ML040140746
| ML040140746 | |
| Person / Time | |
|---|---|
| Site: | Byron  |
| 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) | |
Text
Byron 2003-301 Scenario 03-1 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 No.
Malf. No.
Event Type*
Event Description Preload RP02A&B CS01A FW35C ED06D M RO SRO BOP M BOP Failure of RTB A&B to auto and manually open. (can be opened locally) 1A CS pump OOS Failure of CS to Actuate on Hi-3 Cnmt Press. Train B CS must be manually started from the MCR 1C HD pump OOS 6.9KV Breaker 1591 fails to ABT.
Preload (preload note)
C RO SRO 1SI8801A will not auto open nor open from the MCB 1SI8801B will not open automatically. Will open manually from MCB 1
N BOP SRO Ramp down turbine power to 1000 Mwe at directed MW/min 1
R RO SRO Lower reactor power using rods and/or boration.
2 RX21A 2500 I RO SRO 1PT-455 Controlling Pressurizer Pressure channel fails high (over 30 second ramp) 3 RX03E, 0 I BOP SRO Steam Flow Transmitter 1FT-532 (input to controlling channel) fails low over 3 minute ramp 4
RD09, 8 C RO SRO Automatic rod motion fails at 8 step per minute.
5 ED05D M BOP RO SRO SAT feed breaker to bus 159 trips opens, no ABT. Loss of RCS flow (Loop 1D) ATWS 6
RP02A,B M RO BOP SRO Reactor Trip Breakers fail to open / ATWS 7
TH06 M RO BOP SRO LOCA inside containment. Leads to high-3 containment pressure 8
preload C BOP RO SRO Failure of CS to auto actuate.
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
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)
Determine required boric acid volume
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
Determine required boric acid flow rate
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, I, 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
Monitor Boric Acid blender counter
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.
Determine Operable Channel not selected
Place the Master Pressurizer Pressure Controller in Manual
Control Pressurizer Pressure
Select an operable channel.
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.
Select operable channels to Recorders:
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.
3.3.4 Remote Shutdown System Condition A - Restore within 30 days
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.
Select operable Steam flow channel
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:
RCS Tave
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
Reactor trip & bypass breakers not open
Neutron flux not decreasing Manually attempt to trip reactor with both switches at:
1PM05J
1PM06J RO Identify/report that reactor trip breakers did not open.
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
[CT]
FR-S.1--C Insert control rods at 48 spm in Manual. (automatic is failed to 8 spm)
[CT]
Verify turbine trip
Turbine throttle valves not closed
Turbine governor valves not closed
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
Start boric acid transfer pump
Check emergency boration flow - GREATER THAN 30 GPM
Verify charging flow - GREATER THAN 30 GPM RO Check Pressurizer pressure - Less than 2335 psig 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
Turbine trip BOP Check SG levels
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 < 1200F 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.
Informs SM of plant status for evaluation of E-Plan RO Perform Immediate Actions of 1BEP-0 Verify reactor trip
Rod bottom lights lit
Reactor trip and bypass breakers open
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 First Out Annunciator lit (1-11-B/C/D/E1)
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
SI 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:
AFW Aligned:
1A and 1B AFW pumps running
1AF013A-H open
1AF005A-H throttled
1A and 1B CCW pumps running
1A and 1B SX pumps running
Main Steam isolation valves and Main Steam isolation bypass valves isolated when Containment pressure
>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 BOP/US
[CT]
EP-0E NOTE: This sequence may not happen until the size of the LOCA is increased.
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
Verify TEST switch to normal
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
Stop All RCPs
Verifies Eductor Suction flow > 15 gpm (1FI-CS014)
Verifies CS Additive flow > 5 gpm (1FI-CS016)
BOP Align SX Cooling Towers
All eight riser valves open
0SX163A thru 0SX163H
All four Hot Water Basin Bypass valves closed
0SX162A thru 0SX162D
All eight SX Cooling Tower Fans running in high speed.
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
[CT]
EP-0--I Verify ECCS valve alignment
Group 2 Cold Leg Injection monitor lights lit - OPEN 1SI8801B
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
PORV in automatic
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
Damper 0VA023Y open
Damper 0VA436Y closed
Plenum C fan 0VA03CF running
Damper 0VA072Y open
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.
Stop All RCPs.
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.
Informs SM of plant status for evaluation of E-Plan RO Check RCPs
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
PORVs closed
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)
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 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
Main Steam isolation valves and Main Steam isolation bypass valves closed. (previously completed)
Determine NO SGs are faulted:
No Steam Generator pressure decreasing in an uncontrolled manner
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 2
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 3
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 No.
Malf. No.
Event Type*
Event Description Preload RF RP64 OUT RF RP71 OUT RF RP95 OUT RF RP97 OUT FW43 MS01A 75 MS01B 80 MS01C 60 MS01D 90 FW45E, 100 Override ZDI1AF013E AUTO C BOP C BOP C RO BOP SRO C BOP C BOP SRO 1B Auxiliary Feedwater pump fails to auto start, can be manually started.
1A Auxiliary Feedwater pump fails to auto or manually start.
All Main Steam isolation valves fail partially open, no closure available.
1AF005E potentiometer fails to 100% demand.
1AF013E stuck open.
1 RX29A 65 C BOP SRO Steam Generator 1A Feedwater regulating valve Controller card failure resulting in manual control of Feedwater regulating valve 2
R RO SRO N BOP Raise Reactor Power using rods and dilution Ramp up turbine power from 75% to full power.
3 RX13A, 0 I RO SRO 1LT-459, Controlling Pressurizer level channel fails low.
4 CV09, 50 C RO SRO 1TCV-130A modulates closed 5
MS04D, 100 C BOP SRO 1MS018D, 1D SG PORV fails open.
6 CC03B CC01C CC02A I BOP SRO Component Cooling (CC) Surge Tank level transmitter level tree leak results in auto makeup and 1B CC pump trip with failure of 1A CC pump auto start on low header pressure.
7 MS07A, 2.0 (Pre-loaded)
M BOP RO SRO 1A SG Steam line break (2 MLB/HR) inside containment. 4 faulted steam generators.
All MSIVs fail to Close. Stuck open 8
1A and 1B AFW pumps fail to Start C BOP SRO Pre-loaded. 1A Auxiliary Feedwater pump fails to start. 1B Auxiliary Feedwater pump can only be manually started.
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
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.
Tave and control rod motion.
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.
Investigate BARs.
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.
3.3.4 Remote Shutdown System Condition A - Restore within 30 days
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%.
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:
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.
Reactor trip and bypass breakers open.
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 First Out Annunciator lit (1-11-B/C/D/E1)
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 CT E-0--F Verify AFW SYSTEM:
o Report neither AFW pump auto started.
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.
Stop All RCPs.
CS Eductor Suction Flow > 15 gpm (1FI-CS013 or 1FI-CS014).
CS Eductor Additive Flow > 5 gpm (1FI-CS015 or 1FI-CS016).
BOP Align SX Cooling Towers
All eight riser valves open
0SX163A thru 0SX163H
All four Hot Water Basin Bypass valves closed
0SX162A thru 0SX162D
All eight SX Cooling Tower Fans running in high speed Verify total AFW flow:
> 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
Damper 0VA023Y open
Damper 0VA436Y closed
Plenum C fan 0VA03CF running
Damper 0VA072Y open
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:
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.
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).
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.
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.
Stop All RCPs.
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:
No Main Steam isolation valves closed
Main Steam bypass valves closed
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 CT CA-2.1A.
Control Feed Flow to Minimize RCS Cooldown:
Determine cooldown rate in all RCS cold legs > 100 degrees F in any one hour.
Decrease feed flow to 45 gpm to each steam generator.
Report no control of feed flow to 1A Steam Generator.
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.
CS pump header isolation valves open
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.
CS pump discharge flow > 200 gpm (1FI-CS011\\1FI-CS012)
CS eductor suction flow > 15 gpm (1FI-CS013\\ 1FI-CS-014).
CS eductor additive flow > 5 gpm (1FI-CS015\\ 1FI-CS016).
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
All eight SX Cooling Tower Fans running in high speed
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 CT:
CA-2.1A.
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 1AF013F, G, and H.
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.
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.