ML040140746

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Initial Submittal of the Scenarios for Byron Initial Examination - Dec 2003
ML040140746
Person / Time
Site: Byron  Constellation icon.png
Issue date: 12/01/2003
From: Foss T
Exelon Generation Co
To:
Office of Nuclear Reactor Regulation
References
50-454/03-301, 50-455/03-301
Download: ML040140746 (31)
v • d • e


Text

Simulation Facility Byron Scenario No. 1 Operating Test No. 2003-301 Examiners: _______________________ Applicant: ______________________ SRO

_______________________ ______________________ RO

_______________________ ______________________ BOP Initial Conditions: IC-21 , 100% power, BOL, equilibrium Xenon, steady state Turnover: 100% power. 1A Containment Spray Pump (CS) is OOS for a pump bearing replacement. 1C Heater Drain pump (HD) is OOS for an alignment and vibration problem.

Event Malf. No. Event Event No. Type* Description Preload RP02A&B M RO Failure of RTB A&B to auto and manually open. (can be opened locally)

SRO 1A CS pump OOS CS01A BOP Failure of CS to Actuate on Hi-3 Cnmt Press. Train B CS must be manually started from the MCR FW35C 1C HD pump OOS ED06D M BOP 6.9KV Breaker 1591 fails to ABT.

Preload (preload note) C RO 1SI8801A will not auto open nor open from the MCB SRO 1SI8801B will not open automatically. Will open manually from MCB 1 N BOP Ramp down turbine power to 1000 Mwe at directed MW/min SRO 1 R RO Lower reactor power using rods and/or boration.

SRO 2 RX21A 2500 I RO 1PT-455 Controlling Pressurizer Pressure channel fails high (over 30 SRO second ramp) 3 RX03E, 0 I BOP Steam Flow Transmitter 1FT-532 (input to controlling channel) fails low SRO over 3 minute ramp 4 RD09, 8 C RO Automatic rod motion fails at 8 step per minute.

SRO 5 ED05D M BOP SAT feed breaker to bus 159 trips opens, no ABT. Loss of RCS flow RO (Loop 1D) ATWS SRO 6 RP02A,B M RO Reactor Trip Breakers fail to open / ATWS BOP SRO 7 TH06 M RO LOCA inside containment. Leads to high-3 containment pressure BOP SRO 8 preload C BOP Failure of CS to auto actuate.

RO SRO

  • (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient Byron 2003-301 Scenario 03-1

Scenario No: 03-1 Event No. 1 Event

Description:

Ramp down turbine and reactor power to 1000 MWe.

Time Position Applicants Actions or Behavior CUE Turnover. 100% power. 1A Containment Spray Pump (CS) is OOS for a pump bearing replacement. 1C Heater Drain pump (HD) is OOS for an alignment and vibration problem. Ramp Unit to 1000 Mwe @

5MW/min Note: A portion of the power increase preparations may have been performed in the briefing room US Implement actions of 1BGP 100-4, rev 25, step F.1 (OR per 1BGP 100-4T2)

US Direct load reduction to 1000 MWe at 5 MW/min

  • Initiate load swing instruction sheet, 1BGP 100-4T2
  • Contact Chemistry and HP for load change >15% in one hour
  • Perform Reactivity Briefing CREW Review applicable Prerequisites, Precautions, Limitations and Actions of 1BGP 100-4 RO Verify rod position and boron concentration Initiate boration, if required. (BOP CV-6)

° Effects of previously performed borations

° Boration / Dilution tables IF BATCH addition desired:

  • Determine the desired change in RCS Tave
  • Determine required gallons of boric acid to change Tave IF Calculated addition desired:
  • Determine required gallons of boric acid to increase RCS boron as desired NOTE: The remaining steps will be performed for either method of boration
  • Set 1FK-110 BA Flow Control to desired boration rate (may leave at current value if Batch method used)
  • Set 1FY-0110 BA Blender Preset Counter to desired volume.
  • Place MAKE-UP MODE CONT SWITCH to stop position
  • Set MODE SELECT to bor position
  • Place MAKE-UP MODE CONT SWITCH to start
  • Verify proper operation of valves and BA transfer pump (1CV110B open, 1CV110A throttles open, Boric Acid Pump running, Boric Acid flow indicated on recorder.)

BOP Initiate turbine load reduction:

  • Depress LOAD RATE MW/MIN
  • Enter desired value for rate (5 MW/min)
  • Depress ENTER
  • Depress REF
  • Enter desired final turbine loading (1000 MW)
  • Depress ENTER
  • When ready to begin load decrease, depress GO
  • Verify load reduction occurring RO/BOP Monitor reactor power and load decrease
  • Monitor Nuclear instruments, Tave, DI, Pressurizer press/level
  • Monitor MWe, turbine loading, EHC

Scenario No: 03-1 Event No. 1 Event

Description:

Ramp down turbine and reactor power to 1000 MWe.

Time Position Applicants Actions or Behavior RO During Boration:

  • Monitor VCT level and pressure
  • Verify boration stops at preset value NOTE: Following clearly observable plant response from the reactivity changes and with the concurrence of the lead examiner, the next event may be initiated.

Scenario No: 03-1 Event No. 2 Event

Description:

PT-455 Controlling Pressurizer Pressure Channel fails high Time Position Applicants Actions or Behavior CUE Annunciators:

1-12-B2 PZR PORV OR SAF VLV OPEN 1-12-C6 PZR PORV DSCH TEMP HIGH 1-12-D2 PZR PRESS CONT DEV HIGH PORV 1RY455A OPEN Position indicating light lit.

1PI-455 Indicating 2500 psig.

Pressurizer pressure decreasing RO Diagnose/Announce Pressurizer pressure transmitter failure, 1RY455A and Pressurizer sprays open:

  • Determine Pressurizer pressure is decreasing, identify open PORV and spray valves
  • Stop the Depressurization o Place Master Pressurizer pressure controller in manual and decrease o Close 1RY455A o Close 1RY8000A
  • Manually:

o Close spray valves.

o Control Master Pressurizer pressure controller US Implement and direct actions of 1BOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, ATTACHMENT B, PZR PRESSURE CHANNEL FAILURE:

  • Identify failed Pressurizer pressure channel 1PT455

° Get acknowledgements from RO and BOP.

  • Recognize Technical Specification entry for DNB LCO
  • Inform SM of plant status, evaluate for E-Plan.

° Direct WEC to write WR, CR, and get maintenance involved.

° Direct holding the ramp and boration US ° Briefs Unit 1 NSO and Unit 2 assist NSO on bistable tripping.

RO Perform actions of 1BOA INST-2 as directed:

  • Determine Pressurizer Pressure not normal
  • Take Manual Control to restore Pressure.
  • Place the Master Pressurizer Pressure Controller in Manual
  • Control Pressurizer Pressure
  • Check Pressurizer PORVs, Spray Valves and Heaters:
  • PORVS Closed.
  • Pressurizer Spray valves normal. If not, then manually control.
  • Pressurizer Heaters normal.
  • Check Pressurizer Pressure Control in automatic:
  • 1RY455A returned to automatic.
  • 1RY456 in automatic.
  • Sprays in automatic (after operable channel selected for control).
  • Master Pressurizer Pressure Controller in automatic.
  • Pressurizer Pressure.
  • Loop DeltaT.
  • Coordinates bistable tripping:

o Places colored dots on bistable, indications, and annunciators.

o Maintains communications with NSO tripping bistables.

RO/BOP Ensures the following Bistables are tripped: (May wait to trip bistables, have 6 hrs to complete)

Scenario No: 03-1 Event No. 2 Event

Description:

PT-455 Controlling Pressurizer Pressure Channel fails high Time Position Applicants Actions or Behavior

  • PB455A
  • PB455C
  • PB455D
  • PB455B
  • TB411C
  • TB411D
  • Checks Pressurizer Pressure > 1930 psig and P-11 permissive is NOT Lit (Bypass Permissive 3.3).

BOP Perform actions as directed:

° Assist RO in monitoring panels and parameters.

° Investigate BARs.

° Make phone calls as directed to WEC and maintenance.

° Control load ramp US Refers to Tech Specs, and determines the following:

  • 3.3.1 Reactor Trip System Instrumentation Conditions E and K - trip channel within 6 hrs.
  • 3.3.2 Engineered Safety Feature Actuation System Instrumentation Condition D - trip channel within 6 hrs.
  • 3.4.1 DNB Limits Condition A - Restore DNB within 2 hrs.

NOTE: after completion of all actions and TS determination for the Pressurizer Instrument failure, and with the concurrence of the lead examiner, the next event may be initiated

Scenario No: 03-1 Event No. 3 Event

Description:

Steam Flow Transmitter FT-532 (controlling channel) fails low Time Position Applicants Actions or Behavior CUE Annunciators:

1-15-C3 SG 1C FLOW MISMATCH STM FLOW LOW 1-15-C9 SG 1C LEVEL DEVIATION HIGH LOW 1FI-532 indication reading low 1FW530 throttling closed FW flow decreasing SG level decreasing below program BOP/US Identify/report steam flow channel 1FT-532 failure

  • Take manual control of 1FW530 and increase feed flow above steam flow to restore level as necessary.
  • Balance feed flow with steam flow to stabilize level as necessary.

US Implement and direct actions of 1BOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment H STEAM FLOW CHANNEL FAILURE:

° Get acknowledgements from RO and BOP.

  • Inform SM of plant status, evaluate for E-Plan.

° Direct WEC to write WR, CR, and get maintenance involved.

° Direct holding load decrease BOP Perform actions as directed:

  • Check affected SG levels normal. IF NOT:
  • Place FRV in Manual
  • Verify/establish adequate Feedwater pump Delta P
  • Restore level to a stable condition.

° Establish automatic level control

  • Verify Steam Pressure channels normal

° Verify/restore Feedwater speed control in automatic RO Assist BOP as required to identify failed instrument channel and stabilize SG levels Monitor RCS and stabilize changing parameters resulting from feed flow/steam flow imbalance:

  • Pzr Pressure
  • Boration

° Load decrease NOTE: Following the actions for the failed Steam flow channel and with the concurrence of the lead examiner, the next event may be initiated.

Scenario No: 03-1 Event No. 4,5,6 Event

Description:

Loss of 6.9 KV Bus 159 no ABT resulting in a partial Loss of Flow ATWS. During ATWS Auto Control rod speed fails to 8 spm.

Time Position Applicants Actions or Behavior CUE Annunciators:

1-20-A6 BUS 159 Fd BRKR 1592 TRIP 1-20-D6 BUS 159 VOLT LOW 1-13-A2 RCP BUS UNDERVOLTAGE RX TRIP ALERT 1-13-D3 RCP 1D BRKR OPEN OR LOW FLOW ALERT 1-13-E3 RCP TRIP 1-11-A4 OPDT RX TRIP 1-11-C5 RCP LOW FLOW ABOVE P8 RX TRIP No voltage on Bus 159:

Loop 1D RCS flow coasting down Inward rod motion demanded at only 8 steps per minute.

CREW Diagnoses loss of Bus 159, 1D RCP, and RED First Out dictating need for Reactor Trip, but failure of Automatic Trip to occur.

US Implement and direct actions of 1BEP-0 "REACTOR TRIP OR SAFETY INJECTION" RO/BOP Perform immediate operator actions of 1BEP-0 Determine the reactor is not tripped:

  • Rod bottom lights not lit
  • Neutron flux not decreasing Manually attempt to trip reactor with both switches at:
  • 1PM05J

US Implement and direct actions of 1BFR-S.1 "RESPONSE TO NUCLEAR POWER GENERATION/ATWS"

° Contact WEC for STA duties NOTE: Crew may dispatch operator to locally open reactor trip breakers at any time.

RO Perform immediate operator actions of FR-S.1:

  • Verify reactor is not tripped
  • Rod Bottom lights not lit
  • Reactor trip breakers not open; Bypass breakers open (not racked in)
  • Neutron flux not decreasing from Post Trip.
  • Manually attempt to trip reactor with both switches at:
  • 1PM05J
  • 1PM06J RO Insert control rods at 48 spm in Manual. (automatic is failed to 8 spm)

[CT]

FR-S.1--C BOP Verify turbine trip

  • Turbine throttle valves not closed
  • Turbine governor valves not closed

[CT]

  • Manually trip turbine

Scenario No: 03-1 Event No. 4,5,6 Event

Description:

Loss of 6.9 KV Bus 159 no ABT resulting in a partial Loss of Flow ATWS. During ATWS Auto Control rod speed fails to 8 spm.

Time Position Applicants Actions or Behavior FR-S.1--A Check AFW Pumps Running

  • AFW Pump run lights not lit
  • Manually start AFW pumps RO/BOP Initiate Emergency Boration of RCS
  • Check at least one centrifugal charging pump running
  • Open 1CV8104
  • Check emergency boration flow - GREATER THAN 30 GPM
  • Verify charging flow - GREATER THAN 30 GPM Check Pressurizer pressure - Less than 2335 psig RO BOP Verify Containment Ventilation Isolation
  • Group 6 Containment Vent Isolation monitor lights lit RO Verify reactor subcritical

° PR channels < 5%

° IR channels SUR < 0 Determine the power is still above 5% and continue with steps of 1BFR-S.1.

BOP Isolate Steam Dumps

  • Place steam dump BYPASS INTERLOCK switches to OFF/RESET for both trains.

NOTE: Reactor trip breakers will be locally opened after dumps are in OFF/RESET.

CREW Check trips have occurred

  • Level in at least one SG > 10% if not, verify > 900 gpm AFW flow
  • Control feed flow to maintain SG levels between 10% (31% adverse) and 50%
  • Check SG blowdown isolation valves closed: 1SD002A-H RO Verify all dilution path valves closed
  • Reactor Makeup dilution valves 1CV111A and 1CV111B closed
  • Verify BTRS Mode Selector in off
  • Dispatch operator to locally check valves closed per 1BFR S.1 step 10c CREW Stop reactivity insertion from RCS cooldown
  • RCS temperature not decreasing in uncontrolled manner
  • SG pressure, none decreasing in uncontrolled manner RO Check CETCs < 1200°F NOTE: 500 gpm LOCA will start here RO Verify reactor subcritical
  • PR channels < 5%
  • IR channels SUR < 0

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior CUE Annunciators:

1-1-A2 CNMT DRAIN LEAK DETECT FLOW HIGH Pressurizer pressure decreasing Pressurizer level decreasing Containment pressure increasing US Implement and direct the actions of 1BEP-0 REACTOR TRIP OR SAFETY INJECTION o Get acknowledgements from RO and BOP.

  • Rod bottom lights lit
  • Flux decreasing BOP Verify Turbine tripped
  • All throttle valves closed
  • All governor valves closed Verify 4KV ESF Busses energized
  • Bus 141 bus alive light lit
  • Bus 142 bus alive light lit CREW Determine SI needed/actuated:
  • SI ACTUATED lit (1-BP-4.1)
  • SI Equipment actuated
  • Manually Actuate SI CREW (If manual SI not previously performed) Recognize and respond to conditions requiring a Safety Injection in accordance with 1BEP-0 REACTOR TRIP OR SAFETY INJECTION, Step 4:
  • Pressurizer pressure cannot be maintained > 1829 psig
  • Pressurizer level cannot be maintained > 4%
  • Manually initiate SI Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior BOP/US Verify Feedwater isolation:

  • FW pumps tripped
  • Isolation monitor lights lit
  • FW discharge valves (1FW002A/B/C) closed RO/US NOTE: 1SI8801B may be opened at this point while verifying pump alignments (CT on page 18)

Verify ECCS pumps running:

  • CV pumps
  • RH pumps

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior BOP/US Verify Containment Conditions:

  • RCFC Accident Mode lights lit (Group 2)
  • Phase A lights lit (Group 3)
  • Containment Ventilation lights lit (Group 6)

BOP/US Verify the following:

  • 1A and 1B AFW pumps running
  • 1AF013A-H open
  • 1AF005A-H throttled
  • 1A and 1B CCW pumps running
  • 1A and 1B SX pumps running

>8.2 psig NOTE: RCP Trip criteria may be met at this point RO/BOP Determine if RCPs meet trip criteria

  • Controlled cooldown not in progress
  • RCS pressure <1425 psig
  • High head SI flow indicator (1FI-917) >100 gpm or SI pump discharge flow >200 gpm
  • Trip RCPs NOTE: This sequence may not happen until the size of the LOCA is increased.

BOP/US Check If Containment Spray required:

  • Containment pressure > 20 psig
  • Group 6 lights NOT lit Identifies/reports B Train of CS not operating properly
  • Manually actuates both switches for CS and Phase B actuation at 1PM05J and 1PM06J
  • Determines manual actuation unsuccessful. Performs Attachment B. (Train A CS is OOS)
  • 1CS001B open
  • 1CS007B closed
  • Places 1B CS pump PULL OUT

[CT]

  • Verify TEST switch to normal EP-0E
  • Opens 1CS007B after 30 second time delay
  • Restarts 1B CS pump
  • Verify 1CS019B open
  • Verify 1CS010B open
  • Verify 1 CS pump running
  • Phase B lights Lit
  • Verifies Eductor Suction flow > 15 gpm (1FI-CS014)

BOP Align SX Cooling Towers

  • All eight riser valves open
  • 0SX163A thru 0SX163H
  • All four Hot Water Basin Bypass valves closed
  • 0SX162A thru 0SX162D

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior BOP Verify Total AFW flow:

  • AFW flow > 500 gpm
  • SG levels maintained between 10% (31% Adverse) and 50%
  • SG levels not increasing in an uncontrolled manner RO Verify ECCS valve alignment

[CT]

  • Group 2 Cold Leg Injection monitor lights lit - OPEN 1SI8801B EP-0--I
  • Align SVAG Valve power switches and dispatch NLO to energize breakers ECCS Operations:
  • High Head SI flow > 100 gpm
  • RCS pressure < 1700 psig
  • SI pump flow > 200 gpm
  • RCS pressure < 325 psig o RH pump flow > 1000 gpm Pressurizer PORV relief path available:
  • At least one block valve energized
  • Associated block valve open BOP Verify Main Generator Trip:
  • Output Breakers open
  • 1SX169A and B open
  • Dispatch operator for local check of EDG operation Examiners note: US and RO will likely continue in 1BEP-0 while BOP is performing the next 3 ventilation steps:

BOP Verify Control Room ventilation aligned for emergency operations:

  • Dispatch NLO to trip VV supply fans
  • Operating VC train equipment running
  • Supply fan
  • Return fan
  • M/U fan
  • Chilled water pump
  • MCR chiller 0A running
  • M/U fan outlet damper not full closed 0VC24Y
  • VC train M/U filter light lit
  • Operating VC train Charcoal Adsorber aligned for train A
  • 0VC43Y closed
  • 0VC21Y open
  • 0VC22Y open

° Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Verify Auxiliary Building ventilation aligned

  • Two inaccessible filter plenums aligned
  • Plenum A fan 0VA03CB running
  • Plenum C fan 0VA03CF running

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior

  • Damper 0VA438Y closed BOP Verify FHB ventilation aligned
  • Train B fan 0VA04CB running
  • 0VA055Y open
  • 0VA062Y open
  • 0VA435Y closed RO/US Check Pressurizer sprays & PORVs closed
  • Normal spray valves closed 1RY455B and 1RY455C
  • PORVs closed 1RY455A and 1RY456 CREW Maintain RCS temperature control

° With any RCP running, RCS Tave stable at or trending to 557 degrees F.

° With No RCP running, RCS Cold Leg temperature stable at or trending to 557 degrees F.

CREW Check status of RCPs

  • Determine if RCPs are running.
  • Check if RCPs should be stopped:
  • ECCS flow- high head > 100 gpm; or SI pump > 200 gpm.
  • RCS pressure < 1425 psig.
  • Controlled cooldown NOT in progress, nor previously initiated.

BOP/CREW Check Secondary Pressure Boundaries are intact

  • No SG pressure decreasing in uncontrolled manner
  • No SG completely depressurized BOP/CREW Check SG tube intact
  • No abnormal secondary radiation BOP/CREW Check RCS intact
  • Containment area radiation monitors > alert alarm setpoints
  • Containment pressure > 3.4 psig
  • Containment sump level lights lit US Implement and direct actions of 1BEP-1, LOSS OF REACTOR OR SECONDARY COOLANT o Get acknowledgements from RO and BOP.
  • No RCPs running BOP Check SG Secondary pressure boundaries intact
  • No SG Pressure decreasing uncontrollably
  • No SG completely depressurized Check intact SG levels
  • Narrow range levels > 10% (31% Adverse)
  • Control Intact SG levels to 10% (31% Adverse) to 50% NR level
  • Narrow range levels NOT increasing in uncontrolled manner Check Secondary Radiation levels normal
  • No abnormal secondary radiation

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior RO Check Pressurizer PORVs and isolation valves:

  • PORV Isolation valves open and energized
  • 1RY8000A
  • 1RY8000B
  • 1RY455A
  • 1RY456 CREW Check if ECCS flow should be reduced:

° RCS Subcooling not acceptable

° Secondary heat sink acceptable

  • RCS pressure decreasing
  • Pzr Level <12%

Determine ECCS flow should NOT be reduced.

NOTE: Scenario Termination criteria is completion of step 6 of 1BEP-1 or step 6 1BEP ES-1.3 US Implement and direct actions of 1BEP ES-1.3, TRANSFER TO COLD LEG RECIRCULATION when RWST level < 46% (Actions on page 23)

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior NOTE: At some time Containment pressure may rise to an ORANGE Path condition (without CS pumps running). If so, performance of 1BFR Z.1 RESPONSE TO HIGH CONTAINMENT PRESSURE may be required. Actions are covered below. CUE will be provided by the STA after monitoring the BSTs.

US Implement and direct as advised by the STA the actions of 1BFR-Z.1, RESPONSE TO HIGH CONTAINMENT PRESSURE.

o Get acknowledgements from RO and BOP.

  • Inform SM of plant status for evaluation of E-Plan BOP Verify Containment isolations
  • Phase A Group 3 lights lit
  • Containment Ventilation Group 6 lights lit Check if Containment Pressure has increased to > 20 psig (1PR-937 or 1PI-CS934 thru 937)
  • Stop all RCPs (previously completed)

Verify CS alignment: (previously complete for B Train)

US/BOP Verify Group 6 Phase B isolation lights lit (previously completed)

Verify RCFCs running in accident mode (Group 2 lights lit).

Verify Main Steam Isolation

Determine NO SGs are faulted:

  • No Steam Generator completely depressurized Return to step and procedure in effect.

NOTE: ACTIONS FOR 1BEP ES-1.3, TRANSFER TO COLD LEG RECIRCULATION Byron 2003-301 1 Scenario 03-2

Scenario No: 03-1 Event No. 7,8 Event

Description:

LOCA / Failure of CS to actuate Time Position Applicants Actions or Behavior BOP/RO Perform actions of 1BEP ES-1.3 as directed:

Check CC pumps 2 running Open CC to RH Heat exchanger isolation valves

  • 1CC9412A and 1CC9412B Check CC flows to RH Heat exchanger
  • >5000 gpm Verify adequate Containment sump level
  • Bottom 4 lights lit Align RH pump suctions to Containment sumps:
  • Place control switches for SVAG valves 480 bus feeds in close
  • Check Both RH pumps running
  • Check open 1SI8811A and 1SI8811B
  • Close 1SI8812A and 1SI8812B Check SI and CV pumps in injection mode:
  • SI pumps both running
  • Cold Leg Injection valves (1SI8801A/B) open Align SI and CV pumps for Cold Leg Recirculation:
  • Dispatch operator to energize 1SI8806 and 1SI8813
  • Verify CV pump 1A miniflow isolation valves closed
  • 1CV8111 and 1CV8114
  • Close SI pump miniflow isolation valves
  • 1SI8814, 1SI8920, and 1SI8813 when power restored
  • Close RH Heat exchanger Discharge Cross ties
  • 1RH8716A and B
  • Open SI and CV pump suction header Cross ties
  • 1SI8807A and B, and 1SI8924
  • Check 1A RH pump running
  • Open 1CV8804A
  • Check 1B RH pump running
  • Open 1SI8804B Start ECCS pumps as necessary (NOTE: Scenario may be terminated at this point)

Byron 2003-301 2 Scenario 03-2

Simulation Facility Byron Scenario No. 2 Operating Test No. 2003-301 Examiners: _______________________ Applicant: ______________________ SRO

_______________________ ______________________ RO

_______________________ ______________________ BOP Initial Conditions: IC-18, 75% power, steady state, BOL.

Turnover: Ramp to full power requested by Electric Operations. 1A Motor driven FW is out of service due to breaker cubicle work.

Event Malf. No. Event Event No. Type* Description Preload RF RP64 OUT C BOP 1B Auxiliary Feedwater pump fails to auto start, can be RF RP71 OUT manually started.

RF RP95 OUT RF RP97 OUT FW43 C BOP 1A Auxiliary Feedwater pump fails to auto or manually start.

MS01A 75 C RO All Main Steam isolation valves fail partially open, no closure MS01B 80 BOP available.

MS01C 60 SRO MS01D 90 FW45E, 100 C BOP 1AF005E potentiometer fails to 100% demand.

Override ZDI1AF013E C BOP 1AF013E stuck open.

AUTO SRO 1 RX29A 65 C BOP Steam Generator 1A Feedwater regulating valve Controller SRO card failure resulting in manual control of Feedwater regulating valve 2 R RO Raise Reactor Power using rods and dilution SRO N BOP Ramp up turbine power from 75% to full power.

3 RX13A, 0 I RO 1LT-459, Controlling Pressurizer level channel fails low.

SRO 4 CV09, 50 C RO 1TCV-130A modulates closed SRO 5 MS04D, 100 C BOP 1MS018D, 1D SG PORV fails open.

SRO 6 CC03B I BOP Component Cooling (CC) Surge Tank level transmitter level CC01C SRO tree leak results in auto makeup and 1B CC pump trip with CC02A failure of 1A CC pump auto start on low header pressure.

7 MS07A, 2.0 M BOP 1A SG Steam line break (2 MLB/HR) inside containment. 4 RO faulted steam generators.

(Pre-loaded) SRO All MSIVs fail to Close. Stuck open 8 1A and 1B AFW pumps C BOP Pre-loaded. 1A Auxiliary Feedwater pump fails to start. 1B fail to Start SRO Auxiliary Feedwater pump can only be manually started.

  • (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient Byron 2003-301 3 Scenario 03-2

Scenario No: 03-2 Event No. 1 Event

Description:

Steam Generator 1A Feedwater regulating valve automatic control card failure Time Position Applicants Actions or Behavior CUE Annunciators:

1-4-A3 PROCESS I&C CAB PWR SUP FAILURE 1-15-A9 STEAM GENERATOR 1A LEVEL DEVIATION HIGH LOW Increased Feed Flow to 1A SG Increasing 1A SG Level BOP Diagnose/Recognize failure of 1A Feedwater regulating valve Auto Controller.

  • Announce placing 1A Feedwater regulating valve Controller in manual.
  • Manually control 1FW510 to stabilize/restore level.
  • Dispatch operator to 1PA05J to check for failure lights per BAR 1-4-A3 US Diagnose/Acknowledge failure of 1A Feedwater regulating valve Auto Controller.
  • Orders WEC to generate WR, CR, and get maintenance involved for repairs.

RO Monitors Reactor and Primary parameters for possible effects:

  • Reactor power and Delta I.
  • Reports status to US.

Assists BOP as directed by US:

o Reviews BARs.

Note: Following actions from the failed controller the candidates should start the power change.

Scenario No: 03-2 Event No. 2 Event

Description:

Raise turbine load and reactor power.

Time Position Applicants Actions or Behavior CUE Turnover information includes request from Electric Operations for an increase in Unit 1 MW to full load (1260 MWe) to begin ASAP at 5 MWe/minute.

Note: A portion of the power increase preparations may have been performed in the briefing room US Implement actions of 1BGP 100-3

  • Initiate load swing instruction sheet (1BGP 100-4T2 Boration Dilution Boundary Calculation).

o Contact Chemistry and Health Physics for load change > 15% in one hr.

  • Inform SM of plant Status, and Electric Operations of ramp start.

CREW Review Applicable Precautions, Limitations and Actions.

RO Verify rod position and boron concentration.

Perform reactivity manipulation calculation to determine amount of RCS dilution and expected rod outward movement to maintain Delta I within the limits of BCB-1 Fig. 19.

Determine required dilution volume by:

o Effects of previously performed dilutions.

o Byron Boration Dilution Tables.

Initiate Dilution in accordance with BOP CV5:

IF BATCH addition desired:

  • Determine the desired change in RCS Tave
  • Determine required gallons of primary water to change Tave IF Calculated addition desired:
  • Determine required gallons of primary water to decrease RCS boron as desired NOTE: The remaining steps will be performed for either method of dilution
  • Determine required primary flow rate
  • Place MAKE-UP MODE CONT SWITCH to stop position
  • Set MODE SELECT to dil or alt dil position
  • Set 1FK-111 PW/Total Flow Control to desired flow rate (may leave at current value if Batch method used)
  • Set 1FY-0111 PW/Total Flow Preset Counter to desired volume.
  • Place MAKE-UP MODE CONT Switch to start.
  • Verify proper operation of valves (1CV111A opens, 1CV111B opens, PW flow indicated on recorder).

BOP Initiate turbine load increase:

  • Verify the DEHC IMP IN, SPEED IN, and MW IN half of the pushbuttons are illuminated.
  • Depress the LOAD RATE MW/MIN pushbutton.
  • Enter the desired load rate (5 MW).
  • Depress the ENTER pushbutton.
  • Depress the REF pushbutton.
  • Enter the desired MW on the REFERENCE DEMAND Window using the numbered pushbuttons (1120).
  • Depress the ENTER pushbutton.
  • Depress the GO pushbutton when directed by the US/RO.
  • Verify load begins to increase.

o Monitor 1A SG Level

Scenario No: 03-2 Event No. 2 Event

Description:

Raise turbine load and reactor power.

Time Position Applicants Actions or Behavior RO Monitor power increase:

  • Monitor Reactor power, Tave, and Delta I.
  • Verify control rods automatically move to maintain Tave within + 1.0 degree F of Tref.

If Diluting:

  • Monitor VCT level.
  • Monitor PW/Total counter.
  • Verify dilution auto stops at preset value.
  • Return Reactor Makeup system to blended flow at current boron concentration.

Note: Following clearly observable plant response from the reactivity changes and lead examiners concurrence, the next event can be initiated.

Scenario No: 03-2 Event No. 3 Event

Description:

1LT-459 Controlling Pressurizer level channel fails LOW.

Time Position Applicants Actions or Behavior CUE Annunciators:

1-12-A4 PZR LVL LOW HTRS OFF LTDWN SECURED 1-12-A5 PZR HTR TRIP 1-12-B4 PZR LEVEL CONT DEV LOW 1-12-C5 PZR PHASE LOSS OR REVERSAL 1-12-D5 PZR HTR SCR CLG FAN FAILURE 1LI-459 indicating 0%

US Diagnose/Acknowledge failure of 1LT-459, Controlling Pressurizer level channel and loss of letdown.

Implement and direct the actions of 1BOA INST-2 Attachment C, PRESSURIZER LEVEL CHANNEL FAILURE

  • Identify failed Pressurizer level channel 1LT-459 o Get acknowledgements from RO and BOP.
  • Informs SM of plant status for evaluation of E-Plan o Direct WEC to write WR, CR, and get maintenance involved.

o Evaluate holding the ramp and dilution o Briefs RO and Unit 2 assist NSO on bistable tripping.

RO/US Diagnose failure of 1LT-459.

  • Announce failure and loss of letdown flow.

Perform actions of 1BOA INST-2 Attachment C, PRESSURIZER LEVEL CHANNEL FAILURE as directed by US:

  • Check Pressurizer level
  • If not normal, take manual control (Pressurizer Master Level controller and/ or 1CV121) to restore level.
  • Select operable channel (461/460, left position) for Pressurizer level control.
  • Select operable channel to level recorder (ANY but 459, normally on 460).
  • Verify Pressurizer level > 17%.

NOTE: may be performed by RO or BOP

  • Check Letdown established
  • Re-establishes Letdown IAW BOP CV-17, ESTABLISHING AND SECURING NORMAL AND RH LETDOWN FLOW
  • Restores heaters to normal.
  • Restores automatic level control (Pressurizer Master Level Controller and/or 1CV121).
  • Coordinates bistable tripping (expected alarm 1-12-A3).
  • LB459A BOP Performs actions as directed by US/RO:
  • Assist RO as directed by US/RO with panel monitoring.

o Hold/control ramp o Monitor 1A SG Level RO/BOP Re-establishing Letdown per BOP CV-17:

  • Verify close 1CV8149A,B, and C .

o Assumes CC is still aligned properly to Letdown HX.

  • Place 1CC-130 in manual and raise demand to 20%.
  • Place 1CV-131 in manual and raise demand to 20%.
  • Verify open 1CV8401A/B
  • Verify close 1CV381A
  • Verify open 1CV381B
  • Verify open 1CV8160 and 1CV8152
  • Verify open 1CV8389A/B.
  • Verify open 1CV459 and 1CV460.

Scenario No: 03-2 Event No. 3 Event

Description:

1LT-459 Controlling Pressurizer level channel fails LOW.

Time Position Applicants Actions or Behavior

  • Verify open 1CV8324A/B and 1CV8389A/B.
  • Verify open 1CV8149A/B/C as desired.
  • Ensure 1CC-130 maintains temperature between 105 and 115 degrees F (1TI-130) and place in AUTO
  • Adjust in manual 1CV121 to match charging with letdown while establishing Pressurizer at program level and place in automatic.

US Refer to Tech Spec

  • 3.3.1 Reactor Trip System Instrumentation Condition K - trip channel within 6 hrs.
  • 3.3.3 Post Accident Monitoring Instrumentation Condition B - Restore within 30 days NOTE: Following actions for failed Pressurizer level channel and lead examiners concurrence, the next event may be initiated.

Scenario No: 03-2 Event No. 4 Event

Description:

Failure of 1TCV-130A to control temperature / modulates closed.

Time Position Applicants Actions or Behavior CUE Annunciators:

1-9-E2 LTDWN TEMP HIGH 1-2-D7 CNMT PEN CLG FLOW HIGH LOW 1-8-C5 LTDWN HX OUTLET TEMP HIGH Indicated Letdown Heat Exchanger outlet temperature decreasing (1TI-130)

Letdown Heat Exchanger outlet temperature controller 1TK-130 demand decreasing or 0%

1TCV-129 Diverts to VCT Note: Crew may enter 1BOA PRI-6 due to the high letdown temperature US Diagnose/Acknowledge failure of 1TI-130.

o Direct use of BARs.

o Direct manual control of Letdown Heat Exchanger outlet temperature controller 1TK-130 Controller to re-establish proper letdown cooling flow.

o Direct closing letdown orifice isolation valves o 1CV8149A o 1CV8149B o 1CV8149C

  • Determine automatic control problem.

o Dispatch operator to locally check valve and reports status to crew.

  • Contact Chemistry for Demin Effluent sample.
  • Informs SM of status.

o Order WEC to generate WR, CR, and get maintenance involved for repairs RO Announce increasing letdown temperature trend and 1CC-130A closed.

o Dispatch operator to locally check valve and reports status to US.

  • Verify High Temperature divert valve diverts letdown flow and reports to US.

o Take manual control of 1CC-130 and restores cooling flow.

o Reduce flow by closing letdown orifice isolation valves o 1CV8149A o 1CV8149B o 1CV8149C

  • Verify 1-9-E2 clears.
  • Determine automatic control problem and reports to US.
  • Restore letdown flow to VCT when directed by US.

BOP Review BARs Monitor control board indications.

o Hold/control ramp.

o Dispatch operator to locally check valve and reports status to US.

o Dispatch operator to reset containment penetration cooling flow low o Monitor 1A SG Level o Assist RO as directed by SRO NOTE: Following actions for failed temperature instrument and lead examiners concurrence, the next event may be initiated.

Scenario No: 03-2 Event No. 5 Event

Description:

1MS018D, 1D SG PORV Fails OPEN.

Time Position Applicants Actions or Behavior CUE Indications:

RCS Tave decreasing Reactor power increasing Reactor power/ turbine power mismatch increasing Red PORV open position indication light lit.

LVDT meter indication increasing above 0%.

BOP Diagnoses 1D SG PORV open

  • Determine SG pressure is below setpoint (1115 psig)
  • Report failure to US.

Perform actions directed by US:

  • Place PORV control switch to close.

o Report/Acknowledge SG 1D PORV TROUBLE annunciator (1-15-D10) as expected alarm.

o Dispatch operator to AEER to PORV controller box.

o Dispatch operator to locally isolate 1MS018D by closing 1MS019D.

  • Report status to US.

US Diagnose/Acknowledge failure of 1D SG PORV open and direct actions:

o Determine SG pressure < PORV setpoint.

o Dispatch operator to isolate PORV by closing 1MS019D.

  • Inform SM of plant status.

o Order WEC to generate WR, CR, and get maintenance involved for repairs.

RO Diagnose/Acknowledge failure of 1D SG PORV OPEN.

Monitor Reactor and Primary parameters for effects and expected response:

o Reactor Power o Tave, Delta I and rod motion.

o Assist as directed by US.

o Investigate BARs.

US Refer to Tech Spec

  • 3.7.4 Steam Generator PORVs Condition A - Restore within 30 days o 3.6.3. Containment Isolation Valves (not applicable, PORV is in its isolation position.)

NOTE: Following actions for failed PORV and lead examiners concurrence, the next event may be initiated.

Scenario No: 03-2 Event No. 6 Event

Description:

Component Cooling (CC) Surge Tank level transmitter level tree leak results in auto makeup and 1B CC pump trip with a failure of 1A CC pump to auto start.

Time Position Applicants Actions or Behavior CUE: Annunciators:

1-2-A5 CC SURGE TANK LEVEL HIGH/LOW 1-2-E4 CC SURGE TANK AUTO M/U ON 1-2-A4 CC PUMP TRIP 1B CC pump trip indication 1LI-676 indication at 0%

NOTE: 1BOA PRI-6, COMPONENT COOLING MALFUNCTION, may be referenced but is not written to address a CC surge tank level tree leak.

BOP/US Identify/report:

  • CC Surge tank level low
  • Automatic makeup with CC Surge tank demin water makeup valve 1CC183 open
  • 1B CC pump trip
  • 1A CC pump did not automatically start o Refer to BARs CREW Determine CC Surge tank level tree leak.

o Dispatch operator to investigate

  • Dispatch operator to locally isolate make-up from Demin Water.
  • Directs operator to locally drain CC surge tank level to normal range as appropriate.

BOP Refer to BAR 1-2-E4 and manually control CC Surge tank level.

  • Manually start 1A CC pump
  • Dispatch operator to check 1A CC pump for proper operation.

US Refer to Tech Specs

  • 3.7.7 Component Cooling System Condition B - restore in 7 days (for 1B CC pump trip) o If the crew decides to conservatively declare the 1A CC pump inoperable until further information is available then LCO 3.0.3 would apply.

NOTE: Following local isolation of demin makeup, and lead examiners concurrence, the next event may be initiated.

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior CUE Annunciators:

1-1-A2 CNMT DRAIN LEAK DETECT FLOW HIGH 1-3-D4 CNMT PRESS HIGH 1-11-E1 CNMT PRESS HIGH SI/RX TRIP 1-15-A/B/C/D4 SG 1A/B/C/D LEVEL LOW 1-15-E4 P-4 FW ISOL Indications:

Containment pressure increasing RCS temperature decreasing Increased steam flow US/CREW Implement and direct the actions of 1BEP-0, REACTOR TRIP OR SAFETY INJECTION o Get acknowledgements from RO and BOP.

  • Informs SM of plant status for evaluation of E-Plan o Manually trip reactor or respond to Auto Trip o Manually SI or respond to Auto SI RO Perform actions of 1BEP-0:

Verify reactor trip:

  • Rod bottom lights Lit.
  • Neutron flux decreasing.

BOP Verify Turbine tripped

  • All throttle valves closed
  • All governor valves closed Verify 4KV ESF Busses energized
  • Bus 141 bus alive light lit
  • Bus 142 bus alive light lit RO Determine SI needed/actuated:
  • SI ACTUATED lit (1-BP-4.1)
  • SI Equipment actuated
  • Manually Actuate SI BOP Verify FW Isolation:
  • FW pumps tripped.
  • FW Isolation Monitor Lights lit.
  • FW pumps discharge valves (1FW002A,B, and C) closed.

RO/US Check ECCS pumps running:

  • Both CV pumps.
  • Both RH pumps.
  • Both SI pumps.

BOP/US Verify Containment Conditions:

  • RCFC Accident Mode lights lit (Group 2)
  • Phase A lights lit (Group 3)
  • Containment Ventilation lights lit (Group 6)

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior BOP Verify AFW SYSTEM:

CT o Report neither AFW pump auto started.

E-0--F o Attempt start of Both AFW pumps.

  • Manually Start 1B AFW pump.

o Report failure of 1A AFW pump to manually start (after attempt).

o Report 1B AFW pump was manually started (after attempt).

o Dispatch operator(s) to check 1A AFW pump and breaker to investigate failure to start.

o Dispatch operator(s) to check 1B AFW pump to ensure proper operation.

  • 1AF013E-H open (No running pump on Train A) o 1AF005E full open
  • 1AF005F-H throttled. (No running pump on Train A)

BOP Verify Pumps Running:

  • 1A CC pump.

o U0 CC pump

  • Both SX pumps.

CREW Determine Steamline Isolation Required:

  • Any SG pressure < 640 psig (or will become < 640 psig).
  • Containment pressure approaching 8.2 psig or has exceeded 8.2 psig.
  • Actuate Main Steam isolation (Both switches, and the individual MSIV switches) and verify Main Steam isolation bypasses closed.

Note: CS will eventually be required due to 4 SGs blowing down inside containment. When pressure exceeds 20 psig, then following step must be performed.

BOP Check if Containment Spray required:

  • Containment pressure increased to > 20 psig
  • Group 6 CS Monitor lights lit.
  • Group 6 Phase B Isolation Monitor lights lit.

BOP Align SX Cooling Towers

  • All eight riser valves open
  • 0SX163A thru 0SX163H
  • All four Hot Water Basin Bypass valves closed
  • 0SX162A thru 0SX162D
  • > 500 gpm.
  • Control feed flow to maintain narrow range SG levels 10% (31% Adverse) to 50%.
  • Verify no SG level is increasing in an uncontrolled manner.

RO/BOP Verify ECCS Valve Alignment:

  • Group 2 Cold Leg Injection lights lit.

o Reports Exceptions (1B CC pump, and 1A AFW pump)

  • Align SVAG Valve power switches and dispatch NLO to energize breakers RO Verify ECCS Flow:
  • High Head SI flow > 100 gpm

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior o RCS pressure < 1700 psig o SI pump flow > 200 gpm

  • RCS pressure > 325 psig
  • RH pump flow < 1000 gpm RO Pressurizer PORV relief path available:
  • At least one block valve energized
  • PORV in automatic Associated block valve open Examiners note: US and RO will likely continue in 1BEP-0 while BOP is performing the next 3 ventilation steps:

BOP Verify Control Room ventilation aligned for emergency operations:

  • Dispatch NLO to trip VV supply fans
  • Operating VC train equipment running
  • Supply fan
  • Return fan
  • M/U fan
  • Chilled water pump
  • MCR chiller 0A running
  • M/U fan outlet damper NOT full closed 0VC24Y
  • VC train M/U filter light LIT
  • Operating VC train Charcoal Adsorber aligned for train A
  • 0VC43Y closed
  • 0VC21Y open
  • 0VC22Y open o Control Room pressure greater than +0.125 inches water on 0PDI-VC038 BOP Verify Auxiliary Building ventilation aligned
  • Two inaccessible filter plenums aligned
  • Plenum A fan 0VA03CB running
  • Plenum C fan 0VA03CF running
  • Damper 0VA438Y closed BOP Verify FHB ventilation aligned
  • Train B fan 0VA04CB running
  • 0VA055Y open
  • 0VA062Y open
  • 0VA435Y closed RO Check Pressurizer sprays & PORVs closed
  • Normal spray valves closed 1RY455B and 1RY455C
  • PORVs closed 1RY455A and 1RY456 RO Maintain RCS Temperature Control:

o With any RCP running, RCS Tave stable at or trending to 557 degrees F.

o With No RCP running, RCS Cold Leg temperature stable at or trending to 557 degrees F.

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior BOP/RO If temperature is < 557 and decreasing, then perform the following:

  • Stop dumping steam.
  • Maintain total feed flow > 500 gpm until at least 1 SG is > 10 % (31% Adverse).
  • Verify the following valves closed:
  • Steam Dump valves.
  • MS RHTR Shutoff valves (1MS009A-D).
  • MS RHTR S/U Purge Control Valves (1MS067A-D).
  • MFP turbine HP Stop valves.

Note: Containment pressure may have reached the spray initiation point, and the RCPs could be already stopped. If so, the diagnostic for a faulted SG will be performed and not all of the following steps will be necessary.

RO CHECK Status of RCPs:

  • Determine if RCPS are running.
  • Check if RCPS should be stopped:
  • ECCS flow- high head > 100 gpm; or SI pump > 200 gpm.
  • RCS pressure < 1425 psig.
  • Controlled cooldown NOT in progress, nor previously initiated.

CREW Determine faulted SG(s) exist:

  • ALL SG pressure decreasing uncontrollably.
  • Any SG completely depressurized.

CREW/US Implement and direct the actions of 1BEP-2, FAULTED STEAM GENERATOR ISOLATION:

  • Announce transition to 1BEP-2 o Get acknowledgements from RO and BOP.
  • Inform SM of plant status, evaluate for E-Plan.
  • Request STA report to control room for Status Tree monitoring.

Examiners Note: The STA will monitor Status Trees when requested by the US/Crew. A challenge to Containment could be identified by the STA and he will make the recommendation to transition to and implement 1BFR-Z.1, Response to Containment High Pressure if containment pressure exceeds 20 psig, even if spray is already operating. Refer to page 20 for the evaluation of the crew when in 1BFR-Z.1.

BOP/RO Check Main Steam Isolation:

  • Manually actuate Main Steamline isolation US Determine All Steam Generators are Faulted:
  • Check pressures in all SGs, and determine none are stable or increasing.

Implement and direct the actions of 1BCA-2.1 UNCONTROLLED DEPRESSURIZATION OF ALL SG

  • Announce Transition to 1BCA-2.1 o Get acknowledgements from RO and BOP.
  • Inform SM of plant status, evaluate for E-Plan.

BOP Check Secondary Pressure boundary:

o Request maintenance assistance to close MSIVs.

  • Verify Main Steam isolation bypass valves all closed.
  • Check FW Isolated to all SGs (FWI Monitor lights lit).

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior

  • Check SG Blowdown Isolation and Sample valves all closed.

BOP/RO Control Feed Flow to Minimize RCS Cooldown:

CT

  • Determine cooldown rate in all RCS cold legs > 100 degrees F in any one hour.

CA-2.1A.

o Set 1AF005E flow controller to 0%.

o Attempt to throttle 1AF013E

  • Dispatch operator to locally close 1AF005E.
  • Check Hot Leg temperatures stable or decreasing.

RO/BOP Check Status of RCPs

  • NO RCPs running Monitor AFW pump Suction Pressure:
  • 1-3-E7 AF PUMP SX SUCT VLVS ARMED not lit.

RO Check Pressurizer PORVs and isolation valves:

  • PORV isolation valves 1RY8000A and 1RY8000B energized.
  • PORV 1RY455A and 1RY456 closed.
  • PORV isolation valves at least one open.

BOP/US Check Secondary radiation

  • Reset Phase A Isolation.
  • Request Chemistry to sample all SGs.
  • Check Secondary Radiation trends normal for plant conditions:
  • SJAE/GS Exhaust.
  • SG Blowdown Liquid.
  • Main Steamline Radiation.

CREW Determine RH pumps can be stopped:

  • Both RH pumps running with suction aligned to the RWST.
  • RCS pressure stable or increasing and > 325 psig.
  • Reset SI, and verify SI Actuated light not lit, and the AUTO SI BLOCKED light lit.
  • Stop RH pumps and place in standby.

Note: If CS is stopped in the next step, Containment pressure must be monitored for CS restart conditions (> 20 psig).

BOP/US Check if CS can be stopped:

  • Both CS pumps are running.
  • Reset CS signal.
  • Spray additive tank low 2 lights are not lit
  • Close 1CS019A and 1CS019B (per Caution prior to step 8, 1BCA-2.1).

Check Containment pressure < 15 psig.

  • If Containment pressure < 15 psig, stop both CS pumps.
  • If CS pumps stopped, Verify/Close 1CS019A and 1CS019B, and 1CS007A and 1CS007B.

Examiners Note: Scenario termination is completion of Step 8 of BCA-2.1 or Entry into BEP ES-1.3 Note: The following is to be used whenever the crew implements 1BFR-Z.1, Response to High Containment Pressure.

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior US

  • Implement and direct the actions of 1BFR-Z.1:
  • Announces procedure transition o Get acknowledgements from RO/BOP.
  • Informs SM of plant status and E-Plan evaluation.

RO/BOP Perform actions of 1BFR-Z.1 as directed:

  • Verify Containment isolation Phase A- Group 3 Containment isolation monitor lights lit.
  • Verify Containment Ventilation isolation- Group 6 Containment Vent isolation monitor lights lit.
  • Determines CS is required (Containment pressure has increased to > 20 psig).
  • Stops all RCPs if NOT previously stopped.

BOP o Performs actions of 1BFR-Z.1 as directed:

  • Verifies proper CS system alignment:
  • CS suction valves open
  • 1CS001A\ 1CS009A, or 1CS001B\ 1CS009B.
  • 1CS007A and 1CS007B.
  • CS eductor spray additive valves open
  • 1CS019A and 1CS019B.
  • CS eductor inlet flow control valves open
  • 1CS010A and 1CS010B.
  • CS pumps running.
  • Group 6 Phase B lights Lit.
  • Reset CS signal.
  • Check Spray additive tank LO-2 lights
  • then closes 1CS019A and 1CS019B even if NOT lit per Caution prior to Step 3, 1BFR-Z.1 (Secondary Break only).

Align SX Cooling Towers

  • All eight riser valves open
  • 0SX163A thru 0SX163H
  • All four Hot Water Basin Bypass valves closed
  • 0SX162A thru 0SX162D
  • Verify RCFCs running in Accident Mode
  • Group 2 RCFC Accident Mode status lights lit.
  • Determines Main Steamline isolation necessary and manually actuates Main Steamline isolation and verifies Main Steam bypass valves closed. Reports all Main Steam isolation valves still open.

BOP o Determine all SGs are faulted and controls AFW Flow:

  • Any SG pressure decreasing uncontrollably or completely depressurized.
  • Control AFW flow to 1B, 1C, and 1D SG at 45 gpm per SG by throttling 1AF005F, G, and H; or CT: 1AF013F, G, and H.

CA-2.1A.

  • Attempt Control of AFW to 1A SG via 1AF005E, and 1AF013E and reports no control available.

o Set potentiometer for 1AF005E to 0%.

  • Dispatches operator to locally throttle 1AF005E.
  • Checks FW isolated to all SGs
  • All FW Isolation Monitor lights lit.

Scenario No: 2 Event No. 7 Event

Description:

1A SG Steam line break inside containment resulting in a Reactor trip, all MSIVs fail open, 4 faulted SGs.

Manual actions required to establish and control AFW flow.

Time Position Applicants Actions or Behavior US

  • Returns to step and procedure in effect:
  • Announces procedure transition and gets acknowledgements for RO and BOP.
  • Informs SM of Status.
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