ML16116A337

Refer to BOP GC-5.

Start 1A stator water pump at 1PM02J.

Allow both pumps to run in parallel for 5 minutes (per step D.1).

o Notify EO to perform leak check at skid.

Stop 1B stator water pump at 1PM02J.

Notify EO to reset Hy/GC panel alarm

Inform SRO BOP GC-5 complete.

Monitor primary and secondary panels while BOP performing BOP GC-5.

Provide support as requested to BOP.

Acknowledge report.

o Notify SM BOP GC-5 is complete.

EVALUATOR NOTE: After BOP GC-5 is complete and with lead examiners concurrence, enter next event.

Scenario NRC 16-1 Event 2 No: No.

Event

Description:

Power range N-44 fails high.

Time Position Applicants Actions or Behavior CUE

Annunciator PWR RNG FLUX RATE RX TRIP ALERT (1-10-C3)

Annunciator PWR RNG CHANNEL DEV (1-10-C4)

Annunciator PWR RNG FLUX HIGH ROD STOP (1-10-B5)

Annunciator PWR RNG HIGH STPT RX TRIP ALERT (1-10-A3) o Control rod inward motion RO/

Implement BHC for Uncontrolled Rod Motion.

Ensure turbine power is stable

Place control rods in MANUAL.

o Reference BARs as time permits SRO

Implement 1BOA ROD-1, Uncontrolled Rod Motion

Identify PR N-44 failure

Notify SM to evaluate for E-plan SRO

Implement 1BOA INST-1, NUCLEAR INSTRUMENTATION MALFUNCTION, Attachment A "PR CHANNEL FAILURE" and direct operator action

Notify SM of PR N-44 failure

Notify SM to evaluate for E-plan RO/

Check rod control status BOP

Rod bank select switch in manual

Check for rod stop

Annunciator PWR RNG FLUX HIGH ROD STOP (1-10-B5) - LIT

Place rod stop bypass switch to N-44 at 1PM07J RO

Verify/restore TAVE - TREF to within 1°F o Withdraw control rods o Adjust RCS boron concentration o Adjust turbine load BOP

Check SG levels normal and stable BOP

Bypass/defeat PR channel functions at 1PM07J

N-44 upper current comparator

N-44 lower current comparator

N-44 power mismatch bypass o N-44 rod stop bypass

N-44 channel current comparator BOP

Reset PR Flux Rate Rx Trip Alert RO/

Place computer points in test BOP

N0047

N0048

U1143 (continued)

Place computer point in removed from scan - may use BOP CX-14

N0052A

Place NIS input to DEH - IN TEST (Graphic 5515)

Contact SM/WEC to have bistables BYPASSED o Notify SM or WEC to have bistables TRIPPED and BYPASS restored to normal.

Scenario NRC 16-1 Event 2 No: No.

Event

Description:

Power range N-44 fails high.

Time Position Applicants Actions or Behavior SRO

Direct Loop T recorder selected to operable channel RO

Check if rod control can be placed in auto

C-5 (1-BP-5.7) NOT LIT

TAVE - TREF within 1°F

Place control rods in auto SRO

Determines TS 3.3.1 conditions A, D, and E are applicable.

o Enter degraded equipment log for P-10 & P-8

Contact SM to perform risk assessment, initiate IR, evaluate reactivity screening, make notifications and contact appropriate personnel to investigate/correct instrument failure.

EVALUATOR NOTE: After the actions for N-44 are complete and with lead examiner concurrence, enter next event.

Scenario NRC 16-1 Event 3 No: No.

Event Raise power at 0.4 MW/min

==

Description:==

Time Position Applicants Actions or Behavior CUE o Call from Power Team to raise power to 880 MW at 0.4 Mw/min.

Acknowledge request to raise power to 880 MW at 0.4 Mw/min.

Implement actions of 1BGP 100-3.

Perform pre-job brief for load ramp.

Direct raising load to 880MW at 0.4 MW/min.

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

CREW

Review applicable Precautions, and Limitations and Actions.

Verify rod position and boron concentration.

Initiate dilution as required (BOP CV-5).

Determine required PW volume: (approximate band: 2500 gal - 3000 gal).

Effects of previously performed dilutions.

Byron Boration Dilution Tables.

Determine required PW flow rate.

Perform the following at 1PM05J:

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

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

Place MAKE-UP CONT SWITCH to STOP position.

Set MODE SELECT to DIL/ALT DIL position.

Place MAKE-UP CONT Switch to START.

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

Turn on PZR backup heaters.

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

Select SETPOINT.

Enter 0.4 MW/min into the RATE window.

Select ENTER.

Enter 880 MW into REF DEMAND window.

Select ENTER.

Select EXIT.

o Notify SRO 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/

Monitor reactor power and load ascension:

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

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

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

VCT level.

RCS Tave rising/RCS boron concentration lowering.

PW/Total flow predet counter responding correctly.

Verify dilution auto stops at preset value.

Return Reactor Makeup System to automatic.

Scenario NRC 16-1 Event 3 No: No.

Event Raise power at 0.4 MW/min

==

Description:==

Time Position Applicants Actions or Behavior EVALUATOR NOTE: After measurable change in power and lead examiner approves, initiate the next event.

Scenario NRC 16-1 Event 4 No: No.

Event 1A CC pump trip with failure of 1B CC pump to automatically start

==

Description:==

Time Position Applicants Actions or Behavior EVALUATOR NOTE: Crew MAY enter 1BOA Pri-6, but per BAR 1-2-A4, entry into 1BOA Pri-6 is NOT required if CC flow is restored.

CUE

Annunciator 1-02-A4, CC Pump Trip Alarm LIT

1A CC pump control switch AMBER light LIT

1B CC pump does NOT automatically start BOP o Check BAR 1-2-A4 SRO o Direct actions to restore CC flow IAW BAR 1-2-A4 SRO o Enter 1BOA Pri-6, CC System Malfunction and direct the actions of:

o Step 1: Check CC surge tank level o Step 2: Check system status - Start 1 CC pump o Step 3: Check system temperature o Step 4: Check RCP temperature o Step 5: Check Letdown temperature o Step 6: Check CC system status BOP

Start 1B CC Pump o Place 1A CC Pump to PTL BOP/ o Dispatch EO to check 1A CC Pump for cause of failure RO o Dispatch EO to check 1B CC Pump for proper operation RO o Review BARs o Monitor primary and secondary panels as BOP responds to CC malfunction SRO

Evaluate TS 3.7.7, Condition B o Direct U0 CC Pump to be aligned to replace 1A CC Pump o Exit TS 3.7.7 Condition B o Evaluate 1B CC pump as degraded SRO

Notify SM of malfunction, TS evaluation, request IR and E plan evaluation EVALUATOR NOTE: After the actions for the CC malfunction are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-1 Event 5 No: No.

Event

Description:

1PT-CV131 fails low Time Position Applicants Actions or Behavior CUE o Annunciator LP LTDWN RLF TEMP HIGH (1-9-B1)

1FI-132, letdown line flow, lowering.

1PI-131, letdown line pressure, lowering.

CREW

Refer to BARs

Recognize 1PT-131 failed low.

Implement BHC for Letdown Malfunction

Direct/Ensure RO takes manual control of 1PK-131 and returns letdown pressure to normal.

Inform SM of 1PT-131 failure.

o Direct BOP/RO to stop load ramp/dilution.

o Direct RO to isolate letdown.

Implement BHC for Letdown Malfunctions.

Perform the following at 1PM05J:

Place 1PK-131, letdown line pressure control valve, in manual.

Raise demand on 1PK-131.

Lower letdown line pressure sufficiently to close letdown line relief valve and restore letdown flow to normal.

Maintain letdown flow and pressure by operating 1PK-131 in manual.

Refer to BARs

Support RO by monitoring panels and providing assistance as requested.

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

EVALUATOR NOTE: The crew may elect to isolate letdown based on letdown relief valve lifting or loss of letdown pressure indication. The steps for isolating letdown and restoring normal letdown are in italics on the next page.

EVALUATOR NOTE: The crew may elect to place excess letdown on line due to the loss of letdown pressure indication. The steps for placing excess letdown on line are in italics on the next page.

Scenario NRC 16-1 Event 5 No: No.

Event

Description:

1PT-CV131 fails low Time Position Applicants Actions or Behavior RO/ o Isolate letdown BOP o Close 1CV8149A, B, & C o Close 1CV459 & 1CV460 o Place 1CV121 in manual and control RCP seal injection 8-13 gpm per RCP o Close 1CV8105/8106 o Monitor RMCS during automatic VCT makeup o Proper flow indicated on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110).

RO/ o Establish normal letdown per 1BOA ESP-2 (or BOP CV-17)

BOP o Verify/close 1CV8149A/B/C and 1CV459 and 1CV460 o Verify/open 1CV8401A/B, 1CV8324A/B and 1CV8389A/B o Verify/open 1CV8152/8160 o Check BTRS MODE SELECTOR switch is OFF o Place 1CV131 manual at 40% demand o Place 1CC130 in manual at 60% demand o Verify/open 1CV8105/8106 o Adjust charging flow to approx. 100 gpm w/seal injection 8-10 gpm per RCP o Open 1CV459/460 o Open 1CV8149A/B/C and control 1CV131 to maintain letdown pressure 360-380 psig o Control 1CC130 to maintain letdown temperature 90-115°F o Place controllers in auto o Verify 1PR06J in service RO/ o Establish excess letdown per BOP CV-15 BOP o Verify open 1CV8100 and 1CV8112.

o Open 1CC9437A & B.

o Verify close 1HCV-CV123.

o Place 1CV8143 to VCT o Direct EOs to open 1CV8482 and close 1CV8484.

o Open 1RC8037A, B, C, & D.

o Open 1CV8153A & B.

o Open 1HCV-CV123 and maintain excess letdown outlet temperature < 165°F.

RO o Verify proper operation of RMCS during VCT makeup o Proper flow indicated on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110).

o Restore PZR level to program EVALUATOR NOTE: Initiate the next event when the lead examiner approves.

Scenario NRC 16-1 Event 6 No: No.

Event

Description:

1FW540 oscillating Time Position Applicants Actions or Behavior CUE

Annunciator 1-15-D4, S/G 1D FLOW MISMATCH STM FLOW LOW

Annunciator 1-15-D9, S/G 1D LEVEL DEVIATION HIGH LOW

1D SG level OSCILLATING BOP

Implement BHC for Steam Generator Level.

Place 1FW540 in MANUAL

Control feedwater flow

Balance feedwater flow with steam flow to restore and stabilize SG level SRO

Direct BOP to manually control 1D SG level

Notify SM for IR RO o Monitor primary plant for reactivity effects o Review BARs EVALUATOR NOTE: After the actions to control feedwater flow are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-1 Event 7 No: No.

Event

Description:

1FW540 Failed Closed/Unit 1 Reactor Trip Time Position Applicants Actions or Behavior CUE

Annunciator 1-15-D4, SG 1D Flow Mismatch FW Flow Low Alarm LIT

1FW540 TSLB light LIT

1D SG level lowering CREW

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

Order U-1 Reactor trip

Notify SM of plant status and procedure entry

Request evaluation of Emergency Plan conditions

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

Step 1: Verify reactor trip

Rod bottom lights - ALL LIT

Reactor trip & Bypass breakers - OPEN

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

Step 2: Verify Turbine Trip

All Turbine throttle valves - CLOSED

All Turbine governor valves - CLOSED

Step 3: Verify power to 4KV busses

ESF Buses - BOTH ENERGIZED (141 & 142)

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 SRO

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

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior EVALUATOR NOTE: The next malfunction (LOCA) may now be inserted.

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%

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 EVALUATOR NOTE: If LOCA is inserted, Pzr pressure will be dropping rapidly BOP

Step 5: Check FW status

If RCS < 564°F, verify FW isolation complete and trip running MF pumps CUE

Pzr pressure and level - LOWERING

CNMT pressure - RISING SRO

Transition to 1BEP-0

Notify SM of procedure entry

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

Direct crew to reperform 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 - RUNNING o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J CREW

Determine RCP trip required

[CT-16] o RCS pressure < 1425 psig & High head SI flow (1FI-917) > 100 gpm o TRIP ALL RCPs SRO o Step 5: Direct BOP to perform Attachment B of 1BEP-0 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

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B, SI Verification.

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

RO/

Att B, Step 1: Verify ECCS pumps running BOP

Both CV pumps - RUNNING

[CT-7]

Both RH pumps - RUNNING

Neither SI pump - RUNNING

Manually start 1B SI pump prior to completion of step 6 of 1BEP-0 (CT-7).

o Place 1A SI pump in pull out BOP

Att B, Step 2: Verify ECCS valve alignment

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

o Verify MSIV and Bypass Valves - CLOSED

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

CNMT pressure > 8.2 psig.

MSIVs and bypass valves - CLOSED o MAY actuate MSLI in anticipation of reaching MSLI setpoint of 8.2 psig.

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.

o Group 6 CS monitor lights - ALL LIT.

o Group 6 phase B lights - ALL LIT.

o Verify/Stop ALL RCPs (at 1PM04J).

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

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

o Align SX Cooling Towers o All 8 riser valves - OPEN

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior o All 4 Hot Water Basin Bypass valves - CLOSED o All 8 SX Cooling Tower Fans - HIGH SPEED BOP

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

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

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

Trip all running HD pumps.

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

DGs - BOTH DG running

1SX169A/B OPEN.

Dispatch operator locally to check operation

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

OCB 1-8 and 7-8 open.

PMG output breaker open.

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

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0B Supply fan

0B Return fan

0B M/U fan

0B Chilled water pump

0B Chiller

Operating VC train dampers - ALIGNED.

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

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

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED

0VC05Y - OPEN

0VC06Y - OPEN

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

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

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CB - RUNNING

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

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

0VA04CB - RUNNING

0VA055Y - OPEN

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior

0VA062Y - OPEN

0VA435Y - CLOSED BOP

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

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

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

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

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

1RY455 & 1RY456 CLOSED

PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED

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

Normal PZR Spray Valves CLOSED RO

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

Verify RCS average temperature stable at or trending to 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 RCPs - NONE RUNNING.

o Any RCPs still running - TRIP All RCPs RO

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

Check pressure in all SGs:

None dropping in an uncontrolled manner.

None completely depressurized.

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

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior 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

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

1PR08J SG Blowdown

1PR27J SJAE/GS

1AR22/23A-D Main steam line RO

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

PORV isol valves - BOTH ENERGIZED

PORV relief path - BOTH PORVs in AUTO, 1RY8000A & B - OPEN CREW

Step 6: Check if ECCS flow should be reduced

RCS subcooling - NOT acceptable

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 > 325 psig & stable

Stop both RH pumps and place in standby CREW

Step 9: Check for faulted SG

Pressure in all SG stable or rising

RCS pressure stable or dropping CREW

Step 10: Check if DGs should be stopped

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

Evaluate equipment for long term recovery

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

Step 12: Check if RCS cooldown and depressurization is required

RCS pressure - Greater than 325#

Go to 1BEP ES-1.2, Post LOCA Cooldown and Depressurization

Scenario NRC 16-1 Event 8&9 No: No.

Event

Description:

LOCA / SI pump failure Time Position Applicants Actions or Behavior SRO

Notify SM of plant status and procedure entry

Request evaluation of Emergency Plan conditions

Enter 1BEP ES-1.2 EVALUATOR NOTE: When the Crew enters 1BEP ES-1.2, conclude the scenario.

Simulation Facility Byron Scenario No.: Operating Test No. 2016 Byron NRC N16-2 Examiners: ______________________ Applicant: ____________________ SRO

______________________ ____________________ RO

______________________ ____________________ BOP Initial Conditions: IC-18 Turnover: Unit 1 is at 75% power, steady state, equilibrium xenon, MOL. CB D @ 180, Boron concentration is 945 ppm. Online risk is green. 1A MFP ALOP is running to support the 1B TDFP LO pump swap.

The 1B TDFPs 1A LO pump will be started and the 1B LO pump secured per BOP FW-10. Secure the 1A MFP ALOP per BOP FW-8 step F.18. SM has given an exception to BOP FW-10 Precaution 2, allowing running only the 1A MFP ALOP versus the entire 1A MFP.

Event No. Malf. No. Event Event Type* Description 1 N (BOP, TDFP LO pump swap SRO) 2 MF CV23B 50 C (RO, 1B LD HX tube leak SRO)

TS (SRO) 3 MF MS04B 100 C (BOP, 1B SG PORV spurious open SRO) TS (SRO) 4 MF TH03C 15 R (RO, 1C SGTL with power reduction required SRO)

TS (SRO)

C (BOP) 5 MF CV09 50 I (RO, SRO) 1TI 130 failed Low 6 MF TH03C 400 M (ALL) 1C SGTR 7 MF ED04B M (ALL) LOOP requiring Natural Circ CD using SG PORVs

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

SCENARIO OVERVIEW Unit 1 is at 75% power, steady state, equilibrium xenon, MOL. CB D @ 180, Boron concentration is 945 ppm. Online risk is green. 1A MFP ALOP is running to support the 1B TDFP LO pump swap. The 1B TDFPs 1A LO pump will be started and the 1B LO pump secured per BOP FW-10. Secure the 1A MFP ALOP per BOP FW-8 step F.18. SM has given an exception to BOP FW-10 Precaution 2, allowing running only the 1A MFP ALOP versus the entire 1A MFP.

After completing shift turnover and relief, the crew will swap running 1B TDFP LO pumps using BOP FW-10.

After normal operation, the 1B LD HX develops a tube leak. The crew will enter 1BOA Pri-6 to address the tube leak and swap letdown heat exchangers.

After the letdown heat exchangers have been swapped, 1B SG PORV will spuriously open in AUTO, requiring manual closure.

After the 1B SG PORV failure has been addressed, a SGTL develops in the 1C SG at 15 GPM, which then step increases to 30 GPM. The crew enters 1BOA Sec-8 and determines that a power reduction to 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is required.

After the ramp has begun, 1TI130 fails low, diverting letdown around the demineralizers. The crew will manually control letdown temperature.

After letdown temperature is stabilized, 1C SGTL will suddenly rupture to 400 gpm. The crew will enter 1BEP-0, trip the reactor and initiate safety injection.

While cooling down the plant in 1BEP-3, the station SAT will fault and offsite power will be lost. The crew will continue the cooldown on natural circulation using the SG PORVs.

Completion criteria is completion of SI termination step 24 in 1BEP-3.

Critical Tasks

1. Isolate feedwater flow into and steam flow from the ruptured SG before a transition to ECA-3.1 occurs (ERG Critical Task number - CT-18) (K/A number - EPE038EA1.32. importance - 4.6/4.7)

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

Too high to maintain minimum required subcooling OR

Below the RCS temperature that causes an extreme (red-path) or a severe (orange-path) challenge to the subcriticality and/or the integrity CSF (ERG Critical Task number - CT-19) (K/A number - EPE038EA1.36 importance - 4.3/4.5)

3. Depressurize RCS to meet SI termination criteria (RCS pressure < ruptured SG pressure AND Pzr level >12%, OR Pzr level > 69%, OR RCS subcooling NOT acceptable) before the ruptured SG safety valve opens.

(ERG Critical Task number - CT-20) (K/A number -EPE038EA1.05. importance - 4.1/4.3)

References BOP FW-10 1BEP-0 BOP FW-8 1BEP-3 1BOA Pri-6 1BOA Sec-8

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 18, 75% power, MOL, steady state, equilibrium xenon.

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

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

Verify Simulator Readiness Checklist is completed.

Start the 1A MFP ALOP 1FW01PA-B.

Place Turnover on the Unit Desk.

Run caep N16-2 from thumb drive and verify the following actions load in the caep:

Byron 2016 NRC 16-2l00:00:00l0 Event 2: LD HX leakl00:00:00l1 IMF CV23B 50l08:00:00l2 Event 3: 1B SG PORV openl00:00:00l4 IMF MS04B 100l08:00:00l5 Event 4: 1C SGTLl00:00:00l7 IMF TH03C 25l08:00:00l8 Event 5: 1TI130 failed lowl00:00:00l11 IMF CV09 50l08:00:00l12 Event 6 & etcl00:00:00l14 MMF TH03C 400l08:00:00l15 To close 1AF005C & G locallyl00:00:00l17 mrf fw163 0l08:00:00l18 mrf fw194 0l08:00:00l19 After cooldown has begunl00:00:00l21 IMF ED04Bl08:00:00l22

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: 1B TDFP LO Pump Swap As EO, if asked, report 1B TDFP oil reservoir level is 20.

Event 2: Letdown Heat Exchanger Leak IMF CV23B 50 to insert a 50 GPM in the 1B letdown heat exchanger.

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

As EO, drain the CC surge tank as requested using RF CC15 and CC16 as needed (SMDG CC2)

To open 1A LD HX inlet valve 1CC9452A MRF CC37 100 (outlet valve 1CC9452B RF CC40 is normally open) (SMDG CC6)

To close 1B LD HX inlet valve 1CC9452C MRF CC39 0; 1CC9452D MRF CC43 0 (SMDG CC6)

As SM, if the crew isolates LD and does not swap LD HX (ie, in case they placed excess letdown HX on line), direct the crew to place letdown in service for Chemistry cleanup.

Event 3: 1B SG PORV Spuriously Open in Auto IMF MS04B 100 to open the 1B SG PORV in Auto.

At evaluators discretion, Security Officer calls to report steam issuing from a pipe near U-1 Containment.

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

Event 4: 1C SGTL with power reduction required IMF TH03C 25 to insert a 25 GPM SGTL.

As Field Supervisor, acknowledge request to perform BOP MS-11, Operation with SG Tube Leakage As SM, acknowledge procedure entry, TS entry, request for writing IR, performing risk assessment and making appropriate notifications.

As RP, acknowledge request by shift to monitor radiation levels and initiate BRP 5820-13, Response to High Radiation Monitors, and 0BCSR 11.i.1-1, Gaseous Radwaste Treatment Effluents Dose Calculation - Monthly.

If contacted as RP or Chemistry, report the leak rate confirmed (at the rate inserted).

As SM, authorize power ramp per 1BGP 100-4T1.1 and shutdown.

Event 5: 1TI130 Failed Low Insert IMF CV09 50 to fail 1TI130 low.

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

As EO, report temperature if asked using local indicator 1TI129 (SMDG CV2)

Event 6 & 7: 1C SGTR with LOOP and natural circulation cooldown.

MMF TH03C 400 to insert a 400 1C SGTR.

SM acknowledge procedure entry and E Plan evaluations, and STA request.

After STA requested, as STA report CSF status.

As EO, close 1AF005C & G locally using mrf fw163 0 & mrf fw194 0.

As EO, acknowledge order to standby 1SI101A & B with keys.

IMF ED04B to cause a failure of the U-1 SATs after the cooldown has been started in Step 6, and before Step 9.

When SAT fire alarm comes in, notify the crew that Unit 2 Assist will take the MCR actions.

As TR EO, report there is no fire, but deluge is actuated on the U-1SATs.

Scenario NRC 16-2 Event 1 No: No.

Event

Description:

1B TDFP LO Pump Swap Time Position Applicants Actions or Behavior CUE

Swap 1B TDFP LO pumps Crew

Locate and open BOP FW-10 BOP

Start standby AC LO pump

Wait at least 30 seconds

Secure running AC LO pump RO

Monitor primary panels and assist BOP as required RO/

Secure 1A MFP ALOP per BOP FW-8 Step F.18, Shutdown of a Motor Driven Feedwater Pump BOP EVALUATOR NOTE: When pump swap is complete, go to the next event.

Scenario NRC 16-2 Event 2 No: No.

Event

Description:

Letdown Heat Exchanger Leak Time Position Applicants Actions or Behavior CUE

Letdown line flow lowering

Annunciator 1-2-A5, CC SURGE TANK LEVEL HIGH LOW LIT

0/1PR09J in ALARM

1CC017 closed Crew

Enter 1BOA Pri-6, Component Cooling Malfunction SRO

Notify SM of failure, request E Plan evaluation and IR.

Check CC surge tank level >13%

Check surge tank level-NOT stable

Refer to BAR for 0/1PR09J SRO

Implement Attachment B of 1BOA Pri-6 BOP

Check surge tank level -NOT dropping

Check for inleakage from RCP thermal barrier

NEITHER 1-7-E4 LIT NOR seal injection flow abnormally high SRO

Direct isolation of CC system inleakage

Determine inleakage from letdown HX o Direct letdown isolation

Direct swap of LD HX

Evaluate TS 3.4.13 condition A.

RO/ o Isolate letdown (Crew may choose not to isolate letdown, and swap LD HX on line)

Close 1CV8149A-C

Close 1CV459 and 1CV460

Control seal injection flow with 1CV121 EVALUATOR NOTE: If crew isolates letdown and does not swap LD HX, the SM will direct them to place letdown in service for Chemistry cleanup.

Swap inservice letdown HX PER BOP CV-22

Direct EO to Verify/Open 1CC9452B

Verify 1CC130A/B not fully closed

Direct EO to vent the 1A LD HX

Direct the EO to slowly open 1CC9452A and verify CC flow locally

Direct EO to Verify/open 1CV8467A

Direct EO to close 1CV8467B

Open 1CV8401A

Close 1CV8401B

Direct EO to close 1CC9452C o Direct EO to close 1CC9452D EVALUATOR NOTE: Leak will continue at ~.5 GPM unless 1B LD HX is isolated on the CV side.

Crew o Direct EO to lower CC surge tank level using local drain valves EVALUATOR NOTE: Continue with next event when LD HX are swapped, or at the discretion of the lead examiner.

Scenario NRC 16-2 Event 3 No: No.

Event

Description:

1B SG PORV Spuriously Open in Auto Time Position Applicants Actions or Behavior CUE

1MS018B Position Indication OPEN

Increased steam flow At evaluators discretion, Security Officer calls to report steam issuing from a pipe near U-1 Containment.

Identify Open 1B SG PORV o Attempt to close 1B SG PORV in MANUAL

Close 1B SG PORV with Close switch RO

Monitor primary panels for reactivity effects.

Notify SM of failure, request E Plan evaluation and IR.

TS 3.7.4 Condition A not met since PORV will not open on demand and cannot be controlled by the controller.

EVALUATOR NOTE: When the SG PORV is closed, continue with the next event, or at the discretion of the lead examiner.

Scenario NRC 16-2 Event 4 No: No.

Event

Description:

1C SGTL with power reduction required Time Position Applicants Actions or Behavior CUE

Annunciator 1-16-A5 SG TUBE LEAK RATE EXCEEDED

1AR022/23 in ALARM BOP o Refer to BAR 1-16-A5 o Refer to RM-11 BAR Crew o Notify Chemistry to sample 1C SG for activity o Notify RP to perform RP-BY-700-1006 SRO

Enter 1BOA Sec-8, SGTL

Notify SM for procedure entry, EP evaluation Evaluate TS for primary-secondary leakage: TS 3.4.13, Condition B after the leak rate has been determined.

RO o Establish 75 GPM letdown (as needed to maintain Pzr level)

Crew

Minimize secondary contamination

Notify WEC/Field Supervisor to perform BOP MS-11

Notify RP to monitor radiation levels and initiate dose calculation

Identify leaking SG

Determine SG tube leak rate (to be approximately 25 GPM)

Confirm SG leak rate (@ step 9) with 2 independent indications.

Crew

Initiate Unit Shutdown

Determine leak rate is rising > 100 GPD per step 10

Determine need to reduce power to < 50% within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Implement 1BGP 100-4T1.1 for a fast ramp

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

Direct RO to borate in accordance with ReMa

Direct BOP to ramp in accordance with 1BGP 100-4T3.

Verify rod position and boron concentration.

Initiate boration as required. (BOP CV-6)

Determine required boric acid volume.

o Perform boration boundary calculation per 1BGP 100-4T3.

o Refer to Rema for ramp.

Determine desired boric acid flow rate.

Perform the following at 1PM05J:

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

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

Select SETPOINT.

Enter 600 MW into REF DEMAND window

Select ENTER.

Enter 10 MW/min into the RATE window. (or a rate that will lower power to <50% in remaining time)

Select ENTER.

Select EXIT.

Scenario NRC 16-2 Event 4 No: No.

Event

Description:

1C SGTL with power reduction required Time Position Applicants Actions or Behavior o Notify SRO and RO of pending ramp.

Select GO/HOLD.

Verify GO/HOLD button illuminates.

Verify HOLD illuminated RED.

Select GO.

Verify GO illuminates RED.

Verify main turbine load begins to lower.

Coordinate ramp with boration by RO.

EVALUATOR NOTE: After ramp has begun, continue with next event, or at lead evaluators discretion.

Scenario NRC 16-2 Event 5 No: No.

Event

Description:

1TI130 Failed Low Time Position Applicants Actions or Behavior CUE o Annunciator 1-9-E2, LETDOWN TEMP HIGH LIT o 1CV129 diverted to VCT

1TK130 at minimum demand RO/

Take manual control of 1TK130 and raise demand BOP Crew o Dispatch EO to locally report letdown temperature BOP/

Monitor panels and assist other operator as required.

RO SRO

Notify SM of failure, request E Plan evaluation and IR.

NOTE: Crew may isolate letdown per BHC for Letdown Malfunctions, and may also put on excess letdown. Steps for each follow in italics.

To isolate letdown

Close 1CV8149A/B/C

Close 1CV459/460 To place excess letdown in service per BOP CV-17

Verify/open 1CV8100 & 1CV8112

Open 1CC9437A/B

Verify closed 1CV123

Open 1RC8037A/B/C or D

Open 1CV8153A or B

Open 1CV123 while maintaining outlet temp <165° EVALUATOR NOTE: When High Temp alarm clears or at lead examiners discretion, continue with next event.

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior CUE

1C SG FF < SF

Lowering Pzr level and pressure

1C MSL Radiation Monitor in Alert/Alarm SRO

Order U-1 Reactor trip and safety injection

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)

RO/

Manually actuate Safety Injection BOP CREW

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

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J SRO

Step 5: Direct BOP to perform Attachment B of 1BEP-0 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 - 1C RISING UNCONTROLLED; 1C SG Rad

[CT-18] level is rising

Close 1AF13C & G (CT-18; may be performed in BEP-3)

EVALUATOR NOTE: SRO and RO will continue in 1BEP-0 while BOP is performing Attachment B, SI Verification.

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

Att B, Step 1: Verify ECCS pumps running

CV pumps - BOTH RUNNING

RH pumps - BOTH RUNNING

SI pumps - BOTH RUNNING BOP

Att B, Step 2: Verify ECCS valve alignment

Determine Group 2 Cold Leg Injection monitor lights required for injection - ALL LIT

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior 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 - 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.

o Verify MSIV and Bypass Valves - CLOSED

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

CNMT pressure < 8.2 psig.

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 - 1FW002A-C CLOSED

Trip all running HD pumps.

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

DGs - BOTH DG running

1SX169A & B OPEN.

Dispatch operator locally to check operation

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

OCB 3-4 and 4-5 open.

PMG output breaker open.

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

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

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 - 0VC024Y NOT FULLY CLOSED.

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior

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

0VC025Y - OPEN

0VC312Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED

0VC05Y - OPEN

0VC06Y - OPEN

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

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

Two inaccessible filter plenums aligned.

Plenum A:

0VA03CB - RUNNING

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

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

0VA04CB - RUNNING

0VA055Y - OPEN

0VA062Y - OPEN

0VA435Y - CLOSED 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 SRO of actions taken, equipment status, CAS ownership and that Attachment B is completed o Att B, Step 20: Shutdown unnecessary equipment per 1BGP 100-1T4 and 100 May notify WEC of this step EVALUATOR NOTE: 1BEP-0 main body continues here.

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

1RY455 & 1RY456 CLOSED

PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED

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

Normal PZR Spray Valves CLOSED RO

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

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

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

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior

MSIVs closed RO

Step 9: Check status of RCPs at 1PM05J:

o All RCPs - NONE RUNNING.

o Any RCPs still running - TRIP All RCPs RO

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

Check pressure in all SGs:

None dropping in an uncontrolled manner.

None completely depressurized.

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

o 1PR08J SG Blowdown.

o 1PR27J SJAE/GS. - IN ALERT/ALARM o 1AR22/23A-D Main steam Lines. - Trending up or in ALERT/ALARM CREW Transition to 1BEP-3, Steam Generator Tube Rupture SRO Implement 1BEP-3 "STEAM GENERATOR TUBE RUPTURE and direct operator actions.

Notifies SM of BEP entry

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

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

RCS pressure > 1425 psig CREW Identify ruptured SG Unexpected rise in NR level Main steamline rad monitor 1RT-AR022 Grid 1 4AC322 1RT-AR023 Grid 1 4AC323 High activity for any SG sample

Reset CNMT isol Phase A

Notify Chem to locally sample

Open SG blowdown sample valves at Chem request

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

SG PORV MS018C in AUTO

Check SG PORV MS018C closed

Verify closed when SG pressure < 1115 psig

Verify SG blowdown valves closed unless open for sampling

1SD002G

1SD002H

[CT-18]

Close MSIV and MSIV bypass valves for 1C SG (CT-18)

Check PORVs on intact SGs available for RCS cooldown (note that 1B PORV COULD be used if necessary)

BOP Check ruptured SG level

Narrow Range >10%

[CT-18]

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

1AF013C

1AF013G BOP Check ruptured SG pressure

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior

Ruptured SG pressure greater than 320 psig Crew

Initiate RCS cooldown

Determine required CETC from table (step 6a)

RO/

Check Pzr Pressure - >1930 #

When < 1930#, block Steamline Isol SI BOP

Dump steam to condenser from intact SG at maximum rate

Check steam dumps available

Place MS controller in Manual, reduce demand to 0

Select Steam Pressure Mode

Adjust MS controller to initiate cooldown Crew

Check average of 10 highest CETC - < required temperature from step 6a EVALUATORS NOTE: When cooldown has been established using steam dump valves and P-12 is bypassed, offsite power is lost, requiring cooldown to be resumed on Natural Circ using SG PORVs.

Crew

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

CUE

Loss of U-1 SAT

Loss of power to non-ESF busses

DGs start and load ESF busses EVALUATORS NOTE: If SI was reset before the LOOP occurred, the crew must manually restart the SI & RH pumps.

CREW

Identify loss of offsite power

Verify required equipment restarts on DG sequencer BOP

Dump steam from 1A and 1D SG PORVs using manual control of MA station and

[CT-19] establish/maintain RCS temperature below the determined target temperature. (CT-19)

Check intact SG levels > 10%

Control FF to maintain NR levels 30 - 50%

Check Pzr PORVs and isolation valves

PORV isolation valves energized

PORVs closed

PORV isolation valves both open RO/

Reset SI BOP

Verify SI actuated permissive light NOT LIT

Verify Auto SI blocked light LIT RO/

Reset Phase A isolation BOP Crew

Verify NOT all AC busses energized by offsite power BOP

Establish IA to containment

Check SACs- any running

Open 1IA065 and 1IA066

Scenario NRC 16-2 Event 6&7 No: No.

Event

Description:

1C SGTR with LOOP and natural circulation cooldown.

Time Position Applicants Actions or Behavior 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 for plant conditions CREW

Check RCS subcooling - acceptable RO/

Depressurize RCS BOP

Normal Spray - NOT available RO

Depressurize RCS using Pzr PORV

[CT-20]

Both PORVs available

Open 1 PORV until (CT-20) o RCS Pressure < Ruptured SG pressure and Pzr level > 12%

o Pzr level > 69%

o RCS subcooling NOT acceptable

Close Pzr PORV

Check spray valves and aux spray closed CREW

Check RCS pressure - rising EVALUATOR NOTE: When the CREW determines RCS pressure is rising, conclude the scenario.

(FINAL)

Simulation Facility Byron Scenario No.: Operating Test No.: 2016 Byron NRC NRC 16-3 Examiners: Applicant:

______________________ ____________________ SRO

______________________ ____________________ RO

______________________ ____________________ BOP Initial Conditions: IC-14 Turnover: Unit 1 is at 12% power, BOL, ready to synchronize Main Generator. Online risk is green. CBD @ 132 steps, and boron concentration is 1285 ppm. 1BGP 100-3, step F.27 is the next step to perform.

Steam dump demand must be raised to 25% to 35% as directed by step 23.p. The offgoing shift has just diluted 150 gallons.

Event Malf. No. Event Event No. Type* Description Preload IMF RP15A 1A CV pump auto start failure MRF RP83 OPEN 1B CV pump trip trgset 2 "zlobyan14 > 0" trg 2 "IMF CV01b" IMF MS01A 100 1A MSIV failed open 1 R (RO, Power ascension SRO) 2 N (BOP, Synchronize Main Generator to grid SRO) 3 IMF RX13A 0 15 I (RO, SRO) Pressurizer level channel 1LT-459 fails low (Tech Spec)

TS (SRO) 4 IMF RX30A 65 60 40 I (BOP, 1FW510A, 1A SG FWRV Bypass valve controller failure SRO) 5 MRF ED052A OPEN C (RO, Loss of power to Pzr Heater Groups B and C (Tech Spec)

SRO)

TS (SRO) 6 MRF SW38 OPEN C (BOP, 0B WS pump trip with 0A WS pump auto start failure IMF SW06B SRO) 7 IMF MS08A 4 120 M (ALL) Faulted 1A SG 8 Preload C (RO, 1B CV pump trips/1A CV pump fails to auto start.

SRO) 9 Preload 1A MSIV failed open

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

SCENARIO OVERVIEW Unit 1 is at 12% power, BOL, ready to synchronize Main Generator. Online risk is green. CBD @ 132 steps, and boron concentration is 1285 ppm. 1BGP 100-3, step F.27 is the next step to perform. Steam dump demand must be raised to 25% to 35% as directed by step 23.p. The offgoing shift has just diluted 100 gallons.

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

After power has been raised and the synchronization is complete, the controlling pressurizer level channel will fail low. Letdown will automatically isolate and the RO will take manual control of charging flow. 1BOA INST 2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment C, will be implemented. The RO will restore pressurizer level control to automatic after letdown is reestablished and pressurizer level is restored to normal.

Technical specification 3.3.1 conditions A and K will be entered. On line risk remains green.

After the pressurizer level channel failure has been addressed, the Feedwater Bypass valve controller on the 1A SG fails high. The BOP will take manual control of feedwater flow. The BOP will maintain feedwater flow control in manual. On line risk remains green.

After the feedwater controller failure has been addressed, the supply breaker to Groups B and C Pressurizer Heaters will trip and will not reset. The crew must enter TS 3.4.9, and energize a set of backup heaters to maintain RCS pressure in the normal band.

After the trip of the Pressurizer Heaters has been addressed, the 0B WS pump will trip, and the 0A WS pump will fail to automatically start on low WS header pressure, so the crew will manually start the 0A WS pump. Crew will enter 0/1BOA SEC-5 for the failure.

After the WS Pump trip has been addressed, the 1A SG steam line will fault outside containment, and the 1A MSIV will fail to close, automatically or manually. 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 secondary pressure boundary is not intact the crew will transition to 1BEP-2, FAULTED STEAM GENERATOR ISOLATION.

The crew will complete isolation of 1A SG and transition to 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT.

After the steam generator has blown dry, the crew will transition to 1BEP ES-1.1, SI TERMINATION.

The scenario is complete when the crew has stopped the RH pumps in step 10 of 1BEP ES-1.1.

Critical Tasks

1. Manually start the 1B CV pump prior to completion of Attachment B of 1BEP-0.

(ERG Critical Task number - CT-6) (K/A number - 013000A4.01 importance - 4.5/4.8)

2. Isolate 1A Steam Generator prior to exiting 1BEP-2.

(ERG Critical Task number - CT-17) (K/A number - APE040AA1.10 importance - 4.1/4.1)

References 1BGP 100-3 1BEP-0 1BOA INST-2 1BEP-2 1BOA ESP-2 1BEP-1 1BOA SEC-5 1BEP ES-1.1 0BOA SEC-5

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 14, 12% power, BOL, ready to synchronize Main Generator.

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

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

Verify Simulator Readiness Checklist is completed.

Start 0B WS pump and place 0A WS pump in standby.

Verify 1B CV pump is running and 1A CV pump is in standby.

Set main generator VPL to 25% on Graphic 5501.

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

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

Dilute 150 Gallons. Provide a boration/dilution log with 150 Gallons Dilution for Temperature Control to the oncoming crew. Provide 1BGP 100-3T1 initialed up to step 27.

Adjust MFWP DP to maintain SG levels as power rises.

Put Plant Display 13, AFD Summary, on 1PM05J right CRT.

Start a second CW Makeup Pump.

Run caep N16-3 from thumb drive and verify the following actions load in the caep:

Byron ILT NRC 16-3l00:00:00l0 Event 3: 1LT459 failed lowl00:00:00l2 IMF RX13A 0 15l08:00:00l3 Event 4: 1FW510A controller failurel00:00:00l5 IMF RX30A 65 60 40l08:00:00l6 Event 5: Loss of power to Pzr heatersl00:00:00l8 mrf ed052a openl08:00:00l9 Event 6: WS pump tripl00:00:00l11 imf sw06bl08:00:00l12 Event 7: 1A SG faultl00:00:00l14 imf ms08a 4 120l08:00:00l15 Setup filel00:00:00l20 IMF RP15Al00:00:01l21 MRF RP83 OPENl00:00:02l22 trgset 2 "zlobyan14 > 0"l00:00:03l23 trg 2 "IMF CV01b"l00:00:04l24 IMF MS01A 100l00:00:05l25 mrf sw38 openl00:00:06l26

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

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

Event 3: Pressurizer level channel 1LT-459 failed low.

Insert IMF RX13A 0 15 to fail 1LT-459 low over a 15 second period.

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

As assist NSO contact Unit 1 (X-2208)

Insert the following:

MRF RP20 OPEN (open protection cabinet #1 door)

MRF RX029 TRIP (trip PZR hi water level Rx trip bistable LB459A)

MRF RP20 CLOSE (close protection cabinet #1 door)

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 4: 1FW510A, 1A SG Feed Bypass Controller failure Insert IMF RX30A 65 60 40 to fail 1FW510A controller over a 60 second period. (note: final value, ramp time, initial value)

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

Event 5: Loss of power to Pzr Heater Groups B and C Modify MRF ED052A OPEN to open the feed breaker to Pzr Heater Groups B and C.

Acknowledge as SM the 1A HD pump trip, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation. Acknowledge LCO 3.4. entry.

If dispatched as EO, report breaker 144 Cubicle 3 is TRIPPED on ground overcurrent.

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 6: 0B WS pump trip with 0A WS pump auto start failure Ensure MRF SW38 OPEN is active (in preload) to prevent 0A WS pump auto start.

Insert IMF SW06B to trip the 0B WS pump.

If dispatched as EO, report 0B WS pump breaker is tripped on phase overcurrent.

As SM, acknowledge the failure, BOA entry, and requests for E Plan evaluations, on line risk assessment, maintenance support, and IR initiation.

Event 7: Faulted 1A SG Ensure MF MS01A (in preload) is active at 100 so the 1A MSIV is failed open.

Insert IMF MS08A 4 120 to fault the 1A SG steam line outside containment.

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

After STA requested, as STA report CSF status:

Event 8: 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.

Event 9: 1A MSIV failed open If requested as WEC or MM FLS, report the crew is unable to close the 1A MSIV.

Scenario NRC 16-3 Event 1 No: No.

Event

Description:

Power Ascension Time Position Applicants Actions or Behavior SRO

Direct power ascension per 1BGP 100-3

Approve reactivity changes for RO RO

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

o Dilute as necessary

Turn OFF RMCS Makeup CS

Select DILUTE on the RMCS Mode Select Switch

Enter the desired dilution amount in the PW Flow Totalizer

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

Select MANUAL

Withdraw control rods to desired height BOP

When steam dumps are closed (after generator synchronization), transfer control to Tave Mode

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

Place Mode switch to RESET then to Tave

Ensure C-7 is OFF

Place 1PK-507 in AUTO

Scenario NRC 16-3 Event 2 No: No.

Event

Description:

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

Direct BOP and RO to perform 1BGP 100-3

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

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

Close selected output breaker

Raise turbine power as necessary using graphic 5501

Adjust MVARS to about 100 MVAR OUT

Turn off Synch switch

Turn on remaining Synch switch

Close remaining output breaker

Turn off Synch switch

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

Verify TGTMS graphics are displayed

Set VPL to 120%

Select LIMITERS

Select VPL up arrow until 120% is reached

Select EXIT RO

Monitor primary and secondary panels while BOP is synchronizing the generator

Provide support as requested to BOP.

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

Continue with 1BGP 100-3

Initial flowchart SRO

Acknowledge reports

Placekeep procedure steps appropriately EVALUATOR NOTE: After the actions to synchronize the Main Generator are complete and with lead examiners concurrence, insert the next event. Insert next failure when Generator is at 100 MW.

Scenario NRC 16-3 Event 3 No: No.

Event Pressurizer level channel 1LT-459 fails low

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator PZR LVL LOW HTRS OFF LTDWN SECURED (1-12-A4)

Annunciator PZR HTR TRIP (1-12-A5)

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

PZR level indicators 1LI-460 and 461 rising.

RO o Implement BHC for Letdown Malfunction.

Identify 1LT-459 is failing low.

Identify letdown is isolated.

Report failure to SRO.

Perform the following at 1PM05J:

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

Lower demand on 1FK-121 OR 1LK-459 in conjunction with lowering demand on 1CV182 to lower charging flow to the minimum required for RCP seal injection.

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

o Select operable level channel per BAR 1-12-B4 CREW o Refer to BARs.

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

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 to establish the following conditions:

Check PZR level at 1PM05J:

PZR level - above program level

Verify/place 1FK-121 or 1LK-459 in manual and lower demand.

Select operable PZR level control channel:

Place PZR level control select C/S to CH-461/CH-460.

Select operable recorder at 1PM05J:

Place PZR level select switch to CH-460 or CH-461.

BOP/

Check letdown and PZR heaters at 1PM05J:

PZR level > 17%.

Letdown isolated.

Establish letdown per 1BOA ESP-2, REESTABLISHING CV LETDOWN DURING ABNORMAL CONDITIONS.

Restore PZR heaters to normal.

Verify PZR backup heaters in auto

Cycle PZR variable heater control switch to restore to auto.

EVALUATOR NOTE: The unit supervisor may elect to continue on in 1BOA INST-2 while the BOP reestablishes CV letdown per 1BOA ESP-2.

Restore normal letdown flow per 1BOA ESP-2, REESTABLISHING CV LETDOWN DURING ABNORMAL CONDITIONS.

Perform the following at 1PM05J:

Scenario NRC 16-3 Event 3 No: No.

Event Pressurizer level channel 1LT-459 fails low

==

Description:==

Time Position Applicants Actions or Behavior

Check Letdown Isolated:

Verify 1CV8149A, B, & C closed.

Verify 1CV459 & 1CV460 closed.

Manually close 1CV460

Check letdown flow path:

Verify 1CV8401A, 1CV8324A, 1CV8389A, 1CV8152, and 1CV8160 open.

Verify BTRS mode select switch OFF.

Align letdown controllers:

Place 1CV-131 in MANUAL and raise demand to 40%.

Place 1CV-130 in MANUAL and raise demand to 60%.

Verify charging flow established:

Verify 1CV8105 & 1CV8106 open.

Throttle 1CV182 and 1CV121 to establish 8-13 gpm seal inj and 100 gpm charging flows.

Establish letdown flow:

Open 1CV459 and 1CV460.

Open 1CV8149A/B/C to establish 120 gpm letdown.

Adjust 1CV131 controller to 360 psig and place in AUTO

Adjust 1CC130A/B controller to 90° to 115°F and place in AUTO

Verify 1PR06J in service at RM-11 console.

RO/

Check PZR level control in auto:

Place 1CV-121 and 1CV-459 in automatic when PZR level is restored to normal.

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/WEC for bistable to be BYPASSED

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

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

Scenario NRC 16-3 Event 4 No: No.

Event Feedwater flow controller for 1FW510A fails high

==

Description:==

Time Position Applicants Actions or Behavior CUE o Annunciator S/G 1A Level Deviation High Low (1-15-A9) o 1A SG FW flow indicators rising o FWRV Bypass Valve 1FW-520A opening o 1A SG level indicators rising BOP

Identify 1FW-510A controller output failing high

Refer to BARs

Report failure to SRO

Perform the following at 1PM04J

Place 1FW-510A in MANUAL

Lower FW flow to match or slightly lower than steam flow

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

Assist BOP as requested

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

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Maintain 1FW-510A in Manual and maintain 1A SG level at normal level EVALUATOR NOTE: After the actions for the feedwater flow controller failure are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-3 Event 5 No: No.

Event Loss of power to Pzr Heater Groups B and C

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator 1-12-A5 Pzr Heater Trip

Annunciator 1-12-C5 Phase Loss or Reversal

Annunciator 1-12-D5 Pzr Htr SCR Clg Fan Failure

Loss of power to B and C Pzr Heater contactors

ACB 1445 Disagreement/trip light

Slowly lowering RCS pressure RO

Recognizes supply to Pzr heater contactors B and C is tripped.

o Refer to BAR(s) for alarms listed above

Reports failure to SRO.

Places/verifies > 1 backup heater group in service as requuired o Dispatches EO to bus 144 to check breaker 1445 SRO

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

Enters TS 3.4.9, Condition B EVALUATOR NOTE: After the actions for the Pzr Heater trip are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-3 Event 6 No: No.

Event

Description:

0B WS pump trip with 0A WS pump auto start failure Time Position Applicants Actions or Behavior CUE

Annunciator WS PUMP TRIP OR AUTO START (0-38-A10)

Annunciator WS HDR PRESS LOW (0-38-B10)

Trip/yellow disagreement light on 0B WS Pump BOP

Identify/report trip of 0B WS pump o Refer to BAR(s) 0-38-A10/B10

Manually start 0A WS pump

Dispatch operator to 0B WS pump and breaker SRO

Direct operators to start 0A WS pump

Notify SM of 0B WS pump trip.

o Enter 0BOA SEC-5 / 1BOA SEC-5 for WS SYSTEM MALFUNCTION o Dispatch EO to check 0B WS pump - NOT ROTATING EVALUATOR NOTE: After the actions for the WS pump trip are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-3 Event 7, 8 & 9 No: No.

Event 1A SG fault, 1B CV pump trips/1A CV pump fails to auto start, 1A MSIV failed open

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator UNIT 1 AREA FIRE (1-37-A4).

RM-11 Rad Monitor ALERT/HI RAD Alarms.

1AR 22/23A & 1AR22/23D, 1A & 1D Main steam line.

Steam flow rising on all SGs

FIRE ALARM 1D-15 E VALVE ROOM RO

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

o Initiate a manual SI.

o Initiate a main steam line isolation SRO

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Enter/Implement 1BEP-0 and direct operator actions of 1BEP-0.

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

Verify reactor trip.

Rod bottom lights - ALL LIT.

Reactor trip & Bypass breakers - OPEN.

Neutron flux - DROPPING.

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

Verify Turbine Trip.

All Turbine throttle valves - CLOSED.

All Turbine governor valves - CLOSED.

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

Verify power to 4KV busses.

ESF Buses - BOTH ENERGIZED (141 & 142).

CREW

Check SI Status at 1PM05J/1PM06J:

o SI First OUT annunciator - LIT.

o SI ACTUATED Permissive Light - LIT.

o SI Equipment - AUTOMATICALLY ACTUATED.

o Either SI pumps - RUNNING.

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

(If manual SI not previously performed AND not automatically actuated)

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.

Recognize SI Actuated

Manually actuate SI from 1PM05J and 1PM06J

Manually actuate main steamline isolation SRO

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

Step 6: Verify AF system:

AF pumps - BOTH AF pumps RUNNING.

AF isolation valves - 1AF13A-H OPEN.

AF flow control valves - 1AF005A-H THROTTLED.

Scenario NRC 16-3 Event 7, 8 & 9 No: No.

Event 1A SG fault, 1B CV pump trips/1A CV pump fails to auto start, 1A MSIV failed open

==

Description:==

Time Position Applicants Actions or Behavior

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

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

Verify MSIVs closed - 1A MSIV is OPEN o Crew may isolate 1AF013A & E with SM permission RO

Step 9: Check status of RCPs at 1PM05J:

Determine RCP trip required

RCS pressure < 1425 psig & High head SI flow (1FI-917) > 100 gpm

Trip ALL RCPs RO/

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

Check pressure in all SGs:

1A SG pressure lowering in an uncontrolled manner.

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

EVALUATOR NOTE: BOP is performing Attachment B:

Att B, Step 1: Verify ECCS pumps running

CV pumps - NONE RUNNING.

[CT-6]

Manually start the 1A CV pump prior completion of Attachment B of 1BEP-0.

(CT-6)

Both RH pumps - RUNNING

Both SI pumps - RUNNING

Att B, Step 2: Verify ECCS valve alignment

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

Att B, Step 3: Verify ECCS flow

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

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

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

Group 2 RCFC Accident Mode lights - 4 LIT.

Att B, Step 5: Verify Phase A isolation:

Group 3 Cnmt Isol monitor lights - ALL LIT.

Att B, Step 6: Verify Cnmt Vent isolation:

Group 6 Cnmt Vent Isol monitor lights - ALL LIT.

Scenario NRC 16-3 Event 7, 8 & 9 No: No.

Event 1A SG fault, 1B CV pump trips/1A CV pump fails to auto start, 1A MSIV failed open

==

Description:==

Time Position Applicants Actions or Behavior

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 o 1A S/G pressure < 640 psig

Check MSIVs and bypass valves - CLOSED

1A MSIV - OPEN

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

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

CNMT pressure has NOT risen > 20 psig.

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

FW pumps - TRIPPED.

Isolation monitor lights - LIT.

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

Trip all running HD pumps.

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

DGs - BOTH DG running

1SX169A/B OPEN.

Dispatch operator locally to check operation

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

OCB 1-8 and 7-8 open.

PMG output breaker open.

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

VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.

Operating VC train equipment - RUNNING.

0B Supply fan

0B Return fan

0B M/U fan

0B Chilled water pump

0B Chiller

Operating VC train dampers - ALIGNED.

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

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

0VC09Y - OPEN

0VC313Y - CLOSED

Operating VC train Charcoal Absorber aligned for train B.

0VC44Y - CLOSED

0VC05Y - OPEN

0VC06Y - OPEN

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

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

Two inaccessible filter plenums aligned.

Plenum A:

Scenario NRC 16-3 Event 7, 8 & 9 No: No.

Event 1A SG fault, 1B CV pump trips/1A CV pump fails to auto start, 1A MSIV failed open

==

Description:==

Time Position Applicants Actions or Behavior

0VA03CB - RUNNING

0VA023Y - OPEN

0VA436Y - CLOSED

Plenum C:

0VA03CF - RUNNING

0VA072Y - OPEN

0VA438Y - CLOSE

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

0VA04CB - RUNNING

0VA055Y - OPEN

0VA062Y - OPEN

0VA435Y - CLOSED

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

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

Notify EO to verify SFP level and temperature

Notify STA of SFP cooling status

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

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

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

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Request STA evaluation of status trees.

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

RO/

Check MS isolation at 1PM06J:

All MSIVs and bypass valves - OPEN.

Attempt to close ALL MSIVs

Identify 1A MSIV failed to close BOP

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

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

CREW

Identify faulted SG at 1PM04J:

1A SG pressure decreasing in an uncontrolled manner.

1A SG indicates steam flow with 1A MSIV open RO/ BOP

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

[CT-7]

Verify/close 1AF013A & E at 1PM06J (CT-7)

Top row of FW isolation monitor lights - lit.

1MS018A closed.

1SD002A & B closed.

1SD005A closed.

Scenario NRC 16-3 Event 7, 8 & 9 No: No.

Event 1A SG fault, 1B CV pump trips/1A CV pump fails to auto start, 1A MSIV failed open

==

Description:==

Time Position Applicants Actions or Behavior BOP

Monitor AF pump suction pressure.

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

CREW

Determine 1A S/G tubes are intact:

No RM-11 or HMI Rad Monitor ALERT/HI RAD Alarms.

o 1PR08J SG Blowdown.

o 1PR27J SJAE/GS.

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

CREW

Check if ECCS flow should be reduced

RCS subcooling -ACCEPTABLE

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

RCS pressure - stable or rising

Pzr level - > 12%

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

Transition to 1BEP ES-1.1, SI TERMINATION SRO

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

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

Reset SI BOP

Depress both SI reset PB

Verify SI Actuated light - NOT LIT

Very Auto SI Blocked light - LIT RO/

Reset Cnmt Isolation BOP

Reset Phase A BOP

Establish IA to CNMT

Check SACs - ANY Running

Open 1IA065 and 1IA066 RO/

Realign CV Pump BOP

Do NOT stop the single running CV pump CREW

Check RCS pressure - Stable or rising RO/

Terminate High-head SI BOP

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

Reset CV pump miniflow valves - 1CV8114 and 1CV8116

Verify CV pump miniflow valves - OPEN

Close CV injection valves - 1SI8801A & B EVALUATOR NOTE: The scenario can be terminated at lead examiners discretion.

(Final)

Simulation Facility Byron Scenario No.: Operating Test No. 2016 Byron NRC N16-4 Examiners: Applicant: SRO RO BOP Initial Conditions: IC-18, 75% power, steady state, MOL Turnover: Unit 1 is at 76% power, steady state, MOL, CB D is @ 180 steps and boron concentration is 998 ppm.

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

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

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

SCENARIO OVERVIEW Unit 1 is at 76% power, steady state, MOL, CB D is @ 180 steps and boron concentration is 998 ppm. Online risk is green. Crew is to switch Bus 156 from SAT to UAT following ACB 1561 maintenance.

After completing shift turnover and relief, the crew is directed to switch Bus 156 from SAT to UAT following ACB 1561 maintenance using BOP AP-200.

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

After the ramp has begun, the Unit Supervisor will be called by Engineering stating that after reviewing the previously run ASME surveillance the 1B AF pump has failed the acceptance criteria.

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

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

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

After the FW flow failure has been corrected, VCT Level channel 1LT-112 fails low. RMCS auto makeup will start, and the crew will have to place the Makeup Mode Select switch to Off. Any required makeup will have to be done in Manual.

After the VCT level channel failure has been addressed, the 1C RCP trips. When the crew attempts to trip the reactor, the trip breakers will fail to open. The crew will enter 1BFR S.1, ATWS. At step 16, the crew will be directed to return to 1BEP-0, Reactor Trip or Safety Injection.

After the crew enters 1BFR S.1, the auto turbine trip from a reactor trip signal will not function. The manual Turbine trip P.B. will also malfunction. The turbine GVs must be closed manually, or MSLI actuated.

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. Isolate the main turbine from the SGs (so that RCS pressure does not exceed 3200 psig (UFSAR 15.8).

(ERG Critical Task Number - CT-50) (K/A number - EPE029EA1.13 importance - 4.1/3.9)

2. Insert negative reactivity into the core by at least one of the following methods (prior to procedural step to dispatch operators to locally trip the reactor.):

Insert the control rods Establish emergency boration flow to the RCS (ERG Critical Task Number - CT-52) (K/A number - EPE029EA1.14 importance - 4.2/3.9) or (K/A number

- EPE029EK3.11 importance - 4.2/4.3)

References:

BOP AP-200 1BFR-S.1 BAR 0-37-E6 1BEP-0 1BOA INST-2

SIMULATOR SETUP GUIDE:

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

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

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

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

Place Bus 156 on SAT.

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

Divert 1CV112A to get to approximately 39% VCT level.

Verify Simulator Readiness Checklist is completed.

Provide students with turnover sheets and rema.

Run caep N16-4 from thumb drive and verify the following actions load in the CAEP:

Byron 2016 ILT NRC scenario 16-4l00:00:01l0 Event 4: 0B MDCT fan high vibration alarml00:00:02l2 IMF pa0152 onl10:00:00l3 IMF PA0154 ONl10:00:00l4 IOR zao0iisx032 95l10:00:00l5 Event 5: 1A Tc RTD fails lowl00:00:03l7 IMF RX18A 630l10:00:00l8 Event 6: 1FT-521 fails lowl00:00:04l10 IMF RX04D 0 30l10:00:00l11 Event 7: 1LT-112 fails lowl00:00:05l13 IMF CV16 0l10:00:00l14 Event 8: 1C RCP tripl00:00:06l16 IMF TH16Cl10:00:00l17 Preload: l00:00:07l19 RTB fail to openl00:00:08l20 IMF RP02Al00:00:09l21 IMF RP02Bl00:00:10l22 Turbine trip failurel00:00:11l23 IMF TC03l00:00:12l24 IOR ZDI1HSTG010 NORMl00:00:13l25 trgset 10 "zlo0sx03cbhi(1).gt.0"l00:00:14l30 trgset 11 "zlo0sx03cbhi(1).gt.0"l00:00:15l31 trgset 12 "zlo0sx03cbhi(1).gt.0"l00:00:16l32 trg 10 "dor zao0iisx032"l00:00:17l33 trg 11 "dmf pa0152"l00:00:18l34 trg 12 "dmf pa0154"l00:00:19l35

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

Event 3: Unit Supervisor is notified that 1B AF pump has failed ASME acceptance criteria As Engineering, call the US and notify him that after reviewing pump data from a surveillance run 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ago, the discharge pressure at full recirc flow is 50 GPM below acceptance criteria.

SM acknowledge T/S 3.7.5 entry conditions Event 4: 0B SX MDCT Fan High Vibration IMF PA0154 ON IOR zao0iisx032 95 AS EO, report 0B SX fan is vibrating excessively, and the fan gearbox is leaking.

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

Event 5: 1A Tcold RTD Failed High IMF RX18A 630 As SM Acknowledge procedure entry and request for Emergency Plan evaluations.

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

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

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

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

Event 7: VCT Level Channel 1LT-112 Failed Low IMF CV16 0 As SM Acknowledge request for writing IR, performing risk assessment and making appropriate notifications.

Event 8: ATWS - 1C RCP trip with Rx Trip Breakers Fail to Open

IMF RP02A and RP02B (in preload)

IMF TH16C to trip 1C RCP 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 6 of 1BFR S.1, DMF RP02A and RP02B, and MRF RP01 and RP02 OPEN Event 9: Main Turbine Fails to trip on auto signal or manual push button IMF TC03 IOR ZDIHSTG010 NORM

Scenario NRC 16-4 Event 1 No: No.

Event

Description:

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

Refer to BOP AP-200, step F.1

Direct BOP to switch Bus 156 to the UAT per step F.1 BOP

Switch Bus 156 Electrical Lineup

Turn on synchroscope for Bus 156

Close 1561

Open 1562

Turn off syncroscope RO

Monitor primary and secondary panels EVALUATOR NOTE: When electrical swap is complete, insert the next event.

Scenario NRC 16-4 Event 2 No: No.

Event

Description:

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

US

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

Implement actions of 1BGP 100-3.

o Perform pre-job brief per HU-AA-1211 PRE-JOB, HEIGHTENED LEVEL OF AWARENESS, INFREQUENT PLANT ACTIVITY, AND POST JOB BRIEFINGS for load ramp.

US

Direct raising load to 1240 MW at 0.5 MW/min.

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

CREW

Review applicable Precautions, and Limitations and Actions.

Verify rod position and boron concentration.

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

Determine required PW volume: (approximate band: 1200 gal - 1500 gal).

Rema

Determine required PW flow rate.

Initiate dilution as required (BOP CV-5).

Perform the following at 1PM05J:

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

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

Place MAKE-UP CONT SWITCH to STOP position.

Set MODE SELECT to DIL/ALT DIL position.

Place MAKE-UP CONT Switch to START.

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

Turn on PZR backup heaters.

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

Select SETPOINT.

Enter 0.4 MW/min into the RATE window.

Select ENTER.

Enter 1240 MW into REF DEMAND window.

Select ENTER.

Select EXIT.

o Notify US and RO of pending ramp.

Select GO/HOLD.

Verify GO/HOLD button illuminates.

Verify HOLD illuminated RED.

Select GO.

Verify GO illuminates RED.

Verify main turbine load begins to rise.

RO/BOP

Monitor reactor power and load ascension:

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

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

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

VCT level.

RCS Tave rising/RCS boron concentration lowering.

Scenario NRC 16-4 Event 2 No: No.

Event

Description:

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

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 NRC 16-4 Event 3 No: No.

Event

Description:

Unit Supervisor notified of 1B AF pump ASME surveillance failure Time Position Applicants Actions or Behavior CUE

US called by Engineering that 1B AF pump ASME surveillance acceptance criteria has NOT been met, because developed discharge pressure spec not met.

US

Refers to TS 3.7.5 determines that Condition A applies: Restore pump to operable w/i 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

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

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

Scenario NRC 16-4 Event 4 No: No.

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

==

Description:==

Time Position Applicants Actions or Behavior

Annunciator SX CLG TWR FAN VIBRATION HIGH (0-37-E6) is LIT CUE

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

Refer to BAR 0-37-E6 BOP

Monitor amps NOT normal

Manually trip 0B SX Fan o Monitor SX system temperature and provide recommendation to US as to need for 2 SX fans o Evaluate TS 3.7.9; >6 fans are OPERABLE, so LCOAR entry is not required US

Notify SM to evaluate online risk and create IR

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

Scenario NRC 16-4 Event 5 No: No.

Event

Description:

1A Tcold RTD Failed High Time Position Applicants Actions or Behavior CUE

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

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

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

Identify instrument failure US

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

Notify SM of procedure entry, request EAL evaluation and IR o Order ramp in HOLD RO o 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 US o Contact the WEC to brief, or personally brief an extra NSO to bypass bistables o Direct the crew to coordinate bistable bypassing with extra NSO US

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

Scenario NRC 16-4 Event 6 No.: No.:

Event Feedwater flow channel 1FT-521 fails low

==

Description:==

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

Identify 1FT-521 failed low

Report failure to US

Implement BHC for SG Level failure

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

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 Place ramp on hold US

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

Notify SM of plant status and procedure entry.

Request evaluation of Emergency Plan conditions.

Assist BOP as requested

Monitor reactor panel for reactivity changes EVALUATOR NOTE: After the actions for the feedwater flow channel failure are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-4 Event 7 No: No.

Event

Description:

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

Annunciator VCT LEVEL HIGH-HIGH LOW is LIT

VCT Level 1LI-112 indicates ZERO

Automatic RMCS makeup in operation CREW

Refer to BAR 1-9-A2

Determine 1LT-112 is failed LOW RO

Place RMCS makeup switch in OFF

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

Notify SM of failure, request IR BOP

Monitor primary and secondary panels

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

Scenario NRC 16-4 Event 8&9 No: No.

Event

Description:

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

The following annunciators are LIT:

RCP TRIP (1-13-E3)

RCP LOW FLOW ABOVE P8 RX TRIP (1-11-C5)

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

CREW

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

US

Enters 1BEP-0, REACTOR TRIP OR SAFETY INJECTION

Transition to 1BFR S.1, ATWS

Notify SM of procedure entry

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

Manually TRIP the Reactor from BOTH locations

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

Manually trip the Turbine CT-50 o All Turbine throttle valves - CLOSED.

o All Turbine governor valves - CLOSED.

Recognizes the Turbine did not auto trip from Reactor trip

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

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

Select turbine manual on G-5501 panel

Select RAPID

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

Manually start both AF pumps RO/BOP

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

Check at least 1 CV pump running

Initiate emergency boration by

Open 1CV8104

Start boric acid transfer pump

Check emergency boration and charging flows > 30 GPM RO/BOP

Check Pzr pressure < 2335 PSIG

Verify Group 6 CVI monitor lights LIT CREW

Check if Reactor Trip has occurred

Dispatch EO to locally open Rx Trip Breakers

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

Scenario NRC 16-4 Event 8&9 No: No.

Event

Description:

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

Check if Reactor is subcritical

PR channels <5%

IR channels - negative SUR CREW

Check SG NR levels > 1 SG >10%

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

Check 1SD002A-H closed

Check 1CV111A & B closed

Verify BTRS MODE SELECTOR SWITCH is OFF

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

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

Step 14: Check CETC < 1200°F

Step 15: Verify reactor subcritical

PR channels < 5%

IR channels - negative SUR Crew

Return to procedure and step in effect US

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

Simulation Facility Byron Scenario No.: Operating Test No.: 2016 Byron NRC NRC 16-5 Examiners: Applicant:

______________________ ____________________ SRO

______________________ ____________________ RO

______________________ ____________________ BOP Initial Conditions: IC-22 Turnover: Unit 1 is at 100% power, steady state, equilibrium xenon, MOL. Online risk is green. 1A AF Flow Test is scheduled to be performed. The unit will be ramped to 97% power at 3MW/min for the flow test.

Event Malf. No. Event Event No. Type* Description 1 None R (RO, SRO) Ramp down for AF Flow Test 2 None N (BOP, AF Flow Test SRO) 3 MRF ED042H OPEN TS (SRO) Loss of DC to 1B DG (Tech Spec)

MRF ED042E OPEN Online Risk to Yellow MRF ED042D OPEN IOR ZLO1HSDG0201 OFF 4 IMF RX10A 100 30 I (RO, SRO) Turbine impulse pressure channel 1PT-505 fails TS (SRO) high (Tech Spec) 5 IMF EG03 90 10 C (BOP, Generator voltage regulator failure SRO) 6 IMF CV10 C (RO, SRO) 1CV121 fails open 7 IMF RX05 1000 30 I (BOP, SRO) Steam line pressure detector 1PT-507 fails low 8 IMF ED15C M (ALL) Dual unit loss of all AC power IMF ED15G IMF EG08A

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

SCENARIO OVERVIEW Unit 1 is at 100% power, steady state, equilibrium xenon, MOL. Online risk is green. CBD @ 221 steps, and boron concentration is 883 ppm. 1BOSR 5.5.8.AF-1c, Comprehensive IST Requirements for the Motor Driven Auxiliary Feedwater Pump 1AF01PA, Step F.2 is to be performed following online maintenance of the 1A AF flow controllers.

1BOL 7.5 has been entered for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months and will be exited following the successful completion of the surveillance.

After completing shift turnover and relief, the crew will ramp the unit to 97% power at 3MW/min (Rema supplied by QNE) and perform 1BOSR 5.5.8.AF-1c, Comprehensive IST Requirements for the Motor Driven Auxiliary Feedwater Pump 1AF01PA. This procedure has been signed off to step F.1.k.

After a measurable change in power, control power is lost to the 1B DG (both inputs). Tech Spec 3.8.1, condition B applies. The 1B DG will remain unavailable for the remainder of the scenario. (On-line risk is yellow.)

After the 1B DG failure is addressed and flow test is completed, turbine impulse pressure channel 1PT-505 will fail high over a 30 second period. Control rods will begin automatically withdrawing. After recognizing the instrument failure and checking turbine power stable, the RO will place rod control in manual to stop the outward rod motion.

1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment A, 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 1PT-505 failure is addressed, the generator voltage regulator output will fail high, causing the main generator to be overexcited. The BOP will turn the voltage regulator off and manually lower main generator excitation using the base adjuster.

After the voltage regulator failure is addressed, 1CV 121 will slowly fail open in AUTOMATIC. The RO will take manual control and restore normal charging flow. AUTOMATIC operation of 1CV121 will not be available for the remainder of the scenario.

After normal charging flow is restored and the plant stabilized, steam line pressure detector 1PT-507 will fail low over a 30 second period. Both main feedwater pumps speed will lower, reducing feedwater flow and causing all steam generator levels to begin lowering. The crew will take actions to stabilize the plant by taking manual control of the main feedwater pumps. 1PT-507 will remain unavailable for the remainder of the scenario. On-line risk remains yellow.

After the 1PT-507 failure is addressed, a loss of all offsite power will occur for both Units. When the 1A DG engine attempts to start, the engine will seize, resulting in a loss of all AC power to Unit 1. Transition will be made to 1BCA-0.0, LOSS OF ALL AC POWER. A limited crosstie to Unit 2 will be required due to the failure of 2B DG to energize bus 142. The crew must restore power to Unit 1. After power is restored to Bus 141, SX will be cross-tied between units per 1BCA-0.0, Attachment C.

The scenario is complete when the crew has crosstied power from Unit 2 to Unit 1, and isolated RCP seal injection by closing seal injection filter inlet valve(s).

Critical Tasks

1. Restore power to Bus 141 (before exiting 1BCA-0.0).

(UFSAR 8.3.1.1.2.2) (K/A number - 000055EA2.03; importance 3.9/4.7)

2. Isolate RCP seal injection before a CV pump is started in 1BCA-0.0.

(ERG Critical Task number - CT-27) (K/A number - 003000A4.01; importance - 3.3/3.2)

References 1BOSR 5.5.8.AF-1c 1BOA INST-2 1BCA 0.0

SIMULATOR SETUP GUIDE:

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

Establish the conditions of IC 22, 100% power, MOL, steady state, equilibrium xenon.

Raise CST level to 90%.

Lower hotwell level to 15 in preparation for AF surveillance. Monitor hotwell level on 1PM03J and use remote functions on FW14:

MRF FW048 100 OR

IMF FW37 48 and MRF FW049 0 to 100 (Throttle open while monitoring level carefully, this lowers level quickly.)

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

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

Verify Simulator Readiness Checklist is completed.

Place Turnover and ReMa, 1BGP 100-4T3, Load Change Instruction Sheet, and marked up copy (signed off to step F.1.k, with steps F.3 and F.4 N/A) of 1BOSR 5.5.8.AF-1c, Comprehensive IST Requirements for the Motor Driven Auxiliary Feedwater Pump 1AF01PA on the Unit Desk.

Run caep N16-5 from thumb drive and verify the following actions load in the caep:

Byron 2016 ILT NRC scenario 16-5l00:00:00l1 Throttle AF005 valves locallyl00:00:00l46 Event 2: 1A AFP run - Start ALOPl00:00:00l3 Use RF FW 161-164l00:00:00l47 mrf fw146 startl08:00:00l4 Isolate seal injection valvesl00:00:00l49 Event 3: Loss of DC to 1B DGl00:00:00l6 mrf cv41 0l08:00:00l50 mrf ed042d openl08:00:00l7 mrf cv42 0l08:00:00l51 mrf ed042e openl08:00:00l8 mrf ed042h openl08:00:00l9 ior zlo1hsdg0201 offl08:00:00l10 Event 4: 1PT-505 fails highl00:00:00l12 IMF RX10A 800 30l08:00:00l13 To trip bistablesl00:00:00l14 MRF RP20 OPENl08:00:00l15 MRF RX143 TRIPl08:00:00l16 MRF RP20 CLOSEl08:00:00l17 To trip AMS bistablel00:00:00l18 IOR PN0470 ON l08:00:00l19 MRF RX149 TRIP l08:00:00l20 Event 5: MG Voltage Reg failurel00:00:00l22 imf eg03 95 10l08:00:00l23 Event 6: 1CV-121 fails openl00:00:00l25 imf cv10 200 30 132l08:00:00l26 Events continue on next pagel00:00:00l28 Event 7: 1PT-507 fails lowl00:00:00l31 imf rx05 0 30l08:00:00l32 Event 8: Dual unit LOOPl00:00:00l34 imf ed15cl08:00:00l35 imf ed15el08:00:00l36 imf eg08al08:00:00l37 Emergency stop U1 DGsl00:00:00l39 mrf eg19 tripl08:00:00l40 mrf eg20 tripl08:00:00l41 Close 2414l00:00:00l43 mrf ed006 closel08:00:00l44

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Ramp to 97% power SM acknowledge start of ramp when notified.

TSO acknowledge start of ramp when notified.

Event 2: Perform 1BOSR 5.5.8.AF-1c EO provide information 1BOSR 5.5.8.AF-1c, Comprehensive IST Requirements for the Motor Driven Auxiliary Feedwater Pump 1AF01PA as requested.

EO report 1A AF pump recirc flow when requested. SMDG FW12, MP YCF2333 EO start 1A AF pump ALOP when requested. MRF FW146 START (Note the MCR ALOP Run Light wont start until the 1A AF pump is shut down.)

Events 3: Loss of DC to 1B DG.

Modify/insert and verify the following actuate:

MRF ED042D OPEN

MRF ED042E OPEN

MRF ED042H OPEN

IOR ZLO1HSDG0201 OFF If dispatched as EO to 1B DG, report that all DC control power lights for the 1B DG are de-energized. Faint acrid smell exists in 1PL08J. The Available for Emergency light is out.

If dispatched as EO to DC bus 112, report no damage to the bus and both breakers for 1B DG control power are tripped (125 VDC Bus 112, Compt BF-1, ckt 16 and BR-1, ckt 13). If closure is attempted neither breaker will close.

If asked, report as Unit 2 that both U-2 DGs are operable.

Acknowledge as SM entry into TS 3.8.1, condition B entry, on line risk assessment (yellow), request for common cause failure analysis, request for maintenance support, and IR requests.

Once recognized that the Offsite AC Power Availability surveillance needs to be performed, report that an assist NSO will perform the surveillance.

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 4: Turbine impulse pressure channel 1PT-505 fails high Insert IMF RX10A 800 30 to fail 1PT-505 high over a 30 second period.

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

As extra NSO contact Unit 1 (X-2209)

Insert the following:

MRF RP20 OPEN (open protection cabinet #1 door)

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

MRF RP20 CLOSE (close protection cabinet #1 door)

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

As extra NSO contact Unit 1 (X-2209)

Insert the following:

IOR PN0470 ON (place operating bypass switch 12 in TIP 1 position) (On annunciator tab of Action List)

MRF RX149 TRIP (place operating bypass input switch 11 to test-trip)

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

Event 5: Main generator voltage regulator failure Insert IMF EG03 95 10 for main generator voltage regulator failed.

Acknowledge as SM voltage regulator failure, on line risk assessment, requests for maintenance and OAD support, and IR requests.

Acknowledge as Power Team failure of generator voltage regulator.

Event 6: 1CV-121 failed open IMF CV10 200 30 132 (note: final value, ramp time, initial value)

If dispatched as EO to investigate 1CV-121, report valve is responding normally.

SM acknowledge failure, online risk evaluation and IR initiation Event 7: Steam line pressure detector 1PT-507 fails low.

Insert IMF RX05 0 30 for 1PT-507 failed low.

If dispatched as EO to investigate 1PT-507, wait two minutes report no visible damage to 1PT-507.

Acknowledge as SM 1PT-507 failure, on line risk assessment, request for maintenance support, and IR requests.

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 8: Dual unit loss of all AC power.

Insert and verify the following actuate:

IMF ED15C

IMF ED15E

IMF EG08A After STA requested, as STA report CSF status - Yellow on inventory if pressurizer level < 17%.

When requested as EO to start the U1 D/Gs, report that 1A D/G is seized, 1B DG does not have control power, and 1BOA ELEC-3 was ineffective.

Acknowledge as EO request to depress U1 DG emergency stop push buttons and insert the following:

MRF EG19 TRIP

MRF EG20 TRIP As Unit 2 operator, report ONLY Bus 241 is energized from 2A DG, acknowledge request to perform 2BCA-0.3, and acknowledge request to monitor crosstie current as loads are started.

Insert the following to align Unit 2 4KV ESF buses to Unit 1:

MRF ED006 CLOSE to close ACB 2414.

Acknowledge as EO request to monitor 1B AF pump and request to maintain 1B AF pump day tank level.

As EO, respond to request to throttle 1AF005E-H locally.

MRF FW161, FW162, FW163, FW164 as appropriate to requested flowrates Acknowledge as EO request to isolate RCP seals, wait three minutes and insert the following to isolate the RCS seal injection. Report RCP seal isolation to MCR.

MRF CV41 0 (1A seal injection filter) or MRF CV42 0 (1B seal injection filter) as appropriate for 1CV8384A or B.

INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 8: Dual unit loss of all AC power. (continued)

If asked as Unit 2 for 2SX016A and 2SX027A status, report 2SX016A and 2SX027A are open.

Acknowledge request as EO to close 1SX016B and 2SX016B. Wait three minutes and report 1SX016B and 2SX016B are closed.

If dispatched as EO to check 1SX005 position locally, wait two minutes and report 1SX005 is open.

If asked as Unit 2 for 2SX005 status, report 2SX005 is closed.

If dispatched as EO to close 1SX004, wait two minutes and report 1SX004 is closed.

Acknowledge request as EO to throttle SX to the CC HXs. Wait two minutes and report 0SX007 is closed, 1SX007 is closed and 2SX007 is 20% open.

If requested as Unit 2 to open 2SX005, wait one minute and report 2SX005 is open.

If asked as Unit 2 for 2SX033 and 2SX034 status, report 2SX033 and 2SX034 are open.

If dispatched as EO to throttle 1SX007 to 10% open, report 1SX007 is 10% open.

Acknowledge request as Unit 2 to monitor 2A SX pump amps (120 a) and discharge pressure (94 psi).

If asked as Unit 2 for crosstie loading capability, report adequate capacity exists prior to starting Unit 1 loads.

Acknowledge as EO request to isolate CC surge tank auto makeup and insert the following to isolate CC surge tank makeup:

MRF CC51 0 to close 1CC185

MRF CC52 0 to close 1CC184 Acknowledge as EO request to drain CC surge tank to normal level and insert the following as needed to initiate CC surge tank drain:

MRF CC15 100 to open 1CC2020B

MRF CC16 100 to open 1CC2020A

Scenario NRC 16-5 Event 1 No: No.

Event

Description:

Ramp unit to 97% power Time Position Applicants Actions or Behavior CUE

Provide candidates with 1BGP 100-4T3, Load Change Instruction Sheet and ReMa SRO

Implement 1BGP 100-4T3 for a normal ramp

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

Direct RO to borate in accordance with ReMa (30 gallons, 8 rod steps)

Direct BOP to ramp in accordance with 1BGP 100-4T3 and supplied Rema RO

Set up boration IAW ReMa and BOP CV-6

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

Select STOP on RMCS Makeup Control Switch

Select BORATE on RMCS Mode Select Switch

Enter desired boration amount in BA totalizer

Turn ON RMCS Makeup Control Switch

Verify 1CV110B OPEN

Verify 1CV110A MODULATING

Verify 1AB03P STARTS

Verify proper AB flow on 1FR110

Coordinate boration with start of unit ramp by BOP BOP

Set up DEH for ramp IAW 1BGP 100-4T3

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

Press ENTER

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

Press ENTER

Press GO/HOLD

Press GO and verify load lowers

Initiate ramp

Coordinate ramp with boration by RO.

EVALUATOR NOTE: When ramp is complete, crew will continue with 1BOSR 5.5.8.AF-1c

Scenario NRC 16-5 Event 2 No: No.

Event

Description:

Perform 1BOSR 5.5.8.AF-1c Time Position Applicants Actions or Behavior CUE

Provide candidates with marked copy of 1BOSR 5.5.8.AF-1c SRO

Perform PJB of activity

Implement 1BOSR 5.5.8.AF-1c

Instruct BOP to perform 1BOSR 5.5.8.AF-1c steps F.2, F.5 and F.6.

Instruct RO to monitor reactor power during performance of 1BOSR 5.5.8.AF-1c RO

Monitor reactor power during performance of 1BOSR 5.5.8.AF-1c BOP

Perform 1BOSR 5.5.8.AF-1c

NOTE: Signed off and placekept to step F.1.k

Place U0921 and U0923 to TEST in POINT DETAILS

Start 1A AF pump per BOSR

Contact EO to report 1A AFP recirc flow or check on HMI or Group Trend

Record AF flows in BOSR

Adjust AF flowrate to at least 200 gpm per SG using 1AF005 valves

NOTE: F.3 and F.4 are N/Aed

Shutdown 1A AF pump per BOP AF-6

Contact EO to start 1A AFP ALOP locally EVALUATOR NOTE: When Step F.5 (1A AFP is stopped) of 1BOSR 5.5.8.AF-1c is complete, or at the discretion of the lead examiner, continue with the next event.

Scenario NRC 16-5 Event 3 No: No.

Event

Description:

Loss of DC to 1B DG.

Time Position Applicants Actions or Behavior CUE

Annunciator DG 1B TROUBLE/FAIL TO START (1-22-C8)

Annunciator DG 1B DIFF LOCKOUT/OVERSPEED (1-22-D8)

DG 1B stop light de-energized.

SER point 2491 1B ED Control Panel Trouble.

Refer to BARs RO/

Dispatch EO to 1B EDG room.

BOP CUE

EO reports both DC control power lights for the 1B EDG are de-energized. Faint acrid smell in 1PL08J panel. If EO dispatched to DC bus 112, reports that both breakers for 1B DG control power are tripped. If closure is attempted breakers will not close.

EVALUATOR NOTE: The crew may elect to place the 1B DG and ACB 1423 control switches to pull out due to the DG inoperability.

Place 1B DG control switch to pull out at 1PM01J.

Place ACB 1423 control switch to pull out at 1PM01J.

o May request EO to place 1B EDG in Maintenance Outage SRO

Determine 1B DG is inoperable, determines TS 3.8.1, Cond B is applicable.

Inform SM of TS entry, asks for IR and Sys Eng/maintenance help.

Identify performance of 1BOSR 3.8.1.1 Unit 1 Offsite AC Power Availability Surveillance required within one hour.

EVALUATOR NOTE: Once the crew identifies 1BOSR 8.1.1 is required to be performed, the SM will report that an Extra NSO will perform the surveillance.

EVALUATOR NOTE: Initiate the next event when the lead examiner approves.

Scenario NRC 16-5 Event 4 No: No.

Event Turbine impulse pressure channel 1PT-505 fails high.

==

Description:==

Time Position Applicants Actions or Behavior CUE o Annunciator 1-14-E1, TAVE CONT DEV LOW

1PI-505, first stage pressure, indication rising.

o Control rod outward motion (if rod control mode is in AUTO)

1TR-0412, Auct Tave/Tref recorder, Tref indication rising

1SI-412, Rod Speed, indicates higher than normal, up to 72 steps per minute RO/ o Implement BHC for Uncontrolled Rod Motion.

Perform the following at 1PM05J:

o Determine control rods withdrawing.

Identify 1PT-505 is failing high.

Report failure to SRO o Determine turbine power stable at 1PM06J or OWS drop 210.

o Place rod bank select switch to manual at 1PM05J to stop uncontrolled rod withdrawal.

CREW

Reference BARs 1-14-E1.

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

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.

RO/

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.

Defeat 1PT-505 at 1PM05J:

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

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

NSO/

PB505A - C1-742 BS-1.

BOP RO

Check if rod control can be placed in auto (if rods were in manual)

Check C-5 bypass permissive NOT LIT at 1PM05J.

Check Tave/Tref stable and within 1°F.

1TR-412 at 1PM05J o Adjust Tave - Tref within 1°F by manually inserting control rods at 1PM05J

Place rod bank select switch in AUTO.

Scenario NRC 16-5 Event 4 No: No.

Event Turbine impulse pressure channel 1PT-505 fails high.

==

Description:==

Time Position Applicants Actions or Behavior Extra

Check status of AMS system NSO

Operating Bypass switch in OFF locally.

Extra

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

NSO/

Place Operating Bypass switch to TIP-1 locally.

Place Operating Bypass Input to TEST-TRIP locally.

RO/

Check P13 interlock BOP

Turbine power > 10%

Check P-13 bypass permissive NOT LIT at 1PM05J SRO

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 and with lead examiners concurrence, insert the next event.

Scenario NRC 16-5 Event 5 No: No.

Event Generator voltage regulator failure

==

Description:==

Time Position Applicants Actions or Behavior CUES

Annunciator GENERATOR FIELD FORCING (1-19-B6)

1IIMP023, Exciter Field Current, rising.

1VIMP006, Main Generator Output VARS, rising.

Direct/Ensure BOP takes manual control of generator voltage regulator and lowers generator field current.

Inform SM of voltage regulator failure.

o Direct BOP/RO to stop load ramp/dilution BOP

Implement BHC for Generator Field Forcing

Perform the following at 1PM01J:

Place voltage regulator to off.

Place base adjuster to lower.

Lower generator voltage to < 100 amps prior to main generator trip.

o Refer to BAR CREW

Refer to 1BGP 100-3A6 and 1BGP 100-3A7 for generator MW, and generator VARS within limits BOP

Maintain generator field current, generator MW, and generator VARS within limits by operating the base adjuster.

Refer to BARs

Monitor primary and secondary panels and assist BOP as requested SRO

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

Notify Power Team, NDO and TSO of voltage regulator failure.

Scenario NRC 16-5 Event 6 No: No.

Event

Description:

1CV121 failure OPEN Time Position Applicants Actions or Behavior CUE

Annunciator 1-9-D3, CHG LINE FLOW HIGH LOW LIT

Charging flow RISING

VCT level LOWERING EVALUATOR NOTE: Crew may enter 1BOA Pri-1 for Excessive Primary Leakage RO

Place 1FK-121 in MANUAL

Lower charging flow

Balance charging flow with letdown to restore and stabilize Pzr level BOP o Review BARs

Monitor primary and secondary panels as RO responds to CV malfunction SRO

Notify SM for IR If Crew enters 1BOA Pri-1 for Excessive Primary Leakage SRO o (If 1BOA Pri-1 is entered) Notify SM for procedure entry and EAL evaluation RO/BOP o Check Charging Pumps running o Throttle 1CV121 and 1CV182 to maintain Pzr Level If Crew isolates and bypasses 1CV121 (May use P&ID or BOP CV-26)

RO/BOP

Direct EO to open 1CV8387A while RO/BOP closes 1CV121 RO/BOP

Adjust 1CV182 to maintain proper seal injection flow RO/BOP o Direct EO to close 1CV8384A & B to isolate 1CV121 EVALUATOR NOTE: After the actions to control charging flow are complete and with lead examiners concurrence, insert the next event.

Scenario NRC 16-5 Event 7 No: No.

Event

Description:

Steam line pressure detector 1PT-507 fails low.

Time Position Applicants Actions or Behavior CUE

Annunciators S/G 1A/B/C/D LEVEL DEVIATION HIGH/LOW (1-15-A9/B9/C9/D9)

BOTH main feedwater pump speed/flow - LOWERING.

1PI-507, S/G HDR PRESS, - LOWERING CREW

Refer to BARs

Determine 1PT-507 failing low at 1PM04J.

o Dispatch operators to investigate 1PT-507 failure.

Direct/Ensure BOP takes manual control of FW pump speed and raises FW pump speed.

Inform SM of 1PT-507 failure.

o Direct BOP/RO to stop load ramp/dilution BOP

Implement BHC for SG Level

Perform the following at 1PM04J:

Place 1SK-509A, Master FW pump speed controller in manual.

Raise demand on 1SK-509A.

Raise FW pump speed sufficiently to restore SG levels to normal.

Maintain SG levels by operating 1SK-509A in manual.

o Determines steam dumps not available in STM PRESS mode.

Perform the following at 1PM05J:

Monitor reactor response to SG under and overfeeding transient.

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

Scenario NRC 16-5 Event 8 No: No.

Event Loss of all AC power.

==

Description:==

Time Position Applicants Actions or Behavior CUE

Annunciator LOSS OF OFFSITE POWER (1-20-A1)

Annunciator DG1A TROUBLE/FAIL TO START (1-21-C8)

BOTH 4KV ESF bus alive lights NOT LIT.

CREW

Determine Loss of All AC Power has occurred.

Enter/Implement 1BCA-0.0, "LOSS OF ALL AC POWER", and direct operator actions of 1BCA-0.0 to establish the following conditions:

Direct operator actions of 1BCA-0.0.

Notifies SM of plant status and procedure entry.

Requests evaluation of Emergency Plan conditions.

RO Perform immediate operator actions of 1BCA-0.0:

Manually trip reactor at 1PM05J or 1PM06J.

Verify reactor trip at 1PM05J:

Reactor trip & Bypass breakers - OPEN

Neutron flux - DROPPING BOP Perform immediate operator actions of 1BCA-0.0:

Manually Isolate Steamlines at 1PM05J or 1PM06J:

Actuate main steamline isolation.

Verify all MSIVs and MSIV Bypass valves - CLOSED.

Verify AF flow at 1PM06J:

AF flow >500 gpm (1B AF train only)

Verify RCS isolated at 1PM05J:

BOTH PZR PORVs closed.

1CV8149A, B & C closed.

1CV459 and 1CV460 closed.

1CV8153A & B closed.

Try to restore power to any/both Unit 1 4KV ESF buses at 1PM01J:

DGs - NONE RUNNING.

Actuate SI.

BOP/

Prepare for Unit 2 crosstie:

Dispatch operator to depress emergency stop push buttons on both U1 DGs.

o Reset SI at 1PM06J.

Check status of Unit 2 ESF buses at 1PM01J:

Bus 241 - ENERGIZED from 2A DG.

Notify Unit 2 to implement 2BCA-0.3, RESPONSE TO OPPOSITE UNIT LOSS OF ALL AC POWER.

Bus 242 - DEENERGIZED

GO TO 1BCA-0.0, Step 14 (limited crosstie).

BOP/

Energize bus 141 using limited Unit 2 crosstie (DG 2A) at 1PM01J:

Bus 241 energized from 2A DG.

Check Bus 141 - NOT FAULTED:

ACB 1413 (DG feed) in PULL OUT.

Scenario NRC 16-5 Event 8 No: No.

Event Loss of all AC power.

==

Description:==

Time Position Applicants Actions or Behavior

ACB 1411 (Non-ESF bus tie) in PULL OUT.

ACB 1412 (SAT feed) in PULL OUT.

ACB 1414 (Reserve feed) in PULL OUT.

Verify Bus 141 alarms NOT LIT:

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

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

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

BOP/

Energize bus 141 using limited Unit 2 crosstie (DG 2A) at 1PM01J: (Contd)

Place ESF loads in PULL OUT:

BOTH CENT CHG pumps

BOTH RH pumps

BOTH SI pumps

1A AF pump

ALL RCFCs (HI and LO)

BOTH CS pumps

ALL CC pumps (1A, 1B, and 0)

BOTH SX pumps

BOTH MCR chillers

U-1 SX Tower Fans

[CT]

Check ACB 2414 closed (reserve feed light lit.).

UFSAR

Synch and Close Bus 141/241 reserve feeder breaker:

8.3.1.1.

Close ACB 1414 2.2

Check Bus 141 energized.

Check Bus 131X energized.

Check VC Train 0A fans - RUNNING:

Start 0A supply fan, 0A return fan, & 0A makeup fan.

Notify Electrical Operations to implement an emergency AC restoration program.

GO TO step 17.

BOP/

Check AF pump status at 1PM06J:

1B AF pump - RUNNING.

Check SG levels at 1PM05J:

Maintain NR levels between 10% (31%) and 50%.

Dispatch operator to monitor 1B AF pump.

BOP/

Isolate RCP seals:

Dispatch operator to locally close 1CV8384A & B.

[CT-27]

Close 1CC9438 at 1PM06J.

Close 1CV8100 at 1PM05J.

Verify Equipment loaded on bus 141 at 1PM06J:

/BOP

Annunciator 125V DC BATT CHGR 111 TROUBLE - NOT LIT (1-21-E8)

Annunciator Bus 111 INVERTER TROUBLE NOT LIT (1-4-A5)

Annunciator Bus 113 INVERTER TROUBLE NOT LIT (1-4-C5)