Time Position Applicant’s Actions or Behavior

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.



Examiners: _ ___________________

Applicant: ____________________

SRO

____________________

____________________

RO

____________________

____________________

BOP


Turnover: Unit 1 is in MODE 2 at 2% power, BOL, at 1BGP 100-2, step 21, raising power to 2% - 3% power. Boron concentration is 1316 ppm. Permission has been given to go to MODE 1 and MODE 2 to MODE 1 checklist is approved. An extra NSO will perform 1BOSR NR-1. 1B SX pump is OOS for maintenance and LCOAR entered. 1B SX pump is ready to be RTS following turnover.


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, 1-1-B5 alarm

7 SET FWV1WG046=0.05 IOR ZLO1WG0462 OFF

C (BOP, SRO)

CW pump vibration and loss of vacuum causing loss of steam dumps

8 MS03Q/R/S/T 100 M (all) 4 SG Safety valves stuck open on reactor trip

9 MS01A/B/C/D 100 (in preload)

C (all) All MSIVs failed open


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 and MODE 2 to MODE 1 checklist is approved. An extra NSO will perform 1BOSR NR-1. 1B SX pump is OOS for maintenance and LCOAR entered. 1B SX pump is ready to be RTS following turnover. 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 crosstie SX from Unit 2 in accordance with BAR 1-1-A1 and 1BOA PRI-7, Loss of SX. The SRO will evaluate for TS 3.0.3 for Unit 1 (3.7.8. AR also applies 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 pressure channel failure has been addressed, MSIV 1A HYD/PNEU PRESS HIGH/LOW, 1-1-B5 alarm comes in. The crew will dispatch an operator to investigate, and the SRO will evaluate TS 3.7.2.

After the MSIV alarm has been investigated, an alarm for 1C CW pump will come in. The EO will report high vibration on the 1B CW pump. Main Condenser vacuum will degrade. The crew will enter 1BOA SEC-3, Loss of Vacuum, and upon condenser unavailable, will trip the reactor. On the reactor trip, 1MS017A, 4 SG Safety Valves will stick full open, lowering steam pressure in all SGs. All 4 MSIVs will be failed open and cannot be closed automatically or manually. Crew will use 1BEP-0, 1BEP-2 and 1BCA 2.1.

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

Critical Tasks

CT-9: Manually start SW (SX) pumps for safeguards equipment cooling before any equipment reaches a high temperature limit as designated in 1BOA PRI-7. (Crosstie of SX systems satisfies this CT).

CT-33: Control AFW to minimize RCS cooldown before any RCS cold leg temperature is <240°F. (Integrity CST

orange path)

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.



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


• Place 1B SX Pump C/S to PTL and hang OOS card on it.

• Ensure “1A Seal Inj Filter Online” placard is in place.




• Run caep N14-3 from thumb drive and verify the following actions load in the CAEP: Byron 2014 ILT NRC scenario 14-3r1|00:00:01|0 Event 3: CV Seal Injection Filter Clogged|00:00:02|2 IMF CV07A 80 60|10:00:00|3 Open 1CV8384B|00:00:03|4 MRF CV42 100|10:00:00|5 close 1CV8384A|00:00:04|6 MRF CV41 0|10:00:00|7 Event 4: SX Pump trip and 2SX005 open|00:00:05|9 IMF SW01A|10:00:00|10 mrf sw07 100|10:00:00|11 Event 5: Pressurizer Pressure channel 1PT-455 fails high|00:00:06|13 IMF RX21A 2500 10|10:00:00|14 Event 6: MSIV inoperability|00:00:07|16 IMF PA0005 ON|10:00:00|17 IMF PB2400 ON|10:00:00|18 Event 7: 1C CW vibration/trip then Loss of vacuum causing loss of steam dumps|00:00:08|20 imf pn1593 on|10:00:00|21 imf cw01b|10:00:00|22 IOR ZLO1WG0462 OFF|00:00:09|23 SET FWV1WG046=0.01|10:00:00|24 Event 8 & 9: FOUR SG Safety valves stuck open on reactor trip|00:00:10|26 trgset 12 "zlo52brka(2).gt.0"|00:00:02|31 imf ms03q (12 0) 100|00:00:11|32 imf ms03r (12 1) 100|00:00:12|33 imf ms03s (12 2) 100|00:00:13|34 imf ms03t (12 3) 100|00:00:14|35 IMF MS01A 100|00:00:16|41 IMF MS01B 100|00:00:17|42 IMF MS01C 100|00:00:18|43 IMF MS01D 100|00:00:19|44 imf sw01b|00:00:20|45


Event 1: Realign Feedwater through 1FW039 valves.

Event 2: Ramp unit to 2% - 3% power

SM acknowledges start of ramp when notified.

Event 3: CV Seal Injection filter clogged

IMF CV07A 80 60

AS EO, report 1A Seal Injection filter DP at 35 PSID (High alarm setting is 29 PSID).

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

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

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

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

Event 4: 1A SX Pump trip

IMF SW01A to trip the 1A SX pump.

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

AS EO, (if requested per 1BOA PRI-7) report: 1A SX pump – NOT ROTATING

As Unit 2 NSO, when direct to start the standby Unit 2 SX pump, acknowledge. Make PA “Starting 2B SX pump” and call back reporting both U2 SX pumps are running.

As Unit 2 NSO, when directed to open 2SX005, MRF SW07 100 and report 2SX005 is open. When asked, report Unit 2 SX pressure is 100 PSIG.

As EO, when directed to restart 1A VP chiller, acknowledge order.

As SM, acknowledge E Plan evaluation, procedure entry and TS evaluation. After SX crosstie is done, notify the crew that 1B SX pump RTS is in progress and the 1B SX pump may be restored as soon as the EO notifies them the inplant actions are completed.

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

IMF PN1593 for 1C CW Pump cooling water alarm.

As EO, report that 1C CW pump has very high vibration and you are evacuating the area.

WHEN crew trips the 1C CW pump: IOR ZLO1WG0462 OFF to override vacuum breaker OPEN light off AND

SET FWV1WG046=0.01 to cause loss of Main Condenser vacuum (by slightly opening the vacuum breaker).

As the EO, if asked, 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.

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/B/C/D 100 (in preload) to fail all MSIVs fully open.

Verify MS03Q/R/S/T 100 on reactor trip to fail open 4 SG Safety Valves 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.

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.

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.

Scenario No:

NRC 14-3 Event No.

3

Event Description:

CV Seal Injection Filter Clogged


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.

Scenario No:

NRC 14-3 Event No.

4

Event Description: SX Pump Trip Time Position Applicant’s Actions or Behavior

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

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

o Acknowledge annunciator. o Check BAR o Check SER alarm • Verifies voltage on all 3 phases of Bus 141 to be >3850 volts (per BAR 1-2-A1)

US/crew • Implements 1BOA PRI-7, Essential Service Water Malfunction Identifies NO Unit 1 SX pump available

• Implements 1BOA PRI-7 Attachment A Directs Unit 2 to start their standby SX pum Directs opening 1SX005 Directs Unit 2 to open 2SX005 Checks Unit 2 SX pressure > 90# Check VC chiller running Check VQ chiller running

• Notifies SM of procedure entry and requests Emergency Plan evaluation • Dispatches EO to check 1A SX pump – NOT ROTATING

BOP CT-9

• Opens 1SX005

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

• 3.0.3 applies to Unit 1. • When directed by SM, orders 1B SX pump Returned To Service

BOP • Places 1B SX pump C/S in After Trip. When the SX system is crosstied and actions are complete, and at evaluators cue, initiate

the next event.

Scenario No:

NRC 14-3 Event No.

5

Event Description:

Pressurizer pressure channel 1PT-455 fails high.


CUE • Annunciator PZR PRESS HIGH RX TRIP STPT ALERT (1-12-A2) • Annunciator PZR PORV OR SAFETY VALVE OPEN (1-12-B2) • Annunciator PZR PRESS CONT DEV HIGH (1-12-D2) • Annunciator PZR PORV DSCH TEMP HIGH (1-9-C6) • PZR pressure indicators 1PI-456, 457, and 458 lowering • PZR PORV 1RY-455A open light lit at 1PM05J.

RO • Identify 1PT-455 is failing high. • Identify 1RY455A is open. • Report failure to US. • Perform the following at 1PM05J:

• Place 1RY455A, PZR PORV, C/S in close prior to reactor trip or SI occurring. • Place 1PK-455A, master PZR pressure controller, in manual. • Lower demand on 1PK-455A sufficiently to close PZR spray valves and energize PZR

heaters prior to reactor trip or SI occurring. • Operate 1PK-455 in manual to restore PZR pressure to normal operating band. • Monitor reactor response to RCS pressure transient.

CREW o Refer to BARs. • Identify entry conditions for 1BOA INST-2, “OPERATION WITH A FAILED INSTRUMENT

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

BOP o Refer to BARs • Monitor secondary panels • Assist RO as requested

US • Notify SM of plant status and procedure entry. • Request evaluation of Emergency Plan conditions. • Enter/Implement "1BOA INST-2, “OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment B, “PRESSURIZER PRESSURE CHANNEL FAILURE”. RO • Check PZR pressure at 1PM05J:

• PZR pressure – normal on 1PI-456, 457, & 458. • Manually restore PZR pressure using 1PK-455A.

• Select operable PZR pressure control channel o Place 1PK-455A in manual and restore PZR pressure to normal. • Place PZR pressure control select C/S to CH-457/CH-458.

RO • Check PZR PORVS, spray valves, and heaters at 1PM05J: • PZR PORVs closed. • PZR spray valves normal for plant conditions. • PZR heaters normal for plant conditions.

• Check PZR pressure control in auto at 1PM05J: • Check the following components in AUTO:

• PZR PORV 1RY455A • 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.

Scenario No:

NRC 14-3 Event No.

5

Event Description:

Pressurizer pressure channel 1PT-455 fails high.


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.

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 1A MSIV

US o Evaluates TS 3.7.2, Condition C (for MODE 2), close MSIV within 8 hours. o Evaluates TS 3.7.2, Condition A (for MODE 1), restore MSIV within 8 hours. • 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.

Scenario No:

NRC 14-3 Event No.

7

Event Description: CW pump vibration and loss of vacuum causing loss of steam dumps Time Position Applicant’s Actions or Behavior

CUE • Annunciator 1-17-E11, CW PUMP CLG WTR PRESS LOW is LIT • EO reports 1C CW pump high vibration • Annunciator 1-18-D4, CNDSR VACUUM LOW is LIT • Condenser pressure is rising on MCB gauges and recorder • Steam dump valves CLOSE

US • Implements 1BOA SEC-3 • Orders 1C CW pump to be TRIPPED • Notifies SM of procedure entry and requests E Plan evaluation

BOP • Trips 1C CW pump • Verifies CW flow – NORMAL • Bypasses SP demins • Starts vacuum hogging pump

CUE • Annunciator 1-18-D4, CNDSR VACUUM LOW is LIT • Condenser pressure is rising on MCB gauges and recorder • Steam dump valves CLOSE

BOP • Reports condenser pressure rising. • Reports loss of steam dumps

US

• Determines condenser pressure – NOT ACCEPTABLE • Orders reactor trip and 1BEP-0 entry

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


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.

Scenario No:

NRC 14-3 Event No.

8 & 9

Event Description:

Safety Valve Open with ALL MSIVs Failed Open


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

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 with individual switches on 1PM06J.

RO/ BOP

• Manually actuates SI from 1PM05J and/or 1PM06J

Crew • Re-enters 1BEP-0 US • Transition to 1BEP-0

Scenario No:

NRC 14-3 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior • 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


EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B. Attachment B steps are on pages 18 & 19

RO • Step 6: Verify AF system:

• AF pumps – BOTH AF pumps RUNNING. • AF isolation valves – 1AF13A-H OPEN. • AF flow control valves – 1AF005A-H THROTTLED. • AF flow - >500 GPM • Check SG tubes - INTACT and SG NR levels – NOT RISING UNCONTROLLED

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

• 1RY455 & 1RY456 CLOSED • PORV isol valves – 1RY8000A & 1RY8000B BOTH ENERGIZED • PORV relief path – Both PORVs in AUTO, Both isolation valves – OPEN. • Normal PZR Spray Valves CLOSED

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 557oF. • 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 pressures are lowering in an uncontrolled manner. • Transition to 1BEP-2, “Faulted Steam Generator Isolation”

Scenario No:

NRC 14-3 Event No.

8 & 9

Event Description:



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. • 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 1BEP 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.

EVALUATOR NOTE: BOP is performing Attachment B; steps follow below

BOP

• Att B, Step 1: Verify ECCS pumps running

• Both CV pumps - RUNNING. • Both RH pumps – RUNNING • Both SI pumps – RUNNING


• 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

Scenario No:

NRC 14-3 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior • 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 – 1B SX pump RUNNING OR SX is crosstied from U2. • 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.


• 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.


• Operating VC train dampers – ALIGNED. • M/U fan outlet damper – 0VC08Y NOT FULLY CLOSED. • 0B VC train M/U filter light – LIT. • 0VC09Y - OPEN

Scenario No:

NRC 14-3 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior • 0VC313Y – CLOSED

• Operating VC train Charcoal Absorber aligned for train B. • 0VC44Y - CLOSED • 0VC05Y - OPEN • 0VC06Y – OPEN




• 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 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100-5 - May notify

WEC of this step

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)


Operating Test No.: Byron NRC 2014

Examiners: ______________________

Applicant: ____________________ SRO

______________________

____________________ RO

______________________

____________________ BOP


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 100 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-513A fails high 4 FW35A C (BOP,

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.


SCENARIO OVERVIEW Unit 1 is at 89% power, steady state, equilibrium xenon, MOL. RCS boron concentration is 911 ppm. On line risk is green. After completing shift turnover and relief, steam generator 1B atmospheric relief valve 1MS018B, will develop a hydraulic leak. The Unit Supervisor will enter Tech Spec 3.7.4, Condition A and Tech Spec 3.6.3, Condition C. The crew may dispatch an operator to close 1MS019B to comply with TS 3.6.3, condition C. 1MS018B will remain unavailable for the remainder of the scenario. After the 1MS018B failure has been addressed, Pressurizer level transmitter 1LT-459A, the controlling channel, fails high. The RO will take manual control of either the master Pzr level controller or 1CV121 to raise charging. The crew will enter 1BOA Inst-2, and there is a high level bistable to be tripped or bypassed. Technical specification 3.3.1 conditions A and K will be entered. After the pressurizer level channel failure has been addressed, the controlling steam flow channel on the 1A SG fails high. The BOP will take manual control of feedwater flow. 1BOA INST 2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment H, will be implemented. The BOP will restore feedwater flow control to automatic when SG level is restored to normal. After the feedwater flow channel failure has been addressed, 1A Heater Drain Pump will trip. 1BOA SEC-1, SECONDARY PUMP TRIP, Attachment C, will be entered. The BOP will attempt a start of the 1C HDP but it will not start. The BOP will then initiate a turbine load reduction to 780 MW at 20 MW/minute. The RO will borate the RCS as necessary to stabilize RCS temperature. While borating in response to the 1A Heater Drain Pump trip, the Unit 1 Boric Acid pump motor bearing will seize while the pump is running. MCC 133X3, cubicle A4 will open, causing a trip of the Unit 1 Boric Acid Transfer Pump. The crew will align the Unit 0 Boric Acid Transfer Pump to Unit 1 per BOP AB-17, UNIT 0 BORIC ACID TRANSFER PUMP OPERATIONS step F.1. After the Boric Acid Transfer Pump alignment is complete, 1PT507 will Fail High. This will require the BOP to take manual control of TDFW pump speed. Actions will be directed by BAR 1-15-A-D9 (SG Level deviation Hi/Lo) After the PT-507 failure and Boric Acid Pump trip have been addressed, the 1A SG will develop a 350 gpm SGTR. The crew will implement 1BEP-0, REACTOR TRIP OR SAFETY INJECTION. When safety injection is actuated, the 1B CV pump will trip. The 1A CV pump must be manually started to establish high head ECCS flow. After determining 1A SG has a tube rupture the crew will transition to 1BEP-3, STEAM GENERATOR TUBE RUPTURE. The scenario is complete when the crew isolates high head injection at step 21 of 1BEP-3.

Critical Tasks

1. CT-6: Establish flow from at least one Charging/SI pump before completion of 1BEP-0, Attachment B. 2. CT-18: Isolate ruptured SG before a transition to 1BCA 3.1 is necessary. 3. CT-19: Control initial RCS cooldown to maintain adequate RCS subcooling when RCS is depressurized, and to

prevent requirement of BST Integrity orange or red path due to operator actions. 4. CT-20: Depressurize RCS to E-3 SI termination criteria before SG overfill causes the ruptured SG PORV to stay

open and release water through the PORV.

References: 1BOA Inst-2 1BOA SEC-1 BOP AB-17 BAR 1-15-A-D9 1BEP-0 1BEP-3



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



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



• Run caep N14-4 from thumb drive and verify the following actions load in the CAEP: Byron 2014 ILT NRC scenario 14-4|00:00:00|1 EVENT 1: 1MS018B inoperable|00:00:01|2 IMF PB2411 ON|10:00:02|3 IMF PB2412 ON|10:00:03|4 IOR ZDI1MS018B CLS|10:00:04|5 EVENT 2: 1LT-459 fails high|00:00:05|7 IMF RX13A 100 15|10:00:06|8 EVENT 3: 1FI-513A fails high|00:00:07|10 IMF RX03B 4.8 30|10:00:08|11 EVENT 4 & 5: 1A Heater Drain Pump trip.|00:00:09|13 IMF FW35A|10:00:10|14 EVENT 6: Boric acid transfer pump trip.|00:00:11|16 IMF CV03|10:00:12|17 To swap BATP|00:00:12|18 ior zlo0ab03p on|10:00:12|19 dmf cv03|10:00:12|20 EVENT 7: PT-507 fails high|00:00:13|22 IMF RX05 1500|10:00:14|23 EVENT 8: Ruptured 1A SG|00:00:15|25 IMF TH03A 350|10:00:16|26 Preload|00:00:17|31 1C HD pump Trip/fail to start|00:00:18|32 IMF FW35C|00:00:19|33 1A CV pump auto start failure|00:00:20|34 IMF RP15A|00:00:21|35 MRF RP83 OPEN|00:00:22|36 1B CV pump trip|00:00:23|37 TRGSET 2 "ZLO1SI01PB(3).eq.1"|00:00:24|38 IMF CV01B (2 0)|00:00:25|39

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: SG PORV 1MS018B inoperable (Tech Spec) Insert the following from the CAEP and verify the following actuate: • IMF PB2411 ON • IMF PB2412 ON • IOR ZDI1MS018B CLS As SM acknowledge the failure, LCO 3.6.3, condition C and LCO 3.7.4, condition A, and requests for on line risk assessment, maintenance support, and IR initiation. If dispatched as EO, report 1MS018B has a cracked hydraulic line, it is still dripping into a small puddle of hydraulic fluid that is present beneath the valve. As WEC supervisor. acknowledge request for EST for 1MS018B C/S, if EST is requested. If dispatched as EO to close 1MS019B, perform the following: • MRF MS52 0 Event 2: Pressurizer level channel 1LT-459 fails high. Insert IMF RX13A 100 15 to fail 1LT-459 high over a 15 second period. AS WEC supervisor, acknowledge request to trip or bypass bistable. Inform the US the operators are being briefed. As SM acknowledge the failure, LCOs 3.3.1, conditions A and K entry, on line risk assessment, request for maintenance support, and IR requests.

Event 3: Steam flow channel 1FT-513A fails high Insert IMF RX03B 4.8 30 to fail 1FT-513A high over a 30 second period. As SM acknowledge the failure, on line risk assessment, request for maintenance support, and IR requests.

Event 4 & 5: 1A Heater Drain Pump trip and load reduction Insert IMF FW35A to trip the 1A Heater Drain Pump. Acknowledge as SM the 1A HD pump trip, 1BOA SEC-1 entry, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation. If dispatched as EO, report 1A Heater Drain pump is seized and report ground overcurrent flag at breaker cubicle. Report that 1C HD pump appears normal, no obvious problem. Acknowledge as Power Team load reduction and estimated duration of derate.

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 6: Boric acid transfer pump trip Note: Ensure a boration is in progress prior to inserting the next malfunction. Insert IMF CV03 to trip the Unit 1 boric acid pump. If dispatched as EO, report Unit 1 AB pump breaker 133X3 is tripped and does not appear to be damaged. If breaker re-closure is requested, report breaker is closed. DO NOT DELETE MALFUNCTION. If pump restart is attempted, report the breaker is open. If dispatched as EO, report the Unit 1 AB pump bearing is hot and appears to be damaged. If contacted as Unit 2, report Unit 0 AB pump is NOT supplying Unit 2 demands and is NOT electrically aligned to Unit 2. If dispatched as EO, align the Unit 0 AB pump to Unit 1 demands per BOP AB-17 as follows: • Verify w/MCR AB pump 1 + 0 c/s is in PTL (BOP AB-17, step F.1.a) • Verify w/MCR U-1 makeup c/s is in STOP (BOP AB-17, step F.1.b) • Insert IOR ZLO0AB03P ON • Wait approximately two minutes then perform the following:

• Delete malfunction DMF CV03 • Report Unit 0 AB pump aligned for Unit 1 demands (BOP AB-17 is complete up to step F.1.j) As SM, acknowledge the failure and requests for on line risk assessment, maintenance support, and IR initiation. If the crew asks about desired state of U-1 Boric Acid state as SM that U-0 boric acid pump needs to be aligned in place of the failed U-1 Boric Acid pump. In addition, the SM does NOT want to use the RWST as a boric acid source. The SM desires the Unit to remain on-line.

Event 7: 1PT507 fails High Insert IMF RX05 1500 to fail 1PT507 to 1500 psig. As SM, acknowledge the failure and requests for on line risk assessment, maintenance support, and IR initiation. Event 8: Ruptured 1B SG Insert IMF TH03B 350 to cause a rupture in the 1B SG steam generator. Acknowledge as SM procedure changes, E Plan evaluations, and STA request. After STA requested, as STA report CSF status: Event 9: 1B CV pump trips/1A CV pump fails to auto start (preload) If dispatched as EO to investigate 1B CV pump, report ground overcurrent flag at breaker cubicle.

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 (1-15-B10). • SER 2411, 1B PORV HYDRAULIC FLUID RESERVOIR LOW. • SER 2412, S/G PORV 1B ACCUMULATOR PRESSURE LOW.

BOP • Identify/report trouble alarm on 1MS018B. • Refer to BAR 1-15-B10. • Dispatch operator to 1MS018B. • Place 1MS018B C/S in close at 1PM04J to stop hydraulic pump.

ο Request Equipment Status Tag for 1MS018B.

RO • Assist BOP as requested. Refer to BARs as available. US • Identify entry conditions for TS 3.7.4, condition A Restore to Operable in 30 days

• Identify entry conditions for TS 3.6.3, condition C.: Close 1MS019B in 72 hours and verify closed once per 31 days

• Direct operator to close 1MS019B within 72 hours. US • Inform SM of 1MS018B status, TS Status, request IR, On Line Risk Assessment, maintenance

support, and clearance order/EST for 1MS019B.

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

Scenario No:

NRC 14-4 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 (1-12-A3) is LIT • Annunciator PZR LEVEL HIGH CONT DEV HTRS ON (1-12-C3) is LIT • 1LI-459A indicates 100% level • Charging flow lowering

CREW o Refer to BARs. • Identify entry conditions for 1BOA INST-2, “OPERATION WITH A FAILED INSTRUMENT

CHANNEL”. US • Notify SM of plant status and procedure entry.

• Request evaluation of Emergency Plan conditions. • Implement 1BOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL",

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

RO • Perform the following at 1PM05J: • Place 1FK-121, CV pumps flow control valve, OR 1LK-459, PZR master level controller, in

manual. • Raise demand on 1FK-121 OR 1LK-459 in conjunction with controlling demand on

1CV182 to raise charging flow. • Operate 1FK-121 OR 1LK-459 in manual to minimize PZR level drop and maintain 8-13 gpm

RCP seal injection flow. • Select an operable Pzr level channel for control. • Select an operable Pzr level channel to the recorder. • 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.

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 LOW(1-15-A4)

o Annunciator 1A SG LEVEL DEVIATION HI/LOW(1-15-A9) o Steam flow indicator 1FI-513A rising o FWRV 1FW-510 opening o SG level indicators 1LI-517, 518, 519, 556 rising

BOP • Identify 1FT-513A failed high • Report failure to US • Perform the following at 1PM04J

• Place 1FW-510 in MANUAL • Lower FW flow to match or slightly lower than steam flow • Monitor 1A SG level and control 1FW-510 in MANUAL • Place Master FW pump speed controller in MANUAL • Verify adequate feedwater delta-P

RO • Assist BOP as requested • Monitor reactor panel for reactivity changes

CREW o Refer to BARs • Identify entry conditions for 1BOA INST 2, OPERATION WITH A FAILED INSTRUMENT

CHANNEL, Attachment G.

US • Notify SM of plant status and procedure entry. • Request evaluation of Emergency Plan conditions. • Enter/Implement "1BOA INST-2, “OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment G.

BOP • Select operable SG flow channel F-512 • Check 1A SG level – normal on 1LI-517, 518, 519, 556 • Place 1FW-510 in AUTOMATIC • Place Master FW pump speed controller in AUTOMATIC • Verify steam pressure channels normal

EVALUATOR NOTE: Ensure auto control is reestablished prior to inserting the next event. After the actions for the steam flow channel failure are complete and with lead examiners concurrence, insert the next event.

Scenario No:

NRC 14-4 Event No.

4 & 5

Event Description:

1A Heater Drain Pump trip


CUE • Annunciator HD PUMP TRIP (1-17-D2). • HD Tank level rising. • HD Pump discharge valves opening.

BOP

• Recognizes 1A HD pump tripped. o Refer to BAR 1-17-D2. • Reports failure to US. • Recognizes one Heater Drain Pump running.

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

US • Acknowledge 1A HD pump trip. • Contact SM to perform risk assessment, initiate IR, and contact maintenance to

investigate/correct failure. • Implement 1BOA SEC-1, “SECONDARY PUMP TRIP” Attachment C "HD PUMP TRIP" and direct

operator actions of 1BOA SEC-1 to establish the following conditions.

BOP • Recognizes standby HD pump NOT AVAILABLE. • Check HD pump status at 1PM03J.

• ONLY 1B HD pump running. • Initiate HD runback on OWS graphic 5512 at 1PM02J. • Verify turbine load lowering.

BOP • Check HD Tank level at 1PM03J:

• Level > 72% and rising. • Maintain HD tank level.

o Verify 1HD046A &B in AUTO. o Open 1CB113A-D. o Manually open 1HD117, HD tank overflow valve. o Lower turbine load as necessary to maintain HD tank level <72%.

• Check 1HD117, HD tank overflow valve in auto and closed at 1PM03J. o Lower turbine load as necessary to close 1HD117.

• Check 1B HD pump parameters at 1PM03J. • 1B HD pump amps < 168 amps. • 1B HD pump flow < 2950 KLB/HR.

o Lower turbine load as necessary to restore 1B HD pump parameters. • Deactivate turbine runback:

• Depress STOP HD RUNBACK softkey at OWS graphic 5512 at 1PM02J. NOTE: Crew may ramp lower to control HDT level.

US/RO • Check PDMS operable.

• Annunciator PDMS INOPERABLE not lit (1-10-E8). • 1BOL 3.h not implemented. • Annunciator PDMS LIMIT EXCEEDED not lit (1-10-D7).

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.

Scenario No:

NRC 14-4 Event No.

4 & 5

Event Description:

1A Heater Drain Pump trip

Time Position Applicant’s Actions or Behavior US o Enter TS 3.4.1, RCS DNB Limits, Condition A IF pressure <2209 PSIG.

o Enter TS 3.1.6, Control Bank Insertion Limits Condition A IF RIL LOW-2 alarm is received. RO NOTE TO EVALUATOR: The boric acid pump will trip during this event-see event 6 for

specifics. • Initiate RCS boration at 1PM05J: • Determine required boric acid volume (approximate band: 50 gal – 200 gal).

o Determine from Rema. • Determine desired boric acid flow rate. • Set 1FK-110 BA Flow Control to desired boration rate. • Set 1FY-0110 BA Blender Predet Counter to desired volume. • Place MAKE-UP MODE CONT SWITCH to STOP position. • Place MODE SELECT SWITCH to BORATE position. • Place MAKE-UP MODE CONT SWITCH to START. • Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer

Pump running, 1CV110A throttles open, proper BA flow indicated on recorder). o Turn on PZR backup heaters.

BOP • Verify running CB pump recirc valves in auto. • 1CB113A-D on running pumps.

• Dispatch operators to perform BOP HD-2 for 1A HD pump. • Shutdown CD/CB pump (if started during procedure performance).

US • Notify chemistry to monitor secondary plant chemistry. • Notify SM to perform risk assessment. • Check reactor power change > 15% in one hour.

o Notify chemistry to perform TS 3.4.16 sampling. o Notify rad protection to perform TS sampling.

ο 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.

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 (1-9-A6) • Trip/yellow disagreement light on Boric Acid Transfer pump 1 + 0 C/S (if pump control switch is

taken to start)

RO • Identify/report trip of Unit 1 Boric Acid Transfer pump • Refer to BAR 1-9-A6 and/or 1-9-A4 • Dispatch operator to Unit 1 Boric Acid Transfer pump and breaker

US • Notify SM of Unit 1 Boric Acid Transfer pump trip. • Direct operators to align the Unit 0 Boric Acid Transfer pump for Unit 1 demand o Direct BOP to control load ramp

RO

• Determine Unit 1 Boric Acid Transfer pump bearing is damaged • Report from EO

• Align 0AB03P, Boric Acid Transfer pump 0 for Unit 1 demands per BOP AB-17 ο Verify 0AB03P NOT supplying Unit 2 boric acid demands ο 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 ramp is complete and with lead examiners concurrence, insert the next event.

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 (1-15-A/B/C/D 9)

• 1PK507 MS HDR PRESSURE CONTROLLER METER @ 100% • 1PI-507 SG HDR PRESS - 1500 psig • 1PI-508 FW HTR DISCH. PRESSURE RISING • 1PI-509 MS/FW HDR D/P LOWERING TO “0” • 1PI-MS021 STM HDR PRESS – 1500 psig

BOP • Identify/report Failure of 1PT-507 • Refer to BAR 1-15-A/B/C/D 9 • Inform US of instrument failure ο Take manual control of FW pp turbine speed control

US • Notify SM of instrument failure. ο Direct BOP To take manual control of FW pp speed control ο Direct BOP to stop load ramp ο 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.

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.


CUE • PZR LEVEL CONT DEV LOW (1-12-B4). • PZR PRESS LOW (1-12-B1) • S/G TUBE LEAK RATE EXCEEDED (1-16-A5) • CHG LINE FLOW HIGH LOW (1-9-D3) • PZR Level and Pressure dropping. ο 1A SG level rising or 1FW510 open less than other 3 FWRVs ο Possible RM-11 Rad Monitor ALERT/HI RAD Alarms.

ο 1AR 22/23A 1A Main Steam line. ο 1PR27J SJAE

RO • Reports lowering PZR level and pressure

ο 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.


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.


EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B. Attachment B steps are on pages 17, 18 & 19.

NOTE that CT-6 is part of Att B steps.

RO • Step 6: Verify AF system:

• AF pumps – BOTH AF pumps RUNNING.

Scenario No:

NRC 14-4 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior • AF isolation valves – 1AF13A-H OPEN. • AF flow control valves – 1AF005A-H THROTTLED. • AF flow - >500 GPM • Check SG tubes intact – 1A SG radiation RISING OR 1A SG level RISING in an

uncontrolled manner • Verify/Close AF isol valves

• 1AF013A • 1AF013E • 1AF005A • 1AF005E


• 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 557oF. • 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)

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 ο 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 ο Unexpected rise in NR level ο Main steamline rad monitor

ο 1RT-AR022 Grid 1 4AA122 ο 1RT-AR023 Grid 1 4AA123

Scenario No:

NRC 14-4 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior ο 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/ BOP 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

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

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

• Dump steam using 1MS018C and 1MS018D Crew Dispatch operators to standby 1SI101A & B.

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

• Continue with next steps until target temperature is met. Crew • Stop RCS cooldown when target temperature is met.

• 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 LIT

RO/ • Reset Phase A isolation

Scenario No:

NRC 14-4 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior BOP

BOP • Establish IA to containment • Check SACs- any running • Open 1IA065 and 1IA066

CREW • Check if RH pumps should be stopped • Any RH pump running and aligned to RWST • RCS pressure >325# • Stop both RH pumps

CREW • Check if RCS Cooldown should be stopped • Ave of 10 highest CETC < required temperature in Step 6 • When met, stop cooldown and maintain temperature < required temperature

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 GPM Feed Flow 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.

EVALUATOR NOTE: BOP is performing Attachment B:

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


• 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

Scenario No:

NRC 14-4 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior 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.


• DGs – BOTH DG running • 1SX169A/B OPEN. • Dispatch operator locally to check operation


• 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.


• 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

Scenario No:

NRC 14-4 Event No.

8 & 9

Event Description:


Time Position Applicant’s Actions or Behavior • 0VC06Y – OPEN




• Plenum C:

• 0VA03CF - RUNNING • 0VA072Y – OPEN • 0VA438Y – CLOSE


• 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



• Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100-5 - May notify

WEC of this step

EVALUATOR NOTE: When the CREW isolates High Head Injection the scenario should be terminated.



Examiners: _ ___________________

Applicant: ____________________

SRO

____________________

____________________

RO

____________________

____________________

BOP


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 5 MW/min for the surveillance.


Event Description

Preload RP26C RP28C ESF relay failure of 1A RH pump

ESF relay failure of 1B RH pump 1 RX10A 0 30 I (BOP,

SRO) TS (SRO)

1PT 505 fails low

2 None R (RO) (SRO) N (BOP, SRO)

Ramp down for TV/GV surveillance

3 FW16 0 I (BOP, SRO)

1PT508 fails low

4 CV10 0 60 134 C (RO, SRO)

1CV121 slowly fails closed. Manual control is available.

5 ED11D TS (SRO) C (BOP, SRO)

Loss of IB 114 due to a bus fault. Tech Spec 3.8.9 required shutdown within 8 hours

6 TH04C 50 120 C (RO, SRO)

50 GPM primary leak

7 TH04C 400 180 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


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 5 MW/min.

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

After the PT-505 failure is addressed, the crew will ramp the unit to 89% power at 3MW/min

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

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

After the crew has taken actions for the failure of 1CV121, 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 hours. Several actions will be required as a result of not being able to power the Instrument Bus. These include implementation of 1BOA Instrument 1 for the failed N.I. Channel and dispatching an EO to fail open 1AF005E-H and locally controlling flow as needed or using 1AF013E-H

After the Unit Supervisor has evaluated the failed Instrument Bus, a 50 GPM RCS leak develops inside CNMT. . The crew will enter 1BOA PRI-1, Excessive Primary Plant Leakage, and the RO will raise charging and isolate letdown to stabilize Pzr level.

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

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

Critical Tasks

1. CT-5: Manually start at least one low-head ECCS pump before completion of 1BEP-0 Attachment B.

2. CT-36: Transfer to cold leg recirculation before RWST level reaches 9%.

References

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



• Establish the conditions of IC-22, 100% power.





• Run caep N14-5 from thumb drive and verify the following actions load in the CAEP: Byron 2014 ILT NRC scenario 14-4|00:00:00|1 EVENT 1: 1PT505 fails low|00:00:05|3 IMF RX10A 0 30|10:00:06|4 EVENT 3: 1PT508 fails low|00:00:01|6 IMF FW16 0|10:00:02|7 EVENT 4: 1CV121 fails closed|00:00:03|9 IMF CV10 0 60 134|10:00:04|10 EVENT 5: AC IB 114 failure|00:00:07|12 IMF ED11D|10:00:08|13 EVENT 6: RCS leak|00:00:09|15 IMF TH04C 50 120|10:00:00|16 EVENT 7: LB LOCA|00:00:10|18 IMF TH04C 540000|10:00:00|19 RH pump relay failures|00:00:11|21 IMF RP26C|00:00:12|22 IMF RP28C|00:00:13|23


Event 1: Turbine impulse pressure 1PT505 fails low NOTE: Ensure control rods are in AUTO before inserting this MF. Insert IMF RX10A 0 30 to fail 1PT-505 low over a 30 second period. As SM, acknowledge the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request. As the WEC supervisor, acknowledge crew request to bypass or trip bistables. Report operators are being briefed. Event 2: 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 3: 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 4: 1CV121, fails open in closed. Manual control is taken. This valve will remain in manual through out the rest of the scenario. Initiate event after load ramp down is commenced, with the lead examiners concurrence. As SM, acknowledge the failure, request for maintenance support, and IR request. SDG: CV5 IMF CV10 0 60 134 If the crew decides to isolate and bypass 1CV121 refer to: SDG: CV5 Throttle Open 1CV8387A and Close 1CV8483A Event 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, As ES, report the bus appears to be damaged and the Inverter 114 AC output breaker is tripped. There is NO fire at the bus. SDG: ED7: IMF ED11D SDG FW13: If the crew decides to fail the B train AF005 valves open, utilize the following malfunctions: IMF FW45E, F, G, and H to 100 (to fail open) To throttle the same valves use Remote Functions FW161 (E), 162 (F), 163 (G) and 164 (H) to use the Manual Handwheel to the desired position.

Event 6: Primary leak inside CNMT IMF TH04C 50 120 SM acknowledges procedure entry and E Plan evaluations. Event 7: Large Break LOCA with failure of ESF start relays on both RH pumps, requiring manual start, which functions IMF TH04C 400 180 When crew trips the plant and actuates Safety Injection, or when Automatic Safety Injection actuates: IMF TH04C 540000 SM acknowledges procedure entry and E Plan evaluations. After entering 1BEP-1, at about step 5, the STA notifies the crew that a red path condition exists and recommends 1BFR P.1 be implemented. When requested to de-energize 1CV112D and 1CV112E in 1BEP ES-1.3 112D - MRF ED053O to OPEN 112E - MRF ED071J to OPEN If requested, to vary SX flow to U-0 CC HX use sim dwrg SW2 and vary 0SX007 to 40% If the crew decides to fail the B train AF005 valves open, utilize the following malfunctions: IMF FW45E, F, G, and H to 100 (to fail open) To throttle the same valves use Remote Functions FW161 (E), 162 (F), 163 (G) and 164 (H) to use the Manual Handwheel to the desired position Event 8: ESF failure of RH pumps 1A and 1B RH pump relay failure requiring manual start (In Preload) IMF RP26C and RP28C to prevent SI auto start of 1A and 1B RH pumps.

Scenario No:

NRC 14-5 Event No.

1

Event Description: 1PT505 fails low Time Position Applicant’s Actions or Behavior

CUE • Annunciator 1-14-D1, TAVE CONT DEV HIGH • 1PI-505, first stage pressure, indication lowering. • Bypass Permissive C-5 Turbine Low Power annunciates • Bypass Permissive C-20 AMS Permissive annumciates o Control rod inward motion. • 1TR-0412, Auct Tave/Tref recorder, Tref indication dropping • 1SI-412, Rod Speed, indicates 72 step per minute • Steam Dump Actuated light LIT on 1PM02J

RO/BOP • Perform the following at 1PM05J: o Determine control rods inserting. • Identify 1PT-505 is failing low. • Report failure to US • Determine turbine power stable at 1PM06J or OWS drop 210. o Place rod bank select switch to manual at 1PM05J to stop uncontrolled rod insertion.

CREW • Reference BARs 1-14-D1. • Identify entry conditions for 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT

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

are italicized below • Check turbine power stable • Check Rods in manual, if not place in manual • Check power range N.I.s operable • Check Tave instruments operable • Check Turbine first stage pressure operable

• Go to 1BOA Inst. 2 Operation with a failed Instrument Channel, Attachment D

US • Notify SM of plant status and procedure entry • Request evaluation of Emergency Plan conditions • Implement 1BOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL",

Attachment D "TURBINE IMPULSE PRESSURE CHANNEL FAILURE" and direct operator actions of 1BOA INST -2 to establish the following conditions.

RO/BOP • Restore steam dumps. • Check C-7 bypass permissive NOT LIT at 1PM05J. • Perform the following at 1PM02J:

• Place 1PK-507, MS header pressure controller, in manual. • Lower 1PK-507 demand to 0%. • Place steam dump mode select switch to STM PRESS mode. • Place 1PK-507 in auto.

• Check reactor power <100 % on NIs • Defeat 1PT-505 at 1PM05J

•Place 1PS505Z, turbine impulse pressure defeat C/S, to DEFEAT 505 RO • Check if rod control can be placed in auto

• Check C-5 bypass permissive LIT at 1PM05J. • Check Tave/Tref stable and within 1°F.

• 1TR-412 at 1PM05J • PPC display

o Adjust Tave – Tref within 1°F by manually withdrawing control rods at 1PM05J ο Place rod bank select switch in AUTO.

RO/ BOP

• Check P13 interlock • Turbine power > 10% • Check P-13 bypass permissive NOT LIT at 1PM05J

Scenario No:

NRC 14-5 Event No.

1

Event Description: 1PT505 fails low Time Position Applicant’s Actions or Behavior

US

ο 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

EVALUATOR NOTE: After the actions for the turbine impulse pressure channel failure are complete, insert next event.

Scenario No:

NRC 14-5 Event No.

2

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

• Select STOP on RMCS Makeup Control Switch • Select BORATE on RMCS Mode Select Switch • Enter desired boration amount in BA totalizer • Turn ON RMCS Makeup Control Switch • Verify 1CV110B OPEN • Verify 1CV110A MODULATING • Verify 1AB03P STARTS • Verify proper AB flow on 1FR110

• Coordinate boration with start of unit ramp by BOP BOP • Set up DEH for ramp IAW 1BGP 100-4T3

• Enter desired ramp rate (5 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.

Scenario No:

NRC 14-5 Event No.

3

Event Description: 1PT508 fails LOW Time Position Applicant’s Actions or Behavior

CUE • Annunciator SG 1_ FLOW MISMATCH FW FLOW LOW (1-15-A4/B4/C4/D4) • FWRVs (1FW510/20/30/40) closing • 1B/1C FW turbine speed rising • 1A/B/C/D SG levels rising • Master Feed Pump Speed controller output rising

RO/ 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

ο Master Controller ο Individual Feed Pump Speed Controllers

• Lower feed pump speed to recover S/G levels ο Uses alternate pressure indication (1PI-FW015) ο Establishes proper d/p for power level using alternate indication per placard

ο Remove controller integral by momentarily going to manual on each FWRV US • Notify SM of PT-508 failure, request IR, and maintenance. CREW • Check SG levels normal and stable NOTE: FW pp speed control will be in manual for the remainder of the scenario EVALUATOR NOTE: After the actions for PT-508 are complete, insert next event.

Scenario No:

NRC 14-5 Event No.

4

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.

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 • 1-4- 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

RO/US • Prepare to energize Bus 114 from the CVT: (Directing EO actions in the field) • NOTE: EO will report BUS DAMAGE o Verify OPEN

o Inverter 114 Output breaker o Bus 114 Main feed breaker

o Verify CLOSED Instr. Bus 114 CVT Feed bkr o Close Inst. Bus 114 CVT Input bkr • Contact EMD to investigate damage to bus 114. • Notify Shift Manager • Perform actions associated with 1BOA INST-1 – 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 hours (if not restored go to Cond. D) o Condition D: If Condition B not met, be in Mode 3 in 6 hours and Mode 5 in 36 hrs.

• Direct local Inverter 114 shutdown. ο Review Table D impacts for loss of Inst Bus 114 (Below is a portion of the list that will be

impacted at this time.) o Train B ESF loads will require manual actuation and no reset. o Rods will not withdraw in Manual o PORV 1RY455A will not open in Auto o VCT Auto makeup will not occur. o 1AF005E-H will close as soon as flow starts and cannot be controlled from the MCR. o 1SD054A-D, SD Blowdown failed closed o RCPs 1D and 1B Seal Leakoff Flow Recorders are inoperable o 1PR-403, RC WR Pressure recorder is inoperable o PR N44 is lost o SR audio counts are lost o Several TSLBs lit and 1PM05J CRTs are lost

Scenario No:

NRC 14-5 Event No.

5

Event Description: Loss of Instrument Bus 114 Time Position Applicant’s Actions or Behavior

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 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”

• Reset “Rate Mode” for “N-44” (Spring returned to NORMAL) • 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

• On “DETECTOR CURRENT COMPARATOR”: • Place “UPPER SECTION” to “PR N-44” • Place “LOWER SECTION” to “PR N-44”

• On “MISCELLANEOUS CONTROL AND INDICATION PANEL” • Place “”POWER MISMATCH BYPASS” to “BYPASS PR N-44” • Place “ROD STOP BYPASS” to “BYPASS PR N-44”

• On “COMPARATOR AND RATE PANEL” • Place “COMPARATOR CHANNEL DEFEAT” to “N-44”

o Place “ROD STOP BYPASS SWITCH” for N-44 on 1PM07J in “BYPASS” 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.

Scenario No:

NRC 14-5 Event No.

6

Event Description: Primary leak inside CNMT Time Position Applicant’s Actions or Behavior

CUE • 1PR11J RM-11 High Alert Alarm • Annunciator 1-1-A2, CNMT DRAIN LEAK DETECT FLOW HIGH alarm is LIT • Rising radiation levels on area monitors inside CNMT • Lowering Pzr level (Charging flow will not rise because 1CV121 is in MANUAL)

RO

• Determine Pzr level is lowering • Throttle open 1CV121 to raise charging flow • Isolate letdown

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

US • Notify SM of procedure entry and request E Plan evaluation o TS evaluation 3.4.13 Condition A

CREW • Check Pzr level stable or rising EVALUATOR NOTE: When the RO has isolated LD and Pzr level is stable or rising and at Evaluator’s direction, insert next event.

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 (0-33-D6) is LIT • Automatic reactor trip and/or safety injection actuation

CREW • Identify entry conditions for 1BEP-0, “REACTOR TRIP OR SAFETY INJECTION” US • Notify SM of plant status and procedure entry

• Request evaluation of Emergency Plan conditions • Enter/Implement 1BEP-0 and direct operator actions of 1BEP-0

RO Perform immediate operator actions of 1BEP-0: • Step 1: Verify reactor trip

• Rod bottom lights - ALL LIT • Reactor trip & Bypass breakers - OPEN • Neutron flux – DROPPING

BOP Perform immediate operator actions of 1BEP-0: • Step 2: Verify Turbine Trip

• All Turbine throttle valves - CLOSED • All Turbine governor valves - CLOSED

• Step 3: Verify power to 4KV busses • ESF Buses – BOTH ENERGIZED (141 & 142)

CREW • Check SI Status • SI First Out annunciator –LIT • SI ACTUATED Permissive Light –LIT • SI Equipment – ACTUATED

• Either SI pump – RUNNING • Either CV pump to cold leg isolation valve – OPEN – 1SI8801A

Note: examinee may open 1SI8801B at this time • Recognize SI Actuated • Manually actuate SI from 1PM05J AND 1PM06J


EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B. Attachment B steps are on pages 19-22.

NOTE that CT-5 is part of Att B steps.

EVALUATOR NOTE: 1BEP-0 main body continues here. 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-D THROTTLED (1AF E-H are CLOSED) • AF flow - >500 GPM • Check SG tubes - INTACT and SG NR levels – NOT RISING UNCONTROLLED


• 1RY455 & 1RY456 CLOSED • PORV isol valves – 1RY8000A & 1RY8000B BOTH ENERGIZED • PORV relief path – Both PORVs in AUTO, Both isolation valves – OPEN.

Scenario No:

NRC 14-5 Event No.

7& 8


• 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 557oF. • 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:

• 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

Scenario No:

NRC 14-5 Event No.

7& 8


• 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 when ANY RCS cold leg temperature is <185°F. US • When informed of the red path on 1BFR-P.1 the U.S. should

• Inform the SM of the transition to P.1 and request evaluation of the Emergency Plan • Direct crew actions contained below in italics

RO • Check RCS pressure greater than 325 psig • Check RH flow Greater than 1000 GPM

US • Transitions back to 1BEP-1 Step 6 • Informs SM of procedure transition and requests evaluation of Emergency Plan. • Direct crew actions beginning at step 6

CREW

• Step 6: Check if ECCS flow should be reduced • RCS subcooling – NOT acceptable

CREW • Step 7: Check if CS should be stopped • Both CS pumps –1 RUNNING • Reset CS signal • Check Spray Add Tank Lo-2 lights – NOT lit • CS termination criteria NOT met – for LOCA, operating time at least 8 hours

CREW • Step 8: Check if RH pumps should be stopped • Reset SI

• Depress BOTH SI Reset Pushbuttons at 1PM06J • Verify SI ACTUATED BP light NOT lit at 1PM05J • Verify AUTO SI BLOCKED BP light lit at 1PM05J

• RCS pressure - NOT> 325 psig & stable CREW • Step 10: Check if DGs should be stopped

o Stop DGs and place in standby CREW • Step 11: Initiate evaluation of plant status

• Check cold leg recirc capability – BOTH trains available • 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

Scenario No:

NRC 14-5 Event No.

7& 8


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 (1B manually started) • Check both 1SI8811A • Goes to Step 4 of Attachment A • Closes 1SI8812A • Checks 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 Attempt to restart 1B CS pp (Will not start)

• Check 1 Train of Cnmt Sump recirc established • Return to main body step 4 page 8

• Check SI pump- any running • Check 1SI8801A or B open: CHG pp to Cold Leg Injection valves

CREW • Align SI and CV pumps for cold leg recirc (Step 5) • Verify closed: (CV pp mini-flows) 1CV8111, 1CV8114, 1CV8110, 1CV8116 • Close SI pump mini-flow valves 1SI8813, 1SI8814, 1SI8920 • Close (RH HX disc. X-tie vlvs) 1RH8716A & B • Open/verify open (SI & CV pp suct. Hdr x-tie vlvs) 1SI8807A & B, 1SI8924 • Check 1A RH Pump running • Open (RH HX to CV pps) 1CV8804A • Check 1B RH Pump running • Open (RH HX to SI pps) 1SI8804B • Start CV pumps and SI pumps as necessary

EVALUATOR NOTE: The scenario can be terminated after the first 6 steps of 1BEP ES-1.3 are completed or at lead examiner’s discretion.

EVALUATOR NOTE: BOP is performing Attachment B:

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 Attachment B of 1BEP-0.

• Both SI pumps – 1B NOT RUNNING • Manually start 1B SI pump due to loss of I.B. 114

Scenario No:

NRC 14-5 Event No.

7& 8


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

CREW Recognize and announce ADVERSE CNMT

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

• CNMT pressure has risen > 20 psig. • Group 6 CS monitor lights – ALL LIT. • Group 6 phase B lights – ALL LIT. NOTE: B Train NOT LIT

• Manually actuate CS and Phase B Isolation- 2 out of 2 switches at (at least) 1 out of 2 locations

• Verify/Stop ALL RCPs (at 1PM04J). • CS eductor suction flow - > 15 gpm on 1FI-CS013 & 1FI-CS014. • CS eductor additive flow - > 5 gpm on 1FI-CS015 & 1FI-CS016.

• Align SX Cooling Towers

• All 8 riser valves – OPEN • OPENS 0SX163C and D

Scenario No:

NRC 14-5 Event No.

7& 8


• All 4 Bypass valves CLOSED • 8 fans running in HIGH speed

• Starts 0C, 0D & 0G Fans 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.


• DGs – 1A DG running • Start 1B DG • 1SX169A/B OPEN. • Dispatch operator locally to check operation


BOP • Att B, Step 14: Verify Control Room ventilation aligned for emergency operations at 0PM02J: • VC Rad Monitors – LESS THAN HIGH ALARM SETPOINT. • Operating VC train equipment – RUNNING.

• 0A Supply fan • 0A Return fan • 0A M/U fan • 0A Chilled water pump • 0A Chiller

• Operating VC train dampers – ALIGNED. • M/U fan outlet damper – 0VC24Y NOT FULLY CLOSED. • 0A VC train M/U filter light – LIT. • 0VC09Y - OPEN • 0VC313Y – CLOSED

• Operating VC train Charcoal Absorber aligned for train A. • 0VC43Y - CLOSED • 0VC21Y - OPEN • 0VC22Y – OPEN


BOP • Att B, Step 15: Verify Auxiliary Building ventilation aligned at 0PM02J: • Two inaccessible filter plenums aligned.

• Plenum A: • 0VA03CA - RUNNING • 0VA022Y - OPEN • 0VA020Y – CLOSED

• Plenum C: • 0VA03CF - RUNNING • 0VA072Y – OPEN • 0VA438Y – CLOSE


• 0VA04CA - RUNNING

Scenario No:

NRC 14-5 Event No.

7& 8


• 0VA060Y - OPEN • 0VA057Y - OPEN • 0VA051Y – CLOSED

BOP • Att B, Step 17: Maintain UHS Basin Level - >80% <Cont Action Step> • Att B, Step 18: Initiate periodic checking of Spent Fuel Cooling



o Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100-5 - May notify

WEC of this step

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.

simulation facility byron scenario no.: byron nrc 2014 n14-2

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